Suburban Propane Partners (NYSE: SPH) lifts H1 net income despite lower sales

Rhea-AI Filing Summary

Suburban Propane Partners, L.P. reports solid results for the quarter ended March 28, 2026. Quarterly revenue was $551.2 million, down from $587.7 million a year earlier, mainly on lower propane sales, while net income held steady at $137.5 million versus $137.1 million.

For the first six months of fiscal 2026, revenue was $921.6 million compared with $961.0 million in 2025, but net income rose to $183.3 million from $156.5 million, lifting diluted net income per common unit to $2.75 from $2.41.

The partnership generated $68.6 million of operating cash flow in the first half, funded $44.5 million of capital spending and $23.1 million of acquisitions, and ended the period with $4.3 million in cash and $1.27 billion of long-term borrowings, including $200.3 million on its revolving credit facility.

Insights

Energy MLP and credit structure analyst

Higher profits despite lower sales, with active balance sheet management.

Suburban Propane Partners (SPH) saw revenue soften but profitability improve. Six‑month revenue slipped to $921.6M from $961.0M, yet net income increased to $183.3M from $156.5M, helped by lower product costs and controlled operating expenses.

Margins benefited from a drop in cost of products sold to $338.3M from $389.5M over six months. Operating income rose to $225.6M. The partnership also recognized $3.5M in Clean Fuel Production Tax Credits tied to renewable natural gas, reflecting growing contribution from its renewable platform.

On the balance sheet, long‑term borrowings were $1.27B as of March 28, 2026, including $350M of new 6.50% 2035 senior notes and $200.3M drawn on the Revolving Credit Facility. Refinancing the 2027 notes reduced near‑term maturities, while operating cash flow of $68.6M supported capex, acquisitions and $43.0M of distributions.

Key Figures

Quarterly revenue: $551.2M Quarterly net income: $137.5M Six-month revenue: $921.6M +5 more

8 metrics

Quarterly revenue $551.2M Three months ended March 28, 2026

Quarterly net income $137.5M Three months ended March 28, 2026

Six-month revenue $921.6M Six months ended March 28, 2026

Six-month net income $183.3M Six months ended March 28, 2026

Diluted EPS (six months) $2.75 per unit Six months ended March 28, 2026

Operating cash flow $68.6M Six months ended March 28, 2026

Long-term borrowings $1.27B As of March 28, 2026

Quarterly distribution $0.325 per unit Declared for Q2 fiscal 2026

Key Terms

Clean Fuel Production Tax Credit, Revolving Credit Facility, Senior Notes, Green Bonds, +2 more

6 terms

Clean Fuel Production Tax Credit financial

"RNG produced in the United States and sold for use as a transportation fuel may qualify for the Clean Fuel Production Tax Credit"

Revolving Credit Facility financial

"the Credit Agreement that provides for a $500,000 revolving credit facility"

A revolving credit facility is a type of loan that a business can borrow from whenever it needs money, up to a set limit. It’s like having a credit card for companies—allowing them to borrow, pay back, and borrow again as needed, providing flexibility for managing cash flow or funding short-term expenses.

Senior Notes financial

"5.00 % senior notes, due June 1, 2031 and 6.50 % senior notes, due December 15, 2035"

Senior notes are a type of loan that a company borrows from investors, promising to pay it back with interest. They are called "senior" because in case the company faces financial trouble, these lenders are paid back before others. This makes senior notes safer for investors compared to other types of loans or bonds.

Green Bonds financial

"5.50 % Green Bonds, due October 1, 2028 through October 1, 2033"

Green bonds are loans a borrower sells to investors where the money raised is earmarked for projects with environmental benefits, like renewable energy, clean transportation, or energy-efficient buildings. Think of them as a labeled loan — similar to lending money to someone specifically to install solar panels — which matters to investors because the label can affect demand, reputation, and potentially risk and return if environmental rules, subsidies, or project performance influence cash flow.

Restricted Unit Plan financial

"the Suburban Propane Partners, L.P. 2018 Restricted Unit Plan authorizing the issuance of up to 1,800,000 Common Units"

Long-Term Incentive Plan financial

"the 2021 Long-Term Incentive Plan is a non-qualified, unfunded, long-term incentive plan for executive officers and key employees"

A long-term incentive plan is a company program that pays executives or employees with stock, options, or cash tied to multi-year performance goals, where the rewards become theirs only after meeting conditions over time. Think of it as a delayed bonus or retirement-style reward that aligns employees’ interests with shareholders by encouraging them to boost long-term value; investors watch these plans because they affect pay costs, share dilution and management incentives.

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Table of Contents

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

☒ Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the quarterly period ended March 28, 2026

☐ Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

Commission File Number: 1-14222

SUBURBAN PROPANE PARTNERS, L.P.

(Exact name of registrant as specified in its charter)

Delaware	22-3410353
(State or other jurisdiction of	(I.R.S. Employer
incorporation or organization)	Identification No.)

240 Route 10 West

Whippany, NJ 07981

(973) 887-5300

(Address, including zip code, and telephone number,

including area code, of registrant’s principal executive offices)

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

Title of each class		Trading Symbol		Name of exchange on which registered
Common Units		SPH		New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. ☒ Yes ☐ No

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer	☒		Accelerated filer	☐
Non-accelerated filer	☐		Smaller reporting company	☐
			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. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒

At May 4, 2026, there were 66,343,057 Common Units of Suburban Propane Partners, L.P. outstanding.

Table of Contents

SUBURBAN PROPANE PARTNERS, L.P. AND SUBSIDIARIES

INDEX TO FORM 10-Q

				Page
		PART I. FINANCIAL INFORMATION		1
ITEM 1.		FINANCIAL STATEMENTS (UNAUDITED)		1
		Condensed Consolidated Balance Sheets as of March 28, 2026 and September 27, 2025		1
		Condensed Consolidated Statements of Operations for the three months ended March 28, 2026 and March 29, 2025		2
		Condensed Consolidated Statements of Operations for the six months ended March 28, 2026 and March 29, 2025		3
		Condensed Consolidated Statements of Comprehensive Income for the three and six months ended March 28, 2026 and March 29, 2025		4
		Condensed Consolidated Statements of Cash Flows for the six months ended March 28, 2026 and March 29, 2025		5
		Condensed Consolidated Statements of Partners’ Capital for the three months ended March 28, 2026 and March 29, 2025		6
		Condensed Consolidated Statements of Partners’ Capital for the six months ended March 28, 2026 and March 29, 2025		7
		Notes to Condensed Consolidated Financial Statements		8
ITEM 2.		MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS		29
ITEM 3.		QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK		41
ITEM 4.		CONTROLS AND PROCEDURES		43
		PART II. OTHER INFORMATION		44
ITEM 1.		LEGAL PROCEEDINGS		44
ITEM 1A.		RISK FACTORS		44
ITEM 2.		UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS		44
ITEM 3.		DEFAULTS UPON SENIOR SECURITIES		44
ITEM 4.		MINE SAFETY DISCLOSURES		44
ITEM 5.		OTHER INFORMATION		44
ITEM 6.		EXHIBITS		45
SIGNATURES				46

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DISCLOSURE REGARDING FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q contains forward-looking statements (“Forward-Looking Statements”) as defined in the Private Securities Litigation Reform Act of 1995, Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended, relating to future business expectations and predictions, capital expenditures, strategic alternatives, project developments, and financial condition and results of operations of Suburban Propane Partners, L.P. (the “Partnership”). Some of these statements can be identified by the use of forward-looking terminology such as “prospects,” “outlook,” “believes,” “estimates,” “intends,” “may,” “will,” “should,” “could,” “anticipates,” “expects” or “plans” or the negative or other variation of these or similar words, or by discussion of trends and conditions, strategies or risks and uncertainties. These Forward-Looking Statements involve certain risks and uncertainties that could cause actual results to differ materially from those discussed or implied in such Forward-Looking Statements (statements contained in this Quarterly Report identifying such risks and uncertainties are referred to as “Cautionary Statements”). The risks and uncertainties that could impact the Partnership’s results include, but are not limited to, the following:

•The impact of weather conditions on the demand for propane, renewable propane, fuel oil and other refined fuels, natural gas, renewable natural gas (“RNG”) and electricity;

•The impact of climate change and potential climate change legislation on the Partnership and demand for propane, renewable propane, fuel oil and other refined fuels, natural gas, RNG and electricity;

•Volatility in the unit cost of propane, renewable propane, fuel oil and other refined fuels, natural gas, RNG and electricity, the impact of the Partnership’s hedging and risk management activities, and the adverse impact of price increases on volumes sold as a result of customer conservation;

•The ability of the Partnership to compete with other suppliers of propane, renewable propane, fuel oil, RNG and other energy sources;

•The impact on the price and supply of propane, renewable propane, fuel oil and other refined fuels from the political, military or economic instability of the oil producing nations, including hostilities in the Middle East, Russian military action in Ukraine, global terrorism and other general economic conditions, including the economic instability resulting from natural disasters;

•Economic volatility and downturns, including as a result of tariffs, trade conflict and related uncertainty;

•The ability of the Partnership to acquire and maintain sufficient volumes of, and the costs to the Partnership of acquiring, reliably transporting and storing, propane, renewable propane, fuel oil and other refined fuels;

•The ability of the Partnership to attract and retain employees and key personnel to support the growth of our business;

•The ability of the Partnership to retain customers or acquire new customers;

•The impact of customer conservation, energy efficiency, general economic conditions and technology advances on the demand for propane, renewable propane, fuel oil and other refined fuels, natural gas, RNG and electricity;

•The ability of management to continue to control expenses and manage inflationary increases in fuel, labor and other operating costs;

•Risks related to the Partnership’s renewable fuel projects and investments, including the willingness of customers to purchase fuels generated by the projects, the permitting, financing, construction, development and operation of supporting facilities, the Partnership’s ability to generate a sufficient return on its renewable fuel projects, the Partnership’s dependence on third-party partners to help manage and operate renewable fuel investment projects, and increased regulation and dependence on government funding for commercial viability of renewable fuel investment projects;

•The generation and monetization of environmental attributes produced by the Partnership’s renewable fuel projects, changes to legislation or regulations concerning the generation and monetization of environmental attributes and pricing volatility in the open markets where environmental attributes are traded;

•The impact of changes in applicable laws and government regulations, or their interpretations, including those relating to the environment and climate change, permitting, human health and safety, derivative instruments, the sale or marketing of propane and renewable propane, fuel oil and other refined fuels, natural gas, RNG and electricity, including the impact of recently adopted and proposed changes to New York law and changed regulatory priorities, and other regulatory developments that could impose costs and liabilities on the Partnership’s business;

•The impact of changes in tax laws that could adversely affect the tax treatment of the Partnership for income tax purposes;

•The impact of legal risks and proceedings on the Partnership’s business;

•The impact of operating hazards that could adversely affect the Partnership’s reputation and its operating results to the extent not covered by insurance;

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•The Partnership’s ability to make strategic acquisitions, successfully integrate them and realize the expected benefits of those acquisitions;

•The ability of the Partnership and any third-party service providers on which it may rely for support or services to continue to combat cybersecurity threats to their respective and shared networks and information technology;

•Risks relating to the Partnership’s plans to diversify its business;

•Risks related to the Partnership’s current and future debt obligations that may limit its ability to make distributions to Unitholders, as well as its financial flexibility;

•The impact of current conditions in the global capital, credit and environmental attribute markets, and general economic pressures; and

•Other risks referenced from time to time in filings with the Securities and Exchange Commission (“SEC”) and those factors listed or incorporated by reference into the Partnership’s most recent Annual Report under “Risk Factors.”

Some of these Forward-Looking Statements are discussed in more detail in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in this Quarterly Report. Reference is also made to the risk factors discussed in Item 1A of our Annual Report on Form 10-K for the fiscal year ended September 27, 2025. On different occasions, the Partnership or its representatives have made or may make Forward-Looking Statements in other filings with the SEC, press releases or oral statements made by or with the approval of one of the Partnership’s authorized executive officers. Readers are cautioned not to place undue reliance on Forward-Looking Statements, which reflect management’s view only as of the date made. The Partnership undertakes no obligation to update any Forward-Looking Statement or Cautionary Statement, except as required by law. All subsequent written and oral Forward-Looking Statements attributable to the Partnership or persons acting on its behalf are expressly qualified in their entirety by the Cautionary Statements in this Quarterly Report and in future SEC reports. For a more complete discussion of specific factors which could cause actual results to differ from those in the Forward-Looking Statements or Cautionary Statements, see “Risk Factors” in our Annual Report on Form 10-K for the fiscal year ended September 27, 2025, our Quarterly Reports on Form 10-Q, and our other filings with the SEC.

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PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

SUBURBAN PROPANE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(in thousands)

(unaudited)

		March 28, 2026				September 27, 2025
ASSETS
Current assets:
Cash and cash equivalents		$	4,292			$	405
Accounts receivable, less allowance for doubtful accounts of $6,807 and    $5,107, respectively			148,116				69,479
Inventories			63,549				73,726
Other current assets			51,520				22,664
Total current assets			267,477				166,274
Property, plant and equipment, net			717,455				691,275
Operating lease right-of-use assets			106,490				118,997
Goodwill			1,165,016				1,157,827
Other intangible assets, net			87,463				84,777
Other assets			82,734				77,124
Total assets		$	2,426,635			$	2,296,274
LIABILITIES AND PARTNERS' CAPITAL
Current liabilities:
Accounts payable		$	44,911			$	45,042
Accrued employment and benefit costs			43,959				47,066
Customer deposits and advances			63,401				121,737
Operating lease liabilities			30,953				34,329
Other current liabilities			64,546				54,646
Total current liabilities			247,770				302,820
Long-term borrowings			1,259,048				1,211,745
Accrued insurance			50,783				46,225
Operating lease liabilities			74,573				83,684
Other liabilities			50,559				53,229
Total liabilities			1,682,733				1,697,703
Commitments and contingencies
Partners' capital:
Common Unitholders (66,334 and 65,845 units issued and outstanding at    March 28, 2026 and September 27, 2025, respectively)			749,604				604,054
Accumulated other comprehensive loss			(5,702	)			(5,483	)
Total partners’ capital			743,902				598,571
Total liabilities and partners’ capital		$	2,426,635			$	2,296,274

The accompanying notes are an integral part of these condensed consolidated financial statements.

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SUBURBAN PROPANE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands, except per unit amounts)

(unaudited)

		Three Months Ended
		March 28,				March 29,
		2026				2025
Revenues
Propane		$	491,142			$	525,256
Fuel oil and refined fuels			32,354				33,364
Natural gas and electricity			8,778				9,025
All other			18,932				20,018
			551,206				587,663
Cost of sales
Cost of products sold			207,500				242,362
Operating			139,500				139,377
General and administrative			30,044				29,911
Depreciation and amortization			16,251				17,600
			393,295				429,250
Operating income			157,911				158,413
Interest expense, net			19,694				20,567
Other, net			555				729
Income before provision for (benefit from) income taxes			137,662				137,117
Provision for (benefit from) income taxes			120				(4	)
Net income		$	137,542			$	137,121
Net income per Common Unit - basic		$	2.07			$	2.11
Weighted average number of Common Units outstanding - basic			66,565				64,876
Net income per Common Unit - diluted		$	2.06			$	2.10
Weighted average number of Common Units outstanding - diluted			66,904				65,262

The accompanying notes are an integral part of these condensed consolidated financial statements.

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SUBURBAN PROPANE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands, except per unit amounts)

(unaudited)

		Six Months Ended
		March 28,				March 29,
		2026				2025
Revenues
Propane		$	817,532			$	855,539
Fuel oil and refined fuels			50,521				51,025
Natural gas and electricity			14,677				15,078
All other			38,862				39,350
			921,592				960,992
Cost of sales
Cost of products sold			338,339				389,524
Operating			266,659				262,530
General and administrative			57,917				56,764
Depreciation and amortization			33,115				34,699
			696,030				743,517
Operating income			225,562				217,475
Loss on debt extinguishment			1,183				—
Interest expense, net			39,450				40,179
Other, net			1,256				20,196
Income before provision for income taxes			183,673				157,100
Provision for income taxes			351				559
Net income		$	183,322			$	156,541
Net income per Common Unit - basic		$	2.76			$	2.42
Weighted average number of Common Units outstanding - basic			66,416				64,711
Net income per Common Unit - diluted		$	2.75			$	2.41
Weighted average number of Common Units outstanding - diluted			66,712				65,034

The accompanying notes are an integral part of these condensed consolidated financial statements.

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SUBURBAN PROPANE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(in thousands)

(unaudited)

		Three Months Ended								Six Months Ended
		March 28,				March 29,				March 28,				March 29,
		2026				2025				2026				2025
Net income		$	137,542			$	137,121			$	183,322			$	156,541
Other comprehensive (loss):
Amortization of net actuarial (gains) and prior service credits into earnings			(109	)			(117	)			(219	)			(233	)
Other comprehensive (loss)			(109	)			(117	)			(219	)			(233	)
Total comprehensive income		$	137,433			$	137,004			$	183,103			$	156,308

The accompanying notes are an integral part of these condensed consolidated financial statements.

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SUBURBAN PROPANE PARTNERS, L.P. AND SUBSIDIARIES
 

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands)

(unaudited)

		Six Months Ended
		March 28, 2026				March 29, 2025
Cash flows from operating activities:
Net income		$	183,322			$	156,541
Adjustments to reconcile net income to net cash provided by operations:
Depreciation and amortization			33,115				34,699
Equity in losses and impairment charges for investments in unconsolidated affiliates			896				22,745
Compensation costs recognized under Restricted Unit Plan			4,134				4,219
Loss on debt extinguishment			1,183				—
Other, net			675				2,219
Changes in assets and liabilities:
Accounts receivable			(78,455	)			(85,078	)
Inventories			10,323				1,318
Other current and noncurrent assets			(21,691	)			(2,953	)
Accounts payable			(1,638	)			(1,974	)
Accrued employment and benefit costs			(3,494	)			637
Customer deposits and advances			(58,336	)			(62,262	)
Contributions to defined benefit pension plan			(2,000	)			(2,000	)
Other current and noncurrent liabilities			565				(19,227	)
Net cash provided by operating activities			68,599				48,884
Cash flows from investing activities:
Capital expenditures			(44,535	)			(43,152	)
Investments in and acquisitions of businesses			(23,133	)			(55,309	)
Proceeds from sale of property, plant and equipment			1,837				1,335
Net cash (used in) investing activities			(65,831	)			(97,126	)
Cash flows from financing activities:
Proceeds from long-term borrowings			350,000				—
Repayments of long-term borrowings			(350,000	)			—
Proceeds from borrowings under revolving credit facility			248,232				314,100
Repayments of borrowings under revolving credit facility			(197,132	)			(232,500	)
Issuance costs associated with long-term borrowings			(5,974	)			—
Proceeds from the issuance of Common Units under an at-the-market equity program, net of commissions and offering costs			3,134				8,788
Partnership distributions			(42,957	)			(41,784	)
Other, net			(3,133	)			(3,482	)
Net cash provided by financing activities			2,170				45,122
Net increase (decrease) in cash, cash equivalents and restricted cash			4,938				(3,120	)
Cash, cash equivalents and restricted cash at beginning of period			11,771				20,514
Cash, cash equivalents and restricted cash at end of period		$	16,709			$	17,394
Less: restricted cash			12,417				13,515
Cash and cash equivalents, end of period		$	4,292			$	3,879

The accompanying notes are an integral part of these condensed consolidated financial statements.

