# EDGAR Filing Document

**Accession Number:** 0001136352
**File Stem:** 0001193125-23-043179
**Filing Date:** 2023-2
**Character Count:** 59413
**Document Hash:** 25077f28e2c9572512e874e4e5a07adc
**Contains OCR:** False
**Source Format:** 

## Filing Content

## Filing Summary
**0001193125-23-043179.hdr.sgml**: 20230221

**ACCESSION NUMBER**: 0001193125-23-043179

**CONFORMED SUBMISSION TYPE**: 8-K

**PUBLIC DOCUMENT COUNT**: 15

**CONFORMED PERIOD OF REPORT**: 20230221

**ITEM INFORMATION**: Results of Operations and Financial Condition

**ITEM INFORMATION**: Regulation FD Disclosure

**ITEM INFORMATION**: Financial Statements and Exhibits

**FILED AS OF DATE**: 20230221

**DATE AS OF CHANGE**: 20230221

**FILER**: 

**COMPANY DATA:**
- **COMPANY CONFORMED NAME:** Crestwood Equity Partners LP
- **CENTRAL INDEX KEY:** 0001136352
- **STANDARD INDUSTRIAL CLASSIFICATION:** NATURAL GAS TRANSMISSION & DISTRIBUTION [4923]
- **IRS NUMBER:** 431918951
- **STATE OF INCORPORATION:** DE
- **FISCAL YEAR END:** 1231

**FILING VALUES:**
- **FORM TYPE:** 8-K
- **SEC ACT:** 1934 Act
- **SEC FILE NUMBER:** 001-34664
- **FILM NUMBER:** 23646162

**BUSINESS ADDRESS:**
- **STREET 1:** 811 MAIN STREET
- **STREET 2:** SUITE 3400
- **CITY:** HOUSTON
- **STATE:** TX
- **ZIP:** 77002
- **BUSINESS PHONE:** 832-519-2200

**MAIL ADDRESS:**
- **STREET 1:** 811 MAIN STREET
- **STREET 2:** SUITE 3400
- **CITY:** HOUSTON
- **STATE:** TX
- **ZIP:** 77002

**FORMER COMPANY:**
- **FORMER CONFORMED NAME:** INERGY L P
- **DATE OF NAME CHANGE:** 20010307

?xml version="1.0" encoding="utf-8" ? 8-K

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### UNITED STATES

### SECURITIES AND EXCHANGE COMMISSION

#### Washington, D.C. 20549

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### FORM 8-K

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#### CURRENT REPORT

#### Pursuant to Section 13 or 15(d)

#### of the Securities Exchange Act of 1934

#### Date of report (Date of earliest event reported): February 21, 2023

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## CRESTWOOD EQUITY PARTNERS LP

#### (Exact name of Registrant as specified in its charter)

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| | | |
|:---|:---|:---|
| **DELAWARE** | **001-34664** | **43-1918951** |
| **(State of incorporation<br>or organization)** | **(Commission<br>file number)** | **(I.R.S. employer<br>identification number)** |

---

#### 811 Main St., Suite 3400

#### Houston, TX 77002

#### (Address of principal executive offices) (Zip code)

#### Registrant's telephone number, including area code: (832) 519-2200

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Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

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

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

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

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

#### Securities Registered pursuant to Section 12(b) of the Act

---

| | | |
|:---|:---|:---|
| **Tile of each class** | **Trading**<br> **Symbol(s)** | **Name of each exchange**<br> **on which registered** |
| Common units representing limited partner interests | CEQP | New York Stock Exchange |
| Preferred Units representing limited partner interests | CEQP-P | New York Stock Exchange |

---

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

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

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| | |
|:---|:---|
| **Item 2.02** | **Results of Operations and Financial Condition**  |

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On February 21, 2023, Crestwood Equity Partners LP ("CEQP") issued a press release reporting its financial results for the three months ended December 31, 2022. The press release is included herewith as Exhibit 99.1 and is incorporated herein by reference.

In accordance with General Instruction B.2 of Form 8-K, the information furnished pursuant to Items 2.02 and 7.01 shall not be deemed to be "filed" for purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the "Exchange Act"), or otherwise subject to the liabilities of that section, nor shall such information be deemed incorporated by reference in any filing under the Securities Act or the Exchange Act, except as shall be expressly set forth by specific reference in such a filing. The information furnished pursuant to Items 2.02 and 7.01 shall not be deemed an admission as to the materiality of any information in this report on Form 8-K that is required to be disclosed solely to satisfy the requirements of Regulation FD.

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| | |
|:---|:---|
| **Item 7.01** | **Regulation FD Disclosure**  |

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See "Item 2.02. Results of Operations and Financial Condition" above.

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| | |
|:---|:---|
| **Item 9.01** | **Financial Statements and Exhibits**  |

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&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(d) Exhibits.

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| | |
|:---|:---|
| Exhibit<br> Number | Description |
| 99.1 | [Press Release dated February 21, 2023](d443099dex991.htm) |
| 104 | Cover Page Interactive Data File (embedded within the Inline XBRL document) |

---

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#### SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

---

| | | |
|:---|:---|:---|
|  | CRESTWOOD EQITY PARTNERS LP | CRESTWOOD EQITY PARTNERS LP |
|  | By: | Crestwood Equity GP LLC, its General Partner, |
| Date: February 21, 2023 | By: | /s/ Michael K. Post |
|  |  | Michael K. Post |
|  |  | Vice President, Associate General Counsel & Corporate Secretary |

---

## Exhibit 99.1

**Exhibit 99.1** 

---

| | |
|:---|:---|
| ![LOGO](g443099dsp1.jpg) | ***News Release***<br> **CRESTWOOD EQUITY PARTNERS LP**<br> 811 Main Street, Suite 3400<br> Houston, TX 77002<br> www.crestwoodlp.com |

---

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**Crestwood Announces Fourth Quarter 2022 Financial and Operating Results, the Divestiture of Tres Palacios for $335 Million, and Provides 2023 Guidance and Outlook** 

*Delivered full-year 2022 net income of $72.5 million and Adjusted EBITDA<sup>1</sup> of $762.1 million, a 27% increase year-over-year, driven by expanded operations in the Williston and Delaware Basins from the Oasis Midstream, Sendero Midstream, and CPJV acquisitions offset by the Barnett and Marcellus divestitures; efficient integration of acquired assets led to cost savings and commercial synergies offset by extreme weather events and producer development delays in fourth quarter 2022* 

*Divestiture of Tres Palacios for $335 million; Crestwood's 50% interest yields $167.5 million of cash proceeds which will be used for debt paydown and to accelerate leverage reduction; non-core asset sale at a significant premium to current market multiples largely completes Crestwood's midstream portfolio realignment with a focus on core G&P areas* 

*Expect 2023 Adjusted EBITDA of $780 million to $860 million and growth capital investment of $135 million to $155 million, driving positive free cash flow after distributions of approximately $50 million at the midpoint* 

*2023 capital projects to include gathering system expansions and new supply connections from recent acquisitions; free cash flow allocation priorities focus on debt paydown and enhancing balance sheet strength in 2023* 

**HOUSTON, TEXAS, February 21, 2023 –** Crestwood Equity Partners LP (NYSE: CEQP) ("Crestwood") reported today its financial and operating results for the three months ended December 31, 2022.

