Cheniere Partners' Q3 Net Income Dips 20% Despite Revenue Growth

Ticker: CQP · Form: 10-Q · Filed: 2025-10-30T00:00:00.000Z

Sentiment: bearish

Topics: LNG, Energy, Midstream, Earnings, Operating Costs, Partnership, Distributions

Related Tickers: CQP, LNG, BX, BAM

TL;DR

**CQP's rising costs are eating into profits, making its revenue growth look less impressive and signaling potential margin pressure ahead.**

AI Summary

Cheniere Energy Partners, L.P. (CQP) reported a decrease in net income for the three months ended September 30, 2025, to $506 million, down from $635 million in the same period of 2024, representing a 20.3% decline. For the nine months ended September 30, 2025, net income also fell to $1,700 million from $1,887 million in 2024, a 9.9% decrease. Total revenues, however, increased to $2,404 million for the three-month period in 2025, up from $2,055 million in 2024, driven by a rise in LNG revenues to $1,837 million from $1,479 million. Operating costs and expenses significantly increased to $1,708 million for the three months ended September 30, 2025, compared to $1,228 million in the prior year, primarily due to a surge in cost of sales from $773 million to $1,278 million. The company's total assets decreased from $17,453 million at December 31, 2024, to $16,834 million at September 30, 2025, while total liabilities also decreased from $17,962 million to $17,182 million over the same period. Cash and cash equivalents declined from $270 million to $121 million. CQP continues to develop an expansion project for additional liquefaction capacity at its Sabine Pass LNG Terminal, which has a total production capacity of over 30 mtpa of LNG.

Why It Matters

This filing reveals a concerning trend for CQP investors: while revenues are growing, net income is declining due to significantly higher operating costs, particularly cost of sales. This could signal eroding margins and impact future distributions, which are a key draw for CQP unitholders. The competitive landscape for LNG is intensifying, and CQP's ability to manage these rising costs will be crucial for maintaining its market position against rivals like Freeport LNG and Golden Pass LNG. Employees and customers might see this as a sign of operational challenges, potentially affecting long-term stability and pricing power in the global LNG market.

Risk Assessment

Risk Level: medium — The risk level is medium due to the significant increase in operating costs, specifically cost of sales, which jumped from $773 million in Q3 2024 to $1,278 million in Q3 2025, leading to a 20.3% drop in net income. This cost escalation, coupled with a decrease in cash and cash equivalents from $270 million to $121 million, indicates potential pressure on profitability and liquidity, despite overall revenue growth.

Analyst Insight

Investors should closely monitor CQP's cost management strategies and future earnings reports for signs of margin stabilization. Consider re-evaluating the sustainability of current distribution levels given the declining net income and increased operating expenses. A deeper dive into the drivers of the 'cost of sales' increase is warranted.

Financial Highlights

debt To Equity
N/A
revenue
$2,404M
operating Margin
29.0%
total Assets
$16,834M
total Debt
N/A
net Income
$506M
eps
$0.80
gross Margin
44.4%
cash Position
$121M
revenue Growth
+17.0%

Revenue Breakdown

SegmentRevenueGrowth
LNG revenues$1,837M+24.2%
LNG revenues—affiliate$518M-1.5%
Regasification revenues$34M0.0%
Other revenues$15M-6.3%

Key Numbers

Key Players & Entities

FAQ

What were Cheniere Energy Partners' net income and revenue for Q3 2025?

Cheniere Energy Partners reported net income of $506 million for the three months ended September 30, 2025, a decrease from $635 million in Q3 2024. Total revenues for the same period increased to $2,404 million from $2,055 million.

Why did Cheniere Energy Partners' net income decrease in Q3 2025?

Net income for Cheniere Energy Partners decreased in Q3 2025 primarily due to a significant increase in operating costs and expenses, which rose to $1,708 million from $1,228 million in Q3 2024. The 'cost of sales' component alone surged from $773 million to $1,278 million.

How did Cheniere Energy Partners' cash position change as of September 30, 2025?

As of September 30, 2025, Cheniere Energy Partners' cash and cash equivalents decreased to $121 million from $270 million at December 31, 2024. Restricted cash and cash equivalents also fell from $109 million to $43 million.

What is the current production capacity of Cheniere Energy Partners' Sabine Pass LNG Terminal?

