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美国证券交易委员会

华盛顿特区 20549

10-Q 表

（勾选一项）

☑ 根据《1934 年证券交易法》第 13 或 15(d) 条提交的季度报告

截至 2026 年 9 月 30 日的季度期间

或

☐ 根据《1934 年证券交易法》第 13 或 15(d) 条提交的过渡报告

过渡期间：自 ___________________ 至 ___________________

委员会

注册人；

美国国税局雇主

档案编号

地址和电话号码

注册成立州

识别号码

333-21011

FIRSTENERGY CORP.

俄亥俄州

34-1843785

341 White Pond Drive

阿克伦

44320

电话

(800)

736-3402

333-298694

FirstEnergy Pennsylvania Electric Company

宾夕法尼亚州

92-3343862

800 Cabin Hill Drive

格林斯堡

15601

电话

(800)

736-3402

1-3141

JERSEY CENTRAL POWER & LIGHT COMPANY

新泽西州

21-0485010

300 Madison Avenue

莫里斯敦

07962

电话

(800)

736-3402

根据该法第 12(b) 条注册的证券：

注册人

各类证券名称

交易代码

各证券上市交易所名称

FirstEnergy Corp.

普通股，面值 $0.10

纽约证券交易所

请勾选说明注册人 (1) 是否已在此前 12 个月内（或注册人须提交此类报告的较短期间内）提交《1934 年证券交易法》第 13 或 15(d) 条要求提交的所有报告；以及 (2) 在过去 90 天内是否一直须遵守此类提交要求。

FirstEnergy Corp.

是

☑

否

☐

FirstEnergy Pennsylvania Electric Company

是

☑

否

☐

Jersey Central Power & Light Company

是

☑

否

☐

请勾选说明注册人是否已在此前 12 个月内（或注册人须提交此类文件的较短期间内）以电子方式提交根据 S-T 条例第 405 条（本章 §232.405）要求提交的所有交互式数据文件。

FirstEnergy Corp.

是

☑

否

☐

FirstEnergy Pennsylvania Electric Company

是

☑

否

☐

Jersey Central Power & Light Company

是

☑

否

☐

请勾选说明注册人属于大型加速申报公司、加速申报公司、非加速申报公司、较小报告公司还是新兴成长型公司。参见《交易法》规则 12b-2 中“大型加速申报公司”“加速申报公司”“较小报告公司”和“新兴成长型公司”的定义。


大型加速申报公司	☑ FirstEnergy Corp.

加速申报公司	☐ 不适用

非加速申报公司	☑ FirstEnergy Pennsylvania Electric Company；Jersey Central Power & Light Company

较小报告公司	☐ 不适用

新兴成长型公司	☐ 不适用

如果属于新兴成长型公司，请勾选表明注册人是否选择不采用《交易法》第 13(a) 条规定的、遵守任何新订或修订财务会计准则的延长过渡期。☐

请勾选表明注册人是否为空壳公司（定义见《交易法》规则 12b-2）。

FirstEnergy Corp.

是

☐

否

☑

FirstEnergy Pennsylvania Electric Company

是

☐

否

☑

Jersey Central Power & Light Company

是

☐

否

☑

请注明截至最近可行日期，发行人各类普通股的流通股数：

流通股数

注册人

类别

截至 2026 年 9 月 30 日

FirstEnergy Corp.

普通股，面值 $0.10

578,893,330

FirstEnergy Pennsylvania Electric Company

普通股，无面值

1,000

Jersey Central Power & Light Company

普通股，面值 $10

13,628,447

本合并 Form 10-Q 分别由 FirstEnergy Corp.、FirstEnergy Pennsylvania Electric Company 和 Jersey Central Power & Light Company 提交。本文件中与任何单个注册人有关的信息由该注册人代表自身提交。除 FirstEnergy Corp. 外，各注册人不对与其他注册人有关的信息作任何陈述。

FirstEnergy Pennsylvania Electric Company 和 Jersey Central Power & Light Company 符合 Form 10-Q《一般说明》H(1)(a) 和 (b) 中规定的条件，因此根据 Form 10-Q《一般说明》H(2) 中规定的简化披露格式提交本 Form 10-Q。

FirstEnergy 网站及其他社交媒体网站和应用程序

各注册人的 Form 10-K 年度报告、Form 10-Q 季度报告、Form 8-K 当前报告、这些报告的修订文件，以及根据《交易法》第 13(a) 条向 SEC 提交或提供的所有其他文件，均可在 FirstEnergy 网站 investors.firstenergycorp.com 免费查阅。这些文件也可通过商业文件检索服务以及 SEC 维护的网站 www.sec.gov 向公众获取。

这些 SEC 文件会在以合理可行的最快速度向 SEC 以电子方式提交或提供后，发布在 FirstEnergy 网站上。此外，FirstEnergy 还会定期在其网站的“投资者”栏目发布其他重要信息，包括新闻稿、投资者演示文稿、投资者资料手册、“监管角”中的监管活动更新以及即将举行活动的通知，并将 FirstEnergy 网站视为触达公众投资者的分发渠道，也视为披露重大非公开信息（包括首次或独家披露）以履行 Regulation FD 披露义务的方式。投资者可在 FirstEnergy 网站的“投资者”页面注册电子邮件提醒和 RSS 订阅，以便收到网站发布内容的通知。FirstEnergy 还使用 X（原名 Twitter® 的社交网站）、LinkedIn®、YouTube® 和 Facebook® 作为触达公众投资者的其他分发渠道，并作为披露重大非公开信息的补充方式，以履行其 Regulation FD 披露义务。FirstEnergy 网站、X（原名 Twitter® 的社交网站）账号、LinkedIn® 个人资料、YouTube® 频道或 Facebook® 页面以及这些网站的任何相应应用程序所含信息，均不得视为以引用方式纳入本 Form 10-Q，或构成本 Form 10-Q 的一部分。


	页码

术语表	ii

前瞻性陈述	vi

第一部分：财务信息

第1项财务报表

FirstEnergy Corp.
合并收益表和综合收益表	1

合并资产负债表	2
合并权益表	4
合并现金流量表	6

FirstEnergy Pennsylvania Electric Company
合并收益表和综合收益表	7
合并资产负债表	8
合并权益表	9
合并现金流量表	10