**Fourth Quarter and Full-Year 2022 Financial Highlights<sup>1</sup>** 

• Fourth quarter 2022 net income of $53.9 million, compared to net income of $78.6 million in fourth
quarter 2021; full-year 2022 net income of $72.5 million, compared to a net loss of $37.4 million in 2021

• Fourth quarter 2022 Adjusted EBITDA of $200.3 million, compared to $149.1 million in the fourth quarter
2021, an increase of 34% year-over-year; full-year Adjusted EBITDA of $762.1 million, compared to $600.1 million in 2021, an increase of 27%

• Fourth quarter 2022 distributable cash flow ("DCF") to common unitholders of $110.8 million,
compared to $91.1 million in the fourth quarter 2021, an increase of 22% year-over-year, resulting in a coverage ratio of 1.6x

• Ended the quarter with approximately $3.4 billion of total debt, including $1.1 billion drawn on the
revolving credit facilities, resulting in a consolidated leverage ratio of 4.2x (4.0x pro forma for the sale of Tres Palacios)

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<sup>1</sup> Please see non-GAAP reconciliation tables included at the end of the press release.

-more-

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**NEWS RELEASE** 

 **Page 2 of 16** 

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• Announced fourth quarter 2022 cash distribution of $0.655 per common unit, or $2.62 per common unit on an
annualized basis, an approximate 5% increase year-over-year, payable on February 14, 2023, to unitholders of record as of February 7, 2023

**Recent Developments** 

• On January 17, 2023, Crestwood Midstream Partners LP ("CMLP"), a wholly owned subsidiary of
Crestwood, issued $600 million of 7.375% senior unsecured notes due 2031. Crestwood used the proceeds of the issuance to repay borrowings on the corporate revolving credit facility and to repay and terminate the Crestwood Permian Basin Holdings
LLC ("CPJV") revolving credit facility. Pro forma for the senior notes issuance, Crestwood has approximately $525 million drawn on its $1.75 billion corporate revolving credit facility.

• On February 20, 2023, Crestwood and Brookfield Infrastructure ("Brookfield") announced that they
entered into an agreement to sell Tres Palacios Gas Storage ("Tres Palacios") for $335 million. Crestwood will receive approximately $168 million for its 50% interest in the storage facility and plans to use all sale proceeds to
reduce borrowings on its revolving credit facility. The transaction is expected to close in the second quarter 2023 subject to customary regulatory approvals.

**Management Commentary** 

"2022 was another transformational year for Crestwood as we continued to realign our midstream portfolio by expanding in the Williston, Delaware, and Powder River Basins, which are highly economic, oil-weighted resource plays, while divesting our Barnett and Marcellus assets which were non-core, gas-weighted, and low-growth. We have continued that strategy with the recent sale of our Tres Palacios natural gas storage facility to reduce debt and improve our balance sheet," commented Robert G. Phillips, Founder, Chairman, and Chief Executive Officer of Crestwood.

"While we are disappointed in last year's operating and financial results due to the impact of severe weather events, upstream consolidation, and oilfield services and labor constraints on producer drilling and development activity, we are excited about current 2023 rig activity and planned customer developments on our G&P assets. Moreover, this year we will be focused on realizing additional merger synergies and further commercialization of our systems, as we continue to integrate and expand the Oasis Midstream and Sendero Midstream assets with a measured capital program to capture the significant supply potential based on years of drilling inventory, which was a key component of the acquisitions last year."

Mr. Phillips continued, "In 2023, our Adjusted EBITDA guidance range of $780 million to $860 million is pro forma for the sale of Tres Palacios and represents 8% year-over-year growth at the midpoint. Our 2023 growth capital program is estimated to be $135 million to $155 million, a reduction of more than 20% from last year, with approximately 90% focused on our Williston and Delaware Basin operations. Based on current producer plans, we expect to connect approximately 260 wells in 2023, an increase of approximately 15% year-over-year. Overall, our financial strategy in 2023 remains focused on operational execution, investments in high returning system expansions, increasing volumes, growing free cash flow, and reducing our outstanding debt."

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Mr. Phillips concluded, "The divestiture of Tres Palacios represents Crestwood's fourth non-core divestiture over the last two years and largely completes our strategic realignment around oil-weighted resource plays. I would like to thank the Tres Palacios employees for their hard work and dedication over the past thirteen years who have done an exceptional job managing this strategic storage asset through various commodity and weather cycles. These divestitures, at highly compelling valuations, have enabled the company to maintain a solid balance sheet while transitioning the portfolio and helping to finance growth in the Williston, Delaware, and Powder River Basins. As a result, Crestwood is a stronger and more resilient company than it was a few years ago, with an impressive producer customer portfolio and a significant inventory of highly economic acreage dedications under long-term contracts, which we think will drive a top-tier yield investment opportunity for our unitholders."

**Fourth Quarter 2022 Results and 2023 Outlook** 

**Gathering and Processing North** 

Gathering and Processing North segment EBITDA totaled $140.8 million in the fourth quarter 2022, compared to $116.5 million in the fourth quarter 2021, an increase of 21% year-over-year. Segment EBITDA increased year-over-year as a result of the contribution from the Oasis Midstream LP ("Oasis Midstream") assets acquired in the Williston Basin and the impact of higher commodity prices on the Arrow system's percent-of-proceeds (POP) contracts.

*Williston Basin* 

During the fourth quarter 2022, crude oil gathering volumes averaged 76 MBbls/d, natural gas gathering volumes averaged 243 MMcf/d, natural gas processing volumes averaged 275 MMcf/d, and produced water gathering volumes averaged 152 MBbls/d. Natural gas gathering, natural gas processing, and produced water gathering volumes increased year-over-year by 72%, 108%, and 67%, respectively, due to expanded operations as a result of the Oasis Midstream acquisition. Producers connected 21 wells across Crestwood's footprint during the fourth quarter, resulting in a full-year total of 86 wells, and have subsequently connected 23 wells in January 2023. Crestwood invested $26 million in the fourth quarter, approximately 90% of which was related to the continued build-out of the western portion of the Rough Rider system to service Chord Energy Inc. (NASDAQ: CHRD) ("Chord") dedicated acreage.

