NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited)
Note 1 – Organization and Business Description
The accompanying notes to the consolidated financial statements apply to Crestwood Equity Partners LP (Crestwood Equity or CEQP) and Crestwood Midstream Partners LP (Crestwood Midstream or CMLP), unless otherwise indicated.
The accompanying consolidated financial statements and related notes should be read in conjunction with our 2020 Annual Report on Form 10-K filed with the Securities and Exchange Commission (SEC) on February 26, 2021. The financial information as of June 30, 2021, and for the three and six months ended June 30, 2021 and 2020, is unaudited. The consolidated balance sheets as of December 31, 2020 were derived from the audited balance sheets filed in our 2020 Annual Report on Form 10-K.
References in this report to “we,” “us,” “our,” “ours,” “our company,” the “partnership,” the “Company,” “Crestwood Equity,” “CEQP,” and similar terms refer to either Crestwood Equity Partners LP itself or Crestwood Equity Partners LP and its consolidated subsidiaries, as the context requires. Unless otherwise indicated, references to “Crestwood Midstream” and “CMLP” refer to either Crestwood Midstream Partners LP itself or Crestwood Midstream Partners LP and its consolidated subsidiaries.
Organization
Crestwood Equity Partners LP. CEQP is a publicly-traded (NYSE: CEQP) Delaware limited partnership formed in March 2001. Crestwood Equity GP LLC (Crestwood Equity GP), which is indirectly owned by Crestwood Holdings LLC (Crestwood Holdings), owns our non-economic general partnership interest. Crestwood Holdings is substantially owned and controlled by First Reserve Management, L.P. (First Reserve).
Crestwood Midstream Partners LP. Crestwood Equity owns a 99.9% limited partnership interest in Crestwood Midstream and Crestwood Gas Services GP LLC (CGS GP), a wholly-owned subsidiary of Crestwood Equity, owns a 0.1% limited partnership interest in Crestwood Midstream. Crestwood Midstream GP LLC, a wholly-owned subsidiary of Crestwood Equity, owns the non-economic general partnership interest of Crestwood Midstream.
Crestwood Holdings Strategic Transactions. In March 2021, CEQP acquired approximately 11.5 million CEQP common units, 0.4 million subordinated units of CEQP and 100% of the equity interests of Crestwood Marcellus Holdings LLC and Crestwood Gas Services Holdings LLC (whose assets consisted solely of CEQP common and subordinated units and 1% of the limited partner interests in Crestwood Holdings LP) from Crestwood Holdings, and signed a definitive agreement to acquire the general partner and the remaining 99% limited partner interests of Crestwood Holdings LP (whose assets consist solely of its ownership interest in Crestwood Equity GP, which owns CEQP’s non-economic general partner interest) (collectively the Crestwood Holdings Transactions) for $268 million in cash. The acquisition of the general partner and limited partner interests of Crestwood Holdings LP will close on or before the 180th day after the date of the initial closing of the Crestwood Holdings Transactions. The purchase price was funded through borrowings under the Crestwood Midstream credit facility. CEQP retired the common and subordinated units acquired in the Crestwood Holdings Transactions.
The diagram below reflects a simplified version our ownership structure as of June 30, 2021 following the Crestwood Holdings Transactions.
Business Description
Crestwood Equity develops, acquires, owns or controls, and operates primarily fee-based assets and operations within the energy midstream sector. We provide broad-ranging infrastructure solutions across the value chain to service premier liquids-rich natural gas and crude oil shale plays across the United States. We own and operate a diversified portfolio of natural gas liquids (NGLs), crude oil, natural gas and produced water gathering, processing, storage, disposal and transportation assets that
connect fundamental energy supply with energy demand across the United States. Crestwood Equity is a holding company and all of its consolidated operating assets are owned by or through its wholly-owned subsidiary, Crestwood Midstream.
Our financial statements reflect three operating and reporting segments described below.
•Gathering and Processing. Our gathering and processing operations provide natural gas, crude oil and produced water gathering, compression, treating, processing and disposal services to producers in multiple unconventional resource plays in some of the largest shale plays in the United States in which we have established footprints in the “core of the core” areas.
•Storage and Transportation. Our storage and transportation operations provide crude oil and natural gas storage and transportation services to producers, utilities and other customers.
•Marketing, Supply and Logistics. Our marketing, supply and logistics operations provide NGLs, crude oil and natural gas marketing, storage, terminal and transportation services to producers, refiners, marketers and other customers.
Note 2 – Basis of Presentation and Summary of Significant Accounting Policies
Basis of Presentation
Our consolidated financial statements are prepared in accordance with Generally Accepted Accounting Principles (GAAP) and include the accounts of all consolidated subsidiaries after the elimination of all intercompany accounts and transactions. Certain amounts and footnote disclosures in the prior periods have been reclassified to conform to the current year presentation, none of which impacted our previously reported net income, earnings per unit or partners’ capital. In management’s opinion, all necessary adjustments to fairly present our results of operations, financial position and cash flows for the periods presented have been made and all such adjustments are of a normal and recurring nature. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with GAAP have been omitted pursuant to the rules and regulations of the SEC.
Significant Accounting Policies
There were no material changes in our significant accounting policies from those described in our 2020 Annual Report on Form 10-K. During the six months ended June 30, 2020, we recorded an $80.3 million full impairment of the goodwill associated with our Powder River Basin reporting unit based on events that occurred during 2020 which resulted in a significant decrease in the forecasted cash flows and fair value of the reporting unit. For a further discussion of this goodwill impairment, see our 2020 Annual Report on Form 10-K.
Note 3 – Acquisition
In April 2020, we acquired several NGL storage and rail-to-truck terminals from Plains All American Pipeline, L.P. for approximately $162 million. The acquired assets include 7 MMBbls of NGL storage and seven terminals. These assets are included in our marketing, supply and logistics segment. The transaction costs related to this acquisition were not material during the three and six months ended June 30, 2020.
Note 4 – Certain Balance Sheet Information
Accrued Expenses and Other Liabilities
Accrued expenses and other liabilities consisted of the following (in millions):
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|
|
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|
|
CEQP
|
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CMLP
|
|
|
June 30,
|
|
December 31,
|
|
June 30,
|
|
December 31,
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|
|
2021
|
|
2020
|
|
2021
|
|
2020
|
|
Accrued expenses
|
$
|
50.9
|
|
|
$
|
48.3
|
|
|
$
|
49.4
|
|
|
$
|
46.4
|
|
|
Accrued property taxes
|
6.3
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|
8.4
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|
|
6.3
|
|
|
8.4
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|
|
Income tax payable
|
0.2
|
|
|
0.2
|
|
|
0.2
|
|
|
0.2
|
|
|
Interest payable
|
32.4
|
|
|
24.9
|
|
|
32.4
|
|
|
24.9
|
|
|
Accrued additions to property, plant and equipment
|
39.8
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|
|
12.3
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|
|
39.8
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|
|
12.3
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|
Operating leases
|
12.0
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|
14.7
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|
12.0
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|
14.7
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|
Finance leases
|
2.7
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|
2.9
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|
2.7
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|
2.9
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|
Deferred revenue
|
10.5
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|
|
10.3
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|
|
10.5
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|
|
10.3
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|
|
|
|
|
|
|
|
|
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|
Total accrued expenses and other liabilities
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$
|
154.8
|
|
|
$
|
122.0
|
|
|
$
|
153.3
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|
|
$
|
120.1
|
|
Other Long-Term Liabilities
Other long-term liabilities consisted of the following (in millions):
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CEQP
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CMLP
|
|
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June 30,
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December 31,
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June 30,
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December 31,
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|
|
2021
|
|
2020
|
|
2021
|
|
2020
|
|
Contract liabilities
|
$
|
179.2
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|
|
$
|
172.2
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|
|
$
|
179.2
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|
|
$
|
172.2
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Operating leases
|
23.3
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|
28.5
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|
23.3
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|
28.5
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Asset retirement obligations
|
35.1
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|
34.1
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|
35.1
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|
|
34.1
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Other
|
17.3
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|
18.5
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|
15.0
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|
|
17.0
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Total other long-term liabilities
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$
|
254.9
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|
|
$
|
253.3
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|
|
$
|
252.6
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|
|
$
|
251.8
|
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Note 5 - Investments in Unconsolidated Affiliates
Variable Interest Entity
Crestwood Permian Basin Holdings LLC (Crestwood Permian) is a joint venture owned by Crestwood Infrastructure Holdings LLC (Crestwood Infrastructure), our wholly-owned subsidiary, and an affiliate of First Reserve. We manage and account for our 50% ownership interest in Crestwood Permian, which is a variable interest entity, under the equity method of accounting as we exercise significant influence, but do not control Crestwood Permian and we are not its primary beneficiary due to First Reserve’s rights to exercise control over the entity.