As of September 30, 2025, the Sabine Pass LNG Terminal, owned by Cheniere Energy Partners, has a total production capacity of over 30 million tonnes per annum (mtpa) of LNG.

What is Cheniere Energy Partners' strategy for future growth?

Cheniere Energy Partners is developing an expansion project to provide additional liquefaction capacity adjacent to its existing Liquefaction Project. This development requires acceptable commercial and financing arrangements before a positive final investment decision (FID).

Who are the major unitholders of Cheniere Energy Partners?

As of September 30, 2025, Cheniere owns 48.6% of the common units, CQP Target Holdco L.L.C. and other affiliates of Blackstone Inc. and Brookfield Asset Management Inc. own 41.5%, and the public holds 7.9%. Cheniere also owns 100% of the general partner interest.

How much did Cheniere Energy Partners distribute per common unit in Q3 2025?

For the three months ended September 30, 2025, Cheniere Energy Partners distributed $0.820 per common unit. This is a decrease compared to the $0.810 per common unit distributed in Q3 2024.

What is the significance of derivative instruments for Cheniere Energy Partners?

Cheniere Energy Partners uses commodity derivatives, including natural gas supply contracts and IPM agreements, for the operation of its Liquefaction Project and expansion project. These are valued using market or option-based approaches and are largely classified as Level 3 within the fair value hierarchy due to significant unobservable inputs.

What is Cheniere Energy Partners' exposure to related party transactions?

Cheniere Energy Partners has various services agreements with affiliates of Cheniere for construction, operation, maintenance, and administrative services. For the nine months ended September 30, 2025, LNG revenues from affiliates were $1,738 million, and operating and maintenance expense from affiliates was $126 million.

What new accounting standard is Cheniere Energy Partners evaluating?

Cheniere Energy Partners is evaluating ASU No. 2024-03, 'Income Statement – Reporting Comprehensive Income – Expense Disaggregation Disclosures (Subtopic 220-40): Disaggregation of Income Statement Expenses,' as clarified by ASU No. 2025-01. They plan to adopt this guidance prospectively for their annual report for the year ending December 31, 2027.

Risk Factors

Industry Context

The global LNG market is characterized by increasing demand, driven by energy transition goals and the need for cleaner fuels. Cheniere operates in a competitive landscape with other major LNG exporters. Key trends include the development of new liquefaction capacity, evolving global trade flows, and the impact of geopolitical events on energy prices and supply security.

Regulatory Implications

Development of new liquefaction capacity and export terminals are subject to stringent environmental regulations and permitting processes in the United States. Compliance with these regulations is critical for project execution and operational continuity. Changes in energy policy or international trade agreements could also impact the industry.

What Investors Should Do

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Key Dates

Glossary

mtpa
Million tonnes per annum, a standard unit for measuring the production capacity of LNG facilities. (Indicates the scale of Cheniere's Sabine Pass LNG Terminal capacity, which is over 30 mtpa.)
FID
Final Investment Decision, a critical milestone where a company commits to proceeding with a project after evaluating its commercial and financial viability. (Essential for the development of Cheniere's expansion project; a positive FID is required to move forward.)
IDRs
Incentive Distribution Rights, a contractual right to receive an increasing share of cash distributions as the partnership's performance improves. (Cheniere owns the IDRs for CQP, impacting how cash is distributed and potentially incentivizing growth.)
Level 3 Hierarchy
A classification within the fair value hierarchy for financial instruments, indicating that the valuation relies on significant unobservable inputs and internal models. (Applies to a significant portion of Cheniere's Liquefaction Supply Derivatives, highlighting valuation uncertainty.)
Cost of Sales
The direct costs attributable to the production of goods or services sold by a company. (A major driver of increased operating costs in Q3 2025, rising from $773 million to $1,278 million, impacting profitability.)
Available Cash
As defined in the partnership agreement, generally the partnership's cash on hand at the end of a quarter less any reserves established by the general partner. (Determines the amount of cash distributed to unitholders each quarter.)

Year-Over-Year Comparison

Compared to the prior year's comparable period (Q3 2024), Cheniere Energy Partners, L.P. reported a 20.3% decrease in net income to $506 million, despite a 17.0% increase in total revenues to $2,404 million. This decline in profitability was primarily driven by a substantial 65.3% surge in the cost of sales, from $773 million to $1,278 million, which significantly eroded operating margins. While total assets and liabilities saw modest decreases, cash and cash equivalents declined sharply from $270 million to $121 million, indicating a tighter liquidity position.

