ENTERPRISE PRODUCTS PARTNERS L.P.
10-Ks and 10-Qs
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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM
10-Q
THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended
September 30, 2023
OR
THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from ___ to ___.
Commission file number:
1-14323
(Exact Name of Registrant as Specified in Its Charter)
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(State or Other Jurisdiction of Incorporation or Organization)
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(I.R.S. Employer Identification No.)
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(Address of Principal Executive Offices, including Zip Code)
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(
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(Registrant’s Telephone Number, including Area Code)
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Securities registered pursuant to Section 12(b) of the Securities Exchange Act of 1934:
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Title of Each Class
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Trading Symbol(s)
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Name of Each Exchange On Which Registered
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Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
Yes
☑
No
☐
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).
Yes
☑
No
☐
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
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Accelerated filer
☐
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Non-accelerated filer
☐
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Smaller reporting company
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Emerging growth company
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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.
☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes
☐
No
☑
There were
2,171,879,003
common units of Enterprise Products Partners L.P. outstanding at the close of business on October 31, 2023.
ENTERPRISE PRODUCTS PARTNERS L.P.
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Page No.
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UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
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September 30,
2023
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December 31,
2022
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ASSETS
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Current assets:
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Cash and cash equivalents
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$
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$
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Restricted cash
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Accounts receivable – trade, net of allowance for credit losses
of $
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Accounts receivable – related parties
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Inventories (see Note 3)
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Derivative assets (see Note 13)
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Prepaid and other current assets
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Total current assets
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Property, plant and equipment, net
(see Note 4)
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Investments in unconsolidated affiliates
(see Note 5)
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Intangible assets, net
(see Note 6)
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Goodwill
(see Note 6)
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Other assets
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Total assets
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$
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$
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LIABILITIES AND EQUITY
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Current liabilities:
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||||||||
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Current maturities of debt (see Note 7)
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$
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$
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Accounts payable – trade
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Accounts payable – related parties
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Accrued product payables
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Accrued interest
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Derivative liabilities (see Note 13)
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Other current liabilities
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Total current liabilities
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Long-term debt
(see Note 7)
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Deferred tax liabilities
(see Note 15)
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Other long-term liabilities
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Commitments and contingent liabilities
(see
Note 16)
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Redeemable preferred limited partner interests:
(see Note 8)
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Series A cumulative convertible preferred units (“preferred units”)
(
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Equity:
(see Note 8)
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Partners’ equity:
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Common limited partner interests (
September 30, 2023
,
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Treasury units, at cost
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(
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)
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(
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Accumulated other comprehensive income
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Total partners’ equity
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Noncontrolling interests in consolidated subsidiaries
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Total equity
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Total liabilities, preferred units, and equity
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$
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$
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See Notes to Unaudited Condensed Consolidated Financial Statements.
UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED OPERATIONS
(Dollars in millions, except per unit amounts)
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For the Three Months
Ended September 30,
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For the Nine Months
Ended September 30,
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2023
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2022
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2023
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2022
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Revenues:
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Third parties
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$
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$
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$
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$
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Related parties
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Total revenues (see Note 9)
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Costs and expenses:
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Operating costs and expenses:
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Third party and other costs
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Related parties
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Total operating costs and expenses
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General and administrative costs:
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Third party and other costs
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Related parties
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Total general and administrative costs
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Total costs and expenses (see Note 10)
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Equity in income of unconsolidated affiliates
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Operating income
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Other income (expense):
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Interest expense
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(
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(
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Interest income
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Other, net
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Total other expense, net
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(
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(
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(
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Income before income taxes
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Provision for income taxes (see Note 15)
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(
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(
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Net income
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Net income attributable to noncontrolling interests
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(
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(
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(
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(
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Net income attributable to preferred units
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(
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(
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(
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(
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Net income attributable to common unitholders
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$
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$
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$
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$
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Earnings per unit:
(see Note 11)
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Basic and diluted earnings per common unit
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$
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$
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$
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$
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See Notes to Unaudited Condensed Consolidated Financial Statements.
UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED
COMPREHENSIVE INCOME
(Dollars in millions)
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For the Three Months
Ended September 30,
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For the Nine Months
Ended September 30,
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2023
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2022
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2023
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2022
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Net income
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$
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$
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$
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$
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Other comprehensive income (loss):
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Cash flow hedges: (see Note 13)
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Commodity hedging derivative instruments:
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Changes in fair value of cash flow hedges
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(
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(
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Reclassificatio
n of losses (
gains)
to ne
t income
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(
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(
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Interest rate hedging derivative instruments:
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Changes in fair value of cash flow hedges
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(
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Reclassification of
losses (gains) to
net income
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(
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(
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Total cash flow hedges
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(
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(
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Total other comprehens
ive income (loss)
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(
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(
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Comprehensive income
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Comprehensive income attributable to noncontrolling interests
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(
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)
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(
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)
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(
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(
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||||||||
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Comprehensive income attributable to preferred units
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(
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(
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)
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(
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(
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||||||||
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Comprehensive income attributable to common unitholders
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$
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$
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$
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$
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See Notes to Unaudited Condensed Consolidated Financial Statements.
UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS
(Dollars in millions)
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For the Nine Months
Ended September 30,
|
|||||||
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2023
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2022
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||||||
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Operating activities:
|
||||||||
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Net income
|
$
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$
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||||
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Reconciliation of net income to net cash flows provided by operating activities:
|
||||||||
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Depreciation and accretion
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Amortization of intangible assets
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Amortization of major maintenance costs for reaction-based plants
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Other amortization expense
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Impairment of assets other than goodwill
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Equity in income of unconsolidated affiliates
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(
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)
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(
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)
|
||||
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Distributions received
from unconsolidated affiliates attributable to earnings
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|
||||||
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Net losses (gains) attributable to asset sales and related matters
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(
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)
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|
|||||
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Deferred income tax expense
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|
||||||
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Change in fair market value of derivative instruments
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|
||||||
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Non-cash expense related to long-term operating leases (see Note 16)
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||||||
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Net effect of changes in operating accounts (see Note 17)
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(
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)
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(
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)
|
||||
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Other operating activities
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|
||||||
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Net cash flows provided by operating activities
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Investing activities:
|
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Capital expenditures
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(
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(
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)
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||||
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Cash used for business combinations, net of cash received (See Note 17)
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(
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)
|
|||||
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Investments in unconsolidated affiliates
|
(
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)
|
(
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)
|
||||
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Distributions received
from unconsolidated affiliates attributable to the return of capital
|
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|
||||||
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Proceeds from asset sales and other matters
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|
||||||
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Other investing activities
|
(
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)
|
(
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)
|
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Cash used in investing activities
|
(
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)
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(
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)
|
||||
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Financing activities:
|
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Borrowings under debt agreements
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Repayments of debt
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(
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)
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(
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|
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Debt issuance costs
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(
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)
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(
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)
|
||||
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Monetization of interest rate derivative instruments
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||||||
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Cash distributions paid to common unitholders (see Note 8)
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(
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)
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(
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)
|
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Cash payments made in connection with distribution equivalent rights
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(
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)
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(
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|
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Cash distributions paid to noncontrolling interests
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(
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)
|
(
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)
|
||||
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Cash contributions from noncontrolling interests
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||||||
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Repurchase of common units under 2019 Buyback Program
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(
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)
|
(
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)
|
||||
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Other financing activities
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(
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)
|
(
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)
|
||||
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Cas
h used in financing ac
tivities
|
(
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)
|
(
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)
|
||||
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Net change in cash and cash equivalents, including restricted cash
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(
|
)
|
|||||
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Cash and cash equivalents, including restricted cash, at beginning of period
|
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|
||||||
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Cash and cash equivalents, including restricted cash, at end of period
|
$
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|
$
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|
||||
See Notes to Unaudited Condensed Consolidated Financial Statements.
UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED EQUITY
FOR THE THREE AND NINE MONTHS ENDED SEPTEMBER 30, 2023
(Dollars in millions)
|
|
Partners’ Equity
|
|||||||||||||||||||
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Common
Limited
Partner
Interests
|
Treasury
Units
|
Accumulated
Other
Comprehensive
Income (Loss)
|
Noncontrolling
Interests in
Consolidated
Subsidiaries
|
Total
|
||||||||||||||||
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For the Three Months
Ended
September 30, 2023
:
|
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Balance June 30, 2023
|
$
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$
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(
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)
|
$
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$
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$
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|||||||||
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Net income
|
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Cash distributions paid to common unitholders
|
(
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)
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(
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)
|
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Cash payments made in connection with
distribution equivalent rights
|
(
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)
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(
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)
|
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Cash distributions paid to noncontrolling interests
|
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(
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)
|
(
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)
|
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Cash contributions from noncontrolling interests
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|
|||||||||||||||
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Amortization of fair value of equity-based awards
|
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|
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|
Cash flow hedges
|
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|
(
|
)
|
|
(
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)
|
|||||||||||||
|
Other, net
|
(
|
)
|
|
|
|
(
|
)
|
|||||||||||||
|
Balance, September 30, 2023
|
$
|
|
$
|
(
|
)
|
$
|
|
$
|
|
$
|
|
|||||||||
|
|
Partners’ Equity
|
|||||||||||||||||||
|
Common
Limited
Partner
Interests
|
Treasury
Units
|
Accumulated
Other
Comprehensive
Income (Loss)
|
Noncontrolling
Interests in
Consolidated
Subsidiaries
|
Total
|
||||||||||||||||
|
For the Nine Months
Ended
September 30, 2023
:
|
||||||||||||||||||||
|
Balance, December 31,
2022
|
$
|
|
$
|
(
|
)
|
$
|
|
$
|
|
$
|
|
|||||||||
|
Net income
|
|
|
|
|
|
|||||||||||||||
|
Cash distributions paid to common unitholders
|
(
|
)
|
|
|
|
(
|
)
|
|||||||||||||
|
Cash payments made in connection with
distribution equivalent rights
|
(
|
)
|
|
|
|
(
|
)
|
|||||||||||||
|
Cash distributions paid to noncontrolling interests
|
|
|
|
(
|
)
|
(
|
)
|
|||||||||||||
|
Cash contributions from noncontrolling interests
|
|
|
|
|
|
|||||||||||||||
|
Repurchase and cancellation of common units under
2019 Buyback Program
|
(
|
)
|
|
|
|
(
|
)
|
|||||||||||||
|
Amortization of fair value of equity-based awards
|
|
|
|
|
|
|||||||||||||||
|
Cash flow hedges
|
|
|
(
|
)
|
|
(
|
)
|
|||||||||||||
|
Other, net
|
(
|
)
|
|
|
(
|
)
|
(
|
)
|
||||||||||||
|
Balance,
September 30, 2023
|
$
|
|
$
|
(
|
)
|
$
|
|
$
|
|
$
|
|
|||||||||
See Notes to Unaudited Condensed Consolidated Financial Statements. For information regarding Unit History and
Accumulated Other Comprehensive Income (Loss), see Note 8.
ENTERPRISE PRODUCTS PARTNERS L.P.
UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED EQUITY
FOR THE THREE AND NINE MONTHS ENDED SEPTEMBER 30, 2022
(Dollars in millions)
|
|
Partners’ Equity
|
|||||||||||||||||||
|
Common
Limited
Partner
Interests
|
Treasury
Units
|
Accumulated
Other
Comprehensive
Income (Loss)
|
Noncontrolling
Interests in
Consolidated
Subsidiaries
|
Total
|
||||||||||||||||
|
For the Three Months Ended
September 30, 2022
:
|
||||||||||||||||||||
|
Balance, June 30, 2022
|
$
|
|
$
|
(
|
)
|
$
|
|
$
|
|
$
|
|
|||||||||
|
Net income
|
|
|
|
|
|
|||||||||||||||
|
Cash distributions paid to common unitholders
|
(
|
)
|
|
|
|
(
|
)
|
|||||||||||||
|
Cash payments made in connection with
distribution equivalent rights
|
(
|
)
|
|
|
|
(
|
)
|
|||||||||||||
|
Cash distributions paid to noncontrolling interests
|
|
|
|
(
|
)
|
(
|
)
|
|||||||||||||
|
Repurchase and cancellation of common units under
2019 Buyback Program
|
(
|
)
|
|
|
|
(
|
)
|
|||||||||||||
|
Amortization of fair value of equity-based awards
|
|
|
|
|
|
|||||||||||||||
|
Cash flow hedges
|
|
|
|
|
|
|||||||||||||||
|
Other, net
|
(
|
)
|
|
|
|
(
|
)
|
|||||||||||||
|
Balance,
September 30, 2022
|
$
|
|
$
|
(
|
)
|
$
|
|
$
|
|
$
|
|
|||||||||
|
|
Partners’ Equity
|
|||||||||||||||||||
|
Common
Limited
Partner
Interests
|
Treasury
Units
|
Accumulated
Other
Comprehensive
Income (Loss)
|
Noncontrolling
Interests in
Consolidated
Subsidiaries
|
Total
|
||||||||||||||||
|
For the Nine Months
Ended September 30,
2022
:
|
||||||||||||||||||||
|
Balance,
December 31, 2021
|
$
|
|
$
|
(
|
)
|
$
|
|
$
|
|
$
|
|
|||||||||
|
Net income
|
|
|
|
|
|
|||||||||||||||
|
Cash distributions paid to common unitholders
|
(
|
)
|
|
|
|
(
|
)
|
|||||||||||||
|
Cash payments made in connection with
distribution equivalent rights
|
(
|
)
|
|
|
|
(
|
)
|
|||||||||||||
|
Cash distributions paid to noncontrolling interests
|
|
|
|
(
|
)
|
(
|
)
|
|||||||||||||
|
Cash contributions from noncontrolling interests
|
|
|
|
|
|
|||||||||||||||
|
Repurchase and cancellation of common units under
2019 Buyback Program
|
(
|
)
|
|
|
|
(
|
)
|
|||||||||||||
|
Amortization of fair value of equity-based awards
|
|
|
|
|
|
|||||||||||||||
|
Cash flow hedges
|
|
|
|
|
|
|||||||||||||||
|
Other, net
|
(
|
)
|
|
|
|
(
|
)
|
|||||||||||||
|
Balance,
September 30, 2022
|
$
|
|
$
|
(
|
)
|
$
|
|
$
|
|
$
|
|
|||||||||
See Notes to Unaudited Condensed Consolidated Financial Statements. For information regarding Unit History and
Accumulated Other Comprehensive Income (Loss), see Note 8.
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
KEY REFERENCES USED IN THESE
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Unless the context requires otherwise, references to “we,” “us” or “our” within these Notes to Unaudited Condensed Consolidated Financial Statements are intended to mean the business and operations of Enterprise Products Partners L.P. and its consolidated subsidiaries.
References to the “Partnership” or “Enterprise” mean Enterprise Products Partners L.P. on a standalone basis.
References to “EPO” mean Enterprise Products Operating LLC, which is an indirect wholly owned subsidiary of the Partnership, and its consolidated subsidiaries, through which the Partnership conducts its business. We are managed by our general partner, Enterprise Products Holdings LLC (“Enterprise GP”), which is a wholly owned subsidiary of Dan Duncan LLC, a privately held Texas limited liability company.
The membership interests of Dan Duncan LLC are owned by a voting trust, the current trustees (“DD LLC Trustees”) of which are: (i) Randa Duncan Williams, who is also a director and Chairman of the Board of Directors of Enterprise GP (the “Board”); (ii) Richard H. Bachmann, who is also a director and Vice Chairman of the Board; and (iii) W. Randall Fowler, who is also a director and the Co-Chief Executive Officer and Chief Financial Officer of Enterprise GP. Ms. Duncan Williams and Messrs. Bachmann and Fowler also currently serve as managers of Dan Duncan LLC.
References to “EPCO” mean Enterprise Products Company, a privately held Texas corporation, and its privately held affiliates. The outstanding voting capital stock of EPCO is owned by a voting trust, the current trustees (“EPCO Trustees”) of which are: (i) Ms. Duncan Williams, who serves as Chairman of EPCO; (ii) Mr. Bachmann, who serves as the President and Chief Executive Officer of EPCO; and (iii) Mr. Fowler, who serves as an Executive Vice President and the Chief Financial Officer of EPCO. Ms. Duncan Williams and Messrs. Bachmann and Fowler also currently serve as directors of EPCO.
We, Enterprise GP, EPCO and Dan Duncan LLC are affiliates under the collective common control of the DD LLC Trustees and the EPCO Trustees. EPCO, together with its privately held affiliates, owned approximately
32.3
% of the Partnership’s common units outstanding at September 30, 2023.
With the exception of per unit amounts, or as noted within the context of each disclosure,
the dollar amounts presented in the tabular data within these disclosures are
stated in millions of dollars.
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Note 1. Partnership Organization and Operations
We are a publicly traded Delaware limited partnership, the common units of which are listed on the New York Stock Exchange (“NYSE”) under the ticker symbol “EPD.” Our preferred units are not publicly traded. We were formed in April 1998 to own and operate certain natural gas liquids (“NGLs”) related businesses of EPCO and are a leading North American provider of midstream energy services to producers and consumers of natural gas, NGLs, crude oil, petrochemicals and refined products. We are owned by our limited partners (preferred and common unitholders) from an economic perspective. Enterprise GP, which owns a non-economic general partner interest in us, manages our Partnership. We conduct substantially all of our business operations through EPO and its consolidated subsidiaries.
Our fully integrated, midstream energy asset network (or “value chain”) links producers of natural gas, NGLs and crude oil from some of the largest supply basins in the United States (“U.S.”), Canada and the Gulf of Mexico with domestic consumers and international markets. Our midstream energy operations include:
| • |
natural gas gathering, treating, processing, transportation and storage;
|
| • |
NGL transportation, fractionation, storage, and marine terminals (including those used to export liquefied petroleum gases (“LPG”) and ethane);
|
| • |
crude oil gathering, transportation, storage, and marine terminals;
|
| • |
propylene production facilities (including propane dehydrogenation (“PDH”) facilities), butane isomerization, octane enhancement, isobutane dehydrogenation (“iBDH”) and high purity isobutylene (“HPIB”) production facilities;
|
| • |
petrochemical and refined products transportation, storage, and marine terminals (including those used to export ethylene and polymer grade propylene (“PGP”)); and
|
| • |
a marine transportation business that operates on key U.S. inland and intracoastal waterway systems.
|
Like many publicly traded partnerships, we have no employees. All of our management, administrative and operating functions are performed by employees of EPCO pursuant to an administrative services agreement (the “ASA”) or by other service providers. See Note 14 for information regarding related party matters.
Our results of operations for the nine months ended September 30, 2023 are not necessarily indicative of results expected for the full year of 2023. In our opinion, the accompanying Unaudited Condensed Consolidated Financial Statements include all adjustments consisting of normal recurring accruals necessary for fair presentation. Although we believe the disclosures in these financial statements are adequate and make the information presented not misleading, certain information and footnote disclosures normally included in annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted pursuant to the rules and regulations of the U.S. Securities and Exchange Commission (“SEC”).
These Unaudited Condensed Consolidated Financial Statements and Notes thereto should be read in conjunction with the Audited Consolidated Financial Statements and Notes thereto included in our annual report on Form 10-K for the year ended December 31, 2022 (the “2022 Form 10-K”) filed with the SEC on February 28, 2023.
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Note 2. Summary of Significant Accounting Policies
Apart from those matters described in this footnote, there have been no updates to our significant accounting policies since those reported under Note 2 of the 2022 Form 10-K.
Allowance for Credit Losses
We estimate our allowance for credit losses at each reporting date using a current expected credit loss model, which requires the measurement of expected credit losses for financial assets (e.g., accounts receivable) based on historical experience with customers, current economic conditions, and reasonable and supportable forecasts. We may also increase the allowance for credit losses in response to the specific identification of customers involved in bankruptcy proceedings and similar financial difficulties.
The following table presents our allowance for credit losses activity since December 31, 2022:
|
Allowance for credit losses, December 31,
2022
|
$
|
|
||
|
Charged to costs and expenses
|
|
|||
|
Charged to other accounts
|
|
|||
|
Deductions
|
(
|
)
|
||
|
Allowance for credit losses,
September 30, 2023
|
$
|
|
Cash, Cash Equivalents and Restricted Cash
The following table provides a reconciliation of cash and cash equivalents, and restricted cash reported within the Unaudited Condensed Consolidated Balance Sheets that sum to the total of the amounts shown in the Unaudited Condensed Statements of Consolidated Cash Flows.
|
September 30,
2023
|
December 31,
2022
|
|||||||
|
Cash and cash equivalents
|
$
|
|
$
|
|
||||
|
Restricted cash
|
|
|
||||||
|
Total cash, cash equivalents and restricted cash shown in the
Unaudited Condensed Statements of Consolidated Cash Flows
|
$
|
|
$
|
|
||||
Restricted cash primarily represents amounts held in segregated bank accounts by our clearing brokers as margin in support of our commodity derivative instruments portfolio and related physical purchases and sales of natural gas, NGLs, crude oil, refined products and power. Additional cash may be restricted to maintain our commodity derivative instruments portfolio as prices fluctuate or margin requirements change. See Note 13 for information regarding our derivative instruments and hedging activities.
Note 3. Inventories
Our inventory amounts by product type were as follows at the dates indicated:
|
September 30,
2023
|
December 31,
2022
|
|||||||
|
NGLs
|
$
|
|
$
|
|
||||
|
Petrochemicals and refined products
|
|
|
||||||
|
Crude oil
|
|
|
||||||
|
Natural gas
|
|
|
||||||
|
Total
|
$
|
|
$
|
|
||||
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Due to fluctuating commodity prices, we recognize lower of cost or net realizable value adjustments when the carrying value of our available-for-sale inventories exceeds their net realizable value. The following table presents our total cost of sales amounts and lower of cost or net realizable value adjustments for the periods indicated:
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Cost of sales (1)
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Lower of cost or net realizable value adjustments
recognized in cost of sales
|
|
|
|
|
||||||||||||
|
(1)
|
|
Note 4. Property, Plant and Equipment
The historical costs of our property, plant and equipment and related balances were as follows at the dates indicated:
|
|
Estimated
Useful Life
in Years
|
September 30,
2023
|
December 31,
2022
|
|||||||||
|
Plants, pipelines and facilities (1)(5)
|
|
$
|
|
$
|
|
|||||||
|
Underground and other storage facilities (2)(6)
|
|
|
|
|||||||||
|
Transportation equipment (3)
|
|
|
|
|||||||||
|
Marine vessels (4)
|
|
|
|
|||||||||
|
Land
|
|
|
||||||||||
|
Construction in progress
|
|
|
||||||||||
|
Subtotal
|
|
|
||||||||||
|
Less accumulated depreciation
|
|
|
||||||||||
|
Subtotal property, plant and equipment, net
|
|
|
||||||||||
|
Capitalized major maintenance costs for reaction-based
plants, net of accumulated amortization (7)
|
|
|
||||||||||
|
Property, plant and equipment, net
|
$
|
|
$
|
|
||||||||
|
(1)
|
|
|
(2)
|
|
|
(3)
|
|
|
(4)
|
|
|
(5)
|
|
|
(6)
|
|
|
(7)
|
|
Property, plant and equipment at September 30, 2023 and December 31, 2022 includes $
107
million and $
117
million, respectively, of asset retirement costs capitalized as an increase in the associated long-lived asset.
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
The following table presents information regarding our asset retirement obligations, or AROs, since December 31, 2022:
|
ARO liability balance,
December 31, 2022
|
$
|
|
||
|
Liabilities incurred (1)
|
|
|||
|
Revisions in estimated cash flows (2)
|
(
|
)
|
||
|
Liabilities settled (3)
|
(
|
)
|
||
|
Accretion expense (4)
|
|
|||
|
ARO liability balance,
September 30, 2023
|
$
|
|
|
(1)
|
|
|
(2)
|
|
|
(3)
|
|
|
(4)
|
|
Of the
$
223
million total ARO liability recorded at
September 30, 2023
, $
7
million was reflected as a current liability and $
216
million as a long-term liability.
The following table summarizes our depreciation expense and capitalized interest amounts for the periods indicated:
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
|||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Depreciation expense (1)
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Capitalized interest (2)
|
|
|
|
|
||||||||||||
|
(1)
|
|
|
(2)
|
|
Note 5. Investments in Unconsolidated Affiliates
The following table presents our investments in unconsolidated affiliates by business segment at the dates indicated. We account for these investments using the equity method.
|
September 30,
2023
|
December 31,
2022
|
|||||||
|
NGL Pipelines & Services
|
$
|
|
$
|
|
||||
|
Crude Oil Pipelines & Services
|
|
|
||||||
|
Natural Gas Pipelines & Services
|
|
|
||||||
|
Petrochemical & Refined Products Services
|
|
|
||||||
|
Total
|
$
|
|
$
|
|
||||
The following table presents our equity in income of unconsolidated affiliates by business segment for the periods indicated:
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
|||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
NGL Pipelines & Services
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Crude Oil Pipelines & Services
|
|
|
|
|
||||||||||||
|
Natural Gas Pipelines & Services
|
|
|
|
|
||||||||||||
|
Petrochemical & Refined Products Services
|
|
|
|
|
||||||||||||
|
Total
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Note 6. Intangible Assets and Goodwill
Identifiable Intangible Assets
The following table summarizes our intangible assets by business segment at the dates indicated:
|
September 30, 2023
|
December 31, 2022
|
|||||||||||||||||||||||
|
|
Gross
Value
|
Accumulated
Amortization
|
Carrying
Value
|
Gross
Value
|
Accumulated
Amortization
|
Carrying
Value
|
||||||||||||||||||
|
NGL Pipelines & Services:
|
||||||||||||||||||||||||
|
Customer relationship intangibles
|
$
|
|
$
|
(
|
)
|
$
|
|
$
|
|
$
|
(
|
)
|
$
|
|
||||||||||
|
Contract-based intangibles
|
|
(
|
)
|
|
|
(
|
)
|
|
||||||||||||||||
|
Segment total
|
|
(
|
)
|
|
|
(
|
)
|
|
||||||||||||||||
|
Crude Oil Pipelines & Services:
|
||||||||||||||||||||||||
|
Customer relationship intangibles
|
|
(
|
)
|
|
|
(
|
)
|
|
||||||||||||||||
|
Contract-based intangibles
|
|
(
|
)
|
|
|
(
|
)
|
|
||||||||||||||||
|
Segment total
|
|
(
|
)
|
|
|
(
|
)
|
|
||||||||||||||||
|
Natural Gas Pipelines & Services:
|
||||||||||||||||||||||||
|
Customer relationship intangibles
|
|
(
|
)
|
|
|
(
|
)
|
|
||||||||||||||||
|
Contract-based intangibles
|
|
(
|
)
|
|
|
(
|
)
|
|
||||||||||||||||
|
Segment total
|
|
(
|
)
|
|
|
(
|
)
|
|
||||||||||||||||
|
Petrochemical & Refined Products Services:
|
||||||||||||||||||||||||
|
Customer relationship intangibles
|
|
(
|
)
|
|
|
(
|
)
|
|
||||||||||||||||
|
Contract-based intangibles
|
|
(
|
)
|
|
|
(
|
)
|
|
||||||||||||||||
|
Segment total
|
|
(
|
)
|
|
|
(
|
)
|
|
||||||||||||||||
|
Total intangible assets
|
$
|
|
$
|
(
|
)
|
$
|
|
$
|
|
$
|
(
|
)
|
$
|
|
||||||||||
The following table presents the amortization expense of our intangible assets by business segment for the periods indicated:
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
NGL Pipelines & Services
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Crude Oil Pipelines & Services
|
|
|
|
|
||||||||||||
|
Natural Gas Pipelines & Services
|
|
|
|
|
||||||||||||
|
Petrochemical & Refined Products Services
|
|
|
|
|
||||||||||||
|
Total
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
The following table presents our forecast of amortization expense associated with existing intangible assets for the periods indicated:
|
Remainder
of 2023
|
2024
|
2025
|
2026
|
2027
|
||||||||||||||
|
$
|
|
$
|
|
$
|
|
$
|
|
$
|
|
|||||||||
Goodwill
Goodwill represents the excess of the purchase price of an acquired business over the amounts assigned to assets acquired and liabilities assumed in the transaction. There has been no change in our goodwill amounts since those reported in our 2022 Form 10-K.