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SUBURBAN PROPANE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL

(in thousands)

(unaudited)

		Three Months Ended March 28, 2026
		Number of Common Units				Common Unitholders				Accumulated Other Comprehensive (Loss)				Total Partners' Capital
Balance, beginning of period			66,329			$	631,812			$	(5,593	)		$	626,219
Net income							137,542				—				137,542
Other comprehensive (loss)							—				(109	)			(109	)
Partnership distributions							(21,557	)			—				(21,557	)
Common Units issued under Restricted Unit Plan			5				—				—				—
Net proceeds from the issuance of Common Units    under an at-the-market equity program			—				(14	)			—				(14	)
Compensation costs recognized under Restricted Unit Plan							1,821				—				1,821
Balance, end of period			66,334			$	749,604			$	(5,702	)		$	743,902

		Three Months Ended March 29, 2025
		Number of Common Units				Common Unitholders				Accumulated Other Comprehensive (Loss)				Total Partners' Capital
Balance, beginning of period			64,490			$	551,401			$	(6,263	)		$	545,138
Net income							137,121				—				137,121
Other comprehensive (loss)							—				(117	)			(117	)
Partnership distributions							(20,961	)			—				(20,961	)
Common Units issued under Restricted Unit Plan			7				—				—				—
Net proceeds from the issuance of Common Units    under an at-the-market equity program			442				8,788				—				8,788
Compensation costs recognized under Restricted Unit Plan							1,840				—				1,840
Balance, end of period			64,939			$	678,189			$	(6,380	)		$	671,809

The accompanying notes are an integral part of these condensed consolidated financial statements.

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SUBURBAN PROPANE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL

(in thousands)

(unaudited)

		Six Months Ended March 28, 2026
		Number of Common Units				Common Unitholders				Accumulated Other Comprehensive (Loss)				Total Partners' Capital
Balance, beginning of period			65,845			$	604,054			$	(5,483	)		$	598,571
Net income							183,322				—				183,322
Other comprehensive (loss)							—				(219	)			(219	)
Partnership distributions							(42,957	)			—				(42,957	)
Common Units issued under Restricted Unit Plan			317				(2,083	)			—				(2,083	)
Net proceeds from the issuance of Common Units    under an at-the-market equity program			172				3,134				—				3,134
Compensation costs recognized under Restricted Unit Plan							4,134				—				4,134
Balance, end of period			66,334			$	749,604			$	(5,702	)		$	743,902

		Six Months Ended March 29, 2025
		Number of Common Units				Common Unitholders				Accumulated Other Comprehensive (Loss)				Total Partners' Capital
Balance, beginning of period			64,072			$	553,207			$	(6,147	)		$	547,060
Net income							156,541				—				156,541
Other comprehensive (loss)							—				(233	)			(233	)
Partnership distributions							(41,784	)			—				(41,784	)
Common Units issued under Restricted Unit Plan			425				(2,782	)			—				(2,782	)
Net proceeds from the issuance of Common Units    under an at-the-market equity program			442				8,788				—				8,788
Compensation costs recognized under Restricted Unit Plan							4,219				—				4,219
Balance, end of period			64,939			$	678,189			$	(6,380	)		$	671,809

The accompanying notes are an integral part of these condensed consolidated financial statements.

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SUBURBAN PROPANE PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(dollars in thousands, except unit and per unit amounts)

(unaudited)

1.Partnership Organization and Formation

Suburban Propane Partners, L.P. (the “Partnership”) is a publicly traded Delaware limited partnership principally engaged, through its operating partnership and subsidiaries, in the retail marketing and distribution of propane, renewable propane, renewable natural gas (“RNG”), fuel oil and refined fuels, as well as the marketing of natural gas and electricity in deregulated markets and producer of and investor in low-carbon fuel alternatives. In addition, to complement its core marketing and distribution businesses, the Partnership services a wide variety of home comfort equipment, particularly for heating and ventilation. The publicly traded limited partner interests in the Partnership are evidenced by common units traded on the New York Stock Exchange (“Common Units”), with 66,333,965 Common Units outstanding at March 28, 2026. The holders of Common Units are entitled to participate in distributions and exercise the rights and privileges available to limited partners under the Third Amended and Restated Agreement of Limited Partnership (the “Partnership Agreement”), as amended. Rights and privileges under the Partnership Agreement include, among other things, the election of all members of the Board of Supervisors and voting on the removal of the general partner.

Suburban Propane, L.P. (the “Operating Partnership”), a Delaware limited partnership, is the Partnership’s operating subsidiary formed to operate the propane business and assets. In addition, Suburban Sales & Service, Inc. (the “Service Company”), a subsidiary of the Operating Partnership, was formed to operate the service work and appliance and parts businesses of the Partnership. The Operating Partnership, together with its direct and indirect subsidiaries, accounts for substantially all of the Partnership’s assets, revenues and earnings. The Partnership, the Operating Partnership and the Service Company commenced operations in March 1996 in connection with the Partnership’s initial public offering.

Suburban Renewable Energy, LLC (“Suburban Renewable Energy”) is a wholly owned subsidiary of the Operating Partnership that was formed in January 2022. Suburban Renewable Energy serves as the platform for the Partnership’s investments in innovative, renewable energy technologies and businesses.

The general partner of both the Partnership and the Operating Partnership is Suburban Energy Services Group LLC (the “General Partner”), a Delaware limited liability company, the sole member of which is the Partnership’s Chief Executive Officer. Other than as a holder of 784 Common Units that will remain in the General Partner, the General Partner does not have any economic interest in the Partnership or the Operating Partnership.

The Partnership’s fuel oil and refined fuels, natural gas and electricity, services, and renewable energy businesses are structured as either limited liability companies that are treated as corporations or corporate entities (collectively referred to as the “Corporate Entities”) and, as such, are subject to corporate level U.S. income tax.

Suburban Energy Finance Corp., a direct 100%-owned subsidiary of the Partnership, was formed on November 26, 2003 to serve as co-issuer, jointly and severally with the Partnership, of the Partnership’s senior notes.

2.Basis of Presentation

Principles of Consolidation. The condensed consolidated financial statements include the accounts of the Partnership, the Operating Partnership and all of its direct and indirect subsidiaries. All significant intercompany transactions and account balances have been eliminated. The Partnership consolidates the results of operations, financial condition and cash flows of the Operating Partnership as a result of the Partnership’s 100% limited partner interest in the Operating Partnership.

The accompanying condensed consolidated financial statements are unaudited and have been prepared in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”). They include all adjustments that the Partnership considers necessary for a fair statement of the results of operations, financial position and cash flows for the interim periods presented. Such adjustments consist only of normal recurring items, unless otherwise disclosed. These financial statements should be read in conjunction with the financial statements included in the Partnership’s Annual Report on Form 10-K for the fiscal year ended September 27, 2025. Due to the seasonal nature of the Partnership’s operations, the results of operations for interim periods are not necessarily indicative of the results to be expected for a full year.

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Fiscal Period. The Partnership uses a 52/53-week fiscal year which ends on the last Saturday in September. The Partnership’s fiscal quarters are generally thirteen weeks in duration. When the Partnership’s fiscal year is 53 weeks long, the corresponding fourth quarter is fourteen weeks in duration.

Revenue Recognition. The Partnership recognizes revenue pursuant to the requirements of Financial Accounting Standards Board (“FASB”) Topic 606 – Revenue from Contracts with Customers (“Topic 606”) and all related amendments. Topic 606 provides a five-step model to be applied to all contracts with customers. The five steps are to identify the contract(s) with the customer, identify the performance obligations in the contract, determine the transaction price, allocate the transaction price to the performance obligations in the contract and recognize revenue when each performance obligation is satisfied.

Revenue is recognized by the Partnership when goods or services promised in a contract with a customer have been transferred, and no further performance obligation on that transfer is required, in an amount that reflects the consideration expected to be received. Performance obligations are determined and evaluated based on the specific terms of the arrangements and the distinct products and services offered. Due to the nature of the retail business of the Partnership, there are no remaining or unsatisfied performance obligations as of the end of the reporting period, except for tank rental agreements, maintenance service contracts, fixed price contracts and budgetary programs, as described below. The performance obligation associated with sales of propane, fuel oil and refined fuels is met at the time product is delivered to the customer. Revenue from the sale of appliances and equipment is recognized at the time of sale or when installation is complete, as defined by the performance obligations included within the related customer contract. Revenue from repairs, maintenance and other service activities is recognized upon completion of the service. Revenue from the sale of natural gas and electricity is recognized based on customer usage as determined by meter readings for amounts delivered, an immaterial amount of which may be unbilled at the end of each accounting period.

The Partnership defers the recognition of revenue for annually billed tank rent, maintenance service contracts, fixed price contracts and budgetary programs where customer consideration is received at the start of the contract period, establishing contract liabilities which are disclosed as customer deposits and advances on the condensed consolidated balance sheets. Deliveries to customers enrolled in budgetary programs that exceed billings to those customers establish contract assets which are included in accounts receivable on the condensed consolidated balance sheets. The Partnership ratably recognizes revenue over the applicable term for tank rent and maintenance service agreements, which is generally one year, and at the time of delivery for fixed price contracts and budgetary programs.

The Partnership incurs incremental direct costs, such as commissions to its sales force, to obtain certain contracts. These costs are expensed as incurred, consistent with the practical expedients issued by the FASB, since the expected amortization period is one year or less. The Partnership generally determines selling prices based on, among other things, the current weighted average cost and the current replacement cost of the product at the time of delivery, plus an applicable margin. Except for tank rental agreements, maintenance service contracts, fixed price contracts and budgetary programs, customer payments for the satisfaction of a performance obligation are due upon receipt.

Revenues from the Partnership’s renewable energy platform, as described further in Note 4, “Investments in and Acquisitions of Businesses,” consist of in-take and off-take revenues. In-take revenues are generated from tipping fees charged to third parties who deliver feedstocks, including food and beverage waste, to the Partnership’s facilities. These feedstocks, as well as manure from dairy cattle, are then anaerobically digested and converted into RNG and fertilizer. Off-take revenues are generated through the sale of RNG and the related environmental attributes, including renewable identification numbers (“RINs”) and low carbon fuel standard (“LCFS”) credits that are generated from the production and distribution of RNG, and revenues generated from the sales of fertilizers and other byproducts produced in the RNG production process. Revenues from the Partnership’s renewable energy platform are reported within the “all other” segment (refer to Note 19, “Segment Information” for more information).

In-take revenues are recognized at the point in time when the feedstocks are delivered to the Partnership because that is when the performance obligations have been satisfied. Off-take revenues are recognized at the point in time when the Partnership delivers the RNG to the customer because that is when the performance obligations have been satisfied.

Fair Value Measurements. The Partnership measures certain of its assets and liabilities at fair value, which is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants – in either the principal market or the most advantageous market. The principal market is the market with the greatest level of activity and volume for the asset or liability.

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The common framework for measuring fair value utilizes a three-level hierarchy to prioritize the inputs used in the valuation techniques to derive fair values. The basis for fair value measurements for each level within the hierarchy is described below with Level 1 having the highest priority and Level 3 having the lowest.

•Level 1: Quoted prices in active markets for identical assets or liabilities.

•Level 2: Quoted prices in active markets for similar assets or liabilities; quoted prices for identical or similar instruments in markets that are not active; and model-derived valuations in which all significant inputs are observable in active markets.

•Level 3: Valuations derived from valuation techniques in which one or more significant inputs are unobservable.

Business Combinations. The Partnership accounts for business combinations using the acquisition method and accordingly, the assets and liabilities of the acquired entities are recorded at their estimated fair values at the acquisition date. Goodwill represents the excess of the purchase price over the fair value of the net assets acquired, including the amount assigned to identifiable intangible assets. The primary drivers that generate goodwill are the value of synergies between the acquired entities and the Partnership, and the acquired assembled workforce, neither of which qualifies as an identifiable intangible asset. Identifiable intangible assets with finite lives are amortized over their useful lives. The results of operations of acquired businesses are included in the condensed consolidated financial statements from the acquisition date. The Partnership expenses all acquisition-related costs as incurred.

Use of Estimates. The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America (“US GAAP”) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Estimates have been made by management in the areas of RNG revenue recognition, self-insurance and litigation reserves, pension and other postretirement benefit liabilities and costs, valuation of derivative instruments, depreciation and amortization of long-lived assets, asset impairment assessments, tax valuation allowances, allowances for doubtful accounts, and purchase price allocation for acquired businesses. The Partnership uses Society of Actuaries life expectancy information when developing the annual mortality assumptions for the pension and postretirement benefit plans, which are used to measure net periodic benefit costs and the obligation under these plans. Actual results could differ from those estimates, making it reasonably possible that a material change in these estimates could occur in the near term.

Transferable Tax Credits. In accordance with the Inflation Reduction Act of 2022 (“IRA”), RNG produced in the United States and sold for use as a transportation fuel may qualify for the Clean Fuel Production Tax Credit (“PTC”) under Section 45Z of the Internal Revenue Code. Section 45Z was enacted as part of the IRA and is administered primarily by the U.S. Department of Treasury (“Treasury”) and Internal Revenue Service, in coordination with other federal agencies, including the Environmental Protection Agency and the U.S. Department of Energy. The IRA was designed, in part, to incentivize the development and production of renewable and low carbon energy. On July 4, 2025, The One, Big, Beautiful Bill Act (“OBBBA”) was signed into law, extending the availability of the Section 45Z credit from December 31, 2027 to December 31, 2029. Accordingly, qualifying credits may be claimed for eligible RNG produced and sold after December 31, 2024, and before January 1, 2030.

Although Section 45Z became effective on January 1, 2025, the Partnership did not previously recognize any benefit from these credits pending additional regulatory clarity regarding eligibility, lifecycle greenhouse gas emissions calculations, and transferability. On February 4, 2026, proposed Treasury regulations published in the Federal Register provided sufficient clarity for the Partnership to conclude that the production and sale of its RNG qualifies for the credit.

The value of PTCs earned is based on the statutory base credit rate of $0.20 per gallon equivalent, adjusted for applicable prevailing wage and apprenticeship compliance, lifecycle greenhouse gas emissions calculations, qualifying production and sales volumes, and prevailing market prices for transferable tax credits. Where applicable prevailing wage and apprenticeship requirements are satisfied, the credit may be increased up to five times the base amount. The amount recognized reflects the Partnership’s estimate of credits earned based on currently available guidance, applicable carbon intensity scores, and anticipated monetization values. Actual amounts ultimately realized may differ upon the issuance of final regulations and the ultimate transfer or utilization of the credits.

The Partnership made an accounting policy election to record PTCs as a nonmonetary asset at the estimated fair value to be realized. These non-monetary assets are recognized within “Other current assets” within the condensed consolidated balance sheets, while the corresponding benefit is reported on a net basis within “Operating” expense in the condensed consolidated statements of operations.

During the second quarter of fiscal 2026, following the aforementioned release of additional guidance from the Treasury on February 4, 2026, the Partnership recognized $3,500 of PTCs, of which $2,700 related to calendar year 2025 and $800 related to the second quarter of fiscal 2026.

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Recently Issued Accounting Pronouncements. In December 2023, the FASB issued Accounting Standards Update (“ASU”) 2023-09, “Income Taxes: Improvements to Income Tax Disclosures” (“Topic 740”). This update requires disclosure of specific categories and disaggregation of information in the income tax rate reconciliation table. Topic 740 also requires disclosure of disaggregated information related to income taxes paid, income or loss from continuing operations before income tax expense or benefit, and income tax expense or benefit from continuing operations. The requirements of Topic 740 are effective for annual periods beginning after December 15, 2024, which will be the Partnership’s fiscal 2026 annual report. Early adoption is permitted and the amendments should be applied on a prospective basis with retrospective application also being permitted. The Partnership is assessing the effect of this update on its consolidated financial statements and related disclosures.

In November 2024, the FASB issued ASU 2024-03, “Disaggregation of Income Statement Expenses” (“Subtopic 220-40”) and in January 2025, the FASB issued ASU 2025-01, “Income Statement - Reporting Comprehensive Income - Expense Disaggregation Disclosures.” This update requires enhanced disclosure of income statement expense categories to improve transparency and provide financial statement users with more detailed information about the nature, amount and timing of expenses impacting financial performance. Subtopic 220-40 may be applied either prospectively or retrospectively and, as clarified by ASU 2025-01, is effective for fiscal years beginning after December 15, 2026 and interim periods beginning after December 15, 2027. Subtopic 220-40 will first be effective for the Partnership’s 2028 annual report. The Partnership is assessing the effect of this update on its consolidated financial statements and related disclosures.

Recently Adopted Accounting Pronouncements. On the first day of fiscal 2025, the Partnership adopted the guidance under ASU 2023-07, “Segment Reporting: Improvements to Reportable Segment Disclosures” (“Topic 280”). This update required public entities to disclose significant segment expenses that are regularly provided to the chief operating decision maker and included within segment profit and loss. Beginning with the Annual Report for fiscal 2025, the adoption of Topic 280 resulted in incremental segment reporting disclosures, most notably disclosure of cost of products sold and operating expenses for each reportable segment. See Note 19, "Segment Information" for more information.

On the first day of the second quarter of fiscal 2026, the Partnership early adopted the guidance under ASU 2025-10, “Government Grants: Accounting for Government Grants Received by Business Entities” (“Topic 832”) via a modified retrospective approach. Topic 832 established authoritative guidance for the recognition, measurement and presentation of government grants and certain tax credits, including PTCs under Section 45Z of the Internal Revenue Code.

3.Disaggregation of Revenue

The following table disaggregates revenue for each customer type. See Note 19, “Segment Information” for more information on segment reporting wherein it is disclosed that the Partnership’s Propane, Fuel Oil and Refined Fuels and Natural Gas and Electricity reportable segments generated approximately 89%, 5% and 2%, respectively, of the Partnership’s revenue for all periods presented. The propane segment contributes the majority of the Partnership’s revenue and the concentration of revenue by customer type for the propane segment is not materially different from the consolidated revenue.