Net Investments and Earnings (Loss)
Our net investments in and earnings (loss) from our unconsolidated affiliates are as follows (in millions):
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Investment
|
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Earnings (Loss) from
Unconsolidated Affiliates
|
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Earnings (Loss) from
Unconsolidated Affiliates
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Three Months Ended
|
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Six Months Ended
|
|
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|
|
June 30,
|
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December 31,
|
|
June 30,
|
|
June 30,
|
|
|
|
|
2021
|
|
2020
|
|
2021
|
|
2020
|
|
2021
|
|
2020
|
|
Stagecoach Gas Services LLC(1)
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|
|
$
|
628.2
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|
|
$
|
792.5
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|
|
$
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(28.0)
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|
|
$
|
9.2
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|
|
$
|
(140.3)
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|
|
$
|
18.4
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Tres Palacios Holdings LLC(2)
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|
41.0
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|
|
35.5
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|
|
(0.1)
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|
0.1
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9.2
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|
|
0.1
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|
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Powder River Basin Industrial Complex, LLC(3)
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|
|
3.6
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|
3.6
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—
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0.1
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0.1
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|
(4.4)
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Crestwood Permian Basin Holdings LLC(4)
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|
|
110.1
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|
112.1
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1.0
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(1.0)
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|
0.2
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|
|
(0.2)
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Total
|
|
|
$
|
782.9
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|
|
$
|
943.7
|
|
|
$
|
(27.1)
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|
$
|
8.4
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|
|
$
|
(130.8)
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|
$
|
13.9
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(1)As of June 30, 2021, our equity in the underlying net assets of Stagecoach Gas Services LLC (Stagecoach Gas) approximates the carrying value of our investment. During the six months ended June 30, 2021, we and the other 50% owner of Stagecoach Gas, Con Edison Gas Pipeline and Storage Northeast, LLC (CEGP) entered into an agreement to sell Stagecoach Gas to a subsidiary of Kinder Morgan, Inc. (Kinder Morgan) in a series of transactions. Based on these anticipated transactions, we recorded our share of a loss on long-lived assets (including goodwill) recorded by our Stagecoach Gas equity investment associated with the anticipated sale. This eliminated our $51.3 million historical basis difference between our investment balance and the equity in the underlying net assets of Stagecoach Gas, and also resulted in a $35.5 million and $155.4 million reduction in our earnings from unconsolidated affiliates during the three and six months ended June 30, 2021. In addition, our earnings from unconsolidated affiliates during the three and six months ended June 30, 2021 were also reduced by our proportionate share of transaction costs of approximately $3.0 million related to the anticipated sale, which were paid by us in July 2021 on behalf of Stagecoach Gas. Our Stagecoach Gas investment is included in our storage and transportation segment.
(2)As of June 30, 2021, our equity in the underlying net assets of Tres Palacios Holdings LLC (Tres Holdings) exceeded the carrying value of our investment balance by approximately $22.1 million. During both the three and six months ended June 30, 2021 and 2020, we recorded amortization of approximately $0.3 million and $0.6 million, respectively, related to this excess basis, which is reflected as an increase in our earnings from unconsolidated affiliates in our consolidated statements of operations. Our Tres Holdings investment is included in our storage and transportation segment.
(3)As of June 30, 2021, our equity in the underlying net assets of Powder River Basin Industrial Complex, LLC (PRBIC) approximates the carrying value of our investment balance. During the first quarter of 2020, we recorded our share of a long-lived asset impairment recorded by our PRBIC equity investment, which eliminated our $5.5 million historical basis difference between our investment balance and the equity in the underlying net assets of PRBIC, and also resulted in a $4.5 million reduction in our earnings from unconsolidated affiliates during the six months ended June 30, 2020. Our PRBIC investment is included in our storage and transportation segment.
(4)As of June 30, 2021, our equity in the underlying net assets of Crestwood Permian exceeded our investment balance by $7.7 million, and this excess amount is not subject to amortization. Our Crestwood Permian investment is included in our gathering and processing segment.
Summarized Financial Information of Unconsolidated Affiliates
Below is the summarized operating results for our significant unconsolidated affiliates (in millions; amounts represent 100% of unconsolidated affiliate information):
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|
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Six Months Ended
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|
|
June 30,
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|
2021
|
|
2020
|
|
|
Operating Revenues
|
|
Operating Expenses
|
|
Net Income (Loss)
|
|
Operating Revenues
|
|
Operating Expenses
|
|
Net Income (Loss)
|
|
Stagecoach Gas
|
$
|
77.5
|
|
|
$
|
454.9
|
|
|
$
|
(377.4)
|
|
|
$
|
75.6
|
|
|
$
|
38.9
|
|
|
$
|
36.8
|
|
|
|
|
|
|
|
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|
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|
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|
|
|
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|
|
|
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Other(1)
|
135.1
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|
|
118.0
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|
|
17.6
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|
|
53.5
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|
|
76.1
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|
|
(21.6)
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Total
|
$
|
212.6
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|
|
$
|
572.9
|
|
|
$
|
(359.8)
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|
|
$
|
129.1
|
|
|
$
|
115.0
|
|
|
$
|
15.2
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(1)Includes our Tres Holdings, PRBIC and Crestwood Permian equity investments.
Distributions and Contributions
The following table summarizes our distributions from and contributions to our unconsolidated affiliates (in millions):
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Distributions(1)
|
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Contributions
|
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Six Months Ended
|
|
Six Months Ended
|
|
|
|
|
|
|
|
June 30,
|
|
June 30,
|
|
|
|
|
|
2021
|
|
2020
|
|
2021
|
|
2020
|
|
|
|
|
|
Stagecoach Gas
|
|
$
|
27.0
|
|
|
$
|
30.0
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
|
|
|
|
Tres Holdings
|
|
10.6
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|
|
1.4
|
|
|
6.9
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|
|
6.0
|
|
|
|
|
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|
PRBIC
|
|
0.1
|
|
|
0.1
|
|
|
—
|
|
|
—
|
|
|
|
|
|
|
Crestwood Permian
|
|
5.5
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|
|
6.7
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|
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3.3
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|
|
—
|
|
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|
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Total
|
|
$
|
43.2
|
|
|
$
|
38.2
|
|
|
$
|
10.2
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|
|
$
|
6.0
|
|
|
|
|
|
(1) In July 2021, we received cash distributions from Tres Holdings and Crestwood Permian of approximately $2.5 million and $3.4 million, respectively. In connection with the anticipated sale of Stagecoach Gas, in July 2021, Stagecoach Gas closed on the sale of certain of its wholly-owned subsidiaries to a subsidiary of Kinder Morgan and distributed to us approximately $613.9 million as our proportionate share of the gross proceeds received from the sale. We utilized approximately $3 million of these proceeds to pay transaction costs related to the sale described above, $40 million of these proceeds to pay our contingent consideration obligation and related accrued interest described below, and the remaining proceeds to repay a portion of the amounts outstanding under the Crestwood Midstream credit facility.
Other
Contingent Consideration. Pursuant to the Stagecoach Gas limited liability company agreement, we are required to make $57 million of payments to CEGP because certain performance targets on growth capital projects were not achieved by December 31, 2020. During the six months ended June 30, 2021, we paid $19 million to CEGP related to this obligation. At June 30, 2021, our consolidated balance sheet reflects a $38 million liability related to this obligation, of which $19 million is classified as current. We accrued interest of approximately $2.1 million related to this obligation which is included in accrued expenses and other liabilities on our consolidated balance sheet at June 30, 2021. In July 2021, we repaid all amounts, including accrued interest, related to this obligation.
Guarantee. CEQP issued a guarantee under which CEQP would be required to pay up to $10 million if Crestwood Permian fails to honor its obligations to Crestwood Permian Basin LLC, a 50% equity investment of Crestwood Permian, in the event Crestwood Permian Basin LLC fails to satisfy its obligations under its gas gathering agreement with a third party. We do not believe that it is probable that this guarantee will result in future losses based on our assessment of the nature of the guarantee, the financial condition of the guaranteed party and the period of time that the guarantee has been outstanding, and as a result, we have not recorded a liability related to this guarantee on our consolidated balance sheets at June 30, 2021 and December 31, 2020.
Note 6 – Risk Management
We are exposed to certain market risks related to our ongoing business operations. These risks include exposure to changing commodity prices. We utilize derivative instruments to manage our exposure to fluctuations in commodity prices, which is discussed below. Additional information related to our derivatives is discussed in Note 7.
Risk Management Activities
We sell NGLs (such as propane, ethane, butane and heating oil), crude oil and natural gas to energy-related businesses and may use a variety of financial and other instruments including forward contracts involving physical delivery of NGLs, crude oil and natural gas. We periodically enter into offsetting positions to economically hedge against the exposure our customer contracts create. Certain of these contracts and positions are derivative instruments. We do not designate any of our commodity-based derivatives as hedging instruments for accounting purposes. Our commodity-based derivatives are reflected at fair value in our consolidated balance sheets, and changes in the fair value of these derivatives that impact the consolidated statements of operations are reflected in costs of product/services sold. Our commodity-based derivatives that are settled with physical commodities are reflected as an increase to product revenues, and the commodity inventory that is utilized to satisfy those physical obligations is reflected as an increase to product costs in our consolidated statements of operations. The following table summarizes the impact to our consolidated statements of operations related to our commodity-based derivatives during the three and six months ended June 30, 2021 and 2020 (in millions):
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|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Six Months Ended
|
|
|
|
June 30,
|
|
June 30,
|
|
|
|
2021
|
|
2020
|
|
2021
|
|
2020
|
|
Product revenues
|
|
$
|
52.7
|
|
|
$
|
18.0
|
|
|
$
|
167.5
|
|
|
$
|
93.0
|
|
|
Gain (loss) reflected in product costs
|
|
$
|
(33.3)
|
|
|
$
|
(6.8)
|
|
|
$
|
(41.4)
|
|
|
$
|
15.2
|
|
We attempt to balance our contractual portfolio in terms of notional amounts and timing of performance and delivery obligations. This balance in the contractual portfolio significantly reduces the volatility in product costs related to these instruments.
Notional Amounts and Terms
The notional amounts of our derivative financial instruments include the following:
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|
|
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|
|
June 30, 2021
|
|
December 31, 2020
|
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Fixed Price
Payor
|
|
Fixed Price
Receiver
|
|
Fixed Price
Payor
|
|
Fixed Price
Receiver
|
|
Propane, ethane, butane, heating oil and crude oil (MMBbls)
|
66.3
|
|
|
70.6
|
|
|
72.7
|
|
|
76.5
|
|
|
Natural gas (Bcf)
|
26.1
|
|
|
33.6
|
|
|
22.6
|
|
|
28.6
|
|
Notional amounts reflect the volume of transactions, but do not represent the amounts exchanged by the parties to the financial instruments. Accordingly, notional amounts do not reflect our monetary exposure to market or credit risks. All contracts subject to price risk had a maturity of 38 months or less; however, 85% of the contracted volumes will be delivered or settled within 12 months.
