Form 8-K

8-K — NATIONAL FUEL GAS CO

Accession: 0001193125-26-192083

Filed: 2026-04-29

Period: 2026-04-29

CIK: 0000070145

SIC: 4924 (NATURAL GAS DISTRIBUTION)

Item: Regulation FD Disclosure

Item: Financial Statements and Exhibits

Documents

8-K — d113249d8k.htm (Primary)

EX-99 (d113249dex99.htm)

GRAPHIC (g113249ex99s10g1.jpg)

GRAPHIC (g113249ex99s11g1.jpg)

GRAPHIC (g113249ex99s12g1.jpg)

GRAPHIC (g113249ex99s13g1.jpg)

GRAPHIC (g113249ex99s14g1.jpg)

GRAPHIC (g113249ex99s15g1.jpg)

GRAPHIC (g113249ex99s16g1.jpg)

GRAPHIC (g113249ex99s17g1.jpg)

GRAPHIC (g113249ex99s18g1.jpg)

GRAPHIC (g113249ex99s19g1.jpg)

GRAPHIC (g113249ex99s1g1.jpg)

GRAPHIC (g113249ex99s20g1.jpg)

GRAPHIC (g113249ex99s21g1.jpg)

GRAPHIC (g113249ex99s22g1.jpg)

GRAPHIC (g113249ex99s23g1.jpg)

GRAPHIC (g113249ex99s24g1.jpg)

GRAPHIC (g113249ex99s25g1.jpg)

GRAPHIC (g113249ex99s26g1.jpg)

GRAPHIC (g113249ex99s27g1.jpg)

GRAPHIC (g113249ex99s28g1.jpg)

GRAPHIC (g113249ex99s29g1.jpg)

GRAPHIC (g113249ex99s2g1.jpg)

GRAPHIC (g113249ex99s30g1.jpg)

GRAPHIC (g113249ex99s31g1.jpg)

GRAPHIC (g113249ex99s32g1.jpg)

GRAPHIC (g113249ex99s33g1.jpg)

GRAPHIC (g113249ex99s34g1.jpg)

GRAPHIC (g113249ex99s35g1.jpg)

GRAPHIC (g113249ex99s36g1.jpg)

GRAPHIC (g113249ex99s37g1.jpg)

GRAPHIC (g113249ex99s38g1.jpg)

GRAPHIC (g113249ex99s39g1.jpg)

GRAPHIC (g113249ex99s3g1.jpg)

GRAPHIC (g113249ex99s40g1.jpg)

GRAPHIC (g113249ex99s41g1.jpg)

GRAPHIC (g113249ex99s42g1.jpg)

GRAPHIC (g113249ex99s43g1.jpg)

GRAPHIC (g113249ex99s44g1.jpg)

GRAPHIC (g113249ex99s45g1.jpg)

GRAPHIC (g113249ex99s46g1.jpg)

GRAPHIC (g113249ex99s47g1.jpg)

GRAPHIC (g113249ex99s48g1.jpg)

GRAPHIC (g113249ex99s49g1.jpg)

GRAPHIC (g113249ex99s4g1.jpg)

GRAPHIC (g113249ex99s50g1.jpg)

GRAPHIC (g113249ex99s51g1.jpg)

GRAPHIC (g113249ex99s52g1.jpg)

GRAPHIC (g113249ex99s53g1.jpg)

GRAPHIC (g113249ex99s54g1.jpg)

GRAPHIC (g113249ex99s55g1.jpg)

GRAPHIC (g113249ex99s56g1.jpg)

GRAPHIC (g113249ex99s57g1.jpg)

GRAPHIC (g113249ex99s5g1.jpg)

GRAPHIC (g113249ex99s6g1.jpg)

GRAPHIC (g113249ex99s7g1.jpg)

GRAPHIC (g113249ex99s8g1.jpg)

GRAPHIC (g113249ex99s9g1.jpg)

XML — IDEA: XBRL DOCUMENT (R1.htm)

8-K

8-K (Primary)

Filename: d113249d8k.htm · Sequence: 1

8-K

NATIONAL FUEL GAS CO false 0000070145 0000070145 2026-04-29 2026-04-29

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 8-K

CURRENT REPORT

Pursuant to Section 13 or 15(d)

of the Securities Exchange Act of 1934

Date of Report (Date of earliest event reported): April 29, 2026

NATIONAL FUEL GAS COMPANY

(Exact name of registrant as specified in its charter)

New Jersey

1-3880

13-1086010

(State or other jurisdiction

of incorporation)

(Commission

File Number)

(IRS Employer

Identification No.)

6363 Main Street, Williamsville, New York

14221

(Address of principal executive offices)

(Zip Code)

Registrant’s telephone number, including area code: (716) 857-7000

Former name or former address, if changed since last report: Not Applicable

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):

☐

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

☐

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

☐

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

☐

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

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

Title of each class

Trading

Symbol

Name of Each Exchange

on Which Registered

Common Stock, par value $1.00 per share

NFG

New York Stock Exchange

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

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. ☐

Item 7.01   Regulation FD Disclosure.

On April 29, 2026, National Fuel Gas Company (the “Company”) updated its Investor Presentation. A copy of the presentation is furnished as part of this Current Report as Exhibit 99.

Neither the furnishing of the presentation as an exhibit to this Current Report nor the inclusion in such presentation of any reference to the Company’s internet address shall, under any circumstances, be deemed to incorporate the information available at such internet address into this Current Report. The information available at the Company’s internet address is not part of this Current Report or any other report filed or furnished by the Company with the Securities and Exchange Commission.

In addition to financial measures calculated in accordance with generally accepted accounting principles (“GAAP”), the press release furnished as part of this Current Report as Exhibit 99 contains certain non-GAAP financial measures. The Company believes that such non-GAAP financial measures are useful to investors because they provide an alternative method for assessing the Company’s operating results in a manner that is focused on the performance of the Company’s ongoing operations, for measuring the Company’s cash flow and liquidity, and for comparing the Company’s financial performance to other companies. The Company’s management uses these non-GAAP financial measures for the same purpose, and for planning and forecasting purposes. The presentation of non-GAAP financial measures is not meant to be a substitute for financial measures prepared in accordance with GAAP.

Certain statements contained herein or in the press release furnished as part of this Current Report, including statements regarding estimated future earnings and statements that are identified by the use of the words “anticipates,” “estimates,” “expects,” “forecasts,” “intends,” “plans,” “predicts,” “projects,” “believes,” “seeks,” “will” and “may” and similar expressions, are “forward-looking statements” as defined by the Private Securities Litigation Reform Act of 1995. There can be no assurance that the Company’s projections will in fact be achieved nor do these projections reflect any acquisitions or divestitures that may occur in the future. While the Company’s expectations, beliefs and projections are expressed in good faith and are believed to have a reasonable basis, actual results may differ materially from those projected in forward-looking statements. Furthermore, each forward-looking statement speaks only as of the date on which it is made. In addition to other factors, the following are important factors that could cause actual results to differ materially from those discussed in the forward-looking statements: changes in laws, regulations or judicial interpretations to which the Company is subject, including those involving derivatives, taxes, safety, employment, climate change, other environmental matters, real property, and exploration and production activities such as hydraulic fracturing; governmental/regulatory actions, initiatives and proceedings, including those involving rate cases (which address, among other things, target rates of return, rate design, retained natural gas and system modernization), environmental/safety requirements, affiliate relationships, industry structure, and franchise renewal; changes in economic conditions, including the imposition of additional tariffs on U.S. imports and related retaliatory tariffs, inflationary pressures, supply chain issues, liquidity challenges, and global, national or regional recessions, and their effect on the demand for, and customers’ ability to pay for, the Company’s products and

services; the Company’s ability to complete strategic transactions, such as the pending transaction with CenterPoint Energy Resources Corp., including receipt of required regulatory clearances and satisfaction of other conditions to closing, and to recognize the anticipated benefits of such transactions; governmental/regulatory actions and/or market pressures to reduce or eliminate reliance on natural gas; the Company’s ability to estimate accurately the time and resources necessary to meet emissions targets; changes in the price of natural gas; impairments under the SEC’s full cost ceiling test for natural gas reserves; the creditworthiness or performance of the Company’s key suppliers, customers and counterparties; financial and economic conditions, including the availability of credit, and occurrences affecting the Company’s ability to obtain financing on acceptable terms for working capital, capital expenditures, other investments, and acquisitions, including any downgrades in the Company’s credit ratings and changes in interest rates and other capital market conditions; negotiations with the collective bargaining units representing the Company’s workforce, including potential work stoppages during negotiations; changes in price differentials between similar quantities of natural gas sold at different geographic locations, and the effect of such changes on commodity production, revenues and demand for pipeline transportation capacity to or from such locations; the impact of information technology disruptions, cybersecurity or data security breaches, including the impact of issues that may arise from the use of artificial intelligence technologies; factors affecting the Company’s ability to successfully identify, drill for and produce economically viable natural gas reserves, including among others geology, lease availability and costs, title disputes, weather conditions, water availability and disposal or recycling opportunities of used water, shortages, delays or unavailability of equipment and services required in drilling operations, insufficient gathering, processing and transportation capacity, the need to obtain governmental approvals and permits, and compliance with environmental laws and regulations; increased costs or delays or changes in plans with respect to Company projects or related projects of other companies, as well as difficulties or delays in obtaining necessary governmental approvals, permits or orders or in obtaining the cooperation of interconnecting facility operators; increasing health care costs and the resulting effect on health insurance premiums and on the obligation to provide other post-retirement benefits; other changes in price differentials between similar quantities of natural gas having different quality, heating value, hydrocarbon mix or delivery date; the cost and effects of legal and administrative claims against the Company or activist shareholder campaigns to effect changes at the Company; uncertainty of natural gas reserve estimates; significant differences between the Company’s projected and actual production levels for natural gas; changes in demographic patterns and weather conditions (including those related to climate change); changes in the availability, price or accounting treatment of derivative financial instruments; changes in laws, actuarial assumptions, the interest rate environment and the return on plan/trust assets related to the Company’s pension and other post-retirement benefits, which can affect future funding obligations and costs and plan liabilities; economic disruptions or uninsured losses resulting from major accidents, fires, severe weather, natural disasters, terrorist activities or acts of war, as well as economic and operational disruptions due to third-party outages; significant differences between the Company’s projected and actual capital expenditures and operating expenses; or increasing costs of insurance, changes in coverage and the ability to obtain insurance. The Company disclaims any obligation to update any forward-looking statements to reflect events or circumstances after the date hereof.