	Three Months Ended
	March 28,				March 29,
	2026				2025
Retail
Residential	$	329,249			$	340,280
Commercial		139,248				149,136
Industrial		37,570				38,466
Government		28,660				30,015
Agricultural		11,759				13,428
Wholesale		4,720				16,338
Total revenues	$	551,206			$	587,663

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	Six Months Ended
	March 28,				March 29,
	2026				2025
Retail
Residential	$	532,991			$	537,394
Commercial		243,105				253,878
Industrial		68,187				68,610
Government		46,385				47,464
Agricultural		22,114				23,088
Wholesale		8,810				30,558
Total revenues	$	921,592			$	960,992

The Partnership recognized $31,804 and $73,054 of revenue during the three and six months ended March 28, 2026 , respectively, and $41,033 and $77,155 of revenue during the three and six months ended March 29, 2025, respectively, for annually billed tank rent, maintenance service contracts, fixed price contracts and budgetary programs where customer consideration was received at the start of the contract period, and which was included in contract liabilities as of the beginning of each respective period. Contract assets of $21,379 and $5,806 relating to deliveries to customers enrolled in budgetary programs that exceeded billings to those customers were included in accounts receivable as of March 28, 2026 and September 27, 2025, respectively.

4.Investments in and Acquisitions of Businesses

On December 28, 2022, Suburban Renewable Energy acquired a platform of RNG production assets (the “RNG Acquisition”) from Equilibrium Capital Group (“Equilibrium”), a leading sustainability-driven asset management firm. The purchase price was $190,000 for two operating facilities located in Stanfield, AZ and Columbus, OH, along with potential contingent consideration with an initial fair value of $6,194 that Equilibrium could earn based upon the future economic performance of the acquired RNG assets, and a percentage of the monetization of PTCs earned during calendar years 2025 through 2027 if the acquired RNG assets meet a specified annual EBITDA threshold during the same three-year period. The Partnership determined that the fair value of the contingent consideration to Equilibrium as of September 27, 2025 was $0, resulting in income of $6,194 in fiscal 2025, which was recorded in “Other, net” within the consolidated statement of operations. There was no change in the fair value as of March 28, 2026.

The purchase agreement also included potential contingent consideration payable by Equilibrium to Suburban Renewable Energy based on the costs to construct a gas upgrade system at the Columbus, OH facility. According to the purchase agreement, expenditures for the gas upgrade equipment project that exceeded a certain amount would be funded by Equilibrium, up to a total of $3,000, if the Partnership incurred those costs prior to December 31, 2024. During the first quarter of fiscal 2025, the Partnership recorded a $3,000 increase in the fair value of this contingent consideration, which was recognized as income within “Other, net” on the Partnership’s consolidated statement of operations for fiscal 2025. There was no change in the fair value as of March 28, 2026.

Suburban Renewable Energy owns a 19% equity stake in Independence Hydrogen, Inc. (“IH”) based in Ashburn, VA and has also purchased certain secured convertible notes issued by IH. IH is a veteran-owned and operated, privately held company developing a gaseous hydrogen ecosystem to deliver locally sourced hydrogen to local markets, with a primary focus on material handling and backup power applications. During the first quarter of fiscal 2025, the Partnership recorded an other-than-temporary impairment charge of $9,595, recognized in “Other, net” on the condensed consolidated statement of operations, to write down the carrying value of its investment in IH to its estimated fair value of $21,589 based on third-party investment discussions. The Partnership will continue to monitor IH’s financial condition and other available information to determine if future adjustments are necessary.

The Operating Partnership owns a 38% equity stake in Oberon Fuels, Inc. (“Oberon”) based in San Diego, California and has also purchased certain secured convertible notes issued by Oberon. Oberon is a development-stage producer of low-carbon, renewable dimethyl ether (“rDME”) which can be used in multiple applications as a renewable alternative; including as a replacement for diesel and as a blend with propane for use in the transportation sector. As a development-stage entity, Oberon is reliant on raising capital to fund its operations and strategic growth initiatives. Due to Oberon’s financial condition, which raised substantial doubts about its ability to continue as a going concern, as well as the uncertainty about potential third-party capital infusion, the Partnership determined that its investment in Oberon was fully impaired as of December 28, 2024. During the first quarter of fiscal 2025, the Partnership recorded an other-than-temporary impairment charge of $10,213, recognized in “Other, net” on the condensed consolidated statement of operations, to write down the carrying value of its investment in Oberon to $0.

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Suburban Renewable Energy owns a minority equity stake in another privately-held, development-stage entity. Due to this entity’s financial condition, which raised substantial doubts about its ability to continue as a going concern, as well as the uncertainty about potential third-party capital infusion, the Partnership determined that its investment in this entity was fully impaired as of September 27, 2025. During the fourth quarter of fiscal 2025, the Partnership recorded an other-than-temporary impairment charge of $6,095, recognized in “Other, net” on the condensed consolidated statement of operations, to write down the carrying value of its investment to $0.

The investments in IH and Oberon are being accounted for under the equity method of accounting and were included in “Other assets” within the condensed consolidated balance sheets, and the Partnership’s equity in their losses were included in “Other, net” within the condensed consolidated statements of operations. The investment in the other development-stage entity is being accounted for under the cost method of accounting and was included in “Other assets” within the condensed consolidated balance sheets.

On October 14, 2025, the Partnership acquired the propane assets and operations of a propane retailer headquartered in California for $14,000, including $500 for non-compete consideration, plus working capital acquired. As of March 28, 2026, $13,829 was paid, including working capital, and the remainder of the purchase price will be funded in accordance with the terms of the asset purchase and non-compete agreements.

On October 16, 2025, the Partnership acquired the propane assets and operations of another propane retailer headquartered in California for $10,000, including $1,000 for non-compete consideration, plus working capital acquired. As of March 28, 2026, $9,104 was paid, including working capital, and the remainder of the purchase price will be funded in accordance with the terms of the asset purchase and non-compete agreements.

These acquisitions were consummated pursuant to the Partnership’s strategic growth initiatives for the core propane business. The preliminary purchase price allocations and results of operations of the acquired businesses were not material to the Partnership’s condensed consolidated financial position and statement of operations.

5.Financial Instruments and Risk Management

Cash, Cash Equivalents and Restricted Cash. The Partnership considers all highly liquid instruments purchased with an original maturity of three months or less to be cash equivalents. In accordance with the indenture, as amended, and loan agreement, as amended, governing the Green Bonds assumed in the RNG Acquisition (see Notes 4 and 10), the Partnership is required to maintain certain funds in various accounts that are held with a third-party trustee for debt service and other purposes. The amounts deposited in those accounts are considered Restricted Cash and are reported within other current assets (or other assets, as applicable). The balance classified as short-term included accounts for which the cash will be used within one year, and are related to interest payments as well as operating and maintenance activities for the RNG facility in Arizona. The balance classified as long-term represented cash held in a debt service fund for future debt repayments on the Green Bonds for which the first debt redemption payment is due on October 1, 2028. Refer to Note 6, “Selected Balance Sheet and Statement of Operations Information” for a reconciliation of cash, cash equivalents, and restricted cash. The carrying amount approximates fair value because of the short-term maturity of these instruments.

Derivative Instruments and Hedging Activities

Commodity Price Risk. Given the retail nature of its operations, the Partnership maintains a certain level of priced physical inventory to help ensure its field operations have adequate supply commensurate with the time of year. The Partnership’s strategy is to keep its physical inventory priced relatively close to market for its field operations. The Partnership enters into a combination of exchange-traded futures and option contracts and, in certain instances, over-the-counter options and swap contracts (collectively, “derivative instruments”) to hedge price risk associated with propane and fuel oil physical inventories, as well as future purchases of propane or fuel oil used in its operations, and to help ensure adequate supply during periods of high demand. In addition, the Partnership sells propane, fuel oil, electricity and natural gas to customers at fixed prices, and enters into derivative instruments to hedge a portion of its exposure to fluctuations in commodity prices as a result of selling the fixed price contracts. Under this risk management strategy, realized gains or losses on derivative instruments will typically offset losses or gains on the physical inventory once the product is sold or delivered as it pertains to fixed price contracts. All of the Partnership’s derivative instruments are reported on the condensed consolidated balance sheet at their fair values. In addition, in the course of normal operations, the Partnership routinely enters into contracts such as forward priced physical contracts for the purchase or sale of propane and fuel oil that qualify for and are designated as normal purchase or normal sale contracts. Such contracts are exempted from the fair value accounting requirements and are accounted for at the time product is purchased or sold under the related contract. The Partnership does not use derivative instruments for speculative trading purposes. Market risks associated with derivative instruments are monitored daily for compliance with the Partnership’s Hedging and Risk Management Policy which includes volume limits for open positions. Priced on-hand inventory is also reviewed and managed daily as to exposures to changing market prices.

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On the date that derivative instruments are entered into, other than those designated as normal purchases or normal sales, the Partnership makes a determination as to whether the derivative instrument qualifies for designation as a hedge. Changes in the fair value of derivative instruments are recorded each period in current period earnings or other comprehensive income (“OCI”), depending on whether the derivative instrument is designated as a hedge and, if so, the type of hedge. For derivative instruments designated as cash flow hedges, the Partnership formally assesses, both at the hedge contract’s inception and on an ongoing basis, whether the hedge contract is highly effective in offsetting changes in cash flows of hedged items. Changes in the fair value of derivative instruments designated as cash flow hedges are reported in OCI to the extent effective and reclassified into earnings during the same period in which the hedged item affects earnings. The mark-to-market gains or losses on ineffective portions of cash flow hedges are recognized in earnings immediately. Changes in the fair value of derivative instruments that are not designated as cash flow hedges, and that do not meet the normal purchase and normal sale exemption, are recorded within earnings as they occur. Cash flows associated with derivative instruments are reported as operating activities within the condensed consolidated statement of cash flows.

Interest Rate Risk. A portion of the Partnership’s borrowings bear interest at prevailing interest rates based upon, at the Operating Partnership’s option, Secured Overnight Financing Rate (“SOFR”) plus an applicable margin or the base rate, defined as the higher of the Federal Funds Rate plus ½ of 1% or the agent bank’s prime rate, or SOFR plus 1%, plus the applicable margin. The applicable margin is dependent on the level of the Partnership’s total leverage (the ratio of total debt to income before deducting interest expense, income taxes, depreciation and amortization (“EBITDA”), as adjusted pursuant to the Credit Agreement). Therefore, the Partnership is subject to interest rate risk on the variable component of the interest rate. From time to time, the Partnership manages part of its variable interest rate risk by entering into interest rate swap agreements. The Partnership did not enter into any interest rate swap agreements during the first half of fiscal 2026 or in fiscal 2025.

Valuation of Derivative Instruments. The Partnership measures the fair value of its exchange-traded options and futures contracts using quoted market prices found on the New York Mercantile Exchange (“NYMEX”) (Level 1 inputs); the fair value of its swap contracts using quoted forward prices and the fair value of its interest rate swaps using model-derived valuations driven by observable projected movements of the 3-month SOFR (Level 2 inputs); and the fair value of its over-the-counter options contracts using Level 3 inputs. The Partnership’s over-the-counter options contracts are valued based on an internal option model. The inputs utilized in the model are based on publicly available information as well as broker quotes. The significant unobservable inputs used in the fair value measurements of the Partnership’s over-the-counter options contracts are interest rate and market volatility.

The following summarizes the fair value of the Partnership’s derivative instruments and their location in the condensed consolidated balance sheets as of March 28, 2026 and September 27, 2025, respectively:

		As of March 28, 2026						As of September 27, 2025
Asset Derivatives		Location		Fair Value				Location		Fair Value
Derivatives not designated as    hedging instruments:
Commodity-related derivatives		Other current assets		$	5,815			Other current assets		$	1,504
		Other assets			—			Other assets			102
				$	5,815					$	1,606
Liability Derivatives		Location		Fair Value				Location		Fair Value
Derivatives not designated as    hedging instruments:
Commodity-related derivatives		Other current liabilities		$	6,974			Other current liabilities		$	1,883
		Other liabilities			—			Other liabilities			53
				$	6,974					$	1,936

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The following summarizes the reconciliation of the beginning and ending balances of assets and liabilities measured at fair value on a recurring basis using significant unobservable inputs:

		Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
		Six Months Ended								Six Months Ended
		March 28, 2026								March 29, 2025
		Assets				Liabilities				Assets				Liabilities
Beginning balance of over-the-counter options		$	572			$	250			$	1,475			$	193
Beginning balance realized during the period			(325	)			(180	)			(1,141	)			(119	)
Contracts purchased during the period			—				—				58				—
Change in the fair value of outstanding contracts			388				(70	)			(304	)			(74	)
Ending balance of over-the-counter options		$	635			$	—			$	88			$	—

As of March 28, 2026 and September 27, 2025, the Partnership’s outstanding commodity-related derivatives had a weighted average maturity of approximately four and seven months, respectively.

The effect of the Partnership’s derivative instruments on the condensed consolidated statements of operations for the three and six months ended March 28, 2026 and March 29, 2025 are as follows:

Three Months Ended March 28, 2026

Three Months Ended March 29, 2025

Derivatives Not Designated as Hedging Instruments

Unrealized Gains (Losses)  Recognized in Income

Unrealized Gains (Losses) Recognized in Income

Location

Amount

Location

Amount

Commodity-related derivatives

Cost of products sold

$

(1,358

)

Cost of products sold

$

744

Six Months Ended March 28, 2026

Six Months Ended March 29, 2025

Derivatives Not Designated as Hedging Instruments

Unrealized Gains (Losses) Recognized in Income

Unrealized Gains (Losses) Recognized in Income

Location

Amount

Location

Amount

Commodity-related derivatives

Cost of products sold

$

(428

)

Cost of products sold

$

4,378

The following table presents the fair value of the Partnership’s recognized derivative assets and liabilities on a gross basis and amounts offset on the condensed consolidated balance sheets subject to enforceable master netting arrangements or similar agreements:

		As of March 28, 2026												As of September 27, 2025
										Net amounts												Net amounts
										presented in the												presented in the
		Gross amounts				Effects of netting				balance sheet				Gross amounts				Effects of netting				balance sheet
Asset Derivatives
Commodity-related derivatives		$	21,105			$	(15,290	)		$	5,815			$	4,213			$	(2,607	)		$	1,606
Liability Derivatives
Commodity-related derivatives		$	22,264			$	(15,290	)		$	6,974			$	4,543			$	(2,607	)		$	1,936

The Partnership had $4,572 and $2,813 of posted cash collateral as of March 28, 2026 and September 27, 2025, respectively, with its brokers for outstanding commodity-related derivatives.

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Bank Debt, Green Bonds and Senior Notes. The fair value of the Revolving Credit Facility approximates the carrying value since the interest rates are adjusted quarterly to reflect market conditions. The fair values of the Senior Notes are based upon quoted market prices (a Level 1 input) and the fair value of the Green Bonds is based upon a valuation model (a Level 3 input). “Senior Notes,” “Revolving Credit Facility” and “Green Bonds” are defined below in Note 10, “Long-Term Borrowings.” The fair values of the Senior Notes and Green Bonds are as follows:

		As of
		March 28,				September 27,
		2026				2025
5.875% Senior Notes due March 1, 2027		$	—			$	349,125
5.00% Senior Notes due June 1, 2031			612,625				617,500
6.50% Senior Notes due December 15, 2035			340,375				—
5.50% Green Bonds due October 1, 2028 through October 1, 2033			68,364				71,090
		$	1,021,364			$	1,037,715

6.Selected Balance Sheet and Statement of Operations Information

Cash, Cash Equivalents and Restricted Cash. Restricted cash consists of amounts deposited in various bank accounts held by a trustee, as required for operating, maintenance and debt service purposes, all of which is stipulated in the loan agreement under the indenture to the Green Bonds. The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the condensed consolidated balance sheets that aggregate to the total shown on the condensed consolidated statements of cash flows:

		As of
		March 28,				September 27,
		2026				2025
Cash and cash equivalents		$	4,292			$	405
Restricted cash included in other current assets			4,352				3,302
Restricted cash included in other assets (noncurrent)			8,065				8,064
Total cash, cash equivalents, and restricted cash shown on the    condensed consolidated statements of cash flows		$	16,709			$	11,771

Inventories. Inventories are stated at the lower of cost or market. Cost is determined using a weighted average method for propane, fuel oil and refined fuels and natural gas, and a standard cost basis for appliances, which approximates average cost. Inventories consist of the following:

		As of
		March 28,				September 27,
		2026				2025
Propane, fuel oil and refined fuels and natural gas		$	59,541			$	69,694
Appliances			4,008				4,032
		$	63,549			$	73,726

Other, net. Other, net consists of the following:

		Three Months Ended							Six Months Ended
		March 28,				March 29,			March 28,				March 29,
		2026				2025			2026				2025
Equity in losses of IH (1)		$	375			$	504		$	696			$	10,547
Equity in losses of Oberon (2)			—				—			—				12,198
Contingent consideration from Equilibrium			—				—			—				(3,000	)
Other (3)			180				225			560				451
Other, net		$	555			$	729		$	1,256			$	20,196

(1)Six months ended March 29, 2025 included an other-than-temporary impairment charge of $9,595 (see Note 4 above).

(2)Six months ended March 29, 2025 included an other-than-temporary impairment charge of $10,213 (see Note 4 above).

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(3)Both periods included net periodic benefits costs for the Partnership’s pension and other post-retirement benefit plans (see Note 15 below). Six months ended March 28, 2026 included an other-than-temporary impairment charge of $200 related to a cost-method investee.

7.Goodwill and Other Intangible Assets

Goodwill represents the excess of the purchase price over the fair value of net assets acquired. Goodwill is subject to an impairment review at a reporting unit level, on an annual basis as of the end of fiscal July of each year, or when an event occurs or circumstances change that would indicate potential impairment.

The Partnership has the option to first assess qualitative factors to determine whether the existence of events or circumstances leads to a determination that it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If, after assessing the totality of events or circumstances, an entity determines it is not more likely than not that the fair value of a reporting unit is less than its carrying amount, then performing an impairment test is unnecessary. However, if an entity concludes otherwise, then it is required to perform an impairment test.

Under an impairment test, the Partnership assesses the carrying value of goodwill at a reporting unit level based on an estimate of the fair value of the respective reporting unit. Fair value of the reporting unit is estimated using discounted cash flow analyses taking into consideration estimated cash flows in a ten-year projection period and a terminal value calculation at the end of the projection period. If the fair value of the reporting unit exceeds its carrying value, the goodwill associated with the reporting unit is not considered to be impaired. If the carrying value of the reporting unit exceeds its fair value, an impairment loss is recognized to the extent that the carrying amount of the associated goodwill, if any, exceeds the implied fair value of the goodwill.

The carrying values of goodwill assigned to the Partnership’s operating segments are as follows:

						Fuel oil and				Natural gas
		Propane				refined fuels				and electricity				All other				Total
Balance as of September 27, 2025
Goodwill		$	1,114,230			$	10,900			$	7,900			$	31,259			$	1,164,289
Accumulated adjustments			—				(6,462	)			—				—				(6,462	)
		$	1,114,230			$	4,438			$	7,900			$	31,259			$	1,157,827
Fiscal 2026 Activity
Goodwill acquired (1)		$	7,189			$	—			$	—			$	—			$	7,189
Balance as of March 28, 2026
Goodwill		$	1,121,419			$	10,900			$	7,900			$	31,259			$	1,171,478
Accumulated adjustments			—				(6,462	)			—				—				(6,462	)
		$	1,121,419			$	4,438			$	7,900			$	31,259			$	1,165,016

Other intangible assets consist of the following:

		As of
		March 28,				September 27,
		2026				2025
Customer relationships (1)		$	604,195			$	596,429
Non-compete agreements (1)			47,455				45,955
Other			5,100				5,100
			656,750				647,484
Less: accumulated amortization
Customer relationships			(529,052	)			(523,636	)
Non-compete agreements			(38,296	)			(37,430	)
Other			(1,939	)			(1,641	)
			(569,287	)			(562,707	)
		$	87,463			$	84,777

(1)Reflects the impact from acquisitions (See Note 4).