In 2023, Crestwood expects to connect 115 to 125 wells across the Arrow and Rough Rider systems based on current producer drilling and completion schedules. Crestwood's capital investments in the Williston Basin, approximately 50% of the company's 2023 capital program, will include the continued buildout of a three-product gathering system for Chord's Painted Woods and City of Williston acreage as well as smaller system expansions and compression projects to support new volumes across the Arrow and Rough Rider assets. Crestwood anticipates an average of four to five rigs operating on its dedicated acreage during 2023, driving approximately 5% to 10% volumetric growth year-over-year.

*Powder River Basin* 

During the fourth quarter 2022, gathering volumes averaged 106 MMcf/d and natural gas processing volumes averaged 104 MMcf/d. Natural gas gathering and processing volumes increased year-over-year by 3% and 4%, respectively, driven by new wells connected to the Jackalope system during 2022. In 2023, Crestwood expects producers to connect between 10 to 20 wells as Continental Resources, its largest customer in the basin, continues to delineate its acreage position targeting multiple formations. Crestwood's capital investments in the Powder River Basin are expected to be minimal and include well connects and minor system expansions. Crestwood anticipates an average of one to two rigs operating on its dedicated acreage during 2023.

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**Gathering & Processing South** 

Gathering and Processing South segment EBITDA totaled $45.1 million in the fourth quarter 2022, compared to $29.5 million in the fourth quarter 2021, an increase of 53% year-over-year. Both periods exclude losses on long-lived assets. Segment EBITDA increased year-over-year driven primarily by the contribution of the Sendero Midstream Partners LP ("Sendero Midstream") and the CPJV assets acquired in July 2022 and continued producer development in the Delaware Basin, offset by the divestitures of the Barnett and Marcellus assets in 2022.

*Delaware Basin* 

During the fourth quarter 2022, natural gas gathering volumes averaged 504 MMcf/d, natural gas processing volumes averaged 408 MMcf/d, produced water gathering volumes averaged 153 MBbls/d, and crude oil gathering volumes averaged 21 MBbls/d. Natural gas gathering and natural gas processing volumes increased year-over-year by 101% and 265%, respectively, due to the contribution of the Sendero Midstream assets and significant volume growth on the Willow Lake system in New Mexico. Produced water gathering volumes increased year-over-year by more than eight times due to the integration of Oasis Midstream's Panther assets as well as volume growth on the Desert Hills system. Producers connected 35 wells across Crestwood's footprint during the fourth quarter, resulting in a full-year total of 128 wells. Crestwood invested $36 million in the fourth quarter, the majority of which was related to the expansion of the Panther crude oil and produced water gathering and disposal system as well as compression expansions on the Sendero system.

In 2023, Crestwood expects to connect 120 to 130 wells across its gathering systems in the Delaware Basin based on current producer drilling and completion schedules. Crestwood's capital investments in the Delaware Basin, approximately 40% of the company's 2023 capital program, will include compression expansions in New Mexico and well connects across Crestwood's gathering assets. Crestwood anticipates an average of seven to eight rigs operating on its dedicated acreage during 2023, driving 10% to 15% volume growth year-over-year.

**Storage & Logistics** 

Storage & Logistics segment EBITDA totaled $25.9 million in the fourth quarter 2022, compared to $13.9 million in the fourth quarter 2021. Both periods exclude the non-cash change in fair value of commodity inventory-related derivative contracts. Fourth quarter segment EBITDA was impacted by realized losses on commodity price hedges entered into to partially mitigate commodity price exposure from Crestwood's gathering and processing segments' contracts that have POP structures. In 2023, Crestwood expects S&L segment earnings to return to normalized levels with adjusted EBITDA of $100 million to $110 million, as the NGL Logistics business should benefit from incremental margin opportunities due to contango in the forward NGL pricing curves.

**2023 Financial Guidance** 

Crestwood's 2023 guidance reflects the general business updates noted above and the most recent development plans from customers. In addition, the guidance range assumes the divestiture of Tres Palacios closes in April 2023. These projections are subject to risks and uncertainties in the "Forward-Looking Statements" section at the end of this release.

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&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• Net income of $310 million to $390 million

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• Adjusted EBITDA of $780 million to $860 million

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• Contribution by operating segment is set forth below:

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| | | |
|:---|:---|:---|
| *$US millions* | **Adj. EBITDA Range** | **Adj. EBITDA Range** |
| **Operating Segment** | **Low** | **High** |
|  Gathering & Processing North | $570 | $620 |
|  Gathering & Processing South | 170 | 190 |
|  Storage & Logistics | 100 | 110 |
|  Less: Corporate G&A | (60) | (60) |
|  **FY 2023 Totals** | $**780** | $**860** |

---

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• Distributable cash flow available to common unitholders of $430 million to $510 million

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• Free cash flow after distributions of $10 million to $90 million

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• Full-year coverage ratio of 1.6x to 1.8x based on annual distribution of $2.62 per common unit

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• Year-end 2023 leverage ratio between 3.7x and 4.1x

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• Growth capital spending in the range of $135 million to $155 million

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• Maintenance capital spending in the range of $25 million to $30 million

**Strategic Update and Capital Allocation Priorities** 

In 2023, Crestwood has shifted its focus from regional consolidation to maximizing throughput on available capacity across its expanded gathering and processing systems while reducing costs and capital requirements. Crestwood expects positive free cash flow after distributions of approximately $50 million at the guidance midpoint in 2023, which will be allocated to debt paydown, with a long-term leverage ratio target of less than 3.5x. Crestwood plans to keep the distribution flat at $2.62 per common unit in 2023 and will consider additional distribution increases and common or preferred unit buybacks dependent on leverage reduction targets.

**Capitalization and Liquidity Update** 

Crestwood invested approximately $66 million in the fourth quarter 2022 and $188 million during full-year 2022 in growth capital projects (excluding litigation related capital pertaining to the Bear Den II processing plant), approximately $10 million below the low end of the 2022 growth capital guidance range. As of December 31, 2022, Crestwood had approximately $3.4 billion of debt outstanding, comprised of $2.25 billion of fixed-rate senior notes and $1.1 billion outstanding under its two revolving credit facilities, resulting in a consolidated leverage ratio of 4.2x.

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On January 17, 2023, Crestwood issued $600 million of 7.375% senior unsecured notes and used the proceeds to repay borrowings on its corporate revolving credit facility and to repay and terminate the CPJV credit facility. Pro forma for the issuance of new senior notes and the expected closing of Tres Palacios in second quarter 2023, Crestwood will have $3.2 billion of long-term debt outstanding, including $2.85 billion of fixed-rate senior notes and approximately $360 million outstanding under its $1.75 billion revolving credit facility, and a consolidated leverage ratio of 4.0x.