Credit Risk
Inherent in our contractual portfolio are certain credit risks. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. We take an active role in managing credit risk and have established control procedures, which are reviewed on an ongoing basis. We attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures as well as through customer deposits, letters of credit and entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate. The counterparties associated with our price risk management activities are energy marketers and propane retailers, resellers and dealers.
Certain of our derivative instruments have credit limits that require us to post collateral. The amount of collateral required to be posted is a function of the net liability position of the derivative as well as our established credit limit with the respective counterparty. If our credit rating were to change, the counterparties could require us to post additional collateral. The amount of additional collateral that would be required to be posted would vary depending on the extent of change in our credit rating as well as the requirements of the individual counterparty. In addition, we have variation margin requirements with a derivative clearing broker and a third party broker related to our net asset or liability position with each respective broker. All collateral amounts have been netted against the asset or liability with the respective counterparty and are reflected in our consolidated balance sheets as assets and liabilities from price risk management activities.
The following table presents the fair value of our commodity derivative instruments with credit-risk related contingent features and their associated collateral (in millions):
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
June 30, 2021
|
|
December 31, 2020
|
|
Aggregate fair value liability of derivative instruments with credit-risk-related contingent features(1)
|
$
|
83.7
|
|
|
$
|
38.5
|
|
|
Variation margin-related net derivative asset position
|
$
|
124.7
|
|
|
$
|
35.9
|
|
|
Variation margin-related cash collateral received
|
$
|
99.5
|
|
|
$
|
18.3
|
|
|
Cash collateral received, net
|
$
|
8.5
|
|
|
$
|
12.4
|
|
(1)At June 30, 2021 and December 31, 2020, we posted less than $0.1 million of collateral associated with these derivatives.
Note 7 – Fair Value Measurements
The accounting standard for fair value measurement establishes a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are as follows:
•Level 1—Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of financial instruments such as exchange-traded derivatives, listed equities and US government treasury securities.
•Level 2—Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Instruments in this category include non-exchange-traded derivatives such as over the counter (OTC) forwards, options and physical exchanges.
•Level 3—Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value.
Financial Assets and Liabilities
As of June 30, 2021 and December 31, 2020, we held certain assets and liabilities that are required to be measured at fair value on a recurring basis, which include our derivative instruments related to crude oil, NGLs and natural gas. Our derivative instruments consist of forwards, swaps, futures, physical exchanges and options.
Our derivative instruments that are traded on the New York Mercantile Exchange have been categorized as Level 1.
Our derivative instruments also include OTC contracts, which are not traded on a public exchange. The fair values of these derivative instruments are determined based on inputs that are readily available in public markets or can be derived from information available in publicly quoted markets. These instruments have been categorized as Level 2.
Our OTC options are valued based on the Black Scholes option pricing model that considers time value and volatility of the underlying commodity. The inputs utilized in the model are based on publicly available information as well as broker quotes. These options have been categorized as Level 2.
Our financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels.
The following tables set forth by level within the fair value hierarchy, our financial instruments that were accounted for at fair value on a recurring basis at June 30, 2021 and December 31, 2020 (in millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
June 30, 2021
|
|
|
|
|
|
|
|
|
|
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Gross Fair Value
|
|
Contract Netting(1)
|
|
Collateral/Margin Received or Paid
|
|
Fair Value
|
|
Assets
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Assets from price risk management
|
$
|
52.4
|
|
|
$
|
948.3
|
|
|
$
|
—
|
|
|
$
|
1,000.7
|
|
|
$
|
(873.3)
|
|
|
$
|
(99.8)
|
|
|
$
|
27.6
|
|
|
Suburban Propane Partners, L.P. units(2)
|
2.2
|
|
|
—
|
|
|
—
|
|
|
2.2
|
|
|
—
|
|
|
—
|
|
|
2.2
|
|
|
Total assets at fair value
|
$
|
54.6
|
|
|
$
|
948.3
|
|
|
$
|
—
|
|
|
$
|
1,002.9
|
|
|
$
|
(873.3)
|
|
|
$
|
(99.8)
|
|
|
$
|
29.8
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Liabilities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Liabilities from price risk management
|
$
|
41.2
|
|
|
$
|
974.0
|
|
|
$
|
—
|
|
|
$
|
1,015.2
|
|
|
$
|
(873.3)
|
|
|
$
|
8.2
|
|
|
$
|
150.1
|
|
|
Total liabilities at fair value
|
$
|
41.2
|
|
|
$
|
974.0
|
|
|
$
|
—
|
|
|
$
|
1,015.2
|
|
|
$
|
(873.3)
|
|
|
$
|
8.2
|
|
|
$
|
150.1
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, 2020
|
|
|
|
|
|
|
|
|
|
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Gross Fair Value
|
|
Contract Netting(1)
|
|
Collateral/Margin Received or Paid
|
|
Fair Value
|
|
Assets
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Assets from price risk management
|
$
|
20.2
|
|
|
$
|
480.5
|
|
|
$
|
—
|
|
|
$
|
500.7
|
|
|
$
|
(455.0)
|
|
|
$
|
(18.5)
|
|
|
$
|
27.2
|
|
|
Suburban Propane Partners, L.P. units(2)
|
2.1
|
|
|
—
|
|
|
—
|
|
|
2.1
|
|
|
—
|
|
|
—
|
|
|
2.1
|
|
|
Total assets at fair value
|
$
|
22.3
|
|
|
$
|
480.5
|
|
|
$
|
—
|
|
|
$
|
502.8
|
|
|
$
|
(455.0)
|
|
|
$
|
(18.5)
|
|
|
$
|
29.3
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Liabilities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Liabilities from price risk management
|
$
|
25.1
|
|
|
$
|
494.0
|
|
|
$
|
—
|
|
|
$
|
519.1
|
|
|
$
|
(455.0)
|
|
|
$
|
12.2
|
|
|
$
|
76.3
|
|
|
Total liabilities at fair value
|
$
|
25.1
|
|
|
$
|
494.0
|
|
|
$
|
—
|
|
|
$
|
519.1
|
|
|
$
|
(455.0)
|
|
|
$
|
12.2
|
|
|
$
|
76.3
|
|
(1)Amounts represent the impact of legally enforceable master netting agreements that allow us to settle positive and negative positions.
(2)Amount is reflected in other non-current assets on CEQP’s consolidated balance sheets.
Cash, Accounts Receivable and Accounts Payable
As of June 30, 2021 and December 31, 2020, the carrying amounts of cash, accounts receivable and accounts payable approximate fair value based on the short-term nature of these instruments.
Credit Facility
The fair value of the amounts outstanding under our Crestwood Midstream credit facility approximates the carrying amounts as of June 30, 2021 and December 31, 2020, due primarily to the variable nature of the interest rate of the instrument, which is considered a Level 2 fair value measurement.
Senior Notes
We estimate the fair value of our senior notes primarily based on quoted market prices for the same or similar issuances (representing a Level 2 fair value measurement). The following table represents the carrying amount (reduced for deferred financing costs associated with the respective notes) and fair value of our senior notes (in millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
June 30, 2021
|
|
December 31, 2020
|
|
|
Carrying
Amount
|
|
Fair
Value
|
|
Carrying
Amount
|
|
Fair
Value
|
|
2023 Senior Notes
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
683.8
|
|
|
$
|
691.5
|
|
|
2025 Senior Notes
|
$
|
496.0
|
|
|
$
|
514.7
|
|
|
$
|
495.5
|
|
|
$
|
509.9
|
|
|
2027 Senior Notes
|
$
|
593.7
|
|
|
$
|
617.7
|
|
|
$
|
593.2
|
|
|
$
|
594.1
|
|
|
2029 Senior Notes
|
$
|
690.2
|
|
|
$
|
733.6
|
|
|
$
|
—
|
|
|
$
|
—
|
|
Note 8 – Long-Term Debt
Long-term debt consisted of the following at June 30, 2021 and December 31, 2020 (in millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
June 30,
2021
|
|
December 31,
2020
|
|
Credit Facility
|
$
|
848.6
|
|
|
$
|
719.0
|
|
|
2023 Senior Notes
|
—
|
|
|
687.2
|
|
|
2025 Senior Notes
|
500.0
|
|
|
500.0
|
|
|
2027 Senior Notes
|
600.0
|
|
|
600.0
|
|
|
2029 Senior Notes
|
700.0
|
|
|
—
|
|
|
Other(1)
|
0.4
|
|
|
0.4
|
|
|
Less: deferred financing costs, net
|
27.2
|
|
|
22.6
|
|
|
Total debt
|
2,621.8
|
|
|
2,484.0
|
|
|
Less: current portion
|
0.2
|
|
|
0.2
|
|
|
Total long-term debt, less current portion
|
$
|
2,621.6
|
|
|
$
|
2,483.8
|
|
(1)Represents non-interest bearing obligations related to certain companies acquired in 2014 with payments due through 2022.
Credit Facility
Crestwood Midstream’s five-year $1.25 billion revolving credit facility (the CMLP Credit Facility) is available to fund acquisitions, working capital and internal growth projects and for general partnership purposes. Contemporaneous with the Crestwood Holdings Transactions described in Note 1, Crestwood Midstream entered into the Third Amendment to its credit agreement in order to, among other things, permit the borrowings under the CMLP Credit Facility to fund the Crestwood Holdings Transactions and revise the definition of Change in Control in the CMLP Credit Agreement as it relates to the control of CEQP’s general partner). The other covenants and restrictive provisions under the amended credit agreement are materially consistent with the covenants that existed at December 31, 2020.
Crestwood Midstream is required under its credit agreement to maintain a net debt to consolidated EBITDA ratio (as defined in its credit agreement) of not more than 5.50 to 1.0, a consolidated EBITDA to consolidated interest expense ratio (as defined in its credit agreement) of not less than 2.50 to 1.0, and a senior secured leverage ratio (as defined in its credit agreement) of not more than 3.75 to 1.0. At June 30, 2021, the net debt to consolidated EBITDA ratio was approximately 4.16 to 1.0, the consolidated EBITDA to consolidated interest expense ratio was approximately 4.84 to 1.0, and the senior secured leverage ratio was 1.33 to 1.0.