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8.Leases

The Partnership leases certain property, plant and equipment, including portions of its vehicle fleet, for various periods under noncancelable leases, all of which were determined to be operating leases. The Partnership determines if an agreement contains a lease at inception based on the Partnership’s right to the economic benefits of the leased assets and its right to direct the use of the leased asset. Right-of-use assets represent the Partnership’s right to use an underlying asset, and right-of-use liabilities represent the Partnership’s obligation to make lease payments arising from the lease. Right-of-use assets and liabilities are recognized at the lease commencement date based on the present value of the lease payments over the lease term. As most of the Partnership’s leases do not provide an implicit rate, the Partnership uses its estimated incremental borrowing rate based on the information available at the commencement date, adjusted for the lease term, to determine the present value of the lease payments. This rate is calculated based on a collateralized rate for the specific leasing activities of the Partnership.

Some leases include one or more options to renew at the Partnership’s discretion, with renewal terms that can extend the lease from one to fifteen additional years. The renewal options are included in the measurement of the right-of-use assets and lease liabilities if the Partnership is reasonably certain to exercise the renewal options. Short-term leases are leases having an initial term of twelve months or less. The Partnership recognizes expenses for short-term leases on a straight-line basis and does not record a lease asset or lease liability for such leases.

The Partnership has residual value guarantees associated with certain of its operating leases, related primarily to transportation equipment. See Note 14, “Guarantees” for more information.

The Partnership does not have any material lease obligations that were signed, but not yet commenced, as of March 28, 2026.

Quantitative information on the Partnership’s lease population is as follows:

		Three Months Ended									Six Months Ended
		March 28,				March 29,					March 28,				March 29,
		2026				2025					2026				2025
Lease expense		$	10,701			$	11,171				$	21,922			$	22,378
Other information:
Cash payments for operating leases			10,802				11,301					22,035				22,544
Right-of-use assets obtained in exchange for new    operating lease liabilities			1,200				755					4,627				7,316
Weighted-average remaining lease term											5.4 years				5.5 years
Weighted-average discount rate												6.3	%			6.2	%

The following table summarizes future minimum lease payments under noncancelable operating leases as of March 28, 2026:

Fiscal Year		Operating Leases
2026 (remaining)		$	19,868
2027			31,226
2028			25,312
2029			18,361
2030			11,363
2031 and thereafter			20,129
Total future minimum lease payments		$	126,259
Less: interest			(20,733	)
Total lease obligations		$	105,526

9.Net Income Per Common Unit

Computations of basic income per Common Unit are performed by dividing net income by the weighted average number of outstanding Common Units and vested (and unissued) restricted units granted under the Partnership’s Restricted Unit Plan, as defined below, to retirement-eligible grantees. Computations of diluted income per Common Unit are performed by dividing net income by the weighted average number of outstanding Common Units and unvested restricted units granted under the Restricted Unit Plan. In computing diluted net income per Common Unit, weighted average units outstanding used to compute basic net income per Common Unit were

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increased by 339,144 and 296,834 units for the three and six months ended March 28, 2026, respectively, and 386,750 and 323,179 units for the three and six months ended March 29, 2025, respectively, to reflect the potential dilutive effect of the unvested restricted units outstanding using the treasury stock method.

10.Long-Term Borrowings

Long-term borrowings consist of the following:

		As of
		March 28,				September 27,
		2026				2025
5.875% senior notes, due March 1, 2027		$	—			$	350,000
5.00% senior notes, due June 1, 2031			650,000				650,000
6.50% senior notes, due December 15, 2035			350,000				—
5.50% Green Bonds, due October 1, 2028 through October 1, 2033, net of unaccreted fair value adjustment of $10,140 and $10,953			70,505				69,692
Revolving Credit Facility, due March 15, 2029			200,300				149,200
Subtotal			1,270,805				1,218,892
Less: unamortized debt issuance costs			(11,757	)			(7,147	)
		$	1,259,048			$	1,211,745

Senior Notes

2027 Senior Notes. On February 14, 2017, the Partnership and its 100%-owned subsidiary, Suburban Energy Finance Corp., completed a public offering of $350,000 in aggregate principal amount of 5.875% senior notes due March 1, 2027 (the “2027 Senior Notes”). The 2027 Senior Notes were issued at 100% of the principal amount and required semi-annual interest payments in March and September. The net proceeds from the issuance of the 2027 Senior Notes, along with borrowings under the Revolving Credit Facility, were used to repurchase, satisfy and discharge all of the Partnership’s then-outstanding 7.375% senior notes due in 2021.

On December 22, 2025, the Partnership redeemed, satisfied and discharged all of its previously outstanding 2027 Senior Notes with net proceeds from the issuance of the 2035 Senior Notes, as defined below, and borrowings under the Revolving Credit Facility, also as defined below. In connection with this redemption, satisfaction and discharge, the Partnership recognized a $1,183 loss on debt extinguishment consisting of the write-off of unamortized debt origination costs for the 2027 Senior Notes, as well as other fees and expenses.

2031 Senior Notes. On May 24, 2021, the Partnership and its 100%-owned subsidiary, Suburban Energy Finance Corp., completed a private offering of $650,000 in aggregate principal amount of 5.0% senior notes due June 1, 2031 (the “2031 Senior Notes”) to “qualified institutional buyers,” as defined in Rule 144A under the Securities Act of 1933, as amended (the “Securities Act”), and non-U.S. persons outside the United States under Regulation S under the Securities Act. The 2031 Senior Notes were issued at 100% of the principal amount and require semi-annual interest payments in June and December. The net proceeds from the issuance of the 2031 Senior Notes, along with borrowings under the Revolving Credit Facility, were used to repurchase, satisfy and discharge all of the Partnership’s then-outstanding 5.50% senior notes due in 2024 and 5.75% senior notes due in 2025.

2035 Senior Notes. On December 22, 2025, the Partnership and its 100%-owned subsidiary, Suburban Energy Finance Corp., completed a private offering of $350,000 in aggregate principal amount of 6.50% senior notes due December 15, 2035 (the “2035 Senior Notes”) to “qualified institutional buyers,” as defined in Rule 144A under the Securities Act, and non-U.S. persons outside the United States under Regulation S under the Securities Act. The 2035 Senior Notes were issued at 100% of the principal amount and require semi-annual interest payments in June and December. The net proceeds from the issuance of the 2035 Senior Notes, along with borrowings under the Revolving Credit Facility, were used to redeem, satisfy and discharge all of the 2027 Senior Notes.

At any time prior to December 15, 2028, the Partnership may on any one or more occasions redeem up to 35% of the aggregate principal amount of the 2035 Senior Notes at a redemption price of 106.500% of the principal amount thereof, plus accrued and unpaid interest, if any, with the net cash proceeds of one or more equity offerings, subject to the conditions described more fully in the indenture for the 2035 Senior Notes. The 2035 Senior Notes are redeemable, at the Partnership’s option, in whole or in part, at any time on or after December 15, 2030, in each case at the redemption prices described below, together with any accrued and unpaid interest to the date of the redemption.

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Year		Percentage
2030		103.250%
2031		102.167%
2032		101.083%
2033 and thereafter		100.000%

The Partnership’s obligations under the 2031 Senior Notes and 2035 Senior Notes (collectively, the “Senior Notes”) are unsecured and rank senior in right of payment to any future subordinated indebtedness and equally in right of payment with any future senior indebtedness. The Senior Notes are structurally subordinated to, which means they rank effectively behind, any debt and other liabilities of the Operating Partnership. The Partnership is permitted to redeem some or all of the Senior Notes at redemption prices and times as specified in the indentures governing the Senior Notes. The Senior Notes each have a change of control provision that would require the Partnership to offer to repurchase the notes at 101% of the principal amount repurchased, if a change of control, as defined in the indentures governing the terms of the Senior Notes, occurs and is followed by a rating decline (a decrease in the rating of the notes by either Moody’s Investors Service or Standard and Poor’s Rating Group by one or more gradations) within 90 days of the consummation of the change of control.

Green Bonds. On December 28, 2022, the Partnership assumed the loan agreement under the Indentures of Trust, issued by The Industrial Development Authority of the County of Pinal (“Green Bonds”) from Equilibrium in connection with the RNG Acquisition. The proceeds of the Green Bonds, which bear interest at 5.5%, were loaned to and used by Equilibrium to construct the RNG production facility in Stanfield, Arizona (“SuburbanRNG–Stanfield”) and are secured by all of the assets at that location. The Green Bonds have a par value of $80,645 and require semi-annual interest payments in April and October. Principal payments begin on October 1, 2028 and continue annually through October 1, 2033. The Green Bonds were initially recorded at fair value at the time of the RNG Acquisition and are being accreted to par value over the term of the bonds using the effective interest method.

The Green Bonds contain various restrictive and affirmative covenants, and previously included a financial covenant requiring SuburbanRNG–Stanfield’s debt service coverage ratio, as defined therein, to be not less than 1.00 to 1.00 for three consecutive fiscal quarters. Effective May 2, 2025, the Operating Partnership entered into a guaranty agreement with the trustee under the Indentures of Trust whereby it guarantees all payments due under the Green Bonds, and amended the indenture governing the Green Bonds to eliminate the debt service coverage ratio covenant.

Credit Agreement. On March 15, 2024, the Partnership and the Operating Partnership entered into a Fourth Amended and Restated Credit Agreement (the “Credit Agreement”) that provides for a $500,000 revolving credit facility (the “Revolving Credit Facility”), of which $200,300 and $149,200 was outstanding as of March 28, 2026 and September 27, 2025, respectively. The Revolving Credit Facility matures on March 15, 2029. Borrowings under the Revolving Credit Facility may be used for general corporate purposes, including working capital, capital expenditures and acquisitions. The Operating Partnership has the right to prepay any borrowings under the Revolving Credit Facility, in whole or in part, without penalty at any time prior to maturity.

The Credit Agreement contains certain restrictive and affirmative covenants applicable to the Operating Partnership, its subsidiaries and the Partnership, as well as certain financial covenants, including (a) requiring the Partnership’s Consolidated Interest Coverage Ratio, as defined in the Credit Agreement, to be not less than 2.5 to 1.0 as of the end of any fiscal quarter, (b) prohibiting the Total Consolidated Leverage Ratio, as defined in the Credit Agreement, of the Partnership from being greater than 5.75 to 1.0, and (c) prohibiting the Senior Secured Consolidated Leverage Ratio, as defined in the Credit Agreement, of the Operating Partnership from being greater than 3.25 to 1.0 as of the end of any fiscal quarter.

The Partnership and certain subsidiaries of the Operating Partnership act as guarantors with respect to the obligations of the Operating Partnership under the Credit Agreement pursuant to the terms and conditions set forth therein. The obligations under the Credit Agreement are secured by liens on substantially all of the personal property of the Partnership, the Operating Partnership and their subsidiaries, as well as mortgages on certain real property.

As of March 28, 2026, borrowings under the Revolving Credit Facility bear interest at prevailing interest rates based upon, at the Operating Partnership’s option, SOFR plus the Applicable Rate (as defined in the Credit Agreement), or the base rate, defined as the higher of the Federal Funds Rate plus ½ of 1%, the administrative agent bank’s prime rate, or SOFR plus 1%, plus in each case the Applicable Rate. The Applicable Rate is dependent upon the Partnership’s Total Consolidated Leverage Ratio. As of March 28, 2026, the weighted average interest rate for borrowings under the Revolving Credit Facility was approximately 6.27%. The interest rate and the Applicable Rate will be reset following the end of each calendar quarter.

As of March 28, 2026, the Partnership had standby letters of credit issued under the Revolving Credit Facility of $23,886 which expire periodically through March 15, 2027.

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The Credit Agreement and the Senior Notes both contain various restrictive and affirmative covenants applicable to the Operating Partnership, its subsidiaries and the Partnership, respectively, including (i) restrictions on the incurrence of additional indebtedness, and (ii) restrictions on certain liens, investments, guarantees, loans, advances, payments, mergers, consolidations, distributions, sales of assets and other transactions. Under the Credit Agreement and the indentures governing the Senior Notes, the Operating Partnership and the Partnership are generally permitted to make cash distributions equal to available cash, as defined, as of the end of the immediately preceding quarter, if no event of default exists or would exist upon making such distributions, and with respect to the indentures governing the Senior Notes, the Partnership’s Consolidated Fixed Charge Coverage Ratio, as defined, is greater than 1.75 to 1. The Partnership and the Operating Partnership were in compliance with all covenants and terms of the Senior Notes and the Credit Agreement as of March 28, 2026.

The aggregate amounts of long-term debt maturities subsequent to March 28, 2026 are as follows: fiscal 2026: $-0-; fiscal 2027: $-0-; fiscal 2028: $-0-; fiscal 2029: $212,007; fiscal 2030: $12,352; and thereafter: $1,056,586.

11.Distributions of Available Cash

The Partnership makes distributions to its partners no later than 45 days after the end of each fiscal quarter in an aggregate amount equal to its Available Cash for such quarter. Available Cash, as defined in the Partnership Agreement, generally means all cash on hand at the end of the respective fiscal quarter, less the amount of cash reserves established by the Board of Supervisors in its reasonable discretion for future cash requirements. These reserves are retained for the proper conduct of the Partnership’s business, the payment of debt principal and interest and for distributions during the next four quarters.

On April 23, 2026, the Partnership announced a quarterly distribution of $0.325 per Common Unit, or $1.30 per Common Unit on an annualized basis, in respect of the second quarter of fiscal 2026, payable on May 12, 2026 to holders of record on May 5, 2026.

12.Unit-Based Compensation Arrangements

The Partnership recognizes compensation cost over the respective service period for employee services received in exchange for an award of equity, or equity-based compensation, based on the grant date fair value of the award. The Partnership measures liability awards under an equity-based payment arrangement based on remeasurement of the award’s fair value at the conclusion of each interim and annual reporting period until the date of settlement, taking into consideration the probability that the performance conditions will be satisfied.

Restricted Unit Plan. At the Partnership’s Tri-Annual Meeting held on May 15, 2018, the Unitholders approved and the Partnership adopted the Suburban Propane Partners, L.P. 2018 Restricted Unit Plan (the “Restricted Unit Plan”) authorizing the issuance of up to 1,800,000 Common Units to executives, managers and other employees and members of the Board of Supervisors of the Partnership. The Restricted Unit Plan was amended and restated to authorize the issuance of an additional 1,725,000 and 2,650,000 Common Units by approval of the Unitholders at the Partnership’s Tri-Annual Meetings held on May 18, 2021 and May 21, 2024, respectively, for a total of 6,175,000 Common Units. Unless otherwise determined by the Compensation Committee of the Partnership’s Board of Supervisors (the “Compensation Committee”) on or before the grant date, one-third of all outstanding awards under the Restricted Unit Plan will vest on each of the first three anniversaries of the award grant date. Participants in the Restricted Unit Plan are not eligible to receive quarterly distributions on, or vote, their respective restricted units until vested. Restricted units cannot be sold or transferred prior to vesting. The value of each restricted unit is established by the market price of the Common Unit on the date of grant, net of estimated future distributions during the vesting period. Restricted units are subject to forfeiture in certain circumstances as defined in the Restricted Unit Plan. Compensation expense for the unvested awards is recognized ratably over the vesting periods and is net of estimated forfeitures.

During the six months ended March 28, 2026, the Partnership awarded 401,733 restricted units under the Restricted Unit Plan at an aggregate grant date fair value of $6,711. The following is a summary of activity for the Restricted Unit Plan for the six months ended March 28, 2026:

						Weighted Average
		Restricted				Grant Date Fair
		Units				Value Per Unit
Outstanding September 27, 2025			927,421			$	14.35
Awarded			401,733				16.71
Forfeited			—				—
Vested (1)			(428,214	)			(14.47	)
Outstanding March 28, 2026			900,940			$	15.34

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(1)During fiscal 2026, the Partnership withheld 110,638 Common Units from participants for income tax withholding purposes for those executive officers of the Partnership whose shares of restricted units vested during the period.

As of March 28, 2026, unrecognized compensation cost related to unvested restricted units awarded under the Restricted Unit Plan amounted to $5,618. Compensation cost associated with unvested awards is expected to be recognized over a weighted-average period of approximately one year. Compensation expense for the Restricted Unit Plan, net of forfeitures, for the three and six months ended March 28, 2026 was $1,821 and $4,134, respectively, and $1,840 and $4,219 for the three and six months ended March 29, 2025, respectively.

Phantom Equity Plan. At its November 8, 2022 meeting, the Compensation Committee adopted the Phantom Equity Plan (the “PEP”) to incentivize behaviors that will lead to the creation of long-term value for the Partnership’s Unitholders by functioning as a cash-settled corollary plan to the Partnership’s Restricted Unit Plan. The executive officers of the Partnership, the members of the Board, and other employees of the Partnership are eligible for awards of phantom units under the PEP. Unless otherwise stipulated by the Compensation Committee, the standard vesting schedule for awards under the PEP will be one-third of each award on each of the first three anniversaries of the award grant date, subject to continuous employment or service from the grant date through the applicable payment date. Unvested awards are subject to forfeiture in certain circumstances, as defined in the PEP document and the applicable award agreements. Upon vesting, phantom units are automatically converted into cash equal to the average of the highest and lowest trading prices of the Partnership’s Common Units on the vesting date.

Compensation expense, which includes adjustments to previously recognized compensation expense for current period changes in the fair value of unvested awards, for the three and six months ended March 28, 2026 was $2,676 and $4,652, respectively, and for the three and six months ended March 29, 2025 was $3,620 and $5,194, respectively. As of March 28, 2026 and September 27, 2025, the Partnership had a liability included within accrued employment and benefit costs (or other liabilities, as applicable) of $9,853 and $11,561, respectively, related to the estimated future payments under the PEP.

Distribution Equivalent Rights Plan. On January 17, 2017, the Partnership adopted the Distribution Equivalent Rights Plan (the “DER Plan”), as amended on November 8, 2022, which gives the Compensation Committee discretion to award distribution equivalent rights (“DERs”) to executive officers of the Partnership. Once awarded, DERs entitle the grantee to a cash payment each time the Board of Supervisors declares a cash distribution on the Partnership’s Common Units, which cash payment will be equal to an amount calculated by multiplying the number of unvested restricted units and unvested phantom units which are held by the grantee on the record date of the distribution, by the amount of the declared distribution per Common Unit. Compensation expense recognized under the DER Plan for the three and six months ended March 28, 2026 was $340 and $682, respectively, and $362 and $716 for the three and six months ended March 29, 2025, respectively.