Jersey Central Power & Light Company
收益表和综合收益表	10
资产负债表	12
权益表	13
现金流量表	14

注册人合并财务报表附注编制基础	15

第2项管理层对财务状况和经营业绩的讨论与分析	55
FirstEnergy Corp. 管理层对财务状况和经营业绩的讨论与分析	55

FirstEnergy Pennsylvania Electric Company 管理层对经营业绩的叙述性讨论与分析	99

Jersey Central Power & Light Company 管理层对经营业绩的叙述性讨论与分析	103

第3项关于市场风险的定量和定性披露	107

第4项控制和程序	107

第二部分：其他信息

第1项法律诉讼	107

第1A项风险因素	107

第2项：未注册股权证券的销售及所得款项用途	107

第3项高级证券违约	107

第4项矿山安全披露	107

第5项其他信息	107

第6项附件	108

术语表

本报告使用以下缩写和首字母缩略词来指称 FirstEnergy Corp. 及其现任和前任子公司，包括 FE PA 和 JCP&L：


AE Supply	Allegheny Energy Supply Company, LLC，FE 旗下全资非受监管发电子公司
AGC	Allegheny Generating Company，MP 旗下全资发电子公司
ATSI	American Transmission Systems, Incorporated，FET 旗下全资输电子公司
CEI	The Cleveland Electric Illuminating Company，FE 旗下全资俄亥俄州电力公司子公司
电力公司	OE、CEI、TE、FE PA、JCP&L、MP 和 PE
FE	FirstEnergy Corp.，一家上市电力控股公司
FE PA	FirstEnergy Pennsylvania Electric Company，FirstEnergy Pennsylvania Holding Company LLC 旗下全资宾夕法尼亚州电力公司子公司；FirstEnergy Pennsylvania Holding Company LLC 是 FE 旗下全资子公司
FESC	FirstEnergy Service Company，FE 旗下全资子公司，为 FirstEnergy 关联公司提供法律、财务及其他企业支持服务
FET	FirstEnergy Transmission, LLC，FE 的合并 VIE，也是 ATSI、MAIT 和 TrAIL 的母公司；其在 Valley Link 和 Grid Growth 拥有合资企业，并曾在 PATH 拥有合资企业
FEV	FirstEnergy Ventures Corp.，投资于某些非受监管企业和商业项目
FirstEnergy	FirstEnergy Corp.及其合并子公司
Grid Growth	Grid Growth Ventures, LLC，由 FET 和 Transource 于 September 29, 2025 设立的控股公司
Grid Growth EHV	Grid Growth EHV Holdings, LLC，Grid Growth 的子公司
Grid Growth Ohio	Grid Growth Ohio, LLC
JCP&L	Jersey Central Power & Light Company，FE 旗下全资新泽西州电力公司子公司
KATCo	Keystone Appalachian Transmission Company，FE 旗下全资输电子公司
MAIT	Mid-Atlantic Interstate Transmission, LLC，FET 旗下全资输电子公司
ME	Metropolitan Edison Company，FE 旗下前全资宾夕法尼亚州电力公司子公司，于 January 1, 2024 并入 FE PA
MP	Monongahela Power Company，FE 旗下全资西弗吉尼亚州电力公司子公司
OE	Ohio Edison Company，FE 旗下全资俄亥俄州电力公司子公司
俄亥俄州公司	CEI、OE 和 TE
PATH	Potomac-Appalachian Transmission Highline, LLC，FE 与 AEP 子公司曾成立的合资企业
PATH-WV	PATH West Virginia Transmission Company, LLC
PE	The Potomac Edison Company，FE 全资拥有的马里兰州和西弗吉尼亚州电力公司子公司
Penn	Pennsylvania Power Company，OE 曾全资拥有的宾夕法尼亚州电力公司子公司，于 2024 年 1 月 1 日并入 FE PA
Pennsylvania Companies	ME、PN、Penn 和 WP，均于 2024 年 1 月 1 日并入 FE PA
PN	Pennsylvania Electric Company，FE 曾全资拥有的宾夕法尼亚州电力公司子公司，于 2024 年 1 月 1 日并入 FE PA
Registrants	FE、FE PA 和 JCP&L
TE	The Toledo Edison Company，FE 全资拥有的俄亥俄州电力公司子公司
TrAIL	Trans-Allegheny Interstate Line Company，FET 全资拥有的输电子公司
Transmission Companies	ATSI、MAIT、TrAIL 和 KATCo
Valley Link	Valley Link Transmission Company, LLC，由 FET、DominionHV 和 Transource 于 2024 年 11 月 25 日成立的控股公司
Valley Link Maryland	Valley Link Transmission Maryland, LLC
Valley Link Subsidiaries	Valley Link 的五家子公司：(i) Valley Link Transmission Maryland, LLC；(ii) Valley Link Transmission Ohio, LLC；(iii) Valley Link Transmission Virginia, LLC；(iv) Valley Link Transmission Virginia Development, Inc.；以及 (v) Valley Link Transmission West Virginia, LLC，将开发、建设、拥有、运营和维护由 PJM 授予的输电项目
WP	West Penn Power Company，FE 曾全资拥有的宾夕法尼亚州电力公司子公司，于 2024 年 1 月 1 日并入 FE PA


本报告可能使用以下缩写和首字母词来指代常用术语：

2026 Convertible Notes	FE 的 4.00% 可转换优先票据，2026 年到期
2029 Convertible Notes	FE 的 3.625% 可转换优先票据，2029 年到期
2031 Convertible Notes	FE 的 3.875% 可转换优先票据，2031 年到期
AEP	American Electric Power Company, Inc.
AFS	可供出售
AFUDC	建设期间使用资金的补贴
AI	人工智能
Amended Credit Facilities	FE、FET、电力公司和输电公司签订的八项单独高级无担保银团循环信贷安排的统称，各项安排均经不时修订，最近一次修订日期为 2026 年 10 月 23 日
AMI	高级计量基础设施
AMT	替代性最低税
AOCI	累计其他综合收益（亏损）
ARO	资产弃置义务
ARP	替代收入计划
A&R FET LLC Agreement	FET 经第五次修订及重述的有限责任公司运营协议
A&R FET第四份有限责任公司协议	FET第四次修订并重述的有限责任公司运营协议
ASU	会计准则更新
BGS	基本发电服务
Brookfield	Brookfield Super-Core Infrastructure Partners旗下受控投资工具实体North American Transmission Company II L.P.
CAA	《清洁空气法》
CCR	煤燃烧残渣
CERCLA	1980年《综合环境响应、赔偿与责任法》
CFR	《联邦法规汇编》
CO2	二氧化碳
CODM	首席运营决策者
CPCN	公共便利与必要性证书
CSAPR	跨州空气污染规则
D.C.巡回上诉法院	美国哥伦比亚特区巡回上诉法院
DCR	输电资本回收
DOE	美国能源部
DominionHV	Dominion High Voltage Mid-Atlantic, Inc.，VEPCO的关联公司
DPA	FE与美国检察官办公室俄亥俄南区分处于2021年7月21日签订的暂缓起诉协议
DSP	默认服务计划
EDC	电力配电公司
EE&C计划	能源效率与节约计划
EEI	爱迪生电气协会
EGS	电力发电供应商
EGU	发电机组
ELG	废水排放限制指南
EmPOWER Maryland	EmPOWER Maryland能源效率法
ENEC	扩展净能源成本
Energize365	FirstEnergy的输电和配电基础设施投资计划
EnergizeNJ	JCP&L的第二项基础设施投资计划
EPA	美国环境保护署
EPS	每股收益
ERO	电力可靠性组织

iii


ESP	电力安全计划
《交易法》	经修订的1934年《证券交易法》
FASB	财务会计准则委员会
FE董事会	FE董事会
FE定期贷款融资	FE作为借款人于2026年4月28日签订的7.5亿美元无担保信贷协议，协议另一方为作为贷款人的银行及其他金融机构，以及作为行政代理人的JPMorgan Chase Bank, N.A.
FERC	联邦能源监管委员会
FET股权权益出售	出售FET额外30%的会员权益，使Brookfield持有FET 49.9%的权益
FIP	联邦实施计划
Fitch	Fitch评级服务
FMB	第一抵押债券
FPA	《联邦电力法》
FTR	金融输电权
GAAP	美国公认会计原则
GHG	温室气体
Grid Growth运营协议	Grid Growth 经修订并重述的运营协议，日期为 2026年2月13日
吉瓦	吉瓦
HB 15	俄亥俄州第136届议会通过的第15号众议院法案
HB 6	俄亥俄州第133届议会通过的第6号众议院法案
2022年《通胀削减法案》	2022年《通胀削减法案》
IRS	美国国税局
ISO	独立系统运营商
kV	千伏
LOC	信用证
LTIIP	长期基础设施改进计划
MDOPC	马里兰州人民法律顾问办公室
MDPSC	马里兰州公共服务委员会
MGP	人造煤气厂
MISO	中大陆独立系统运营商
Moody’s	Moody’s Investors Service, Inc.
MW	兆瓦
MWh	兆瓦时
N/A	不适用
NAAQS	国家环境空气质量标准
NCI	非控股权益
NERC	北美电力可靠性公司
NJBPU	新泽西州公用事业委员会
NOAC	俄亥俄州西北部聚合联盟
NOL	净经营亏损
NOx	氮氧化物
NYPSC	纽约州公共服务委员会
OAG	俄亥俄州检察长
OBBBA	《2025年大而美法案》，于2025年7月4日通过
OCC	俄亥俄州消费者顾问
ODSA	俄亥俄州发展服务局
俄亥俄州和解协议	由俄亥俄州各公司、OCC、PUCO工作人员及其他若干签署方于2021年11月1日签订的《和解与建议书》
OPEB	其他离职后福利
OPIC	其他实收资本


OVEC	俄亥俄河谷电力公司
宾夕法尼亚州合并	宾夕法尼亚州各公司于2024年1月1日合并
PE 定期贷款融资	由 PE 作为借款人、相关银行及其他金融机构作为贷款人、PNC Bank, National Association 作为行政代理人于2026年6月16日签订的1.5亿美元无担保信贷协议
PJM	PJM Interconnection, LLC，一家服务于 PJM 区域的区域输电组织
PJM 区域	PJM 协调电力输送的区域，包括特拉华州、伊利诺伊州、印第安纳州、肯塔基州、马里兰州、密歇根州、新泽西州、北卡罗来纳州、俄亥俄州、宾夕法尼亚州、田纳西州、弗吉尼亚州、西弗吉尼亚州及哥伦比亚特区的全部或部分地区
PJM 电价表	PJM 开放接入输电电价表
PPUC	宾夕法尼亚州公用事业委员会
PUCO	俄亥俄州公用事业委员会
Regulation FD	SEC颁布的《公平披露条例》
RFC	ReliabilityFirst Corporation
RFR	无风险利率
RGGI	区域温室气体倡议
ROE	股本回报率
RSS	富网站摘要
RTEP	区域输电扩建计划
RTEP 开放窗口	PJM 在 RTEP 框架下开展的竞争性输电规划与招标流程，符合资格的输电开发商可提交方案以满足已确定的输电系统需求，并竞争项目授予
RTO	区域输电组织
S&P	标准普尔评级服务
俄亥俄州南区	美国俄亥俄州南区联邦地区法院
SEC	美国证券交易委员会
《证券法》	经修订的 1933 年《证券法》
SEET	显著超额收益测试
SIP	《清洁空气法》下的州实施计划
第六巡回法院	美国第六巡回上诉法院
SO2	二氧化硫
SOFR	担保隔夜融资利率
SOS	标准供电服务
SPE	特殊目的实体
TCJA	2017 年 12 月 22 日通过的《减税与就业法案》
Transource	Transource Energy, LLC，AEP 的子公司
U.S.	美国
《公用事业 RELIEF 法案》	Maryland House Bill 1532，2026 年 5 月 12 日通过
Valley Link 运营协议	Valley Link 于 2025 年 2 月 21 日签订的修订并重述运营协议
VEPCO	Virginia Electric and Power Company，Dominion Energy, Inc. 的子公司
VIE	可变利益实体
VSCC	弗吉尼亚州公司委员会
WVPSC	西弗吉尼亚州公共服务委员会
ZEC	零排放证书