Crestwood currently has 71.3 million preferred units outstanding (par value of $9.13 per unit) that pay a fixed-rate annual cash distribution of 9.25%, payable quarterly. The preferred units are listed on the New York Stock Exchange and trade under the ticker symbol CEQP-P.

**Sustainability Program Update** 

In January 2023, Crestwood was one of three midstream companies included in the 2023 Bloomberg Gender-Equality Index (GEI). This marks the third consecutive year being included in the GEI and validates the company's commitment to advancing diversity, equity and inclusion within the organization. Crestwood continues to advance its carbon management plan across its portfolio, including at its newly acquired assets, and remains on track to publish its fifth annual sustainability report in June 2023. For more information on Crestwood's approach to sustainability, please visit https://esg.crestwoodlp.com.

**Upcoming Conference Participation** 

Crestwood's management will participate in the following upcoming investor conferences. Prior to the start of each conference, new presentation materials may be posted to the Investors section of Crestwood's website at <u>www.crestwoodlp.com</u>.

• J.P. Morgan Global High Yield & Leveraged Finance Conference, Miami, FL, March 6 - 8, 2023

• 51st Annual Scotia Howard Weil Energy Conference, Miami, FL, March 6 - 8, 2023

**2022 K-1 Tax Packages** 

Crestwood's K-1 tax packages are expected to be made available online and mailed by mid-March 2023. Once available, K-1s can be found online at <u>www.taxpackagesupport.com/CEQP</u> for the common units, <u>www.taxpackagesupport.com/CEQP_Preferred</u> for the preferred units, and <u>www.taxpackagesupport.com/oasis</u> for Oasis Midstream for January 1 - 31, 2022.

**2022 Annual Report Form 10-K** 

Crestwood plans to file its annual report on Form 10-K with the Securities and Exchange Commission for the year ended December 31, 2022, by February 27, 2023. The 10-K report will be available to view, print or download on the Investors page of Crestwood's website at www.crestwoodlp.com. Crestwood will also provide a printed copy of the annual report on Form 10-K, free of charge upon request. Such requests should be directed in writing via email to investorrelations@crestwoodlp.com or via mail to Investor Relations, 811 Main St., Suite 3400, Houston, TX 77002.

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**Earnings Conference Call Schedule** 

Management will host a conference call for investors and analysts of Crestwood today at 9:00 a.m. Eastern Time (8:00 a.m. Central Time) which will be broadcast live over the Internet. Investors will be able to connect to the webcast via the "Investors" page of Crestwood's website at <u>www.crestwoodlp.com</u>. Please log in at least ten minutes in advance to register and download any necessary software. A replay will be available shortly after the call for 90 days.

**Non-GAAP Financial Measures** 

Adjusted EBITDA, distributable cash flow and free cash flow are non-GAAP financial measures. The accompanying schedules of this news release provide reconciliations of these non-GAAP financial measures to their most directly comparable financial measures calculated and presented in accordance with GAAP. Our non-GAAP financial measures should not be considered as alternatives to GAAP measures such as net income or operating income or any other GAAP measure of liquidity or financial performance.

**Forward-Looking Statements** 

This news release contains forward-looking statements within the meaning of the U.S. Private Securities Litigation Reform Act of 1995 and Section 21E of the Securities and Exchange Act of 1934. The words "expects," "believes," "anticipates," "plans," "will," "shall," "estimates," and similar expressions identify forward-looking statements, which are generally not historical in nature. Forward-looking statements are subject to risks and uncertainties and are based on the beliefs and assumptions of management, based on information currently available to them. Although Crestwood believes that these forward-looking statements are based on reasonable assumptions, it can give no assurance that any such forward-looking statements will materialize. Important factors that could cause actual results to differ materially from those expressed in or implied from these forward-looking statements include the risks and uncertainties described in Crestwood's reports filed with the Securities and Exchange Commission, including its Annual Report on Form 10-K and its subsequent reports, which are available through the SEC's EDGAR system at www.sec.gov and on our website. Readers are cautioned not to place undue reliance on forward-looking statements, which reflect management's view only as of the date made, and Crestwood assumes no obligation to update these forward-looking statements.

**About Crestwood Equity Partners LP** 

Houston, Texas, based Crestwood Equity Partners LP (NYSE: CEQP) is a master limited partnership that owns and operates midstream businesses in multiple shale resource plays across the United States. Crestwood Equity is engaged in the gathering, processing, treating, compression, storage and transportation of natural gas; storage, transportation, terminalling and marketing of NGLs; gathering, storage, terminalling and marketing of crude oil; and gathering and disposal of produced water. To learn more about Crestwood Equity Partners LP, visit <u>www.crestwoodlp.com</u>; and to learn more about Crestwood's sustainability efforts, please visit <u>https://esg.crestwoodlp.com</u>.

Source: Crestwood Equity Partners LP

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**Crestwood Equity Partners LP** 

**Investor Contacts** 

Andrew Thorington, 713-381-3028

andrew.thorington@crestwoolp.com

Vice President, Finance & Investor Relations

Rhianna Disch, 713-380-3006

rhianna.disch@crestwoodlp.com

Director, Investor Relations

**Sustainability and Media Contact** 

Joanne Howard, 832-519-2211

joanne.howard@crestwoodlp.com

Senior Vice President, Sustainability and Corporate Communications

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**CRESTWOOD EQUITY PARTNERS LP** 