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Note 7. Debt Obligations
The following table presents our consolidated debt obligations (arranged by company and maturity date) at the dates indicated:
|
September 30,
2023
|
December 31,
2022
|
|||||||
|
EPO senior debt obligations:
|
||||||||
|
Commercial Paper Notes, variable-rates
|
$
|
|
$
|
|
||||
|
Senior Notes HH,
|
|
|
||||||
|
Senior Notes JJ,
|
|
|
||||||
|
March 2023 $1.5 Billion 364-Day Revolving Credit Agreement, variable-rate, due March 2024 (1)
|
|
|
||||||
|
Senior Notes MM,
|
|
|
||||||
|
Senior Notes FFF,
|
|
|
||||||
|
Senior Notes PP,
|
|
|
||||||
|
Senior Notes SS,
|
|
|
||||||
|
March 2023 $2.7 Billion Multi-Year Revolving Credit Agreement, variable-rate, due March 2028 (2)
|
|
|
||||||
|
Senior Notes WW,
|
|
|
||||||
|
Senior Notes YY,
|
|
|
||||||
|
Senior Notes AAA,
|
|
|
||||||
|
Senior Notes GGG,
|
|
|
||||||
|
Senior Notes D,
|
|
|
||||||
|
Senior Notes H,
|
|
|
||||||
|
Senior Notes J,
|
|
|
||||||
|
Senior Notes W,
|
|
|
||||||
|
Senior Notes R,
|
|
|
||||||
|
Senior Notes Z,
|
|
|
||||||
|
Senior Notes BB,
|
|
|
||||||
|
Senior Notes DD,
|
|
|
||||||
|
Senior Notes EE,
|
|
|
||||||
|
Senior Notes GG,
|
|
|
||||||
|
Senior Notes II,
|
|
|
||||||
|
Senior Notes KK,
|
|
|
||||||
|
Senior Notes QQ,
|
|
|
||||||
|
Senior Notes UU,
|
|
|
||||||
|
Senior Notes XX,
|
|
|
||||||
|
Senior Notes ZZ,
|
|
|
||||||
|
Senior Notes BBB,
|
|
|
||||||
|
Senior Notes DDD,
|
|
|
||||||
|
Senior Notes EEE,
|
|
|
||||||
|
Senior Notes NN,
|
|
|
||||||
|
Senior Notes CCC,
|
|
|
||||||
|
Total principal amount of senior debt obligations
|
|
|
||||||
|
EPO Junior Subordinated Notes C, variable-rate, due June 2067
(3)(7)
|
|
|
||||||
|
EPO Junior Subordinated Notes D, variable-rate, due August 2077
(4)(7)
|
|
|
||||||
|
EPO Junior Subordinated Notes E, fixed/variable-rate, due August 2077
(5)(7)
|
|
|
||||||
|
EPO Junior Subordinated Notes F, fixed/variable-rate, due February 2078
(6)(7)
|
|
|
||||||
|
TEPPCO Junior Subordinated Notes, variable-rate, due June 2067
(3)(7)
|
|
|
||||||
|
Total principal amount of senior and junior debt obligations
|
|
|
||||||
|
Other, non-principal amounts
|
(
|
)
|
(
|
)
|
||||
|
Less current maturities of debt
|
(
|
)
|
(
|
)
|
||||
|
Total long-term debt
|
$
|
|
$
|
|
||||
|
(1)
|
|
|
(2)
|
|
|
(3)
|
|
|
(4)
|
|
|
(5)
|
|
|
(6)
|
|
|
(7)
|
|
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
References to “TEPPCO” mean TEPPCO Partners, L.P. prior to its merger with one of our wholly owned subsidiaries in October 2009.
Variable Interest Rates
The following table presents the range of interest rates and weighted-average interest rates paid on our consolidated variable-rate debt during the nine months ended September 30, 2023:
|
|
Range of Interest
Rates Paid
|
Weighted-Average
Interest Rate Paid
|
|
Commercial Paper Notes
|
|
|
|
EPO Junior Subordinated Notes C and TEPPCO Junior Subordinated Notes
|
|
|
|
EPO Junior Subordinated Notes D
|
|
|
Amounts borrowed under EPO’s March 2023 $1.5 Billion 364-Day Revolving Credit Agreement and March 2023 $2.7 Billion Multi-Year Revolving Credit Agreement bear interest, at EPO’s election, equal to: (i)
SOFR, plus an additional variable spread; or (ii) an alternate base rate, which is the greatest of (a) the Prime Rate in effect on such day, (b) the Federal Funds Effective Rate in effect on such day plus 0.5%, or (c) Adjusted Term SOFR, for an interest period of one month in effect on such day plus 1%, and a variable spread. The applicable spreads are determined based on EPO's debt ratings.
In July 2017, the Financial Conduct Authority in the U.K. announced a desire to phase out LIBOR as a benchmark by the end of June 2023. In December 2022, the Board of Governors of the Federal Reserve System approved a final rule to implement the Adjustable Interest Rate (LIBOR) Act, which established benchmark replacements for certain contracts that reference various tenors of LIBOR and do not provide an alternative rate or would result in a rate that is expressed in terms of the last known value of LIBOR (typically referred to as a “frozen LIBOR” provision). The final rule became effective during the first quarter of 2023.
As a result of the LIBOR Act, our Junior Subordinated Notes C and D and the TEPPCO Junior Subordinated Notes, which were subject to a variable rate (as defined by the applicable agreement) based on three-month LIBOR (in each case, a “LIBOR Rate”) through June 30, 2023, replaced the applicable LIBOR Rate with a variable rate based on the three-month CME Term SOFR as administered by the CME Group Benchmark Administration, Ltd. plus a 0.26161% tenor spread adjustment beginning on July 1, 2023.
Additionally, our Junior Subordinated Notes E and F, which would have been subject to a variable rate (as defined by the applicable agreement) based on three-month LIBOR beginning in August 2027 and February 2028, respectively, will replace the applicable LIBOR Rate with the three-month CME Term SOFR plus a 0.26161% tenor spread adjustment.
The foregoing tenor spread adjustment will be in addition to the applicable spread under the terms of each series of Junior Subordinated Notes. We do not expect the transition from LIBOR to have a material financial impact on us.
Scheduled Maturities of Debt
The following table presents the scheduled maturities of principal amounts of EPO’s consolidated debt obligations at September 30, 2023 for the next five years, and in total thereafter:
|
|
Scheduled Maturities of Debt
|
|||||||||||||||||||||||||||
|
|
Total
|
Remainder
of 2023
|
2024
|
2025
|
2026
|
2027
|
Thereafter
|
|||||||||||||||||||||
|
Commercial Paper Notes
|
$
|
|
$
|
|
$
|
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||||||||
|
Senior Notes
|
|
|
|
|
|
|
|
|||||||||||||||||||||
|
Junior Subordinated Notes
|
|
|
|
|
|
|
|
|||||||||||||||||||||
|
Total
|
$
|
|
$
|
|
$
|
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||||||||
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
March 2023 $1.5 Billion 364-Day Revolving Credit Agreement
In March 2023, EPO entered into a new 364-Day Revolving Credit Agreement (the “March 2023 $1.5 Billion 364-Day Revolving Credit Agreement”) that replaced its September 2022 364-Day Revolving Credit Agreement. There were no principal amounts outstanding under the September 2022 364-Day Revolving Credit Agreement when it was replaced by the March 2023 $1.5 Billion 364-Day Revolving Credit Agreement. As of September 30, 2023, there were no principal amounts outstanding under the March 2023 $1.5 Billion 364-Day Revolving Credit Agreement.
Under the terms of the March 2023 $1.5 Billion 364-Day Revolving Credit Agreement, EPO may borrow up to $
1.5
billion (which may be increased by up to $
200
million to $
1.7
billion at EPO’s election, provided certain conditions are met) at a variable interest rate for a term of up to 364 days, subject to the terms and conditions set forth therein. The March 2023 $1.5 Billion 364-Day Revolving Credit Agreement matures in March 2024. To the extent that principal amounts are outstanding at the maturity date, EPO may elect to have the entire principal balance then outstanding continued as non-revolving term loans for a period of one additional year, payable in March 2025. Borrowings under the March 2023 $1.5 Billion 364-Day Revolving Credit Agreement may be used for working capital, capital expenditures, acquisitions and general company purposes.
The March 2023 $1.5 Billion 364-Day Revolving Credit Agreement contains customary representations, warranties, covenants (affirmative and negative) and events of default, the occurrence of which would permit the lenders to accelerate the maturity date of any amounts borrowed under this credit agreement. The March 2023 $1.5 Billion 364-Day Revolving Credit Agreement also restricts EPO’s ability to pay cash distributions to the Partnership, if an event of default (as defined in the credit agreement) has occurred and is continuing at the time such distribution is scheduled to be paid or would result therefrom.
EPO’s obligations under the March 2023 $1.5 Billion 364-Day Revolving Credit Agreement are not secured by any collateral; however, they are guaranteed by the Partnership.
March 2023 $2.7 Billion Multi-Year Revolving Credit Agreement
In March 2023, EPO entered into a new revolving credit agreement that matures in March 2028 (the “March 2023 $2.7 Billion Multi-Year Revolving Credit Agreement”). The March 2023 $2.7 Billion Multi-Year Revolving Credit Agreement replaced EPO’s prior multi-year revolving credit agreement that was scheduled to mature in September 2026. There were no principal amounts outstanding under the prior multi-year revolving credit agreement when it was replaced by the March 2023 $2.7 Billion Multi-Year Revolving Credit Agreement.
As of
September 30, 2023
, there were no principal amounts outstanding under the March 2023 $2.7 Billion Multi-Year Revolving Credit Agreement.
Under the terms of the March 2023 $2.7 Billion Multi-Year Revolving Credit Agreement, EPO may borrow up to $
2.7
billion (which may be increased by up to $
500
million to $
3.2
billion at EPO’s election, provided certain conditions are met) at a variable interest rate for a term of five years, subject to the terms and conditions set forth therein. The March 2023 $2.7 Billion Multi-Year Revolving Credit Agreement matures in March 2028, although the maturity date may be extended at EPO’s request (up to two requests) for a one-year extension of the maturity date by delivering a request prior to the maturity date and with the consent of required lenders as set forth under the March 2023 $2.7 Billion Multi-Year Revolving Credit Agreement. Borrowings under the March 2023 $2.7 Billion Multi-Year Revolving Credit Agreement may be used for working capital, capital expenditures, acquisitions and general company purposes.
The March 2023 $2.7 Billion Multi-Year Revolving Credit Agreement contains customary representations, warranties, covenants (affirmative and negative) and events of default, the occurrence of which would permit the lenders to accelerate the maturity date of any amounts borrowed under this credit agreement. The March 2023 $2.7 Billion Multi-Year Revolving Credit Agreement also restricts EPO’s ability to pay cash distributions to the Partnership, if an event of default (as defined in the credit agreement) has occurred and is continuing at the time such distribution is scheduled to be paid or would result therefrom.
EPO’s obligations under the March 2023 $2.7 Billion Multi-Year Revolving Credit Agreement are not secured by any collateral; however, they are guaranteed by the Partnership.
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Issuance of $1.75 Billion of Senior Notes in January 2023
In January 2023, EPO issued $
1.75
billion aggregate principal amount of senior notes comprised of (i) $
750
million principal amount of senior notes due January 2026 (“Senior Notes FFF”) and (ii) $
1.0
billion principal amount of senior notes due January 2033 (“Senior Notes GGG”).
Net proceeds from this offering were used by EPO for general company purposes, including for growth capital investments, and the repayment of debt (including the repayment of all of our $
1.25
billion principal amount of
3.35
%
Senior Notes HH at their maturity in March 2023 and amounts outstanding under our commercial paper program).
Senior Notes FFF were issued at
99.893
% of their principal amount and have a fixed-rate interest rate of
5.05
% per year. Senior Notes GGG were issued at
99.803
% of their principal amount and have a fixed-rate interest rate of
5.35
% per year. The Partnership guaranteed these senior notes through an unconditional guarantee on an unsecured and unsubordinated basis.
Letters of Credit
At September 30, 2023, EPO had $
152
million of letters of credit outstanding primarily related to our commodity hedging activities.
Lender Financial Covenants
We were in compliance with the financial covenants of our consolidated debt agreements at September 30, 2023.
Parent-Subsidiary Guarantor Relationships
The Partnership acts as guarantor of the consolidated debt obligations of EPO, with the exception of the remaining debt obligations of TEPPCO. If EPO were to default on any of its guaranteed debt, the Partnership would be responsible for full and unconditional repayment of such obligations.
Note 8. Capital Accounts
Common Limited Partner Interests
The following table summarizes changes in the number of our common units outstanding since December 31, 2022:
|
Common units outstanding at December 31,
2022
|
|
|||
|
Common unit repurchases under 2019 Buyback Program
|
(
|
)
|
||
|
Common units issued in connection with the vesting of phantom unit awards, net
|
|
|||
|
Other
|
|
|||
|
Common units outstanding at March 31, 2023
|
|
|||
|
Common unit repurchases under 2019 Buyback Program
|
(
|
)
|
||
|
Common units issued in connection with the vesting of phantom unit awards, net
|
|
|||
|
Common units outstanding at June 30, 2023
|
|
|||
|
Common units issued in connection with the vesting of phantom unit awards, net
|
|
|||
|
Common units outstanding at September 30, 2023
|
|
Registration Statements
We have a universal shelf registration statement on file with the SEC which allows the Partnership and EPO (each on a standalone basis) to issue an unlimited amount of equity and debt securities, respectively.
In addition, the Partnership has a registration statement on file with the SEC covering the issuance of up to $
2.5
billion of its common units in amounts, at prices and on terms based on market conditions and other factors at the time of such offerings (referred to as the Partnership’s at-the-market (“ATM”) program). The Partnership did not issue any common units under its ATM program during the
nine months ended September 30, 2023
. The Partnership’s capacity to issue additional common units under the ATM program remains at
$
2.5
billion as of September 30, 2023.
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
We may issue additional equity and debt securities to assist us in meeting our future liquidity requirements, including those related to capital investments.
Common Unit Repurchases Under 2019 Buyback Program
In January 2019, we announced that the Board had approved a $
2.0
billion multi-year unit buyback program (the “2019 Buyback Program”), which provides the Partnership with an additional method to return capital to investors. The 2019 Buyback Program authorizes the Partnership to repurchase its common units from time to time, including through open market purchases and negotiated transactions. No time limit has been set for completion of the program, and it may be suspended or discontinued at any time.
The Partnership elected not to repurchase common units during the three months ended September 30, 2023. During the nine months ended September 30, 2023, the Partnership repurchased
3,592,710
common units under the 2019 Buyback Program through open market purchases
.
The total cost of these repurchases, including commissions and fees, was $
92
million. During the three and
nine months ended September 30, 2022
, the Partnership repurchased
2,925,842
and
4,333,963
common units, respectively, under the 2019 Buyback Program through open market purchases. The total cost of these repurchases, including commissions and fees, was $
72
million and $
107
million, respectively. Common units
repurchased under the 2019 Buyback Program are immediately cancelled upon acquisition. At September 30, 2023, the remaining available capacity under the
2019 Buyback Program was $
1.2
billion.
Common Units Issued in Connection With the Vesting of Phantom Unit Awards
After taking into account tax withholding requirements, the Partnership issued
4,644,474
new
common units to employees in connection with the vesting of phantom unit awards
during the
nine months ended September 30, 2023. See Note 12 for information regarding our phantom unit awards.
Common Units Delivered Under DRIP and EUPP
The Partnership has registration statements on file with the SEC in connection with its distribution reinvestment plan (“DRIP”) and employee unit purchase plan (“EUPP”). In July 2019, the Partnership announced that, beginning with the quarterly distribution payment paid in August 2019, it would use common units purchased on the open market, rather than issuing new common units, to satisfy its delivery obligations under the DRIP and EUPP. This election is subject to change in future quarters depending on the Partnership’s need for equity capital.
During the
nine months ended September 30, 2023
, agents of the Partnership purchased
4,986,549
common units on the open market and delivered them to participants in the DRIP and EUPP. Apart from $
2
million
attributable to the plan discount available to all participants in the EUPP, the funds used to effect these purchases were sourced from the DRIP and EUPP participants. No other Partnership funds were used to satisfy these obligations. We plan to use open market purchases to satisfy DRIP and EUPP reinvestments in connection with the distribution expected to be paid on November 14, 2023.
Preferred Units
There were
50,412
of our Series A Cumulative Convertible Preferred Units (“preferred units”) outstanding at September 30, 2023.
We present the capital accounts attributable to our preferred unitholders as mezzanine equity on our consolidated balance sheets since the terms of the preferred units allow for cash redemption by such unitholders in the event of a Change of Control (as defined in our partnership agreement), without regard to the likelihood of such an event.
During the nine months ended September 30, 2023, the Partnership made quarterly cash distributions to its preferred unitholders of $
3
million.
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Accumulated Other Comprehensive Income (Loss)
The following tables present the components of accumulated other comprehensive income (loss) as reported on our Unaudited Condensed Consolidated Balance Sheets at the dates indicated:
|
|
Cash Flow Hedges
|
|||||||||||||||
|
|
Commodity
Derivative
Instruments
|
Interest Rate
Derivative
Instruments
|
Other
|
Total
|
||||||||||||
|
Accumulated Other Comprehensive Income (Loss),
December 31, 2022
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Other comprehensive income (loss) for period, before reclassifications
|
(
|
)
|
(
|
)
|
|
(
|
)
|
|||||||||
|
Reclassification of losses (gains) to net income during period
|
(
|
)
|
(
|
)
|
|
(
|
)
|
|||||||||
|
Total other comprehensive income (loss) for period
|
(
|
)
|
(
|
)
|
|
(
|
)
|
|||||||||
|
Accumulated Other Comprehensive Income (Loss),
September 30, 2023
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Cash Flow Hedges
|
||||||||||||||||
|
|
Commodity
Derivative
Instruments
|
Interest Rate
Derivative
Instruments
|
Other
|
Total
|
||||||||||||
|
Accumulated Other Comprehensive Income (Loss),
December 31, 2021
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Other comprehensive income (loss) for period, before reclassifications
|
|
|
|
|
||||||||||||
|
Reclassification of losses (gains) to net income during period
|
(
|
)
|
|
|
(
|
)
|
||||||||||
|
Total other comprehensive income (loss) for period
|
|
|
|
|
||||||||||||
|
Accumulated Other Comprehensive Income (Loss),
September 30, 2022
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
The following table presents reclassifications of (income) loss out of accumulated other comprehensive income into net income during the periods indicated:
|
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
Losses (gains) on cash flow hedges:
|
Location
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Interest rate derivatives
|
Interest expense
|
$
|
(
|
)
|
$
|
|
$
|
(
|
)
|
$
|
|
||||||
|
Commodity derivatives
|
Revenue
|
|
|
|
(
|
)
|
|||||||||||
|
Commodity derivatives
|
Operating costs and expenses
|
(
|
)
|
(
|
)
|
(
|
)
|
(
|
)
|
||||||||
|
Total
|
|
$
|
|
$
|
|
$
|
(
|
)
|
$
|
(
|
)
|
||||||
For information regarding our interest rate and commodity derivative instruments, see Note 13.
Cash Distributions
On October 5, 2023, we announced that the Board declared a quarterly cash distribution of $
0.50
per common unit, or $
2.00
per common unit on an annualized basis, to be paid to the Partnership’s common unitholders with respect to the third quarter of 2023. The quarterly distribution is payable on November 14, 2023 to unitholders of record as of the close of business on October 31, 2023. The total amount to be paid is $
1.1
billion, which includes $
10
million for distribution equivalent rights (“DERs”) on phantom unit awards.
The payment of quarterly cash distributions is subject to management’s evaluation of our financial condition, results of operations and cash flows in connection with such payments and Board approval. Management will evaluate any future increases in cash distributions on a quarterly basis.
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Note 9. Revenues
We classify our revenues into sales of products and midstream services. Product sales relate primarily to our various marketing activities whereas midstream services represent our other integrated businesses (i.e., gathering, processing, transportation, fractionation, storage and terminaling). The following table presents our revenues by business segment, and further by revenue type, for the periods indicated:
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
NGL Pipelines & Services:
|
||||||||||||||||
|
Sales of NGLs and related products
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Segment midstream services:
|
||||||||||||||||
|
Natural gas processing and fractionation
|
|
|
|
|
||||||||||||
|
Transportation
|
|
|
|
|
||||||||||||
|
Storage and terminals
|
|
|
|
|
||||||||||||
|
Total segment midstream services
|
|
|
|
|
||||||||||||
|
Total NGL Pipelines & Services
|
|
|
|
|
||||||||||||
|
Crude Oil Pipelines & Services:
|
||||||||||||||||
|
Sales of crude oil
|
|
|
|
|
||||||||||||
|
Segment midstream services:
|
||||||||||||||||
|
Transportation
|
|
|
|
|
||||||||||||
|
Storage and terminals
|
|
|
|
|
||||||||||||
|
Total segment midstream services
|
|
|
|
|
||||||||||||
|
Total Crude Oil Pipelines & Services
|
|
|
|
|
||||||||||||
|
Natural Gas Pipelines & Services:
|
||||||||||||||||
|
Sales of natural gas
|
|
|
|
|
||||||||||||
|
Segment midstream services:
|
||||||||||||||||
|
Transportation
|
|
|
|
|
||||||||||||
|
Total segment midstream services
|
|
|
|
|
||||||||||||
|
Total Natural Gas Pipelines & Services
|
|
|
|
|
||||||||||||
|
Petrochemical & Refined Products Services:
|
||||||||||||||||
|
Sales of petrochemicals and refined products
|
|
|
|
|
||||||||||||
|
Segment midstream services:
|
||||||||||||||||
|
Fractionation and isomerization
|
|
|
|
|
||||||||||||
|
Transportation, including marine logistics
|
|
|
|
|
||||||||||||
|
Storage and terminals
|
|
|
|
|
||||||||||||
|
Total segment midstream services
|
|
|
|
|
||||||||||||
|
Total Petrochemical & Refined Products Services
|
|
|
|
|
||||||||||||
|
Total consolidated revenues
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
Substantially all of our revenues are derived from contracts with customers as defined within Accounting Standards Codification (“ASC”) 606,
Revenue from Contracts with Customers
.
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Unbilled Revenue and Deferred Revenue
The following table provides information regarding our contract assets and contract liabilities at September 30, 2023:
|
Contract Asset
|
Location
|
Balance
|
|||
|
Unbilled revenue (current amount)
|
Prepaid and other current assets
|
$
|
|
||
|
Total
|
$
|
|
|||
|
Contract Liability
|
Location
|
Balance
|
|||
|
Deferred revenue (current amount)
|
Other current liabilities
|
$
|
|
||
|
Deferred revenue (noncurrent)
|
Other long-term liabilities
|
|
|||
|
Total
|
$
|
|
|||
The following table presents significant changes in our unbilled revenue and deferred revenue balances for the nine months ended September 30, 2023:
|
Unbilled
Revenue
|
Deferred
Revenue
|
|||||||
|
Balance at December 31, 2022
|
$
|
|
$
|
|
||||
|
Amount included in opening balance transferred to other accounts during period (1)
|
(
|
)
|
(
|
)
|
||||
|
Amount recorded during period (2)
|
|
|
||||||
|
Amounts recorded during period transferred to other accounts (1)
|
(
|
)
|
(
|
)
|
||||
|
Other changes
|
|
(
|
)
|
|||||
|
Balance at September 30, 2023
|
$
|
|
$
|
|
||||
|
(1)
|
|
|
(2)
|
|
Remaining Performance Obligations
The following table presents estimated fixed future consideration from revenue contracts that contain minimum volume commitments, deficiency and similar fees and the term of the contracts exceeds one year. These amounts represent the revenues we expect to recognize in future periods from these contracts as of September 30, 2023.
|
Period
|
Fixed
Consideration
|
|||
|
|
$
|
|
||
|
|
|
|||
|
|
|
|||
|
|
|
|||
|
|
|
|||
|
Thereafter
|
|
|||
|
Total
|
$
|
|
||
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Note 10. Business Segments and Related Information
Our operations are reported under
four
business segments: (i) NGL Pipelines & Services, (ii) Crude Oil Pipelines & Services, (iii) Natural Gas Pipelines & Services and (iv) Petrochemical & Refined Products Services. Our business segments are generally organized and managed according to the types of services rendered (or technologies employed) and products produced and/or sold.
Financial information regarding these segments is evaluated regularly by our co-chief operating decision makers in deciding how to allocate resources and in assessing our operating and financial performance. The co-principal executive officers of our general partner have been identified as our co-chief operating decision makers. While these two officers evaluate results in a number of different ways, the business segment structure is the primary basis for which the allocation of resources and financial results are assessed.