前瞻性陈述：本 10-Q 表格包含基于注册人管理层当前可获得信息的前瞻性陈述。除非上下文另有要求，“我们”及“我们的”均指所有注册人。此类陈述存在一定风险和不确定性，提醒读者不要过度依赖这些前瞻性陈述。这些陈述包括对管理层意图、信念和当前预期的说明。此类陈述通常包含但不限于“预期”“潜在”“预计”“预测”“目标”“将”“打算”“相信”“预计”“估计”“计划”等词语及类似表述。前瞻性陈述涉及估计、假设、已知和未知风险、不确定性及其他因素，这些因素可能导致实际结果、业绩或成就与前瞻性陈述明示或暗示的未来结果、业绩或成就存在重大差异，相关因素可能包括以下内容（大写术语的定义见术语表）：

•政府调查和协议可能导致的责任、成本增加及意外进展，包括与遵守或未能遵守 DPA 相关的事项，以及与总检察长办公室和 SEC 达成的和解；

•与诉讼相关的风险和不确定性，包括证券集体诉讼、监管程序、仲裁、调解及类似程序；

•影响我们和/或客户以及与我们开展业务的供应商的国家和地区经济状况变化，包括地缘政治冲突、经济衰退、利率波动、通胀压力、供应链中断、燃料成本上涨及劳动力影响；

•天气变化，例如温和的季节性天气变化和恶劣天气状况（包括由气候变化引发或加剧的事件，如野火、飓风、洪水、干旱、大风事件和极端高温事件）及其他自然灾害，这些可能导致风暴修复费用增加或产生重大责任，并对未来经营业绩造成负面影响；

•因应对恶劣天气状况和其他自然灾害的监管行动或结果而产生的潜在责任和成本增加；

•立法和监管动态以及行政命令，包括但不限于与费率、发电资源充足性、发电设施与大型负荷的共址，以及合规和执法活动相关的事项；

•能否按照我们的财务计划进入公开证券及其他资本和信贷市场、此类资本的成本以及资本和信贷市场的整体状况，包括 FE 丧失知名成熟发行人资格；

•与物理攻击相关的风险，例如战争、恐怖主义、破坏或其他暴力行为，以及针对我们或供应商信息技术系统的网络攻击和其他中断（可能危及我们的运营），还有敏感数据、知识产权、专有信息或个人身份信息的数据安全泄露；

•能否通过建立持续改进文化及实现其他战略和财务目标来取得或实现预期收益，包括但不限于执行 Energize365 输配电投资计划、执行费率申报战略、控制成本、改善信用指标、维持投资级评级、强化资产负债表和实现盈利增长；

•影响某些负债计量以及 FirstEnergy 养老金信托所持资产价值的市场状况变化，可能对我们的预测增长率和经营业绩产生负面影响，也可能导致其比目前预期更早或以更大金额向养老金计划缴款；

•关于诸如我们服务区域内经济状况、输配电系统可靠性、西弗吉尼亚州发电资源规划，或支持已确定输配电投资机会的资本或其他资源可用性等因素的假设发生变化；

•人力资本管理方面的挑战，包括吸引和留住受过适当培训且具备资质的员工，以及工会化员工队伍造成的劳资中断；

•环境法律法规的变化，包括但不限于与气候变化、CCR 相关的联邦和州规则，以及此类法律法规可能发生的变化；

•客户电力需求的变化，包括但不限于经济状况、数据中心的发展、气候变化的影响以及新兴技术，尤其是电气化、储能、发电设施与大型负荷的共址，以及分布式发电源方面；

•信用评级机构未来采取的行动可能对我们的融资渠道或融资条款，或我们的财务状况和流动性产生不利影响；

•我们的信贷安排可能存在不遵守债务契约的情况；

•遵守适用的可靠性标准以及能效和峰值需求削减要求的能力；

•重要会计政策的变化；

•税法或法规的任何变化，包括但不限于《2022年通胀削减法案》(IRA)、OBBBA，或不利的税务审计结果或裁定，以及此类法律法规可能发生的变化；

•实现我们公开披露的气候相关目标、机遇、改进和效率目标的能力，包括 FirstEnergy 的温室气体减排目标；以及

•我们不时在向 SEC 提交的文件中讨论的风险及其他因素。

FE 董事会在实际宣布分红时考虑的具体情况，可能导致任何期间不时宣布的 FE 普通股股息总额与以往期间有所不同。证券评级并非买入或持有证券的建议，授予评级的评级机构可随时修订或撤销评级。每项评级都应独立于其他评级进行评估。

本季度报告（Form 10-Q）中关于 FirstEnergy 气候战略（包括 FirstEnergy 温室气体排放减排目标）的前瞻性及其他陈述，并不意味着这些陈述必然对投资者具有重要性，或必须在 FirstEnergy 向 SEC 提交的文件中披露。此外，关于气候事项（包括温室气体排放）的历史、当前及前瞻性陈述，可能依据仍在制定中的进展衡量标准、仍在演变的内部控制和流程，以及未来可能发生变化的假设。

这些前瞻性陈述还受以下风险因素的限定，并应与其一并阅读：(a) FirstEnergy 和 JCP&L 截至 2025 年 12 月 31 日止年度的 Form 10-K 年度报告第 1A 项“风险因素”，该报告于 2026 年 2 月 18 日向 SEC 提交；(b) 本文第 2 项“管理层对财务状况和经营业绩的讨论与分析”；以及 (c) 本文及我们向 SEC 提交的其他文件中讨论的其他因素。上述因素审阅也不应被视为详尽无遗。新的因素会不时出现，管理层无法预测所有此类因素，也无法评估任何此类因素对我们业务的影响，或任何因素或因素组合可能在多大程度上导致实际结果与任何前瞻性陈述所述结果存在重大差异。对于因新信息、未来事件或其他原因而更新或修订本文所载或通过引用纳入的信息中的任何前瞻性陈述，我们明确不承担任何义务，法律要求的情况除外。

vii

第一部分：财务信息

第 1 项。财务报表

FIRSTENERGY CORP.

合并损益及综合收益表

（未经审计）


	截至 9 月 30 日的三个月		截至 9 月 30 日的九个月
（单位：百万美元，每股金额除外）	2026		2025		2026		2025

收入：
配电服务及零售发电	$	3,665			$	3,373		$	9,696	$	9,152
输电	624			592			1,938		1,740
其他	268			183			803		401
收入总额(1)	4,557			4,148			12,437		11,293

运营费用：
燃料	189			163			506		480
外购电力	1,471			1,341			4,057		3,382
其他运营费用	1,323			976			3,948		3,005
折旧费用	427			417			1,272		1,243
监管资产摊销（递延），净额	(103)			89			(785)		(20)
一般税费	315			332			999		973
运营费用总额	3,622			3,318			9,997		9,063

营业收入	935			830			2,440		2,230

其他收入（费用）：
债务赎回成本（附注 6。）	—			—			—		(24)

杂项收入，净额	39			41			139		118

利息费用	(345)			(312)			(1,008)		(899)
资本化融资成本	55			51			161		131
其他费用总额	(251)			(220)			(708)		(674)

所得税前收入	684			610			1,732		1,556

所得税	69			78			299		292





净收入	$	615			$	532		$	1,433	$	1,264

归属于非控股权益的收入	58			91			183		195

归属于 FIRSTENERGY CORP. 的收益	$	557			$	441		$	1,250	$	1,069

综合收益	$	615			$	532		$	1,433	$	1,264

归属于非控股权益的综合收益	58			91			183		195

归属于 FIRSTENERGY CORP. 的综合收益	$	557			$	441		$	1,250	$	1,069









归属于 FIRSTENERGY CORP. 的每股收益（附注 3.）：


基本	$	0.96			$	0.76		$	2.16	$	1.85



摊薄	$	0.96			$	0.76		$	2.16	$	1.85

加权平均已发行普通股数：
基本	579			577			578		577
摊薄	580			578			580		578

(1) 包括截至 2026 年和 2025 年 9 月 30 日止三个月分别征收的 1.32 亿美元和 1.26 亿美元消费税及总收入税，以及截至 2026 年和 2025 年 9 月 30 日止九个月分别征收的 3.70 亿美元和 3.49 亿美元。

参见注册人财务报表合并附注。

FIRSTENERGY CORP.