Long-Term Incentive Plan. On November 10, 2020, the Partnership adopted the 2021 Long-Term Incentive Plan (“the LTIP”). The LTIP is a non-qualified, unfunded, long-term incentive plan for executive officers and key employees that provides for payment, in the form of cash, of an award of equity-based compensation at the end of a three-year performance period. The LTIP document governs the terms and conditions of the outstanding awards with the level of compensation earned being based on the Partnership’s average distributable cash flow over the three-year measurement period. The level of compensation earned under the fiscal 2022 and 2023 awards and the still unvested fiscal 2024 and 2025 awards is evaluated using two separate measurement components: (i) 50% weight based on the level of average distributable cash flow of the Partnership over the three-year measurement period; and (ii) 50% weight based on the achievement of certain operating and strategic objectives, set by the Compensation Committee for that award’s three-year measurement period.

At its November 11, 2025 meeting, the Partnership adopted amendments to the LTIP to incorporate a third measurement component for award cycles that began with the fiscal 2026 award cycle that commenced at the beginning of fiscal 2026 and will conclude at the end of fiscal 2028. Under the amended LTIP, performance will be evaluated using the following measurement components: (i) 50% weight based on the average distributable cash flow of the Partnership over the three-year measurement period; (ii) 25% weight based on the achievement of certain operating and strategic objectives, set by the Compensation Committee for that award’s three-year measurement period; and (iii) 25% weight based on the level of adjusted EBITDA generated by the Partnership’s RNG business, as defined in the LTIP, over the three-year measurement period.

As a result of the quarterly remeasurement of the liability for awards under the LTIP, compensation expense recognized for the three and six months ended March 28, 2026 was $1,669 and $5,733, respectively, and $1,003 and $4,588 for the three and six months ended March 29, 2025, respectively. As of March 28, 2026 and September 27, 2025, the Partnership had a liability included within accrued employment and benefit costs (or other liabilities, as applicable) of $14,001 and $11,521, respectively, related to estimated future payments under the LTIP. In the first quarter of fiscal 2026 and 2025, cash payouts totaling $3,253 and $4,038 were made relating to the fiscal 2023 and 2022 awards, respectively.

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13.Commitments and Contingencies

Accrued Insurance. The Partnership is self-insured for general and product, workers’ compensation and automobile liabilities up to predetermined amounts above which third party insurance applies. As of March 28, 2026 and September 27, 2025, the Partnership had accrued liabilities of $59,443 and $56,685, respectively, representing the total estimated losses for known and anticipated or unasserted general and product, workers’ compensation and automobile claims. For the portion of the estimated liability that exceeds insurance deductibles, the Partnership records an asset within other assets (or prepaid expenses and other current assets, as applicable) related to the amount of the liability expected to be covered by insurance which amounted to $15,755 and $15,654 as of March 28, 2026 and September 27, 2025, respectively.

Legal Matters. The Partnership’s operations are subject to operating hazards and risks normally incidental to handling, storing and delivering combustible liquids such as propane. The Partnership has been, and will continue to be, a defendant in various legal proceedings and litigation as a result of these operating hazards and risks, and as a result of other aspects of its business. Although any litigation is inherently uncertain, based on past experience, the information currently available to the Partnership, and the amount of its accrued insurance liabilities, the Partnership does not believe that currently pending or threatened litigation matters, or known claims or known contingent claims, will have a material adverse effect on its results of operations, financial condition or cash flow.

The State of New York amended Section 349-d of the New York General Business Law (“GBL”) effective on March 18, 2024, to require that energy service companies that operate in the state, such as Agway Energy Services, LLC (“AES”) in connection with its natural gas and electricity business, first obtain written consent from the customer before any change in commodity prices can be charged to the customer. To date, the amended statute has not had a material negative impact on AES, but the Partnership continues to assess the impact that the GBL amendment may have in the future on its natural gas and electricity business. In addition, the New York Public Service Commission (“NY PSC”) has amended its Uniform Business Practices (“UBP”), that apply to AES and other energy supply companies that operate in the state. The UBP amendments require AES to provide notice to its customers that includes a historical comparison between the rates charged by AES and what the customer would have paid had they remained with their existing utility. The business model for AES provides for a bundled product offering in which a customer is charged one price for the commodity, plus the inclusion of a home warranty offering called EnergyGuard. This value-added warranty plan is a differentiator when comparing AES pricing with that of the local utility.

14.Guarantees

The Partnership has residual value guarantees associated with certain of its operating leases, related primarily to transportation equipment, with remaining lease periods scheduled to expire periodically through fiscal 2033. Upon completion of the lease period, the Partnership guarantees that the fair value of the equipment will equal or exceed the guaranteed amount, or the Partnership will pay the lessor the difference. Although the fair value of equipment at the end of its lease term has historically exceeded the guaranteed amounts, the maximum potential amount of aggregate future payments the Partnership could be required to make under these leasing arrangements, assuming the equipment is deemed worthless at the end of the lease term, was $41,730 as of March 28, 2026. The fair value of residual value guarantees for outstanding operating leases was de minimis as of March 28, 2026 and September 27, 2025.

15.Pension Plans and Other Postretirement Benefits

The following table provides the components of net periodic benefit costs:

		Pension Benefits
		Three Months Ended								Six Months Ended
		March 28,				March 29,				March 28,				March 29,
		2026				2025				2026				2025
Interest cost		$	619			$	647			$	1,238			$	1,293
Expected return on plan assets			(352	)			(330	)			(704	)			(659	)
Amortization of net loss			57				61				114				123
Net periodic benefit cost		$	324			$	378			$	648			$	757

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		Postretirement Benefits
		Three Months Ended								Six Months Ended
		March 28,				March 29,				March 28,				March 29,
		2026				2025				2026				2025
Interest cost		$	22			$	25			$	45			$	50
Amortization of prior service credits			(5	)			(7	)			(11	)			(13	)
Amortization of net (gain)			(161	)			(171	)			(322	)			(343	)
Net periodic benefit cost		$	(144	)		$	(153	)		$	(288	)		$	(306	)

The Partnership expects to contribute approximately $4,000 to the defined benefit pension plan during fiscal 2026, of which $2,000 was contributed during the six months ended March 28, 2026. The projected annual contribution requirements related to the Partnership’s postretirement health care and life insurance benefit plan for fiscal 2026 is $289, of which $128 was contributed during the six months ended March 28, 2026. The components of net periodic benefit cost are included in the line item “Other, net” in the condensed consolidated statements of operations.

The Partnership contributes to multi-employer pension plans (“MEPPs”) in accordance with various collective bargaining agreements covering union employees. As one of the many participating employers in these MEPPs, the Partnership is responsible with the other participating employers for any plan underfunding. As of March 28, 2026 and September 27, 2025, the Partnership’s estimated obligation to these MEPPs was $17,815 and $18,559, respectively, as a result of its voluntary full withdrawal from certain MEPPs.

16.Amounts Reclassified Out of Accumulated Other Comprehensive Income

The following table summarizes amounts reclassified out of accumulated other comprehensive income (loss) for the three and six months ended March 28, 2026 and March 29, 2025:

		Three Months Ended								Six Months Ended
		March 28,				March 29,				March 28,				March 29,
		2026				2025				2026				2025
Pension Benefits
Balance, beginning of period		$	(8,640	)		$	(9,747	)		$	(8,697	)		$	(9,809	)
Reclassifications to earnings:
Amortization of net loss (1)			57				61				114				123
Other comprehensive income			57				61				114				123
Balance, end of period		$	(8,583	)		$	(9,686	)		$	(8,583	)		$	(9,686	)
Postretirement Benefits
Balance, beginning of period		$	3,047			$	3,484			$	3,214			$	3,662
Reclassifications to earnings:
Amortization of net gain and prior service credits (1)			(166	)			(178	)			(333	)			(356	)
Other comprehensive loss			(166	)			(178	)			(333	)			(356	)
Balance, end of period		$	2,881			$	3,306			$	2,881			$	3,306
Accumulated Other Comprehensive Loss
Balance, beginning of period		$	(5,593	)		$	(6,263	)		$	(5,483	)		$	(6,147	)
Reclassifications to earnings			(109	)			(117	)			(219	)			(233	)
Other comprehensive loss			(109	)			(117	)			(219	)			(233	)
Balance, end of period		$	(5,702	)		$	(6,380	)		$	(5,702	)		$	(6,380	)

(1)These amounts are included in the computation of net periodic benefit cost. See Note 15, “Pension Plans and Other Postretirement Benefits.”

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17.At-the-Market Equity Program

On February 20, 2025, the Partnership entered into an Equity Distribution Agreement (the “Equity Distribution Agreement”) with Wells Fargo Securities, LLC, J.P. Morgan Securities LLC, BofA Securities, Inc., and Evercore Group L.L.C., each acting as a sales agent and/or principal (each, an “Agent,” and collectively, the “Agents”). Pursuant to the terms of the Equity Distribution Agreement, the Partnership may issue and sell from time to time, through the Agents, the Partnership’s Common Units having an aggregate offering amount of up to $100,000.

The Agents use their commercially reasonable efforts, as the sales agents and subject to the terms of the Equity Distribution Agreement, to sell the Common Units offered. Sales of the Common Units are deemed to be an “at the market offering” as defined in Rule 415(a)(4) promulgated under the Securities Act, including sales made directly on or through the New York Stock Exchange. The Partnership may also agree to sell Common Units to the Agents as principal for their own account on terms agreed to by the Partnership and the Agents. Each Agent will be entitled to a commission from the Partnership on the gross sales price per Common Unit sold under the Equity Distribution Agreement by such Agent acting as the Partnership’s sales agent.

During the six months ended March 28, 2026, the Partnership issued 171,745 Common Units under the Equity Distribution Agreement for net proceeds of $3,134, after $158 of agent commissions and offering costs. During the six months ended March 29, 2025, the Partnership issued 442,425 Common Units under the Equity Distribution Agreement for net proceeds of $8,788, after $295 of agent commissions and offering costs. The net proceeds from the sales of Common Units were used for general limited partnership purposes, including debt reduction and funding strategic growth initiatives.

18.Income Taxes

For federal income tax purposes, as well as for state income tax purposes in the majority of the states in which the Partnership operates, the earnings attributable to the Partnership and the Operating Partnership are not subject to income tax at the partnership level. With the exception of those states that impose an entity-level income tax on partnerships, the taxable income or loss attributable to the Partnership and to the Operating Partnership, which may vary substantially from the income (loss) before income taxes reported by the Partnership in the condensed consolidated statement of operations, are includable in the federal and state income tax returns of the Common Unitholders. The aggregate difference in the basis of the Partnership’s net assets for financial and tax reporting purposes cannot be readily determined as the Partnership does not have access to each Common Unitholder’s basis in the Partnership.

As described in Note 1, “Partnership Organization and Formation,” the earnings of the Corporate Entities are subject to U.S. corporate level income tax. However, based upon past performance, the Corporate Entities are currently reporting an income tax provision composed primarily of minimum state income taxes. A full valuation allowance has been provided against the deferred tax assets (with the exception of certain net operating loss carryforwards (“NOLs”) that arose after 2017) based upon an analysis of all available evidence, both negative and positive at the balance sheet date, which, taken as a whole, indicates that it is more likely than not that sufficient future taxable income will not be available to utilize the assets. Management’s periodic reviews include, among other things, the nature and amount of the taxable income and expense items, the expected timing of when assets will be used or liabilities will be required to be reported and the reliability of historical profitability of businesses that are expected to provide future earnings. Furthermore, management considered tax-planning strategies it could use to increase the likelihood that the deferred tax assets will be realized.

19.Segment Information

The Partnership manages and evaluates its operations in four operating segments, three of which are reportable segments: Propane, Fuel Oil and Refined Fuels and Natural Gas and Electricity. The chief operating decision maker (“CODM”) is the Partnership’s President and Chief Executive Officer, who evaluates performance of the operating segments using segment operating income (loss), to evaluate performance and to assist in making capital resource allocation decisions.

Costs excluded from these profit measures are captured in Corporate and include corporate overhead expenses not allocated to the operating segments. Unallocated corporate overhead expenses include all costs of back-office support functions that are reported as general and administrative expenses within the condensed consolidated statements of operations. In addition, certain costs associated with field operations support that are reported in operating expenses within the condensed consolidated statements of operations, including purchasing, training and safety, are not allocated to the individual operating segments. Thus, operating profit for each operating segment includes only the costs that are directly attributable to the operations of the individual segment. The accounting policies of the operating segments are otherwise the same as those described in Note 2, “Summary of Significant Accounting Policies,” in the Partnership’s Annual Report on Form 10-K for the fiscal year ended September 27, 2025.

The propane segment is primarily engaged in the retail distribution of propane and renewable propane to residential, commercial, industrial, agricultural and government customers and, to a lesser extent, wholesale distribution to large industrial end users. In the residential, commercial and government markets, propane is used primarily for space heating, water heating, cooking and clothes drying.

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Industrial customers use propane generally as a motor fuel burned in internal combustion engines that power over-the-road vehicles, forklifts and stationary engines, to fire furnaces and as a cutting gas. In the agricultural markets, propane is primarily used for tobacco curing, crop drying, poultry brooding and weed control. In addition, the Partnership's equity investment in Oberon is included within the propane segment.

The fuel oil and refined fuels segment is primarily engaged in the retail distribution of fuel oil, diesel, kerosene and gasoline to residential and commercial customers for use primarily as a source of heat in homes and buildings.

The natural gas and electricity segment is engaged in the marketing of natural gas and electricity to residential and commercial customers in the deregulated energy markets of New York and Pennsylvania. Under this operating segment, the Partnership owns the relationship with the end consumer and has agreements with the local distribution companies to deliver the natural gas or electricity from the Partnership’s suppliers to the customer.

Activities in the “all other” operating segment include the Partnership’s service business, which is primarily engaged in the sale, installation and servicing of a wide variety of home comfort equipment, particularly in the areas of heating and ventilation. In addition, the Partnership's platform of RNG businesses and the equity investment in IH are included within “all other.”

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The following table presents certain data by reportable segment and provides a reconciliation of total operating segment information to the corresponding condensed consolidated amounts for the periods presented:

		Three Months Ended								Six Months Ended
		March 28,				March 29,				March 28,				March 29,
		2026				2025				2026				2025
Revenues:
Propane		$	491,142			$	525,256			$	817,532			$	855,539
Fuel oil and refined fuels			32,354				33,364				50,521				51,025
Natural gas and electricity			8,778				9,025				14,677				15,078
Subtotal			532,274				567,645				882,730				921,642
All other			18,932				20,018				38,862				39,350
Total revenues		$	551,206			$	587,663			$	921,592			$	960,992
Cost of Products Sold: (1)
Propane		$	176,258			$	213,010			$	288,377			$	342,751
Fuel oil and refined fuels			20,255				20,134				31,555				30,685
Natural gas and electricity			7,490				5,840				10,660				8,396
Subtotal			204,003				238,984				330,592				381,832
All other			3,497				3,378				7,747				7,692
Total cost of products sold		$	207,500			$	242,362			$	338,339			$	389,524
Payroll & Payroll Benefit Expenses: (2)
Propane		$	51,971			$	50,899			$	96,176			$	92,754
Fuel oil and refined fuels			5,270				4,877				9,541				8,657
Natural gas and electricity			283				294				577				607
Subtotal			57,524				56,070				106,294				102,018
All other			17,112				16,329				33,218				32,276
Corporate			27,826				25,513				51,691				48,392
Total payroll & payroll benefit expenses		$	102,462			$	97,912			$	191,203			$	182,686
Vehicle: (3)
Propane		$	21,706			$	20,000			$	40,813			$	36,850
Fuel oil and refined fuels			989				992				1,683				1,759
Natural gas and electricity			—				—				—				—
Subtotal			22,695				20,992				42,496				38,609
All other			883				855				1,701				1,631
Corporate			2,878				3,948				5,740				8,083
Total vehicle expenses		$	26,456			$	25,795			$	49,937			$	48,323
Other Expenses: (4)
Propane		$	31,883			$	31,530			$	59,646			$	60,055
Fuel oil and refined fuels			1,298				1,214				2,447				2,113
Natural gas and electricity			1,073				1,032				1,998				2,151
Subtotal			34,254				33,776				64,091				64,319
All other			3,228				5,263				8,815				10,032
Corporate			3,144				6,542				10,530				13,934
Total other controllable expenses		$	40,626			$	45,581			$	83,436			$	88,285

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		Three Months Ended								Six Months Ended
		March 28,				March 29,				March 28,				March 29,
		2026				2025				2026				2025
Depreciation and amortization:
Propane		$	12,601			$	12,149			$	25,266			$	24,591
Fuel oil and refined fuels			263				269				528				538
Natural gas and electricity			—				—				—				—
Subtotal			12,864				12,418				25,794				25,129
All other			2,747				2,765				6,012				5,528
Corporate			640				2,417				1,309				4,042
Total depreciation and amortization		$	16,251			$	17,600			$	33,115			$	34,699
Operating income (loss):
Propane		$	196,723			$	197,668			$	307,254			$	298,538
Fuel oil and refined fuels			4,279				5,878				4,767				7,273
Natural gas and electricity			(68	)			1,859				1,442				3,924
Reportable segment operating income			200,934				205,405				313,463				309,735
Reconciliation to net income:
Corporate and all other operating (loss)			(43,023	)			(46,992	)			(87,901	)			(92,260	)
Loss on debt extinguishment			—				—				(1,183	)			—
Interest expense, net			(19,694	)			(20,567	)			(39,450	)			(40,179	)
Other, net			(555	)			(729	)			(1,256	)			(20,196	)
(Provision for) benefit from income taxes			(120	)			4				(351	)			(559	)
Net income		$	137,542			$	137,121			$	183,322			$	156,541

The CODM uses the following expense categories to manage the resources of the Partnership. These expense categories and amounts align with the segment-level information that is regularly provided to the CODM:

(1)The cost of products sold reported in the condensed consolidated statements of operations represents the weighted average unit cost of propane, fuel oil and refined fuels, and natural gas and electricity sold, including transportation costs to deliver products from the Partnership’s supply points to storage locations or to the Partnership’s customer service centers. Cost of products sold also includes the cost of appliances and related parts sold or installed computed on a basis that approximates the average cost of the products. Cost of products sold does not include depreciation and amortization expense.

(2)Payroll and payroll benefits expenses represent the compensation and benefit costs for field and direct operating support personnel.

(3)Vehicle expenses represent the costs of operating and maintaining the Partnership’s vehicle fleet and include fuel, lease expenses and maintenance and repair costs.

(4)Other expenses include all other costs such as self-insurance, professional services and all other expenses not included within (1), (2) or (3) above, and the benefit from the recognition of PTCs.