Item 9.01   Financial Statements and Exhibits.

(d)

Exhibits

Exhibit 99

Investor Presentation dated April 2026

Exhibit 104

Cover Page Interactive Data File (embedded within the Inline XBRL document).

SIGNATURES

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

NATIONAL FUEL GAS COMPANY

By:

/s/ Lee E. Hartz

Lee E. Hartz

General Counsel and Secretary

Dated: April 29, 2026

EX-99

EX-99

Filename: d113249dex99.htm · Sequence: 2

EX-99

Investor Presentation Fiscal 2026

– 2nd Quarter Update April 29, 2026 Exhibit 99

National Fuel Gas Company Company

Overview (3) Recent Highlights (6) Why National Fuel? (11) Financial Overview (16) Integrated Upstream & Gathering Highlights (20) Pipeline & Storage and Utility Highlights (32) Guidance & Other Financial Information (46)

Company Overview Left picture: Seneca

Resources rig in Tioga County, PA. Right picture: Buffalo Bills’ New Highmark Stadium construction in Orchard Park, NY. Corporate HQ: Buffalo, NY ~2,300 employees NYSE: NFG Market Cap: ~$8.4B 123 Years of consecutive dividend payments 55 Years

of consecutive dividend increases >10% Adjusted EPS Growth FY24-FY27E Investment Grade credit rating 25% reduction in methane emissions since 2020 Note: This presentation includes forward-looking statements. Please review the safe harbor for

forward looking statements at the end of this presentation. Market capitalization is presented as of April 27, 2026.

History of National Fuel Industry

Pioneer Born From Rockefeller’s Standard Oil Company

NFG: A Diversified, Integrated Natural

Gas Company Developing our large, high-quality acreage in Marcellus & Utica shales Providing safe, reliable and affordable service to customers in WNY and NW PA CNP Ohio Acquisition Will Double Rate Base Integrated Upstream & Gathering

Regulated Midstream Pipeline & Storage Downstream Utility Expanding and modernizing pipeline infrastructure to provide outlets for Appalachian natural gas production ~1.2 Million Net acres in Appalachia ~1.1 Bcf/day Net total production(3) 77

Bcf of natural gas storage capacity 4.5 MMDth Daily interstate pipeline capacity under contract 756,000 Utility customers ~800 Miles of pipeline replaced over the last five years 69% 18% 13% Adjusted EBITDA(1) Non-Regulated Regulated (1) Twelve

months ended March 31, 2026. A reconciliation of Adjusted EBITDA to Net Income as presented on the Consolidated Statement of Income and Earnings Reinvested in the Business is included at the end of this presentation. (2) Closing of the CNP Ohio

acquisition is expected to occur in the fourth quarter of calendar 2026, pending review of a notice filing by the Public Utilities Commission of Ohio and other customary closing conditions. (3) Average for the three months ended March 31, 2026.

(2)

Recent Highlights Strength of the

Integrated Model Evident as Each Business Contributes Meaningfully Doubled core inventory in the EDA with the delineation of Upper Utica zone Filed a rate case in our Utility’s Pennsylvania jurisdiction requesting new rates effective fiscal

2027 Slide 40 Slide 26 Utility Upstream & Gathering Continue to add new firm transportation agreements to support future production growth Slide 28 Upstream & Gathering Acquisition of CenterPoint’s Ohio gas utility business remains on

track to close in Q4 calendar 2026 Slide 7 Utility Pipeline expansion projects, including new Line N System Upgrade, highlight improving outlook Slide 37 Expect to file Supply rate case with FERC on 4/30/26, with new rates effective fiscal 2027

Slide 33 Pipeline & Storage Pipeline & Storage

Announced Acquisition of

CenterPoint’s Ohio Gas Utility Acquiring a High-Quality Gas Utility in a Neighboring Service Territory Entered into an agreement to acquire CenterPoint’s Ohio gas utility business for $2.62 billion, representing ~1.6x 2026E rate base of

$1.6 billion Increases Scale & Balances Business Mix Attractive Regulatory & Political Environment Significantly Increases Regulated Investment Opportunity Enhances Regulated Earnings Growth & Dividend Support Strong Pro-forma Credit

Profile Accretive to Long-Term Earnings per Share Note: Closing of the CNP Ohio acquisition is expected to occur in the fourth quarter of calendar 2026, pending review of a notice filing by the Public Utilities Commission of Ohio and other customary

closing conditions.

Acquisition Update Remain on Track to

Close in the Fourth Quarter Calendar 2026 Integration Planning Progressing Well Working closely with the CenterPoint management team to ensure a smooth transition for employees and customers Regulatory Filings on Track Submitted notice filing with

the Public Utilities Commission of Ohio (PUCO) on January 9, 2026; expect to be completed by end of Q3 FY26 Hart-Scott-Rodino filed January 16, 2026; 30 day waiting period expired and requirement is deemed satisfied Financing Update Issued $350 MM

in common equity through a private placement with accredited, long-only investors; fulfills equity needs to maintain investment grade credit rating Debt issuance will incorporate pro forma financial statements (expected this spring); once available,

will look to access debt capital markets to raise remaining proceeds due at closing Continue to target Debt/EBITDA of 2.5 – 3.0x and FFO/Net Debt of greater than 30% by the end of the fiscal year after closing PUCO Issued Final Ruling on Ohio

Rate Case On January 7, 2026 PUCO issued its final order regarding CenterPoint’s Ohio gas rate case Adopted a modestly lower ROE (Authorized 9.79% vs 9.85%) and extended the amortization period for certain riders from 15 to 25 years; outcome

has a minimal impact to earnings and credit metrics and is accretive to long-term rate base growth New rates went into effect January 12, 2026 Ohio Legislative Update Passed Senate Bill 103 which modernizes ratemaking in Ohio Allows for a 3-year

fully projected test period (previously used historical test period) with an authorized return true-up mechanism Enables timely recovery of costs and cash flows by requiring PUCO to issue final order within 360 days from date of filing (well in

advance of previous timelines)

Western Development Area –

~920,000 Acres Eastern Development Area – ~310,000 Acres Non-Regulated Business Overview Reported annually as of September 30, 2025. Average net production and throughput for the three months ended March 31, 2026. Integrated Upstream &

Gathering Segment Seneca Resources Company Total Net Acres (Pennsylvania): ~1.2 million Total Proved Reserves: 5.0 Tcfe(1) Current Net Production: ~1.1 Bcf/d(2) Current Firm Transportation: ~1 Bcf/d to premium markets 45+ years of Marcellus and

Utica development inventory National Fuel Gas Midstream Company Total Throughput: ~1.2 Bcf/d(2) (including third-party) ~400 miles of gathering pipeline ~128k HP of compression Interconnections with 7 major pipelines

Regulated Business Overview Pipeline

& Storage Segment Utility Segment Regulated by Federal Energy Regulatory Commission (FERC) Total Rate Base: $1.7 Billion(2) ~2,600 miles of pipeline / 28 storage fields National Fuel Gas Supply Corporation: Firm Contracted Storage Capacity: 71

Bcf(3) Firm Contracted Transportation Capacity: 3.4 Bcf / day(3) Empire Pipeline, Inc.: Firm Contracted Storage Capacity: 4 Bcf(3) Firm Contracted Transportation Capacity: 1.1 Bcf / day(3) Interconnections with 8 major interstate pipelines New York

Jurisdiction 543,000 customers Regulated by the New York Public Service Commission (NYPSC) Pennsylvania Jurisdiction 213,000 customers Regulated by the Pennsylvania Public Utility Commission (PAPUC) Total Rate Base: $1.6 Billion(2) Fiscal 2025 Total

Throughput: ~142 Bcf Provides >90% of the space heating load in operating footprint Closing of the CNP Ohio acquisition is expected to occur in the fourth quarter of calendar 2026, pending review of a notice filing by the Public Utilities