合并资产负债表

（未经审计）


（单位：百万美元，股份金额除外）	9 月 30 日 2026		12 月 31 日 2025
资产
流动资产：
现金及现金等价物	$	48			$	57
受限现金	84			42
应收款项 -
客户	1,854			1,783
减 — 客户应收款项坏账准备	49			57
	1,805			1,726

其他，扣除坏账准备后的净额；2026 年和 2025 年坏账准备分别为 $7 和 $11	338			295

材料和用品，按平均成本计价	605			577



预付税款及其他	397			282

	3,277			2,979
不动产、厂房和设备：
在用	59,064			56,213
减 — 累计折旧准备	15,647			15,189
	43,417			41,024
在建工程	4,306			3,389
	47,723			44,413



投资和其他非流动资产：
商誉	5,618			5,618
投资	619			641
监管资产	1,593			829
其他	998			1,424

	8,828			8,512
资产总额(1)	$	59,828			$	55,904

负债和权益
流动负债：
一年内到期的长期债务	$	2,156			$	723
短期借款	1,970			325
应付账款	2,473			2,002

应计利息	306			373
应计税款	751			768
应计薪酬和福利	249			286

应付股利	269			257
客户押金	259			250
其他	297			287

	8,730			5,271
非流动负债：
长期债务及其他长期义务	25,926			25,508
累计递延所得税	6,440			6,032
退休福利	1,458			1,469
监管负债	923			1,185



其他	1,852			2,513

	36,599			36,707
负债总额(1)	45,329			41,978

权益：
普通股股东权益-
普通股，面值 $0.10，授权发行 700,000,000 股；截至 2026 年 9 月 30 日和 2025 年 12 月 31 日，流通股分别为 578,893,330 股和 577,851,052 股。	58			58

其他实收资本	12,454			12,431
累计其他综合亏损	(14)			(14)
留存收益	477			35
普通股股东权益合计	12,975			12,510
非控股权益	1,524			1,416

权益总额	14,499			13,926

承诺、担保和或有事项（附注 10）

负债和权益总额	$	59,828			$	55,904

(1) 截至 2026 年 9 月 30 日和 2025 年 12 月 31 日，VIE 的合并资产分别为 $14,114 million 和 $13,270 million，且仅可用于清偿 VIE 的义务。截至 2026 年 9 月 30 日和 2025 年 12 月 31 日，这些资产分别包括：受限现金 $25 million 和 $40 million，应收账款 $79 million 和 $92 million，材料和用品（按平均成本计价）$1 million 和 $1 million，预付税款及其他流动资产 $36 million 和 $41 million，不动产、厂房和设备 $13,501 million

以及商誉，分别为 12,475 百万美元和 12,475 百万美元；投资，分别为 1 百万美元和 19 百万美元；监管资产，分别为 136 百万美元和 22 百万美元；其他非流动资产，分别为 111 百万美元和 348 百万美元。此外，截至 2025 年 12 月 31 日的资产包括 8 百万美元现金及现金等价物。截至 2026 年 9 月 30 日和 2025 年 12 月 31 日的合并负债分别包括 10,293 百万美元和 9,933 百万美元的 VIE 负债，其债权人对 FE 不享有追索权。截至 2026 年 9 月 30 日和 2025 年 12 月 31 日，这些负债分别包括：即将到期的长期债务 53 百万美元和 126 百万美元、短期借款 370 百万美元和 245 百万美元、应计利息 91 百万美元和 108 百万美元、应计税款 333 百万美元和 335 百万美元、其他流动负债 6 百万美元和 9 百万美元、长期债务及其他长期债务义务 7,266 百万美元和 6,893 百万美元、累计递延所得税 1,664 百万美元和 1,540 百万美元、监管负债 494 百万美元和 346 百万美元，以及其他非流动负债 16 百万美元和 331 百万美元。

请参阅注册人合并财务报表附注。

FIRSTENERGY CORP.

合并权益表

（未经审计）


	截至 2026 年 9 月 30 日的九个月
	普通股	其他实收资本		累计其他综合收益（亏损）	留存收益		普通股股东权益总额		非控股权益		权益总额
（百万美元）	股数	金额
2026 年 1 月 1 日余额	578		$	58		$	12,431			$	(14)	$	35		$	12,510		$	1,416	$	13,926
净利润	—		—		—			—			405	405		61			466

股票投资计划和股份薪酬福利计划	—		—		8			—			—	8		—			8
已宣派普通股现金股息（3 月每股 0.465 美元）	—		—		—			—			(269)	(269)		—			(269)
已宣派非控股权益现金分配	—		—		—			—			—	—		(25)			(25)

2026 年 3 月 31 日余额	578		$	58		$	12,439			$	(14)	$	171		$	12,654		$	1,452	$	14,106
净利润	—		—		—			—			288	288		64			352

股票投资计划和股份薪酬福利计划	1		—		18			—			—	18		—			18
已宣派非控股权益现金分配	—		—		—			—			—	—		(25)			(25)
2026 年可转换票据转换溢价	—		—		(25)			—			—	(25)		—			(25)
2026 年 6 月 30 日余额	579		$	58		$	12,432			$	(14)	$	459		$	12,935		$	1,491	$	14,426
净利润	—		—		—			—			557	557		58			615

股票投资计划和股份薪酬福利计划	—		—		22			—			—	22		—			22
已宣派普通股现金股息（7 月和 9 月每股 0.465 美元）	—		—		—			—			(539)	(539)		—			(539)
已宣派非控股权益现金分配	—		—		—			—			—	—		(25)			(25)

2026 年 9 月 30 日余额	579		$	58		$	12,454			$	(14)	$	477		$	12,975		$	1,524	$	14,499


	截至 2025 年 9 月 30 日的九个月
	普通股	其他实收资本		累计其他综合收益（亏损）	留存收益		普通股股东权益总额		非控股权益		权益总额
（百万美元）	股数	金额
2025 年 1 月 1 日余额	577		$	58		$	12,368			$	(14)	$	43		$	12,455		$	1,265	$	13,720
净利润	—		—		—			—			360	360		54			414

股票投资计划和股份薪酬福利计划	—		—		9			—			—	9		—			9
已宣派普通股现金股息（3 月每股 0.445 美元）	—		—		—			—			(257)	(257)		—			(257)
已宣派非控股权益现金分配	—		—		—			—			—	—		(24)			(24)
2025 年 3 月 31 日余额	577		$	58		$	12,377			$	(14)	$	146		$	12,567		$	1,295	$	13,862
净利润	—		—		—			—			268	268		50			318

股票投资计划和股份薪酬福利计划	—		—		16			—			—	16		—			16
已宣派非控股权益现金分配	—		—		—			—			—	—		(25)			(25)

2025 年 6 月 30 日余额	577		$	58		$	12,393			$	(14)	$	414		$	12,851		$	1,320	$	14,171
净利润	—		—		—			—			441	441		91			532

股票投资计划和股份薪酬福利计划	1		—		19			—			—	19		—			19
已宣派普通股现金股息（7 月和 9 月每股 0.445 美元）	—		—		—			—			(515)	(515)		—			(515)
已宣派的非控股权益现金分配	—		—		—			—			—	—		(25)			(25)
其他	—		—		2			—			—	2		—			2
2025年9月30日余额	578		$	58		$	12,414			$	(14)	$	340		$	12,798		$	1,386	$	14,184

参见注册人的合并财务报表附注。

FIRSTENERGY CORP.

合并现金流量表

（未经审计）


	截至9月30日的九个月，
（百万美元）	2026		2025
经营活动产生的现金流量：
净利润	$	1,433			$	1,264
将净利润调节为经营活动产生的现金净额的调整项-
折旧、摊销和减值	1,486			1,349

冬季风暴 Fern 递延购电成本，净额（附注9。）	(145)			—
递延风暴恢复费用	(546)			(56)
递延所得税和投资税抵免，净额	289			222
员工福利成本，净额	(12)			12


输电收入收款，净额	46			141
新泽西州 ZEC 退款，净额（附注9。）	55			—
流动资产和负债变动-
应收款项	(122)			(32)
材料和用品	(28)			(29)
预付税款和其他流动资产	(69)			(92)
应付账款	280			79
应计税款	(190)			(135)
应计利息	(67)			29
应计薪酬和福利	(58)			—
其他流动负债	(42)			(36)
俄亥俄州和解客户补偿及退款（附注9。）	(266)			—
现金抵押品，净额	9			3
员工福利计划供款及相关付款	(33)			(38)
其他	38			(117)
经营活动提供的现金净额	2,058			2,564



投资活动产生的现金流量：
资本投资	(4,187)			(3,539)

出售信托持有的投资证券	42			89
购买信托持有的投资证券	(52)			(99)

资产拆除成本	(378)			(290)
其他	(4)			34
投资活动使用的现金净额	(4,579)			(3,805)

融资活动产生的现金流量：
新增融资-
长期债务	2,575			5,925
短期借款，净额	1,645			—


赎回和偿还-
长期债务	(720)			(2,179)
短期借款，净额	—			(259)


非控股权益现金分配	(75)			(74)


普通股股息支付	(795)			(759)
债务发行和赎回成本及其他	(76)			(136)
融资活动提供的现金净额	2,554			2,518

现金、现金等价物和受限现金净变动	33			1,277
期初现金、现金等价物和受限现金	99			154
期末现金、现金等价物和受限现金	$	132			$	1,431

补充现金流量信息：
重大非现金交易：
应计资本投资	$	496			$	316
转让 McElroy’s Run CCR 蓄水设施	$	—			$	99

参见注册人的合并财务报表附注。

FIRSTENERGY PENNSYLVANIA ELECTRIC COMPANY AND SUBSIDIARIES

合并收益及综合收益表

（未经审计）


	截至9月30日的三个月，		截至9月30日的九个月，
（百万美元）	2026		2025		2026		2025

收入：
非关联方收入	$	1,187			$	1,068		$	3,359	$	3,007
关联方收入	4			5			13		16
总收入税收款	73			66			207		186
总收入	1,264			1,139			3,579		3,209

营业费用：
外购电力	617			529			1,698		1,436
其他营业费用(1)	317			225			910		770
折旧费用	85			81			255		238
监管资产摊销（递延），净额	(59)			32			(139)		(50)
一般税费	79			73			228		208
营业费用总额	1,039			940			2,952		2,602

