{"schemaVersion":1,"research":true,"symbol":"ato","name":"Atmos Energy","topic":"moat","path":"/stock/ato/moat","status":"published","version":3,"updatedAt":"2026-10-18T00:23:21.506Z","locked":false,"publicFairValue":false,"fairValue":null,"moat":{"verdict":"narrow","summary":"Atmos Energy has a narrow moat supported by established regulated infrastructure, historically renewed franchises and limited historical pipeline competition. Actual rate recoveries and increased contracted capacity demonstrate economic benefits beyond reported margins. Pricing power operates through regulatory approval rather than unrestricted price setting. Capital requirements, recovery delays, alternative energy and potential pipeline entry limit confidence in wider durability.","advantages":[{"mechanism":"efficient_scale","claim":"Established distribution, transmission and storage infrastructure supports an incumbent advantage. Historically renewed franchises and limited pipeline competition, combined with demonstrated regulatory recovery of investment costs, support a narrow moat. The passages do not establish exclusive territories or quantify the economics of duplicating the network.","durability":"Historical franchise renewals, recurring capital-recovery mechanisms and increased tariff-customer capacity support persistence. Continued franchise renewal and favorable regulation remain necessary; neither is guaranteed.","risks":"Industrial customers can substitute electricity or bypass the system; new pipelines could increase competition. Regulatory disallowances, recovery delays, safety obligations and dependence on external financing could weaken investment economics. These disclosed possibilities are not evidence of realized competitive deterioration.","invalidation":"The thesis would weaken materially if franchises were lost, competing pipelines or customer bypass caused sustained losses of contracted capacity, or repeated regulatory disallowances prevented recovery of prudently incurred investment. Sustained demand contraction alongside rising unrecovered infrastructure costs would also invalidate it.","competitors":[],"evidenceIds":["e1","e2","e3","e4","e5","e6","e7","e8"],"counterEvidenceIds":["e9","e10","e11","e12","e13"]}],"evidence":[{"id":"e1","sourceId":"filing-1","location":"Business / historical franchise renewals and management renewal expectations","excerpt":"Historically, we have successfully renewed these franchises and believe that we will continue to be able to renew our franchises as they expire."},{"id":"e2","sourceId":"filing-1","location":"Business / historical pipeline and storage competition","excerpt":"Our pipeline and storage operations historically have faced limited competition from other existing intrastate pipelines and gas marketers seeking to provide or arrange transportation, storage, and other services for customers."},{"id":"e3","sourceId":"filing-1","location":"Business / regulatory establishment of distribution revenues","excerpt":"Revenues in this operating segment are established by regulatory authorities in the states in which we operate."},{"id":"e4","sourceId":"filing-1","location":"Business / purchased gas cost recovery mechanism","excerpt":"Purchased gas cost adjustment mechanisms provide a method of recovering purchased gas costs on an ongoing basis without filing a rate case because they provide a dollar-for-dollar offset to increases or decreases in the cost of natural gas."},{"id":"e5","sourceId":"filing-1","location":"MD&A / fiscal 2025 distribution operating income rate-adjustment driver","excerpt":"Key drivers for the change in operating income include: •a $184.1 million increase in rate adjustments, primarily in our Mid-Tex Division."},{"id":"e6","sourceId":"filing-2","location":"MD&A / May 2026 approval of APT GRIP filing","excerpt":"On May 12, 2026, the RRC approved the Company's GRIP filing."},{"id":"e7","sourceId":"filing-2","location":"MD&A / realized pipeline operating income contribution from approved rate adjustments","excerpt":"Key drivers for the change in operating income include: •a $75.7 million increase primarily due to rate adjustments from the GRIP filings approved in June 2025 and May 2026."