At June 30, 2021, Crestwood Midstream had $366.7 million of available capacity under its credit facility considering the most restrictive debt covenants in its credit agreement. At June 30, 2021 and December 31, 2020, Crestwood Midstream’s outstanding standby letters of credit were $34.7 million and $23.9 million. Borrowings under the credit facility accrue interest at prime or Eurodollar based rates plus applicable spreads, which resulted in interest rates between 2.33% and 4.50% at June 30,
2021 and 2.40% and 4.50% at December 31, 2020. The weighted-average interest rate on outstanding borrowings as of June 30, 2021 and December 31, 2020 was 2.38% and 2.45%.
Senior Notes
2029 Senior Notes. In January 2021, Crestwood Midstream issued $700 million of 6.00% unsecured senior notes due 2029 (the 2029 Senior Notes). The 2029 Senior Notes will mature on February 1, 2029, and interest is payable semi-annually in arrears on February 1 and August 1 of each year, beginning on August 1, 2021. The net proceeds from this offering of approximately $691.0 million were used to repay a portion of the 2023 Senior Notes and to repay indebtedness under the CMLP Credit Facility.
2023 Senior Note Repayments. During the six months ended June 30, 2021, we redeemed $687.2 million of principal outstanding under our 2023 Senior Notes. In conjunction with the repayment of the notes, we recognized a loss on extinguishment of debt of approximately $1.2 million and $6.7 million during the three and six months ended June 30, 2021, and paid approximately $8.6 million of accrued interest on the 2023 Senior Notes on the dates they were repurchased. We funded the repayment using a portion of the proceeds from the issuance of the 2029 Senior Notes and borrowings under the CMLP Credit Facility.
Note 9 – Commitments and Contingencies
Legal Proceedings
Linde Lawsuit. On December 23, 2019, Linde Engineering North America Inc. (Linde) filed a lawsuit in the District Court of Harris County, Texas alleging that Arrow Field Services, LLC, our consolidated subsidiary, and Crestwood Midstream breached a contract entered into in March 2018 under which Linde was to provide engineering, procurement and construction services to us related to the completion of the construction of the Bear Den II cryogenic processing plant. Linde claims damages of $55 million in unpaid invoices and other damages. This matter is not an insurable event based on our insurance policies, and we are unable to predict the outcome for this matter.
General. We are periodically involved in litigation proceedings. If we determine that a negative outcome is probable and the amount of loss is reasonably estimable, then we accrue the estimated amount. The results of litigation proceedings cannot be predicted with certainty. We could incur judgments, enter into settlements or revise our expectations regarding the outcome of certain matters, and such developments could have a material adverse effect on our results of operations or cash flows in the period in which the amounts are paid and/or accrued. As of June 30, 2021 and December 31, 2020, we had approximately $36.3 million and $10.4 million accrued for outstanding legal matters. Based on currently available information, we believe it is remote that future costs related to known contingent liability exposures for which we can estimate will exceed current accruals by an amount that would have a material adverse impact on our consolidated financial statements. As we learn new facts concerning contingencies, we reassess our position both with respect to accrued liabilities and other potential exposures.
Any loss estimates are inherently subjective, based on currently available information, and are subject to management’s judgment and various assumptions. Due to the inherently subjective nature of these estimates and the uncertainty and unpredictability surrounding the outcome of legal proceedings, actual results may differ materially from any amounts that have been accrued.
Regulatory Compliance
In the ordinary course of our business, we are subject to various laws and regulations. In the opinion of our management, compliance with current laws and regulations will not have a material effect on our results of operations, cash flows or financial condition.
Environmental Compliance
Our operations are subject to stringent and complex laws and regulations pertaining to worker health, safety, and the environment. We are subject to laws and regulations at the federal, state, regional and local levels that relate to air and water quality, hazardous and solid waste management and disposal, and other environmental matters. The cost of planning, designing, constructing and operating our facilities must incorporate compliance with environmental laws and regulations and
safety standards. Failure to comply with these laws and regulations may trigger a variety of administrative, civil and potentially criminal enforcement measures.
During 2019, we experienced produced water releases on our Arrow water gathering system located within the Fort Berthold Indian Reservation in North Dakota. In January 2021, we received a Notice of Violation and Opportunity to Confer from the Environmental Protection Agency (EPA) related to the water releases. In March 2021, we executed a Consent Agreement with the EPA and agreed to pay $0.1 million for penalties related to the water releases. The EPA provided the public a 30-day period to comment on the Consent Agreement and is currently reviewing the comments received. We expect to finalize and settle the Consent Agreement after the EPA completes its review and response, if necessary, to the comments received. We are also substantially complete with all remediation efforts related to the water releases and continue to monitor any remaining impacts. We will continue our remediation efforts to ensure that lands impacted by the produced water releases are fully remediated. In response to the water releases, we removed several miles of gathering pipeline from the system that remained in service and replaced those sections with a pipeline composed of higher capacity material that is more suitable to the environment and climate conditions in the Bakken. The replaced pipeline increased water gathering capacity on the Arrow system and furthers our commitment to sustainability and environmental stewardship in the areas where we live and operate. We believe these events are insurable under our policies. We have not recorded an insurance receivable as of June 30, 2021.
At both June 30, 2021 and December 31, 2020, our accrual of approximately $1.3 million was based on our undiscounted estimate of amounts we will spend on compliance with environmental and other regulations, and any associated fines or penalties. We estimate that our potential liability for reasonably possible outcomes related to our environmental exposures could range from approximately $1.3 million to $1.9 million at June 30, 2021.
Self-Insurance
We utilize third-party insurance subject to varying retention levels of self-insurance, which management considers prudent. Such self-insurance relates to losses and liabilities primarily associated with medical claims, workers’ compensation claims and general, product, vehicle and environmental liability. Losses are accrued based upon management’s estimates of the aggregate liability for claims incurred using certain assumptions followed in the insurance industry and based on past experience. The primary assumption utilized is actuarially determined loss development factors. The loss development factors are based primarily on historical data. Our self insurance reserves could be affected if future claim developments differ from the historical trends. We believe changes in health care costs, trends in health care claims of our employee base, accident frequency and severity and other factors could materially affect the estimate for these liabilities. We continually monitor changes in employee demographics, incident and claim type and evaluate our insurance accruals and adjust our accruals based on our evaluation of these qualitative data points. We are liable for the development of claims for our previously disposed of retail propane operations, provided they were reported prior to August 1, 2012. The following table summarizes CEQP’s and CMLP’s self-insurance reserves at June 30, 2021 and December 31, 2020 (in millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CEQP
|
|
CMLP
|
|
|
June 30,
2021
|
|
December 31, 2020
|
|
June 30,
2021
|
|
December 31, 2020
|
|
Self-insurance reserves(1)
|
$
|
6.6
|
|
|
$
|
7.7
|
|
|
$
|
5.7
|
|
|
$
|
6.7
|
|
(1)At June 30, 2021, CEQP and CMLP classified approximately $4.8 million and $4.1 million, respectively, of these reserves as other long-term liabilities on their consolidated balance sheets.
Guarantees and Indemnifications
We are involved in various joint ventures that sometimes require financial and performance guarantees. In a financial guarantee, we are obligated to make payments if the guaranteed party fails to make payments under, or violates the terms of, the financial arrangement. In a performance guarantee, we provide assurance that the guaranteed party will execute on the terms of the contract. If they do not, we are required to perform on their behalf. We also periodically provide indemnification arrangements related to assets or businesses we have sold. For a further description of our guarantees associated with our joint ventures, see Note 5.
Our potential exposure under guarantee and indemnification arrangements can range from a specified amount to an unlimited dollar amount, depending on the nature of the claim, specificity as to duration, and the particular transaction. As of June 30, 2021 and December 31, 2020, we have no amounts accrued for these guarantees.
Note 10 - Leases
The following table summarizes the balance sheet information related to our operating and finance leases at June 30, 2021 and December 31, 2020 (in millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
June 30,
2021
|
|
December 31, 2020
|
|
Operating Leases
|
|
|
|
|
Operating lease right-of-use assets, net
|
$
|
29.6
|
|
|
$
|
36.8
|
|
|
|
|
|
|
|
Accrued expenses and other liabilities
|
$
|
12.0
|
|
|
$
|
14.7
|
|
|
Other long-term liabilities
|
23.3
|
|
|
28.5
|
|
|
Total operating lease liabilities
|
$
|
35.3
|
|
|
$
|
43.2
|
|
|
Finance Leases
|
|
|
|
|
Property, plant and equipment
|
$
|
12.8
|
|
|
$
|
13.3
|
|
|
Less: accumulated depreciation
|
9.0
|
|
|
7.9
|
|
|
Property, plant and equipment, net
|
$
|
3.8
|
|
|
$
|
5.4
|
|
|
|
|
|
|
|
Accrued expenses and other liabilities
|
$
|
2.7
|
|
|
$
|
2.9
|
|
|
Other long-term liabilities
|
0.7
|
|
|
1.9
|
|
|
Total finance lease liabilities
|
$
|
3.4
|
|
|
$
|
4.8
|
|
Lease expense. Our operating lease expense, net totaled $4.3 million and $7.1 million for the three months ended June 30, 2021 and 2020 and $9.1 million and $14.6 million for the six months ended June 30, 2021 and 2020. Our finance lease expense totaled $0.9 million and $1.1 million for the three months ended June 30, 2021 and 2020 and $1.8 million and $2.2 million for the six months ended June 30, 2021 and 2020.