营业收入	225			199			627		607

其他收入（费用）：
利息收入—关联方	4			4			15		13
杂项收入，净额	16			12			47		39

利息费用—非关联方	(52)			(47)			(156)		(142)
利息费用—关联方	(6)			(6)			(18)		(18)
资本化融资成本	5			4			14		10
其他费用总额	(33)			(33)			(98)		(98)

税前收入	192			166			529		509

所得税	25			32			101		114

净利润	$	167			$	134		$	428	$	395



综合收益表

净利润	$	167			$	134		$	428	$	395

其他综合收益：
养老金和其他退休后福利（OPEB）先前服务成本	—			(1)			—		(1)
其他综合收益	—			(1)			—		(1)
其他综合收益所得税	—			—			—		—
其他综合收益，扣除税款后	—			(1)			—		(1)

综合收益	$	167			$	133		$	428	$	394

(1) 包括截至2026年和2025年9月30日止三个月的关联运营费用分别为27百万美元和29百万美元，以及截至2026年和2025年9月30日止九个月的关联运营费用分别为84百万美元和100百万美元。

参见注册公司的合并财务报表附注。

FIRSTENERGY PENNSYLVANIA ELECTRIC COMPANY及子公司

合并资产负债表

（未经审计）


（单位：百万美元，股份金额除外）	2026年9月30日		2025年12月31日
资产
流动资产：


应收款—
客户	$	697			$	751
减：客户应收款坏账准备	23			30
	674			721
关联公司	32			42
其他	79			63



预付税款及其他	74			29
	859			855
不动产、厂房和设备：
在用	12,618			11,969
减：累计折旧准备	3,378			3,318
	9,240			8,651
在建工程	469			311
	9,709			8,962






递延费用和其他资产：
商誉	962			962
监管资产	349			109
投资	14			14
预付养老金和其他退休后福利（OPEB）费用	167			142
其他	145			148
	1,637			1,375
资产总额	$	12,205			$	11,192

负债和权益
流动负债：
即将到期的长期债务	$	—			$	300

关联公司短期借款	212			328

应付账款—
关联公司	82			14
其他	314			340
应计税款	72			52
应计利息	47			44
客户押金	137			131
其他	97			102
	961			1,311
非流动负债：
长期债务及其他长期义务	4,279			3,434
累计递延所得税净额	1,805			1,703
退休福利	9			9

其他	355			308
	6,448			5,454
负债总额	7,409			6,765

普通股股东权益：

普通股及其他实收资本，无面值，授权发行10,000股，已发行1,000股	2,639			2,633
累计其他综合亏损	(8)			(8)
留存收益	2,165			1,802
普通股股东权益总额	4,796			4,427



承诺、担保和或有事项（附注10。）

负债和普通股股东权益总额	$	12,205			$	11,192

参见注册公司的合并财务报表附注。

FIRSTENERGY PENNSYLVANIA ELECTRIC COMPANY及子公司

合并普通股股东权益表

（未经审计）


	截至2026年9月30日止九个月
	普通股	其他实收资本		累计其他综合收益（AOCI）	留存收益		股东权益总额
（单位：百万美元，股份金额除外）	股份数量	账面价值
2026年1月1日余额	1,000		$	—		$	2,633		$	(8)	$	1,802	$	4,427
净利润	—		—		—			—		170	170

股票薪酬(1)	—		—		2			—		—	2
已宣告的普通股现金股息	—		—		—			—		(65)	(65)
2026年3月31日余额	1,000		$	—		$	2,635		$	(8)	$	1,907	$	4,534
净利润	—		—		—			—		91	91

股票薪酬(1)	—		—		2			—		—	2


2026年6月30日余额	1,000		$	—		$	2,637		$	(8)	$	1,998	$	4,627
净利润	—		—		—			—		167	167

股票薪酬(1)	—		—		2			—		—	2



2026年9月30日余额	1,000		$	—		$	2,639		$	(8)	$	2,165	$	4,796


	截至2025年9月30日的九个月
	普通股	其他实收资本		累计其他综合收益	留存收益		股东权益总额
（百万美元，股份数量除外）	股份数量	账面价值
2025年1月1日余额	1,000		$	—		$	2,627			$	(7)		$	1,559		$	4,179
净利润	—		—		—			—			157		157

股票薪酬(1)	—		—		1			—			—		1
已宣告的普通股现金股息	—		—		—			—			(85)		(85)
2025年3月31日余额	1,000		$	—		2,628			$	(7)		$	1,631		$	4,252
净利润	—		—		—			—			104		104

股票薪酬(1)	—		—		2			—			—		2


2025年6月30日余额	1,000		$	—		$	2,630			$	(7)		$	1,735		$	4,358
净利润	—		—		—			—			134		134
其他综合收益	—		—		—			(1)			—		(1)
股票薪酬(1)	—		—		2			—			—		2



2025年9月30日余额	1,000		$	—		$	2,632			$	(8)		$	1,869		$	4,493

(1) 以授予部分 FE PA 员工的 FE 普通股权益形式发放，主要与 401(k) 储蓄计划有关。

参见注册人财务报表合并附注。

FIRSTENERGY PENNSYLVANIA ELECTRIC COMPANY 及其子公司

合并现金流量表

（未经审计）


	截至9月30日的九个月，
（百万美元）	2026		2025
经营活动产生的现金流量：
净利润	$	428			$	395
将净利润调节为经营活动产生的现金净额的调整项-
折旧和摊销	301			231

递延风暴修复费用	(181)			(39)
递延所得税和投资税抵免，净额	49			43
员工福利成本，净额	(25)			(21)





流动资产和负债变动 -
应收款项	42			80
预付税款和其他流动资产	(46)			(39)
应付账款	(36)			(14)
应计税款	20			28
应计利息	3			1
客户押金	6			9

其他流动负债	(7)			(12)
抵押品，净额	2			(7)
员工福利计划缴款及相关付款	(4)			(4)
其他	47			(16)
经营活动提供的现金净额	599			635

投资活动产生的现金流量：
资本性投资	(856)			(591)
向关联公司提供的贷款，净额	—			5
资产拆除成本	(104)			(70)
其他	—			(1)
投资活动使用的现金净额	(960)			(657)

融资活动产生的现金流量：
新增融资-
长期债务	850			—
关联公司短期借款，净额	—			107

赎回和偿还-
长期债务	(300)			—
关联公司短期借款，净额	(116)			—

普通股股息支付	(65)			(85)

其他	(8)			—
融资活动提供的现金净额	361			22

现金、现金等价物和受限现金净变动	—			—
期初现金、现金等价物和受限现金	—			—
期末现金、现金等价物和受限现金	$	—			$	—

现金流量补充信息：




重大非现金交易：
应计资本性投资	$	146			$	51

参见注册人的财务报表合并附注。

JERSEY CENTRAL POWER & LIGHT COMPANY

收益及综合收益表

（未经审计）


	截至9月30日的三个月		截至9月30日的九个月
（百万美元）	2026		2025		2026		2025

收入	$	886			$	864		$	2,211	$	2,022

运营费用：
外购电力	446			451			1,173		1,052
其他运营费用(1)	345			158			763		440
折旧准备	63			66			187		196
监管资产净摊销（递延）	(156)			13			(338)		(19)
一般税费	6			6			19		18
运营费用总额	704			694			1,804		1,687

运营收入	182			170			407		335

其他收入（费用）：

杂项收入净额	13			13			41		36

非关联方利息费用	(43)			(34)			(123)		(93)
关联方利息费用	(4)			(3)			(9)		(6)
资本化融资成本	10			12			35		31
其他费用总额	(24)			(12)			(56)		(32)

税前收入	158			158			351		303

所得税	36			40			84		76

净收入	$	122			$	118		$	267	$	227

综合收益	$	122			$	118		$	267	$	227

(1) 包括截至2026年和2025年9月30日的三个月关联方运营费用分别为28百万美元和27百万美元；截至2026年和2025年9月30日的九个月分别为85百万美元和86百万美元。

参见注册人的财务报表合并附注。

JERSEY CENTRAL POWER & LIGHT COMPANY

资产负债表

（未经审计）


（百万美元，股份金额除外）	9月30日 2026		12月31日 2025
资产
流动资产：

受限现金	$	55			$	—
应收款—
客户	395			330
减：客户应收款坏账准备	5			6
	390			324
关联公司	35			22
其他	30			25
持有待售资产（附注1。）	18			—
预付税款及其他	64			33
	592			404

不动产、厂房及设备：
在用	9,784			9,267
减：累计折旧准备	2,444			2,439
	7,340			6,828
在建工程	1,086			880
	8,426			7,708


投资及其他非流动资产：
商誉	1,811			1,811
投资	286			297
监管资产	950			515
预付其他退休后福利成本	257			243
其他	139			131
	3,443			2,997
资产总额	$	12,461			$	11,109

负债及普通股股东权益
流动负债：
当前应付长期债务	$	2			$	2
短期借款—
关联公司	175			93
其他	450			—
应付账款—
关联公司	192			103
其他	184			175
Accrued compensation and benefits	31			34
Customer deposits	35			35
Accrued taxes	2			11
Accrued interest	40			44

Other	23			41
	1,134			538
NONCURRENT LIABILITIES:
Long-term debt and other long-term obligations	3,372			3,023
Accumulated deferred income taxes, net	1,493			1,348
Nuclear fuel disposal costs	252			245
Retirement benefits	25			32

Other	752			763
	5,894			5,411
TOTAL LIABILITIES	7,028			5,949

COMMON STOCKHOLDER'S EQUITY:
Common stock, $10 par value, authorized 16,000,000 shares - 13,628,447 shares outstanding as of September 30, 2026, and December 31, 2025.	136			136
Other paid-in capital	3,536			3,530
Accumulated other comprehensive loss	(4)			(4)
Retained earnings	1,765			1,498
TOTAL COMMON STOCKHOLDER’S EQUITY	5,433			5,160












COMMITMENTS, GUARANTEES AND CONTINGENCIES (NOTE 10.)