**Consolidated Statements of Operations** 

***(in millions, except per unit data)***

***(unaudited)***

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| | | | | |
|:---|:---|:---|:---|:---|
|  | **Three Months Ended<br>December 31,** | **Three Months Ended<br>December 31,** | **Year Ended<br>December 31,** | **Year Ended<br>December 31,** |
|  | **2022** | **2021** | **2022** | **2021** |
|  Revenues | $1402.9 | $1380.4 | $6000.7 | $4569.0 |
|  Costs of products/services sold | 1132.7 | 1133.6 | 4997.1 | 3843.9 |
|  Operating expenses and other: |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Operations and maintenance | 52.1 | 30.8 | 196.1 | 121.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; General and administrative | 26.6 | 30.2 | 130.4 | 97.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Depreciation, amortization and accretion | 86.6 | 61.6 | 328.9 | 244.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Loss on long-lived assets, net | 0.8 | 20.0 | 187.7 | 39.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Gain on acquisition |  |  | (75.3) |  |
|  | 166.1 | 142.6 | 767.8 | 502.4 |
|  Operating income | 104.1 | 104.2 | 235.8 | 222.7 |
|  Earnings (loss) from unconsolidated affiliates, net | 3.5 | 5.5 | 15.7 | (120.4) |
|  Interest and debt expense, net | (53.6) | (30.1) | (177.4) | (132.1) |
|  Loss on modification/extinguishment of debt |  | (0.8) |  | (7.5) |
|  Other income (expense), net | 0.1 | (0.1) | 0.3 | 0.1 |
|  Income (loss) before income taxes | 54.1 | 78.7 | 74.4 | (37.2) |
|  Provision for income taxes | (0.2) | (0.1) | (1.9) | (0.2) |
|  Net income (loss) | 53.9 | 78.6 | 72.5 | (37.4) |
|  Net income attributable to non-controlling partner | 10.4 | 10.4 | 41.2 | 41.1 |
|  Net income (loss) attributable to Crestwood Equity Partners LP | 43.5 | 68.2 | 31.3 | (78.5) |
|  Net income attributable to preferred units | 15.1 | 15.1 | 60.1 | 60.1 |
|  Net income (loss) attributable to partners | $28.4 | $53.1 | $(28.8) | $(138.6) |
|  Net income (loss) per limited partner unit: |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Basic | $0.27 | $0.84 | $(0.29) | $(2.11) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Diluted | $0.26 | $0.79 | $(0.29) | $(2.11) |

---

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**NEWS RELEASE** 

 **Page 10 of 16** 

**CRESTWOOD EQUITY PARTNERS LP** 

**Selected Balance Sheet Data** 

***(in millions)***

***(unaudited)***

---

| | | |
|:---|:---|:---|
|  | **December 31,** | **December 31,** |
|  | **2022** | **2021** |
|  Cash | $7.5 | $13.3 |
|  **<u>Outstanding debt:</u>** |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Revolving Credit Facilities | $1129.1 | $282.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Senior Notes | 2250.0 | 1800.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Other | 26.7 | 0.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Subtotal | 3405.8 | 2082.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Less: deferred financing costs, net | 27.5 | 29.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Total debt | $3378.3 | $2052.3 |
|  **<u>Partners' capital</u>** |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Total partners' capital | $1907.2 | $1099.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Common units outstanding | 104.6 | 63.0 |

---

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**NEWS RELEASE** 

 **Page 11 of 16** 

**CRESTWOOD EQUITY PARTNERS LP** 

**Reconciliation of Non-GAAP Financial Measures** 

***(in millions)***

***(unaudited)***

---

| | | | | |
|:---|:---|:---|:---|:---|
|  | **Three Months Ended<br>December 31,** | **Three Months Ended<br>December 31,** | **Year Ended<br>December 31,** | **Year Ended<br>December 31,** |
|  | **2022** | **2021** | **2022** | **2021** |
|  **<u>Net Income (Loss) to Adjusted EBITDA</u>** |  |  |  |  |
|  Net income (loss) | $53.9 | $78.6 | $72.5 | $(37.4) |
|  Interest and debt expense, net | 53.6 | 30.1 | 177.4 | 132.1 |
|  Loss on modification/extinguishment of debt |  | 0.8 |  | 7.5 |
|  Provision for income taxes | 0.2 | 0.1 | 1.9 | 0.2 |
|  Depreciation, amortization and accretion | 86.6 | 61.6 | 328.9 | 244.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; **EBITDA<sup>(a)</sup>** | $194.3 | $171.2 | $580.7 | $346.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Significant items impacting EBITDA: |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Unit-based compensation charges | 10.4 | 12.1 | 37.2 | 34.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Loss on long-lived assets, net | 0.8 | 20.0 | 187.7 | 39.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Gain on acquisition |  |  | (75.3) |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(Earnings) loss from unconsolidated affiliates, net | (3.5) | (5.5) | (15.7) | 120.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Adjusted EBITDA from unconsolidated affiliates, net | 5.8 | 10.5 | 30.0 | 67.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Change in fair value of commodity inventory-related derivative contracts | (9.8) | (62.4) | (14.4) | (13.5) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Significant transaction and environmental related costs and other items | 2.3 | 3.2 | 31.9 | 5.1 |
|  **Adjusted EBITDA<sup>(a)</sup>** | $**200.3** | $**149.1** | $**762.1** | $**600.1** |
|  **<u>Distributable Cash Flow</u><sup>(b)</sup>** |  |  |  |  |
|  Adjusted EBITDA<sup>(a)</sup> | $200.3 | $149.1 | $762.1 | $600.1 |
|  Cash interest expense<sup>(c)</sup> | (54.2) | (28.6) | (178.2) | (125.9) |
|  Maintenance capital expenditures<sup>(d)</sup> | (13.5) | (6.2) | (28.7) | (19.3) |
|  Adjusted EBITDA from unconsolidated affiliates, net | (5.8) | (10.5) | (30.0) | (67.0) |
|  Distributable cash flow from unconsolidated affiliates | 5.6 | 9.3 | 28.0 | 62.6 |
|  PRB cash received in excess of recognized revenues<sup>(e)</sup> | 4.1 | 3.5 | 16.8 | 22.1 |
|  Provision for income taxes | (0.2) | (0.1) | (1.9) | (0.2) |
|  Distributable cash flow attributable to CEQP | 136.3 | 116.5 | 568.1 | 472.4 |
|  Distributions to preferred | (15.1) | (15.1) | (60.1) | (60.1) |
|  Distributions to Niobrara preferred | (10.4) | (10.3) | (41.4) | (41.2) |
|  **Distributable cash flow attributable to CEQP common** | $**110.8** | $**91.1** | $**466.6** | $**371.1** |

---

(a) EBITDA is defined as income before income taxes, plus debt-related costs (interest and debt expense, net, and
gain (loss) on modification/extinguishment of debt) and depreciation, amortization and accretion expense. Adjusted EBITDA considers the adjusted earnings impact of our unconsolidated affiliates by adjusting our equity earnings or losses from our
unconsolidated affiliates to reflect our proportionate share (based on the distribution percentage) of their EBITDA, excluding gains and losses on long-lived assets and other impairments. Adjusted EBITDA also considers the impact of certain
significant items, such as unit-based compensation charges, gains or losses and impairments on long-lived assets, impairments of goodwill, third party costs incurred related to potential and completed acquisitions, certain environmental remediation
costs, the change in fair value of commodity inventory-related derivative contracts, costs associated with the realignment and restructuring of our operations and corporate structure, and other transactions identified in a specific reporting period.
The change in fair value of commodity inventory-related derivative contracts is considered in determining Adjusted EBITDA given that the timing of recognizing gains and losses on these derivative contracts differs from the recognition of revenue for
the related underlying sale of inventory to which these derivatives relate. Changes in the fair value of other derivative contracts are not considered in determining Adjusted EBITDA given the relatively short-term nature of those derivative
contracts. EBITDA and Adjusted EBITDA are not measures calculated in accordance with U.S. GAAP, as they do not include deductions for items such as depreciation, amortization and accretion, interest and income taxes, which are necessary to maintain
our business. EBITDA and Adjusted EBITDA should not be considered as alternatives to net income, operating cash flow or any other measure of financial performance presented in accordance with U.S. GAAP. EBITDA and Adjusted EBITDA calculations may
vary among entities, so our computation may not be comparable to measures used by other companies.