Note 11 – Partners’ Capital and Non-Controlling Partner
Common and Subordinated Units
In conjunction with the Crestwood Holdings Transactions discussed in Note 1, in March 2021, CEQP acquired approximately 11.5 million CEQP common units and 0.4 million subordinated units of CEQP from Crestwood Holdings for approximately $268 million. CEQP reflected the purchase price as a reduction to its common unitholders’ partners’ capital in its consolidated statement of partners’ capital during the first quarter of 2021. The Crestwood Holdings Transactions resulted in CEQP retiring the common and subordinated units acquired from Crestwood Holdings. Transaction costs related to the Crestwood Holdings Transactions of approximately $7.6 million are reflected as a reduction of CEQP’s common unitholders’ partners’ capital in its consolidated statement of partners’ capital during the first quarter of 2021.
Distributions
Crestwood Equity
Limited Partners. A summary of CEQP’s limited partner quarterly cash distributions for the six months ended June 30, 2021 and 2020 is presented below:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Record Date
|
|
Payment Date
|
|
Per Unit Rate
|
|
Cash Distributions
(in millions)
|
|
2021
|
|
|
|
|
|
|
|
February 5, 2021
|
|
February 12, 2021
|
|
$
|
0.625
|
|
|
$
|
46.4
|
|
|
May 7, 2021
|
|
May 14, 2021
|
|
$
|
0.625
|
|
|
39.3
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
85.7
|
|
|
2020
|
|
|
|
|
|
|
|
February 7, 2020
|
|
February 14, 2020
|
|
$
|
0.625
|
|
|
$
|
45.3
|
|
|
May 8, 2020
|
|
May 15, 2020
|
|
$
|
0.625
|
|
|
45.7
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
91.0
|
|
On July 15, 2021, we declared a distribution of $0.625 per limited partner unit to be paid on August 13, 2021 to unitholders of record on August 6, 2021 with respect to the quarter ended June 30, 2021.
Preferred Unitholders. During the six months ended June 30, 2021 and 2020, we paid cash distributions to our preferred unitholders of approximately $30.0 million in both periods. On July 15, 2021, the board of directors of our general partner authorized a cash distribution to our preferred unitholders of approximately $15.0 million for the quarter ended June 30, 2021.
Crestwood Midstream
During the six months ended June 30, 2021 and 2020, Crestwood Midstream paid cash distributions of $395.4 million and $119.0 million to its partners.
Non-Controlling Partner
Crestwood Niobrara issued preferred interests to CN Jackalope Holdings LLC (Jackalope Holdings), which are reflected as non-controlling interest in subsidiary apart from partners’ capital (i.e., temporary equity) on our consolidated balance sheets. We adjust the carrying amount of our non-controlling interest to its redemption value each period through net income attributable to non-controlling partner.
The following table shows the change in our non-controlling interest in subsidiary at June 30, 2021 and 2020 (in millions):
|
|
|
|
|
|
|
|
|
|
|
Balance at December 31, 2020
|
|
$
|
432.7
|
|
|
|
|
|
|
Distributions to non-controlling partner
|
|
(19.6)
|
|
|
Net income attributable to non-controlling partner
|
|
20.4
|
|
|
Balance at June 30, 2021
|
|
$
|
433.5
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at December 31, 2019
|
|
$
|
426.2
|
|
|
Contributions from non-controlling partner
|
|
2.8
|
|
|
Distributions to non-controlling partner
|
|
(18.5)
|
|
|
Net income attributable to non-controlling partner
|
|
20.1
|
|
|
Balance at June 30, 2020
|
|
$
|
430.6
|
|
In July 2021, Crestwood Niobrara paid cash distributions to Jackalope Holdings of approximately $10.3 million for the quarter ended June 30, 2021.
Other
In February 2021, Crestwood Equity issued 50,000 performance units under the Crestwood Equity Partners LP Long Term Incentive Plan (Crestwood LTIP). The performance units are designed to provide an incentive for continuous employment to certain key employees. The vesting of performance units is subject to the attainment of certain performance and market goals over a three-year period, and entitle a participant to receive common units of Crestwood Equity without payment of an exercise price upon vesting. As of June 30, 2021, we had total unamortized compensation expense of approximately $1.0 million related to these performance units, which we expect will be amortized during the next three years. During the three and six months ended June 30, 2021, we recognized compensation expense of less than $0.1 million and $0.1 million related to these performance units, which is included in general and administrative expenses on our consolidated statements of operations.
Note 12 - Earnings Per Limited Partner Unit
We calculate basic net income per limited partner unit using the two-class method. Our income (loss) is allocated to our common units and other participating securities (i.e., subordinated units) based on the amount of dividends paid in the current period plus an allocation of the undistributed earnings or excess distributions over earnings to the extent that each security participates in income (loss) or excess distributions over income (loss). The dilutive effect of the stock-based compensation performance units is calculated using the treasury stock method which considers the impact to net income or loss attributable to Crestwood Equity Partners and limited partner units from the potential issuance of limited partner units. The dilutive effect of the Preferred units and Crestwood Niobrara preferred units are calculated using the if-converted method which assumes units are converted at the beginning of the period (beginning with their respective issuance date), and the resulting common units are included in the denominator of the diluted net income per common unit calculation for the period being presented. Distributions declared in the period and undeclared distributions that accumulated during the period are added back to the numerator for purposes of the if-converted calculation.
We exclude potentially dilutive securities from the determination of diluted earnings per unit (as well as their related income statement impacts) when their impact is anti-dilutive. The following table summarizes information regarding the weighted-average of common units excluded during the three and six months ended June 30, 2021 and 2020 (in millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Six Months Ended
|
|
|
June 30,
|
|
June 30,
|
|
|
2021
|
|
2020
|
|
2021
|
|
2020
|
|
Preferred units (1)
|
7.1
|
|
|
7.1
|
|
|
7.1
|
|
|
7.1
|
|
|
Crestwood Niobrara’s preferred units(1)
|
3.6
|
|
|
8.2
|
|
|
3.6
|
|
|
8.2
|
|
|
Unit-based compensation performance units(1)
|
0.1
|
|
|
0.2
|
|
|
0.1
|
|
|
0.3
|
|
|
Subordinated units(1)(2)
|
—
|
|
|
0.4
|
|
|
0.2
|
|
|
0.4
|
|
(1)For additional information regarding the potential conversion/redemption of our preferred units and Crestwood Niobrara’s preferred units to CEQP common units, and of our performance units and subordinated units, see our 2020 Annual Report on Form 10-K.
(2)In conjunction with the Crestwood Holdings Transactions, in March 2021, CEQP retired the subordinated units. For additional information regarding the retirement of the subordinated units, see Note 1 and Note 11.
Note 13 – Segments
We have three operating and reportable segments: (i) gathering and processing; (ii) storage and transportation; and (iii) marketing, supply and logistics. Our corporate operations include all general and administrative expenses that are not allocated to our reportable segments. For a further description of our operating and reporting segments, see Note 1. We assess the performance of our operating segments based on EBITDA, which is defined as income before income taxes, plus debt-related costs (interest and debt expense, net and loss on modification/extinguishment of debt) and depreciation, amortization and accretion expense.
Below is a reconciliation of CEQP’s and CMLP’s net loss to EBITDA (in millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CEQP
|
|
CMLP
|
|
|
Three Months Ended
|
|
Six Months Ended
|
|
Three Months Ended
|
|
Six Months Ended
|
|
|
June 30,
|
|
June 30,
|
|
June 30,
|
|
June 30,
|
|
|
2021
|
|
2020
|
|
2021
|
|
2020
|
|
2021
|
|
2020
|
|
2021
|
|
2020
|
|
Net loss
|
$
|
(38.1)
|
|
|
$
|
(24.3)
|
|
|
$
|
(76.4)
|
|
|
$
|
(47.7)
|
|
|
$
|
(38.5)
|
|
|
$
|
(26.8)
|
|
|
$
|
(78.9)
|
|
|
$
|
(52.4)
|
|
|
Add:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest and debt expense, net
|
35.1
|
|
|
34.0
|
|
|
71.1
|
|
|
66.6
|
|
|
35.1
|
|
|
34.0
|
|
|
71.1
|
|
|
66.6
|
|
|
Loss on modification/extinguishment of debt
|
1.2
|
|
|
—
|
|
|
6.7
|
|
|
—
|
|
|
1.2
|
|
|
—
|
|
|
6.7
|
|
|
—
|
|
|
Provision (benefit) for income taxes
|
0.1
|
|
|
(0.1)
|
|
|
—
|
|
|
(0.1)
|
|
|
0.1
|
|
|
(0.2)
|
|
|
—
|
|
|
(0.2)
|
|
|
Depreciation, amortization and accretion
|
58.8
|
|
|
61.0
|
|
|
118.0
|
|
|
117.1
|
|
|
62.2
|
|
|
64.6
|
|
|
125.0
|
|
|
124.2
|
|
|
EBITDA
|
$
|
57.1
|
|
|
$
|
70.6
|
|
|
$
|
119.4
|
|
|
$
|
135.9
|
|
|
$
|
60.1
|
|
|
$
|
71.6
|
|
|
$
|
123.9
|
|
|
$
|
138.2
|
|
The following tables summarize CEQP’s and CMLP’s reportable segment data for the three and six months ended June 30, 2021 and 2020 (in millions). Intersegment revenues included in the following tables are accounted for as arms-length transactions that apply our revenue recognition policy described in our 2020 Annual Report on Form 10-K. Included in earnings (loss) from unconsolidated affiliates, net reflected in the tables below was approximately $48.1 million and $9.5 million of our proportionate share of interest expense, depreciation and amortization expense, goodwill impairments and gains (losses) on long-lived assets, net recorded by our equity investments for the three months ended June 30, 2021 and 2020 and $177.5 million and $23.3 million for the six months ended June 30, 2021 and 2020.