TOTAL LIABILITIES AND COMMON STOCKHOLDER’S EQUITY	$	12,461			$	11,109

See Combined Notes to Financial Statements of the Registrants.

JERSEY CENTRAL POWER & LIGHT COMPANY

STATEMENTS OF COMMON STOCKHOLDER’S EQUITY

(Unaudited)


	Nine Months Ended September 30, 2026
	Common Stock
(In millions, except share amounts)	Number of Shares	Carrying Value		Other Paid-In Capital	AOCI		Retained Earnings		Total Common Stockholder's Equity
Balance, January 1, 2026	13,628,447		$	136		$	3,530			$	(4)	$	1,498	$	5,160
Net income	—		—		—			—			66	66
Stock-based compensation(1)	—		—		2			—			—	2

Balance, March 31, 2026	13,628,447		$	136		$	3,532			$	(4)	$	1,564	$	5,228
Net income	—		—		—			—			79	79
Stock-based compensation(1)	—		—		2			—			—	2

Balance, June 30, 2026	13,628,447		$	136		$	3,534			$	(4)	$	1,643	$	5,309
Net income	—		—		—			—			122	122
Stock-based compensation(1)	—		—		2			—			—	2

Balance, September 30, 2026	13,628,447		$	136		$	3,536			$	(4)	$	1,765	$	5,433


	Nine Months Ended September 30, 2025
	Common Stock
(In millions, except share amounts)	Number of Shares	Carrying Value		Other Paid-In Capital	AOCI		Retained Earnings		Total Common Stockholder's Equity
Balance, January 1, 2025	13,628,447		$	136		$	3,523			$	(4)		$	1,312	$	4,967
Net income	—		—		—			—			47		47
Stock-based compensation(1)	—		—		2			—			—		2
Cash dividends declared on common stock	—		—		—			—			(30)		(30)
Balance, March 31, 2025	13,628,447		$	136		$	3,525			$	(4)		$	1,329	$	4,986
Net income	—		—		—			—			62		62
Stock-based compensation(1)	—		—		1		—			—		1


Balance, June 30, 2025	13,628,447		$	136		$	3,526			$	(4)		$	1,391	$	5,049
Net income	—		—		—			—			118		118
Stock-based compensation(1)	—		—		2			—			—		2
Common stock dividends declared	—		$	—		$	—			$	—		$	(90)	(90)
Balance, September 30, 2025	13,628,447		$	136		$	3,528			$	(4)		$	1,419	$	5,079

(1) In the form of FE common equity granted to certain JCP&L employees primarily related to the FirstEnergy 401(k) Savings Plan.

See Combined Notes to Financial Statements of the Registrants.

JERSEY CENTRAL POWER & LIGHT COMPANY

STATEMENTS OF CASH FLOWS

(Unaudited)


	For the Nine Months Ended September 30,
(In millions)	2026		2025
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$	267			$	227
Adjustments to reconcile net income to net cash from operating activities-
Depreciation, amortization and impairments	170			205
Transmission revenue collections, net	—			19
Deferred storm restoration expenses	(293)			(3)
Deferred income taxes and investment tax credits, net	127			82
Spent nuclear fuel disposal trust income	10			10

New Jersey temporary rate credits, net	20			(50)
Employee benefit costs, net	(20)			(17)

New Jersey ZEC refund, net (Note 9.)	55			—
Changes in current assets and liabilities-
Receivables	(83)			(43)
Prepaid taxes and other current assets	(25)			(28)
Accounts payable	52			17
Accrued taxes	(9)			2
Accrued interest	(4)			7
Accrued compensation and benefits	(3)			(3)

Other current liabilities	(22)			(8)
Cash collateral, net	5			5

Other	(1)			(45)
Net cash provided from operating activities	246			377

CASH FLOWS FROM INVESTING ACTIVITIES:
Capital investments	(996)			(778)
Loans with affiliated companies, net	—			(26)
Sales of investment securities held in trusts	42			89
Purchases of investment securities held in trusts	(52)			(99)
Asset removal costs	(64)			(58)
Other	1			(1)
Net cash used for investing activities	(1,069)			(873)

CASH FLOWS FROM FINANCING ACTIVITIES:
New financing-
Long-term debt	350			1,350

Short-term borrowings - affiliated companies, net	82			—
Short-term borrowings - other, net	450			11
Redemptions and repayments-


Short-term borrowings - affiliated companies, net	—			(22)


Common stock dividend payments	—			(120)
Debt issuance costs and other	(4)			(15)
Net cash provided from financing activities	878			1,204

Net change in cash, cash equivalents, and restricted cash	55			708
Cash, cash equivalents, and restricted cash at beginning of period	—			—
Cash, cash equivalents, and restricted cash at end of period	$	55			$	708

SUPPLEMENTAL CASH FLOW INFORMATION:




Significant non-cash transactions:
Accrued capital investments	$	130			$	87

See Combined Notes to Financial Statements of the Registrants.

COMBINED NOTES TO FINANCIAL STATEMENTS OF THE REGISTRANTS

(Unaudited)


Note		Registrant	Page Number

1.	Organization and Basis of Presentation	FirstEnergy, FE PA, JCP&L	16

2.	Revenue	FirstEnergy, FE PA, JCP&L	22

3.	Earnings Per Share	FirstEnergy	24

4.	Pension and Other Post-Employment Benefits	FirstEnergy, FE PA, JCP&L	25

5.	Income Taxes	FirstEnergy, FE PA, JCP&L	27

6.	Fair Value Measurements	FirstEnergy, FE PA, JCP&L	29

7.	Variable Interest Entities	FirstEnergy, FE PA, JCP&L	34

8.	Asset Retirement Obligations	FirstEnergy, FE PA, JCP&L	36

9.	Regulatory Matters	FirstEnergy, FE PA, JCP&L	37

10.	Commitments, Guarantees and Contingencies	FirstEnergy, FE PA, JCP&L	45

11.	Segment Information	FirstEnergy, FE PA, JCP&L	51

12.	Transactions with Affiliates	FE PA, JCP&L	54

1. ORGANIZATION AND BASIS OF PRESENTATION

Defined terms and abbreviations used herein have the meanings set forth in the Glossary of Terms. This is a combined set of financial statements filed separately for FirstEnergy, FE PA, and JCP&L. Unless otherwise indicated, the disclosures in these notes apply to each of the Registrants.

FirstEnergy

FE was incorporated under Ohio law in 1996. FE’s principal business is the holding, directly or indirectly, of all of the outstanding equity of its principal subsidiaries: OE, CEI, TE, FE PA, JCP&L, FESC, MP, AGC, PE and KATCo. Additionally, FET is a VIE of FE, and is the parent company of ATSI, MAIT, and TrAIL. FirstEnergy continues to evaluate the legal, financial, operational and branding benefits of consolidating the Ohio Companies into a single Ohio power company.

FE and its subsidiaries are principally involved in the transmission, distribution and generation of electricity. FirstEnergy’s electric operating companies comprise one of the nation’s largest investor-owned electric systems, serving over six million customers in the Midwest and Mid-Atlantic regions. FirstEnergy’s transmission operations include more than 24,000 miles of lines and two regional transmission operation centers. As of September 30, 2026, AGC and MP control 3,610 MWs of net maximum generation capacity.

FET also owns a 34% equity interest in Valley Link. On November 25, 2024, FET, DominionHV, and Transource formed Valley Link, which is the holding company responsible for managing and executing those projects awarded by PJM, and entered into a limited liability company agreement. Valley Link is the owner of the Valley Link Subsidiaries, which are organized in various states. The Valley Link Subsidiaries comprise the entities that are expected to develop, construct, own, operate and maintain those transmission projects awarded by PJM.

On February 13, 2026, FET and Transource entered into the Grid Growth Operating Agreement, which established the general framework for Grid Growth to accept, design, develop, construct, own, operate and finance certain transmission projects, among others, awarded by PJM on February 12, 2026, to certain of the subsidiaries of Grid Growth. This general framework includes parameters regarding the relationship between the two members, confers governance rights to its members so long as certain ownership percentages are maintained and defines the list of projects that Grid Growth will have the right to develop. The relative ownership interests of the members under the Grid Growth Operating Agreement are 50% for each of FET and Transource. Grid Growth is the sole owner of Grid Growth Ohio and owns an 80% interest in Grid Growth EHV, with Transource owning the remaining interest.