(b) Distributable cash flow is defined as Adjusted EBITDA, adjusted for cash interest expense, maintenance capital
expenditures, income taxes, the cash received from our Powder River Basin operations in excess of revenue recognized, and our proportionate share (based on the distribution percentage) of our unconsolidated affiliates' distributable cash flow.
Distributable cash flow should not be considered an alternative to cash flows from operating activities or any other measure of financial performance calculated in accordance with U.S. GAAP as those items are used to measure operating performance,
liquidity, or the ability to service debt obligations. We believe that distributable cash flow provides additional information for evaluating our ability to declare and pay distributions to unitholders. Distributable cash flow, as we define it, may
not be comparable to distributable cash flow or similarly titled measures used by other companies.

(c) Cash interest expense less amortization of deferred financing costs.

(d) Maintenance capital expenditures are defined as those capital expenditures which do not increase operating
capacity or revenues from existing levels.

(e) Cash received from customers of our Powder River Basin operations pursuant to certain contractual minimum
revenue commitments in excess of related revenue recognized under FASB ASC 606.

------

**NEWS RELEASE** 

 **Page 12 of 16** 

**CRESTWOOD EQUITY PARTNERS LP** 

**Reconciliation of Non-GAAP Financial Measures** 

***(in millions)***

***(unaudited)***

---

| | | | | |
|:---|:---|:---|:---|:---|
|  | **Three Months Ended<br>December 31,** | **Three Months Ended<br>December 31,** | **Year Ended<br>December 31,** | **Year Ended<br>December 31,** |
|  | **2022** | **2021** | **2022** | **2021** |
|  **<u>Operating Cash Flows to Adjusted EBITDA</u>** |  |  |  |  |
|  Net cash provided by operating activities | $161.9 | $53.8 | $439.2 | $426.7 |
|  Net changes in operating assets and liabilities | (9.6) | 121.5 | 114.3 | 6.7 |
|  Amortization of debt-related deferred costs | (0.5) | (1.6) | (2.2) | (6.7) |
|  Interest and debt expense, net | 53.6 | 30.1 | 177.4 | 132.1 |
|  Unit-based compensation charges | (10.4) | (12.1) | (37.2) | (34.9) |
|  Loss on long-lived assets, net | (0.8) | (20.0) | (187.7) | (39.6) |
|  Gain on acquisition |  |  | 75.3 |  |
| (Earnings) loss from unconsolidated affiliates, net, adjusted for cash distributions received | (0.2) | (0.5) | 0.7 | (138.0) |
|  Deferred income taxes |  |  | (1.1) | 0.4 |
|  Provision for income taxes | 0.2 | 0.1 | 1.9 | 0.2 |
|  Other non-cash income (expense) | 0.1 | (0.1) | 0.1 | (0.3) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; **EBITDA<sup>(a)</sup>** | $**194.3** | $**171.2** | $**580.7** | $**346.6** |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Unit-based compensation charges | 10.4 | 12.1 | 37.2 | 34.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Loss on long-lived assets, net | 0.8 | 20.0 | 187.7 | 39.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Gain on acquisition |  |  | (75.3) |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(Earnings) loss from unconsolidated affiliates, net | (3.5) | (5.5) | (15.7) | 120.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Adjusted EBITDA from unconsolidated affiliates, net | 5.8 | 10.5 | 30.0 | 67.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Change in fair value of commodity inventory-related derivative contracts | (9.8) | (62.4) | (14.4) | (13.5) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Significant transaction and environmental related costs and other items | 2.3 | 3.2 | 31.9 | 5.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; **Adjusted EBITDA<sup>(a)</sup>** | $**200.3** | $**149.1** | $**762.1** | $**600.1** |
|  **<u>Distributable Cash Flow <sup>(b)</sup></u>** |  |  |  |  |
|  Adjusted EBITDA <sup>(a)</sup> | $200.3 | $149.1 | $762.1 | $600.1 |
|  Cash interest expense <sup>(c)</sup> | (54.2) | (28.6) | (178.2) | (125.9) |
|  Maintenance capital expenditures <sup>(d)</sup> | (13.5) | (6.2) | (28.7) | (19.3) |
|  Adjusted EBITDA from unconsolidated affiliates, net | (5.8) | (10.5) | (30.0) | (67.0) |
|  Distributable cash flow from unconsolidated affiliates | 5.6 | 9.3 | 28.0 | 62.6 |
|  PRB cash received in excess of recognized revenues <sup>(e)</sup> | 4.1 | 3.5 | 16.8 | 22.1 |
|  Provision for income taxes | (0.2) | (0.1) | (1.9) | (0.2) |
|  Distributable cash flow attributable to CEQP | 136.3 | 116.5 | 568.1 | 472.4 |
|  Distributions to preferred | (15.1) | (15.1) | (60.1) | (60.1) |
|  Distributions to Niobrara preferred | (10.4) | (10.3) | (41.4) | (41.2) |
|  **Distributable cash flow attributable to CEQP common** | $**110.8** | $**91.1** | $**466.6** | $**371.1** |
|  **<u>Free Cash Flow After Distributions <sup>(f)</sup></u>** |  |  |  |  |
|  Distributable cash flow attributable to CEQP common | $110.8 | $91.1 | $466.6 | $371.1 |
|  Less: Growth capital expenditures | 65.7 | 18.6 | 191.6 | 59.5 |
|  Less: Distributions to common unitholders<sup>(g)</sup> | 68.9 | 39.7 | 265.8 | 157.6 |
|  Free cash flow after distributions | $**(23.8)** | $**32.8** | $**9.2** | $**154.0** |