Segment EBITDA Information
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended June 30, 2021
|
|
|
Gathering and Processing
|
|
Storage and Transportation
|
|
Marketing, Supply and Logistics
|
|
Corporate
|
|
Total
|
|
Crestwood Midstream
|
|
|
|
|
|
|
|
|
|
|
Revenues
|
$
|
173.3
|
|
|
$
|
2.0
|
|
|
$
|
754.3
|
|
|
$
|
—
|
|
|
$
|
929.6
|
|
|
Intersegment revenues
|
84.2
|
|
|
3.1
|
|
|
(87.3)
|
|
|
—
|
|
|
—
|
|
|
Costs of product/services sold
|
120.6
|
|
|
(0.4)
|
|
|
677.0
|
|
|
—
|
|
|
797.2
|
|
|
Operations and maintenance expense
|
14.7
|
|
|
1.0
|
|
|
10.1
|
|
|
—
|
|
|
25.8
|
|
|
General and administrative expense
|
—
|
|
|
—
|
|
|
—
|
|
|
19.7
|
|
|
19.7
|
|
|
Gain on long-lived assets, net
|
0.3
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
0.3
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Earnings (loss) from unconsolidated affiliates, net
|
1.0
|
|
|
(28.1)
|
|
|
—
|
|
|
—
|
|
|
(27.1)
|
|
|
Crestwood Midstream EBITDA
|
$
|
123.5
|
|
|
$
|
(23.6)
|
|
|
$
|
(20.1)
|
|
|
$
|
(19.7)
|
|
|
$
|
60.1
|
|
|
Crestwood Equity
|
|
|
|
|
|
|
|
|
|
|
General and administrative expense
|
—
|
|
|
—
|
|
|
—
|
|
|
3.1
|
|
|
3.1
|
|
|
Other income, net
|
—
|
|
|
—
|
|
|
—
|
|
|
0.1
|
|
|
0.1
|
|
|
Crestwood Equity EBITDA
|
$
|
123.5
|
|
|
$
|
(23.6)
|
|
|
$
|
(20.1)
|
|
|
$
|
(22.7)
|
|
|
$
|
57.1
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended June 30, 2020
|
|
|
Gathering and Processing
|
|
Storage and Transportation
|
|
Marketing, Supply and Logistics
|
|
Corporate
|
|
Total
|
|
Crestwood Midstream
|
|
|
|
|
|
|
|
|
|
|
Revenues
|
$
|
114.5
|
|
|
$
|
3.1
|
|
|
$
|
235.1
|
|
|
$
|
—
|
|
|
$
|
352.7
|
|
|
Intersegment revenues
|
14.3
|
|
|
2.4
|
|
|
(16.7)
|
|
|
—
|
|
|
—
|
|
|
Costs of product/services sold
|
21.3
|
|
|
0.1
|
|
|
204.3
|
|
|
—
|
|
|
225.7
|
|
|
Operations and maintenance expense
|
19.3
|
|
|
0.7
|
|
|
11.6
|
|
|
—
|
|
|
31.6
|
|
|
General and administrative expense
|
—
|
|
|
—
|
|
|
—
|
|
|
28.4
|
|
|
28.4
|
|
|
Loss on long-lived assets, net
|
(3.6)
|
|
|
—
|
|
|
(0.2)
|
|
|
—
|
|
|
(3.8)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Earnings (loss) from unconsolidated affiliates, net
|
(1.0)
|
|
|
9.4
|
|
|
—
|
|
|
—
|
|
|
8.4
|
|
|
Crestwood Midstream EBITDA
|
$
|
83.6
|
|
|
$
|
14.1
|
|
|
$
|
2.3
|
|
|
$
|
(28.4)
|
|
|
$
|
71.6
|
|
|
Crestwood Equity
|
|
|
|
|
|
|
|
|
|
|
General and administrative expense
|
—
|
|
|
—
|
|
|
—
|
|
|
1.1
|
|
|
1.1
|
|
|
Other income, net
|
—
|
|
|
—
|
|
|
—
|
|
|
0.1
|
|
|
0.1
|
|
|
Crestwood Equity EBITDA
|
$
|
83.6
|
|
|
$
|
14.1
|
|
|
$
|
2.3
|
|
|
$
|
(29.4)
|
|
|
$
|
70.6
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended June 30, 2021
|
|
|
Gathering and Processing
|
|
Storage and Transportation
|
|
Marketing, Supply and Logistics
|
|
Corporate
|
|
Total
|
|
Crestwood Midstream
|
|
|
|
|
|
|
|
|
|
|
Revenues
|
$
|
327.7
|
|
|
$
|
4.0
|
|
|
$
|
1,630.6
|
|
|
$
|
—
|
|
|
$
|
1,962.3
|
|
|
Intersegment revenues
|
189.5
|
|
|
5.5
|
|
|
(195.0)
|
|
|
—
|
|
|
—
|
|
|
Costs of product/services sold
|
237.1
|
|
|
—
|
|
|
1,373.9
|
|
|
—
|
|
|
1,611.0
|
|
|
Operations and maintenance expense
|
36.1
|
|
|
1.6
|
|
|
20.9
|
|
|
—
|
|
|
58.6
|
|
|
General and administrative expense
|
—
|
|
|
—
|
|
|
—
|
|
|
36.9
|
|
|
36.9
|
|
|
Gain (loss) on long-lived assets, net
|
(1.2)
|
|
|
—
|
|
|
0.1
|
|
|
—
|
|
|
(1.1)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Earnings (loss) from unconsolidated affiliates, net
|
0.2
|
|
|
(131.0)
|
|
|
—
|
|
|
—
|
|
|
(130.8)
|
|
|
Crestwood Midstream EBITDA
|
$
|
243.0
|
|
|
$
|
(123.1)
|
|
|
$
|
40.9
|
|
|
$
|
(36.9)
|
|
|
$
|
123.9
|
|
|
Crestwood Equity
|
|
|
|
|
|
|
|
|
|
|
General and administrative expense
|
—
|
|
|
—
|
|
|
—
|
|
|
4.6
|
|
|
4.6
|
|
|
Other income, net
|
—
|
|
|
—
|
|
|
—
|
|
|
0.1
|
|
|
0.1
|
|
|
Crestwood Equity EBITDA
|
$
|
243.0
|
|
|
$
|
(123.1)
|
|
|
$
|
40.9
|
|
|
$
|
(41.4)
|
|
|
$
|
119.4
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended June 30, 2020
|
|
|
Gathering and Processing
|
|
Storage and Transportation
|
|
Marketing, Supply and Logistics
|
|
Corporate
|
|
Total
|
|
Crestwood Midstream
|
|
|
|
|
|
|
|
|
|
|
Revenues
|
$
|
329.4
|
|
|
$
|
6.6
|
|
|
$
|
744.6
|
|
|
$
|
—
|
|
|
$
|
1,080.6
|
|
|
Intersegment revenues
|
54.3
|
|
|
5.0
|
|
|
(59.3)
|
|
|
—
|
|
|
—
|
|
|
Costs of product/services sold
|
129.6
|
|
|
0.3
|
|
|
630.2
|
|
|
—
|
|
|
760.1
|
|
|
Operations and maintenance expense
|
46.3
|
|
|
2.1
|
|
|
20.8
|
|
|
—
|
|
|
69.2
|
|
|
General and administrative expense
|
—
|
|
|
—
|
|
|
—
|
|
|
41.9
|
|
|
41.9
|
|
|
Loss on long-lived assets, net
|
(4.6)
|
|
|
—
|
|
|
(0.2)
|
|
|
—
|
|
|
(4.8)
|
|
|
Goodwill impairment
|
(80.3)
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(80.3)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Earnings (loss) from unconsolidated affiliates, net
|
(0.2)
|
|
|
14.1
|
|
|
—
|
|
|
—
|
|
|
13.9
|
|
|
Crestwood Midstream EBITDA
|
$
|
122.7
|
|
|
$
|
23.3
|
|
|
$
|
34.1
|
|
|
$
|
(41.9)
|
|
|
$
|
138.2
|
|
|
Crestwood Equity
|
|
|
|
|
|
|
|
|
|
|
General and administrative expense
|
—
|
|
|
—
|
|
|
—
|
|
|
2.5
|
|
|
2.5
|
|
|
Other income, net
|
—
|
|
|
—
|
|
|
—
|
|
|
0.2
|
|
|
0.2
|
|
|
Crestwood Equity EBITDA
|
$
|
122.7
|
|
|
$
|
23.3
|
|
|
$
|
34.1
|
|
|
$
|
(44.2)
|
|
|
$
|
135.9
|
|
Other Segment Information
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CEQP
|
|
CMLP
|
|
|
June 30, 2021
|
|
December 31, 2020
|
|
June 30, 2021
|
|
December 31, 2020
|
|
Total Assets
|
|
|
|
|
|
|
|
|
Gathering and Processing
|
$
|
3,402.2
|
|
|
$
|
3,464.6
|
|
|
$
|
3,540.2
|
|
|
$
|
3,609.7
|
|
|
Storage and Transportation
|
781.4
|
|
|
944.6
|
|
|
781.4
|
|
|
944.6
|
|
|
Marketing, Supply and Logistics
|
918.2
|
|
|
805.0
|
|
|
918.2
|
|
|
805.0
|
|
|
Corporate
|
28.4
|
|
|
29.5
|
|
|
24.6
|
|
|
26.2
|
|
|
Total Assets
|
$
|
5,130.2
|
|
|
$
|
5,243.7
|
|
|
$
|
5,264.4
|
|
|
$
|
5,385.5
|
|
Note 14 - Revenues
Contract Assets and Contract Liabilities
Our contract assets and contract liabilities are reported in a net position on a contract-by-contract basis at the end of each reporting period. Our receivables related to our revenue contracts accounted for under Accounting Standards Update 2014-09, Revenue from Contracts with Customers (Topic 606) totaled $298.4 million and $219.9 million for both CEQP and CMLP at June 30, 2021 and December 31, 2020, and are included in accounts receivable on our consolidated balance sheets. Our contract assets are included in other non-current assets on our consolidated balance sheets. Our contract liabilities primarily consist of current and non-current deferred revenues. On our consolidated balance sheets, our current deferred revenues are included in accrued expenses and other liabilities and our non-current deferred revenues are included in other long-term liabilities. The majority of revenues associated with our deferred revenues is expected to be recognized as the performance obligations under the related contracts are satisfied over the next 16 years.