Commission of Ohio and other customary closing conditions. Estimated rate base as of March 31, 2026. Reported annually as of September 30, 2025, and includes short-term and long-term contracted capacity. (1)

Why National Fuel? Optimized capital

allocation Lower cost of capital Operational synergies Improved profitability Regulated earnings growth from modernization, expansion and Ohio utility acquisition Increasing free cash flow driven by improving upstream & gathering capital

efficiencies Responsibly Reduce Emissions Continued progress toward emissions reduction targets Enhanced GHG disclosures on sustainability initiatives 123 consecutive years of dividend payments 55 consecutive years of dividend increases

Long-Standing History of Shareholder Returns Responsibly Reducing Emissions Visibility on Long-Term EPS & FCF Growth Strong Integrated Returns

Integrated Model Drives Strong

Returns Source: NFG actuals as reported; S&P500 and Industry Peers as reported in Bloomberg for the TTM ending September 30th. NFG adjusted excludes after-tax non-cash ceiling test impairments. Average Annual NFG Stock Outperformance Since FY17

NFG vs. S&P 500: +2% NFG vs. E&P Peers: +6% NFG vs. Utility Peers: +6% NFG’s ROCE Outperforms Peers and Broader Market, on Average, Over a Multi-Year Period Decrease driven by non-cash impairments S&P O&G Index NFG S&P 500

UTY Integrated Business Model Benefits Operational: Lower cost structure Financial: Lower cost of capital Strategic: Optimized capital allocation Commercial: Greater revenue / margin NFG Adj. (2)

(1) Fiscal 2024 adjusted EPS of $1.85

for the regulated companies excluded an after-tax impairment charge of $0.37 in the Pipeline & Storage segment (GAAP EPS for the regulated companies was $1.48). In fiscal 2025, there were no items impacting comparability in the regulated

companies. Fiscal 2025 EPS of $2.24 for the regulated companies increased $0.39, or 21%, over fiscal 2024 adjusted EPS of $1.85. (2) FY25 and Q1 FY26 include actual results, as reported. Remaining 9 months of FY26 and FY27 NYMEX based on flat price

assumptions. Includes current hedge positions as of December 31, 2025 and excludes acquisitions. Note: The Company defines free cash flow as net cash provided by operating activities, less net cash used in investing activities, adjusted for

acquisitions and divestitures. See non-GAAP financial measures information at the end of this presentation. Assumes current hedges. Assumes no pricing-related curtailments. Strong Value Proposition Driven by Earnings & Cash Flow Outlook

Increasing EPS drives future dividend growth Ratemaking activity propelled FY25 adjusted EPS growth of ~21%(1) Beyond FY26, expect adj. EPS CAGR of 5-7%, similar to average annual rate base growth CNP Ohio acquisition supports long-term 5-7%

regulated adj. EPS growth on higher base of earnings post close Regulated: Pipeline & Storage & Utility Businesses Significant FCF generation expected to provide flexibility in capital allocation priorities Hedging provides near-term

visibility to growing FCF generation, with the ability to capture higher natural gas prices long-term Non-Regulated: Upstream and Gathering Businesses Non-Regulated Free Cash Flow(2) 8-10% CAGR (current business) Regulated Adjusted Earnings Per

Share ($ millions) $3.00 $4.00 $5.00 NYMEX Long-Term Growth Remains On Track: >10% Consolidated 3-Year Adjusted EPS CAGR (FY24-27E) + EPS growth from CNP Ohio

Over Half Century of Dividend Growth

$1.6 Billion Dividend payments Over Last 10 Years $2.14 per share 55 Years Consecutive Dividend Increases $0.19 per share 123 Years Consecutive Payments 4% 2025 Dividend Increase Acquisition of CNP Ohio Provides Potential Enhancement to Long-Term

Dividend Growth

Considerable Progress on Emissions

Reductions All emissions reduction targets based on 2020 baseline. Measured using calendar 2024 emissions data, as reported in Company’s 2024 Corporate Responsibility Report. Continued Progress On Our Methane Intensity Targets(1) E&P and

Gathering surpassed targets six years ahead of plan Prioritization of emissions reduction projects that deliver highest impact per dollar invested Continued progress on consolidated emissions reductions while growing the business: 25% consolidated

methane emissions reductions since 2020 10% consolidated GHG reductions since 2020 Latest Corporate Responsibility Report Provides Disclosures on Sustainability Initiatives

Financial Overview

Continued Momentum Propels Higher

Earnings Guidance Growth Supports Consolidated 3-Year Adj. EPS CAGR >10% (FY24-27E) Adjusted Earnings Per Share(1) ($ per share) Excludes items impacting comparability. Consolidated Adjusted Earnings Per Share includes Corporate & All Other.

See Comparable GAAP Financial Measure Slides & Reconciliations at the end of this presentation. The acquisition of CNP’s Ohio natural gas utility business is expected to close in Q4 of calendar 2026 and therefore, has no impact on FY26

shown above. Fiscal 2026 Adjusted EPS is shown at the midpoint of guidance range, as detailed on slide 47, assuming NYMEX pricing of $3.00. Q2 Financial Summary Integrated Upstream and Gathering – higher realized prices compared to the prior

year, primarily from a 38% increase in NYMEX pricing Regulated – higher utility net income compared to the prior year as a result of rate case outcomes and modernization investments; continued progress on Pipeline & Storage expansion

projects to support future growth FY26 Guidance Highlights Integrated Upstream and Gathering – ongoing improvement in capital efficiency Regulated – continued growth as a result of ongoing ratemaking efforts, driven by the three-year NY

rate settlement (through FY27) and PA modernization tracker, or DSIC (Distribution System Improvement Charge) Quarter Highlights & FY26 Outlook (2) +10%

Capital Allocation Priorities Drive

Spending Levels (2) Capital expenditures includes accrued capex. Total Capital Expenditures include Corporate and All Other. A reconciliation to Capital Expenditures as presented on the Consolidated Statement of Cash Flows is included at the end of

this presentation. FY26 consolidated capital guidance is displayed at the midpoint of the range ($955 - $1,065 million). FY23 reflects the netting of $150 million related to the acquisition of Appalachian upstream assets. FY24 reflects the netting

of $6.2 million related to the acquisition of assets from UGI. Capital Expenditures by Segment ($ millions)(1) Capital Allocation Priorities Organic Investments Responsibly Manage the Balance Sheet Return of Capital to Shareholders Highly Strategic

M&A Invest in regulated growth via modernization and pipeline expansions Maintain mid-single digit production growth in Integrated Upstream & Gathering segment Maintain investment grade credit rating Target optimal ratemaking capital

structure Uphold 55-year history of dividend increases Execute value-accretive share repurchases Integrated Upstream & Gathering opportunities geographically proximate to existing operations Regulated growth to add scale and further balance

business mix Regulated Growth Non- Regulated Capital Efficiency

Balance Sheet Resiliency Through the

Commodity Cycle Net Debt / Adjusted EBITDA(1) Net Debt is net of cash and temporary cash investments. Reconciliations of Net Debt and Adjusted EBITDA are included at the end of this presentation. A reconciliation of Funds From Operations (FFO) to

Net Cash Provided by Operating Activities can also be found at the end of this presentation. We are unable to reconcile certain forward looking non-GAAP financial measures and ratios. Please see slide entitled Comparable GAAP Financial Measure

Slides & Reconciliations at the end of this presentation. Note that FY26 and FY27 are shown at current strip. (2) Note that FY26 excludes any potential impact from financing the CNP Ohio acquisition. Further, note the capitalization ratio as of

3/31/26 excludes the impact of the $350 MM common equity issuance. Current Credit Rating Investment Grade Credit Rating S&P BBB- Moody’s Baa3 Fitch BBB Investment Grade Credit Rating Committed to Investment Grade Credit Rating Debt

Maturity Profile by Fiscal Year ($ MM) FFO / Net Debt(1) Capitalization as of 3/31/26 Downgrade Threshold Downgrade Threshold $1.3B Committed Credit Facility Post Close CNP Ohio Post Close CNP Ohio (2) (2) (2)

Integrated Upstream and Gathering

Business Highlights

Integrated Upstream & Gathering

Highlights Significant Improvement in Capital Efficiency (FY26E vs. FY23) Production up 16% and Capital down 15% 50% Increase in Core Inventory (15+ Years) Over 45 Years of Total Remaining Inventory >500 MDth/d Increase in Firm Transportation

(FT) by FY30 ~1,500 MDth/d of total FT by FY30 New FT agreement to the Gulf Coast for 50 MDth/day Re-certified with A-grades from MiQ and Equitable Origin A-grade Certifications Four Years in a Row Enhancing Capital Efficiency Expanding Inventory

Depth Increasing Firm Transportation Improving Sustainability Metrics Upstream and Gathering

Integrated Upstream & Gathering

Eastern Development Area ~310,000 Acres Development zones: Marcellus, Upper Utica, Lower Utica 25+ years of development inventory at PV-10 breakeven price of less than $2.25/MMBtu NYMEX Expect to average 25 to 27 wells brought online per year Well

and facility design optimization continues to drive improved productivity Diverse and growing marketing portfolio with ~1,500 MDth/d of future firm transportation Integrated gathering systems provide optimized investment timing, low-cost structure

and resilient thru-cycle margins Western Development Area ~920,000 Acres (mostly held in fee) Development zones: Marcellus, Lower Utica Development Plan Highlights Upstream and Gathering