},{"id":"e8","sourceId":"filing-2","location":"MD&A / increased capacity contracted by tariff-based customers","excerpt":"•a $12.1 million increase due to higher capacity contracted by tariff-based customers due to their increased peak day demand."},{"id":"e9","sourceId":"filing-1","location":"Risk discussion / industrial energy substitution and system bypass","excerpt":"In the case of industrial customers, such as manufacturing plants, adverse economic conditions, including higher gas costs, could cause these customers to use alternative sources of energy, such as electricity, or bypass our systems in favor of special competitive contracts with lower per-unit costs."},{"id":"e10","sourceId":"filing-1","location":"Business / potential competition from new pipelines","excerpt":"The completion of new pipelines in our service area may increase the competition in this segment of our business."},{"id":"e11","sourceId":"filing-2","location":"MD&A / management recovery expectation and absence of assured full recovery","excerpt":"Although we believe these costs are ultimately recoverable through our rates based on the regulatory frameworks currently available to us, full recovery is not assured."},{"id":"e12","sourceId":"filing-2","location":"Forward-looking risk discussion / regulation, safety, alternative energy and capital access","excerpt":"These risks and uncertainties include the following: federal, state, and local regulatory and political trends and decisions, including the impact of rate proceedings before various state regulatory commissions; increased federal regulatory oversight and potential penalties; possible increased federal, state, and local regulation of the safety of our operations; possible significant costs and liabilities resulting from pipeline integrity and other similar programs and related repairs; the inherent hazards and risks involved in distributing, transporting, and storing natural gas; the availability and accessibility of contracted gas supplies, interstate pipeline, and/or storage services; increased competition from energy suppliers and alternative forms of energy; failure to attract and retain a qualified workforce; natural disasters, adverse weather, terrorist activities, or other events and other risks and uncertainties discussed herein, all of which are difficult to predict and many of which are beyond our control; failure of technology that affects the Company's business operations; the threat of cyber-attacks or acts of cyber-terrorism that could disrupt our business operations and information technology systems or result in the loss or exposure of confidential or sensitive customer, employee, or Company information; the impact of new cybersecurity compliance requirements; adverse weather conditions; the impact of legislation to reduce or eliminate greenhouse gas emissions or fossil fuels; the impact of climate change; the capital-intensive nature of our business; our ability to continue to access the credit and capital markets to execute our business strategy; market risks beyond our control affecting our risk management activities, including commodity price volatility, counterparty performance or creditworthiness, and interest rate risk; the concentration of our operations in Texas; the impact of adverse economic conditions on our customers; changes in the availability and price of natural gas; and increased costs of providing health care benefits, along with pension and postretirement health care benefits and increased funding requirements."},{"id":"e13","sourceId":"filing-2","location":"Condensed consolidated cash flows / nine-month spending, cash generation and financing","excerpt":"5 ATMOS ENERGY CORPORATION CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS Nine Months Ended June 30 2026 2025 (Unaudited) (In thousands) Cash Flows From Operating Activities Net income $ 1,227,552 $ 1,023,863 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation and amortization expense 591,853 549,069 Deferred income taxes 300,650 214,609 Other (50,435) (49,402) Net assets / liabilities from risk management activities 1,417 (1,966) Net change in other operating assets and liabilities (399,571) (34,841) Net cash provided by operating activities 1,671,466 1,701,332 Cash Flows From Investing