The following table summarizes our contract assets and contract liabilities (in millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
June 30, 2021
|
|
December 31, 2020
|
|
Contract assets (non-current)
|
|
$
|
1.5
|
|
|
$
|
1.0
|
|
|
Contract liabilities (current)(1)
|
|
$
|
10.5
|
|
|
$
|
10.3
|
|
|
Contract liabilities (non-current)(1)
|
|
$
|
179.2
|
|
|
$
|
172.2
|
|
(1)During the three and six months ended June 30, 2021, we recognized revenues of approximately $3.3 million and $6.4 million that were previously included in contract liabilities at December 31, 2020. The remaining change in our contract liabilities during the three and six months ended June 30, 2021, related to capital reimbursements associated with our revenue contracts and revenue deferrals associated with our contracts with increasing (decreasing) rates.
The following table summarizes the transaction price allocated to our remaining performance obligations under certain contracts that have not been recognized as of June 30, 2021 (in millions):
|
|
|
|
|
|
|
|
Remainder of 2021
|
$
|
46.5
|
|
|
2022
|
76.0
|
|
|
2023
|
52.6
|
|
|
2024
|
31.7
|
|
|
Total
|
$
|
206.8
|
|
Our remaining performance obligations presented in the table above exclude estimates of variable rate escalation clauses in our contracts with customers, and is generally limited to fixed-fee and percentage-of-proceeds service contracts which have fixed pricing and minimum volume terms and conditions. Our remaining performance obligations generally exclude, based on the following practical expedients that we elected to apply, disclosures for (i) variable consideration allocated to a wholly-unsatisfied promise to transfer a distinct service that forms part of the identified single performance obligation; (ii) unsatisfied performance obligations where the contract term is one year or less; and (iii) contracts for which we recognize revenues as amounts are invoiced.
Disaggregation of Revenues
The following tables summarize our revenues from contracts with customers disaggregated by type of product/service sold and by commodity type for each of our segments for the three and six months ended June 30, 2021 and 2020 (in millions). We believe this summary best depicts how the nature, amount, timing and uncertainty of our revenues and cash flows are affected by economic factors. Our non-Topic 606 revenues presented in the tables below primarily represents revenues related to our commodity-based derivatives.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended June 30, 2021
|
|
|
Gathering and Processing
|
|
Storage and Transportation
|
|
Marketing, Supply and Logistics
|
|
Intersegment Elimination
|
|
Total
|
|
Topic 606 revenues
|
|
|
|
|
|
|
|
|
|
|
Gathering
|
|
|
|
|
|
|
|
|
|
|
Natural gas
|
$
|
33.3
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
33.3
|
|
|
Crude oil
|
18.4
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
18.4
|
|
|
Water
|
22.7
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
22.7
|
|
|
Processing
|
|
|
|
|
|
|
|
|
|
|
Natural gas
|
7.3
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
7.3
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Compression
|
|
|
|
|
|
|
|
|
|
|
Natural gas
|
3.7
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
3.7
|
|
|
Storage
|
|
|
|
|
|
|
|
|
|
|
Crude oil
|
0.1
|
|
|
0.9
|
|
|
—
|
|
|
(0.9)
|
|
|
0.1
|
|
|
NGLs
|
—
|
|
|
—
|
|
|
2.4
|
|
|
—
|
|
|
2.4
|
|
|
Pipeline
|
|
|
|
|
|
|
|
|
|
|
Crude oil
|
—
|
|
|
1.7
|
|
|
—
|
|
|
(1.1)
|
|
|
0.6
|
|
|
NGLs
|
—
|
|
|
—
|
|
|
0.1
|
|
|
—
|
|
|
0.1
|
|
|
Transportation
|
|
|
|
|
|
|
|
|
|
|
Crude oil
|
0.4
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
0.4
|
|
|
NGLs
|
—
|
|
|
—
|
|
|
4.2
|
|
|
—
|
|
|
4.2
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Rail Loading
|
|
|
|
|
|
|
|
|
|
|
Crude oil
|
—
|
|
|
2.3
|
|
|
—
|
|
|
(1.1)
|
|
|
1.2
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Product Sales
|
|
|
|
|
|
|
|
|
|
|
Natural gas
|
26.8
|
|
|
—
|
|
|
44.3
|
|
|
(26.8)
|
|
|
44.3
|
|
|
Crude oil
|
101.7
|
|
|
—
|
|
|
344.4
|
|
|
(14.7)
|
|
|
431.4
|
|
|
NGLs
|
42.9
|
|
|
—
|
|
|
304.8
|
|
|
(42.6)
|
|
|
305.1
|
|
|
Other
|
—
|
|
|
0.2
|
|
|
0.6
|
|
|
(0.1)
|
|
|
0.7
|
|
|
Total Topic 606 revenues
|
257.3
|
|
|
5.1
|
|
|
700.8
|
|
|
(87.3)
|
|
|
875.9
|
|
|
Non-Topic 606 revenues
|
0.2
|
|
|
—
|
|
|
53.5
|
|
|
—
|
|
|
53.7
|
|
|
Total revenues
|
$
|
257.5
|
|
|
$
|
5.1
|
|
|
$
|
754.3
|
|
|
$
|
(87.3)
|
|
|
$
|
929.6
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended June 30, 2020
|
|
|
Gathering and Processing
|
|
Storage and Transportation
|
|
Marketing, Supply and Logistics
|
|
Intersegment Elimination
|
|
Total
|
|
Topic 606 revenues
|
|
|
|
|
|
|
|
|
|
|
Gathering
|
|
|
|
|
|
|
|
|
|
|
Natural gas
|
$
|
33.2
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
33.2
|
|
|
Crude oil
|
17.9
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
17.9
|
|
|
Water
|
18.3
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
18.3
|
|
|
Processing
|
|
|
|
|
|
|
|
|
|
|
Natural gas
|
7.1
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
7.1
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Compression
|
|
|
|
|
|
|
|
|
|
|
Natural gas
|
5.7
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
5.7
|
|
|
Storage
|
|
|
|
|
|
|
|
|
|
|
Crude oil
|
0.4
|
|
|
1.1
|
|
|
—
|
|
|
(0.8)
|
|
|
0.7
|
|
|
NGLs
|
—
|
|
|
—
|
|
|
3.6
|
|
|
—
|
|
|
3.6
|
|
|
Pipeline
|
|
|
|
|
|
|
|
|
|
|
Crude oil
|
—
|
|
|
1.3
|
|
|
—
|
|
|
(0.4)
|
|
|
0.9
|
|
|
NGLs
|
—
|
|
|
—
|
|
|
0.2
|
|
|
—
|
|
|
0.2
|
|
|
Transportation
|
|
|
|
|
|
|
|
|
|
|
Crude oil
|
1.5
|
|
|
—
|
|
|
0.3
|
|
|
—
|
|
|
1.8
|
|
|
NGLs
|
—
|
|
|
—
|
|
|
2.6
|
|
|
—
|
|
|
2.6
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Rail Loading
|
|
|
|
|
|
|
|
|
|
|
Crude oil
|
—
|
|
|
2.9
|
|
|
—
|
|
|
(1.2)
|
|
|
1.7
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Product Sales
|
|
|
|
|
|
|
|
|
|
|
Natural gas
|
6.9
|
|
|
—
|
|
|
15.5
|
|
|
(6.8)
|
|
|
15.6
|
|
|
Crude oil
|
34.8
|
|
|
—
|
|
|
102.0
|
|
|
(7.1)
|
|
|
129.7
|
|
|
NGLs
|
3.0
|
|
|
—
|
|
|
92.4
|
|
|
(0.3)
|
|
|
95.1
|
|
|
Other
|
—
|
|
|
0.2
|
|
|
0.2
|
|
|
(0.1)
|
|
|
0.3
|
|
|
Total Topic 606 revenues
|
128.8
|
|
|
5.5
|
|
|
216.8
|
|
|
(16.7)
|
|
|
334.4
|
|
|
Non-Topic 606 revenues
|
—
|
|
|
—
|
|
|
18.3
|
|
|
—
|
|
|
18.3
|
|
|
Total revenues
|
$
|
128.8
|
|
|
$
|
5.5
|
|
|
$
|
235.1
|
|
|
$
|
(16.7)
|
|
|
$
|
352.7
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended June 30, 2021
|
|
|
Gathering and Processing
|
|
Storage and Transportation
|
|
Marketing, Supply and Logistics
|
|
Intersegment Elimination
|
|
Total
|
|
|
|
|
|
|
|
|
|
|
|
|
Topic 606 revenues
|
|
|
|
|
|
|
|
|
|
|
Gathering
|
|
|
|
|
|
|
|
|
|
|
Natural gas
|
$
|
64.7
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
64.7
|
|
|
Crude oil
|
39.1
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
39.1
|
|
|
Water
|
44.7
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
44.7
|
|
|
Processing
|
|
|
|
|
|
|
|
|
|
|
Natural gas
|
14.3
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
14.3
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Compression
|
|
|
|
|
|
|
|
|
|
|
Natural gas
|
8.4
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
8.4
|
|
|
Storage
|
|
|
|
|
|
|
|
|
|
|
Crude oil
|
0.2
|
|
|
1.5
|
|
|
—
|
|
|
(1.4)
|
|
|
0.3
|
|
|
NGLs
|
—
|
|
|
—
|
|
|
6.1
|
|
|
—
|
|
|
6.1
|
|
|
Pipeline
|
|
|
|
|
|
|
|
|
|
|
Crude oil
|
—
|
|
|
3.0
|
|
|
—
|
|
|
(1.6)
|
|
|
1.4
|
|
|
NGLs
|
—
|
|
|
—
|
|
|
0.1
|
|
|
—
|
|
|
0.1
|
|
|
Transportation
|
|
|
|
|
|
|
|
|
|
|
Crude oil
|
1.1
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
1.1
|
|
|
NGLs
|
—
|
|
|
—
|
|
|
8.4
|
|
|
—
|
|
|
8.4
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Rail Loading
|
|
|
|
|
|
|
|
|
|
|
Crude oil
|
—
|
|
|
4.6
|
|
|
—
|
|
|
(2.4)
|
|
|
2.2
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Product Sales