Increasing FCF through Enhanced

Capital Efficiency… A reconciliation to Capital Expenditures as presented on the Consolidated Statement of Cash Flows is included at the end of this presentation. FY23 capex reflects the netting of $150 million related to acquisition of

upstream assets and acreage from total capital expenditures. FY24 capex reflects the netting of $6 million related to the acquisition of assets from UGI from E&P capex of $536 million. Significant Improvement in Capital Efficiency Since FY23

+16% -15% Capital Expenditures ($ MM)(1) Net Production (Bcfe) Gathering Upstream Upstream and Gathering

…While Driving Low-Cost

Structure and Strong Margins LTM Peer vs NFG Margin ($/Mcfe)(1) (1) Margin calculated as LTM EBITDA divided by LTM total production as of 12/31/2025. NFG shown as of 12/31/2025 for comparative purposes and represents the combined Integrated Upstream

and Gathering segment. Peers include AR, CNX, EQT, EXE, GPOR and RRC. FY26E Integrated Operating Expense ($/Mcfe) 94% 89% 100% 92% 92% 69% 64% % Gas Volumes Upstream and Gathering

Lower Utica Gen 4 Testing Underway

Gen 3 design primarily uses 1,800 ft. inter-well spacing, 2,200 lbs. per ft. of proppant intensity, and 150 ft. stage spacing. Gen 4 design primarily uses 2,000 ft. inter-well spacing, 3,000 lbs. per ft. of proppant intensity, and 150 ft. stage

spacing. Blue shaded leasehold is where Seneca has > 25% ownership in township. Upstream and Gathering Lower Utica Well Performance Gen 1 Lower Utica Gen 2 Lower Utica Gen 3 Lower Utica (1) Gen 4(2,3) Testing Underway FY26 Planned Producing

Addition of Upper Utica Zone More

than Doubles Tioga Utica Inventory Upper Utica Adds ~8 Years Inventory on Existing Infrastructure Increased Core Inventory to ~400 Premium Locations Blue shaded leasehold is where Seneca has > 25% ownership in township. Includes wells online for

at least 1 month and offset operator. Upstream and Gathering Upper Utica Type Curve Upper Utica(2) (9 wells) ~220 additional Upper Utica locations with similar productivity to Lower Utica ~300 ft resource column with strong frac barrier

establishes two distinct zones ~170 premium Lower Utica locations with EURs of 2.5 Bcf / 1,000 ft. Upper Utica Lower Utica Frac Barrier ~300 ft Upper Utica Map(1) Remaining FY26 Uppers Producing Upper Third party operator

Decades of High-Quality Inventory at

Industry Leading Breakevens Assumes an average of 25 to 30 wells brought online/year, which is equivalent to current pace. Enverus research is at $2.50 breakevens as of the most recent report published on April 20, 2026. Peers include EQT, RRC, AR,

GPOR, Ascent, CNX, EXE. Enverus Analysis Validates Inventory Depth (1) EDA WDA Seneca Analysis: >15 Years of Inventory @ <$2.00 Breakevens (2) Upper Utica Upper Utica Upstream and Gathering Does not yet incorporate Upper Utica

locations

Production Growth Supported by New

Firm Transportation Marketing Portfolio Has Premium Market Access(1) New FT Enhances Long-Term Marketing Portfolio: Supports future production growth with egress from EDA Minimizes spot exposure (together with in-basin firm sales) Increases

optionality and connectively to premium markets Data center developments (Western PA, Mid-Atlantic) Gulf Coast (LNG exports, industrial markets) NEW Added another 50 MDth/d to the Gulf Coast (100 MDth/d in total) Northern Markets ~30% of total

Southeast, Gulf Coast ~20% of total Northeast ~20% of total Percentages in chart indicate firm transportation capacity as of fiscal 2030. FT increases of 100 MDth/d in FY26 (Premium PA Markets and Gulf Coast), 215 MDth/d in FY27 (Premium PA Markets

and Gulf Coast), 275 MDth/d in FY28-30 (Premium PA Markets and Gulf Coast). NE Supply Divers. 50 MDth/d Niagara Expansion (TGP & NFG - Supply) 170 MDth/d Atlantic Sunrise (Transco) 189 MDth/d Tioga County Extension (NFG - Empire) 200 MDth/d

Premium PA Markets ~30% of total Premium PA Markets 490 MDth/d ~1,000 MDth/d FT ~1,500 MDth/d FT Gulf Coast 100 MDth/d Leidy South (Transco & NFG - Supply) 330 MDth/d Upstream and Gathering

FY 2026 Sales Mix Provides

Significant Price Certainty (1) Q3 Volumes: Fixed Price 23 Bcfe, NYMEX-Linked 69 Bcfe, Index 3 Bcfe. Q4 Volumes: Fixed Price 23 Bcfe, NYMEX-Linked 69 Bcfe, Index 3 Bcfe. All prices shown in $/MMBtu. NYMEX-linked and Index prices shown as

differentials to NYMEX. Expected production of 425 to 440 Bcfe Minimal spot exposure of 25 to 40 Bcfe (~15% of remaining volumes) Firm sales contracts in place for ~85% of expected remaining production ~75% of expected production paired with a NYMEX

financial hedge or entered into at a fixed price Continue to utilize in-basin firm sales to reduce spot exposure Fiscal 2026 Highlights Upstream and Gathering Firm Sales & Production Cadence(1) $2.55 $2.55 ($0.81) ($0.81) ($0.54) ($0.41) 109

Bcfe 102 Bcfe

…Collars and Unhedged

Production Provide Upside Capture Opportunities Hedging Program: Disciplined with Upside Potential Methodical Approach to Layering in Hedges Over Time Supports Investment Grade Credit Rating Swaps and Fixed Price Sales Provide Price

Certainty(1)… Swaps and Fixed Price Sales Provide Price Certainty(1)… ~55% ~25% ~40%- 45% ~70%- 75% ~95%- 100% ~20% Upside with Collars FY26 estimated hedge percentage shown for the remaining 6 months and assumes midpoint of production

guidance for the year with the remaining years at mid-single digit growth. Strip includes NYMEX settle for April 2026. (2) Upstream and Gathering

Industry-Leading Focus on

Sustainability Responsible Gas Certifications, Emission Reductions & Water Management Equitable Origin – EO100TM Standard for Responsible Energy Development Certification (100% of natural gas production and gathering assets certified)

Certification focuses on three emissions management criteria: Methane Intensity Company Practices to Manage Methane Emissions Emissions Monitoring Technology Deployment MiQ (100% of production assets re-certified in August 2025) Encompasses the

following principles: Corporate Governance, Transparency & Ethics Human Rights, Social Impacts & Community Development Indigenous People’s Rights Fair Labor & Working Conditions Climate Change, Biodiversity & Environment

Emission Reductions Water Management Wholly-owner water management subsidiary, Highland Field Services, LLC, optimizes water handling, treatment and storage Partner with local townships, government agencies, and environmental groups on water quality

improvement projects Operate a vast water pipeline network which reduces truck traffic, leading to decreased emissions and less wear on roads Both E&P (Seneca) and Gathering (Midstream) surpassed 2030 Methane Intensity Reduction Targets in

calendar 2024 Significant reductions in methane driven by: Natural gas pneumatic device conversions Operational BMPs for well liquids unloading and flowback Increased fugitive emissions monitoring In 2024, Highland recycled more than 95% of

Seneca’s produced fluids Upstream and Gathering Executed a long-term agreement with Centrica Energy to sell 250,000 MMBtu/day of MiQ-certified gas certificates over the next ten years.

Pipeline & Storage and Utility

Overview Business Highlights

Pipeline & Storage and Utility

Highlights Tioga Pathway and Shippingport Lateral projects expected to add ~$30 MM in incremental annual revenues Construction is ongoing with both projects on track for a late calendar 2026 targeted in-service date Continued interest in further

capacity additions across our FERC-regulated pipeline system, including newly announced Line N System Upgrade project New York 3-Year rate case settlement(2) drives continued earnings growth Pennsylvania Utility rate case filed on 1/28/2026, with

rates expected to be effective 11/1/26 Supply Corp. expects to file a rate case with FERC on 4/30/26, with new rates effective 11/1/26 Utility rate base is expected to double upon closing, significantly increasing scale Begins to rebalance business

mix by increasing share of regulated earnings and cash flows Supports long-term 5-7% regulated adjusted EPS target, while growing regulated earnings Pipeline Expansion Projects Drive Meaningful Growth Rate Case Activity Balances Modernization

Spending & Affordability Continued Growth Expected from Ohio Utility Acquisition DSIC tracker allows recovery on incremental system investments after July 31, 2024, subject to attaining rate year plant balance of $781.3 million and earning below

a statewide ROE target (currently 10.25%). See Case 23-G-0627 on file with the NY PSC. Long-standing modernization programs enable continued investment in the system to ensure the safety and reliability of service to customers Rate base growth in

Pennsylvania from Distribution System Improvement Charge (DSIC)(1), or system modernization tracker, allows for additional earnings growth up to ~$7 MM/year Long-term expected rate base growth of approximately 5-7% drives earnings growth