Activities Capital expenditures (3,076,281) (2,597,787) Debt and equity securities activities, net (6,168) (2,348) Other, net 6,317 6,469 Net cash used in investing activities (3,076,132) (2,593,666) Cash Flows From Financing Activities Net proceeds from equity issuances 941,694 568,603 Issuance of common stock through stock purchase and employee retirement plans 4,783 11,532 Proceeds from issuance of long-term debt 1,296,231 1,143,447 Repayment of long-term debt (10,000) — Repayment of securitized long-term debt by AEK (4,394) (4,051) Cash dividends paid (490,698) (412,312) Debt issuance costs (10,944) (10,140) Net cash provided by financing activities 1,726,672 1,297,079 Net increase in cash and cash equivalents and restricted cash and cash equivalents 322,006 404,745 Cash and cash equivalents and restricted cash and cash equivalents at beginning of period 203,803 308,856 Cash and cash equivalents and restricted cash and cash equivalents at end of period $ 525,809 $ 713,601 See accompanying notes to condensed consolidated financial statements."},{"id":"e14","sourceId":"filing-1","location":"MD&A / fiscal 2025 residential customer growth and increased industrial load","excerpt":"•a $26.7 million increase related to residential customer growth, primarily in our Mid-Tex Division, and increased industrial load."},{"id":"e15","sourceId":"filing-2","location":"MD&A / nine-month pipeline revenues, transportation volumes and operating results","excerpt":"Nine Months Ended June 30 2026 2025 Change (In thousands, unless otherwise noted) Mid-Tex / Affiliate transportation revenue $ 680,779 $ 602,105 $ 78,674 Third-party transportation revenue 214,871 174,061 40,810 Other revenue 13,325 10,611 2,714 Total operating revenues 908,975 786,777 122,198 Total purchased gas cost 1,836 (638) 2,474 Operating expenses 331,384 342,161 (10,777) Operating income 575,755 445,254 130,501 Other non-operating income 31,205 38,361 (7,156) Interest charges 48,843 57,869 (9,026) Income before income taxes 558,117 425,746 132,371 Income tax expense 126,488 93,220 33,268 Net income $ 431,629 $ 332,526 $ 99,103 Gross pipeline transportation volumes — MMcf 681,829 678,457 3,372 Consolidated pipeline transportation volumes — MMcf 526,249 507,870 18,379 Operating income for our pipeline and storage segment increased 29.3 percent."},{"id":"e16","sourceId":"filing-2","location":"MD&A / quarterly distribution operating results and throughput","excerpt":"Three Months Ended June 30 2026 2025 Change (In thousands, unless otherwise noted) Operating revenues $ 774,658 $ 767,132 $ 7,526 Purchased gas cost 237,072 255,883 (18,811) Operating expenses 428,505 415,783 12,722 Operating income 109,081 95,466 13,615 Other non-operating income 8,732 7,017 1,715 Interest charges 12,870 22,271 (9,401) Income before income taxes 104,943 80,212 24,731 Income tax expense 15,558 9,731 5,827 Net income $ 89,385 $ 70,481 $ 18,904 Consolidated distribution sales volumes — MMcf 37,376 41,008 (3,632) Consolidated distribution transportation volumes — MMcf 35,767 34,346 1,421 Total consolidated distribution throughput — MMcf 73,143 75,354 (2,211) Consolidated distribution average cost of gas per Mcf sold $ 6.34 $ 6.24 $ 0.10 30 Operating income for our distribution segment increased 14.3 percent."},{"id":"e17","sourceId":"filing-2","location":"MD&A / rate-design recovery of the gas-cost portion of bad debt","excerpt":"This risk is currently mitigated by rate design that allows us to collect from our customers the gas cost portion of our bad debt expense on approximately 89 percent of our residential and commercial revenues."},{"id":"e18","sourceId":"filing-2","location":"MD&A / approved annual Louisiana affiliate demand-fee increases through September 2027","excerpt":"The demand fee our Louisiana natural gas transmission pipeline charges to our Louisiana distribution division increases five percent annually and has been approved by the Louisiana Public Service Commission until September 30, 2027."},{"id":"e19","sourceId":"filing-2","location":"MD&A / favorable pipeline pretax income impact from Texas infrastructure legislation","excerpt":"Additionally, our pipeline and storage segment's income before income taxes for the nine months ended June 30, 2026 was favorably impacted by $61.6 million as a result of Texas legislation that became effective during the third quarter of fiscal 2025 related to infrastructure spending."