The following information summarizes the assets and operations of each business segment:
| • |
Our NGL Pipelines & Services
business segment includes our natural gas processing and related NGL marketing activities, NGL pipelines, NGL fractionation facilities, NGL and related product storage facilities, and NGL marine terminals
.
|
| • |
Our Crude Oil Pipelines & Services business segment includes our crude oil pipelines, crude oil storage and marine terminals, and related crude oil marketing activities.
|
| • |
Our Natural Gas Pipelines & Services business segment includes our natural gas pipeline systems that provide for the gathering, treating and transportation of natural gas. This segment also includes our natural gas marketing activities.
|
| • |
Our Petrochemical & Refined Products Services
business segment includes our (i) propylene production facilities, which include propylene fractionation units and PDH facilities, and related pipelines and marketing activities, (ii) butane isomerization complex and related deisobutanizer operations, (iii) octane enhancement, iBDH and HPIB production facilities, (iv) refined products pipelines, terminals and related marketing activities, (v) ethylene export terminal and related operations; and (vi) marine transportation business
.
|
Segment 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. Gross operating margin is exclusive of other income and expense transactions, income taxes, the cumulative effect of changes in accounting principles and extraordinary charges. Gross operating margin is presented on a 100% basis before any allocation of earnings to noncontrolling interests. Our calculation of gross operating margin may or may not be comparable to similarly titled measures used by other companies.
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
The following table presents our measurement of total segment gross operating margin for the periods presented. The GAAP financial measure most directly comparable to total segment gross operating margin is operating income.
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Operating income
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Adjustments to reconcile operating income to total segment gross operating margin
(addition or subtraction indicated by sign):
|
||||||||||||||||
|
Depreciation, amortization and accretion expense in operating costs and expenses (1)
|
|
|
|
|
||||||||||||
|
Asset impairment charges in operating costs and expenses
|
|
|
|
|
||||||||||||
|
Net losses (gains) attributable to asset sales and related matters in operating costs
and expenses
|
|
|
(
|
)
|
|
|||||||||||
|
General and administrative costs
|
|
|
|
|
||||||||||||
|
Non-refundable payments received from shippers attributable to make-up rights (2)
|
|
|
|
|
||||||||||||
|
Subsequent recognition of revenues attributable to make-up rights (3)
|
(
|
)
|
(
|
)
|
(
|
)
|
(
|
)
|
||||||||
|
Total segment gross operating margin
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
(1)
|
|
|
(2)
|
|
|
(3)
|
|
Gross operating margin by segment is calculated by subtracting segment operating costs and expenses from segment revenues, with both segment totals reflecting the adjustments noted in the preceding table, as applicable, and before the elimination of intercompany transactions.
The following table presents gross operating margin by segment for the periods indicated:
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
|||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Gross operating margin by segment:
|
||||||||||||||||
|
NGL Pipelines & Services
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Crude Oil Pipelines & Services
|
|
|
|
|
||||||||||||
|
Natural Gas Pipelines & Services
|
|
|
|
|
||||||||||||
|
Petrochemical & Refined Products Services
|
|
|
|
|
||||||||||||
|
Total segment gross operating margin
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Summarized Segment Financial Information
Information by business segment, together with reconciliations to amounts presented on, or included in, our Unaudited Condensed Statements of Consolidated Operations, is presented in the following table:
|
|
Reportable Business Segments
|
|||||||||||||||||||||||
|
|
NGL
Pipelines
& Services
|
Crude Oil
Pipelines
& Services
|
Natural Gas
Pipelines
& Services
|
Petrochemical
& Refined
Products
Services
|
Adjustments
and
Eliminations
|
Consolidated
Total
|
||||||||||||||||||
|
Revenues from third parties:
|
||||||||||||||||||||||||
|
Three months ended September 30, 2023
|
$
|
|
$
|
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||||||
|
Three months ended September 30, 2022
|
|
|
|
|
|
|
||||||||||||||||||
|
Nine months ended September 30, 2023
|
|
|
|
|
|
|
||||||||||||||||||
|
Nine months ended September 30, 2022
|
|
|
|
|
|
|
||||||||||||||||||
|
Revenues from related parties:
|
||||||||||||||||||||||||
|
Three months ended September 30, 2023
|
|
|
|
|
|
|
||||||||||||||||||
|
Three months ended September 30, 2022
|
|
|
|
|
|
|
||||||||||||||||||
|
Nine months ended September 30, 2023
|
|
|
|
|
|
|
||||||||||||||||||
|
Nine months ended September 30, 2022
|
|
|
|
|
|
|
||||||||||||||||||
|
Intersegment and intrasegment revenues:
|
||||||||||||||||||||||||
|
Three months ended September 30, 2023
|
|
|
|
|
(
|
)
|
|
|||||||||||||||||
|
Three months ended September 30, 2022
|
|
|
|
|
(
|
)
|
|
|||||||||||||||||
|
Nine months ended September 30, 2023
|
|
|
|
|
(
|
)
|
|
|||||||||||||||||
|
Nine months ended September 30, 2022
|
|
|
|
|
(
|
)
|
|
|||||||||||||||||
|
Total revenues:
|
||||||||||||||||||||||||
|
Three months ended September 30, 2023
|
|
|
|
|
(
|
)
|
|
|||||||||||||||||
|
Three months ended September 30, 2022
|
|
|
|
|
(
|
)
|
|
|||||||||||||||||
|
Nine months ended September 30, 2023
|
|
|
|
|
(
|
)
|
|
|||||||||||||||||
|
Nine months ended September 30, 2022
|
|
|
|
|
(
|
)
|
|
|||||||||||||||||
|
Equity in income of unconsolidated affiliates:
|
||||||||||||||||||||||||
|
Three months ended September 30, 2023
|
|
|
|
|
|
|
||||||||||||||||||
|
Three months ended September 30, 2022
|
|
|
|
|
|
|
||||||||||||||||||
|
Nine months ended September 30, 2023
|
|
|
|
|
|
|
||||||||||||||||||
|
Nine months ended September 30, 2022
|
|
|
|
|
|
|
||||||||||||||||||
Segment revenues include intersegment and intrasegment transactions, which are generally based on transactions made at market-based rates. Our consolidated revenues reflect the elimination of intercompany transactions. Substantially all of our consolidated revenues are earned in the U.S. and derived from a wide customer base.
Information by business segment, together with reconciliations to our Unaudited Condensed Consolidated Balance Sheet totals, is presented in the following table:
|
|
Reportable Business Segments
|
|||||||||||||||||||||||
|
|
NGL
Pipelines
& Services
|
Crude Oil
Pipelines
& Services
|
Natural Gas
Pipelines
& Services
|
Petrochemical
& Refined
Products
Services
|
Adjustments
and
Eliminations
|
Consolidated
Total
|
||||||||||||||||||
|
Property, plant and equipment, net:
(see Note 4)
|
||||||||||||||||||||||||
|
At September 30, 2023
|
$
|
|
$
|
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||||||
|
At December 31, 2022
|
|
|
|
|
|
|
||||||||||||||||||
|
Investments in unconsolidated affiliates:
(see Note 5)
|
||||||||||||||||||||||||
|
At September 30, 2023
|
|
|
|
|
|
|
||||||||||||||||||
|
At December 31, 2022
|
|
|
|
|
|
|
||||||||||||||||||
|
Intangible assets, net:
(see Note 6)
|
||||||||||||||||||||||||
|
At September 30, 2023
|
|
|
|
|
|
|
||||||||||||||||||
|
At December 31, 2022
|
|
|
|
|
|
|
||||||||||||||||||
|
Goodwill:
(see Note 6)
|
||||||||||||||||||||||||
|
At September 30, 2023
|
|
|
|
|
|
|
||||||||||||||||||
|
At December 31, 2022
|
|
|
|
|
|
|
||||||||||||||||||
|
Segment assets:
|
||||||||||||||||||||||||
|
At September 30, 2023
|
|
|
|
|
|
|
||||||||||||||||||
|
At December 31, 2022
|
|
|
|
|
|
|
||||||||||||||||||
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Supplemental Revenue and Expense Information
The following table presents additional information regarding our consolidated revenues and costs and expenses for the periods indicated:
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Consolidated revenues:
|
||||||||||||||||
|
NGL Pipelines & Services
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Crude Oil Pipelines & Services
|
|
|
|
|
||||||||||||
|
Natural Gas Pipelines & Services
|
|
|
|
|
||||||||||||
|
Petrochemical & Refined Products Services
|
|
|
|
|
||||||||||||
|
Total consolidated revenues
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
|
||||||||||||||||
|
Consolidated costs and expenses
|
||||||||||||||||
|
Operating costs and expenses:
|
||||||||||||||||
|
Cost of sales
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Other operating costs and expenses (1)
|
|
|
|
|
||||||||||||
|
Depreciation, amortization and accretion
|
|
|
|
|
||||||||||||
|
Asset impairment charges
|
|
|
|
|
||||||||||||
|
Ne
t losses (gains)
attributable to asset sales and related matters
|
|
|
(
|
)
|
|
|||||||||||
|
General and administrative costs
|
|
|
|
|
||||||||||||
|
Total consolidated costs and expenses
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
(1)
|
|
Fluctuations in our product sales revenues and cost of sales amounts are explained in large part by changes in energy commodity prices. In general, higher energy commodity prices result in an increase in our revenues attributable to product sales; however, these higher commodity prices would also be expected to increase the associated cost of sales as purchase costs are higher. The same type of relationship would be true in the case of lower energy commodity sales prices and purchase costs.
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Note 11. Earnings Per Unit
The following table presents our calculation of basic and diluted earnings per common unit for the periods indicated:
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
BASIC EARNINGS PER COMMON UNIT
|
||||||||||||||||
|
Net income attributable to common unitholders
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Earnings allocated to phantom unit awards (1)
|
(
|
)
|
(
|
)
|
(
|
)
|
(
|
)
|
||||||||
|
Net income allocated to common unitholders
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
|
||||||||||||||||
|
Basic weighted-average number of common units outstanding
|
|
|
|
|
||||||||||||
|
|
||||||||||||||||
|
Basic earnings per common unit
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
|
||||||||||||||||
|
DILUTED EARNINGS PER COMMON UNIT
|
||||||||||||||||
|
Net income attributable to common unitholders
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Net income attributable to preferred units
|
|
|
|
|
||||||||||||
|
Net income attributable to limited partners
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
|
||||||||||||||||
|
Diluted weighted-average number of units outstanding:
|
||||||||||||||||
|
Distribution-bearing common units
|
|
|
|
|
||||||||||||
|
Phantom units (2)
|
|
|
|
|
||||||||||||
|
Preferred units (2)
|
|
|
|
|
||||||||||||
|
Total
|
|
|
|
|
||||||||||||
|
|
||||||||||||||||
|
Diluted earnings per common unit
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
(1)
|
|
|
(2)
|
|
Note 12. Equity-Based Awards
An allocated portion of the fair value of EPCO’s equity-based awards is charged to us under the ASA. The following table summarizes compensation expense we recognized in connection with equity-based awards for the periods indicated:
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Equity-classified awards:
|
||||||||||||||||
|
Phantom unit awards
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Profits interest awards
|
|
|
|
|
||||||||||||
|
Total
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
The fair value of equity-classified awards is amortized to earnings over the requisite service or vesting period. Equity-classified awards are expected to result in the issuance of the Partnership’s common units upon vesting.
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Phantom Unit Awards
Subject to customary forfeiture provisions, phantom unit awards allow recipients to acquire the Partnership’s common units once a defined vesting period expires (at no cost to the recipient apart from fulfilling required service and other conditions). The following table presents phantom unit award activity for the period indicated:
|
|
Number of
Units
|
Weighted-
Average Grant
Date Fair Value
per Unit
(1)
|
||||||
|
Phantom unit awards at
December 31, 2022
|
|
$
|
|
|||||
|
Granted (2)
|
|
$
|
|
|||||
|
Vested
|
(
|
)
|
$
|
|
||||
|
Forfeited
|
(
|
)
|
$
|
|
||||
|
Phantom unit awards at
September 30, 2023
|
|
$
|
|
|||||
|
(1)
|
|
|
(2)
|
|
Each phantom unit award includes a
DER, which entitles the participant to nonforfeitable cash payments equal to the product of the number of phantom unit awards outstanding for the participant and the cash distribution per common unit paid by the Partnership to its common unitholders. Cash payments made in connection with DERs are charged to partners’ equity when the phantom unit award is expected to result in the issuance of common units; otherwise, such amounts are expensed.
The following table presents supplemental information regarding phantom unit awards for the periods indicated:
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Cash payments made in connection with DERs
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Total intrinsic value of phantom unit awards that vested during period
|
|
|
|
|
||||||||||||
For the EPCO group of companies, the unrecognized compensation cost associated with phantom unit awards was $
225
million at September 30, 2023, of which our share of such cost is currently estimated to be $
184
million. Due to the graded vesting provisions of these awards, we expect to recognize our share of the unrecognized compensation cost for these awards over a weighted-average period of
2.1
years.
Profits Interest Awards
EPCO has two limited partnerships (referred to as “Employee Partnerships”) that serve as long-term incentive arrangements for key employees of EPCO by providing them profits interest awards (or Class B limited partner interests) in one or more of the Employee Partnerships. At
September 30, 2023
, our share of the total unrecognized compensation cost related to the Employee Partnerships was $
1
million
, which we expect to recognize over a weighted-average period of less than one
year.
On November 6, 2023, the partners of both Employee Partnerships amended their respective Employee Partnership’s limited partnership agreement to provide that the Class B limited partner interests therein will vest on the
earliest of (i) December 3, 2027, (ii) the first date on or after November 6, 2023 for which the closing sale price of the Partnership’s common units on the NYSE is equal to or greater than $
29.02
per unit (subject to certain adjustments), (iii) a change of control, or (iv) dissolution of such Employee Partnership.
Note 13. Hedging Activities and Fair Value Measurements
In the normal course of our business operations, we are exposed to certain risks, including changes in interest rates and commodity prices. In order to manage risks associated with assets, liabilities and certain anticipated future transactions, we use derivative instruments such as futures, forward contracts, swaps, options and other instruments with similar characteristics. Substantially all of our derivatives are used for non-trading activities.
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Interest Rate Hedging Activities
We may utilize interest rate swaps, forward-starting swaps, options to enter into forward-starting swaps (“swaptions”), and similar derivative instruments to manage our exposure to changes in interest rates charged on borrowings under certain consolidated debt agreements. This strategy may be used in controlling our overall cost of capital associated with such borrowings.
Treasury Locks
A treasury lock is an agreement that fixes the price (or yield) of a specified U.S. treasury security for an established period of time. We use treasury lock agreements to hedge our exposure to interest rate changes and to reduce the volatility of financing costs on an expected future debt issuance. During the fourth quarter of 2022, we entered into a treasury lock transaction to fix the ten-year treasury rate at
3.45
% on a notional amount of $
750
million. In January 2023, we entered into an additional treasury lock transaction to fix the three-year treasury rate at
4.165
% on a notional amount of $
750
million. The purpose of these transactions was to hedge the underlying interest rate risk associated with debt issuances which occurred in January 2023 (see Note 7). Both of our treasury lock transactions were designated as cash flow hedges of the interest payments associated with these debt issuances. In January 2023, we terminated both treasury lock transactions simultaneously with our issuance of the three-year and ten-year notes and received total cash proceeds of $
21
million. As cash flow hedges, gains on these derivative instruments are reflected as a component of accumulated other comprehensive income and will be amortized to earnings as a reduction to interest expense over the full term of each issuance.
Commodity Hedging Activities
The prices of natural gas, NGLs, crude oil, petrochemicals and refined products, and power are subject to fluctuations in response to changes in supply and demand, market conditions and a variety of additional factors that are beyond our control. In order to manage such price risks, we enter into commodity derivative instruments such as physical forward contracts, futures contracts, fixed-for-float swaps and basis swaps.
At
September 30, 2023
, our predominant commodity hedging strategies consisted of (i) hedging anticipated future purchases and sales of commodity products associated with transportation, storage and blending activities, (ii) hedging natural gas processing margins, (iii) hedging the fair value of commodity products held in inventory and (iv)
hedging anticipated future purchases of power for certain operations in Southeast Texas
.
| • |
The objective of our anticipated future commodity purchases and sales hedging program is to hedge the margins of certain transportation, storage, blending and operational activities by locking in purchase and sale prices through the use of derivative instruments and related contracts.
|
| • |
The objective of our natural gas processing hedging program is to hedge an amount of earnings associated with these activities. We achieve this objective by executing fixed-price sales for a portion of our expected equity production using derivative instruments and related contracts. For certain natural gas processing contracts, the hedging of expected equity NGL production also involves the purchase of natural gas for plant thermal reduction, which is hedged using derivative instruments and related contracts.
|
| • |
The objective of our inventory hedging program is to hedge the fair value of commodity products currently held in inventory by locking in the sales price of the inventory through the use of derivative instruments and related contracts.
|
| • |
The objective of our commercial energy hedging program is to hedge anticipated future purchases of power for certain operations in Southeast Texas by locking in purchase prices through the use of derivative instruments and related contracts.
|
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
The following table summarizes our portfolio of commodity derivative instruments outstanding at September 30, 2023 (volume measures as noted):
|
|
Volume (1)
|
Accounting
|
|
|
Derivative Purpose
|
Current
(2)
|
Long-Term
(2)
|
Treatment
|
|
Derivatives designated as hedging instruments:
|
|||
|
Natural gas processing:
|
|||
|
Forecasted natural gas purchases for plant thermal reduction (billion cubic feet (“Bcf”))
|
|
n/a
|
Cash flow hedge
|
|
Forecasted sales of natural gas (Bcf)
|
|
n/a
|
Cash flow hedge
|
|
Forecasted sales of NGLs (MMBbls)
|
|
n/a
|
Cash flow hedge
|
|
Octane enhancement:
|
|||
|
Forecasted sales of octane enhancement products (MMBbls)
|
|
|
Cash flow hedge
|
|
Natural gas marketing:
|
|||
|
Forecasted purchases of natural gas (Bcf)
|
|
n/a
|
Cash flow hedge
|
|
Forecasted sales of natural gas (Bcf)
|
|
n/a
|
Cash flow hedge
|
|
Natural gas storage inventory management activities (Bcf)
|
|
n/a
|
Fair value hedge
|
|
NGL marketing:
|
|||
|
Forecasted purchases of NGLs and related hydrocarbon products (MMBbls)
|
|
|
Cash flow hedge
|
|
Forecasted sales of NGLs and related hydrocarbon products (MMBbls)
|
|
|
Cash flow hedge
|
|
Refined products marketing:
|
|||
|
Forecasted purchases of refined products (MMBbls)
|
|
n/a
|
Cash flow hedge
|
|
Forecasted sales of refined products (MMBbls)
|
|
n/a
|
Cash flow hedge
|
|
Crude oil marketing:
|
|
||
|
Forecasted purchases of crude oil (MMBbls)
|
|
n/a
|
Cash flow hedge
|
|
Forecasted sales of crude oil (MMBbls)
|
|
|
Cash flow hedge
|
|
Petrochemical marketing:
|
|||
|
Forecasted purchases of petrochemical products (MMBbls)
|
|
n/a
|
Cash flow hedge
|
|
Forecasted sales of petrochemical products (MMBbls)
|
|
n/a
|
Cash flow hedge
|
|
Commercial energy:
|
|||
|
Forecasted purchases of power related to asset operations (terawatt hours (“TWh”))
|
|
|
Cash flow hedge
|
|
Derivatives not designated as hedging instruments:
|
|||
|
Natural gas risk management activities (Bcf) (3)
|
|
|
Mark-to-market
|
|
NGL risk management activities (MMBbls) (3)
|
|
|
Mark-to-market
|
|
Refined products risk management activities (MMBbls) (3)
|
|
n/a
|
Mark-to-market
|
|
Crude oil risk management activities (MMBbls) (3)
|
|
|
Mark-to-market
|
|
(1)
|
|
|
(2)
|
|
|
(3)
|
|
The carrying amount of our inventories subject to fair value hedges was $
2
million and $
12
million at September 30, 2023 and December 31, 2022, respectively.
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Tabular Presentation of Fair Value Amounts, and Gains and Losses on
Derivative Instruments and Related Hedged Items
The following table provides a balance sheet overview of our derivative assets and liabilities at the dates indicated:
|
|
Asset Derivatives
|
|
Liability Derivatives
|
||||||||||||
|
September 30, 2023
|
|
December 31, 2022
|
|
September 30, 2023
|
|
December 31, 2022
|
|||||||||
|
Balance
Sheet
Location
|
Fair
Value
|
|
Balance
Sheet
Location
|
Fair
Value
|
|
Balance
Sheet
Location
|
Fair
Value
|
|
Balance
Sheet
Location
|
Fair
Value
|
|||||
|
Derivatives designated as hedging instruments
|
|||||||||||||||
|
Interest derivatives
|
Current
assets
|
$
|
|
Current
assets
|
$
|
|
Current
liabilities
|
$
|
|
Current
liabilities
|
$
|
|
|||
|
Commodity derivatives
|
Current
assets
|
$
|
|
|
Current
assets
|
$
|
|
|
Current
liabilities
|
$
|
|
|
Current
liabilities
|
$
|
|
|
Commodity derivatives
|
Other assets
|
|
|
|
Other assets
|
|
|
|
Other liabilities
|
|
|
|
Other liabilities
|
|
|
|
Total commodity derivatives
|
|
|
|
|
|||||||||||
|
Total derivatives designated as hedging instruments
|
$
|
|
$
|
|
$
|
|
$
|
|
|||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Derivatives not designated as hedging instruments
|
|||||||||||||||
|
Commodity derivatives
|
Current
assets
|
$
|
|
|
Current
assets
|
$
|
|
|
Current
liabilities
|
$
|
|
|
Current
liabilities
|
$
|
|
|
Commodity derivatives
|
Other assets
|
|
|
|
Other assets
|
|
|
Other liabilities
|
|
|
Other liabilities
|
|
|||
|
Total commodity derivatives
|
|
|
|
|
|
|
|
|
|
|
|
|
|||
|
Total derivatives not designated as hedging instruments
|
$
|
|
$
|
|
$
|
|
$
|
|
|||||||
Certain of our commodity derivative instruments are subject to master netting arrangements or similar agreements. The following tables present our derivative instruments subject to such arrangements at the dates indicated:
|
|
Offsetting of Financial Assets and Derivative Assets
|
|||||||||||||||||||||||||||
|
|
Gross
Amounts of
Recognized
Assets
|
Gross
Amounts
Offset in the
Balance Sheet
|
Amounts
of Assets
Presented
in the
Balance Sheet
|
Gross Amounts Not Offset
in the Balance Sheet
|
Amounts That
Would Have
Been Presented
On Net Basis
|
|||||||||||||||||||||||
|
Financial
Instruments
|
Cash
Collateral
Received
|
Cash
Collateral
Paid
|
||||||||||||||||||||||||||
|
|
(i)
|
(ii)
|
(iii) = (i) – (ii)
|
(iv)
|
(v) = (iii) + (iv)
|
|||||||||||||||||||||||
|
As of September 30, 2023:
|
||||||||||||||||||||||||||||
|
Commodity derivatives
|
$
|
|
$
|
|
$
|
|
$
|
(
|
)
|
$
|
|
$
|
|
$
|
|
|||||||||||||
|
As of December 31, 2022:
|
||||||||||||||||||||||||||||
|
Interest rate derivatives
|
$
|
|
$
|
|
$
|
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||||||||
|
Commodity derivatives
|
|
|
|
(
|
)
|
|
(
|
)
|
|
|||||||||||||||||||
|
|
Offsetting of Financial Liabilities and Derivative Liabilities
|
|||||||||||||||||||||||||||
|
|
Gross
Amounts of
Recognized
Liabilities
|
Gross
Amounts
Offset in the
Balance Sheet
|
Amounts
of Liabilities
Presented
in the
Balance Sheet
|
Gross Amounts Not Offset
in the Balance Sheet
|
Amounts That
Would Have
Been Presented
On Net Basis
|
|||||||||||||||||||||||
|
Financial
Instruments
|
Cash
Collateral
Received
|
Cash
Collateral
Paid
|
||||||||||||||||||||||||||
|
|
(i)
|
(ii)
|
(iii) = (i) – (ii)
|
(iv)
|
(v) = (iii) + (iv)
|
|||||||||||||||||||||||
|
As of September 30, 2023:
|
||||||||||||||||||||||||||||
|
Commodity derivatives
|
$
|
|
$
|
|
$
|
|
$
|
(
|
)
|
$
|
|
$
|
(
|
)
|
$
|
|
||||||||||||
|
As of December 31, 2022:
|
||||||||||||||||||||||||||||
|
Commodity derivatives
|
$
|
|
$
|
|
$
|
|
$
|
(
|
)
|
$
|
|
$
|
|
$
|
|
|||||||||||||
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Derivative assets and liabilities recorded on our Unaudited Condensed Consolidated Balance Sheets are presented on a gross-basis and determined at the individual transaction level. The tabular presentation above provides a means for comparing the gross amount of derivative assets and liabilities, excluding associated accounts payable and receivable, to the net amount that would likely be receivable or payable under a default scenario based on the existence of rights of offset in the respective derivative agreements. Any cash collateral paid or received is reflected in these tables, but only to the extent that it represents variation margins. Any amounts associated with derivative prepayments or initial margins that are not influenced by the derivative asset or liability amounts or those that are determined solely on their volumetric notional amounts are excluded from these tables.
The following tables present the effect of our derivative instruments designated as fair value hedges on our Unaudited Condensed Statements of Consolidated Operations for the periods indicated:
|
Derivatives in Fair Value
Hedging Relationships
|
Location
|
Gain (Loss) Recognized in
Income on Derivative
|
|||||||||||||||
|
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Commodity derivatives
|
|
$
|
|
$
|
|
$
|
|
$
|
(
|
)
|
|||||||
|
Total
|
|
$
|
|
$
|
|
$
|
|
$
|
(
|
)
|
|||||||
|
Derivatives in Fair Value
Hedging Relationships
|
Location
|
Gain (Loss) Recognized in
Income on Hedged Item
|
|||||||||||||||
|
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Commodity derivatives
|
Revenue
|
$
|
(
|
)
|
$
|
|
$
|
(
|
)
|
$
|
|
||||||
|
Total
|
|
$
|
(
|
)
|
$
|
|
$
|
(
|
)
|
$
|
|
||||||
The gain (loss) corresponding to the hedge ineffectiveness on the fair value hedges was negligible for all periods presented. The remaining gain (loss) for each period presented is primarily attributable to prompt-to-forward month price differentials that were excluded from the assessment of hedge effectiveness.