Modernization Programs Drive Rate Base Growth

Pipeline & Storage Segment

Overview Firm transportation includes short-term and long-term and is disclosed annually as of September 30, 2025. Reported as of March 31, 2026. Empire Pipeline, Inc. National Fuel Gas Supply Corporation Empire Pipeline Supply Corp. Contracted

Capacity(1): Firm Storage: 71 Bcf (fully subscribed) Firm Transportation: 3.4 Bcf / day Rate Base(2): ~$1.4 billion FERC Rate Proceeding Status: Rate case settled in Q2 FY24 and approved by FERC June 11, 2024 New rates went into effect February 1,

2024 Supply Rate Case expected to be filed 4/30/26 Contracted Capacity(1): Firm Storage: 4 Bcf (fully subscribed) Firm Transportation: 1.1 Bcf / day Rate Base(2): ~$0.3 billion FERC Rate Proceeding Status: Settlement approved by FERC on March 17,

2025 New rates went into effect November 1, 2025 Moratorium period until April 30, 2027 Comeback required by May 31, 2031 Pipeline & Storage

Pipeline & Storage Customer Mix

Customer Transportation by Shipper Type Affiliated Customer Mix (Contracted Capacity) Note: Data disclosed annually as of 9/30/2025. Pipeline & Storage Firm Transport

Pipeline Modernization &

Expansion Projects Propel Growth A reconciliation to Capital Expenditures as presented on the Consolidated Statement of Cash Flows is included at the end of this presentation. FY26E capex is presented at mid-point of guidance. Capex Investments

Support Long-Term Rate Base Growth Estimate of ~5-7% Pipeline & Storage Organic Growth Drivers Expect long-term non-expansion capex spend of ~$100-150 MM/year Expansion projects drive further growth potential, such as the Tioga Pathway and

Shippingport Lateral projects (late calendar 2026) Tioga Pathway & Shippingport Lateral Project

Executing on Pipeline Expansion

Projects Line N System Upgrade Project Replacement of 6 miles of Line N (with delivery to TGP Mercer) Total Capex: ~$93 million (~$27 million in expansion capital) Expansion Capacity: 94,000 Dth/day Target In-Service: November 2028 Executed

Precedent Agreement Foundation Shipper Open Season anticipated in mid-2026 Tioga Pathway Project Outlet to support Seneca’s growing production out of the EDA Total Capex: ~$100 million (~$82 million in expansion capital) Capacity: 190,000

Dth/day Total annual revenue: ~$15 million Shippingport Lateral Project Supports behind the meter data center development along the Line N corridor Total Capex: ~$57 million Capacity: 205,000 Dth/day with potential to increase significantly Total

annual revenue: ~$15 million à Both Tioga Pathway and Shippingport Lateral projects have received FERC approval and remain on track for a November 2026 in-service date Tioga Pathway Pipeline Pipeline & Storage Line N System Upgrade NEW

Shippingport Lateral

Continued Expansion Opportunities for

Supply Corp. Line N System Pipeline & Storage Additional Line N Expansion Opportunities Line N is well positioned to support growing baseload power needs across PJM, as well as behind the meter generation for AI and data center deployments

Significant data centers exist today, plus more expected in the future Proximate to fiber corridor and high-voltage transmission lines Ability to serve greenfield, underutilized, or previously decommissioned power assets along Line N corridor Access

to significant gas supply in SW PA/WV Line N has several expansion options to scale with evolving project requirements Evaluating potential projects for end users, as well as projects for producers and marketers that could reach various markets,

including to Rover and TGP Pipeline at Mercer Line N

Utility Service Territories in New

York & Pennsylvania New York Last Rate Case: Joint Proposal approved December 19, 2024 (3-year rate plan effective Oct. 1, 2024 through Sept. 30, 2027) Total Customers(1): ~543,000 Allowed ROE: 9.7% (NYPSC Case 23-G-0627) Rate Mechanisms:

Revenue Decoupling Weather Normalization Low Income Customer Discount Reconciliation Merchant Function Charge (Uncollectibles Adj.) 90/10 Sharing (Large Customers) Uncollectible Expense Tracker Pennsylvania *Filed rate case with the PAPUC in January

2026, see next slide Last Rate Case: 2023 (rates effective August 1, 2023) Total Customers(1): ~213,000 Allowed ROE: Black-box settlement (2023) Rate Mechanisms: Weather Normalization (added Aug. 1, 2023), subject to 3% deadband Low Income Rates

Merchant Function Charge (Uncollectibles Adj.) Distribution System Improvement Charge (DSIC) Initiated recovery of eligible costs on January 1, 2025 Disclosed annually as of September 30, 2025. Utility

Pennsylvania Rate Case Overview Base

Rate Increase = $19.7 million 7.4% increase in total revenues, or ~2.5% increase per year since last rate case New rates expected to be effective November 1, 2026 Proposed Base Revenue Increase Key Drivers Capital Structure and Returns: Capital

Structure = 43.6% debt / 56.4% equity Return on Equity = 11.25% Total Rate of Return = 8.78% Increasing rate base and depreciation expense associated with higher plant in-service NFGDC PA plans to accelerate pipeline replacement from 53 miles in

2025 to 57 miles in 2027 O&M expense inflation (e.g., labor and benefits) Seeking permanent status for Weather Normalization Adjustment (WNA) mechanism Proposing Residential Energy Efficiency pilot program Proposing to mitigate the rate increase

by utilizing $7 MM set aside in a trust for the future benefit of rate payers (related to previous OPEB over-collections) On January 28, 2026, National Fuel Gas Distribution Corporation filed a request with the Pennsylvania Public Utility Commission

(PAPUC) to amend its tariff and increase its base rates Utility

NY Utility Rate Case Supports Growing

Earnings Outlook Three-Year Rate Settlement Approved on December 19th, 2024 Joint Proposal approved(1) on December 19, 2024: 3-year rate settlement (fiscal 2025 – 2027) with no significant modifications to the filed Joint Proposal New rates

implemented on Jan. 1, 2025 with make-whole provision allowing full recovery over calendar 2025 of incremental revenue requirement not billed to customers between Oct. 1, 2024, and Dec. 31, 2024 Maintains modernization (pipeline replacement) program

at a minimum of 105 miles per year over rate plan Recovery of system modernization costs, including higher rate base and depreciation expense, now included in new base rates (revenue requirement) Ratemaking mechanisms: Continuation of: weather

normalization; revenue decoupling; industrial 90/10 symmetrical sharing; merchant function charge New: uncollectible expense tracker; gas safety and customer service performance metrics; customer bill impact levelization See Case 23-G-0627 on the NY

PSC website. Rate Case Drivers Old Rates Approved (New) Rates (in millions) FY24 FY25 FY26 FY27 Revenue Requirement Cumulative Increase (relative to FY24) n/a $57.3 $73.1 $85.8 Rate Base $858 $1,044 $1,104 $1,163 Authorized ROE 8.7% 9.7% 9.7% 9.7%

Authorized Equity Ratio 43% 48% 48% 48% Utility Utility

Customer Affordability New York

Pennsylvania Based on 2025 average monthly residential bill data posted on company websites required by the NYPSC. Based on analysis of 2025 PAPUC Annual Rate Comparison Report, which includes data for average monthly residential bills for January

2025. Utility #1 Out of 9 Gas Utilities(1) #1 Out of 6 Gas Utilities(2) Expect to be among the lowest in calendar 2026 as well, including rate increase Expect to be among the lowest in calendar 2026 as well, including proposed rate increase

Utility Continues its Significant

Investments in Safety (1) A reconciliation to Capital Expenditures as presented on the Consolidated Statement of Cash Flows is included at the end of this presentation. Increase from FY23 to FY24 is partially due to the impact of New York

State’s Roadway Excavation Quality Assurance Act (“REQAA”) which will continue to increase investment costs in future years. Long-Standing Focus on Distribution System Safety and Reliability Utility (2)

Long-Standing Pipeline Replacement

& Modernization NY ~10,000 miles PA ~5,000 miles Miles of Utility Main Pipeline Replaced(2) Utility Mains by Material(1) (1) All values are reported on a calendar year basis, as of December 31, 2025, as required by the DOT. (2) All values are

reported on a fiscal year basis, as required by the NYPSC and PAPUC. Utility

Baseline emissions & emissions

reduction targets are calculated pursuant to the reporting methodology under the EPA GHG Reporting Program (current Subpart W, and using AR5), primarily Distribution pipeline mains & services. Revisions of Subpart W emissions factors, effective

for 2025 reporting, will change the reported baseline, 2025 emissions profile, and progress against these targets. New York Climate Leadership and Community Protection Act, enacted in 2019. Targets Exceed Those Included in New York State Climate Act

(CLCPA)(2) Reductions Primarily Driven by Ongoing Modernization of Mains and Services Utility Targeting Substantial Emissions Reductions 2030 75% Significant Reductions in Utility GHG Emissions to Date, Driven by System Modernization Efforts GHG

Reduction Targets, Continuing Focus on Lowering Carbon Footprint ~70% Reduction Since 1990 (510,000 Metric Tons CO2e) Utility GHG Emissions Reduction Targets(1) (Based on 1990 EPA Subpart W Emissions) 90% 2050 Utility

Guidance & Other Financial

Information Contact Information: Natalie Fischer, Director of Investor Relations (716) 857-7315 fischern@natfuel.com

Updated FY26 Adjusted EPS Guidance

& Assumptions Note: The acquisition of CenterPoint Energy’s Ohio natural gas utility business is expected to close in Q4 of calendar 2026 and therefore, has no impact on FY26 shown above, including financing and acquisition related costs.