},{"id":"e20","sourceId":"filing-2","location":"MD&A / operating cash-flow decline attributed to timing of gas-cost recoveries","excerpt":"Operating cash flow decreased by $29.9 million primarily due to the timing of gas cost recoveries."},{"id":"e21","sourceId":"filing-2","location":"Liquidity and capital resources / debt and equity capitalization","excerpt":"The following table presents our capitalization inclusive of short-term debt and the current portion of long-term debt as of June 30, 2026, September 30, 2025 and June 30, 2025: June 30, 2026 September 30, 2025 June 30, 2025 (In thousands, except percentages) Short-term debt $ — — % $ — — % $ — — % Long-term debt (1) 10,251,258 40.2 % 8,918,944 39.7 % 8,919,726 40.0 % Shareholders’ equity 15,258,058 59.8 % 13,558,890 60.3 % 13,385,838 60.0 % Total $ 25,509,316 100.0 % $ 22,477,834 100.0 % $ 22,305,564 100.0 % (1) Inclusive of our finance leases, but exclusive of AEK's securitized long-term debt."},{"id":"e22","sourceId":"filing-2","location":"Liquidity and capital resources / actual debt-covenant compliance","excerpt":"Debt Covenants We were in compliance with all of our debt covenants as of June 30, 2026."},{"id":"e23","sourceId":"filing-3","location":"Compensation discussion / fiscal 2025 net income and diluted EPS outcomes","excerpt":"In fiscal 2025, we generated net income of $1,198.8 million or $7.46 per diluted share representing increases over net income for the year ended September 30, 2024 of $1,042.9 million or $6.83 per diluted share."},{"id":"e24","sourceId":"filing-2","location":"Condensed consolidated income statement / nine-month earnings and diluted EPS","excerpt":"4 ATMOS ENERGY CORPORATION CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME Nine Months Ended June 30 2026 2025 (Unaudited) (In thousands, except per share data) Operating revenues Distribution segment $ 3,911,164 $ 3,758,995 Pipeline and storage segment 908,975 786,777 Intersegment eliminations (636,093) (580,497) Total operating revenues 4,184,046 3,965,275 Purchased gas cost Distribution segment 1,605,020 1,647,490 Pipeline and storage segment 1,836 (638) Intersegment eliminations (635,326) (579,731) Total purchased gas cost 971,530 1,067,121 Operation and maintenance expense 648,762 662,440 Depreciation and amortization expense 591,853 549,069 Taxes, other than income 371,919 346,159 Operating income 1,599,982 1,340,486 Other non-operating income 55,760 68,906 Interest charges 115,288 144,476 Income before income taxes 1,540,454 1,264,916 Income tax expense 312,902 241,053 Net income $ 1,227,552 $ 1,023,863 Basic net income per share $ 7.40 $ 6.47 Diluted net income per share $ 7.33 $ 6.40 Cash dividends per share $ 3.00 $ 2.61 Basic weighted average shares outstanding 165,845 158,245 Diluted weighted average shares outstanding 167,352 159,798 Net income $ 1,227,552 $ 1,023,863 Other comprehensive income (loss), net of tax Net unrealized holding losses on available-for-sale securities, net of tax of $(69) and $(13) (242) (34) Cash flow hedges: Amortization and unrealized gains (losses) on interest rate agreements, net of tax of $(4,070) and $2,264 (14,366) 12,279 Total other comprehensive income (loss) (14,608) 12,245 Total comprehensive income $ 1,212,944 $ 1,036,108 See accompanying notes to condensed consolidated financial statements."},{"id":"e25","sourceId":"filing-3","location":"Compensation discussion / fiscal 2025 incentive structure, vesting and negative-TSR payout limits","excerpt":"Element Description Objective within Compensation Program Base Salary Fixed cash compensation, subject to annual review Adjusted in response to changes in performance, duties, strategic importance, or competitive salary practices •Reflects roles, responsibilities, skills, experience, and performance •Provides base compensation at a level consistent with competitive salary practices Annual Incentive Compensation Annual cash performance award based on achievement of Company financial performance measures Option to convert all or portion of award to time-based RSUs under