Filing Stats: 4,743 words · 19 min read · ~16 pages · Grade level 15.7 · Accepted 2025-10-29 17:38:49

Filing Documents

Financial Information

Part I. Financial Information Item 1. Consolidated Financial Statements 3 Consolidated Statements of Operations 3 Consolidated Balance Sheets 4 Consolidated Statements of Partners' Deficit 5 Consolidated Statements of Cash Flows 6

Notes to Consolidated Financial Statements

Notes to Consolidated Financial Statements 7 Note 1—Nature of Operations and Basis of Presentation 7 Note 2—Unitholders' Equity 7 Note 3—Trade and Other Receivables, Net of Current Expected Credit Losses 8 Note 4—Inventory 8 Note 5—Property, Plant and Equipment, Net of Accumulated Depreciation 9 Note 6—Derivative Instruments 9 Note 7—Accrued Liabilities 12 Note 8—Debt 13 Note 9—Revenues 15 Note 10—Related Party Transactions 16 Note 11—Net Income per Common Unit 17 Note 12—Segment Information and Customer Concentration 18 Note 13—Supplemental Cash Flow Information 19 Item 2.

Management's Discussion and Analysis of Financial Condition and Results of Operations

Management's Discussion and Analysis of Financial Condition and Results of Operations 20 Item 3.

Quantitative and Qualitative Disclosures about Market Risk

Quantitative and Qualitative Disclosures about Market Risk 31 Item 4.

Controls and Procedures

Controls and Procedures 31

Other Information

Part II. Other Information Item 1.

Legal Proceedings

Legal Proceedings 32 Item 1A.

Risk Factors

Risk Factors 32 Item 5. Other Information 32 Item 6. Exhibits 33

Signatures

Signatures 34 i Table of Contents DEFINITIONS As used in this quarterly report, the terms listed below have the following meanings: Common Industry and Other Terms ASU Accounting Standards Update Bcf/d billion cubic feet per day Bcfe billion cubic feet equivalent DOE U.S. Department of Energy EPC engineering, procurement and construction FASB Financial Accounting Standards Board FERC Federal Energy Regulatory Commission FID final investment decision FTA countries countries with which the United States has a free trade agreement providing for national treatment for trade in natural gas GAAP generally accepted accounting principles in the United States Henry Hub the final settlement price (in U.S. dollars per MMBtu) for the New York Mercantile Exchange's Henry Hub natural gas futures contract for the month in which a relevant cargo's delivery window is scheduled to begin IPM agreements integrated production marketing agreements in which the gas producer sells to us gas on a global LNG or natural gas index price, less a fixed liquefaction fee, shipping and other costs LNG liquefied natural gas, a product of natural gas that, through a refrigeration process, has been cooled to a liquid state, which occupies a volume that is approximately 1/600th of its gaseous state MMBtu million British thermal units; one British thermal unit measures the amount of energy required to raise the temperature of one pound of water by one degree Fahrenheit mtpa million tonnes per annum NGA Natural Gas Act of 1938, as amended non-FTA countries countries with which the United States does not have a free trade agreement providing for national treatment for trade in natural gas and with which trade is permitted SEC U.S. Securities and Exchange Commission SOFR Secured Overnight Financing Rate SPA LNG sale and purchase agreement TBtu trillion British thermal units; one British thermal unit measures the amount of energy required to raise the temperature of on