The following tables present the effect of our derivative instruments designated as cash flow hedges on our Unaudited Condensed Statements of Consolidated Operations and Unaudited Condensed Statements of Consolidated Comprehensive Income for the periods indicated:
|
Derivatives in Cash Flow
Hedging Relationships
|
Change in Value Recognized in
Other Comprehensive Income (Loss) on Derivative
|
|||||||||||||||
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Interest rate derivatives
|
$
|
|
$
|
|
$
|
(
|
)
|
$
|
|
|||||||
|
Commodity derivatives – Revenue (1)
|
(
|
)
|
|
(
|
)
|
|
||||||||||
|
Commodity derivatives – Operating costs and expenses (1)
|
|
|
|
|
||||||||||||
|
Total
|
$
|
(
|
)
|
$
|
|
$
|
(
|
)
|
$
|
|
||||||
|
(1)
|
|
|
Derivatives in Cash Flow
Hedging Relationships
|
Location
|
Gain (Loss) Reclassified from
Accumulated Other Comprehensive Income (Loss) to Income
|
|||||||||||||||
|
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Interest rate derivatives
|
|
$
|
|
$
|
(
|
)
|
$
|
|
$
|
(
|
)
|
||||||
|
Commodity derivatives
|
Revenue
|
(
|
)
|
(
|
)
|
(
|
)
|
|
|||||||||
|
Commodity derivatives
|
Operating costs and expenses
|
|
|
|
|
||||||||||||
|
Total
|
|
$
|
(
|
)
|
$
|
(
|
)
|
$
|
|
$
|
|
||||||
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Over the next twelve months, we expect to reclassify $
9
million of gains attributable to interest rate derivative instruments from accumulated other comprehensive income to earnings as a decrease in interest expense. Likewise, we expect to reclassify $
18
million of net gains attributable to commodity derivative instruments from accumulated other comprehensive income to earnings, with $
35
million as an increase in revenue and $
17
million as an increase in operating costs and expenses.
The following table presents the effect of our derivative instruments not designated as hedging instruments on our Unaudited Condensed Statements of Consolidated Operations for the periods indicated:
|
Derivatives Not Designated
as Hedging Instruments
|
Location
|
Gain (Loss) Recognized in
Income on Derivative
|
|||||||||||||||
|
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Commodity derivatives
|
Revenue
|
$
|
(
|
)
|
$
|
|
$
|
|
$
|
|
|||||||
|
Commodity derivatives
|
Operating costs and expenses
|
|
|
|
|
||||||||||||
|
Total
|
|
$
|
(
|
)
|
$
|
|
$
|
|
$
|
|
|||||||
The $
190
million net gain recognized for the nine months ended September 30, 2023 (as noted in the preceding table) from derivatives not designated as hedging instruments consists of $
240
million of net realized gains and $
50
million of net unrealized mark-to-market losses attributable to commodity derivatives.
Fair Value Measurements
The following tables set forth, by level within the Level 1, 2 and 3 fair value hierarchy, the carrying values of our financial assets and liabilities at the dates indicated. These assets and liabilities are measured on a recurring basis and are classified based on the lowest level of input used to estimate their fair value. Our assessment of the relative significance of such inputs requires judgment.
The values for commodity derivatives are presented before and after the application of CME Rule 814, which deems that financial instruments cleared by the CME are settled daily in connection with variation margin payments. As a result of this exchange rule, CME-related derivatives are considered to have no fair value at the balance sheet date for financial reporting purposes; however, the derivatives remain outstanding and subject to future commodity price fluctuations until they are settled in accordance with their contractual terms. Derivative transactions cleared on exchanges other than the CME (e.g., the Intercontinental Exchange or ICE) continue to be reported on a gross basis.
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
|
|
At September 30, 2023
Fair Value Measurements Using
|
|||||||||||||||
|
|
Quoted Prices
in Active
Markets for
Identical Assets
and Liabilities
(Level 1)
|
Significant
Other
Observable
Inputs
(Level 2)
|
Significant
Unobservable
Inputs
(Level 3)
|
Total
|
||||||||||||
|
Financial assets:
|
||||||||||||||||
|
Commodity derivatives:
|
||||||||||||||||
|
Value before application of CME Rule 814
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Impact of CME Rule 814
|
(
|
)
|
(
|
)
|
|
(
|
)
|
|||||||||
|
Total commodity derivatives
|
|
|
|
|
||||||||||||
|
Total
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
|
||||||||||||||||
|
Financial liabilities:
|
||||||||||||||||
|
Commodity derivatives:
|
||||||||||||||||
|
Value before application of CME Rule 814
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Impact of CME Rule 814
|
(
|
)
|
(
|
)
|
|
(
|
)
|
|||||||||
|
Total commodity derivatives
|
|
|
|
|
||||||||||||
|
Total
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
|
At December 31, 2022
Fair Value Measurements Using
|
|||||||||||||||
|
|
Quoted Prices
in Active
Markets for
Identical Assets
and Liabilities
(Level 1)
|
Significant
Other
Observable
Inputs
(Level 2)
|
Significant
Unobservable
Inputs
(Level 3)
|
Total
|
||||||||||||
|
Financial assets:
|
||||||||||||||||
|
Interest rate derivatives:
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Commodity derivatives:
|
||||||||||||||||
|
Value before application of CME Rule 814
|
|
|
|
|
||||||||||||
|
Impact of CME Rule 814
|
(
|
)
|
(
|
)
|
|
(
|
)
|
|||||||||
|
Total commodity derivatives
|
|
|
|
|
||||||||||||
|
Total
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
|
||||||||||||||||
|
Financial liabilities:
|
||||||||||||||||
|
Commodity derivatives:
|
||||||||||||||||
|
Value before application of CME Rule 814
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Impact of CME Rule 814
|
(
|
)
|
(
|
)
|
|
(
|
)
|
|||||||||
|
Total commodity derivatives
|
|
|
|
|
||||||||||||
|
Total
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
In the aggregate, the fair value of our commodity hedging portfolios at
September 30, 2023
was a net derivative liability of $
108
million prior to the impact of CME Rule 814.
Financial assets and liabilities recorded on the balance sheet at September 30, 2023 using significant unobservable inputs (Level 3) are not material to the Unaudited Condensed Consolidated Financial Statements.
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Other Fair Value Information
The carrying amounts of cash and cash equivalents (including restricted cash balances), accounts receivable, commercial paper notes and accounts payable approximate their fair values based on their short-term nature. The estimated total fair value of our fixed-rate debt obligations was $
24.5
billion and $
24.2
billion at September 30, 2023 and December 31, 2022, respectively. The aggregate carrying value of these debt obligations was $
28.0
billion and $
27.5
billion at September 30, 2023 and December 31, 2022, respectively. These values are primarily based on quoted market prices for such debt or debt of similar terms and maturities (Level 2) and our credit standing. Changes in market rates of interest affect the fair value of our fixed-rate debt. The carrying values of our variable-rate long-term debt obligations approximate their fair values since the associated interest rates are market-based. We do not have any long-term investments in debt or equity securities recorded at fair value.
Note 14. Related Party Transactions
The following table summarizes our related party transactions for the periods indicated:
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Revenues – related parties:
|
||||||||||||||||
|
Unconsolidated affiliates
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Costs and expenses – related parties:
|
||||||||||||||||
|
EPCO and its privately held affiliates
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Unconsolidated affiliates
|
|
|
|
|
||||||||||||
|
Total
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
The following table summarizes our related party accounts receivable and accounts payable balances at the dates indicated:
|
|
September 30,
2023
|
December 31,
2022
|
||||||
|
Accounts receivable - related parties:
|
||||||||
|
EPCO and its privately held affiliates
|
$
|
|
$
|
|
||||
|
Unconsolidated affiliates
|
|
|
||||||
|
Total
|
$
|
|
$
|
|
||||
|
|
||||||||
|
Accounts payable - related parties:
|
||||||||
|
EPCO and its privately held affiliates
|
$
|
|
$
|
|
||||
|
Unconsolidated affiliates
|
|
|
||||||
|
Total
|
$
|
|
$
|
|
||||
We believe that the terms and provisions of our related party agreements are fair to us; however, such agreements and transactions may not be as favorable to us as we could have obtained from unaffiliated third parties.
Relationship with EPCO and Affiliates
We have an extensive and ongoing relationship with EPCO and its privately held affiliates (including Enterprise GP, our general partner), which are not a part of our consolidated group of companies.
At September 30, 2023, EPCO and its privately held affiliates (including Dan Duncan LLC and certain Duncan family trusts) beneficially owned the following limited partner interests in us:
|
Total Number of Limited Partner Interests Held
|
Percentage of
Common Units
Outstanding
|
|
|
|
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Of the total number of Partnership common units held by EPCO and its privately held affiliates,
62,976,464
have been pledged as security under the separate credit facilities of EPCO and its privately held affiliates at September 30, 2023. These credit facilities contain customary and other events of default, including defaults by us and other affiliates of EPCO. An event of default, followed by a foreclosure on the pledged collateral, could ultimately result in a change in ownership of these units and affect the market price of the Partnership’s common units.
The Partnership and Enterprise GP are both separate legal entities apart from each other and apart from EPCO and its other affiliates, with assets and liabilities that are also separate from those of EPCO and its other affiliates. EPCO and its privately held affiliates use cash on hand and cash distributions they receive from us and other investments to fund their other activities and to meet their respective debt obligations, if any. During the nine months ended September 30, 2023 and 2022, we paid EPCO and its privately held affiliates cash distributions totaling $
1.0
billion and $
955
million, respectively.
We have no employees. All of our administrative and operating functions are provided either by employees of EPCO (pursuant to the ASA) or by other service providers. We and our general partner are parties to the ASA. The following table presents our related party costs and expenses attributable to the ASA with EPCO for the periods indicated:
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
|||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Operating costs and expenses
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
General and administrative expenses
|
|
|
|
|
||||||||||||
|
Total costs and expenses
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
We lease office space from privately held affiliates of EPCO at rental rates that approximate market rates. For each of the
three months ended September 30, 2023
and
2022
, we recognized $
3
million of related party operating lease expense in connection with these office space leases. For each of the nine months ended September 30, 2023 and 2022, we recognized $
10
million of related party operating lease expense in connection with these office space leases.
Note 15. Income Taxes
Income taxes are accounted for under the asset-and-liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and operating loss and tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. We recognize the effect of income tax positions only if those positions are more likely than not of being sustained. Recognized income tax positions are measured at the largest amount that is greater than 50% likely of being realized. Changes in recognition or measurement are reflected in the period in which the change in judgment occurs.
We did not rely on any uncertain tax positions in recording our income tax-related amounts during the three and
nine months ended September 30, 2023
and
2022
.
Our federal, state and foreign income tax benefit (provision) is summarized below:
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Current portion of income tax provision:
|
||||||||||||||||
|
Federal
|
$
|
(
|
)
|
$
|
(
|
)
|
$
|
(
|
)
|
$
|
(
|
)
|
||||
|
State
|
(
|
)
|
(
|
)
|
(
|
)
|
(
|
)
|
||||||||
|
Foreign
|
|
|
|
(
|
)
|
|||||||||||
|
Total current portion
|
(
|
)
|
(
|
)
|
(
|
)
|
(
|
)
|
||||||||
|
Deferred portion of income tax provision:
|
||||||||||||||||
|
Federal
|
(
|
)
|
(
|
)
|
|
(
|
)
|
|||||||||
|
State
|
(
|
)
|
(
|
)
|
(
|
)
|
(
|
)
|
||||||||
|
Total deferred portion
|
(
|
)
|
(
|
)
|
(
|
)
|
(
|
)
|
||||||||
|
Total provision for income taxes
|
$
|
(
|
)
|
$
|
(
|
)
|
$
|
(
|
)
|
$
|
(
|
)
|
||||
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
A reconciliation of the provision for income taxes with amounts determined by applying the statutory U.S. federal income tax rate to income before income taxes is as follows:
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Pre-Tax Net Book Income (“NBI”)
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Texas Margin Tax (1)
|
(
|
)
|
(
|
)
|
(
|
)
|
(
|
)
|
||||||||
|
State income tax provision, net of federal benefit
|
|
|
(
|
)
|
(
|
)
|
||||||||||
|
Federal income tax provision computed by applying
the federal statutory rate to NBI of corporate entities
|
(
|
)
|
(
|
)
|
(
|
)
|
(
|
)
|
||||||||
|
Other
|
|
(
|
)
|
|
(
|
)
|
||||||||||
|
Provision for income taxes
|
$
|
(
|
)
|
$
|
(
|
)
|
$
|
(
|
)
|
$
|
(
|
)
|
||||
|
|
||||||||||||||||
|
Effective income tax rate
|
(
|
)%
|
(
|
)%
|
(
|
)%
|
(
|
)%
|
||||||||
|
(1)
|
|
The following table presents the significant components of deferred tax assets and deferred tax liabilities at the dates indicated:
|
September 30,
|
December 31,
|
|||||||
|
|
2023
|
2022
|
||||||
|
Deferred tax liabilities:
|
||||||||
|
Attributable to investment in OTA
|
$
|
|
$
|
|
||||
|
Attributable to property, plant and equipment
|
|
|
||||||
|
Attributable to investments in other entities
|
|
|
||||||
|
Other
|
|
|
||||||
|
Total deferred tax liabilities
|
|
|
||||||
|
Deferred tax assets:
|
||||||||
|
Net operating loss carryovers (1)
|
|
|
||||||
|
Temporary differences related to Texas Margin Tax
|
|
|
||||||
|
Total deferred tax assets
|
|
|
||||||
|
Valuation allowance
|
|
|
||||||
|
Total deferred tax assets, net of valuation allowance
|
|
|
||||||
|
Total net deferred tax liabilities
|
$
|
|
$
|
|
||||
|
(1)
|
|
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Note 16. Commitments and Contingent Liabilities
Litigation
As part of our normal business activities, we may be named as defendants in legal proceedings, including those arising from regulatory and environmental matters. Although we are insured against various risks to the extent we believe it is prudent, there is no assurance that the nature and amount of such insurance will be adequate, in every case, to fully indemnify us against losses arising from future legal proceedings. We will vigorously defend the Partnership in litigation matters.
There were no accruals for litigation contingencies at September 30, 2023 and December 31, 2022, respectively.
Contractual Obligations
Scheduled Maturities of Debt
We have long-term and short-term payment obligations under debt agreements. In total, the principal amount of our consolidated debt obligations were $
29.2
billion and $
28.6
billion at September 30, 2023 and December 31, 2022, respectively. See Note 7 for additional information regarding our scheduled future maturities of debt principal.
Lease Accounting Matters
There has been no significant change in our operating lease obligations since those disclosed in the 2022 Form 10-K.
The following table presents information regarding operating leases where we are the lessee at September 30, 2023:
|
Asset Category
|
ROU
Asset
Carrying
Value
(1)
|
Lease
Liability
Carrying
Value
(2)
|
Weighted-
Average
Remaining
Term
|
Weighted-
Average
Discount
Rate
(3)
|
|||||
|
Storage and pipeline facilities
|
$
|
|
$
|
|
|
|
|||
|
Transportation equipment
|
|
|
|
|
|||||
|
Office and warehouse space
|
|
|
|
|
|||||
|
Total
|
$
|
|
$
|
|
|||||
|
(1)
|
|
|
(2)
|
|
|
(3)
|
|
The following table disaggregates our total operating lease expense for the
periods indicated
:
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Long-term operating leases:
|
||||||||||||||||
|
Fixed lease expense:
|
||||||||||||||||
|
Non-cash lease expense (amortization of ROU assets)
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
|
Related accretion expense on lease liability balances
|
|
|
|
|
||||||||||||
|
Total fixed lease expense
|
|
|
|
|
||||||||||||
|
Variable lease expense
|
|
|
|
|
||||||||||||
|
Subtotal operating lease expense
|
|
|
|
|
||||||||||||
|
Short-term operating leases
|
|
|
|
|
||||||||||||
|
Total operating lease expense
|
$
|
|
$
|
|
$
|
|
$
|
|
||||||||
ENTERPRISE PRODUCTS PARTNERS L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Cash payments attributable to operating lease liabilities were $
21
million and $
19
million for the three months ended September 30, 2023 and 2022, respectively. For the nine months ended September 30, 2023 and 2022, cash paid for operating lease liabilities was $
62
million and $
47
million, respectively.
Operating lease income for each of the three months ended September 30, 2023 and 2022 was
$
4
million. For the
nine months ended September 30, 2023
and
2022
, operating lease income was $
12
million and $
10
million, respectively.
Purchase Obligations
Our consolidated purchase obligations at September 30, 2023 did not differ materially from those reported in our 2022 Form 10-K.
Note 17. Supplemental Cash Flow Information
The following table provides information regarding the net effect of changes in our operating accounts and cash payments for interest and income taxes for the periods indicated:
|
|
For the Nine Months
Ended September 30,
|
|||||||
|
|
2023
|
2022
|
||||||
|
Decrease (increase) in:
|
||||||||
|
Accounts receivable – trade
|
$
|
|
$
|
|
||||
|
Accounts receivable – related parties
|
|
(
|
)
|
|||||
|
Inventories
|
(
|
)
|
(
|
)
|
||||
|
Prepaid and other current assets
|
(
|
)
|
|
|||||
|
Other assets
|
|
|
||||||
|
Increase (decrease) in:
|
||||||||
|
Accounts payable – trade
|
|
(
|
)
|
|||||
|
Accounts payable – related parties
|
(
|
)
|
(
|
)
|
||||
|
Accrued product payables
|
|
(
|
)
|
|||||
|
Accrued interest
|
(
|
)
|
(
|
)
|
||||
|
Other current liabilities
|
|
(
|
)
|
|||||
|
Other long-term liabilities
|
(
|
)
|
(
|
)
|
||||
|
Net effect of changes in operating accounts
|
$
|
(
|
)
|
$
|
(
|
)
|
||
|
Cash payments for interest, net of $
nine months ended September 30, 2023
and
2022
, respectively
|
$
|
|
$
|
|
||||
|
Cash payments for federal and state income taxes
|
$
|
|
$
|
|
||||
We incurred liabilities for construction in progress that had not been paid at September 30, 2023 and December 31, 2022 of $
371
million and $
238
million, respectively. Such amounts are not included under the caption “Capital expenditures” on the Unaudited Condensed Statements of Consolidated Cash Flows.
Acquisition of Navitas Midstream
In February 2022, we acquired all of the member interests in Navitas Midstream Partners, LLC (“Navitas Midstream”) for $
3.2
billion in net cash consideration.
RESULTS OF OPERATIONS.
For the Three and Nine Months Ended September 30, 2023 and 2022
The following information should be read in conjunction with our Unaudited Condensed Consolidated Financial Statements and accompanying Notes included in this quarterly report on Form 10-Q and the Audited Consolidated Financial Statements and related Notes, together with our discussion and analysis of financial position and results of operations, included in our annual report on Form 10-K for the year ended December 31, 2022 (the “2022 Form 10-K”), as filed on February 28, 2023 with the U.S. Securities and Exchange Commission (“SEC”). Our financial statements have been prepared in accordance with generally accepted accounting principles (“GAAP”) in the United States (“U.S.”).
Cautionary Statement Regarding Forward-Looking Information
This quarterly report on Form 10-Q for the three and nine months ended September 30, 2023 (our “quarterly report”) contains various forward-looking statements and information that are based on our beliefs and those of our general partner, as well as assumptions made by us and information currently available to us. When used in this document, words such as “anticipate,” “project,” “expect,” “plan,” “seek,” “goal,” “estimate,” “forecast,” “intend,” “could,” “should,” “would,” “will,” “believe,” “may,” “scheduled,” “pending,” “potential” and similar expressions and statements regarding our plans and objectives for future operations are intended to identify forward-looking statements. Although we and our general partner believe that our expectations reflected in such forward-looking statements (including any forward-looking statements/expectations of third parties referenced in this quarterly report) are reasonable, neither we nor our general partner can give any assurances that such expectations will prove to be correct.
Forward-looking statements are subject to a variety of risks, uncertainties and assumptions as described in more detail under Part I, Item 1A of our 2022 Form 10-K. If one or more of these risks or uncertainties materialize, or if underlying assumptions prove incorrect, our actual results may vary materially from those anticipated, estimated, projected or expected. You should not put undue reliance on any forward-looking statements. The forward-looking statements in this quarterly report speak only as of the date hereof. Except as required by federal and state securities laws, we undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or any other reason.
Key References Used in this Management’s Discussion and Analysis
Unless the context requires otherwise, references to “we,” “us” or “our” within this quarterly report are intended to mean the business and operations of Enterprise Products Partners L.P. and its consolidated subsidiaries.
References to the “Partnership” or “Enterprise” mean Enterprise Products Partners L.P. on a standalone basis.
References to “EPO” mean Enterprise Products Operating LLC, which is an indirect wholly owned subsidiary of the Partnership, and its consolidated subsidiaries, through which the Partnership conducts its business. We are managed by our general partner, Enterprise Products Holdings LLC (“Enterprise GP”), which is a wholly owned subsidiary of Dan Duncan LLC, a privately held Texas limited liability company.
The membership interests of Dan Duncan LLC are owned by a voting trust, the current trustees (“DD LLC Trustees”) of which are: (i) Randa Duncan Williams, who is also a director and Chairman of the Board of Directors of Enterprise GP (the “Board”); (ii) Richard H. Bachmann, who is also a director and Vice Chairman of the Board; and (iii) W. Randall Fowler, who is also a director and the Co-Chief Executive Officer and Chief Financial Officer of Enterprise GP. Ms. Duncan Williams and Messrs. Bachmann and Fowler also currently serve as managers of Dan Duncan LLC.
References to “EPCO” mean Enterprise Products Company, a privately held Texas corporation, and its privately held affiliates. The outstanding voting capital stock of EPCO is owned by a voting trust, the current trustees (“EPCO Trustees”) of which are: (i) Ms. Duncan Williams, who serves as Chairman of EPCO; (ii) Mr. Bachmann, who serves as the President and Chief Executive Officer of EPCO; and (iii) Mr. Fowler, who serves as an Executive Vice President and the Chief Financial Officer of EPCO. Ms. Duncan Williams and Messrs. Bachmann and Fowler also currently serve as directors of EPCO.
We, Enterprise GP, EPCO and Dan Duncan LLC are affiliates under the collective common control of the DD LLC Trustees and the EPCO Trustees. EPCO, together with its privately held affiliates, owned approximately 32.3% of the Partnership’s common units outstanding at September 30, 2023.
As generally used in the energy industry and in this quarterly report, the acronyms below have the following meanings:
|
/d
|
=
|
per day
|
MMBPD
|
=
|
million barrels per day
|
|
BBtus
|
=
|
billion British thermal units
|
MMBtus
|
=
|
million British thermal units
|
|
Bcf
|
=
|
billion cubic feet
|
MMcf
|
=
|
million cubic feet
|
|
BPD
|
=
|
barrels per day
|
MWac
|
=
|
megawatts, alternating current
|
|
MBPD
|
=
|
thousand barrels per day
|
MWdc
|
=
|
megawatts, direct current
|
|
MMBbls
|
=
|
million barrels
|
TBtus
|
=
|
trillion British thermal units
|
As used in this quarterly report, the phrase “quarter-to-quarter” means the third quarter of 2023 compared to the third quarter of 2022.
Likewise, the phrase “period-to-period” means the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022.
Overview of Business
We are a publicly traded Delaware limited partnership, the common units of which are listed on the New York Stock Exchange (“NYSE”) under the ticker symbol “EPD.” Our preferred units are not publicly traded. We were formed in April 1998 to own and operate certain natural gas liquids (“NGLs”) related businesses of EPCO and are a leading North American provider of midstream energy services to producers and consumers of natural gas, NGLs, crude oil, petrochemicals and refined products. We are owned by our limited partners (preferred and common unitholders) from an economic perspective. Enterprise GP, which owns a non-economic general partner interest in us, manages our Partnership. We conduct substantially all of our business operations through EPO and its consolidated subsidiaries.
Our fully integrated, midstream energy asset network (or “value chain”) links producers of natural gas, NGLs and crude oil from some of the largest supply basins in the U.S., Canada and the Gulf of Mexico with domestic consumers and international markets. Our midstream energy operations include:
| • |
natural gas gathering, treating, processing, transportation and storage;
|
| • |
NGL transportation, fractionation, storage, and marine terminals (including those used to export liquefied petroleum gases (“LPG”) and ethane);
|
| • |
crude oil gathering, transportation, storage, and marine terminals;
|
| • |
propylene production facilities (including propane dehydrogenation (“PDH”) facilities), butane isomerization, octane enhancement, isobutane dehydrogenation (“iBDH”) and high purity isobutylene (“HPIB”) production facilities;
|
| • |
petrochemical and refined products transportation, storage, and marine terminals (including those used to export ethylene and polymer grade propylene (“PGP”)); and
|
| • |
a marine transportation business that operates on key U.S. inland and intracoastal waterway systems.
|
The safe operation of our assets is a top priority. We are committed to protecting the environment and the health and safety of the public and those working on our behalf by conducting our business activities in a safe and environmentally responsible manner. For additional information, see “
Environmental, Safety and Conservation
” within the Regulatory Matters section of Part I, Items 1 and 2 of the 2022 Form 10-K.
Like many publicly traded partnerships, we have no employees. All of our management, administrative and operating functions are performed by employees of EPCO pursuant to an administrative services agreement (the “ASA”) or by other service providers.
Our financial position, results of operations and cash flows are subject to certain risks. For information regarding such risks, see “
Risk Factors
” included under Part I, Item 1A of the 2022 Form 10-K.
We provide investors access to additional information regarding the Partnership and our consolidated businesses, including information relating to governance procedures and principles, through our website,
www.enterpriseproducts.com
.
Recent Developments
Enterprise Announces Permian Growth Projects; Conversion of Crude Oil Pipeline back to NGL Service
In October 2023, we announced the following four new projects to support ongoing production growth in the Permian Basin (including their respective scheduled completion dates):
| • |
the Bahia NGL Pipeline (first half of 2025);
|
| • |
our Mentone 4 natural gas processing plant in the Delaware Basin (second half of 2025);
|
| • |
our Orion natural gas processing plant in the Midland Basin (second half of 2025); and
|
| • |
an NGL fractionator (“Frac 14”) and an associated deisobutanizer (“DIB”) unit in Chambers County, TX (second half of 2025)
|
In addition, we have taken initial steps to convert the
Midland-to-Sealy segment of the Midland-to-ECHO 2 pipeline back to NGL service (as part of our Seminole NGL Pipeline). We expect this conversion to be completed in December 2023.
Enterprise Begins Service At PDH 2 Plant
In July 2023, we placed into service our second propane dehydrogenation plant (“PDH 2”) in Chambers County, Texas. Supported by long-term, fee-based contracts, PDH 2 has the capacity to consume 35 MBPD of propane to produce 1.65 billion pounds of PGP per year, which will help us supply our petrochemical customers with the feedstock to produce products that meet the needs of a growing global population. With the completion and integration of our PDH 2 plant with our existing PDH 1 plant and other propylene production facilities, we now have the capacity to produce approximately 11 billion pounds of propylene per year.