our LTIP with three-year cliff vesting at a 20% premium Payout is limited to target if TSR is negative for the fiscal year •Increases alignment of senior management and shareholders’ interests by linking pay and performance •Promotes achievement of annual Company financial goals by linking pay to attainment of such goals Long-Term Incentive Compensation 75% in performance-based RSUs payable only if performance goals are achieved over the three-fiscal year performance period 25% in time-based RSUs also payable, with cliff vesting, at the end of the three-fiscal year period Payout for performance-based RSUs is limited to target if TSR is negative for the performance period •Motivates and rewards financial performance over a sustained period •Increases alignment of senior management and shareholders’ interests by encouraging share ownership of senior management •Enhances retention of senior management •Rewards strong TSR and earnings growth Retirement Benefits Tax-qualified retirement, supplemental retirement and other benefits •Provides for current and future needs of senior management •Enhances recruitment and retention •Follows competitive market practices Change in Control Severance Benefits Change in control severance agreements with contingent amounts payable only if employment is terminated under certain conditions following a change in control •Enhances retention of senior management by providing continuity of employment •Promotes objective evaluation and execution of potential changes to the Company’s strategy and structure 2026 Proxy Statement 37 Compensation Discussion & Analysis Fiscal 2025 Actual Results The table below shows the target performance, adjusted performance, and actual results for our fiscal 2025 performance-based compensation."},{"id":"e26","sourceId":"filing-3","location":"Director compensation / CEO and director ownership guidelines and eligible ownership sources","excerpt":"Minimum ownership levels are as follows: Position Minimum Ownership Level Chairman of the Board 5X annual retainer CEO 7X base salary Non-Employee Directors 5X annual retainer Ownership Sources Included •Direct or indirect ownership of Company stock •Unvested time-based RSUs •Share units held by non-employee directors under our Directors Plan (defined on page 30) and the LTIP 2026 Proxy Statement 31 Proposal 2 Ratification of Appointment of Independent Registered Public Accounting Firm The Audit Committee has appointed E&Y to continue as our independent registered public accounting firm for the fiscal year ending September 30, 2026."},{"id":"e27","sourceId":"filing-3","location":"Corporate governance / independent committee membership and chairmanship","excerpt":"Only independent directors serve on our Audit Committee, Human Resources Committee (“HR Committee”) and Governance Committee, and all standing Board committees are chaired by independent directors."},{"id":"e28","sourceId":"filing-3","location":"Corporate governance / independent director executive sessions","excerpt":"Executive Sessions Independent directors regularly hold executive sessions of the Board led by the Lead Director outside the presence of the Chairman, the President and CEO, or any other Company employee, and they generally meet in a private session with the Chairman and the President and CEO at regularly scheduled Board meetings."},{"id":"e29","sourceId":"filing-3","location":"Compensation process / executive exclusion from own compensation decisions","excerpt":"However, Mr. Akers (along with any other named executive officers in attendance at HR Committee meetings), are excused when the compensation of such named executive officers is discussed and decisions regarding their compensation are reached by the HR Committee."