		As of
		March 28,				September 27,
		2026				2025
Assets:
Propane		$	2,012,988			$	1,933,532
Fuel oil and refined fuels			46,150				41,078
Natural gas and electricity			12,668				9,973
Reportable segment assets			2,071,806				1,984,583
All other			276,039				260,393
Corporate			78,790				51,298
Total assets		$	2,426,635			$	2,296,274

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following is a discussion and analysis of the financial condition and results of operations of the Partnership as of and for the three and six months ended March 28, 2026, seen from our perspective. The discussion and analysis should be read in conjunction with Management’s Discussion and Analysis of Financial Condition and Results of Operations and the historical consolidated financial statements and notes thereto included in the Annual Report on Form 10-K for the fiscal year ended September 27, 2025.

Executive Overview

The following are factors that regularly affect our operating results and financial condition. Our business is subject to the risks and uncertainties described in Item 1A included in the Annual Report on Form 10-K for the fiscal year ended September 27, 2025 and in this Quarterly Report. Management currently considers the following events, trends, and uncertainties to be most important to understanding our financial condition and operating performance:

Product Costs and Supply

The level of profitability in the retail propane, fuel oil, natural gas and electricity businesses is largely dependent on the difference between retail sales price and our costs to acquire and transport products. The unit cost of our products, particularly propane, fuel oil and natural gas, is subject to volatility as a result of supply and demand dynamics or other market conditions, including, but not limited to, economic and political factors impacting crude oil and natural gas supply or pricing. We enter into product supply contracts that are generally one-year agreements subject to annual renewal, and also purchase product on the open market. We attempt to reduce price risk by pricing product on a short-term basis. Our propane supply contracts typically provide for pricing based upon index formulas using the posted prices established at major supply points such as Mont Belvieu, Texas, or Conway, Kansas (plus transportation costs) at the time of delivery.

To supplement our annual purchase requirements, we may utilize forward fixed price purchase contracts to acquire a portion of the propane that we resell to our customers, which allows us to manage our exposure to unfavorable changes in commodity prices and to ensure adequate physical supply. The percentage of contract purchases, and the amount of supply contracted for under forward contracts at fixed prices, will vary from year to year based on market conditions.

Changes in our costs to acquire and transport products can occur rapidly over a short period of time and can impact profitability. There is no assurance that we will be able to pass on product acquisition and transportation cost increases fully or immediately, particularly when such costs increase rapidly. Therefore, average retail sales prices can vary significantly from year to year as our costs fluctuate with the propane, fuel oil, crude oil and natural gas commodity markets and infrastructure conditions. In addition, periods of sustained higher commodity and/or transportation prices can lead to customer conservation, resulting in reduced demand for our product.

According to the Energy Information Administration, U.S. propane inventory levels at the end of March 2026 were 77.0 million barrels, which was 74.5% higher than March 2025 levels and 46.5% higher than the five-year average for March. The increase in inventory levels contributed to a decrease in average posted propane prices (basis Mont Belvieu, Texas) of 23.1% compared to the prior year second quarter.

Seasonality

The retail propane and fuel oil distribution businesses, as well as the retail natural gas marketing business, are seasonal because these fuels are primarily used for heating in residential and commercial buildings. Historically, approximately two‑thirds of our retail propane volume is sold during the six-month peak heating season from October through March. The fuel oil business tends to experience greater seasonality given its more limited use for space heating and approximately three-fourths of our fuel oil volumes are sold between October and March. Consequently, sales and operating profits are concentrated in our first and second fiscal quarters. Cash flows from operations, therefore, are greatest during the second and third fiscal quarters when customers pay for product purchased during the winter heating season. We expect lower operating profits and either net losses or lower net income during the period from April through September (our third and fourth fiscal quarters). To the extent necessary, we will reserve cash from the second and third quarters for distribution to holders of our Common Units in the fourth quarter and the following fiscal year first quarter.

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Weather

Weather conditions have a significant impact on the demand for our products, in particular propane, fuel oil and natural gas, for both heating and agricultural purposes. Many of our customers rely heavily on propane, fuel oil or natural gas as a heating source. Accordingly, the volume sold is directly affected by the severity of the winter weather in our service areas, which can vary substantially from year to year. In any given area, sustained warmer than normal temperatures will tend to result in reduced propane, fuel oil and natural gas consumption, while sustained colder than normal temperatures will tend to result in greater consumption.

Hedging and Risk Management Activities

We engage in hedging and risk management activities to reduce the effect of price volatility on our product costs and to ensure the availability of product during periods of short supply. We enter into propane forward, options and swap agreements with third parties, and use futures and options contracts traded on the New York Mercantile Exchange (“NYMEX”) to purchase and sell propane, fuel oil, crude oil, natural gas and electricity at fixed prices in the future. The majority of the futures, forward and options agreements are used to hedge price risk associated with propane and fuel oil physical inventory, as well as, in certain instances, forecasted purchases of propane or fuel oil. In addition, we sell propane, fuel oil, natural gas and electricity to customers at fixed prices, and enter into derivative instruments to hedge a portion of our exposure to fluctuations in commodity prices as a result of selling the fixed price contracts. Forward contracts are generally settled physically at the expiration of the contract whereas futures, options and swap contracts are generally settled at the expiration of the contract through a net settlement mechanism. Although we use derivative instruments to reduce the effect of price volatility associated with priced physical inventory and forecasted transactions, we do not use derivative instruments for speculative trading purposes. Risk management activities are monitored by an internal Commodity Risk Management Committee, made up of six members of management and reporting to our Audit Committee, through enforcement of our Hedging and Risk Management Policy.

Inflation and Other Cost Increases

We are experiencing inflationary pressures in the costs of various goods and services we use to operate our business, including volatile wholesale costs for the products we distribute. Although we have not experienced significant disruptions with securing the products we sell, inflationary factors and competition for resources across the supply chain have resulted in increased costs in a wide variety of areas, including labor, transportation costs, operating costs and the cost of capital expansion projects, tanks and other equipment. These and other factors, including the impact of tariffs and trade conflicts, may continue to impact our product costs, expenses, and capital expenditures, and could continue to have an impact on consumer demand as consumers manage the impact of inflation and tariffs on their resources.

At-the-Market Equity Program

On February 20, 2025, we entered into an Equity Distribution Agreement (the “Equity Distribution Agreement”) with Wells Fargo Securities, LLC, J.P. Morgan Securities LLC, BofA Securities, Inc., and Evercore Group L.L.C., each acting as a sales agent and/or principal (each, an “Agent,” and collectively, the “Agents”). Pursuant to the terms of the Equity Distribution Agreement, we may issue and sell from time to time, through the Agents, our Common Units representing limited partner interests in the Partnership having an aggregate offering amount of up to $100.0 million (the “ATM equity program”).

The Agents use their commercially reasonable efforts, as the sales agents and subject to the terms of the Equity Distribution Agreement, to sell the Common Units offered. Sales of the Common Units are deemed to be an “at the market offering” as defined in Rule 415(a)(4) promulgated under the Securities Act, including sales made directly on or through the New York Stock Exchange. We may also agree to sell Common Units to the Agents as principal for their own account on terms agreed to by us and the Agents. Each Agent will be entitled to a commission from us on the gross sales price per Common Unit sold under the Equity Distribution Agreement by such Agent acting as our sales agent. During the six months ended March 28, 2026, we issued and sold 171,745 Common Units under the Equity Distribution Agreement for net proceeds of $3.1 million, after agent commissions and offering costs of $0.2 million.

We use the net proceeds from the sales of Common Units pursuant to the Equity Distribution Agreement for general limited partnership purposes, including debt reduction and funding strategic growth initiatives.

Transferable Tax Credits

In accordance with the Inflation Reduction Act of 2022 (“IRA”), renewable natural gas (“RNG”) produced in the United States and sold for use as a transportation fuel may qualify for the Clean Fuel Production Tax Credit (“PTC”) under Section 45Z of the Internal Revenue Code. Section 45Z was enacted as part of the IRA and is administered primarily by the U.S. Department of Treasury and Internal Revenue Service, in coordination with other federal agencies, including the Environmental Protection Agency and the U.S. Department of Energy. The IRA was designed, in part, to incentivize the development and production of renewable and low carbon

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energy. On July 4, 2025, The One, Big, Beautiful Bill Act (“OBBBA”) was signed into law, extending the availability of the Section 45Z credit from December 31, 2027 to December 31, 2029. Accordingly, qualifying credits may be claimed for eligible RNG produced and sold after December 31, 2024, and before January 1, 2030.

Although Section 45Z became effective on January 1, 2025, we did not previously recognize any benefit from these credits pending additional regulatory clarity regarding eligibility, lifecycle greenhouse gas emissions calculations, and transferability. On February 4, 2026, proposed Treasury regulations published in the Federal Register provided sufficient clarity for us to conclude that the production and sale of our RNG qualify for the credit.

The value of PTCs earned is based on the statutory base credit rate of $0.20 per gallon equivalent, adjusted for applicable prevailing wage and apprenticeship compliance, lifecycle greenhouse gas emissions calculations, qualifying production and sales volumes, and prevailing market prices for transferable tax credits. Where applicable prevailing wage and apprenticeship requirements are satisfied, the credit may be increased up to five times the base amount. The amount recognized reflects our estimate of credits earned based on currently available guidance, applicable carbon intensity scores, and anticipated monetization values. Actual amounts ultimately realized may differ upon the issuance of final regulations and the ultimate transfer or utilization of the credits.

Critical Accounting Policies and Estimates

Our significant accounting policies are summarized in Note 2, “Summary of Significant Accounting Policies,” included within the Notes to Consolidated Financial Statements section of our Annual Report on Form 10-K for the fiscal year ended September 27, 2025.

Certain amounts included in or affecting our consolidated financial statements and related disclosures must be estimated, requiring management to make certain assumptions with respect to values or conditions that cannot be known with certainty at the time the financial statements are prepared. The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America (“US GAAP”) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. We are also subject to risks and uncertainties that may cause actual results to differ from estimated results. Estimates are used when accounting for depreciation and amortization of long-lived assets, employee benefit plans, self-insurance and litigation reserves, environmental reserves, allowances for doubtful accounts, asset valuation assessments and valuation of derivative instruments. We base our estimates on historical experience and on various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Any effects on our business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known to us. Management has reviewed these critical accounting estimates and related disclosures with the Audit Committee of our Board of Supervisors.

Results of Operations and Financial Condition

Net income for the second quarter of fiscal 2026 was $137.5 million, or $2.07 per Common Unit, compared to net income of $137.1 million, or $2.11 per Common Unit, for the second quarter of fiscal 2025. Adjusted earnings before interest, taxes, depreciation, and amortization (“Adjusted EBITDA”, as defined and reconciled below) for the second quarter of fiscal 2026 improved $0.3 million, or 0.2%, to $175.3 million, compared to the prior year second quarter.

Retail propane gallons sold in the second quarter of fiscal 2026 of 161.6 million gallons were flat compared to the prior year second quarter, as the impact of cooler temperatures across much of the eastern half of the United States on heat-related demand and contributions from our recent acquisitions, were offset by considerably warmer temperatures in the West. Average temperatures (as measured by the number of heating degree days reported by the National Oceanic and Atmospheric Administration) across all of our service territories during the second quarter of fiscal 2026 were 6% warmer than normal and 1% warmer than the prior year second quarter. Notably, average temperatures in the East were 2% warmer than normal and 3% colder than the prior year, whereas average temperatures in the West were 22% warmer than normal and 17% warmer than the prior year.

Average propane prices (basis Mont Belvieu, Texas) for the second quarter of fiscal 2026 decreased 23.1% compared to the prior year second quarter. Total gross margin of $343.7 million for the second quarter of fiscal 2026 decreased $1.6 million, or 0.5%, compared to the prior year second quarter. Gross margin for the second quarter of fiscal 2026 included a $1.4 million unrealized loss attributable to the mark-to-market adjustment for derivative instruments used in risk management activities, compared to a $0.7 million unrealized gain in the prior year second quarter. These non-cash adjustments, which were reported in cost of products sold, were excluded from Adjusted EBITDA for both periods. Excluding the impact of the mark-to-market adjustments, total gross margin increased $0.5 million compared to the prior year second quarter, primarily due to an increase in propane unit margins of $0.03 per gallon, or 1.7%.

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Combined operating and general and administrative expenses of $169.5 million for the second quarter of fiscal 2026 were flat compared to the prior year second quarter, as higher payroll and benefit-related expenses, higher fuel and other vehicle costs, and an increase in accruals for self-insurance matters, were offset by a benefit of $3.5 million from the recognition of PTCs and an insurance recovery related to the partial settlement of certain claims associated with our acquisition of RNG production assets in December 2022.

In December 2025, we strategically refinanced our previously outstanding $350.0 million of 5.875% senior notes due 2027 (“2027 Senior Notes”) with net proceeds from the issuance of new 6.50% senior notes due 2035 (“2035 Senior Notes”) totaling $350.0 million and borrowings under our Revolving Credit Facility. The refinancing extends weighted average debt maturities by nearly three years and provides additional financial flexibility.

During the first quarter of fiscal 2026, we acquired two well-run propane businesses in strategic markets in California for total consideration of $24.0 million, inclusive of non-compete payments. During the second quarter of fiscal 2026, we utilized cash flows from operating activities to repay $64.3 million in borrowings under our revolving credit facility. The Consolidated Leverage Ratio, as defined in our credit agreement, for the twelve-month period ended March 28, 2026 improved to 4.34x, compared to 4.54x for the twelve-month period ended March 29, 2025.

As previously announced on April 23, 2026, our Board of Supervisors declared a quarterly distribution of $0.325 per Common Unit for the three months ended March 28, 2026. On an annualized basis, this distribution rate equates to $1.30 per Common Unit. The distribution is payable on May 12, 2026 to Common Unitholders of record as of May 5, 2026.

Our anticipated cash requirements for the remainder of fiscal 2026 include: (i) maintenance and growth capital expenditures of approximately $19.9 million for the propane segment; (ii) capital expenditures of approximately $19.0 million to support the construction and development efforts for our renewable energy platform; (iii) interest and income tax payments of approximately $37.5 million; and (iv) distributions of approximately $43.3 million to our Common Unitholders, based on the quarterly distribution rate of $0.325 per Common Unit. Based on our liquidity position, which includes availability of funds under the Revolving Credit Facility and expected cash flow from operating activities and our ATM equity program, we expect to have sufficient funds to meet our current and future obligations.

Our long-term strategic growth plan is to foster the growth of our core propane business, while making strategic investments in lower carbon renewable energy alternatives that allow us to leverage our core competencies in safety, logistics expertise and customer service. Suburban Propane has a proud legacy of being a trusted provider of energy to local communities for almost 100 years. We are leveraging the strength and stability of our core propane business to position Suburban Propane for sustainable, long-term growth by helping to identify and invest in solutions to support the ongoing energy evolution to a lower-carbon energy economy. That innovation includes our advancements in delivering renewable propane and renewable natural gas as direct drop-in replacements for their traditional energy equivalents.

Three Months Ended March 28, 2026 Compared to Three Months Ended March 29, 2025

Revenues

(Dollars and gallons in thousands)		Three Months Ended
		March 28,				March 29,								Percent
		2026				2025				(Decrease)				(Decrease)
Revenues
Propane		$	491,142			$	525,256			$	(34,114	)			(6.5	)%
Fuel oil and refined fuels			32,354				33,364				(1,010	)			(3.0	)%
Natural gas and electricity			8,778				9,025				(247	)			(2.7	)%
All other			18,932				20,018				(1,086	)			(5.4	)%
Total revenues		$	551,206			$	587,663			$	(36,457	)			(6.2	)%
Retail gallons sold
Propane			161,593				162,027				(434	)			(0.3	)%
Fuel oil and refined fuels			7,469				7,760				(291	)			(3.8	)%

As discussed above, average temperatures (as measured in heating degree days) across all of our service territories during the second quarter of fiscal 2026 were 6% warmer than normal and 1% warmer than the prior year second quarter. Average temperatures in the West were 22% warmer than normal and 17% warmer than the prior year second quarter, whereas average temperatures in the East were 2% warmer than normal and 3% cooler than the prior year second quarter. The cooler average temperatures were primarily in the Northeast and Mid-Atlantic, which led to increased heat-related demand from customers in those markets.

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Revenues from the distribution of propane and related activities of $491.1 million decreased $34.1 million, or 6.5%, compared to the prior year, primarily due to lower average retail selling prices. Average propane selling prices decreased 4.2% compared to the prior year second quarter, reflecting lower average wholesale costs, resulting in a $21.3 million decrease in revenues. Retail propane gallons sold were essentially flat compared to the prior year second quarter, as the impact of cooler temperatures in the East on heat-related demand and contributions from our recent acquisitions, substantially offset considerably warmer temperatures in the West, resulting in a $1.4 million decrease in revenues. Included within the propane segment are revenues from risk management activities, which decreased $11.4 million, primarily due to a lower notional amount of hedging contracts used in risk management activities that were settled physically.

Revenues from the distribution of fuel oil and refined fuels of $32.4 million were $1.0 million, or 3.0%, lower than the prior year second quarter, primarily due to a decrease in volumes sold, offset to an extent by higher average retail selling prices. Fuel oil and refined fuels gallons sold decreased 0.3 million gallons, or 3.8%, resulting in a $1.2 million decrease in revenues. Average fuel oil and refined fuels selling prices increased 0.8% compared to the prior year, resulting in a $0.2 million increase in revenues.

Revenues in our natural gas and electricity segment of $8.8 million were $0.2 million, or 2.7%, lower than the prior year, resulting from less natural gas and electricity usage, primarily due to the impact of a lower customer base.

Revenues in our all other segment of $18.9 million were $1.1 million, or 5.4%, lower than the prior year, primarily due to lower tipping fees at our RNG facilities and lower services revenues.

Cost of Products Sold

(Dollars in thousands)		Three Months Ended												Percent
		March 28,				March 29,				Increase				Increase
		2026				2025				(Decrease)				(Decrease)
Cost of products sold
Propane		$	176,258			$	213,010			$	(36,752	)			(17.3	)%
Fuel oil and refined fuels			20,255				20,134				121				0.6	%
Natural gas and electricity			7,490				5,840				1,650				28.3	%
All other			3,497				3,378				119				3.5	%
Total cost of products sold		$	207,500			$	242,362			$	(34,862	)			(14.4	)%
As a percent of total revenues			37.6	%			41.2	%

The cost of products sold reported in the condensed consolidated statements of operations represents the weighted average unit cost of propane, fuel oil and refined fuels, and natural gas and electricity sold, including transportation costs to deliver product from our supply points to storage or to our customer service centers. Cost of products sold also includes the cost of appliances and related parts sold or installed by our customer service centers computed on a basis that approximates the average cost of the products.