Excludes items impacting comparability. See Comparable GAAP Financial Measure Slides & Reconciliations at the end of this presentation. Guidance assumes NYMEX pricing of $3.00/MMBtu and in-basin spot pricing of $2.20/MMBtu for the remaining 6

months in Fiscal 2026, and reflects the impact of existing financial hedges, firm sales and firm transportation contracts. Customer Margin is defined as Operating Revenues less Purchased Gas Expense. Consolidated Effective Tax Rate ~25.5% ~25.5%

Integrated Upstream & Gathering Previous Guidance Updated Guidance NYMEX natural gas price (per MMBtu) $3.75 $3.00 Remaining 6 months Spot Price (per MMBtu) $2.85 $2.20 Remaining 6 months Production (Bcf) 440 – 455 425 – 440

Integrated Operating Costs ($/Mcf) Upstream G&A ~$0.18 ~$0.18 LOE $0.17 - $0.18 $0.16 - $0.17 Gathering O&M ~$0.11 ~$0.12 DD&A $0.76 - $0.81 $0.76 - $0.81 Pipeline & Storage Previous Guidance Updated Guidance Revenues ($MM) $415

– 430 $420 – 435 O&M Expense 4 – 5% increase 4 – 5% increase Utility ($MM) Previous Guidance Updated Guidance Customer Margin(3) $470 – 490 $470 – 490 O&M Expense $250 - 260 $250 - 260 Non-Service Pension

/ OPEB Income $23 - 27 $23 - 27 Capital Expenditures ($MM) Previous Guidance Updated Guidance Integrated Upstream & Gathering $560 – $610 $560 – $610 P&S $210 – $250 $210 – $250 Utility $185 – $205 $185 –

$205 Total Company $955 – $1,065 $955 – $1,065 (1) Assuming $3.00 NYMEX, FY26 Adjusted EPS(2) of $7.45 - $7.75 ($7.60 at midpoint) represents 10% increase from FY25

Type Curves Demonstrate Outstanding

Well Results *All TILs except for 1 in FY26 are Tioga Utica Estimated wells Fiscal 2026 Drills 25 - 27 TILs* 25 - 27 Avg. TLL 12,500 – 13,000’ Drilling rigs 1.5 Estimated Tioga Utica Lower Tioga Utica Upper Tioga Marcellus Lycoming

Marcellus WDA Utica Location Count 170 220 56 20 250 Avg. TLL (ft) 13,000’ 13,000’ 10,000’ 8,000’ 13,000’ D&C ($000s/ft) $1,250- $1,300 $1,250- $1,300 $900- $1,000 $1,075- $1,125 $1,050- $1,100 Avg. Royalty 15% 15%

15% 16% 2% EUR (Bcfe/ft) 2.5 2.0 – 2.4 2.0 2.7 1.7 Operational Data

Regulated Businesses: Rate Case

Overview Supply Empire NY(2) PA Regulatory Agency (Governed by) FERC FERC NYPSC PAPUC Timing / Status Expect to file a rate case on April 30, 2026, with new rates effective Nov. 2026 Last settlement approved by FERC June 11, 2024 New rates went into

effect February 1, 2024 No moratorium or comeback period Amendment to 2019 Settlement approved by FERC on March 17, 2025 New rates went into effect November 1, 2025 Moratorium period until April 30, 2027 Comeback required by May 31, 2031 Joint

Proposal approved(2) December 2024 with no significant modifications in the settlement 3-year rate plan effective October 1, 2024, with make-whole provision Filed rate case on January 28, 2026 requesting new rates effective Nov. 2026 with a $19M

increase in base rates Last settlement approved in June 2023 Rates in effect since August 1, 2023 Rate Base(1) (in millions) $1,350 $300 $1,100 $500 Equity Ratio Not stated – Black box settlement Not stated – Black box settlement

Authorized 48% Not stated – Black box settlement Authorized ROE Not Stated – Black box settlement Not Stated – Black box settlement Authorized 9.7% Not Stated – Black box settlement Pipeline & Storage Utility Estimated as

of March 31, 2026. See Case 23-G-0627 on file with the NY PSC. Recent updates in orange

Detailed Hedging Information for

Modeling Calculated as the weighted average NYMEX forward price for each time period shown based on the Fixed Price Physical firm sale execution date, plus basis differentials and transportation costs.  (All volumes in MMBtu; Prices in $ /

MMBtu) 3Q 26 4Q 26 Rem 26 FY 27 FY 28 FY 29 Hedged Volumes 85,214 85,490 170,704 271,067 131,335 34,638 Swaps Volume 36,810 36,810 73,620 122,050 57,730 4,350 Wtd. Avg. Price $4.04 $4.04 $4.04 $3.95 $3.82 $3.73 Collars Volume 25,200 25,200 50,400

58,300 17,680 -- Wtd. Avg. Ceiling $4.58 $4.58 $4.58 $4.62 $4.67 -- Wtd. Avg. Floor $3.54 $3.54 $3.54 $3.59 $3.64 -- Fixed Price Physical Volume 23,204 23,480 46,684 90,717 55,925 30,288 Wtd. Avg. Price $2.55 $2.55 $2.55 $2.65 $2.80 $2.83 NYMEX

Equiv. Price(1) $3.22 $3.38 $3.30 $3.64 $3.76 $3.71 Capped Firm Sales Volume 1,488 1,500 2,989 5,933 506 -- NYMEX Cap $4.95 $4.95 $4.95 $4.95 $4.95 --             Volume -- -- -- 7,323 7,943 7,892 NYMEX Cap -- -- --

$5.00 $5.00 $5.00 Volume 4,028 4,064 8,092 16,010 15,887 15,784 NYMEX Cap $5.65 $5.65 $5.65 $5.65 $5.65 $5.65 Volume 1,816 1,831 3,647 7,239 7,295 7,349 NYMEX Cap $7.00 $7.00 $7.00 $7.00 $7.00 $7.00

Comparable GAAP Financial Measure

Slides & Reconciliations This presentation contains certain non-GAAP financial measures. For pages that contain non-GAAP financial measures, pages containing the most directly comparable GAAP financial measures and reconciliations are provided

in the slides that follow. The Company believes that its non-GAAP financial measures are useful to investors because they provide an alternative method for assessing the Company’s ongoing operating results or liquidity and for comparing the

Company’s financial performance to other companies. The Company’s management uses these non-GAAP financial measures for the same purpose, and for planning and forecasting purposes. The presentation of non-GAAP financial measures is not

meant to be a substitute for financial measures prepared in accordance with GAAP. Management defines adjusted earnings and adjusted earnings per share as reported GAAP earnings before items impacting comparability. Management defines adjusted EBITDA

as reported GAAP earnings before the following items: interest expense, income taxes, depreciation, depletion and amortization, other income and deductions, impairments, and other items reflected in operating income that impact comparability. The

revised adjusted earnings per share guidance range also excludes certain items that impacted the comparability of adjusted operating results during the six months ended March 31, 2026, including after-tax unrealized losses on other investments,

which reduced earnings by $0.01 per share. While the Company expects to record certain adjustments to unrealized gain or loss on investments during the remaining six months ending September 30, 2026, the amounts of these and other potential

adjustments are not reasonably determinable at this time. As such, the Company is unable to provide earnings guidance other than on a non-GAAP basis. Management defines free cash flow as net cash provided by operating activities, less net cash used

in investing activities, adjusted for acquisitions and divestitures. The Company is unable to provide a reconciliation of projected free cash flow as described in this presentation to its respective comparable financial measure calculated in

accordance with GAAP without unreasonable efforts. This is due to our inability to reliably predict the comparable GAAP projected metrics, including operating income and total production costs, given the unknown effect, timing, and potential

significance of certain income statement items. Reconciliations of forward-looking non-GAAP financial measures and non-GAAP ratios to comparable GAAP measures are not available due to the challenges and impracticability of estimating certain items,

particularly depreciation and depletion expense, interest expense, income tax expense (benefit), other potential adjustments and charges, including ceiling test impairments, and non-cash unrealized derivative fair value gains and losses that are

subject to market variability. Because of those challenges, a reconciliation of forward-looking non-GAAP financial measures and non-GAAP ratios is not available without unreasonable effort.

Non-GAAP Reconciliations - Adjusted

Operating Results

Non-GAAP Reconciliations - Adjusted

EBITDA, by Segment

Non-GAAP Reconciliations - Adjusted

EBITDA & Net Debt

Non-GAAP Reconciliations - Funds From

Operations

Reconciliation – Capital

Expenditures

Safe Harbor For Forward Looking

Statements This presentation may contain “forward-looking statements” as defined by the Private Securities Litigation Reform Act of 1995, including statements regarding future prospects, plans, objectives, goals, projections, estimates

of gas quantities, strategies, future events or performance and underlying assumptions, capital structure, anticipated capital expenditures, completion of construction projects, projections for pension and other post-retirement benefit obligations,

impacts of the adoption of new accounting rules, and possible outcomes of litigation or regulatory proceedings, as well as statements that are identified by the use of the words “anticipates,” “estimates,”

“expects,” “forecasts,” “intends,” “plans,” “predicts,” “projects,” “believes,” “seeks,” “will,” “may,” and similar expressions.