Enterprise Begins Service At Its Twelfth NGL Fractionator in Chambers County, Texas
In July 2023, our twelfth NGL fractionator (“Frac 12”) located in Chambers County, Texas was placed into service. The incremental 150 MBPD of nameplate capacity at Frac 12 will help accommodate growing NGL production from new natural gas processing plants in the Permian Basin and help satisfy the demand for feedstocks by the petrochemical and refining industries and LPG exports to developing nations. Supported by long-term customer agreements, the addition of Frac 12 increases total NGL fractionation capacity to approximately 1.2 MMBPD at our Chambers County complex and approximately 1.7 MMBPD company-wide.
Enterprise Begins Service At Its Poseidon Natural Gas Processing Plant
|
In July 2023, we placed into service our Poseidon cryogenic natural gas processing plant (“Poseidon”), which is located in Glasscock County, Texas. The new plant, which is our sixth in the Midland Basin, has a nameplate capacity of 300 MMcf/d and can extract more than 40 MBPD of NGLs. Supported by long-term acreage dedication agreements, the new plant will support Permian Basin producers as they meet growing demand in the U.S. and internationally. With the addition of Poseidon, we now have the capability to process 1.3 Bcf/d of natural gas and extract more than 185 MBPD of NGLs in the Midland Basin.
|
Enterprise Completes Expansion of Acadian Haynesville Extension
In May 2023, we completed an expansion of our Acadian Haynesville Extension natural gas pipeline. This expansion adds approximately 400 MMcf/d of Haynesville natural gas takeaway capacity to meet growing industrial demand in the Mississippi River Corridor and supports the Louisiana liquefied natural gas export market.
The incremental compression added as part of the expansion project increased total natural gas transportation capacity on the Acadian Haynesville Extension from approximately 2.1 Bcf/d to 2.5 Bcf/d. This expansion is underwritten by long-term, take-or-pay contracts.
Issuance of $1.75 Billion of Senior Notes in January 2023
In January 2023, EPO issued $1.75 billion aggregate principal amount of senior notes comprised of (i) $750 million principal amount of senior notes due January 2026 (“Senior Notes FFF”) and (ii) $1.0 billion principal amount of senior notes due January 2033 (“Senior Notes GGG”).
Net proceeds from this offering were used by EPO for general company purposes, including for growth capital investments, and the repayment of debt (including the repayment of all of our $1.25 billion principal amount of 3.35% Senior Notes HH at their maturity in March 2023 and amounts outstanding under our commercial paper program).
Senior Notes FFF were issued at 99.893% of their principal amount and have a fixed-rate interest rate of 5.05% per year. Senior Notes GGG were issued at 99.803% of their principal amount and have a fixed-rate interest rate of 5.35% per year. The Partnership guaranteed these senior notes through an unconditional guarantee on an unsecured and unsubordinated basis.
Selected Energy Commodity Price Data
The following table presents selected average index prices for natural gas and selected NGL and petrochemical products for the periods indicated:
|
|
Polymer
|
Refinery
|
Indicative Gas
|
||||||
|
Natural
|
Normal
|
Natural
|
Grade
|
Grade
|
Processing
|
||||
|
Gas,
|
Ethane,
|
Propane,
|
Butane,
|
Isobutane,
|
Gasoline,
|
Propylene,
|
Propylene,
|
Gross Spread
|
|
|
$/MMBtu
|
$/gallon
|
$/gallon
|
$/gallon
|
$/gallon
|
$/gallon
|
$/pound
|
$/pound
|
$/gallon
|
|
|
(1)
|
(2)
|
(2)
|
(2)
|
(2)
|
(2)
|
(3)
|
(3)
|
(4)
|
|
|
2022 by quarter:
|
|||||||||
|
1st Quarter
|
$4.96
|
$0.40
|
$1.30
|
$1.59
|
$1.60
|
$2.21
|
$0.63
|
$0.39
|
$0.55
|
|
2nd Quarter
|
$7.17
|
$0.59
|
$1.24
|
$1.50
|
$1.68
|
$2.17
|
$0.61
|
$0.40
|
$0.46
|
|
3rd Quarter
|
$8.20
|
$0.55
|
$1.08
|
$1.19
|
$1.44
|
$1.72
|
$0.47
|
$0.28
|
$0.26
|
|
4th Quarter
|
$6.26
|
$0.39
|
$0.79
|
$0.97
|
$1.03
|
$1.54
|
$0.32
|
$0.18
|
$0.17
|
|
2022 Averages
|
$6.65
|
$0.48
|
$1.10
|
$1.31
|
$1.44
|
$1.91
|
$0.51
|
$0.31
|
$0.36
|
|
2023 by quarter:
|
|||||||||
|
1st Quarter
|
$3.44
|
$0.25
|
$0.82
|
$1.11
|
$1.16
|
$1.62
|
$0.50
|
$0.22
|
$0.37
|
|
2nd Quarter
|
$2.09
|
$0.21
|
$0.67
|
$0.78
|
$0.84
|
$1.44
|
$0.40
|
$0.21
|
$0.37
|
|
3rd Quarter
|
$2.54
|
$0.30
|
$0.68
|
$0.83
|
$0.94
|
$1.55
|
$0.36
|
$0.15
|
$0.40
|
|
2023 Averages
|
$2.69
|
$0.25
|
$0.72
|
$0.91
|
$0.98
|
$1.54
|
$0.42
|
$0.19
|
$0.38
|
|
(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, Texas 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 (“RGP”) prices represent weighted-average spot prices for such product as reported by IHS.
|
|
(4)
|
The “Indicative Gas Processing Gross Spread” represents our generic estimate of the gross economic benefit from extracting NGLs from natural gas production based on certain pricing assumptions. Specifically, it is the amount by which the assumed economic value of a composite gallon of NGLs in Chambers County, Texas exceeds the value of the equivalent amount of energy in natural gas at Henry Hub, Louisiana. Our estimate of the indicative spread does not consider the operating costs incurred by a natural gas processing facility to extract the NGLs nor the transportation and fractionation costs to deliver the NGLs to market. In addition, the actual gas processing spread earned at each plant is further influenced by regional pricing and extraction dynamics.
|
The weighted-average indicative market price for NGLs was $0.61 per gallon in the third quarter of 2023 versus $0.95 per gallon in the third quarter of 2022. Likewise, the weighted-average indicative market price for NGLs was $0.61 per gallon during the nine months ended September 30, 2023 compared to $0.99 per gallon during the same period in 2022.
The following table presents selected average index prices for crude oil for the periods indicated:
|
|
WTI
|
Midland
|
Houston
|
LLS
|
|
Crude Oil,
|
Crude Oil,
|
Crude Oil,
|
Crude Oil,
|
|
|
$/barrel
|
$/barrel
|
$/barrel
|
$/barrel
|
|
|
(1)
|
(2)
|
(2)
|
(3)
|
|
|
2022 by quarter:
|
||||
|
1st Quarter
|
$94.29
|
$96.43
|
$96.77
|
$96.77
|
|
2nd Quarter
|
$108.41
|
$109.66
|
$109.96
|
$110.17
|
|
3rd Quarter
|
$91.56
|
$93.41
|
$93.77
|
$94.17
|
|
4th Quarter
|
$82.64
|
$83.97
|
$84.33
|
$85.50
|
|
2022 Averages
|
$94.23
|
$95.87
|
$96.21
|
$96.65
|
|
2023 by quarter:
|
||||
|
1st Quarter
|
$76.13
|
$77.50
|
$77.74
|
$79.00
|
|
2nd Quarter
|
$73.78
|
$74.48
|
$74.68
|
$75.87
|
|
3rd Quarter
|
$82.26
|
$83.85
|
$84.02
|
$84.72
|
|
2023 Averages
|
$77.39
|
$78.61
|
$78.81
|
$79.86
|
|
(1)
|
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.
|
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.
We attempt to mitigate commodity price exposure through our hedging activities and the use of fee-based arrangements. See Note 13 of the Notes to Unaudited Condensed Consolidated Financial Statements included under Part I, Item 1 of this quarterly report and “
Quantitative and Qualitative Disclosures About Market Risk
” under Part I, Item 3 of this quarterly report for information regarding our commodity hedging activities.
Impact of Inflation
Inflation rates in the United States increased significantly in 2022 and have continued to remain elevated in 2023 compared to recent historical levels. While pandemic-era supply chain disruptions have largely dissipated and measures taken by the U.S. Federal Reserve Bank have helped slow the growth of inflation in 2023, the high cost environment that began in 2022 has generally remained intact in 2023. However, to the extent that a rising cost environment impacts our results, there are typically offsetting benefits either inherent in our business or that result from other steps we take proactively to reduce the impact of inflation on our net operating results. These benefits include: (1) provisions included in our long-term fee-based revenue contracts that offset cost increases in the form of rate escalations based on positive changes in the U.S. Consumer Price Index, Producer Price Index for Finished Goods or other factors; (2) provisions in other revenue contracts that enable us to pass through higher energy costs to customers in the form of gas, electricity and fuel rebills or surcharges; and (3) higher commodity prices, which generally enhance our results in the form of increased volumetric throughput and demand for our services. Additionally, we take measures to mitigate the impact of cost increases in certain commodities, including a portion of our electricity needs, using fixed-price, term purchase agreements or financial derivatives. For these reasons, the increased cost environment, caused in part by inflation, has not had a material impact on our historical results of operations for the periods presented in this report. However, a significant or prolonged period of high inflation could adversely impact our results if costs were to increase at a rate greater than the increase in the revenues we receive.
See “
Capital Investments
” within this Part I, Item 2 for a discussion of the impact of inflation on our capital investment decisions.
Income Statement Highlights
The following table summarizes the key components of our consolidated results of operations for the periods indicated (dollars in millions):
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Revenues
|
$
|
11,998
|
$
|
15,468
|
$
|
35,093
|
$
|
44,536
|
||||||||
|
Costs and expenses:
|
||||||||||||||||
|
Operating costs and expenses:
|
||||||||||||||||
|
Cost of sales
|
8,786
|
12,319
|
25,796
|
35,325
|
||||||||||||
|
Other operating costs and expenses
|
986
|
926
|
2,749
|
2,567
|
||||||||||||
|
Depreciation, amortization and accretion expenses
|
583
|
537
|
1,692
|
1,607
|
||||||||||||
|
Asset impairment charges
|
11
|
29
|
27
|
48
|
||||||||||||
|
Net losses (gains) attributable to asset sales and related matters
|
−
|
1
|
(4
|
)
|
3
|
|||||||||||
|
Total operating costs and expenses
|
10,366
|
13,812
|
30,260
|
39,550
|
||||||||||||
|
General and administrative costs
|
59
|
55
|
172
|
179
|
||||||||||||
|
Total costs and expenses
|
10,425
|
13,867
|
30,432
|
39,729
|
||||||||||||
|
Equity in income of unconsolidated affiliates
|
122
|
111
|
347
|
335
|
||||||||||||
|
Operating income
|
1,695
|
1,712
|
5,008
|
5,142
|
||||||||||||
|
Other income (expense):
|
||||||||||||||||
|
Interest expense
|
(328
|
)
|
(309
|
)
|
(944
|
)
|
(937
|
)
|
||||||||
|
Other, net
|
5
|
7
|
36
|
12
|
||||||||||||
|
Total other expense, net
|
(323
|
)
|
(302
|
)
|
(908
|
)
|
(925
|
)
|
||||||||
|
Income before income taxes
|
1,372
|
1,410
|
4,100
|
4,217
|
||||||||||||
|
Provision for income taxes
|
(22
|
)
|
(18
|
)
|
(45
|
)
|
(54
|
)
|
||||||||
|
Net income
|
1,350
|
1,392
|
4,055
|
4,163
|
||||||||||||
|
Net income attributable to noncontrolling interests
|
(31
|
)
|
(31
|
)
|
(91
|
)
|
(93
|
)
|
||||||||
|
Net income attributable to preferred units
|
(1
|
)
|
(1
|
)
|
(3
|
)
|
(3
|
)
|
||||||||
|
Net income attributable to common unitholders
|
$
|
1,318
|
$
|
1,360
|
$
|
3,961
|
$
|
4,067
|
||||||||
Revenues
The following table presents each business segment’s contribution to consolidated revenues for the periods indicated (dollars in millions):
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
NGL Pipelines & Services:
|
||||||||||||||||
|
Sales of NGLs and related products
|
$
|
3,021
|
$
|
5,519
|
$
|
10,325
|
$
|
16,139
|
||||||||
|
Midstream services
|
736
|
718
|
2,050
|
2,232
|
||||||||||||
|
Total
|
3,757
|
6,237
|
12,375
|
18,371
|
||||||||||||
|
Crude Oil Pipelines & Services:
|
||||||||||||||||
|
Sales of crude oil
|
5,068
|
4,455
|
12,999
|
13,202
|
||||||||||||
|
Midstream services
|
297
|
269
|
851
|
979
|
||||||||||||
|
Total
|
5,365
|
4,724
|
13,850
|
14,181
|
||||||||||||
|
Natural Gas Pipelines & Services:
|
||||||||||||||||
|
Sales of natural gas
|
537
|
1,556
|
1,828
|
3,795
|
||||||||||||
|
Midstream services
|
347
|
330
|
1,046
|
901
|
||||||||||||
|
Total
|
884
|
1,886
|
2,874
|
4,696
|
||||||||||||
|
Petrochemical & Refined Products Services:
|
||||||||||||||||
|
Sales of petrochemicals and refined products
|
1,647
|
2,346
|
5,052
|
6,470
|
||||||||||||
|
Midstream services
|
345
|
275
|
942
|
818
|
||||||||||||
|
Total
|
1,992
|
2,621
|
5,994
|
7,288
|
||||||||||||
|
Total consolidated revenues
|
$
|
11,998
|
$
|
15,468
|
$
|
35,093
|
$
|
44,536
|
||||||||
Third Quarter of 2023 Compared to Third Quarter of 2022.
Total revenues for the third quarter of 2023 decreased a net $
3.5
billion when compared to the third quarter of 2022 primarily due to lower marketing revenues.
Revenues from the marketing of NGLs and petrochemicals and refined products decreased a combined $
3.2
billion quarter-to-quarter primarily due to lower average sales prices, which accounted for a $
2.9
billion decrease, and lower sales volumes, which accounted for an additional $
265
million decrease. Revenues from the marketing of natural gas decreased $1.0 billion quarter-to-quarter primarily due to lower average sales prices. Revenues from the marketing of crude oil increased a net $613 million quarter-to-quarter primarily due to higher sales volumes, which accounted for a $
1.4 b
illion increase, partially offset by lower average sales prices, which accounted for a $
837
million decrease.
Revenues from midstream services for the third quarter of 2023 increased $
133
million when compared to the third quarter of 2022.
R
evenues from our NGL, natural gas and petrochemicals and refined products pipeline assets increased a combined $66 million quarter-to-quarter primarily due to higher demand for transportation services. Revenues from our Chambers County propylene production facilities increased $38 million quarter-to-quarter primarily due to higher propylene processing revenues as a result of contributions from our PDH 2 facility, which was placed into service in July 2023. Lastly, revenues from our natural gas processing facilities increased $
27
million quarter-to-quarter primarily due to an increase in total fee-based natural gas processing volumes as a result of the addition of Poseidon, which was placed into service in July 2023.
Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022
.
Total revenues for the nine months ended September 30, 2023 decreased $9.4 billion when compared to the nine months ended September 30, 2022 primarily due to lower marketing revenues.
Revenues from the marketing of NGLs decreased $5.8 billion period-to-period primarily due to lower average sales prices. Revenues from the marketing of crude oil, natural gas and petrochemicals and refined products decreased a combined net $3.6 billion period-to-period primarily due to lower average sales prices, which accounted for a $6.8 billion decrease, partially offset by higher sales volumes, which accounted for a $3.2 billion increase.
Revenues from midstream services for the nine months ended September 30, 2023 decreased a net $41 million when compared to the nine months ended September 30, 2022.
Revenues from our natural gas processing facilities decreased $153 million period-to-period primarily due to lower market values for the equity NGL-equivalent production volumes we receive as non-cash consideration for processing services.
Revenues from our crude oil pipeline assets decreased $101 million period-to-period primarily due to lower deficiency revenues as a result of the expiration of minimum volume commitments under certain long-term gathering agreements on our EFS Midstream System and South Texas Crude Oil Pipeline System. Lastly, revenues from our NGL and natural gas pipeline assets increased a combined $233 million period-to-period primarily due to higher demand for transportation services and the addition of the Midland Basin Gathering System, which
was acquired in February 2022.
Operating costs and expenses
Total operating costs and expenses for the three and nine months ended September 30, 2023 decreased $3.4 billion and $9.3 billion, respectively, when compared to the same periods in 2022.
Cost of sales
Third Quarter of 2023 Compared to Third Quarter of 2022.
Cost of sales for the third quarter of 2023 decreased a net $3.5
b
illion when compared to the third quarter of 2022. The cost of sales associated with the marketing of NGLs and petrochemicals and refined products decreased a combined $3.6 billion quarter-to-quarter primarily due to lower average purchase prices, which accounted for a $3.4 billion decrease, and lower volumes, which accounted for an additional $240 million decrease. The cost of sales associated with the marketing of natural gas decreased $520 million primarily due to lower average purchase prices.
The cost of sales associated with the marketing of crude oil increased a net $641 million primarily due to higher volumes, which accounted for a $1.2 billion increase, partially offset by lower average purchase prices, which accounted for a $620 million decrease.
Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022
.
Cost of sales for the nine months ended September 30, 2023 decreased $9.5 billion when compared to the nine months ended September 30, 2022. The cost of sales associated with our marketing of NGLs decreased $6.4 billion period-to-period primarily due to lower average purchase prices. The cost of sales associated with the marketing of crude oil, natural gas and petrochemicals and refined products decreased a combined net $3.1 billion primarily due to lower average purchase prices, which accounted for a $5.9 billion decrease, partially offset by higher volumes, which accounted for a $2.8 billion increase.
Other operating costs and expenses
Other operating costs and expenses for the third quarter of 2023 increased $60 million when compared to the third quarter of 2022 primarily due to higher maintenance, rental, employee compensation and other operating costs.
Other operating costs and expenses for the nine months ended September 30, 2023 increased a net $182 million when compared to the nine months ended September 30, 2022 primarily due to higher maintenance, rental, employee compensation and other operating costs, which accounted for a $252 million increase, partially offset by lower utility costs, which accounted for a $70 million decrease.
Depreciation, amortization and accretion expenses
Depreciation, amortization and accretion expense for the three and nine months ended September 30, 2023 increased a combined $46 million and $85
million, respectively,
when compared to the same periods in 2022. Depreciation expense increased $29 million quarter-to-quarter and $49
million period-to-period
primarily due to the addition of our PDH 2 facility, which was placed into service in July 2023, assets attributable to the acquisition of our Midland Basin System in February 2022 and other assets placed into full or limited service since the end of the respective periods in 2022. Additionally,
amortization expense associated with our contract-based intangible assets accounted for an additional $7 million of the quarter-to-quarter increase and $17 million of the period-to-period increase
.
General and administrative costs
General and administrative costs for the third quarter of 2023 increased $4 million when compared to the third quarter of 2022 primarily due to higher employee compensation costs. General and administrative costs for the nine months ended September 30, 2023 decreased $7 million when compared to the same period in 2022 primarily due to lower professional services and employee compensation costs.
Equity in income of unconsolidated affiliates
Equity income from our unconsolidated affiliates for the three and nine months ended September 30, 2023 increased $11 million and $12 million, respectively, when compared to the same periods in 2022 primarily due to higher earnings from investments in crude oil pipelines.
Operating income
Operating income for the three and nine months ended September 30, 2023 decreased $17 million and $134 million, respectively, when compared to the same periods in 2022 due to the previously described quarter-to-quarter and period-to-period changes.
Interest expense
The following table presents the components of our consolidated interest expense for the periods indicated (dollars in millions):
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Interest charged on debt principal outstanding (1)
|
$
|
341
|
$
|
321
|
$
|
1,014
|
$
|
962
|
||||||||
|
Impact of interest rate hedging program, including related amortization
|
(2
|
)
|
1
|
(3
|
)
|
15
|
||||||||||
|
Interest costs capitalized in connection with construction projects (2)
|
(17
|
)
|
(22
|
)
|
(86
|
)
|
(60
|
)
|
||||||||
|
Other
|
6
|
9
|
19
|
20
|
||||||||||||
|
Total
|
$
|
328
|
$
|
309
|
$
|
944
|
$
|
937
|
||||||||
|
(1)
|
The weighted-average interest rates on debt principal outstanding during the three and nine months ended September 30, 2023 were 4.55% and 4.57%, respectively. The weighted-average interest rate on debt principal outstanding during each of the three and nine months ended September 30, 2022 were 4.33% and 4.32%, respectively.
|
|
(2)
|
We capitalize interest costs incurred on funds used to construct property, plant and equipment while the asset is in its construction phase. Capitalized interest amounts become part of the historical cost of an asset and are charged to earnings (as a component of depreciation expense) on a straight-line basis over the estimated useful life of the asset once the asset enters its intended service. When capitalized interest is recorded, it reduces interest expense from what it would be otherwise. Capitalized interest amounts fluctuate based on the timing of when projects are placed into service, our capital investment levels and the interest rates charged on borrowings.
|
Interest charged on debt principal outstanding, which is a key driver of interest expense, increased a net $20 million quarter-to-quarter. This increase was primarily due to
the issuance of $1.75 billion fixed-rate senior notes in January 2023, which accounted for a $23 million increase, partially offset by a $13 million decrease as a result of the retirement of $1.25 billion of fixed-rate senior notes in March 2023 and the redemption of $350 million of junior subordinated notes in August 2022
. In addition, interest expense on our outstanding variable-rate junior subordinated notes increased $5 million primarily due to a quarter-to-quarter increase in the applicable 3-month variable rate. Beginning on July 1, 2023, our junior subordinated notes subject to a variable rate replaced the applicable LIBOR Rate with the 3-month CME Term SOFR plus a 0.26161% tenor spread adjustment.
Interest charged on debt principal outstanding increased a net $52 million period-to-period. This increase was primarily due to
the aforementioned issuance of senior notes, which accounted for a $66 million increase, partially offset by a $40 million decrease as a result of the retirement of $1.4 billion and $1.25 billion of fixed-rate senior notes in February 2022 and March 2023, respectively, and the redemption of the aforementioned junior subordinated notes in August 2022
. In addition, interest expense on our outstanding variable-rate junior subordinated notes increased $16 million primarily due to a period-to-period increase in the applicable 3-month variable rate.
For additional information regarding our debt obligations, see Note 7 of the Notes to Unaudited Condensed Consolidated Financial Statements included under Part I, Item 1 of this quarterly report. For a discussion of our capital projects, see “
Capital Investments
” within this Part I, Item 2.
Income taxes
Our income taxes are primarily comprised of our state tax obligations under the Revised Texas Franchise Tax (“Texas Margin Tax”). Our provision for income taxes for the three and nine months ended September 30, 2023 increased $4 million
and decreased $9 million, respectively, when compared to the same periods in 2022.
Business Segment Highlights
Our operations are reported under four business segments: (i) NGL Pipelines & Services, (ii) Crude Oil Pipelines & Services, (iii) Natural Gas Pipelines & Services and (iv) Petrochemical & Refined Products Services. Our business segments are generally organized and managed according to the types of services rendered (or technologies employed) and products produced and/or sold.
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 following table presents gross operating margin by segment and total gross operating margin, a non-generally accepted accounting principle (“non-GAAP”) financial measure, for the periods indicated (dollars in millions):
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Gross operating margin by segment:
|
||||||||||||||||
|
NGL Pipelines & Services
|
$
|
1,196
|
$
|
1,296
|
$
|
3,518
|
$
|
3,848
|
||||||||
|
Crude Oil Pipelines & Services
|
432
|
415
|
1,251
|
1,237
|
||||||||||||
|
Natural Gas Pipelines & Services
|
239
|
278
|
791
|
727
|
||||||||||||
|
Petrochemical & Refined Products Services
|
453
|
353
|
1,255
|
1,178
|
||||||||||||
|
Total segment gross operating margin (1)
|
2,320
|
2,342
|
6,815
|
6,990
|
||||||||||||
|
Net adjustment for shipper make-up rights
|
11
|
(21
|
)
|
32
|
(49
|
)
|
||||||||||
|
Total gross operating margin (non-GAAP)
|
$
|
2,331
|
$
|
2,321
|
$
|
6,847
|
$
|
6,941
|
||||||||
|
(1)
|
Within the context of this table, total segment gross operating margin represents a subtotal and corresponds to measures similarly titled within our business segment disclosures found under Note 10 of the Notes to Unaudited Condensed Consolidated Financial Statements included under Part I, Item 1 of this quarterly report.
|
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. Our calculation of gross operating margin may or may not be comparable to similarly titled measures used by other companies. Segment gross operating margin for NGL Pipelines & Services and Crude Oil Pipelines & Services reflect adjustments for shipper make-up rights that are included in management’s evaluation of segment results. However, these adjustments are excluded from non-GAAP total gross operating margin.
The GAAP financial measure most directly comparable to total gross operating margin is operating income. For a discussion of operating income and its components, see the previous section titled “
Income Statement Highlights
” within this Part I, Item 2. The following table presents a reconciliation of operating income to total gross operating margin for the periods indicated (dollars in millions):
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Operating income
|
$
|
1,695
|
$
|
1,712
|
$
|
5,008
|
$
|
5,142
|
||||||||
|
Adjustments to reconcile operating income to total gross operating margin
(addition or subtraction indicated by sign):
|
||||||||||||||||
|
Depreciation, amortization and accretion expense in operating costs
and expenses (1)
|
566
|
524
|
1,644
|
1,569
|
||||||||||||
|
Asset impairment charges in operating costs and expenses
|
11
|
29
|
27
|
48
|
||||||||||||
|
Net losses (gains) attributable to asset sales and related matters in operating
costs and expenses
|
−
|
1
|
(4
|
)
|
3
|
|||||||||||
|
General and administrative costs
|
59
|
55
|
172
|
179
|
||||||||||||
|
Total gross operating margin (non-GAAP)
|
$
|
2,331
|
$
|
2,321
|
$
|
6,847
|
$
|
6,941
|
||||||||
|
(1)
|
Excludes amortization of major maintenance costs for reaction-based plants, which are a component of gross operating margin.
|
Each of our business segments benefits from the supporting role of our marketing activities. The main purpose of our marketing activities is to support the utilization and expansion of assets across our midstream energy asset network by increasing the volumes handled by such assets, which results in additional fee-based earnings for each business segment. In performing these support roles, our marketing activities also seek to participate in supply and demand opportunities as a supplemental source of gross operating margin for us. The financial results of our marketing efforts fluctuate due to changes in volumes handled and overall market conditions, which are influenced by current and forward market prices for the products bought and sold.