FINANCIAL INFORMATION

PART I. FINANCIAL INFORMATION

CONSOLIDATED FINANCIAL STATEMENTS

ITEM 1. CONSOLIDATED FINANCIAL STATEMENTS CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF OPERATIONS (in millions, except per unit data) (unaudited) Three Months Ended September 30, Nine Months Ended September 30, 2025 2024 2025 2024 Revenues LNG revenues $ 1,837 $ 1,479 $ 5,961 $ 4,653 LNG revenues—affiliate 518 526 1,738 1,441 Regasification revenues 34 34 102 102 Other revenues 15 16 47 48 Total revenues 2,404 2,055 7,848 6,244 Operating costs and expenses Cost of sales (excluding operating and maintenance expense and depreciation and amortization expense shown separately below) 1,278 773 4,177 2,398 Cost of sales—affiliate — — — 4 Operating and maintenance expense 191 200 683 610 Operating and maintenance expense—affiliate 40 41 126 123 Operating and maintenance expense—related party — 15 28 44 General and administrative expense 3 2 9 8 General and administrative expense—affiliate 23 23 70 68 Depreciation and amortization expense 173 171 515 509 Other operating costs and expenses — 2 2 10 Other operating costs and expenses—affiliate — 1 1 2 Total operating costs and expenses 1,708 1,228 5,611 3,776 Income from operations 696 827 2,237 2,468 Other income (expense) Interest expense, net of capitalized interest ( 189 ) ( 199 ) ( 567 ) ( 603 ) Loss on modification or extinguishment of debt ( 7 ) — ( 7 ) ( 3 ) Interest and dividend income 5 7 14 25 Other income—affiliate 1 — 23 — Total other expense ( 190 ) ( 192 ) ( 537 ) ( 581 ) Net income $ 506 $ 635 $ 1,700 $ 1,887 Basic and diluted net income per common unit (1) $ 0.80 $ 1.08 $ 2.79 $ 3.21 Weighted average basic and diluted number of common units outstanding 484.0 484.0 484.0 484.0 (1) In computing basic and diluted net income per common unit, net income is reduced by the amount of undistributed net income allocated to participating securities other than common units, as required under the two-class method. See Note 11—Net Income per C

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (unaudited) NOTE 1— NATURE OF OPERATIONS AND BASIS OF PRESENTATION We own a natural gas liquefaction and export facility located in Cameron Parish, Louisiana at Sabine Pass (the "Sabine Pass LNG Terminal" ), which has natural gas liquefaction facilities with total production capacity of over 30 mtpa of LNG (the "Liquefaction Project" ) as of September 30, 2025. The Sabine Pass LNG Terminal also has five LNG storage tanks, vaporizers and three marine berths. We also own and operate a 94 -mile natural gas supply pipeline that interconnects the Sabine Pass LNG Terminal with several large interstate and intrastate pipelines (the "Creole Trail Pipeline" ). We are developing an expansion project to provide additional liquefaction capacity adjacent to the Liquefaction Project, and we are commercializing to support the additional liquefaction capacity associated with this potential expansion project. The development of this project or other projects, including infrastructure projects in support of natural gas supply and LNG demand, will require, among other things, acceptable commercial and financing arrangements before we make a positive FID. We do not have employees and thus we and our subsidiaries have various services agreements with affiliates of Cheniere in the ordinary course of business, including services required to construct, operate and maintain the Liquefaction Project, and administrative services. See Note 10—Related Party Transactions for additional details of the activity under these services agreements during the three and nine months ended September 30, 2025 and 2024. As of September 30, 2025, Cheniere owned 48.6 % of our limited partner interest in the form of 239.9 million of our common units. Cheniere also owns 100 % of our general partner interest and our incentive distribution rights ( "IDRs" ). Basis of Presentation The accompanying unaudited Consolidated Financial Statements of CQP have been

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED (unaudited) The general partner interest is entitled to at least 2 % of all distributions made by us. In addition, the general partner holds IDRs, which allow the general partner to receive a higher percentage of quarterly distributions of available cash from operating surplus as additional target levels are met, but may transfer these rights separately from its general partner interest. The higher percentages range from 15 % to 50 %, inclusive of the general partner interest. Our partnership agreement requires that, within 45 days after the end of each quarter, we distribute all of our available cash, which, as defined in our partnership agreement, is generally our cash on hand at the end of a quarter less the amount of any reserves established by our general partner. All distributions we have paid to date have been made from accumulated operating surplus as defined in the partnership agreement. As of September 30, 2025, our total securities beneficially owned in the form of common units were held 48.6 % by Cheniere, 41.5 % by CQP Target Holdco L.L.C. ( "CQP Target Holdco" ) and other affiliates of Blackstone Inc. ( "Blackstone" ) and Brookfield Asset Management Inc. ( "Brookfield" ) and 7.9 % by the public. All of our 2 % general partner interest was held by Cheniere. CQP Target Holdco's equity interests are 50.0 % owned by BIP Chinook Holdco L.L.C., an affiliate of Blackstone, and 50.0 % owned by BIF IV Cypress Aggregator (Delaware) LLC, an affiliate of Brookfield. The ownership of CQP Target Holdco, Blackstone and Brookfield are based on their most recent filings with the SEC. NOTE 3— TRADE AND OTHER RECEIVABLES, NET OF CURRENT EXPECTED CREDIT LOSSES Trade and other receivables, net of current expected credit losses, consisted of the following (in millions): September 30, December 31, 2025 2024 Trade receivables $ 329 $ 370 Other receivables 30 10 Total trade and other receivables, net of curre