---

(a) EBITDA is defined as income before income taxes, plus debt-related costs (interest and debt expense, net, and
gain (loss) on modification/extinguishment of debt) and depreciation, amortization and accretion expense. Adjusted EBITDA considers the adjusted earnings impact of our unconsolidated affiliates by adjusting our equity earnings or losses from our
unconsolidated affiliates to reflect our proportionate share (based on the distribution percentage) of their EBITDA, excluding gains and losses on long-lived assets and other impairments. Adjusted EBITDA also considers the impact of certain
significant items, such as unit-based compensation charges, gains or losses and impairments on long-lived assets, impairments of goodwill, third party costs incurred related to potential and completed acquisitions, certain environmental remediation
costs, the change in fair value of commodity inventory-related derivative contracts, costs associated with the realignment and restructuring of our operations and corporate structure, and other transactions identified in a specific reporting period.
The change in fair value of

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**NEWS RELEASE** 

 **Page 13 of 16** 

commodity inventory-related derivative contracts is considered in determining Adjusted EBITDA given that the timing of recognizing gains and losses on these derivative contracts differs from the recognition of revenue for the related underlying sale of inventory to which these derivatives relate. Changes in the fair value of other derivative contracts are not considered in determining Adjusted EBITDA given the relatively short-term nature of those derivative contracts. EBITDA and Adjusted EBITDA are not measures calculated in accordance with U.S. GAAP, as they do not include deductions for items such as depreciation, amortization and accretion, interest and income taxes, which are necessary to maintain our business. EBITDA and Adjusted EBITDA should not be considered as alternatives to net income, operating cash flow or any other measure of financial performance presented in accordance with U.S. GAAP. EBITDA and Adjusted EBITDA calculations may vary among entities, so our computation may not be comparable to measures used by other companies.

(b) Distributable cash flow is defined as Adjusted EBITDA, adjusted for cash interest expense, maintenance capital
expenditures, income taxes, the cash received from our Powder River Basin operations in excess of revenue recognized, and our proportionate share (based on the distribution percentage) of our unconsolidated affiliates' distributable cash flow.
Distributable cash flow should not be considered an alternative to cash flows from operating activities or any other measure of financial performance calculated in accordance with U.S. GAAP as those items are used to measure operating performance,
liquidity, or the ability to service debt obligations. We believe that distributable cash flow provides additional information for evaluating our ability to declare and pay distributions to unitholders. Distributable cash flow, as we define it, may
not be comparable to distributable cash flow or similarly titled measures used by other companies.

(c) Cash interest expense less amortization of deferred financing costs.

(d) Maintenance capital expenditures are defined as those capital expenditures which do not increase operating
capacity or revenues from existing levels.

(e) Cash received from customers of our Powder River Basin operations pursuant to certain contractual minimum
revenue commitments in excess of related revenue recognized under FASB ASC 606.

(f) Free cash flow after distributions is defined as distributable cash flow attributable to common unitholders
less growth capital expenditures and distributions to common unitholders. Free cash flow after distributions should not be considered an alternative to cash flows from operating activities or any other measure of liquidity calculated in accordance
with U.S. GAAP as those items are used to measure liquidity or the ability to service debt obligations. We believe that free cash flow after distributions provides additional information for evaluating our ability to generate cash flow after paying
our distributions to common unitholders and paying for our growth capital expenditures.

(g) The year ended December 31, 2022, excludes $7.4 million of distributions made on August 12, 2022
related to 11.3 million CEQP common units issued in conjunction with the acquisition of the remaining 50% equity interest in Crestwood Permian Basin Holdings LLC on July 11, 2022. The three months and year ended December 31, 2021,
excludes $21.1 million of distributions made on February 14, 2022 to legacy Oasis Midstream unitholders.

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**NEWS RELEASE** 

 **Page 14 of 16** 

**CRESTWOOD EQUITY PARTNERS LP** 

**Segment Data** 

***(in millions)***

***(unaudited)***

---

| | | | | |
|:---|:---|:---|:---|:---|
|  | **Three Months<br>Ended December 31,** | **Three Months<br>Ended December 31,** | **Year Ended<br>December 31,** | **Year Ended<br>December 31,** |
|  | **2022** | **2021** | **2022** | **2021** |
|  **<u>Gathering and Processing North</u>** |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Revenues | $329.5 | $296.0 | $1537.9 | $1034.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Costs of product/services sold | 162.0 | 166.8 | 848.6 | 553.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Operations and maintenance expense | 26.7 | 12.9 | 105.3 | 51.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Gain on long-lived assets, net |  | 0.2 |  | 0.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; EBITDA | $140.8 | $116.5 | $584.0 | $430.1 |
|  **<u>Gathering and Processing South</u>** |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Revenues | $207.7 | $29.9 | $588.9 | $105.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Costs of product/services sold | 149.9 | 0.1 | 399.5 | 0.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Operations and maintenance expense | 14.4 | 5.5 | 43.0 | 22.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Loss on long-lived assets, net | (1.1) | (20.7) | (183.9) | (40.6) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Gain on acquisition |  |  | 75.3 |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Earnings from unconsolidated affiliates, net | 1.7 | 5.2 | 11.1 | 9.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; EBITDA | $44.0 | $8.8 | $48.9 | $51.1 |
|  **<u>Storage and Logistics</u>** |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Revenues | $865.7 | $1054.5 | $3873.9 | $3429.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Costs of product/services sold | 820.8 | 966.7 | 3749.0 | 3289.8 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Operations and maintenance expense | 11.0 | 12.4 | 47.8 | 47.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Gain (loss) on long-lived assets, net |  | 0.6 | (4.1) | 0.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Earnings (loss) from unconsolidated affiliates, net | 1.8 | 0.3 | 4.6 | (130.0) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; EBITDA | $35.7 | $76.3 | $77.6 | $(37.0) |
|  Total Segment EBITDA | $220.5 | $201.6 | $710.5 | $444.2 |
|  Corporate | (26.2) | (30.4) | (129.8) | (97.6) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; **EBITDA** | $194.3 | $171.2 | $580.7 | $346.6 |