NGL Pipelines & Service
s
The following table presents segment gross operating margin and selected volumetric data for the NGL Pipelines & Services segment for the periods indicated (dollars in millions, volumes as noted):
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Segment gross operating margin:
|
||||||||||||||||
|
Natural gas processing and related NGL marketing activities
|
$
|
293
|
$
|
485
|
$
|
929
|
$
|
1,487
|
||||||||
|
NGL pipelines, storage and terminals
|
704
|
611
|
1,992
|
1,716
|
||||||||||||
|
NGL fractionation
|
199
|
200
|
597
|
645
|
||||||||||||
|
Total
|
$
|
1,196
|
$
|
1,296
|
$
|
3,518
|
$
|
3,848
|
||||||||
|
Selected volumetric data:
|
||||||||||||||||
|
NGL pipeline transportation volumes (MBPD)
|
3,974
|
3,702
|
3,965
|
3,650
|
||||||||||||
|
NGL marine terminal volumes (MBPD)
|
771
|
747
|
787
|
713
|
||||||||||||
|
NGL fractionation volumes (MBPD)
|
1,519
|
1,371
|
1,528
|
1,341
|
||||||||||||
|
Equity NGL-equivalent production volumes (MBPD) (1)
|
184
|
182
|
173
|
188
|
||||||||||||
|
Fee-based natural gas processing volumes (MMcf/d) (2,3)
|
5,928
|
5,202
|
5,717
|
5,091
|
||||||||||||
|
(1)
|
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.
|
|
(2)
|
Volumes reported correspond to the revenue streams earned by our natural gas processing plants.
|
|
(3)
|
Fee-based natural gas processing volumes are measured at either the wellhead or plant inlet in MMcf/d.
|
Natural gas processing and related NGL marketing activities
Third Quarter of 2023 Compared to Third Quarter of 2022
.
Gross operating margin from natural gas processing and related NGL marketing activities for the third quarter of 2023 decreased $192 million when compared to the third quarter of 2022.
Gross operating margin from our NGL marketing activities decreased $77 million quarter-to-quarter primarily due to lower average sales margins, which accounted for a $61 million decrease, and lower non-cash, mark-to-market earnings, which accounted for an additional $16 million decrease.
Gross operating margin from our Midland Basin natural gas processing facilities decreased a net $65 million quarter-to-quarter primarily due to lower average processing margins (including the impact of hedging activities), which accounted for a $70 million decrease, and higher utility and other operating expenses, which accounted for an additional $8 million decrease, partially offset by higher fee-based natural gas processing volumes, which accounted for a $13 million increase. Fee-based processing volumes at our Midland Basin natural gas processing facilities increased 212 MMcf/d quarter-to-quarter primarily due to processing volumes contributed by our Poseidon natural gas processing plant, which was placed into service in July 2023.
Gross operating margin from our Delaware Basin natural gas processing facilities decreased $35 million quarter-to-quarter primarily due to lower average processing margins (including the impact of hedging activities). Fee-based natural gas processing volumes and equity NGL-equivalent production volumes at these facilities decreased 14 MMcf/d and 2 MBPD, respectively, quarter-to-quarter.
Gross operating margin from our South Texas natural gas processing facilities decreased a net $4 million quarter-to-quarter primarily due to lower average processing margins (including the impact of hedging activities), which accounted for a $5 million decrease, and a 6 MBPD decrease in equity NGL-equivalent production volumes, which accounted for an additional $5 million decrease, partially offset by a 181 MMcf/d increase in fee-based natural gas processing volumes, which accounted for a $3 million increase, and lower maintenance and other operating costs, which accounted for an additional $3 million increase.
Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022
.
Gross operating margin from natural gas processing and related NGL marketing activities for the nine months ended September 30, 2023 decreased $558 million when compared to the nine months ended September 30, 2022.
Gross operating margin from our NGL marketing activities decreased $256 million period-to-period primarily due to lower average sales margins, which accounted for a $218 million decrease, and lower sales volumes, which accounted for an additional $35 million decrease.
Gross operating margin from our Midland Basin natural gas processing facilities decreased a net $146 million period-to-period primarily due to lower average processing margins (including the impact of hedging activities), which accounted for a $204 million decrease, and higher operating costs, which accounted for an additional $20 million decrease, partially offset by an increase in total equity NGL-equivalent production volumes, which accounted for a $24 million increase, and an increase in total fee-based natural gas processing volumes, which accounted for an additional $56 million increase. Fee-based natural gas processing volumes at these facilities, which reflect the average daily operating rates from the time the asset was acquired, increased 173 MMcf/d and equity NGL-equivalent production volumes increased 1 MBPD period-to-period.
Gross operating margin from our Delaware Basin natural gas processing facilities decreased $86 million period-to-period primarily due to lower average processing margins (including the impact of hedging activities).
Fee-based natural gas processing volumes at these facilities increased
81
MMcf/d and equity NGL-equivalent production volumes decreased
3
MBPD
period-to-period
.
Gross operating margin from our South Texas natural gas processing facilities decreased $40 million period-to-period primarily due to lower average processing margins (including the impact of hedging activities), which accounted for a $33 million decrease, and higher maintenance and other operating costs, which accounted for an additional $7 million decrease. Fee-based natural gas processing volumes increased 96 MMcf/d and equity NGL-equivalent production volumes decreased 1 MBPD period-to-period.
Gross operating margin from our Louisiana and Mississippi natural gas processing facilities decreased $16 million
period-to-period primarily due to lower average processing margins (including the impact of hedging activities). Fee-based natural gas processing volumes increased 206 MMcf/d and equity NGL-equivalent production volumes decreased 3 MBPD period-to-period (net to our interest).
On a combined basis, gross operating margin from our Rockies natural gas processing facilities (Meeker, Pioneer and Chaco) decreased $10 million period-to-period primarily due to a 10 MBPD decrease in equity NGL-equivalent production volumes. Fee-based natural gas processing volumes decreased a combined 48 MMcf/d period-to-period.
NGL pipelines, storage and terminals
Third Quarter of 2023 Compared to Third Quarter of 2022
.
Gross operating margin from our NGL pipelines, storage and terminal assets during the third quarter of 2023 increased $93 million when compared to the third quarter of 2022.
Gross operating margin for our Eastern ethane pipelines, which include our ATEX and Aegis pipelines, increased a combined $25 million quarter-to-quarter
primarily due to higher average transportation fees. Transportation volumes on these pipelines increased a combined 91 MBPD quarter-to-quarter.
A number of our pipelines, including the Mid-America Pipeline System, Seminole NGL Pipeline, Chaparral NGL Pipeline, and Shin Oak NGL Pipeline, serve Permian Basin and/or Rocky Mountain producers. On a combined basis, gross operating margin from these pipelines increased a net $19 million quarter-to-quarter primarily due to higher average transportation fees, which accounted for a $19 million increase, and a
64 MBPD (net to our interest) increase in transportation volumes, which accounted for an additional $5 million increase, partially offset by lower other revenues, which accounted for a $3 million decrease.
Gross operating margin from our South Texas NGL Pipeline System increased $14 million quarter-to-quarter primarily due to a 36 MBPD increase in transportation volumes, which accounted for a $7 million increase, and higher average transportation and related fees, which accounted for an additional $7 million increase.
Gross operating margin from LPG-related activities at our Enterprise Hydrocarbons Terminal (“EHT”) increased $13 million quarter-to-quarter primarily due to higher average loading fees. LPG export volumes at EHT increased 9 MBPD quarter-to-quarter. Gross operating margin at our Morgan’s Point Ethane Export Terminal increased $9 million quarter-to-quarter primarily due to a 15 MBPD increase in export volumes, which accounted for a $4 million increase, and higher average loading fees, which accounted for an additional $3 million increase. Gross operating margin from our related Houston Ship Channel Pipeline System increased $9 million quarter-to-quarter primarily due to higher average transportation fees, which accounted for a $4 million increase, and a 69 MBPD increase in transportation volumes, which accounted for an additional $3 million increase.
Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022
.
Gross operating margin from our NGL pipelines, storage and terminal assets during the nine months ended September 30, 2023 increased $276 million when compared to the nine months ended September 30, 2022.
On a combined basis gross operating margin for our Eastern ethane pipelines increased $58 million period-to-period
primarily due to a combined 82 MBPD increase in transportation volumes.
Gross operating margin from LPG-related activities at EHT increased $49 million period-to-period primarily due to higher average loading fees, which accounted for a $25 million increase, and a 49 MBPD increase in LPG export volumes, which accounted for an additional $19 million increase. Gross operating margin at our Morgan’s Point Ethane Export Terminal increased $34 million period-to-period primarily due to a 25 MBPD increase in export volumes, which accounted for a $21 million increase, and higher average loading fees, which accounted for an additional $9 million increase.
Gross operating margin from our related Houston Ship Channel Pipeline System increased $23 million period-to-period primarily due to a
105
MBPD increase in transportation volumes, which accounted for a $14 million increase, and higher average transportation fees, which accounted for an additional $9 million increase.
Gross operating margin from our South Texas NGL Pipeline System increased $31 million period-to-period primarily due to higher average transportation and related fees, which accounted for a $19 million increase, a 26 MBPD increase in transportation volumes, which accounted for a $6 million increase, and higher storage and other revenues, which accounted for an additional $6 million increase.
On a combined basis, gross operating margin for our pipelines that serve Permian Basin and/or Rocky Mountain producers increased a net $24 million period-to-period primarily due to higher average transportation fees, which accounted for a $27 million increase, a 72 MBPD (net to our interest) increase in transportation volumes, which accounted for a $9 million increase, and higher other revenues, which accounted for an additional $9 million increase, partially offset by higher maintenance and other operating costs, which accounted for a $21 million decrease.
Gross operating margin from our Chambers County storage complex increased $13 million period-to-period primarily due to lower operating costs, which accounted for a $7 million increase, and higher storage revenues, which accounted for an additional $6 million increase.
Gross operating margin from our South Louisiana NGL Pipeline System increased $11 million period-to-period primarily due to higher average transportation fees, which accounted for a $4 million increase, lower operating costs, which accounted for a $4 million increase, and a 16 MBPD increase in transportation volumes, which accounted for an additional $3 million increase.
NGL fractionation
Third Quarter of 2023 Compared to Third Quarter of 2022
.
Gross operating margin from NGL fractionation during the third quarter of 2023 decreased $1 million when compared to the third quarter of 2022.
Gross operating margin from our Chambers County NGL fractionation complex was flat quarter-to-quarter primarily due to a
114
MBPD (net to our interest) increase in fractionation volumes, which accounted for a $20 million increase, and lower utility and other operating costs, which accounted for an additional $8 million increase, offset by lower average fractionation fees, which accounted for a $24 million decrease, and lower ancillary service revenues, which accounted for an additional $5 million decrease. NGL fractionation volumes at our Chambers County NGL fractionation complex increased primarily due to contributions from Frac 12, which entered service in July 2023.
On a combined basis, gross operating margin from our other NGL fractionators decreased $3 million quarter-to-quarter primarily due to lower average fractionation fees. NGL fractionation volumes from our other NGL fractionators increased a combined
34
MBPD (net to our interest) quarter-to-quarter.
Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022
.
Gross operating margin from NGL fractionation during the nine months ended September 30, 2023 decreased $48 million when compared to the nine months ended September 30, 2022.
Gross operating margin from our Chambers County NGL fractionation complex decreased a net $35 million period-to-period primarily due to lower average fractionation fees, which accounted for a $53 million decrease
, and
lower ancillary services revenues, which accounted for an additional $46 million decrease,
partially offset by lower utility and other operating costs, which accounted for a $40 million increase, and a 155 MBPD (net to our interest) increase in fractionation volumes, which accounted for an additional $21 million increase.
NGL fractionation volumes from our Chambers County NGL fractionation complex increased primarily due to contributions from Frac 12.
On a combined basis, gross operating margin from our other NGL fractionators decreased a net $16 million period-to-period primarily due to lower average fractionation fees, which accounted for a $26 million decrease, and lower ancillary service revenues, which accounted for an additional $8 million decrease, partially offset by a combined
32
MBPD (net to our interest) increase in NGL fractionation volumes, which accounted for a $13 million increase.
Crude Oil Pipelines & Services
The following table presents segment gross operating margin and selected volumetric data for the Crude Oil Pipelines & Services segment for the periods indicated (dollars in millions, volumes as noted):
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Segment gross operating margin:
|
||||||||||||||||
|
Midland-to-ECHO System and related business activities
|
$
|
136
|
$
|
84
|
$
|
406
|
$
|
281
|
||||||||
|
Other crude oil pipelines, terminals and related marketing results
|
296
|
331
|
845
|
956
|
||||||||||||
|
Total
|
$
|
432
|
$
|
415
|
$
|
1,251
|
$
|
1,237
|
||||||||
|
Selected volumetric data:
|
||||||||||||||||
|
Crude oil pipeline transportation volumes (MBPD)
|
2,560
|
2,216
|
2,409
|
2,204
|
||||||||||||
|
Crude oil marine terminal volumes (MBPD)
|
988
|
824
|
881
|
799
|
||||||||||||
Third Quarter of 2023 Compared to Third Quarter of 2022
. Gross operating margin from our Crude Oil Pipelines & Services segment for the third quarter of 2023 increased $17 million when compared to the third quarter of 2022.
Gross operating margin from our West Texas Pipeline System increased $72 million quarter-to-quarter primarily due to higher ancillary service and other revenues. Transportation volumes on our West Texas Pipeline System increased 46 MBPD quarter-to-quarter.
Gross operating margin from our Midland-to-ECHO System and related business activities increased $52 million quarter-to-quarter primarily due to a 137 MBPD (net to our interest) increase in transportation volumes, which accounted for a $27 million increase, and higher average transportation fees and related margins from marketing activities, which accounted for an additional $25 million increase.
Gross operating margin from our ECHO terminal increased $13 million quarter-to-quarter primarily due to higher terminaling and storage revenues, which accounted for a $9 million increase, and lower utility and other operating costs, which accounted for an additional $4 million increase.
Gross operating margin from crude oil activities at EHT increased $11 million quarter-to-quarter primarily due to higher loading revenues. Crude oil terminal volumes at EHT increased 200 MBPD quarter-to-quarter.
Gross operating margin from our crude oil marketing activities (excluding those attributable to the Midland-to-ECHO System) decreased $100 million quarter-to-quarter primarily due to lower non-cash, mark-to-market earnings, which accounted for a $75 million decrease, and lower average sales margins, which accounted for an additional $28 million decrease.
Gross operating margin from our South Texas Crude Oil Pipeline System decreased $25 million quarter-to-quarter primarily due to lower ancillary service and other revenues. Transportation volumes on our South Texas Crude Oil Pipeline System decreased 15 MBPD quarter-to-quarter.
Gross operating margin from our equity investment in the Seaway Pipeline decreased $6 million quarter-to-quarter primarily due to lower transportation and related fee revenues. Transportation volumes on our Seaway Pipeline increased 104 MBPD (net to our interest) quarter-to-quarter.
Gross operating margin from our EFS Midstream System decreased a net $4 million quarter-to-quarter primarily due to lower average transportation fees, which accounted for a $9 million decrease, partially offset by a 165 MMcf/d and 20 MBPD increase in natural gas and condensate transportation volumes, respectively, which accounted for a $6 million increase.
Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022
. Gross operating margin from our Crude Oil Pipelines & Services segment for the nine months ended September 30, 2023 increased $14 million when compared to the nine months ended September 30, 2022.
Gross operating margin from our West Texas Pipeline System increased $160 million period-to-period primarily due to higher ancillary service and other revenues. Transportation volumes on our West Texas Pipeline System increased 24 MBPD period-to-period.
Gross operating margin from our Midland-to-ECHO System and related business activities increased a net $125 million period-to-period primarily due to higher average transportation fees and related margins from marketing activities, which accounted for a $76 million increase, and a 108 MBPD (net to our interest) increase in transportation volumes, which accounted for an additional $62 million increase, partially offset by higher chemical, utility and other operating costs, which accounted for a $19 million decrease.
Gross operating margin from our ECHO terminal increased $17 million period-to-period primarily due to higher terminaling and storage revenues, which accounted for a $14 million increase, and lower utility and other operating costs, which accounted for an additional $3 million increase.
Gross operating margin from crude oil activities at EHT increased a net $8 million period-to-period primarily due to higher loading revenues, which accounted for a $17 million increase, partially offset by lower storage and other revenues, which accounted for a $10 million decrease. Crude oil terminal volumes at EHT increased 123 MBPD period-to-period.
Gross operating margin from our EFS Midstream system decreased $162 million period-to-period primarily due to lower deficiency revenues as a result of the expiration of minimum volume commitments under certain long-term gathering agreements at the end of June 2022, which accounted for a $106 million decrease, and lower average transportation fees, which accounted for an additional $51 million decrease.
Gross operating margin from our South Texas Crude Oil Pipeline System decreased $67 million period-to-period primarily due to lower ancillary service and other revenues, which accounted for a $29 million decrease, lower deficiency revenues as a result of the expiration of minimum volume commitments under certain long-term agreements at the end of July 2022, which accounted for an $18 million decrease, and lower average transportation fees, which accounted for an additional $13 million decrease. Transportation volumes on our South Texas Crude Oil Pipeline System decreased 32 MBPD period-to-period.
Gross operating margin from our equity investment in the Seaway Pipeline decreased $48 million period-to-period primarily due to lower transportation and related fee revenues. Transportation volumes on our Seaway Pipeline increased 73 MBPD (net to our interest) period-to-period.
Gross operating margin from our Midland terminal decreased $13 million period-to-period primarily due to lower ancillary service and other revenues.
Gross operating margin from our crude oil marketing activities (excluding those attributable to the Midland-to-ECHO System) decreased $5 million period-to-period primarily due to lower average sales margins.
Natural Gas Pipelines & Services
The following table presents segment gross operating margin and selected volumetric data for the Natural Gas Pipelines & Services segment for the periods indicated (dollars in millions, volumes as noted):
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Segment gross operating margin
|
$
|
239
|
$
|
278
|
$
|
791
|
$
|
727
|
||||||||
|
Selected volumetric data:
|
||||||||||||||||
|
Natural gas pipeline transportation volumes (BBtus/d)
|
18,440
|
17,514
|
18,244
|
16,935
|
||||||||||||
Third Quarter of 2023 Compared to Third Quarter of 2022
. Gross operating margin from our Natural Gas Pipelines & Services segment for the third quarter of 2023 decreased $39 million when compared to the third quarter of 2022.
On a combined basis, gross operating margin from our Jonah Gathering System, Piceance Basin Gathering System, and San Juan Gathering System in the Rocky Mountains decreased $26 million quarter-to-quarter primarily due to lower average gathering fees, which accounted for a $16 million decrease, higher maintenance and other operating costs, which accounted for a $5 million decrease, and a combined
90
BBtus/d decrease in gathering volumes, which accounted for an additional $2 million decrease.
Gross operating margin from our natural gas marketing activities decreased $11 million quarter-to-quarter primarily due to lower average sales margins attributable to location price differentials.
Gross operating margin from our Acadian Gas System and Haynesville Gathering System decreased a combined $10 million quarter-to-quarter primarily due to lower other revenues. On a combined basis, transportation volumes increased 51 BBtus/d quarter-to-quarter.
Gross operating margin from our East Texas Gathering System increased $5 million quarter-to-quarter primarily due to a
240
BBtus/d increase in gathering volumes.
Gross operating margin from our Midland Basin Gathering System, increased a net $3 million quarter-to-quarter primarily due to a 308 BBtus/d increase in natural gas gathering volumes, which accounted for a $9 million increase, partially offset by higher rental and other operating costs, which accounted for a $6 million decrease.
Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022
. Gross operating margin from our Natural Gas Pipelines & Services segment for the nine months ended September 30, 2023 increased $64 million when compared to the nine months ended September 30, 2022.
Gross operating margin from our natural gas marketing activities increased $24 million period-to-period primarily due to higher average sales margins attributable to location price differentials.
Gross operating margin from our East Texas Gathering System increased a net $17 million period-to-period primarily due to a
350
BBtus/d increase in gathering volumes, which accounted for a $22 million increase, partially offset by higher maintenance and other operating costs, which accounted for a $5 million decrease.
Gross operating margin from our Texas Intrastate System increased a net $15 million period-to-period primarily due to a
627
BBtus/d increase in transportation volumes, which accounted for a $19 million increase, and higher average transportation fees, which accounted for an additional $17 million increase, partially offset by higher operating costs, which accounted for a $13 million decrease, and lower ancillary and other revenues, which accounted for an additional $8 million decrease.
Gross operating margin from our Delaware Basin Gathering System increased $11 million period-to-period primarily due to higher ancillary service and other revenues, which accounted for a $6 million increase, and a 95 BBtus/d increase in gathering volumes, which accounted for an additional $4 million increase.
Gross operating margin from our Midland Basin Gathering System increased a net $7 million period-to-period primarily due to an increase in total natural gas gathering volumes, which accounted for a $43 million increase, partially offset by higher rental and other operating costs, which accounted for a $36 million decrease. Gathering volumes on our Midland Basin Gathering System, which reflect the average daily operating rates from the time the asset was acquired, increased 250 BBtus/d period-to-period.
On a combined basis, gross operating margin from our Jonah Gathering System, Piceance Basin Gathering System and San Juan Gathering System in the Rocky Mountains decreased a net $20 million period-to-period primarily due to higher maintenance and other operating costs, which accounted for a $15 million decrease, a 119 BBtus/d decrease in gathering volumes, which accounted for a $9 million decrease, and a decrease in condensate sales, which accounted for an additional $5 million decrease, partially offset by higher average gathering fees, which accounted for a $10 million increase.
Petrochemical & Refined Products Services
The following table presents segment gross operating margin and selected volumetric data for the Petrochemical & Refined Products Services segment for the periods indicated (dollars in millions, volumes as noted):
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Segment gross operating margin:
|
||||||||||||||||
|
Propylene production and related activities
|
$
|
120
|
$
|
110
|
$
|
427
|
$
|
474
|
||||||||
|
Butane isomerization and related operations
|
30
|
30
|
92
|
84
|
||||||||||||
|
Octane enhancement and related plant operations
|
164
|
104
|
341
|
308
|
||||||||||||
|
Refined products pipelines and related activities
|
93
|
67
|
261
|
194
|
||||||||||||
|
Ethylene exports and related activities
|
28
|
28
|
89
|
88
|
||||||||||||
|
Marine transportation and other services
|
18
|
14
|
45
|
30
|
||||||||||||
|
Total
|
$
|
453
|
$
|
353
|
$
|
1,255
|
$
|
1,178
|
||||||||
|
|
||||||||||||||||
|
Selected volumetric data:
|
||||||||||||||||
|
Propylene production volumes (MBPD)
|
103
|
101
|
104
|
105
|
||||||||||||
|
Butane isomerization volumes (MBPD)
|
112
|
122
|
110
|
109
|
||||||||||||
|
Standalone deisobutanizer (“DIB”) processing volumes (MBPD)
|
185
|
165
|
170
|
159
|
||||||||||||
|
Octane enhancement and related plant sales volumes (MBPD) (1)
|
41
|
40
|
34
|
39
|
||||||||||||
|
Pipeline transportation volumes, primarily refined products and petrochemicals (MBPD)
|
826
|
758
|
817
|
750
|
||||||||||||
|
Marine terminal volumes, primarily refined products and petrochemicals (MBPD)
|
331
|
166
|
311
|
200
|
||||||||||||
|
(1)
|
Reflects aggregate sales volumes for our octane enhancement and iBDH facilities located at our Chambers County complex and our HPIB facility located adjacent to the Houston Ship Channel.
|
Propylene production and related activities
Third Quarter of 2023 Compared to Third Quarter of 2022
.
Gross operating margin from propylene production and related activities for the third quarter of 2023 increased $10 million when compared to the third quarter of 2022.
Gross operating margin from our propylene pipeline systems increased a combined $6 million quarter-to-quarter primarily due to higher average transportation fees. On a combined basis, transportation volumes decreased 5 MBPD (net to our interest) quarter-to-quarter.
On a combined basis, gross operating margin from our Chambers County propylene production facilities decreased a net $1 million quarter-to-quarter primarily due to
lower propylene sales volumes, which accounted for a $19 million decrease, higher chemical, maintenance and other operating costs, which accounted for a $13 million decrease, and lower average propylene sales margins, which accounted for an additional $8 million decrease, partially offset by higher propylene processing revenues, which accounted for a $33 million increase, and higher storage and other revenues, which accounted for an additional $6 million increase. Propylene and associated by-product production volumes at these facilities increased a combined 1 MBPD (net to our interest) quarter-to-quarter primarily due to contributions from our PDH 2 facility, which was placed into service in July 2023, partially offset by downtime at our PDH 1 facility for unplanned maintenance during the third quarter of 2023.
Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022
.
Gross operating margin from propylene production and related activities for the nine months ended September 30, 2023 decreased $47 million when compared to the nine months ended September 30, 2022.
On a combined basis, gross operating margin from our Chambers County propylene production facilities decreased a net $72 million period-to-period primarily due to lower propylene sales volumes, which accounted for a $67 million decrease, and lower average propylene sales margins, which accounted for an additional $38 million decrease, partially offset by higher propylene processing revenues, which accounted for a $22 million increase, and higher storage and other revenues, which accounted for an additional $11 million increase. Propylene and associated by-product production volumes at these facilities, which reflect the average daily operating rates from the time the asset was placed into service, decreased a combined 1 MBPD (net to our interest) period-to-period primarily due to major maintenance activities at our PDH 1 facility during the first and third quarters of 2023 and major maintenance at three of our propylene splitters during the second quarter of 2023, partially offset by production from our PDH 2 facility, which was placed into service in July 2023.
Gross operating margin from our propylene pipeline systems increased a combined $14 million period-to-period primarily due to higher average transportation fees. On a combined basis, transportation volumes decreased 4 MBPD (net to our interest) period-to-period.
Butane isomerization and related operations
Third Quarter of 2023 Compared to Third Quarter of 2022
.
Gross operating margin from butane isomerization and related operations was flat quarter-to-quarter primarily due to lower utility and other operating costs, which accounted for a $4 million increase, and a 17 MBPD increase in transportation volumes, which accounted for an additional $2 million increase, offset by lower average isomerization fees, which accounted for a $6 million decrease.
Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022
.
Gross operating margin from butane isomerization and related operations increased a net $8 million period-to-period primarily due to lower utility and other operating costs, which accounted for a $15 million increase, and a 16 MBPD increase in transportation volumes, which accounted for an additional $3 million increase, partially offset by lower by-product sales, which accounted for a $10 million decrease.
Octane enhancement and related plant operations
Third Quarter of 2023 Compared to Third Quarter of 2022
.
Gross operating margin from our octane enhancement and related plant operations for the third quarter of 2023 increased $60 million when compared to the third quarter of 2022 primarily due to higher average sales margins, which accounted for a $35 million increase, higher sales volumes, which accounted for a $16 million increase, and lower utility and other operating costs, which accounted for an additional $8 million increase.
Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022
.
Gross operating margin from our octane enhancement and related plant operations during the nine months ended September 30, 2023 increased $33 million when compared to the nine months ended September 30, 2022 primarily due to higher average sales margins, which accounted for a $24 million increase, and lower utility and other operating costs, which accounted for an additional $7 million increase.
Refined products pipelines and related activities
Third Quarter of 2023 Compared to Third Quarter of 2022
.
Gross operating margin from refined products pipelines and related activities for the third quarter of 2023 increased $26 million when compared to the third quarter of 2022.
Gross operating margin from our refined products marketing activities increased a net $13 million quarter-to-quarter primarily due to higher average sales margins, which accounted for a $22 million increase, partially offset by lower sales volumes, which accounted for an $11 million decrease.
Gross operating margin from our refined products terminal in Beaumont, Texas increased $5 million quarter-to-quarter primarily due to higher storage and other fee revenues. Refined product marine terminal volumes at Beaumont increased 157 MBPD quarter-to-quarter.
Gross operating margin from our TE Products Pipeline System increased $3 million quarter-to-quarter primarily due to higher average transportation and related fees. Overall, transportation volumes on our TE Products Pipeline System increased 26 MBPD quarter-to-quarter.
Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022
.
Gross operating margin from refined products pipelines and related activities for the nine months ended September 30, 2023 increased $67 million when compared to the nine months ended September 30, 2022.
Gross operating margin from our refined products marketing activities increased $64 million period-to-period primarily due to higher average sales margins.
Gross operating margin from our refined products terminal in Beaumont, Texas increased $16 million
period-to-period
primarily due to higher storage and other fee revenues. Refined product marine terminal volumes at Beaumont increased 118 MBPD
period-to-period.
Gross operating margin from our TE Products Pipeline System decreased $20 million period-to-period primarily due to higher operating costs. Overall, transportation volumes on our TE Products Pipeline System increased 34 MBPD period-to-period.
Ethylene exports and related activities
Third Quarter of 2023 Compared to Third Quarter of 2022
. Gross operating margin from ethylene exports and related activities
during the third quarter of 2023 was flat when compared to the third quarter of 2022. On a combined basis, gross operating margin from our ethylene pipelines, storage and related marketing activities increased $2 million quarter-to-quarter primarily due to a combined 30 MBPD (net to our interest) increase in transportation volumes. Gross operating margin from our ethylene export terminal decreased a net $2 million quarter-to-quarter primarily due to lower average loading fees, which accounted for a $4 million decrease, and higher operating costs, which accounted for an additional $3 million decrease, partially offset by a 6 MBPD (net to our interest) increase in ethylene export volumes, which accounted for a $5 million increase.
Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022
.
Gross operating margin from ethylene exports and related activities during the nine months ended September 30, 2023 increased a net $1 million when compared to the nine months ended September 30, 2022. On a combined basis, gross operating margin from our ethylene pipelines, storage and related marketing activities increased $7 million period-to-period primarily due to a combined 21 MBPD (net to our interest) increase in transportation volumes. Gross operating margin from our ethylene export terminal decreased a net $6 million period-to-period primarily due to lower average loading fees, which accounted for a $7 million decrease, and higher operating costs, which accounted for an additional $2 million decrease, partially offset by a 1 MBPD (net to our interest) increase in ethylene export volumes, which accounted for a $3 million increase.
Marine transportation and other services
Third Quarter of 2023 Compared to Third Quarter of 2022
.
Gross operating margin from marine transportation and other services increased a net $4 million quarter-to-quarter primarily due to higher average fees, which accounted for a $7 million increase, partially offset by higher operating costs, which accounted for a $3 million decrease.
Nine Months Ended September 30, 2023 Compared to Nine Months Ended September 30, 2022
.
Gross operating margin from marine transportation and other services increased a net $15 million period-to-period primarily due to higher average fees, which accounted for a $16 million increase, and higher fleet utilization rates, which accounted for an additional $7 million increase, partially offset by higher operating costs, which accounted for a $9 million decrease.
Liquidity and Capital Resources
Based on current market conditions (as of the filing date of this quarterly report), we believe that the Partnership and its consolidated businesses will have sufficient liquidity, cash flow from operations and access to capital markets to fund their capital investments and working capital needs for the reasonably foreseeable future. At September 30, 2023, we had $3.8 billion of consolidated liquidity. This amount was comprised of $3.6 billion of available borrowing capacity under EPO’s revolving credit facilities, which is the net of $4.2 billion of total borrowing capacity under EPO’s revolving credit facilities and $620 million outstanding under EPO’s commercial paper program, and $171 million of unrestricted cash on hand.
We may issue debt and equity securities to assist us in meeting our future funding and liquidity requirements, including those related to capital investments. We have a universal shelf registration statement on file with the SEC which allows the Partnership and EPO to issue an unlimited amount of equity and debt securities, respectively.
Enterprise Declares Cash Distribution for Third Quarter of 2023
On October 5, 2023, we announced that the Board declared a quarterly cash distribution of $0.50 per common unit, or $2.00 per unit on an annualized basis, to be paid to the Partnership’s common unitholders with respect to the third quarter of 2023. The quarterly distribution is payable on November 14, 2023 to unitholders of record as of the close of business on October 31, 2023. The total amount to be paid is $1.1 billion, which includes $10 million for distribution equivalent rights on phantom unit awards.
The payment of quarterly cash distributions is subject to management’s evaluation of our financial condition, results of operations and cash flows in connection with such payments and Board approval. Management will evaluate any future increases in cash distributions on a quarterly basis.
Consolidated Debt
At September 30, 2023, the average maturity of EPO’s consolidated debt obligations was approximately 19.3 years. The following table presents the scheduled maturities of principal amounts of EPO’s consolidated debt obligations at September 30, 2023 for the years indicated (dollars in millions):
|
|
Scheduled Maturities of Debt
|
|||||||||||||||||||||||||||
|
|
Total
|
Remainder
of 2023
|
2024
|
2025
|
2026
|
2027
|
Thereafter
|
|||||||||||||||||||||
|
Commercial Paper Notes
|
$
|
620
|
$
|
620
|
$
|
–
|
$
|
–
|
$
|
–
|
$
|
–
|
$
|
–
|
||||||||||||||
|
Senior Notes
|
26,275
|
–
|
850
|
1,150
|
1,625
|
575
|
22,075
|
|||||||||||||||||||||
|
Junior Subordinated Notes
|
2,296
|
–
|
–
|
–
|
–
|
–
|
2,296
|
|||||||||||||||||||||
|
Total
|
$
|
29,191
|
$
|
620
|
$
|
850
|
$
|
1,150
|
$
|
1,625
|
$
|
575
|
$
|
24,371
|
||||||||||||||
In January 2023, EPO issued $1.75 billion aggregate principal amount of senior notes comprised of (i) $750 million principal amount of senior notes due January 2026 (“Senior Notes FFF”) and (ii) $1.0 billion principal amount of senior notes due January 2033 (“Senior Notes GGG”). Senior Notes FFF were issued at 99.893% of their principal amount and have a fixed-rate interest rate of 5.05% per year. Senior Notes GGG were issued at 99.803% of their principal amount and have a fixed-rate interest rate of 5.35% per year. Net proceeds from this offering were used by EPO for general company purposes, including for growth capital investments, and the repayment of debt (including the repayment of all of our $1.25 billion principal amount of 3.35% Senior Notes HH at their maturity in March 2023 and amounts outstanding under our commercial paper program).
In March 2023, EPO entered into a new 364-Day Revolving Credit Agreement (the “March 2023 $1.5 Billion 364-Day Revolving Credit Agreement”) that replaced its September 2022 364-Day Revolving Credit Agreement. The March 2023 $1.5 Billion 364-Day Revolving Credit Agreement matures in March 2024. EPO’s borrowing capacity was unchanged from the prior 364-day revolving credit agreement. As of September 30, 2023, there are no principal amounts outstanding under this new revolving credit agreement.
In March 2023, EPO entered into a new revolving credit agreement that matures in March 2028 (the “March 2023 $2.7 Billion Multi-Year Revolving Credit Agreement”). The March 2023 $2.7 Billion Multi-Year Revolving Credit Agreement replaced EPO’s prior multi-year revolving credit agreement that was scheduled to mature in September 2026. We proposed to reduce
EPO’s borrowing capacity from $3.0 billion under the prior multi-year revolving credit agreement to $2.7 billion under the March 2023 $2.7 Billion Multi-Year Revolving Credit Agreement. Under the new agreement, EPO retains the right to increase its borrowing capacity by up to $500 million to $3.2 billion, provided certain conditions for the election are met. As of September 30, 2023, there are no principal amounts outstanding under this new revolving credit agreement.
For additional information regarding our consolidated debt obligations, see Note 7 of the Notes to Unaudited Condensed Consolidated Financial Statements included under Part I, Item 1 of this quarterly report.
Credit Ratings
As of November
9
, 2023, the investment-grade credit ratings of EPO’s long-term senior unsecured debt securities were A- from Standard and Poor’s, Baa1 from Moody’s and A- from Fitch Ratings. In addition, the credit ratings of EPO’s short-term senior unsecured debt securities were A-2 from Standard and Poor’s, P-2 from Moody’s and F-2 from Fitch Ratings. EPO’s credit ratings reflect only the view of a rating agency and should not be interpreted as a recommendation to buy, sell or hold any of our securities. A credit rating can be revised upward or downward or withdrawn at any time by a rating agency, if it determines that circumstances warrant such a change. A credit rating from one rating agency should be evaluated independently of credit ratings from other rating agencies.
Common Unit Repurchases Under 2019 Buyback Program
In January 2019, we announced that the Board had approved a $2.0 billion multi-year unit buyback program (the “2019 Buyback Program”), which provides the Partnership with an additional method to return capital to investors. The Partnership elected not to repurchase common units during the three months ended September 30, 2023. During the nine months ended September 30, 2023, the Partnership repurchased
3,592,710
common units through open market purchases. The total cost of these repurchases, including commissions and fees, was $92
million.
As of September 30, 2023, the remaining available capacity under the 2019 Buyback Program was $1.2 billion.
Cash Flow Statement Highlights
The following table summarizes our consolidated cash flows from operating, investing and financing activities for the periods indicated (dollars in millions).
|
|
For the Nine Months
Ended September 30,
|
|||||||
|
|
2023
|
2022
|
||||||
|
Net cash flows provided by operating activities
|
$
|
5,203
|
$
|
5,314
|
||||
|
Cash used in investing activities
|
2,220
|
4,309
|
||||||
|
Cash used in financing activities
|
2,875
|
3,715
|
||||||
Net cash flows provided by operating activities are largely dependent on earnings from our consolidated business activities. Changes in energy commodity prices may impact the demand for natural gas, NGLs, crude oil, petrochemicals and refined products, which could impact sales of our products and the demand for our midstream services. Changes in demand for our products and services may be caused by other factors, including prevailing economic conditions, reduced demand by consumers for the end products made with hydrocarbon products, increased competition, public health emergencies, adverse weather conditions and government regulations affecting prices and production levels. We may also incur credit and price risk to the extent customers do not fulfill their contractual obligations to us in connection with our marketing activities and long-term take-or-pay and dedication agreements. For a more complete discussion of these and other risk factors pertinent to our business, see “
Risk Factors
” included under Part I, Item 1A of the 2022 Form 10-K.
For additional information regarding our cash flow amounts, please refer to the Unaudited Condensed Statements of Consolidated Cash Flows included under Part I, Item 1 of this quarterly report.
The following information highlights significant quarter-to-quarter fluctuations in our consolidated cash flow amounts:
Operating activities
Net cash flows provided by operating activities for the
nine months ended September 30,
2023 decreased $111 million when compared to the
nine months ended September 30,
2022 primarily due to:
| • |
an $88 million period-to-period decrease resulting from lower partnership earnings (determined by adjusting our $108 million period-to-period decrease in net income for changes in the non-cash items identified on our Unaudited Condensed Statements of Consolidated Cash Flows); and
|
| • |
a $24
mill
ion period-to-period decrease from changes in operating accounts primarily due to the use of working capital employed in our marketing activities, which includes the impact of (i) fluctuations in commodity prices, (ii) timing of our inventory purchase and sale strategies, and (iii) changes in margin deposit requirements associated with our commodity derivative instruments.
|
For information regarding significant period-to-period changes in our consolidated net income and underlying segment results, see “
Income Statement Highlights
” and “
Business Segment Highlights
” within this Part I, Item 2.
Investing activities
Cash used in investing activities during
the nine months ended September 30,
2023 decreased a net $2.1 billion when compared to the nine months ended September 30,
2022 primarily due to:
| • |
a net $
3.2
billion cash outflow in February 2022 in connection with the acquisition of our Midland Basin System; partially offset by
|
| • |
a $1.1 billion period-to-period increase in investments for property, plant and equipment (see “
Capital Investments
” within this Part I, Item 2 for additional information).
|
Financing activities
Cash used in financing activities during the
nine months ended September 30,
2023 decreased a net $840 million when compared to the nine months ended September 30,
2022 primarily due to:
| • |
a net cash inflow of $627 million related to debt transactions that occurred during the nine months ended September 30, 2023 compared to a net cash outflow of $347
million related to debt transactions that occurred during the nine months ended September 30, 2022.
During the nine months ended September 30, 2023, we issued $1.75 billion aggregate principal amount of senior notes and issued a net $126 million under EPO’s commercial paper program, partially offset by the repayment of $1.25 billion principal amount of senior notes. During the nine months ended September 30, 2022, we repaid $
1.75
billion aggregate principal amount of senior and junior subordinated notes, partially offset by net issuances of $1.4 billion under EPO’s commercial paper program; partially offset by
|
| • |
a $154 million period-to-period increase in cash distributions paid to common unitholders primarily attributable to increases in the quarterly cash distribution rate per unit.
|
Non-GAAP Cash Flow Measures
Distributable Cash Flow
Our partnership agreement requires us to make quarterly distributions to our common unitholders of all available cash, after any cash reserves established by Enterprise GP in its sole discretion. Cash reserves include those for the proper conduct of our business, including those for capital investments, debt service, working capital, operating expenses, common unit repurchases, commitments and contingencies and other amounts. The retention of cash allows us to reinvest in our growth and reduce our future reliance on the equity and debt capital markets.
We measure available cash by reference to distributable cash flow (“DCF”), which is a non-GAAP cash flow measure. DCF is an important financial measure for our common unitholders since it serves as an indicator of our success in providing a cash return on investment. Specifically, this financial measure indicates to investors whether or not we are generating cash flows at a level that can sustain our declared quarterly cash distributions. DCF is also a quantitative standard used by the investment community with respect to publicly traded partnerships since 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 unitholder. Our management compares the DCF we generate to the cash distributions we expect to pay our common unitholders. Using this metric, management computes our distribution coverage ratio. Our calculation of DCF may or may not be comparable to similarly titled measures used by other companies.
Based on the level of available cash each quarter, management proposes a quarterly cash distribution rate to the Board, which has sole authority in approving such matters. Enterprise GP has a non-economic ownership interest in the Partnership and is not entitled to receive any cash distributions from it based on incentive distribution rights or other equity interests.
Our use of DCF for the limited purposes described above and in this quarterly report is not a substitute for net cash flows provided by operating activities, which is the most comparable GAAP measure to DCF. For a discussion of net cash flows provided by operating activities, see “
Cash Flow Statement Highlights
” within this Part I, Item 2.
The following table summarizes our calculation of DCF for the periods indicated (dollars in millions):
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Net income attributable to common unitholders (GAAP) (1)
|
$
|
1,318
|
$
|
1,360
|
$
|
3,961
|
$
|
4,067
|
||||||||
|
Adjustments to net income attributable to common unitholders to derive DCF (addition or subtraction indicated by sign):
|
||||||||||||||||
|
Depreciation, amortization and accretion expenses
|
599
|
558
|
1,742
|
1,675
|
||||||||||||
|
Cash distributions received from unconsolidated affiliates (2)
|
120
|
132
|
367
|
411
|
||||||||||||
|
Equity in income of unconsolidated affiliates
|
(122
|
)
|
(111
|
)
|
(347
|
)
|
(335
|
)
|
||||||||
|
Asset impairment charges
|
12
|
29
|
28
|
48
|
||||||||||||
|
Change in fair market value of derivative instruments
|
38
|
(48
|
)
|
48
|
46
|
|||||||||||
|
Deferred income tax expense
|
13
|
8
|
5
|
24
|
||||||||||||
|
Sustaining capital expenditures (3)
|
(99
|
)
|
(77
|
)
|
(284
|
)
|
(234
|
)
|
||||||||
|
Other, net
|
(11
|
)
|
11
|
(6
|
)
|
1
|
||||||||||
|
Operational DCF (4)
|
$
|
1,868
|
$
|
1,862
|
$
|
5,514
|
$
|
5,703
|
||||||||
|
Proceeds from asset sales and other matters
|
1
|
6
|
7
|
20
|
||||||||||||
|
Monetization of interest rate derivative instruments accounted for as cash flow hedges
|
‒
|
‒
|
21
|
‒
|
||||||||||||
|
DCF (non-GAAP)
|
$
|
1,869
|
$
|
1,868
|
$
|
5,542
|
$
|
5,723
|
||||||||
|
|
||||||||||||||||
|
Cash distributions paid to common unitholders with respect to period, including distribution equivalent rights on phantom unit awards
|
$
|
1,096
|
$
|
1,042
|
$
|
3,267
|
$
|
3,109
|
||||||||
|
|
||||||||||||||||
|
Cash distribution per common unit declared by Enterprise GP with respect to period (5)
|
$
|
0.5000
|
$
|
0.4750
|
$
|
1.4900
|
$
|
1.4150
|
||||||||
|
|
||||||||||||||||
|
Total DCF retained by the Partnership with respect to period (6)
|
$
|
773
|
$
|
826
|
$
|
2,275
|
$
|
2,614
|
||||||||
|
|
||||||||||||||||
|
Distribution coverage ratio (7)
|
1.7
|
x
|
1.8
|
x
|
1.7
|
x
|
1.8
|
x
|
||||||||
|
(1)
|
For a discussion of the primary drivers of changes in our comparative income statement amounts, see “
Income Statement Highlights
” within this Part I, Item 2.
|
|
(2)
|
Reflects aggregate distributions received from unconsolidated affiliates attributable to both earnings and the return of capital.
|
|
(3)
|
Sustaining capital expenditures include cash payments and accruals applicable to the period.
|
|
(4)
|
Represents DCF before proceeds from asset sales and the monetization of interest rate derivative instruments accounted for as cash flow hedges.
|
|
(5)
|
See Note 8 of the Notes to Unaudited Condensed Consolidated Financial Statements included under Part I, Item 1 of this quarterly report for information regarding our cash distributions declared with respect to the periods indicated.
|
|
(6)
|
Cash retained by the Partnership may be used for capital investments, debt service, working capital, operating expenses, common unit repurchases, commitments and contingencies and other amounts. The retention of cash reduces our reliance on the capital markets.
|
|
(7)
|
Distribution coverage ratio is determined by dividing DCF by total cash distributions paid to common unitholders and in connection with distribution equivalent rights with respect to the period.
|
The following table presents a reconciliation of net cash flows provided by operating activities to DCF for the periods indicated (dollars in millions):
|
|
For the Three Months
Ended September 30,
|
For the Nine Months
Ended September 30,
|
||||||||||||||
|
|
2023
|
2022
|
2023
|
2022
|
||||||||||||
|
Net cash flows provided by operating activities (GAAP)
|
$
|
1,718
|
$
|
1,050
|
$
|
5,203
|
$
|
5,314
|
||||||||
|
Adjustments to reconcile net cash flows provided by operating activities to DCF (addition or subtraction indicated by sign):
|
||||||||||||||||
|
Net effect of changes in operating accounts
|
303
|
900
|
706
|
682
|
||||||||||||
|
Sustaining capital expenditures
|
(99
|
)
|
(77
|
)
|
(284
|
)
|
(234
|
)
|
||||||||
|
Distributions received from unconsolidated affiliates attributable to the return of capital
|
7
|
27
|
37
|
82
|
||||||||||||
|
Proceeds from asset sales and other matters
|
1
|
6
|
7
|
20
|
||||||||||||
|
Net income attributable to noncontrolling interests
|
(31
|
)
|
(31
|
)
|
(91
|
)
|
(93
|
)
|
||||||||
|
Monetization of interest rate derivative instruments accounted for as cash flow hedges
|
‒
|
‒
|
21
|
‒
|
||||||||||||
|
Other, net
|
(30
|
)
|
(7
|
)
|
(57
|
)
|
(48
|
)
|
||||||||
|
DCF (non-GAAP)
|
$
|
1,869
|
$
|
1,868
|
$
|
5,542
|
$
|
5,723
|
||||||||
Capital Investments
Through the third quarter of 2023, we placed into service the 400 MMcf/d expansion of our Acadian Gas System, PDH 2 facility, Frac 12 and our Poseidon natural gas processing plant. In October 2023, we placed our Mentone 2 natural gas processing plant into service. We have approximately $6.8
billion of growth capital projects scheduled to be completed by the first half of 2026, including the following major projects (including their respective scheduled completion dates):
| • |
natural gas gathering expansion projects in the Delaware and Midland Basins (2023 and 2024);
|
| • |
our Texas Western Products System, which is comprised of two wholly owned subsidiaries that will lease capacity on our Chaparral Pipeline and a portion of our Seminole and Mid-America Pipeline System’s Rocky Mountain segment, will offer westbound transportation service of refined products from the U.S. Gulf Coast to markets in West Texas, New Mexico, Colorado and Utah (fourth quarter of 2023 through second quarter of 2024);
|
| • |
our Mentone 3 natural gas processing plant in the Delaware Basin (first quarter of 2024);
|
| • |
our Leonidas natural gas processing plant in the Midland Basin (first quarter of 2024);
|
| • |
the expansion of our LPG and PGP export capacity at EHT (first half of 2025);
|
| • |
the Bahia NGL Pipeline (first half of 2025);
|
| • |
an NGL fractionator (“Frac 14”) and an associated DIB unit in Chambers County, Texas (second half of 2025);
|
| • |
our Mentone 4 natural gas processing plant in the Delaware Basin (second half of 2025);
|
| • |
an eighth natural gas processing plant (“Orion”) in the Midland Basin (second half of 2025);
|
| • |
an expansion of our Morgan’s Point terminal to increase ethylene export capacity (second half of 2024 and second half of 2025); and
|
| • |
an Ethane and Propane Export Terminal located in Orange County, Texas (second half of 2025 and first half of 2026).
|
Based on information currently available, we expect our total capital investments for 2023, net of contributions from noncontrolling interests, to approximate $3.4 billion, which reflects growth capital investments of $3.0
billion and sustaining capital expenditures of $400
million. 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 state and federal permitting, mitigation and related requirements. We received a favorable Record of Decision from the Department of Transportation’s Maritime Administration for SPOT during the fourth quarter of 2022; however, we can give no assurance as to when or whether the project will ultimately be authorized to begin construction or operation.
Our forecast of capital investments is dependent upon our ability to generate the required funds from either operating cash flows or other means, including borrowings under debt agreements, the issuance of additional equity and debt securities, and potential divestitures. We may revise our forecast of capital investments due to factors beyond our control, such as adverse economic conditions, weather-related issues and changes in supplier prices resulting from raw material or labor shortages, supply chain disruptions or inflation. Furthermore, our forecast of capital investments may change over time based on future decisions by management, which may include changing the scope or timing of projects or cancelling projects altogether. Our success in raising capital, having the ability to increase revenues commensurate with cost increases and our ability to partner with other companies to share project costs and risks, continue to be significant factors in determining how much capital we can invest. We believe our access to capital resources is sufficient to meet the demands of our current and future growth needs and, although we currently expect to make the forecast capital investments noted above, we may revise our plans in response to changes in economic and capital market conditions.
The following table summarizes our capital investments for the periods indicated (dollars in millions):
|
|
For the Nine Months
Ended September 30,
|
|||||||
|
|
2023
|
2022
|
||||||
|
Capital investments for property, plant and equipment: (1)
|
||||||||
|
Growth capital projects (2)
|
$
|
1,945
|
$
|
960
|
||||
|
Sustaining capital projects (3)
|
309
|
243
|
||||||
|
Total
|
$
|
2,254
|
$
|
1,203
|
||||
|
Cash used for business combinations, net (4)
|
$
|
–
|
$
|
3,204
|
||||
|
Investments in unconsolidated affiliates
|
$
|
2
|
$
|
1
|
||||
|
(1)
|
Growth and sustaining capital amounts presented in the table above are presented on a cash basis. In total, these amounts represent “Capital expenditures” as presented on our Unaudited Condensed Statements of Consolidated Cash Flows.
|
|
(2)
|
Growth capital projects either (a) result in new sources of cash flow due to enhancements of or additions to existing assets (e.g., additional revenue streams, cost savings resulting from debottlenecking of a facility, etc.) or (b) expand our asset base through construction of new facilities that will generate additional revenue streams and cash flows.
|
|
(3)
|
Sustaining capital projects are capital expenditures (as defined by GAAP) resulting from improvements to existing assets. Such expenditures serve to maintain existing operations but do not generate additional revenues or result in significant cost savings. Sustaining capital expenditures include the costs of major maintenance activities at our reaction-based plants, which are accounted for using the deferral method.
|
|
(4)
|
Amount for the nine months ended September 30, 2022 represents net cash used for the acquisition of our Midland Basin System, which closed on February 17, 2022.
|
Comparison of Nine Months Ended September 30, 2023 with Nine Months Ended September 30, 2022
In total, investments in growth capital projects increased a net $985 million period-to-period primarily due to the following:
|
•
|
higher investments in natural gas processing and gathering projects in the Permian Basin (e.g., construction of four natural gas processing plants and related gathering systems), which accounted for a $632 million increase;
|
|
•
|
higher investments in ethane, LPG and ethylene export expansion projects at our Gulf Coast terminals, which accounted for a $175 million increase;
|
|
•
|
higher investments in our Texas Western Products System, which accounted for a $164 million increase; and
|
|
•
|
higher investments in Frac 12 (placed into service in July 2023) at our Chambers County complex, which accounted for an additional $81 million increase; partially offset by
|
|
•
|
lower investments in PDH 2 (placed into service in July 2023) at our Chambers County complex, which accounted for an $87 million decrease.
|
Investments attributable to sustaining capital projects increased $66 million period-to-period primarily due to fluctuations in timing and costs of pipeline integrity and similar projects.