FESC provides legal, financial and other corporate support services at cost, in accordance with its cost allocation manual, to affiliated FirstEnergy companies. FE does not bill directly or allocate any of its costs to any subsidiary company. Costs are charged to FE's subsidiaries for services received from FESC either through direct billing or through an allocation process. Allocated costs are for services that are provided on behalf of more than one company and are allocated using formulas developed by FESC and are generally settled under commercial terms within thirty days.

FE PA

FE PA is incorporated in Pennsylvania and is a wholly owned subsidiary of FirstEnergy Pennsylvania Holding Company LLC, which is a wholly owned subsidiary of FE. FE PA owns property and does business as an electric public utility in Pennsylvania and New York, providing distribution services to approximately 2.1 million customers in Pennsylvania and approximately 4,000 customers in Waverly, New York. FE PA serves an area that has a population of approximately 4.5 million. FE PA complies with the regulations, orders, policies and practices prescribed by FERC, the PPUC and the NYPSC.

JCP&L

JCP&L owns property and does business as an electric public utility in New Jersey, providing distribution services to approximately 1.2 million customers, as well as transmission services in northern, western, and east central New Jersey. JCP&L serves an area that has a population of approximately 2.8 million. JCP&L plans, operates, and maintains its transmission system in accordance with NERC reliability standards, and other applicable regulatory requirements. In addition, JCP&L complies with the regulations, orders, policies and practices prescribed by FERC and the NJBPU.

Asset held-for-sale

JCP&L had previously committed to a plan to sell its Morristown, New Jersey office building. During the third quarter of 2026, progress on the sale continued to the point that management determined it is probable the sale will close within one year, subject to customary closing conditions and applicable regulatory approvals. As a result, the carrying value of the office building has been classified as held-for-sale on the accompanying JCP&L Balance Sheets and is included within “Prepaid taxes and other” on FirstEnergy’s Consolidated Balance Sheets. Upon classification as held-for-sale, JCP&L recognized a $5 million pre-tax impairment charge, which is included within \"Other operating expenses\" on JCP&L’s and FirstEnergy’s Consolidated Statements of Income and Comprehensive Income for the three and nine months ended September 30, 2026. The impairment charge is included in FirstEnergy’s Integrated segment.

Revision of Previously Issued Interim Financial Statements of JCP&L

During the fourth quarter of 2025, JCP&L identified an error in the recording of certain expenses for smart meter cost of removal associated with the deployment of its AMI program, resulting in an understatement of expense on the Statements of Income and Comprehensive Income and Regulatory assets/liabilities on the Balance Sheets since 2023. The identified error impacted JCP&L's previously issued 2023 and 2024 annual financial statements, and interim periods in 2024 and 2025. JCP&L evaluated the error, and the specific impact on each affected prior period was not material, however, as a result of the cumulative impact, JCP&L determined to revise previously issued financial statements to correct the error and, in doing so, also corrected certain other previously identified immaterial errors, including the misclassification of certain retired assets. As such, JCP&L has revised the previously issued interim Statements of Income and Comprehensive Income for the three and nine months ended September 30, 2025 and the Statement of Cash Flows and Statements of Common Stockholder’s Equity for the nine months ended September 30, 2025.

JCP&L Interim Statements of Income and Comprehensive Income


	For the Three Months Ended September 30, 2025		For the Nine Months Ended September 30, 2025
(In millions)	As Reported		Adjustment		As Revised		As Reported	Adjustment		As Revised
Deferral of regulatory assets, net	$	11			$	2		$	13		$	(25)		$	6	$	(19)
Other operating expenses	158			—			158		436		4		440
Total operating expenses	692			2			694		1,677		10		1,687
Operating income	172			(2)			170		345		(10)		335
Income before income taxes	160			(2)			158		313		(10)		303
Income taxes	41			(1)			40		79		(3)		76
Net income	119			(1)			118		234		(7)		227
Comprehensive income	119			(1)			118		234		(7)		227

JCP&L Interim Statements of Common Stockholder's Equity


	For the Nine Months Ended September 30, 2025
(In millions)	As Reported		Adjustment		As Revised
Balance, January 1, 2025	$	4,977			$	(10)		$	4,967
Net income	49			(2)			47
Balance, March 31, 2025	4,998			(12)			4,986
Net income	66			(4)			62
Balance, June 30, 2025	$	5,065			$	(16)		$	5,049
Net income	119			(1)			118
Balance, September 30, 2025	5,096			(17)			5,079

JCP&L Interim Statements of Cash Flows


	For the Nine Months Ended September 30, 2025
(In millions)	As Reported		Adjustment		As Revised
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$	234			$	(7)		$	227
Adjustments to reconcile net income to net cash from operating activities-
Depreciation, amortization, and impairments	199		(1)	6			205
Deferred income taxes and investment tax credits, net	85			(3)			82
Net cash provided from operating activities	381			(4)			377

CASH FLOWS FROM INVESTING ACTIVITIES:
Capital investments	$	(782)			$	4		$	(778)
Net cash used for investing activities	(877)			4			(873)

Net change in cash, cash equivalents, and restricted cash	$	708			$	—		$	708

(1) Amount includes the effect of a reclassification made to conform prior period presentation to the current year presentation.

Basis of Presentation

The Registrants follow GAAP and comply with the related regulations, orders, policies and practices prescribed by the SEC, FERC, and, as applicable, the PUCO, the PPUC, the MDPSC, the NYPSC, the WVPSC, the VSCC and the NJBPU. The accompanying interim financial statements as of September 30, 2026, and for the three and nine months ended September 30, 2026, and 2025, respectively, are unaudited, but reflect all adjustments, consisting of normal recurring adjustments, that, in the opinion of management, are necessary for the fair presentation of the financial statements. The balance sheets, as of December 31, 2025, were derived from audited financial statements. The preparation of financial statements in conformity with GAAP requires management to make periodic estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and disclosure of contingent assets and liabilities. Actual results could differ from these estimates. The reported results of operations are not necessarily indicative of results of operations for any future period.

These interim financial statements have been prepared pursuant to the rules and regulations of the SEC for Quarterly Reports on Form 10-Q. Certain information and disclosures normally included in financial statements and notes prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations. These interim financial statements should be read in conjunction with FirstEnergy’s and JCP&L’s audited financial statements and notes included in their Annual Report on Form 10-K for the year ended December 31, 2025, filed with the SEC on February 18, 2026, and FE PA’s Registration Statement on Form S-4 filed with the SEC on September 1, 2026.

The Registrants consolidate all majority-owned subsidiaries over which they exercise control and, when applicable, entities for which they have a controlling financial interest. Intercompany transactions and balances are eliminated in consolidation as appropriate and permitted pursuant to GAAP. The Registrants consolidate a variable interest entity when it is determined that it is the primary beneficiary.

As previously disclosed in FirstEnergy’s Form 10-Q for the period ended March 31, 2026, the disclosure related to the combined assets and liabilities of the consolidated VIEs has been revised as of December 31, 2025, to exclude $243 million of liabilities. The correction was not material to FirstEnergy’s previously issued financial statements.

Certain prior year amounts have been reclassified to conform to the current year presentation.

Economic Conditions

FirstEnergy continues to monitor supply lead times in light of demand increases across the industry, including due to data center usage, and the imposition of tariffs and retaliatory tariffs that have been, and may be, imposed by the U.S. government in response. In addition, ongoing geopolitical conflicts have contributed to volatility in global energy markets and fuel and transportation costs, which may further impact supply availability or pricing. FirstEnergy continues to implement mitigation strategies to address volatility in interest rates, inflation and supply constraints and does not expect any corresponding service disruptions or any material impact on its capital investment plan. However, a prolonged continuation or further increase in demand, sustained or escalating geopolitical tensions, rising fuel costs or the continuation of uncertain or adverse macroeconomic conditions, including inflationary pressures and new or increased existing tariffs, could lead to an increase in supply chain disruptions that could, in turn, have an adverse effect on the Registrants’ results of operations, cash flow and financial condition.

Capitalized Financing Costs

The Registrants’ capitalized financing costs were as follows:


	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
	2026		2025	2026		2025
FirstEnergy	(In millions)
Allowance for equity funds used during construction	$	33		$	30		$	98	$	76
Capitalized interest	$	22		$	21		$	63	$	55

FE PA
Allowance for equity funds used during construction	$	1		$	2		$	4	$	3
Capitalized interest	$	4		$	2		$	10	$	7

JCP&L
Allowance for equity funds used during construction	$	5		$	8		$	18	$	21
Capitalized interest	$	5		$	4		$	17	$	10

FET Noncontrolling Interest

FirstEnergy presents Brookfield’s 49.9% total ownership portion of FET’s net income and net assets as NCI. NCI is included as a component of equity on FirstEnergy’s Consolidated Balance Sheets.

On May 20, 2026, FE, FET and Brookfield entered into the A&R FET LLC Agreement, which amends and restates the A&R Fourth FET LLC Agreement in its entirety. The A&R FET LLC Agreement implements the application of the parties’ existing governance arrangements under the A&R Fourth FET LLC Agreement to FET’s participation in Valley Link and Grid Growth. The relative ownership percentages of the members of FET, the size and composition of FET’s board of directors, the ownership-based thresholds at which Brookfield’s rights apply, and the scope of the matters as to which Brookfield has consent, consultation or other approval rights with respect to FET, in each case as set forth in the A&R Fourth FET LLC Agreement, are not modified by the A&R FET LLC Agreement.