}],"changes":["No comparable previous version."],"limitations":["Assessment uses only supplied passages. Filing dates are November 14, 2025, August 5, 2026 and December 19, 2025, respectively; each retains dateKind filed.","Competition disclosures identify generic categories, not named direct competitors. Suppliers, compensation peers and directors' former employers do not establish competitive coverage.","Exclusive service rights, franchise durations, network duplication costs and comparative investment returns are not supplied. Efficient scale is an inference from infrastructure, franchise history and disclosed limited competition.","Historical competition and franchise-renewal statements are issuer disclosures; future renewal and cost-recovery expectations are management claims.","Customer dependency and retention are assessed indirectly from operating demand, customer growth and contracted capacity. No retention rate or customer-level switching study is supplied.","Governance and incentive terms are disclosed, but executive ownership balances, ownership-guideline compliance and a complete assessment of realized compensation outcomes are absent. Director nominees are not treated as subsequently elected directors.","The Louisiana demand-fee escalator concerns an affiliate transaction and does not independently demonstrate third-party willingness to pay. Interim 2026 results do not establish full-year outcomes or exceptional durability."],"qualityAssessments":[{"category":"moat","checks":[{"criterion":"structural_advantage","grade":3,"rationale":"Established regulated systems, historical franchise renewals and limited historical pipeline competition support a strong incumbent advantage. Approved investment recovery demonstrates its economic operation; territorial exclusivity and duplication economics are unverified.","evidenceIds":["e1","e2","e3","e6","e7"]},{"criterion":"durability","grade":2,"rationale":"Renewal history and recurring recovery mechanisms support persistence, but franchise terms are missing and full investment recovery is expressly uncertain. New pipeline entry remains a disclosed possibility rather than an observed loss.","evidenceIds":["e1","e6","e7","e10","e11"]},{"criterion":"customer_dependency","grade":3,"rationale":"Residential customer growth, increased industrial load and higher capacity contracted to meet tariff customers' peak demand support dependency indirectly. Industrial bypass and substitution prevent an inference of universal customer captivity.","evidenceIds":["e8","e14","e15","e9"]},{"criterion":"erosion_resilience","grade":2,"rationale":"Actual rate recoveries and gas-cost pass-through provide protection, but alternative energy, potential pipeline entry and a substantial externally financed investment program expose the advantage to erosion. These risks have not established realized moat failure.","evidenceIds":["e4","e7","e9","e10","e12","e13"]}]},{"category":"pricing_power","checks":[{"criterion":"realized_pricing","grade":3,"rationale":"Fiscal 2025 distribution rate adjustments contributed $184.1 million to operating income, and approved GRIP adjustments contributed $75.7 million in the 2026 nine-month pipeline comparison. These are realized regulatory pricing outcomes, not merely requested increases or unrestricted pricing power.","evidenceIds":["e5","e6","e7"]},{"criterion":"retention","grade":3,"rationale":"Customer growth, increased contracted capacity and continuing transportation volumes support repeat demand indirectly. No churn statistic is inferred; lower quarterly distribution throughput and industrial substitution possibilities qualify the assessment.","evidenceIds":["e14","e8","e15","e16","e9"]},{"criterion":"margin_resilience","grade":3,"rationale":"Dollar-for-dollar gas-cost recovery, bad-debt recovery provisions and actual operating income gains demonstrate protection against cost changes. Quarterly distribution operating income increased despite lower throughput. Recovery timing still affects cash flow, and legislative benefits contributed to pipeline results, limiting attribution solely to pricing.","evidenceIds":["e4","e17","e16","e7","e19","e20"]},{"criterion":"contractual_freedom","grade":1,"rationale":"Regulators establish distribution revenues and approve key capital-recovery adjustments. The approved Louisiana affiliate escalator provides bounded visibility through September 2027, but overall freedom to set prices is weak.","evidenceIds":["e3","e6","e18"]}]},{"category":"strong_management","checks":[{"criterion":"capital_discipline","grade":2,"rationale":"Nine-month operating cash flow of $1.67 billion funded only part of $3.08 billion of capital expenditures; $941.7 million of equity proceeds and $1.30 