Forward-looking statements involve risks and uncertainties which could cause actual results or outcomes to differ materially from those expressed in the forward-looking statements. The Company’s expectations, beliefs and projections are

expressed in good faith and are believed by the Company to have a reasonable basis, but there can be no assurance that management’s expectations, beliefs or projections will result or be achieved or accomplished. In addition to other factors,

the following are important factors that could cause actual results to differ materially from those discussed in the forward-looking statements: changes in laws, regulations or judicial interpretations to which the Company is subject, including

those involving derivatives, taxes, safety, employment, climate change, other environmental matters, real property, and exploration and production activities such as hydraulic fracturing; governmental/regulatory actions, initiatives and proceedings,

including those involving rate cases (which address, among other things, target rates of return, rate design, retained natural gas and system modernization), environmental/safety requirements, affiliate relationships, industry structure, and

franchise renewal; changes in economic conditions, including the imposition of additional tariffs on U.S. imports and related retaliatory tariffs, inflationary pressures, supply chain issues, liquidity challenges, and global, national or regional

recessions, and their effect on the demand for, and customers’ ability to pay for, the Company’s products and services; the Company’s ability to complete strategic transactions, such as the pending transaction with CenterPoint

Energy Resources Corp., including receipt of required regulatory clearances and satisfaction of other conditions to closing, and to recognize the anticipated benefits of such transactions; governmental/regulatory actions and/or market pressures to

reduce or eliminate reliance on natural gas; the Company’s ability to estimate accurately the time and resources necessary to meet emissions targets; changes in the price of natural gas; impairments under the SEC’s full cost ceiling test

for natural gas reserves; the creditworthiness or performance of the Company’s key suppliers, customers and counterparties; financial and economic conditions, including the availability of credit, and occurrences affecting the Company’s

ability to obtain financing on acceptable terms for working capital, capital expenditures, other investments, and acquisitions, including any downgrades in the Company’s credit ratings and changes in interest rates and other capital market

conditions; negotiations with the collective bargaining units representing the Company’s workforce, including potential work stoppages during negotiations; changes in price differentials between similar quantities of natural gas sold at

different geographic locations, and the effect of such changes on commodity production, revenues and demand for pipeline transportation capacity to or from such locations; the impact of information technology disruptions, cybersecurity or data

security breaches, including the impact of issues that may arise from the use of artificial intelligence technologies; factors affecting the Company’s ability to successfully identify, drill for and produce economically viable natural gas

reserves, including among others geology, lease availability and costs, title disputes, weather conditions, water availability and disposal or recycling opportunities of used water, shortages, delays or unavailability of equipment and services

required in drilling operations, insufficient gathering, processing and transportation capacity, the need to obtain governmental approvals and permits, and compliance with environmental laws and regulations; increased costs or delays or changes in

plans with respect to Company projects or related projects of other companies, as well as difficulties or delays in obtaining necessary governmental approvals, permits or orders or in obtaining the cooperation of interconnecting facility operators;

increasing health care costs and the resulting effect on health insurance premiums and on the obligation to provide other post-retirement benefits; other changes in price differentials between similar quantities of natural gas having different

quality, heating value, hydrocarbon mix or delivery date; the cost and effects of legal and administrative claims against the Company or activist shareholder campaigns to effect changes at the Company; uncertainty of natural gas reserve estimates;

significant differences between the Company’s projected and actual production levels for natural gas; changes in demographic patterns and weather conditions (including those related to climate change); changes in the availability, price or

accounting treatment of derivative financial instruments; changes in laws, actuarial assumptions, the interest rate environment and the return on plan/trust assets related to the Company’s pension and other post-retirement benefits, which can

affect future funding obligations and costs and plan liabilities; economic disruptions or uninsured losses resulting from major accidents, fires, severe weather, natural disasters, terrorist activities or acts of war, as well as economic and

operational disruptions due to third-party outages; significant differences between the Company’s projected and actual capital expenditures and operating expenses; or increasing costs of insurance, changes in coverage and the ability to obtain

insurance. Forward-looking statements include estimates of gas quantities. Proved gas reserves are those quantities of gas which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically

producible under existing economic conditions, operating methods and government regulations. Other estimates of gas quantities, including estimates of probable reserves, possible reserves, and resource potential, are by their nature more speculative

than estimates of proved reserves. Accordingly, estimates other than proved reserves are subject to substantially greater risk of being actually realized. Investors are urged to consider closely the disclosure in our Form 10-K available at

www.nationalfuel.com. You can also obtain this form on the SEC’s website at www.sec.gov. Forward-looking and other statements in this presentation regarding methane and greenhouse gas reduction plans and goals are not an indication that these

statements are necessarily material to investor or required to be disclosed in our filings with the SEC. In addition, historical, current and forward-looking statements regarding methane and greenhouse gas emissions may be based on standards for

measuring progress that are still developing, internal controls, and processes that continue to evolve and assumptions that are subject to change in the future. For a discussion of the risks set forth above and other factors that could cause actual

results to differ materially from results referred to in the forward-looking statements, see “Risk Factors” in the Company’s Form 10-K for the fiscal year ended September 30, 2025, and the Form 10-Q for the quarters ended December

31, 2025 and March 31, 2026. The Company disclaims any obligation to update any forward-looking statements to reflect events or circumstances after the date thereof or to reflect the occurrence of unanticipated events.

GRAPHIC

GRAPHIC

Filename: g113249ex99s10g1.jpg · Sequence: 6

Binary file (133214 bytes)

Download g113249ex99s10g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s11g1.jpg · Sequence: 7

Binary file (108153 bytes)

Download g113249ex99s11g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s12g1.jpg · Sequence: 8

Binary file (98160 bytes)

Download g113249ex99s12g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s13g1.jpg · Sequence: 9

Binary file (145165 bytes)

Download g113249ex99s13g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s14g1.jpg · Sequence: 10

Binary file (75737 bytes)

Download g113249ex99s14g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s15g1.jpg · Sequence: 11

Binary file (120608 bytes)

Download g113249ex99s15g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s16g1.jpg · Sequence: 12

Binary file (22597 bytes)

Download g113249ex99s16g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s17g1.jpg · Sequence: 13

Binary file (134182 bytes)

Download g113249ex99s17g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s18g1.jpg · Sequence: 14

Binary file (134143 bytes)

Download g113249ex99s18g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s19g1.jpg · Sequence: 15

Binary file (123250 bytes)

Download g113249ex99s19g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s1g1.jpg · Sequence: 16

Binary file (46504 bytes)

Download g113249ex99s1g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s20g1.jpg · Sequence: 17

Binary file (26784 bytes)

Download g113249ex99s20g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s21g1.jpg · Sequence: 18

Binary file (120475 bytes)

Download g113249ex99s21g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s22g1.jpg · Sequence: 19

Binary file (146973 bytes)

Download g113249ex99s22g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s23g1.jpg · Sequence: 20

Binary file (88704 bytes)

Download g113249ex99s23g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s24g1.jpg · Sequence: 21

Binary file (77621 bytes)

Download g113249ex99s24g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s25g1.jpg · Sequence: 22

Binary file (84646 bytes)

Download g113249ex99s25g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s26g1.jpg · Sequence: 23

Binary file (100666 bytes)

Download g113249ex99s26g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s27g1.jpg · Sequence: 24

Binary file (92689 bytes)

Download g113249ex99s27g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s28g1.jpg · Sequence: 25

Binary file (146667 bytes)

Download g113249ex99s28g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s29g1.jpg · Sequence: 26

Binary file (89366 bytes)

Download g113249ex99s29g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s2g1.jpg · Sequence: 27

Binary file (164548 bytes)

Download g113249ex99s2g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s30g1.jpg · Sequence: 28

Binary file (109021 bytes)

Download g113249ex99s30g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s31g1.jpg · Sequence: 29

Binary file (162539 bytes)

Download g113249ex99s31g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s32g1.jpg · Sequence: 30

Binary file (27325 bytes)

Download g113249ex99s32g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s33g1.jpg · Sequence: 31

Binary file (171124 bytes)

Download g113249ex99s33g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s34g1.jpg · Sequence: 32

Binary file (141239 bytes)

Download g113249ex99s34g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s35g1.jpg · Sequence: 33

Binary file (72983 bytes)

Download g113249ex99s35g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s36g1.jpg · Sequence: 34

Binary file (95991 bytes)

Download g113249ex99s36g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s37g1.jpg · Sequence: 35

Binary file (150979 bytes)

Download g113249ex99s37g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s38g1.jpg · Sequence: 36

Binary file (162591 bytes)

Download g113249ex99s38g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s39g1.jpg · Sequence: 37

Binary file (114013 bytes)

Download g113249ex99s39g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s3g1.jpg · Sequence: 38

Binary file (116151 bytes)

Download g113249ex99s3g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s40g1.jpg · Sequence: 39

Binary file (118215 bytes)