---

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**NEWS RELEASE** 

 **Page 15 of 16** 

**CRESTWOOD EQUITY PARTNERS LP** 

**Operating Statistics** 

***(unaudited)***

---

| | | | | |
|:---|:---|:---|:---|:---|
|  | **Three Months Ended<br>December 31,** | **Three Months Ended<br>December 31,** | **Year Ended<br>December 31,** | **Year Ended<br>December 31,** |
|  | **2022** | **2021** | **2022** | **2021** |
|  **<u>Gathering and Processing North</u>** |  |  |  |  |
|  Gas gathering volumes (MMcf/d) |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Williston Basin | 243.1 | 141.1 | 246.9 | 139.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Powder River Basin | 105.9 | 102.6 | 106.3 | 100.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Total gas gathering volumes | 349.0 | 243.7 | 353.2 | 239.8 |
|  Processing volumes (MMcf/d) |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Williston Basin | 275.4 | 132.2 | 279.1 | 132.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Powder River Basin | 103.5 | 99.2 | 103.2 | 97.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Total processing volumes | 378.9 | 231.4 | 382.3 | 230.1 |
|  Williston Basin |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Crude oil gathering volumes (MBbls/d) | 75.9 | 80.0 | 78.0 | 87.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Water gathering volumes (MBbls/d) | 151.6 | 90.7 | 164.9 | 86.4 |
|  **<u>Gathering and Processing South</u>** |  |  |  |  |
|  Gas gathering volumes (MMcf/d) |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Delaware Basin <sup>(a)</sup> | 504.2 | 250.5 | 472.2 | 228.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Marcellus<sup>(b)</sup> | 203.3 | 221.4 | 209.8 | 227.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Barnett<sup>(b)</sup> |  | 228.2 | 212.9 | 218.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Total gas gathering volumes | 707.5 | 700.1 | 894.9 | 674.4 |
|  Processing volumes (MMcf/d) |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Delaware Basin <sup>(a)</sup> | 408.4 | 111.8 | 391.8 | 84.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Barnett<sup>(b)</sup> |  | 76.8 | 70.4 | 76.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Total processing volumes | 408.4 | 188.6 | 462.2 | 161.1 |
|  Delaware Basin - Crude oil gathering volumes (MBbls/d) <sup>(a)</sup> | 20.5 |  | 21.4 |  |
|  Delaware Basin - Water gathering volumes (MBbls/d) <sup>(a)</sup> | 152.7 | 17.5 | 131.3 | 39.5 |
|  **<u>Storage and Logistics</u>** |  |  |  |  |
|  Tres Palacios Storage - firm contracted capacity (Bcf) <sup>(a)</sup> | 29.1 | 28.8 | 29.0 | 29.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; % of operational capacity contracted | 76% | 75% | 76% | 76% |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Firm storage services (MMcf/d) <sup>(a)</sup> | 212.2 | 147.9 | 294.1 | 271.8 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Interruptible services (MMcf/d) <sup>(a)</sup> | 227.5 | 128.9 | 190.1 | 91.1 |
|  COLT Hub |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Rail loading (MBbls/d) | 12.8 | 35.8 | 14.0 | 43.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Outbound pipeline (MBbls/d) <sup>(c)</sup> | 24.7 | 18.0 | 25.0 | 16.7 |

---

(a) Includes our 50% owned joint venture, operational data reported at 100%.

(b) The Barnett assets and Marcellus assets were sold in July 2022 and October 2022, respectively.

(c) Represents only throughput leaving the terminal.

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**NEWS RELEASE** 

 **Page 16 of 16** 

**CRESTWOOD EQUITY PARTNERS LP** 

**Full Year 2023 Adjusted EBITDA, Distributable Cash Flow and Free Cash Flow Guidance** 

**Reconciliation of Non-GAAP Financial Measures** 

***(in millions)***

***(unaudited)***

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| | |
|:---|:---|
|  | **Expected 2023 Range**<br>**Low - High** |
|  **Net Income Reconciliation** |  |
|  Net income (loss) | $310 - $390 |
|  Interest and debt expense, net <sup>(a)</sup> | 225 - 230 |
|  Depreciation, amortization and accretion | 325 - 335 |
|  Unit-based compensation charges | 30 - 35 |
|  Earnings from unconsolidated affiliates | (130) - (135) |
|  Adjusted EBITDA from unconsolidated affiliates | 10 - 15 |
|  **Adjusted EBITDA** | **$780 - $860** |
|  Cash interest expense <sup>(b)</sup> | (220) - (225) |
|  Maintenance capital expenditures <sup>(c)</sup> | (25) - (30) |
|  Adjusted EBITDA from unconsolidated affiliates | (10) - (15) |
|  Distributable cash flow from unconsolidated affiliates | 9 - 14 |
|  Cash distributions to preferred unitholders <sup>(d)</sup> | (101) |
|  **Distributable cash flow attributable to CEQP <sup>(e)</sup>** | **$430 - $510** |
|  **Cash Flows from Operating Activities Reconciliation** |  |
|  Net cash provided by operating activities, net | $685 - $765 |
|  Interest and debt expense, net <sup>(a)</sup> | 225 - 230 |
|  Adjusted EBITDA from unconsolidated affiliates | 10 - 15 |
|  Earnings from unconsolidated affiliates | (130) - (135) |
|  Amortization of debt-related deferred costs | (5) - (10) |
|  Changes in operating assets and liabilities, net | (5) - (15) |
|  **Adjusted EBITDA** | **$780 - $860** |
|  Cash interest expense <sup>(b)</sup> | (220) - (225) |
|  Maintenance capital expenditures <sup>(c)</sup> | (25) - (30) |
|  Adjusted EBITDA from unconsolidated affiliates | (10) - (15) |
|  Distributable cash flow from unconsolidated affiliates | 9 - 14 |
|  Cash distributions to preferred unitholders <sup>(d)</sup> | (101) |
|  **Distributable cash flow attributable to CEQP <sup>(e)</sup>** | **$430 - $510** |
|  Less: Growth capital expenditures | 135 - 155 |
|  Less: Distributions to common unitholders | 276 |
|  **Free cash flow after distributions<sup>(f)</sup>** | **$10 - $90** |

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(a) Includes gain (loss) on modification/extinguishment of debt, net

(b) Cash interest expense less amortization of deferred financing costs.

(c) Maintenance capital expenditures are defined as those capital expenditures which do not increase operating
capacity or revenues from existing levels.

(d) Includes cash distributions to preferred unitholders and Crestwood Niobrara preferred unitholders.

(e) Distributable cash flow is defined as Adjusted EBITDA, adjusted for cash interest expense, maintenance capital
expenditures, income taxes, and our proportionate share of our unconsolidated affiliates' distributable cash flow. Distributable cash flow should not be considered an alternative to cash flows from operating activities or any other measure of
financial performance calculated in accordance with generally accepted accounting principles as those items are used to measure operating performance, liquidity, or the ability to service debt obligations. We believe that distributable cash flow
provides additional information for evaluating our ability to declare and pay distributions to unitholders. Distributable cash flow, as we define it, may not be comparable to distributable cash flow or similarly titled measures used by other
companies.

(f) Free cash flow after distributions is defined as distributable cash flow attributable to common unitholders
less growth capital expenditures and distributions to common unitholders. Free cash flow after distributions should not be considered an alternative to cash flows from operating activities or any other measure of liquidity calculated in accordance
with generally accepted accounting principles as those items are used to measure liquidity or the ability to service debt obligations. We believe that free cash flow after distributions provides additional information for evaluating our ability to
generate cash flow after paying our distributions to common unitholders and paying for our growth capital expenditures.