billion of debt proceeds show financing dependence and dilution. Roughly 60% equity capitalization, covenant compliance, realized rate recovery and rising per-share earnings provide counterbalancing evidence. Incremental investment returns are not established.","evidenceIds":["e13","e21","e22","e7","e24"]},{"criterion":"incentive_alignment","grade":3,"rationale":"The disclosed fiscal 2025 program allocated 75% of long-term incentives to performance-based RSUs over three fiscal years, with negative-TSR payout limits and ownership guidelines. These are existing program disclosures, not proposed awards. Actual executive ownership and guideline compliance are missing, and eligible ownership includes unvested time-based RSUs.","evidenceIds":["e25","e26"]},{"criterion":"execution","grade":3,"rationale":"Fiscal 2025 diluted EPS rose from $6.83 to $7.46; nine-month 2026 diluted EPS increased from $6.40 to $7.33 despite higher share counts. Approved rate recovery and increased contracted capacity demonstrate execution beyond management's stated strategy. Legislative benefits contributed, and these financial outcomes do not independently establish safety performance.","evidenceIds":["e23","e24","e6","e7","e8","e19"]},{"criterion":"governance","grade":3,"rationale":"Actual independent membership of key committees, independent committee chairs, regular executive sessions and executive recusal from their own compensation decisions support strong oversight practices. The passages do not establish exceptional governance effectiveness or subsequent election of the proposed director slate.","evidenceIds":["e27","e28","e29"]}]}],"qualityPolicy":"quality-scores-2","basisHash":"5f443c3555354f6c9414a779f7ed78cee7977ee4058af6a35f4f851e90de1957","updatedAt":"2026-10-18T00:23:21.506Z","sources":[{"id":"filing-1","url":"https://www.sec.gov/Archives/edgar/data/731802/000073180225000056/ato-20250930.htm","publishedAt":"2025-11-14","sha256":"169403d439692b0f8199473ac75ef2da18532d36f261eafb1a8379ea0849701e","dateKind":"filed"},{"id":"filing-2","url":"https://www.sec.gov/Archives/edgar/data/731802/000073180226000102/ato-20260630.htm","publishedAt":"2026-08-05","sha256":"c029ecc330689721d8f4f4dd11be77f78dae831739bcc219ce1856af84aa07ff","dateKind":"filed"},{"id":"filing-3","url":"https://www.sec.gov/Archives/edgar/data/731802/000073180225000076/ato-20251218.htm","publishedAt":"2025-12-19","sha256":"a7dc6f9faab2399114009d8ca9965a72239f1a2009ce37ec0ab80e5687e549cc","dateKind":"filed"}],"model":"gpt-6.1-sol","providerId":"codex:985312d7a669bff005a640fc759f5e20fb99f2586147ea7f757da8535918db1a","usage":{"input_tokens":52716,"cached_input_tokens":20992,"cache_write_input_tokens":0,"output_tokens":3593,"reasoning_output_tokens":229}},"signals":[{"period":"2021","end":"2021-09-30","values":{"gross_margin":69.69273570868879,"operating_margin":26.55908014403564,"roic":5.564672036533494,"fcf_margin":-89.61995486413754,"sbc_revenue":0.33030177638085517},"issues":{"pfcf":"Trailing free cash flow is zero or negative, so this ratio is undefined.","pfcf_growth":"Prior-year TTM FCF per diluted share is zero or negative; a growth-adjusted multiple is undefined.","pocf":"Trailing operating cash flow is zero or negative, so this ratio is undefined.","software_capex":"Separately disclosed software and intangible investment is unavailable in the extracted statements for this period.","sbc_fcf":"Free cash flow before SBC deduction is zero or negative, so this ratio is undefined.","sbc_ocf":"Operating cash flow is zero or negative, so this ratio is undefined.","roic_wacc":"Enter a WACC assumption from 0 to 100%.","debt_fcf":"Trailing free cash flow is zero or negative, so this ratio is undefined.","buybacks":"The reported inputs required for this metric are unavailable in the extracted statements for this period."