Given the retail nature of our operations, we maintain a certain level of priced physical inventory to help ensure that our field operations have adequate supply commensurate with the time of year. Our strategy has been, and will continue to be, to keep our physical inventory priced relatively close to market for our field operations. Consistent with past practices, we principally utilize futures and/or options contracts traded on the NYMEX to mitigate the price risk associated with our priced physical inventory, as well as, in certain instances, forecasted purchases of propane, fuel oil, natural gas and electricity. In addition, we sell propane, fuel oil, natural gas and electricity to customers at fixed prices, and enter into derivative instruments to hedge a portion of our exposure to fluctuations in commodity prices as a result of selling the fixed price contracts. At expiration, the derivative contracts are settled by the delivery of the product to the respective party or are settled by the payment to the respective party of a net amount equal to the difference between the then market price and the fixed contract price or option exercise price. Under this risk management strategy, realized gains or losses on futures or options contracts, which are reported in cost of products sold, will typically offset losses or gains on the physical inventory once the product is sold or delivered as it pertains to fixed price contracts (which may or may not occur in the same accounting period). We do not use futures or options contracts, or other derivative instruments, for speculative trading purposes. Unrealized non-cash gains or losses from changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded within cost of products sold. Cost of products sold excludes depreciation and amortization; these amounts are reported separately within the condensed consolidated statements of operations.

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In the commodities markets, average posted propane prices (basis Mont Belvieu, Texas) were 23.1% lower than the prior year second quarter, and average fuel oil prices were 22.3% higher. The net change in the fair value of derivative instruments resulted in a $1.4 million unrealized non-cash loss in the second quarter of fiscal 2026, compared to a $0.7 million unrealized non-cash gain in the prior year second quarter. This led to a year-over-year net increase of $2.1 million in cost of products sold, of which $1.9 million and $0.2 million was reported within the propane segment and the natural gas and electricity segment, respectively. These unrealized mark-to-market adjustments were excluded from Adjusted EBITDA for both periods.

Cost of products sold associated with the distribution of propane and related activities of $176.3 million decreased $36.8 million, or 17.3%, compared to the prior year second quarter. Lower average wholesale costs contributed to a $27.0 million decrease in cost of products sold, while lower volumes sold contributed to a $0.5 million decrease. Included within the propane segment are costs from other propane activities, which decreased $11.2 million compared to the prior year primarily due to a lower notional amount of hedging contracts used in risk management that were settled physically. This was offset to an extent by the net increase in costs of products sold of $1.9 million resulting from the change in mark-to-market adjustments on derivative instruments in both periods discussed above.

Cost of products sold associated with our fuel oil and refined fuels segment of $20.3 million increased $0.1 million, or 0.6%, compared to the prior year second quarter. Higher average wholesale costs led to an increase of $0.9 million, substantially offset by a decrease of $0.8 million from lower volumes sold.

Cost of products sold in our natural gas and electricity segment of $7.5 million increased $1.7 million, or 28.3%, compared to the prior year primarily due to higher natural gas and electricity wholesale costs and the net increase of $0.2 million resulting from the change in mark-to-market adjustments on derivative instruments used in both periods discussed above.

Operating Expenses

(Dollars in thousands)		Three Months Ended
		March 28,				March 29,								Percent
		2026				2025				Increase				Increase
Operating expenses		$	139,500			$	139,377			$	123				0.1	%
As a percent of total revenues			25.3	%			23.7	%

All costs of operating our retail distribution and appliance sales and service operations, as well as the RNG production facilities, are reported within operating expenses in the condensed consolidated statements of operations. These operating expenses include the compensation and benefits of field and direct operating support personnel, costs of operating and maintaining our vehicle fleet, overhead and other costs of our purchasing, training and safety departments and other direct and indirect costs of operating our customer service centers and RNG production facilities.

Operating expenses of $139.5 million for the second quarter of fiscal 2026 increased $0.1 million, or 0.1%, compared to the prior year second quarter, primarily due to higher payroll and benefit-related costs, higher fuel and vehicle maintenance costs, and an increase in accruals for self-insurance matters, substantially offset by a benefit of $3.5 million from the recognition of PTCs and an insurance recovery for the partial settlement of certain claims associated with the RNG Acquisition.

General and Administrative Expenses

(Dollars in thousands)		Three Months Ended
		March 28,				March 29,								Percent
		2026				2025				Increase				Increase
General and administrative expenses		$	30,044			$	29,911			$	133				0.4	%
As a percent of total revenues			5.5	%			5.1	%

All costs of our back office support functions, including compensation and benefits for executives and other support functions, as well as other costs and expenses to maintain finance and accounting, treasury, legal, human resources, corporate development and the information systems functions are reported within general and administrative expenses in the condensed consolidated statements of operations.

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General and administrative expenses of $30.0 million for the second quarter of fiscal 2026 were essentially flat compared to the prior year second quarter, as higher variable compensation expense was substantially offset by the capitalization of payroll and benefit-related costs associated with software implementation as part of our multi-year initiative to modernize our information technology platform.

Depreciation and Amortization

(Dollars in thousands)		Three Months Ended
		March 28,				March 29,								Percent
		2026				2025				(Decrease)				(Decrease)
Depreciation and amortization		$	16,251			$	17,600			$	(1,349	)			(7.7	)%
As a percent of total revenues			2.9	%			3.0	%

Depreciation and amortization expense of $16.3 million for the second quarter of fiscal 2026 decreased $1.3 million, or 7.7%, compared to the prior year second quarter, primarily as a result of accelerated depreciation in the prior year for assets taken out of service.

Interest Expense, net

(Dollars in thousands)		Three Months Ended
		March 28,				March 29,								Percent
		2026				2025				(Decrease)				(Decrease)
Interest expense, net		$	19,694			$	20,567			$	(873	)			(4.2	)%
As a percent of total revenues			3.6	%			3.5	%

Net interest expense of $19.7 million decreased $0.9 million, or 4.2%, compared to the prior year second quarter, primarily due to a lower level of average outstanding borrowings under our Revolving Credit Facility along with lower benchmark interest rates on those borrowings, offset to an extent by a higher interest rate for a tranche of senior notes that were refinanced in the first quarter of fiscal 2026. See Liquidity and Capital Resources below for additional discussion.

Other, net

(Dollars in thousands)		Three Months Ended
		March 28,				March 29,								Percent
		2026				2025				(Decrease)				(Decrease)
Equity in losses of IH		$	375			$	504			$	(129	)			(25.6	)%
Other (1)			180				225				(45	)			(20.0	)%
Other, net		$	555			$	729			$	(174	)			(23.9	)%
As a percent of total revenues			0.1	%			0.1	%

(1)Represents net periodic benefit costs for our pension and other postretirement benefit plans (see Item 1, Note 15 of this Quarterly Report).

EBITDA and Adjusted EBITDA

EBITDA represents net income before deducting interest expense, income taxes, depreciation and amortization. Adjusted EBITDA represents EBITDA excluding the unrealized net gain or loss on mark-to-market activity for derivative instruments and other items, as applicable, as provided in the table below. Our management uses EBITDA and Adjusted EBITDA as supplemental measures of operating performance and we are including them because we believe that they provide our investors and industry analysts with additional information that we determined is useful to evaluate our operating results. EBITDA and Adjusted EBITDA are not recognized terms under US GAAP and should not be considered as an alternative to net income or net cash provided by operating activities determined in accordance with US GAAP. Because EBITDA and Adjusted EBITDA as determined by us excludes some, but not all, items that affect net income, they may not be comparable to EBITDA and Adjusted EBITDA or similarly titled measures used by other companies.

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The following table sets forth our calculations of EBITDA and Adjusted EBITDA:

(Dollars in thousands)		Three Months Ended
		March 28,				March 29,
		2026				2025
Net income		$	137,542			$	137,121
Add:
Provision for (benefit from) income taxes			120				(4	)
Interest expense, net			19,694				20,567
Depreciation and amortization			16,251				17,600
EBITDA			173,607				175,284
Unrealized non-cash losses (gains) on changes in fair value of derivatives			1,358				(744	)
Equity in losses and impairment charges for investments in unconsolidated affiliates			375				504
Adjusted EBITDA		$	175,340			$	175,044

We also reference gross margins, computed as revenues less cost of products sold as those amounts are reported on the condensed consolidated financial statements. Our management uses gross margin as a supplemental measure of operating performance and we are including it as we believe that it provides our investors and industry analysts with additional information that we determined is useful to evaluate our operating results. As cost of products sold does not include depreciation and amortization expense, the gross margin we reference is considered a non-GAAP financial measure.

Six Months Ended March 28, 2026 Compared to Six Months Ended March 29, 2025

Revenues

(Dollars and gallons in thousands)		Six Months Ended												Percent
		March 28,				March 29,				Increase				Increase
		2026				2025				(Decrease)				(Decrease)
Revenues
Propane		$	817,532			$	855,539			$	(38,007	)			(4.4	)%
Fuel oil and refined fuels			50,521				51,025				(504	)			(1.0	)%
Natural gas and electricity			14,677				15,078				(401	)			(2.7	)%
All other			38,862				39,350				(488	)			(1.2	)%
Total revenues		$	921,592			$	960,992			$	(39,400	)			(4.1	)%
Retail gallons sold
Propane			271,758				267,766				3,992				1.5	%
Fuel oil and refined fuels			12,006				12,127				(121	)			(1.0	)%

Average temperatures (as measured in heating degree days) across all of our service territories for the first half of fiscal 2026 were 6% warmer than normal and 2% cooler than the prior year. The fiscal 2026 heating season was characterized by periods of extremely cold weather in the eastern half of the U.S., principally in the Northeast, Mid-Atlantic and Midwest regions of our operating footprint, and sustained unseasonably warm conditions in the western half. In the East, average temperatures were approximately 1% warmer than normal and 6% colder than the prior year, while average temperatures in the West were approximately 23% and 13% warmer than normal and the prior year, respectively.

Revenues from the distribution of propane and related activities of $817.5 million decreased $38.0 million, or 4.4%, compared to the prior year, due to lower average retail selling prices, partially offset by higher volumes sold. Average propane selling prices decreased 3.3%, reflecting lower average wholesale costs, resulting in a $27.8 million decrease in revenues. Retail propane gallons sold increased 4.0 million gallons, or 1.5%, resulting in a $12.4 million increase in revenues. The increase in propane volumes sold was primarily due to the impact of colder temperatures across much of the eastern half of the United States on heat-related demand and contributions from our recent acquisitions, which more than offset considerably warmer temperatures in the West and incremental volumes in the prior year first half in the aftermath of Hurricanes Helene and Milton in the Southeast. Included within the propane segment are revenues from risk management activities, which decreased $22.6 million, primarily due to a lower notional amount of hedging contracts used in risk management activities that were settled physically.

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Revenues from the distribution of fuel oil and refined fuels of $50.5 million were $0.5 million, or 1.0%, lower than the prior year first half, primarily due to a decrease in volumes sold. Fuel oil and refined fuels gallons sold decreased 0.1 million gallons, or 1.0%, resulting in a $0.5 million decrease in revenues. Average fuel oil and refined fuels selling prices were essentially flat compared to the prior year.

Revenues in our natural gas and electricity segment of $14.7 million were $0.4 million, or 2.7%, lower than the prior year, resulting from lower electricity usage, primarily due to the impact of a lower customer base.

Revenues in our all other segment of $38.9 million were $0.5 million, or 1.2%, lower than the prior year first half, primarily due to lower tipping fees at our RNG facilities and lower services revenues.

Cost of Products Sold

(Dollars in thousands)		Six Months Ended												Percent
		March 28,				March 29,				Increase				Increase
		2026				2025				(Decrease)				(Decrease)
Cost of products sold
Propane		$	288,377			$	342,751			$	(54,374	)			(15.9	)%
Fuel oil and refined fuels			31,555				30,685				870				2.8	%
Natural gas and electricity			10,660				8,396				2,264				27.0	%
All other			7,747				7,692				55				0.7	%
Total cost of products sold		$	338,339			$	389,524			$	(51,185	)			(13.1	)%
As a percent of total revenues			36.7	%			40.5	%

In the commodities markets, average posted propane prices (basis Mont Belvieu, Texas) were 18.9% lower than the prior year first half, while average fuel oil prices were 13.6% higher than the prior year first half. The net change in the fair value of derivative instruments resulted in a $0.4 million unrealized non-cash loss in the first half of fiscal 2026, compared to a $4.4 million unrealized non-cash gain in the first half of fiscal 2025. This led to a year-over-year net increase of $4.8 million in cost of products sold, of which $4.7 million and $0.1 million was reported within the propane segment and the natural gas and electricity segment, respectively. These unrealized mark-to-market adjustments were excluded from Adjusted EBITDA for both periods.

Cost of products sold associated with the distribution of propane and related activities of $288.4 million decreased $54.4 million, or 15.9%, compared to the prior year. Lower average wholesale costs contributed to a $40.6 million decrease in cost of products sold, while higher volumes sold contributed to a $4.7 million increase. Included within the propane segment are costs from other propane activities, which decreased $23.2 million compared to the prior year first half primarily due to a lower notional amount of hedging contracts used in risk management that were settled physically. This was offset to an extent by the net increase in costs of products sold of $4.7 million resulting from the change in mark-to-market adjustments on derivative instruments in both periods discussed above.

Cost of products sold associated with our fuel oil and refined fuels segment of $31.6 million increased $0.9 million, or 2.8%, compared to the prior year. Higher average wholesale costs led to an increase of $1.2 million, which was partially offset by the impact of $0.3 million from lower volumes sold.

Cost of products sold in our natural gas and electricity segment of $10.7 million increased $2.3 million, or 27.0%, compared to the prior year primarily due to higher natural gas and electricity wholesale costs and the net increase of $0.1 million resulting from the change in mark-to-market adjustments on derivative instruments used in both periods discussed above.

Operating Expenses

(Dollars in thousands)		Six Months Ended
		March 28,				March 29,								Percent
		2026				2025				Increase				Increase
Operating expenses		$	266,659			$	262,530			$	4,129				1.6	%
As a percent of total revenues			28.9	%			27.3	%

Operating expenses of $266.7 million for the first half of fiscal 2026 increased $4.1 million, or 1.6%, compared to the prior year first half, primarily due to higher payroll and benefit-related costs, higher volume-related variable operating costs to support the increase in customer demand and an increase in accruals for self-insurance matters, offset to an extent by a benefit of $3.5 million from the recognition of PTCs and an insurance recovery for the partial settlement of certain claims associated with the RNG Acquisition.

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General and Administrative Expenses

(Dollars in thousands)		Six Months Ended
		March 28,				March 29,								Percent
		2026				2025				Increase				Increase
General and administrative expenses		$	57,917			$	56,764			$	1,153				2.0	%
As a percent of total revenues			6.3	%			5.9	%

General and administrative expenses of $57.9 million for the first half of fiscal 2026 increased $1.2 million, or 2.0%, compared to the prior year, primarily due to higher variable compensation costs associated with the increase in earnings and costs related to our multi-year initiative to modernize our information technology platform, offset to an extent by the capitalization of payroll and benefit- related costs associated with software implementation.

Depreciation and Amortization

(Dollars in thousands)		Six Months Ended
		March 28,				March 29,								Percent
		2026				2025				(Decrease)				(Decrease)
Depreciation and amortization		$	33,115			$	34,699			$	(1,584	)			(4.6	)%
As a percent of total revenues			3.6	%			3.6	%

Depreciation and amortization expense of $33.1 million for the first half of fiscal 2026 decreased $1.6 million, or 4.6%, primarily as a result of accelerated depreciation in the prior year for assets taken out of service.

Loss on Debt Extinguishment

On December 22, 2025, we redeemed, satisfied and discharged all of our previously outstanding 2027 Senior Notes with net proceeds from the issuance of the 2035 Senior Notes and borrowings under the Revolving Credit Facility. In connection with this transaction, during the first quarter of fiscal 2026, we recognized a loss on debt extinguishment of $1.2 million, consisting of the write-off of unamortized debt origination costs and other fees and expenses.

Interest Expense, net

(Dollars in thousands)		Six Months Ended
		March 28,				March 29,								Percent
		2026				2025				(Decrease)				(Decrease)
Interest expense, net		$	39,450			$	40,179			$	(729	)			(1.8	)%
As a percent of total revenues			4.3	%			4.2	%

Net interest expense of $39.5 million decreased $0.7 million, or 1.8%, compared to the prior year period, primarily due to a lower level of average outstanding borrowings under our Revolving Credit Facility and lower benchmark interest rates on those borrowings, offset to an extent by a higher interest rate for a tranche of senior notes that were refinanced in the first quarter of fiscal 2026. See Liquidity and Capital Resources below for additional discussion.

Other, net

(Dollars in thousands)		Six Months Ended												Percent
		March 28,				March 29,				Increase				Increase
		2026				2025				(Decrease)				(Decrease)
Equity in losses of IH (1)		$	696			$	10,547			$	(9,851	)			(93.4	)%
Equity in losses of Oberon (2)			—				12,198				(12,198	)			—
Contingent consideration from Equilibrium			—				(3,000	)			3,000				—
Other (3)			560				451				109				24.2	%
Other, net		$	1,256			$	20,196			$	(18,940	)			(93.8	)%
As a percent of total revenues			0.1	%			2.1	%

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(1)Six months ended March 29, 2025 included an other-than-temporary impairment charge of $9.6 million recorded during the first quarter of fiscal 2025 (see Item 1, Note 4 of this Quarterly Report).

(2)Six months ended March 29, 2025 included an other-than-temporary impairment charge of $10.2 million recorded during the first quarter of fiscal 2025 (see Item 1, Note 4 of this Quarterly Report).

(3)Both periods included net periodic benefits costs for our pension and other postretirement benefit plans (see Item 1, Note 15 of this Quarterly Report). Six months ended March 28, 2026 included an other-than-temporary impairment charge of $0.2 million related to a cost-method investee recorded during the first quarter of fiscal 2026.

EBITDA and Adjusted EBITDA

The following table sets forth our calculations of EBITDA and Adjusted EBITDA:

(Dollars in thousands)		Six Months Ended
		March 28,				March 29,
		2026				2025
Net income		$	183,322			$	156,541
Add:
Provision for income taxes			351				559
Interest expense, net			39,450				40,179
Depreciation and amortization			33,115				34,699
EBITDA			256,238				231,978
Unrealized non-cash losses (gains) on changes in fair value of derivatives			428				(4,378	)
Equity in losses and impairment charges for investments in unconsolidated affiliates			896				22,745
Loss on debt extinguishment			1,183				—
Adjusted EBITDA		$	258,745			$	250,345

We also reference gross margins, computed as revenues less cost of products sold as those amounts are reported on the condensed consolidated financial statements. Our management uses gross margin as a supplemental measure of operating performance and we are including it as we believe that it provides our investors and industry analysts with additional information that we determined is useful to evaluate our operating results. As cost of products sold does not include depreciation and amortization expense, the gross margin we reference is considered a non-GAAP financial measure.

Liquidity and Capital Resources

Analysis of Cash Flows

Operating Activities. Net cash provided by operating activities for the first half of fiscal 2026 was $68.6 million compared to $48.9 million in the first half of the prior year. The change was primarily due to higher earnings in the current period coupled with a smaller increase in working capital compared to the prior year, which stemmed from the decline in average wholesale costs of propane.