|
|
|
|
|
|
|
|
|
|
|
Natural gas
|
69.6
|
|
|
—
|
|
|
139.9
|
|
|
(69.0)
|
|
|
140.5
|
|
|
Crude oil
|
191.7
|
|
|
—
|
|
|
595.6
|
|
|
(37.4)
|
|
|
749.9
|
|
|
NGLs
|
83.2
|
|
|
—
|
|
|
710.8
|
|
|
(82.9)
|
|
|
711.1
|
|
|
Other
|
—
|
|
|
0.4
|
|
|
0.8
|
|
|
(0.3)
|
|
|
0.9
|
|
|
Total Topic 606 revenues
|
517.0
|
|
|
9.5
|
|
|
1,461.7
|
|
|
(195.0)
|
|
|
1,793.2
|
|
|
Non-Topic 606 revenues
|
0.2
|
|
|
—
|
|
|
168.9
|
|
|
—
|
|
|
169.1
|
|
|
Total revenues
|
$
|
517.2
|
|
|
$
|
9.5
|
|
|
$
|
1,630.6
|
|
|
$
|
(195.0)
|
|
|
$
|
1,962.3
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended June 30, 2020
|
|
|
Gathering and Processing
|
|
Storage and Transportation
|
|
Marketing, Supply and Logistics
|
|
Intersegment Elimination
|
|
Total
|
|
|
|
|
|
|
|
|
|
|
|
|
Topic 606 revenues
|
|
|
|
|
|
|
|
|
|
|
Gathering
|
|
|
|
|
|
|
|
|
|
|
Natural gas
|
$
|
77.0
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
77.0
|
|
|
Crude oil
|
44.4
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
44.4
|
|
|
Water
|
41.3
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
41.3
|
|
|
Processing
|
|
|
|
|
|
|
|
|
|
|
Natural gas
|
17.3
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
17.3
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Compression
|
|
|
|
|
|
|
|
|
|
|
Natural gas
|
12.0
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
12.0
|
|
|
Storage
|
|
|
|
|
|
|
|
|
|
|
Crude oil
|
0.9
|
|
|
1.7
|
|
|
—
|
|
|
(1.2)
|
|
|
1.4
|
|
|
NGLs
|
—
|
|
|
—
|
|
|
5.2
|
|
|
—
|
|
|
5.2
|
|
|
Pipeline
|
|
|
|
|
|
|
|
|
|
|
Crude oil
|
—
|
|
|
2.9
|
|
|
—
|
|
|
(0.9)
|
|
|
2.0
|
|
|
NGLs
|
—
|
|
|
—
|
|
|
0.2
|
|
|
—
|
|
|
0.2
|
|
|
Transportation
|
|
|
|
|
|
|
|
|
|
|
Crude oil
|
3.5
|
|
|
—
|
|
|
1.9
|
|
|
—
|
|
|
5.4
|
|
|
NGLs
|
—
|
|
|
—
|
|
|
4.3
|
|
|
—
|
|
|
4.3
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Rail Loading
|
|
|
|
|
|
|
|
|
|
|
Crude oil
|
—
|
|
|
6.3
|
|
|
—
|
|
|
(2.6)
|
|
|
3.7
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Product Sales
|
|
|
|
|
|
|
|
|
|
|
Natural gas
|
18.9
|
|
|
—
|
|
|
33.8
|
|
|
(18.5)
|
|
|
34.2
|
|
|
Crude oil
|
155.9
|
|
|
—
|
|
|
352.2
|
|
|
(23.4)
|
|
|
484.7
|
|
|
NGLs
|
12.5
|
|
|
—
|
|
|
252.7
|
|
|
(12.2)
|
|
|
253.0
|
|
|
Other
|
—
|
|
|
0.7
|
|
|
0.7
|
|
|
(0.5)
|
|
|
0.9
|
|
|
Total Topic 606 revenues
|
383.7
|
|
|
11.6
|
|
|
651.0
|
|
|
(59.3)
|
|
|
987.0
|
|
|
Non-Topic 606 revenues
|
—
|
|
|
—
|
|
|
93.6
|
|
|
—
|
|
|
93.6
|
|
|
Total revenues
|
$
|
383.7
|
|
|
$
|
11.6
|
|
|
$
|
744.6
|
|
|
$
|
(59.3)
|
|
|
$
|
1,080.6
|
|
Note 15 – Related Party Transactions
Crestwood Holdings indirectly owns both CEQP’s and CMLP’s general partner. The affiliates of Crestwood Holdings and its owners are considered CEQP’s and CMLP’s related parties. We enter into transactions with our affiliates within the ordinary course of business, including product purchases, marketing services and various operating agreements. We also enter into transactions with our affiliates related to services provided on our expansion projects. During the six months ended June 30, 2021 and 2020, we paid approximately $0.5 million and $2.9 million of capital expenditures to Applied Consultants, Inc., an affiliate of Crestwood Holdings.
The following table shows transactions with our affiliates which are reflected in our consolidated statements of operations (in millions). For a further description of our related party agreements, see our 2020 Annual Report on Form 10-K.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Six Months Ended
|
|
|
June 30,
|
|
June 30,
|
|
|
2021
|
|
2020
|
|
2021
|
|
2020
|
|
Revenues at CEQP and CMLP(1)
|
$
|
13.2
|
|
|
$
|
7.5
|
|
|
$
|
18.1
|
|
|
$
|
15.0
|
|
|
Costs of product/services sold at CEQP and CMLP(2)
|
$
|
25.4
|
|
|
$
|
3.6
|
|
|
$
|
66.5
|
|
|
$
|
6.8
|
|
|
Operations and maintenance expenses charged by CEQP and CMLP(3)
|
$
|
6.0
|
|
|
$
|
5.5
|
|
|
$
|
11.7
|
|
|
$
|
11.7
|
|
|
General and administrative expenses charged by CEQP to CMLP, net(4)
|
$
|
6.6
|
|
|
$
|
10.9
|
|
|
$
|
12.5
|
|
|
$
|
18.0
|
|
|
General and administrative expenses at CEQP charged to (from) Crestwood Holdings, net(5)
|
$
|
—
|
|
|
$
|
(1.5)
|
|
|
$
|
4.8
|
|
|
$
|
11.3
|
|
(1)Primarily relates to the sale of NGLs to a subsidiary of Crestwood Permian.
(2)Includes (i) $14.8 million and $45.1 million during the three and six months ended June 30, 2021 and $3.2 million and $6.4 million during the three and six months ended June 30, 2020 related to purchases of natural gas and NGLs from a subsidiary of Crestwood Permian; (ii) $0.3 million and $11.1 million during the three and six months ended June 30, 2021 and $0.1 million during both the three and six months ended June 30, 2020 related to purchases of natural gas from a subsidiary of Tres Holdings and (iii) $10.3 million during both the three and six months ended June 30, 2021 and $0.3 million during both the three and six months ended June 30, 2020 related to purchases of NGLs from Ascent Resources - Utica, LLC, an affiliate of Crestwood Holdings.
(3)We have operating agreements with certain of our unconsolidated affiliates pursuant to which we charge them operations and maintenance expenses in accordance with their respective agreements, and these charges are reflected as a reduction of operations and maintenance expenses in our consolidated statements of operations. During the three and six months ended June 30, 2021, we charged $1.6 million and $3.3 million to Stagecoach Gas, $1.2 million and $2.4 million to Tres Holdings, and $3.2 million and $6.0 million to Crestwood Permian. During the three and six months ended June 30, 2020, we charged $1.6 million and $3.3 million to Stagecoach Gas, $1.1 million and $2.2 million to Tres Holdings, and $2.8 million and $6.2 million to Crestwood Permian.
(4)Includes $7.6 million and $14.5 million of unit-based compensation charges allocated from CEQP to CMLP for the three and six months ended June 30, 2021 and $11.9 million and $20.1 million for the three and six months ended June 30, 2020. In addition, includes $1.0 million and $2.0 million of CMLP’s general and administrative costs allocated to CEQP during the three and six months ended June 30, 2021 and $1.0 million and $2.1 million during the three and six months ended June 30, 2020.
(5)Includes $1.7 million of unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the three months ended June 30, 2020. Also includes a $4.6 million and a $10.9 million reduction of unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP during the six months ended June 30, 2021 and 2020. During the three months ended June 30, 2021, there were no unit-based compensation charges allocated from Crestwood Holdings to CEQP and CMLP. CEQP allocates a portion of its general and administrative costs to Crestwood Holdings and during the six months ended June 30, 2021, CEQP allocated $0.2 million of it’s general and administrative costs to Crestwood Holdings and approximately $0.2 million and $0.4 million of costs were allocated to Crestwood Holdings during the three and six months ended June 30, 2020. During the three months ended June 30, 2021, CEQP did not allocate any general and administrative costs to Crestwood Holdings.
The following table shows accounts receivable and accounts payable with our affiliates (in millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
June 30,
2021
|
|
December 31,
2020
|
|
Accounts receivable at CEQP and CMLP
|
$
|
7.0
|
|
|
$
|
2.5
|
|
|
Accounts payable at CEQP(1)
|
$
|
11.3
|
|
|
$
|
7.5
|
|
|
Accounts payable at CMLP
|
$
|
11.3
|
|
|
$
|
5.0
|
|
(1)In conjunction with the Crestwood Holdings Transactions discussed in Note 1, CEQP eliminated approximately $2.4 million of accounts payable to Crestwood Holdings which is reflected as an increase to CEQP’s common unitholders’ partners’ capital in its consolidated statement of partners’ capital during the first quarter of 2021.