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED (unaudited) NOTE 5— PROPERTY, PLANT AND EQUIPMENT, NET OF ACCUMULATED DEPRECIATION Property, plant and equipment, net of accumulated depreciation consisted of the following (in millions): September 30, December 31, 2025 2024 LNG terminal Terminal and interconnecting pipeline facilities $ 20,452 $ 20,292 Construction-in-process 210 227 Accumulated depreciation ( 5,332 ) ( 4,835 ) Total LNG terminal, net of accumulated depreciation 15,330 15,684 Fixed assets Fixed assets 31 30 Accumulated depreciation ( 25 ) ( 24 ) Total fixed assets, net of accumulated depreciation 6 6 Assets under finance leases Tug vessels 75 75 Accumulated depreciation ( 12 ) ( 5 ) Total assets under finance leases, net of accumulated depreciation 63 70 Property, plant and equipment, net of accumulated depreciation $ 15,399 $ 15,760 Depreciation expense was $ 172 million and $ 169 million during the three months ended September 30, 2025 and 2024, respectively, and $ 511 million and $ 505 million during the nine months ended September 30, 2025 and 2024, respectively. NOTE 6— DERIVATIVE INSTRUMENTS We have commodity derivatives consisting of natural gas supply contracts, including our IPM agreements, for the operation of the Liquefaction Project and expansion project, as well as the associated economic hedges (collectively, the "Liquefaction Supply Derivatives" ). The following table shows the fair value of our derivative instruments that are required to be measured at fair value on a recurring basis, distinguished by the fair value hierarchy levels prescribed by GAAP (in millions): Fair Value Measurements as of September 30, 2025 December 31, 2024 Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED (unaudited) In developing our volatility assumptions, we acknowledge that the global LNG industry is inherently influenced by events such as unplanned supply constraints, geopolitical incidents, unusual climate events including drought and uncommonly mild, by historical standards, winters and summers, and real or threatened disruptive operational impacts to global energy infrastructure. Our current estimate of volatility includes the impact of otherwise rare events unless we believe market participants would exclude such events on account of their assertion that those events were specific to our company and deemed within our control. As applicable to our natural gas supply contracts, our fair value estimates incorporate market participant-based assumptions pertaining to certain contractual uncertainties, including those related to the availability of market information for delivery points, as well as the timing of satisfaction of certain events or development of infrastructure to support natural gas gathering and transport. We may recognize changes in fair value through earnings that could significantly impact our results of operations if and when such uncertainties are resolved. The Level 3 fair value measurements of our natural gas positions within the Liquefaction Supply Derivatives could be materially impacted by a significant change in certain natural gas and international LNG prices. The following table includes quantitative information for the unobservable inputs for the Level 3 Liquefaction Supply Derivatives as of September 30, 2025: Net Fair Value Liability (in millions) Valuation Approach Significant Unobservable Input Range of Significant Unobservable Inputs / Weighted Average (1) Liquefaction Supply Derivatives $( 1,184 ) Market approach incorporating present value techniques Henry Hub basis spread $( 0.468 ) - $ 0.295 / $( 0.013 ) Option pricing model International LNG pricing spread, re

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED (unaudited) (5) Roll-off in the current period of amounts recognized in our Consolidated Balance Sheets at the end of the previous period due to settlement of the underlying instruments in the current period. (6) Transferred out of Level 3 as a result of observable market for the underlying natural gas purchase agreements. Liquefaction Supply Derivatives We hold Liquefaction Supply Derivatives, which are indexed to Henry Hub, global LNG or other natural gas price indices. As of September 30, 2025, the remaining fixed terms of the Liquefaction Supply Derivatives ranged up to approximately 15 years, some of which commence or accelerate upon the satisfaction of certain events or development of infrastructure to support natural gas gathering and transport. The forward notional amount for the Liquefaction Supply Derivatives was approximately 5,283 TBtu and 5,500 TBtu as of September 30, 2025 and December 3

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