}},{"period":"2022","end":"2022-09-30","values":{"gross_margin":59.952609229395414,"operating_margin":21.91946901012028,"roic":5.130542758752142,"fcf_margin":-34.910851943826046,"sbc_revenue":0.25568453626207915},"issues":{"pfcf":"Trailing free cash flow is zero or negative, so this ratio is undefined.","pfcf_growth":"Prior-year TTM FCF per diluted share is zero or negative; a growth-adjusted multiple is undefined.","software_capex":"Separately disclosed software and intangible investment is unavailable in the extracted statements for this period.","sbc_fcf":"Free cash flow before SBC deduction is zero or negative, so this ratio is undefined.","roic_wacc":"Enter a WACC assumption from 0 to 100%.","debt_fcf":"Trailing free cash flow is zero or negative, so this ratio is undefined.","buybacks":"The reported inputs required for this metric are unavailable in the extracted statements for this period."}},{"period":"2023","end":"2023-09-30","values":{"gross_margin":66.03387740485765,"operating_margin":24.960418510079975,"roic":5.378264348909905,"fcf_margin":15.291588515298255,"sbc_revenue":0.238061991080511},"issues":{"pfcf_growth":"Prior-year TTM FCF per diluted share is zero or negative; a growth-adjusted multiple is undefined.","software_capex":"Separately disclosed software and intangible investment is unavailable in the extracted statements for this period.","roic_wacc":"Enter a WACC assumption from 0 to 100%.","buybacks":"The reported inputs required for this metric are unavailable in the extracted statements for this period."}},{"period":"2024","end":"2024-09-30","values":{"gross_margin":null,"operating_margin":32.54024369133967,"roic":6.135048092908589,"fcf_margin":-28.89133188978069,"sbc_revenue":0.25710730394577724},"issues":{"pfcf":"Trailing free cash flow is zero or negative, so this ratio is undefined.","pfcf_growth":"TTM FCF per diluted share growth is zero or negative; a growth-adjusted multiple requires positive growth.","software_capex":"Separately disclosed software and intangible investment is unavailable in the extracted statements for this period.","sbc_fcf":"Free cash flow before SBC deduction is zero or negative, so this ratio is undefined.","gross_margin":"The reported inputs required for this metric are unavailable in the extracted statements for this period.","roic_wacc":"Enter a WACC assumption from 0 to 100%.","debt_fcf":"Trailing free cash flow is zero or negative, so this ratio is undefined.","buybacks":"The reported inputs required for this metric are unavailable in the extracted statements for this period."}},{"period":"2025","end":"2025-09-30","values":{"gross_margin":null,"operating_margin":33.17142823727794,"roic":6.0376299921572665,"fcf_margin":-32.150154537074535,"sbc_revenue":0.27071365614411125},"issues":{"pfcf":"Trailing free cash flow is zero or negative, so this ratio is undefined.","pfcf_growth":"Prior-year TTM FCF per diluted share is zero or negative; a growth-adjusted multiple is undefined.","software_capex":"Separately disclosed software and intangible investment is unavailable in the extracted statements for this period.","sbc_fcf":"Free cash flow before SBC deduction is zero or negative, so this ratio is undefined.","gross_margin":"The reported inputs required for this metric are unavailable in the extracted statements for this period.","roic_wacc":"Enter a WACC assumption from 0 to 100%.","debt_fcf":"Trailing free cash flow is zero or negative, so this ratio is undefined.","buybacks":"The reported inputs required for this metric are unavailable in the extracted statements for this period."}}],"sources":[{"id":"filing-1","url":"https://www.sec.gov/Archives/edgar/data/731802/000073180225000056/ato-20250930.htm","publishedAt":"2025-11-14","sha256":"169403d439692b0f8199473ac75ef2da18532d36f261eafb1a8379ea0849701e","dateKind":"filed"},{"id":"filing-2","url":"https://www.sec.gov/Archives/edgar/data/731802/000073180226000102/ato-20260630.htm","publishedAt":"2026-08-05","sha256":"c029ecc330689721d8f4f4dd11be77f78dae831739bcc219ce1856af84aa07ff","dateKind":"filed"},{"id":"filing-3","url":"https://www.sec.gov/Archives/edgar/data/731802/000073180225000076/ato-20251218.htm","publishedAt":"2025-12-19","sha256":"a7dc6f9faab2399114009d8ca9965a72239f1a2009ce37ec0ab80e5687e549cc","dateKind":"filed"}],"history":[{"version":3,"updatedAt":"2026-10-18T16:35:43.872Z","verdict":"narrow","value":null},{"version":2,"updatedAt":"2026-10-18T02:27:49.793Z","verdict":"narrow","value":null},{"version":1,"updatedAt":"2026-10-18T02:18:02.026Z","verdict":null,"value":null}],"hasRequested":false,"requestStatus":"completed","researchIssue":null,"archivedMoat":null,"scope":"supported_catalog"}