Critical Accounting Policies and Estimates
A discussion of our critical accounting policies and estimates is included in our 2022 Form 10-K. The following types of estimates, in our opinion, are subjective in nature, require the exercise of professional judgment and involve complex analysis:
| • |
valuation of assets and liabilities acquired in a business combination;
|
| • |
depreciation methods and estimated useful lives of property, plant and equipment;
|
| • |
measuring recoverability of long-lived assets and fair value of equity method investments;
|
| • |
amortization methods of customer relationships and contract-based intangible assets;
|
| • |
methods we employ to measure the fair value of goodwill and related assets; and
|
| • |
the use of estimates for revenue and expenses.
|
When used to prepare our Unaudited Condensed Consolidated Financial Statements, the foregoing types of estimates are based on our current knowledge and understanding of the underlying facts and circumstances. Such estimates may be revised as a result of changes in the underlying facts and circumstances. Subsequent changes in these estimates may have a significant impact on our consolidated financial position, results of operations and cash flows.
Other Matters
Parent-Subsidiary Guarantor Relationship
The Partnership (the “Parent Guarantor”) has guaranteed the payment of principal and interest on the consolidated debt obligations of EPO (the “Subsidiary Issuer”), with the exception of the remaining debt obligations of TEPPCO Partners, L.P. (collectively, the “Guaranteed Debt”). If EPO were to default on any of its Guaranteed Debt, the Partnership would be responsible for full and unconditional repayment of such obligations. At September 30, 2023, the total amount of Guaranteed Debt was $29.4 billion, which was comprised of $26.3 billion of EPO’s senior notes, $2.3 billion of EPO’s junior subordinated notes, $620 million of short-term commercial paper notes and $237 million of related accrued interest.
The Partnership’s guarantees of EPO’s senior note obligations, commercial paper notes and borrowings under bank credit facilities represent unsecured and unsubordinated obligations of the Partnership that rank equal in right of payment to all other existing or future unsecured and unsubordinated indebtedness of the Partnership. In addition, these guarantees effectively rank junior in right of payment to any existing or future indebtedness of the Partnership that is secured and unsubordinated, to the extent of the assets securing such indebtedness.
The Partnership’s guarantees of EPO’s junior subordinated notes represent unsecured and subordinated obligations of the Partnership that rank equal in right of payment to all other existing or future subordinated indebtedness of the Partnership and senior in right of payment to all existing or future equity securities of the Partnership. The Partnership’s guarantees of EPO’s junior subordinated notes effectively rank junior in right of payment to (i) any existing or future indebtedness of the Partnership that is secured, to the extent of the assets securing such indebtedness and (ii) all other existing or future unsecured and unsubordinated indebtedness of the Partnership.
The Partnership may be released from its guarantee obligations only in connection with EPO’s exercise of its legal or covenant defeasance options as described in the underlying agreements.
Selected Financial Information of Obligor Group
The following tables present summarized financial information of the Partnership (as Parent Guarantor) and EPO (as Subsidiary Issuer) on a combined basis (collectively, the “Obligor Group”), after the elimination of intercompany balances and transactions among the Obligor Group.
In accordance with Rule 13.01 of Regulation S-X, the summarized financial information of the Obligor Group excludes the Obligor Group’s equity in income and investments in the consolidated subsidiaries of EPO that are not party to the guarantee obligations (the “Non-Obligor Subsidiaries”). The total carrying value of the Obligor Group’s investments in the Non-Obligor Subsidiaries was $47.5 billion at September 30, 2023. The Obligor Group’s equity in the earnings of the Non-Obligor Subsidiaries for the nine months ended September 30, 2023 was $4.3 billion. Although the net assets and earnings of the Non-Obligor Subsidiaries are not directly available to the holders of the Guaranteed Debt to satisfy the repayment of such obligations, there are no significant restrictions on the ability of the Non-Obligor Subsidiaries to pay distributions or make loans to EPO or the Partnership. EPO exercises control over the Non-Obligor Subsidiaries. We continue to believe that the unaudited condensed consolidated financial statements of the Partnership presented under Part I, Item 1 of this quarterly report provide a more appropriate view of our credit standing. Our investment grade credit ratings are based on the Partnership’s consolidated financial statements and not the Obligor Group’s financial information presented below.
The following table presents summarized balance sheet information for the combined Obligor Group at the dates indicated (dollars in millions):
|
Selected asset information:
|
September 30,
2023
|
December 31,
2022
|
||||||
|
Current receivables from Non-Obligor Subsidiaries
|
$
|
1,433
|
$
|
1,012
|
||||
|
Other current assets
|
4,985
|
4,949
|
||||||
|
Long-term receivables from Non-Obligor Subsidiaries
|
187
|
187
|
||||||
|
Other noncurrent assets, excluding investments in Non-Obligor Subsidiaries
of $47.5 billion at September 30, 2023 and December 31, 2022
|
9,177
|
9,130
|
||||||
|
Selected liability information:
|
||||||||
|
Current portion of Guaranteed Debt, including interest of $237 million at September 30, 2023 and
$426 million at December 31, 2022
|
$
|
1,706
|
$
|
2,171
|
||||
|
Current payables to Non-Obligor Subsidiaries
|
1,443
|
1,899
|
||||||
|
Other current liabilities
|
3,879
|
4,121
|
||||||
|
Noncurrent portion of Guaranteed Debt, principal only
|
27,707
|
26,807
|
||||||
|
Noncurrent payables to Non-Obligor Subsidiaries
|
57
|
38
|
||||||
|
Other noncurrent liabilities
|
96
|
98
|
||||||
|
Mezzanine equity of Obligor Group:
|
||||||||
|
Preferred units
|
$
|
49
|
$
|
49
|
||||
The following table presents summarized income statement information for the combined Obligor Group for the periods indicated (dollars in millions):
|
For the Nine
Months Ended
September 30,
2023
|
For the Twelve
Months Ended
December 31,
2022
|
|||||||
|
Revenues from Non-Obligor Subsidiaries
|
$
|
12,047
|
$
|
14,145
|
||||
|
Revenues from other sources
|
10,467
|
27,312
|
||||||
|
Operating income of Obligor Group
|
671
|
836
|
||||||
|
Net income (loss) of Obligor Group excluding equity in earnings of Non-Obligor Subsidiaries of
$4.3 billion for the nine months ended September 30, 2023 and
$5.9 billion for the twelve months ended December 31, 2022
|
(307
|
)
|
(450
|
)
|
||||
Related Party Transactions
For information regarding our related party transactions, see Note 14 of the Notes to Unaudited Condensed Consolidated Financial Statements included under Part I, Item 1 of this quarterly report.
ABOUT MARKET RISK.
General
In the normal course of our business operations, we are exposed to certain risks, including changes in interest rates and commodity prices. In order to manage risks associated with assets, liabilities and certain anticipated future transactions, we use derivative instruments such as futures, forward contracts, swaps and other instruments with similar characteristics. Substantially all of our derivatives are used for non-trading activities.
We assess the risk associated with each of our derivative instrument portfolios using a sensitivity analysis model. This approach measures the change in fair value of the derivative instrument portfolio based on a hypothetical 10% change in the underlying interest rates or quoted market prices on a particular day. In addition to these variables, the fair value of each portfolio is influenced by changes in the notional amounts of the instruments outstanding and the discount rates used to determine the present values. The sensitivity analysis approach does not reflect the impact that the same hypothetical price movement would have on the hedged exposures to which they relate. Therefore, the impact on the fair value of a derivative instrument resulting from a change in interest rates or quoted market prices (as applicable) would normally be offset by a corresponding gain or loss on the hedged debt instrument, inventory value or forecasted transaction assuming:
| • |
the derivative instrument functions effectively as a hedge of the underlying risk;
|
| • |
the derivative instrument is not closed out in advance of its expected term; and
|
| • |
the hedged forecasted transaction occurs within the expected time period.
|
We routinely review the effectiveness of our derivative instrument portfolios in light of current market conditions. Accordingly, the nature and volume of our derivative instruments may change depending on the specific exposure being managed.
Commodity Hedging Activities
The price of energy commodities such as natural gas, NGLs, crude oil, petrochemicals and refined products and power are subject to fluctuations in response to changes in supply and demand, market conditions and a variety of additional factors that are beyond our control. In order to manage such price risks, we enter into commodity derivative instruments such as physical forward contracts, futures contracts, fixed-for-float swaps and basis swaps.
At September 30, 2023, our predominant commodity hedging strategies consisted of (i) hedging anticipated future purchases and sales of commodity products associated with transportation, storage and blending activities, (ii) hedging natural gas processing margins, (iii) hedging the fair value of commodity products held in inventory and (iv) hedging anticipated future purchases of power for certain operations in Southeast Texas. For a summary of our portfolio of commodity derivative instruments outstanding, see Note 13 of the Notes to Unaudited Condensed Consolidated Financial Statements included under Part I, Item 1 of this quarterly report.
Sensitivity Analysis
The following tables show the effect of hypothetical price movements on the estimated fair values of our principal commodity derivative instrument portfolios at the dates indicated (dollars in millions).
The fair value information presented in the sensitivity analysis tables excludes the impact of applying Chicago Mercantile Exchange (“CME”) Rule 814, which deems that financial instruments cleared by the CME are settled daily in connection with variation margin payments. As a result of this exchange rule, CME-related derivatives are considered to have no fair value at the balance sheet date for financial reporting purposes; however, the derivatives remain outstanding and subject to future commodity price fluctuations until they are settled in accordance with their contractual terms. Derivative transactions cleared on exchanges other than the CME (e.g., the Intercontinental Exchange or ICE) continue to be reported on a gross basis.
Natural gas marketing portfolio
|
|
|
Portfolio Fair Value at
|
|||||||||||
|
Scenario
|
Resulting
Classification
|
December 31,
2022
|
September 30,
2023
|
October 16,
2023
|
|||||||||
|
Fair value assuming no change in underlying commodity prices
|
Asset (Liability)
|
$
|
90
|
$
|
2
|
$
|
3
|
||||||
|
Fair value assuming 10% increase in underlying commodity prices
|
Asset (Liability)
|
97
|
−
|
1
|
|||||||||
|
Fair value assuming 10% decrease in underlying commodity prices
|
Asset (Liability)
|
83
|
5
|
6
|
|||||||||
NGL and refined products marketing, natural gas processing and octane enhancement portfolio
|
|
|
Portfolio Fair Value at
|
|||||||||||
|
Scenario
|
Resulting
Classification
|
December 31,
2022
|
September 30,
2023
|
October 16,
2023
|
|||||||||
|
Fair value assuming no change in underlying commodity prices
|
Asset (Liability)
|
$
|
18
|
$
|
(22
|
)
|
$
|
(16
|
)
|
||||
|
Fair value assuming 10% increase in underlying commodity prices
|
Asset (Liability)
|
(29
|
)
|
(54
|
)
|
(40
|
)
|
||||||
|
Fair value assuming 10% decrease in underlying commodity prices
|
Asset (Liability)
|
64
|
9
|
8
|
|||||||||
Crude oil marketing portfolio
|
|
|
Portfolio Fair Value at
|
|||||||||||
|
Scenario
|
Resulting
Classification
|
December 31,
2022
|
September 30,
2023
|
October 16,
2023
|
|||||||||
|
Fair value assuming no change in underlying commodity prices
|
Asset (Liability)
|
$
|
53
|
$
|
(72
|
)
|
$
|
(55
|
)
|
||||
|
Fair value assuming 10% increase in underlying commodity prices
|
Asset (Liability)
|
24
|
(173
|
)
|
(129
|
)
|
|||||||
|
Fair value assuming 10% decrease in underlying commodity prices
|
Asset (Liability)
|
81
|
30
|
20
|
|||||||||
Commercial energy derivative portfolio
|
|
|
Portfolio Fair Value at
|
|||||||||||
|
Scenario
|
Resulting
Classification
|
December 31,
2022
|
September 30,
2023
|
October 16,
2023
|
|||||||||
|
Fair value assuming no change in underlying commodity prices
|
Asset (Liability)
|
$
|
(38
|
)
|
$
|
(16
|
)
|
$
|
(17
|
)
|
|||
|
Fair value assuming 10% increase in underlying commodity prices
|
Asset (Liability)
|
(10
|
)
|
4
|
2
|
||||||||
|
Fair value assuming 10% decrease in underlying commodity prices
|
Asset (Liability)
|
(63
|
)
|
(36
|
)
|
(37
|
)
|
||||||
Interest Rate Hedging Activities
We may utilize interest rate swaps, forward-starting swaps, options to enter into forward-starting swaps (“swaptions”), and similar derivative instruments to manage our exposure to changes in interest rates charged on borrowings under certain consolidated debt agreements. This strategy may be used in controlling our overall cost of capital associated with such borrowings. As of the filing date of this quarterly report, we do not have any interest rate hedging instruments outstanding.
Disclosure Controls and Procedures
As of the end of the period covered by this quarterly report, our management carried out an evaluation, with the participation of (i) A. James Teague, Co-Chief Executive Officer of Enterprise GP and (ii) W. Randall Fowler, Co-Chief Executive Officer and Chief Financial Officer of Enterprise GP, of the effectiveness of our disclosure controls and procedures pursuant to Rule 13a-15 of the Securities Exchange Act of 1934. Based on this evaluation, as of the end of the period covered by this quarterly report, Messrs. Teague and Fowler concluded:
| (i) |
that our disclosure controls and procedures are designed to ensure that information required to be disclosed by us in the reports that we file or submit under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to our management, including our principal executive and financial officers, as appropriate to allow for timely decisions regarding required disclosures; and
|
| (ii) |
that our disclosure controls and procedures are effective.
|
Changes in Internal Control over Financial Reporting
There were no changes in our internal controls over financial reporting (as defined in Rule 13a-15(f) under the Securities Exchange Act of 1934) during the third quarter of 2023, that have materially affected, or are reasonably likely to materially affect, our internal controls over financial reporting.
Section 302 and 906 Certifications
The required certifications of Messrs. Teague and Fowler under Sections 302 and 906 of the Sarbanes-Oxley Act of 2002 are included as exhibits to this quarterly report (see Exhibits 31 and 32 under Part II, Item 6 of this quarterly report).
As part of our normal business activities, we may be named as defendants in litigation and legal proceedings, including those arising from regulatory and environmental matters. Although we are insured against various risks to the extent we believe it is prudent, there is no assurance that the nature and amount of such insurance will be adequate, in every case, to indemnify us against liabilities arising from future legal proceedings. We will vigorously defend the Partnership in litigation matters.
For additional information regarding our litigation matters, see Note 16 of the Notes to Unaudited Condensed Consolidated Financial Statements included under Part I, Item 1 of this quarterly report.
On occasion, we are assessed monetary penalties by governmental authorities related to administrative or judicial proceedings involving environmental matters. The following information summarizes matters where the eventual resolution of each of these matters may result in monetary sanctions in excess of $0.3 million. We do not expect that any expenditures related to the following matters will be material to our consolidated financial statements.
|
•
|
In June 2019, we received a Notice of Violation from the U.S. Environmental Protection Agency (“EPA”) in connection with regulatory requirements applicable to facilities that we operate near Baton Rouge, Louisiana.
|
|
•
|
In July 2021, we received a civil penalty demand from the U.S. Department of Justice and the State of Colorado regarding alleged violations of hydrocarbon leak detection and repair regulations applicable to our Meeker gas processing plant in Colorado.
|
|
•
|
In August 2022, we received a Notice of Violation from the U.S. EPA alleging that gasoline at two of our refined products terminals in Texas had exceeded certain Clean Air Act-related standards during two past regulatory control periods.
|
|
•
|
In August 2022, we received two Notices of Enforcement from the Texas Commission on Environmental Quality for alleged exceedances of air permit emission limits at our PDH 1 and iBDH facilities in Texas.
|
An investment in our securities involves certain risks. Security holders and potential investors in our securities should carefully consider the risks described under “
Risk Factors
” set forth in Part I, Item 1A of our 2022 Form 10-K, in addition to other information in such annual report and this quarterly report. The risk factors set forth in our 2022 Form 10-K are important factors that could cause our actual results to differ materially from those contained in any written or oral forward-looking statements made by us or on our behalf.
Recent Issuances of Unregistered Securities
Holders of our Series A Cumulative Convertible Preferred Units (“preferred units”) are entitled to receive cumulative quarterly distributions at a rate of 7.25% per annum. We may satisfy our obligation to pay distributions to the preferred unitholders through the issuance, in whole or in part, of additional preferred units (referred to as paid-in-kind or “PIK” distributions), with the remainder in cash, subject to certain rights of a holder to elect all cash and other conditions as described in our partnership agreement.
The Partnership made quarterly PIK distributions of 18,076, 18,404 and 18,737 preferred units to OTA Holdings, Inc., an indirect, wholly owned subsidiary of the Partnership (“OTA”) in the first, second and third quarters of 2023, respectively. The preferred units held by OTA are accounted for as treasury units in consolidation. For additional information regarding the preferred units, see Note 8 of the Notes to Unaudited Condensed Consolidated Financial Statements included under Part I, Item 1 of this quarterly report.
The issuances of preferred units as PIK distributions during the three and nine months ended September 30, 2023 were undertaken in reliance upon an exemption from the registration requirements of the Securities Act of 1933, as amended, pursuant to Section 4(a)(2) thereof.
Other than as described above, there were no sales of unregistered equity securities during the third quarter of 2023.
Issuer Purchases of Equity Securities
The following table summarizes our equity repurchase activity during the third quarter of 2023:
|
Period
|
Total Number
of Units
Purchased
|
Average
Price Paid
per Unit
|
Total Number
Of Units
Purchased
as Part of
2019 Buyback
Program
|
Remaining
Dollar Amount
of Units That May
Be Purchased
Under the 2019 Buyback Program
($ thousands)
|
||||||||||||
|
2019 Buyback Program: (1)
|
||||||||||||||||
|
July 2023
|
–
|
$
|
–
|
–
|
$
|
1,177,244
|
||||||||||
|
August 2023
|
–
|
$
|
–
|
–
|
$
|
1,177,244
|
||||||||||
|
September 2023
|
–
|
$
|
–
|
–
|
$
|
1,177,244
|
||||||||||
|
Vesting of phantom unit awards:
|
||||||||||||||||
|
August 2023 (2)
|
51,885
|
$
|
26.66
|
n/a
|
n/a
|
|||||||||||
|
(1)
|
In January 2019, we announced the 2019 Buyback Program, which authorized the repurchase of up to $2 billion of EPD’s common units. Units repurchased under this program are cancelled immediately upon acquisition.
|
|
(2)
|
Of the 178,556 phantom unit awards that vested in August 2023 and converted to common units, 51,885 units were sold back to us by employees to cover related withholding tax requirements. These repurchases are not part of any announced program. We cancelled these units immediately upon acquisition.
|
None.
Not applicable.
As previously disclosed, in December 2018, Enterprise Products Company (“EPCO”), an affiliate of the General Partner, formed EPD 2018 Unit IV L.P. (“EPD IV”) and EPCO Unit II L.P. (“EPCO II” and together with EPD IV, the “Employee Partnerships”), each to serve as an additional long-term incentive arrangement for certain employees of EPCO through a “profits interest” in such Employee Partnership. On December 3, 2018, EPCO Holdings Inc., a wholly owned subsidiary of EPCO (“EPCO Holdings”), contributed (i) 6,400,000 common units representing limited partner interests in Enterprise Products Partners (“Common Units”) to EPD IV and (ii) 1,600,000 Common Units to EPCO II (collectively, the “Contributions”), all such Common Units having a then current fair market value of $27.02 per Common Unit, as measured by the closing sales price per Common Unit on the NYSE on that date. In exchange for the Contributions, EPCO Holdings was admitted as the Class A limited partner of each Employee Partnership. Certain EPCO employees, including (in the case of EPD IV) certain of our named executive officers, were issued Class B limited partner interests and admitted as Class B limited partners of each Employee Partnership without any capital contribution. The profits interest awards (or Class B limited partner interests) in each Employee Partnership entitle the holder to participate in the appreciation in value of our Common Units and increases in quarterly cash distributions paid on our Common Units in excess of $0.4325 per unit, and are subject to forfeiture.
Prior to November 6, 2023, the limited partnership agreement for each of EPD IV and EPCO II provided that Class B limited partner interests therein will vest on the earliest of (i) December 3, 2023, (ii) a change of control or (iii) a dissolution of the applicable Employee Partnership. On November 6, 2023, the partners of EPD IV and EPCO II amended their respective Employee Partnership’s limited partnership agreement (each an “Amendment”) to provide that Class B limited partner interests therein will instead vest on the earliest of (i) December 3, 2027, (ii) the first date on or after November 6, 2023 for which the closing sale price for Common Units on the NYSE (or other principal United States securities exchange on which the Common Units are traded) is equal to or greater than $29.02 (as such dollar amount may be adjusted in order to reflect any equity split, equity distribution or dividend, reverse split, combination, reclassification, recapitalization or other similar event affecting the Common Units), (iii) a change of control or (iv) dissolution of such Employee Partnership.
Copies of the Amendment for each of EPD IV and EPCO II are filed as Exhibit 10.2 and Exhibit 10.3, respectively. The foregoing description of the Amendments is qualified in its entirety by such exhibits, which are incorporated by reference herein.
|
Exhibit Number
|
Exhibit*
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|
2.1
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|
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2.2
|
|
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2.3
|
|
|
2.4
|
|
|
2.5
|
|
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2.6
|
|
|
2.7
|
|
|
2.8
|
|
|
2.9
|
|
|
2.10
|
|
|
2.11
|
|
|
2.12
|
|
2.13
|
|
|
2.14
|
|
|
3.1
|
|
|
3.2
|
|
|
3.3
|
|
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3.4
|
|
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3.5
|
|
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3.6
|
|
|
3.7
|
|
|
3.8
|
|
|
3.9
|
|
|
3.10
|
|
|
3.11
|
|
|
3.12
|
|
|
4.1
|
|
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4.2
|
|
|
4.3
|
|
4.4
|
|
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4.5
|
|
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4.6
|
|
|
4.7
|
|
|
4.8
|
|
|
4.9
|
|
|
4.10
|
|
|
4.11
|
|
|
4.12
|
|
|
4.13
|
|
|
4.14
|
|
|
4.15
|
|
|
4.16
|
|
4.17
|
|
|
4.18
|
|
|
4.19
|
|
|
4.20
|
|
|
4.21
|
|
|
4.22
|
|
|
4.23
|
|
|
4.24
|
|
|
4.25
|
|
|
4.26
|
|
|
4.27
|
|
|
4.28
|
|
|
4.29
|
|
4.30
|
|||
|
4.31
|
|||
|
4.32
|
|||
|
4.33
|
|||
|
4.34
|
|||
|
4.35
|
|||
|
4.36
|
|||
|
4.37
|
|||
|
4.38
|
|||
|
4.39
|
|||
|
4.40
|
|||
|
4.41
|
|||
|
4.42
|
|||
|
4.43
|
|||
|
4.44
|
|||
|
4.45
|
|||
|
4.46
|
|||
|
4.47
|
|||
|
4.48
|
|||
|
4.49
|
|||
|
4.50
|
|||
|
4.51
|
|||
|
4.52
|
|||
|
4.53
|
|||
|
4.54
|
|||
|
4.55
|
|||
|
4.56
|
|||
|
4.57
|
|||
|
4.58
|
|||
|
4.59
|
|||
|
4.60
|
|||
|
4.61
|
|||
|
4.62
|
|||
|
4.63
|
|||
|
4.64
|
|
|
4.65
|
|
|
4.66
|
|
|
4.67
|
|
|
4.68
|
|
|
4.69
|
|
|
4.70
|
|
|
4.71
|
|
|
4.72
|
|
|
4.73
|
|
|
4.74
|
|
|
4.75
|
|
|
4.76
|
|
|
4.77
|
|
|
4.78
|
|
4.79
|
|
|
4.80
|
|
|
4.81
|
|
|
4.82
|
|
|
4.83
|
|
|
4.84
|
|
|
4.85
|
|
|
4.86
|
|
|
4.87
|
|
|
4.88
|
|
|
10.1
|
|
|
10.2#
|
|
|
10.3#
|
|
22.1#
|
|
|
31.1#
|
|
|
31.2#
|
|
|
32.1#
|
|
|
32.2#
|
|
|
101#
|
Interactive data files pursuant to Rule 405 of Regulation S-T formatted in iXBRL (Inline Extensible Business Reporting Language) in this Form 10-Q include the: (i) Unaudited Condensed Consolidated Balance Sheets, (ii) Unaudited Condensed Statements of Consolidated Operations, (iii) Unaudited Condensed Statements of Consolidated Comprehensive Income, (iv) Unaudited Condensed Statements of Consolidated Cash Flows, (v) Unaudited Condensed Statements of Consolidated Equity and (vi) Notes to the Unaudited Condensed Consolidated Financial Statements.
|
|
104#
|
Cover Page Interactive Data File (embedded within the iXBRL document).
|
|
*
|
With respect to any exhibits incorporated by reference to any Exchange Act filings, the Commission file numbers for Enterprise Products Partners L.P., Enterprise GP Holdings L.P, TEPPCO Partners, L.P. and TE Products Pipeline Company, LLC are 1-14323, 1-32610, 1-10403 and 1-13603, respectively.
|
|
***
|
Identifies management contract and compensatory plan arrangements.
|
|
#
|
Filed with this report.
|
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized on November 9, 2023.
|
ENTERPRISE PRODUCTS PARTNERS L.P.
(A Delaware Limited Partnership)
|
|||
|
By:
|
Enterprise Products Holdings LLC, as General Partner
|
||
|
By:
|
/s/ R. Daniel Boss
|
||
|
Name:
|
R. Daniel Boss
|
||
|
Title:
|
Executive Vice President – Accounting, Risk Control and Information Technology of the General Partner
|
||
TABLE OF CONTENTS
Part I. Financial InformationItem 1. Financial StatementsNote 1. Partnership Organization and OperationsNote 2. Summary Of Significant Accounting PoliciesNote 3. InventoriesNote 4. Property, Plant and EquipmentNote 5. Investments in Unconsolidated AffiliatesNote 6. Intangible Assets and GoodwillNote 7. Debt ObligationsNote 8. Capital AccountsNote 9. RevenuesNote 10. Business Segments and Related InformationNote 11. Earnings Per UnitNote 12. Equity-based AwardsNote 13. Hedging Activities and Fair Value MeasurementsNote 14. Related Party TransactionsNote 15. Income TaxesNote 16. Commitments and Contingent LiabilitiesNote 17. Supplemental Cash Flow InformationItem 2. Management S Discussion and Analysis Of Financial Condition andItem 3. Quantitative and Qualitative DisclosuresItem 4. Controls and ProceduresPart II. Other InformationPart II. OItem 1. Legal ProceedingsItem 1A. Risk FactorsItem 2. Unregistered Sales Of Equity Securities and Use Of ProceedsItem 3. Defaults Upon Senior SecuritiesItem 4. Mine Safety DisclosuresItem 5. Other InformationItem 6. Exhibits