Investing Activities. Net cash used in investing activities of $65.8 million for the first half of fiscal 2026 consisted of capital expenditures of $44.5 million (including approximately $31.2 million to support the growth of operations and $13.3 million for maintenance expenditures), $22.9 million used to fund the acquisitions of two propane businesses, and $0.2 million used to fund additional investments in an unconsolidated affiliate. This was partially offset by $1.8 million in proceeds from the sale of property, plant and equipment. See Item 1, Note 4 of this Quarterly Report.

Net cash used in investing activities of $97.1 million for the first half of fiscal 2025 consisted of capital expenditures of $43.2 million (including approximately $30.5 million to support the growth of operations and $12.7 million for maintenance expenditures), $50.0 million used to fund the acquisitions of propane businesses, and $5.3 million used to fund additional investments in Oberon and IH. This was partially offset by $1.4 million in proceeds from the sale of property, plant and equipment.

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Financing Activities. Net cash provided by financing activities of $2.2 million for the first half of fiscal 2026 reflected $51.1 million in net borrowings under our Revolving Credit Facility to support seasonal working capital needs and $3.1 million in net proceeds raised from the sale of Common Units under our ATM equity program (see Item 1, Note 17, “At-the-Market Equity Program,” of this Quarterly Report). Financing activities also reflected $43.0 million paid for the quarterly distributions to Common Unitholders at a rate of $0.325 per Common Unit paid in respect of the fourth quarter of fiscal 2025 and first quarter of fiscal 2026, $6.0 million of issuance costs related to the issuance of our 2035 Senior Notes, as well as other financing activities of $3.1 million. As described in Item 1, Note 10 of this Quarterly Report, during the first quarter of fiscal 2026, we completed the private offering of $350.0 million in aggregate principal amount of our 2035 Senior Notes. The net proceeds from the offering of the 2035 Senior Notes, along with borrowings under the Revolving Credit Facility, were used to redeem, satisfy and discharge all of the then outstanding 2027 Senior Notes.

Net cash provided by financing activities of $45.1 million for the first half of fiscal 2025 reflected $81.6 million in net borrowings under our Revolving Credit Facility to support seasonal working capital needs and $8.8 million in net proceeds raised from the sale of Common Units under our ATM equity program. Financing activities also reflected $41.8 million paid for the quarterly distributions to Common Unitholders at a rate of $0.325 per Common Unit paid in respect of the fourth quarter of fiscal 2024 and first quarter of fiscal 2025, as well as other financing activities of $3.5 million.

Summary of Long-Term Debt Obligations and Revolving Credit Facility

As of March 28, 2026, our long-term debt consisted of $650.0 million in aggregate principal amount of 5.0% Senior Notes due June 1, 2031, $350.0 million in aggregate principal amount of 6.5% Senior Notes due December 15, 2035, $80.6 million in aggregate principal amount of 5.5% Green Bonds due October 1, 2028 through October 1, 2033 (“Green Bonds”) and $200.3 million outstanding under our $500.0 million senior secured revolving credit facility (“Revolving Credit Facility”) provided by our Fourth Amended and Restated Credit Agreement (the “Credit Agreement”). Total long-term borrowings as of March 28, 2026 and March 29, 2025 were $1,280.9 million and $1,313.2 million, respectively. See Item 1, Note 10 of this Quarterly Report.

The Green Bonds contain various restrictive and affirmative covenants, and previously required SuburbanRNG–Stanfield’s debt service coverage ratio, as defined therein, to be not less than 1.00 to 1.00 for three consecutive fiscal quarters. Effective May 2, 2025, the Operating Partnership entered into a guaranty agreement whereby it guaranteed all payments due under the Green Bonds, and amended the indenture governing the Green Bonds to eliminate the debt service coverage ratio covenant.

The aggregate amounts of long-term debt maturities subsequent to March 28, 2026 are as follows: fiscal 2026: $-0-; fiscal 2027: $-0-; fiscal 2028: $-0-; fiscal 2029: $212.0 million; fiscal 2030: $12.3 million; and thereafter: $1,056.6 million.

Total Consolidated Leverage Ratio. Total Consolidated Leverage Ratio, as defined by our Credit Agreement, represents total indebtedness as of the balance sheet date minus unrestricted cash and cash equivalents in an amount not to exceed $25.0 million, divided by Adjusted EBITDA calculated on a trailing twelve-month basis plus non-cash compensation costs recognized under our Restricted Unit Plans for the same period, and other items. The measurement of the Total Consolidated Leverage Ratio for the trailing twelve-month periods ended March 28, 2026 and September 27, 2025 was as follows:

(Dollars in thousands)		As of and for the Twelve Months Ended
		March 28,				September 27,
		2026				2025
Total debt		$	1,280,945			$	1,229,845
Less: cash and cash equivalents (1)			(4,292	)			(405	)
Total debt, less cash and cash equivalents		$	1,276,653			$	1,229,440
Adjusted EBITDA		$	286,428			$	278,028
Compensation costs recognized under Restricted Unit Plan			7,691				7,775
Other (2)			—				542
Adjusted EBITDA for use in calculation		$	294,119			$	286,345
Total Consolidated Leverage Ratio (3)		4.34 x				4.29 x

(1)Effective with the execution of the Credit Agreement on March 15, 2024, total debt for the Total Consolidated Leverage Ratio covenant is net of unrestricted cash and cash equivalents in an amount not to exceed $25.0 million.

(2)Represents pro forma adjustments for acquisitions completed during the reporting period, as provided for under the Credit Agreement.

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(3)Seasonal working capital needs are typically greater during the first and second quarters, which can lead to increased borrowings under the Revolving Credit Facility. The Consolidated Leverage Ratio for the twelve months ended March 29, 2025 was 4.54x.

Partnership Distributions

We are required to make distributions in an amount equal to all of our Available Cash, as defined in our Third Amended and Restated Partnership Agreement, as amended (the “Partnership Agreement”), no more than 45 days after the end of each fiscal quarter to holders of record on the applicable record dates. Available Cash, as defined in the Partnership Agreement, generally means all cash on hand at the end of the respective fiscal quarter less the amount of cash reserves established by the Board of Supervisors in its reasonable discretion for future cash requirements. These reserves are retained for the proper conduct of our business, the payment of debt principal and interest and for distributions during the next four quarters. The Board of Supervisors reviews the level of Available Cash on a quarterly basis based upon information provided by management.

On April 23, 2026, we announced a quarterly distribution of $0.325 per Common Unit, or $1.30 on an annualized basis, in respect of the second quarter of fiscal 2026, payable on May 12, 2026 to holders of record on May 5, 2026.

Other Commitments

We have a noncontributory, cash balance format, defined benefit pension plan which was frozen to new participants effective January 1, 2000. Effective January 1, 2003, the defined benefit pension plan was amended such that future service credits ceased and eligible employees would receive interest credits only toward their ultimate retirement benefit. We also provide postretirement health care and life insurance benefits for certain retired employees under a plan that was frozen to new participants effective March 31, 1998. At March 28, 2026, we had a liability for the defined benefit pension plan and accrued retiree health and life benefits of $8.1 million and $3.8 million, respectively.

We are self-insured for general and product, workers’ compensation and automobile liabilities up to predetermined thresholds above which third party insurance applies. At March 28, 2026, we had accrued insurance liabilities of $59.4 million, and a receivable of $15.8 million related to the amount of the liability expected to be covered by insurance.

Legal Matters

See Item 1, Note 13, “Commitments and Contingencies,” Legal Matters subsection of this Quarterly Report.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Commodity Price Risk

We enter into product supply contracts that are generally one-year agreements subject to annual renewal, and also purchase product on the open market. Our propane supply contracts typically provide for pricing based upon index formulas using the posted prices established at major supply points such as Mont Belvieu, Texas, or Conway, Kansas (plus transportation costs) at the time of delivery. In addition, to supplement our annual purchase requirements, we may utilize forward fixed price purchase contracts to acquire a portion of the propane that we resell to our customers, which allows us to manage our exposure to unfavorable changes in commodity prices and to ensure adequate physical supply. The percentage of contract purchases, and the amount of supply contracted for under forward contracts at fixed prices, will vary from year to year based on market conditions. In certain instances, and when market conditions are favorable, we are able to purchase product under our supply arrangements at a discount to the market.

Product cost changes can occur rapidly over a short period of time and can impact profitability. We attempt to reduce commodity price risk by pricing product on a short-term basis. The level of priced, physical product maintained in storage facilities and at our customer service centers for immediate sale to our customers will vary depending on several factors, including, but not limited to, price, supply and demand dynamics for a given time of the year. Typically, our on hand priced position does not exceed more than four to eight weeks of our supply needs, depending on the time of the year. In the course of normal operations, we routinely enter into contracts such as forward priced physical contracts for the purchase or sale of propane and fuel oil that, under accounting rules for derivative instruments and hedging activities, qualify for and are designated as normal purchase or normal sale contracts. Such contracts are exempted from fair value accounting and are accounted for at the time product is purchased or sold under the related contract.

Under our hedging and risk management strategies, we enter into a combination of exchange-traded futures and options contracts and, in certain instances, over-the-counter options and swap contracts (collectively, “derivative instruments”) to manage the price risk associated with physical product and with future purchases of the commodities used in our operations, principally propane and fuel oil, as well as to help ensure the availability of product during periods of high demand. In addition, we sell propane, fuel oil, natural gas

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and electricity to customers at fixed prices, and enter into derivative instruments to hedge a portion of our exposure to fluctuations in commodity prices as a result of selling the fixed price contracts. We do not use derivative instruments for speculative or trading purposes. Futures and swap contracts require that we sell or acquire propane or fuel oil at a fixed price for delivery at fixed future dates. An option contract allows, but does not require, its holder to buy or sell propane or fuel oil at a specified price during a specified time period. However, the writer of an option contract must fulfill the obligation of the option contract, should the holder choose to exercise the option. At expiration, the contracts are settled by the delivery of the product to the respective party or are settled by the payment of a net amount equal to the difference between the then market price and the fixed contract price or option exercise price. To the extent that we utilize derivative instruments to manage exposure to commodity price risk and commodity prices move adversely in relation to the contracts, we could suffer losses on those derivative instruments when settled. Conversely, if prices move favorably, we could realize gains. Under our hedging and risk management strategy, realized gains or losses on derivative instruments will typically offset losses or gains on the physical inventory once the product is sold to customers at market prices, or delivered to customers as it pertains to fixed price contracts.

Futures are traded with brokers of the NYMEX and require daily cash settlements in margin accounts. Forward contracts are generally settled at the expiration of the contract term by physical delivery, and swap and options contracts are generally settled at expiration through a net settlement mechanism. Market risks associated with our derivative instruments are monitored daily for compliance with our Hedging and Risk Management Policy which includes volume limits for open positions. Open inventory positions are reviewed and managed daily as to exposures to changing market prices.

Credit Risk

Exchange-traded futures and options contracts are guaranteed by the NYMEX and, as a result, have minimal credit risk. We are subject to credit risk with over-the-counter forward, swap and options contracts to the extent the counterparties do not perform. We evaluate the financial condition of each counterparty with which we conduct business and establish credit limits to reduce exposure to the risk of non-performance by our counterparties.

Interest Rate Risk

A portion of our borrowings bear interest at prevailing interest rates based upon, at the Operating Partnership’s option, SOFR plus an applicable margin or the base rate, defined as the higher of the Federal Funds Rate plus ½ of 1% or the agent bank’s prime rate, or SOFR plus 1%, plus the applicable margin. The applicable margin is dependent on the level of our total consolidated leverage (the total ratio of debt to consolidated EBITDA). Therefore, we are subject to interest rate risk on the variable component of the interest rate. From time to time, we enter into interest rate swap agreements to manage a part of our variable interest rate risk. The interest rate swaps are designated as cash flow hedges. Changes in the fair value of the interest rate swaps are recognized in other comprehensive income (“OCI”) until the hedged item is recognized in earnings. As of March 28, 2026, we were not party to an interest rate swap agreement.

Derivative Instruments and Hedging Activities

All of our derivative instruments are reported on the balance sheet at their fair values. On the date that derivative instruments are entered into, we make a determination as to whether the derivative instrument qualifies for designation as a hedge. Changes in the fair value of derivative instruments are recorded each period in current period earnings or OCI, depending on whether a derivative instrument is designated as a hedge and, if so, the type of hedge. For derivative instruments designated as cash flow hedges, we formally assess, both at the hedge contract’s inception and on an ongoing basis, whether the hedge contract is highly effective in offsetting changes in cash flows of hedged items. Changes in the fair value of derivative instruments designated as cash flow hedges are reported in OCI to the extent effective and reclassified into earnings during the same period in which the hedged item affects earnings. The mark-to-market gains or losses on ineffective portions of cash flow hedges are immediately recognized in earnings. Changes in the fair value of derivative instruments that are not designated as cash flow hedges, and that do not meet the normal purchase and normal sale exemption, are recorded in earnings as they occur. Cash flows associated with derivative instruments are reported as operating activities within the condensed consolidated statement of cash flows.

Sensitivity Analysis

In an effort to estimate our exposure to unfavorable market price changes in commodities related to our open positions under derivative instruments, we developed a model that incorporates the following data and assumptions:

A.The fair value of open positions as of March 28, 2026.

B.The market prices for the underlying commodities used to determine A. above were adjusted adversely by a hypothetical 10% change and compared to the fair value amounts in A. above to project the potential negative impact on earnings that would be recognized for the respective scenario.

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Based on the sensitivity analysis described above, the hypothetical 10% adverse change in market prices for open derivative instruments as of March 28, 2026 indicates an increase in potential future net losses of $1.9 million. See also Item 7A of our Annual Report on Form 10-K for the fiscal year ended September 27, 2025. The above hypothetical change does not reflect the worst-case scenario. Actual results may be significantly different depending on market conditions and the composition of the open position portfolio.

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

The Partnership maintains disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”)) that are designed to provide reasonable assurance that information required to be disclosed in the Partnership’s filings and submissions under the Exchange Act is recorded, processed, summarized and reported within the periods specified in the rules and forms of the SEC and that such information is accumulated and communicated to the Partnership’s management, including its principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure.

The Partnership completed an evaluation under the supervision and with participation of the Partnership’s management, including the Partnership’s principal executive officer and principal financial officer, of the effectiveness of the design and operation of the Partnership’s disclosure controls and procedures as of March 28, 2026. Based on this evaluation, the Partnership’s principal executive officer and principal financial officer have concluded that, as of March 28, 2026, such disclosure controls and procedures were effective to provide the reasonable assurance described above.

Changes in Internal Control Over Financial Reporting

There have not been any changes in the Partnership’s internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) of the Exchange Act) during the quarter ended March 28, 2026 that have materially affected or are reasonably likely to materially affect its internal control over financial reporting.

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PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

None.

ITEM 1A. RISK FACTORS

In addition to the other information set forth in this report, you should carefully consider the factors discussed in Item 1A. “Risk Factors” in the Partnership’s Annual Report on Form 10-K for the fiscal year ended September 27, 2025.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

None.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5. OTHER INFORMATION

During the fiscal quarter ended March 28, 2026, our supervisors and executive officers (as defined in Rule 16a-1 under the Securities Exchange Act of 1934, as amended), did not adopt or terminate any Rule 10b5-1 trading arrangement or any non-Rule 10b5-1 trading arrangement (each as defined in Item 408(a) and (c) of Regulation S-K).

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ITEM 6. EXHIBITS

(a)Exhibits

INDEX TO EXHIBITS

The exhibits listed on this Exhibit Index are filed as part of this Quarterly Report. Exhibits required to be filed by Item 601 of Regulation S-K, which are not listed below, are not applicable.

Exhibit Number		Description
4.1		Indenture, dated as of December 22, 2025, relating to the 6.500% Senior Notes due 2035, among Suburban Propane Partners, L.P., Suburban Energy Finance Corp. and The Bank of New York Mellon, as Trustee. (Incorporated by reference to Exhibit 4.1 to the Partnership’s Current Report on Form 8-K filed December 22, 2025)
31.1		Certification of the President and Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. (Filed herewith)
31.2		Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. (Filed herewith)
32.1		Certification of the President and Chief Executive Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. (Furnished herewith)
32.2		Certification of the Chief Financial Officer and Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. (Furnished herewith)
101.INS		XBRL Instance Document – the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
101.SCH		Inline XBRL Taxonomy Extension Schema With Embedded Linkbases Document.
104		Cover Page Interactive Data File – the cover page interactive data file does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.

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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 thereunto duly authorized.

	SUBURBAN PROPANE PARTNERS, L.P.
May 7, 2026	By:		/s/ MICHAEL A. KUGLIN
Date			Michael A. Kuglin
			Chief Financial Officer
May 7, 2026	By:		/s/ DANIEL S. BLOOMSTEIN
Date			Daniel S. Bloomstein
			Vice President, Controller and Chief Accounting Officer

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FAQ

How did Suburban Propane Partners (SPH) perform financially in the latest quarter?

Suburban Propane Partners generated quarterly revenue of $551.2 million and net income of $137.5 million. Revenue decreased from $587.7 million a year earlier, but net income was essentially flat, reflecting lower product costs and disciplined operating expense management.

What were Suburban Propane Partners’ six-month results for fiscal 2026?

Over the first six months of fiscal 2026, Suburban Propane Partners reported revenue of $921.6 million and net income of $183.3 million. Net income rose from $156.5 million in the prior-year period, and diluted net income per common unit increased to $2.75 from $2.41.

How much leverage does Suburban Propane Partners (SPH) have outstanding?

As of March 28, 2026, Suburban Propane Partners had $1.27 billion of long-term borrowings. This included $650 million of 2031 senior notes, $350 million of 2035 senior notes, $70.5 million of green bonds and $200.3 million drawn on its revolving credit facility.

What cash flow did Suburban Propane Partners generate in the first half of 2026?

In the first six months of fiscal 2026, Suburban Propane Partners produced $68.6 million in net cash from operating activities. This cash supported $44.5 million of capital expenditures, $23.1 million of business acquisitions and $43.0 million in partnership distributions.

Did Suburban Propane Partners (SPH) benefit from renewable fuel tax credits?

Yes. Following new Treasury guidance, the partnership recognized $3.5 million of Clean Fuel Production Tax Credits in the second quarter of fiscal 2026. These credits relate to renewable natural gas production and were recorded as non-monetary assets and a reduction of operating expenses.

What is the current quarterly distribution for Suburban Propane Partners unitholders?

Suburban Propane Partners declared a quarterly distribution of $0.325 per common unit for the second quarter of fiscal 2026. This equates to $1.30 per unit annually and is payable on May 12, 2026, to unitholders of record as of May 5, 2026.

How many common units of Suburban Propane Partners (SPH) are outstanding?

At March 28, 2026, Suburban Propane Partners had approximately 66.33 million common units outstanding. The partnership issues additional units through its restricted unit plan and at-the-market equity program, which can modestly increase the total unit count over time.