Download g113249ex99s40g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s41g1.jpg · Sequence: 40

Binary file (157243 bytes)

Download g113249ex99s41g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s42g1.jpg · Sequence: 41

Binary file (104708 bytes)

Download g113249ex99s42g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s43g1.jpg · Sequence: 42

Binary file (99746 bytes)

Download g113249ex99s43g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s44g1.jpg · Sequence: 43

Binary file (92716 bytes)

Download g113249ex99s44g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s45g1.jpg · Sequence: 44

Binary file (147449 bytes)

Download g113249ex99s45g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s46g1.jpg · Sequence: 45

Binary file (29448 bytes)

Download g113249ex99s46g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s47g1.jpg · Sequence: 46

Binary file (140390 bytes)

Download g113249ex99s47g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s48g1.jpg · Sequence: 47

Binary file (94164 bytes)

Download g113249ex99s48g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s49g1.jpg · Sequence: 48

Binary file (134346 bytes)

Download g113249ex99s49g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s4g1.jpg · Sequence: 49

Binary file (118724 bytes)

Download g113249ex99s4g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s50g1.jpg · Sequence: 50

Binary file (116908 bytes)

Download g113249ex99s50g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s51g1.jpg · Sequence: 51

Binary file (206961 bytes)

Download g113249ex99s51g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s52g1.jpg · Sequence: 52

Binary file (93479 bytes)

Download g113249ex99s52g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s53g1.jpg · Sequence: 53

Binary file (86152 bytes)

Download g113249ex99s53g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s54g1.jpg · Sequence: 54

Binary file (103193 bytes)

Download g113249ex99s54g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s55g1.jpg · Sequence: 55

Binary file (78611 bytes)

Download g113249ex99s55g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s56g1.jpg · Sequence: 56

Binary file (120130 bytes)

Download g113249ex99s56g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s57g1.jpg · Sequence: 57

Binary file (301758 bytes)

Download g113249ex99s57g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s5g1.jpg · Sequence: 58

Binary file (139709 bytes)

Download g113249ex99s5g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s6g1.jpg · Sequence: 59

Binary file (117463 bytes)

Download g113249ex99s6g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s7g1.jpg · Sequence: 60

Binary file (110107 bytes)

Download g113249ex99s7g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s8g1.jpg · Sequence: 61

Binary file (168840 bytes)

Download g113249ex99s8g1.jpg

GRAPHIC

GRAPHIC

Filename: g113249ex99s9g1.jpg · Sequence: 62

Binary file (140028 bytes)

Download g113249ex99s9g1.jpg

XML — IDEA: XBRL DOCUMENT

XML

Filename: R1.htm · Sequence: 64

v3.26.1

Document and Entity Information

Apr. 29, 2026

Cover [Abstract]

Entity Registrant Name

NATIONAL FUEL GAS CO

Amendment Flag

false

Entity Central Index Key

0000070145

Document Type

8-K

Document Period End Date

Apr. 29, 2026

Entity Incorporation State Country Code

NJ

Entity File Number

1-3880

Entity Tax Identification Number

13-1086010

Entity Address, Address Line One

6363 Main Street

Entity Address, City or Town

Williamsville

Entity Address, State or Province

NY

Entity Address, Postal Zip Code

14221

City Area Code

(716)

Local Phone Number

857-7000

Written Communications

false

Soliciting Material

false

Pre Commencement Tender Offer

false

Pre Commencement Issuer Tender Offer

false

Security 12b Title

Common Stock, par value $1.00 per share

Trading Symbol

NFG

Security Exchange Name

NYSE

Entity Emerging Growth Company

false

X

- Definition

Boolean flag that is true when the XBRL content amends previously-filed or accepted submission.

+ References

No definition available.

+ Details

Name:

dei_AmendmentFlag

Namespace Prefix:

dei_

Data Type:

xbrli:booleanItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Area code of city

+ References

No definition available.

+ Details

Name:

dei_CityAreaCode

Namespace Prefix:

dei_

Data Type:

xbrli:normalizedStringItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Cover page.

+ References

No definition available.

+ Details

Name:

dei_CoverAbstract

Namespace Prefix:

dei_

Data Type:

xbrli:stringItemType

Balance Type:

na

Period Type:

duration

X

- Definition

For the EDGAR submission types of Form 8-K: the date of the report, the date of the earliest event reported; for the EDGAR submission types of Form N-1A: the filing date; for all other submission types: the end of the reporting or transition period. The format of the date is YYYY-MM-DD.

+ References

No definition available.

+ Details

Name:

dei_DocumentPeriodEndDate

Namespace Prefix:

dei_

Data Type:

xbrli:dateItemType

Balance Type:

na

Period Type:

duration

X

- Definition

The type of document being provided (such as 10-K, 10-Q, 485BPOS, etc). The document type is limited to the same value as the supporting SEC submission type, or the word 'Other'.

+ References

No definition available.

+ Details

Name:

dei_DocumentType

Namespace Prefix:

dei_

Data Type:

dei:submissionTypeItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Address Line 1 such as Attn, Building Name, Street Name

+ References

No definition available.

+ Details

Name:

dei_EntityAddressAddressLine1

Namespace Prefix:

dei_

Data Type:

xbrli:normalizedStringItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Name of the City or Town

+ References

No definition available.

+ Details

Name:

dei_EntityAddressCityOrTown

Namespace Prefix:

dei_

Data Type:

xbrli:normalizedStringItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Code for the postal or zip code

+ References

No definition available.

+ Details

Name:

dei_EntityAddressPostalZipCode

Namespace Prefix:

dei_

Data Type:

xbrli:normalizedStringItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Name of the state or province.

+ References

No definition available.

+ Details

Name:

dei_EntityAddressStateOrProvince

Namespace Prefix:

dei_

Data Type:

dei:stateOrProvinceItemType

Balance Type:

na

Period Type:

duration

X

- Definition

A unique 10-digit SEC-issued value to identify entities that have filed disclosures with the SEC. It is commonly abbreviated as CIK.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b-2

+ Details

Name:

dei_EntityCentralIndexKey

Namespace Prefix:

dei_

Data Type:

dei:centralIndexKeyItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Indicate if registrant meets the emerging growth company criteria.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b-2

+ Details

Name:

dei_EntityEmergingGrowthCompany

Namespace Prefix:

dei_

Data Type:

xbrli:booleanItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Commission file number. The field allows up to 17 characters. The prefix may contain 1-3 digits, the sequence number may contain 1-8 digits, the optional suffix may contain 1-4 characters, and the fields are separated with a hyphen.

+ References

No definition available.

+ Details

Name:

dei_EntityFileNumber

Namespace Prefix:

dei_

Data Type:

dei:fileNumberItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Two-character EDGAR code representing the state or country of incorporation.

+ References

No definition available.

+ Details

Name:

dei_EntityIncorporationStateCountryCode

Namespace Prefix:

dei_

Data Type:

dei:edgarStateCountryItemType

Balance Type:

na

Period Type:

duration

X

- Definition

The exact name of the entity filing the report as specified in its charter, which is required by forms filed with the SEC.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b-2

+ Details

Name:

dei_EntityRegistrantName

Namespace Prefix:

dei_

Data Type:

xbrli:normalizedStringItemType

Balance Type:

na

Period Type:

duration

X

- Definition

The Tax Identification Number (TIN), also known as an Employer Identification Number (EIN), is a unique 9-digit value assigned by the IRS.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b-2

+ Details

Name:

dei_EntityTaxIdentificationNumber

Namespace Prefix:

dei_

Data Type:

dei:employerIdItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Local phone number for entity.

+ References

No definition available.

+ Details

Name:

dei_LocalPhoneNumber

Namespace Prefix:

dei_

Data Type:

xbrli:normalizedStringItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Boolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 13e

-Subsection 4c

+ Details

Name:

dei_PreCommencementIssuerTenderOffer

Namespace Prefix:

dei_

Data Type:

xbrli:booleanItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Boolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 14d

-Subsection 2b

+ Details

Name:

dei_PreCommencementTenderOffer

Namespace Prefix:

dei_

Data Type:

xbrli:booleanItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Title of a 12(b) registered security.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b

+ Details

Name:

dei_Security12bTitle

Namespace Prefix:

dei_

Data Type:

dei:securityTitleItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Name of the Exchange on which a security is registered.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection d1-1

+ Details

Name:

dei_SecurityExchangeName

Namespace Prefix:

dei_

Data Type:

dei:edgarExchangeCodeItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Boolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as soliciting material pursuant to Rule 14a-12 under the Exchange Act.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 14a

-Subsection 12

+ Details

Name:

dei_SolicitingMaterial

Namespace Prefix:

dei_

Data Type:

xbrli:booleanItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Trading symbol of an instrument as listed on an exchange.

+ References

No definition available.

+ Details

Name:

dei_TradingSymbol

Namespace Prefix:

dei_

Data Type:

dei:tradingSymbolItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Boolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as written communications pursuant to Rule 425 under the Securities Act.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Securities Act

-Number 230

-Section 425

+ Details

Name:

dei_WrittenCommunications

Namespace Prefix:

dei_

Data Type:

xbrli:booleanItemType

Balance Type:

na

Period Type:

duration