Equity Method Investments

Investments over which the Registrants have the ability to exercise significant influence, but do not have a controlling financial interest, follow the equity method of accounting. Under the equity method, the interest in the entity is reported in “Investments” on the Registrants’ Balance Sheets. The percentage of ownership share of the entity’s earnings is reported in the Registrants’ Statement of Income and reflected in “Other income (expense)”.

Equity method investments, which are included within \"Investments\" on FirstEnergy’s Consolidated Balance Sheets, were approximately $17 million and $38 million as of September 30, 2026, and December 31, 2025, respectively.

Equity method investment balances as of September 30, 2026, and December 31, 2025, and earnings during the first nine months of 2026 for FE PA were immaterial.

JCP&L did not have any equity method investments as of September 30, 2026, or December 31, 2025.

Valley Link - On February 21, 2025, FET, DominionHV and Transource entered into the Valley Link Operating Agreement, which established the general framework for Valley Link and the Valley Link Subsidiaries to accept, design, develop, construct, own, operate and finance those transmission projects awarded by PJM to Valley Link. This general framework includes parameters regarding the relationship among the three members, confers governance rights to its members so long as certain ownership percentages are maintained, as described below, and defines the list of projects that Valley Link will have the right to develop. Valley Link is the owner of the Valley Link Subsidiaries, which are organized in various states. On February 26, 2025, in response to the 2024 PJM RTEP Open Window, PJM awarded two electric transmission projects to Valley Link estimated to be approximately $3 billion, with FET’s share estimated to be approximately $1 billion.

As of February 21, 2025, the relative ownership interests of the members are FET (34%), DominionHV (30%), and Transource (36%), and Valley Link will not be consolidated with FET for financial or tax reporting purposes and expects to be accounted for under equity method accounting. Investment balances as of September 30, 2026, and earnings during the first nine months of 2026 related to Valley Link were immaterial.

Grid Growth - On February 13, 2026, FET and Transource entered into the Grid Growth Operating Agreement, which established the general framework for Grid Growth to accept, design, develop, construct, own, operate and finance certain transmission projects awarded by PJM to certain of the subsidiaries of Grid Growth. This general framework includes parameters

regarding the relationship between the two members, confers governance rights to members so long as certain ownership percentages are maintained and defines the list of projects that Grid Growth will have the right to develop. As of February 13, 2026, the relative ownership interests of the members are 50% by each of FET and Transource. Grid Growth is the sole owner of Grid Growth Ohio and owns an 80% interest in Grid Growth EHV, with Transource owning the remaining interest. FET’s ownership interest in Grid Growth is subject to the equity method of accounting. There were no investment balances as of September 30, 2026, and no earnings were recognized during the first nine months of 2026 related to Grid Growth.

On February 12, 2026, in response to the 2025 PJM RTEP Open Window, PJM awarded a project to Grid Growth estimated to be approximately $1 billion, with FET’s share estimated to be approximately $448 million.

PATH-WV - A subsidiary of FE formerly owned 50% of PATH-WV, which was a joint venture with a subsidiary of AEP. In March 2024, PATH completed the process of terminating all of its FERC-jurisdictional rates and facilities, with the result that PATH no longer is a “public utility” and no longer is subject to FERC jurisdiction. During the second quarter of 2026, FET received cash payments of approximately $21 million after the liquidation of PATH was authorized by FirstEnergy and its non-affiliated joint venture partner. The cash payment was classified in other within “Cash from Investing Activities” of FirstEnergy’s Consolidated Statements of Cash Flows.

Goodwill

The Registrants evaluate goodwill for impairment annually on July 31 and more frequently if indicators of impairment arise. For 2026, the Registrants performed a qualitative assessment of their reporting units' goodwill, assessing economic, industry and market considerations in addition to the reporting units' overall financial performance. Key factors used in the assessment included: growth rates, interest rates, expected capital investments, utility sector market performance, regulatory and legal developments, and other market considerations. It was determined that the fair values of these reporting units were, more likely than not, greater than their carrying values and a quantitative analysis was not necessary.

FirstEnergy's reporting units are consistent with its reportable segments and consist of Distribution, Integrated and Stand-Alone Transmission. The following table presents goodwill by reporting unit as of September 30, 2026, and as of the measurement date, July 31, 2026:


(In millions)	Distribution Segment		Integrated Segment	Stand-Alone Transmission Segment		FirstEnergy Consolidated
Goodwill	$	3,222		$	1,953		$	443	$	5,618

FE PA has a single reporting unit consistent with its single reportable segment. Goodwill as of both July 31, 2026, and September 30, 2026, was $962 million.

JCP&L has a single reporting unit consistent with its single reportable segment. Goodwill as of both July 31, 2026, and September 30, 2026, was $1,811 million.

New Accounting Pronouncements

Recently Issued Pronouncements - The following new authoritative accounting guidance issued by the FASB has not yet been adopted by the Registrants. Unless otherwise indicated, the Registrants’ management is currently assessing the impact such guidance may have on the Registrants’ financial statements and disclosures, as well as the potential to early adopt (where applicable). Management has assessed other FASB issuances of new standards not described below based upon the current expectation that such new standards will not significantly impact the Registrants’ financial statements.

ASU 2024-03, \"Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures (Subtopic 220-40)\" (Issued in November 2024 and subsequently updated within ASU 2025-01): ASU 2024-03 requires disaggregated disclosure of income statement expenses for public business entities. The ASU does not change the expense captions an entity presents on the face of the income statement; rather, it requires disaggregation of certain expense captions into specified categories in disclosures within the footnotes to the financial statements. ASU 2024-03 is effective for the Registrants beginning with the combined Annual Report on Form 10-K for the year ended December 31, 2027, with early adoption permitted. The guidance is permitted to be applied prospectively, and comparative disclosures are not required for reporting periods beginning before the effective date. Entities can elect to apply the new standard retrospectively to any or all prior periods presented in the financial statements.

ASU 2025-06, “Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Targeted Improvements to the Accounting for Internal-Use Software\" (Issued in September 2025): ASU 2025-06 amends the existing standard that refers to various stages of a software development project to align better with current software development methods, such as agile programming. Under the new standard, entities will start capitalizing eligible costs when management has authorized and committed to funding the software project, and when it is probable that the project will be completed and the software will be used to perform the function intended. In evaluating whether it is probable that the project will be completed, an entity is required

to consider whether there is significant uncertainty associated with the development activities of the software. ASU 2025-06 is effective for the Registrants beginning with the financial statements for the first quarter of 2028, with early adoption permitted. The guidance is permitted to be applied using a prospective, retrospective or modified transition approach.

ASU 2025-10, “Government Grants (Topic 832): Accounting for Government Grants Received by Business Entities” (Issued in December 2025): ASU 2025-10 establishes authoritative guidance for the recognition, measurement, presentation, and disclosure of government grants received by business entities. ASU 2025-10 requires that a government grant be recognized when it is probable that the entity will comply with the conditions of the grant and that the grant will be received. It permits two approaches for asset-related grants, either the cost reduction method (reduce the carrying amount of the asset) or the deferred income method (recognize income over the useful life of the asset). Income-related grants are recognized systematically in income as the related costs are incurred. ASU 2025-10 is effective for the Registrants beginning with financial statements for the first quarter of 2029, with early adoption permitted. The guidance is permitted to be applied using a modified prospective, modified retrospective or full retrospective approach.

ASU 2026‑02, “Environmental Credits and Environmental Credit Obligations (Topic 818)” (Issued in May 2026): ASU 2026‑02 establishes new guidance for the recognition, measurement, presentation, and disclosure of environmental credits and environmental credit obligations. The standard requires entities to account for environmental credits based on their intended use, including whether the credits are expected to be used for compliance purposes, held for sale, or used for voluntary initiatives. The guidance also requires recognition of liabilities for environmental credit obligations and introduces a measurement model that incorporates both credits on hand and credits required to settle the obligation. ASU 2026‑02 is permitted to be applied retrospectively through a cumulative-effect adjustment to the opening balance of retained earnings (or other appropriate components of equity or net assets on the balance sheet) as of the beginning of the annual reporting period of adoption. ASU 2026‑02 is effective for the Registrants beginning with financial statements for the first quarter of 2028, with early adoption permitted.

2. REVENUE

The disclosures in this note apply to all Registrants, unless indicated otherwise.

FirstEnergy

The following represents a disaggregation of FirstEnergy’s revenue from contracts with customers for the three and nine months ended September 30, 2026, and 2025:


	Three Months Ended September 30,		Nine Months Ended September 30,
	2026		2025		2026		2025
	(In millions)
Distribution
Retail generation and distribution services:
Residential	$	1,533			$	1,333		$	4,068	$	3,685
Commercial	466			450			1,238		1,274
Industrial(1)	208			188			521		539
Wholesale	7			6			16		10
Other revenue from contracts with customers	22			23		58		60
Total revenues from contracts with customers	2,236			2,000			5,901		5,568

Other revenue unrelated to contracts with customers	17			20		56		63
Total Distribution	$	2,253			$	2,020		$	5,957	$	5,631

Integrated
Retail generation and distribution services:
Residential	$	931			$	880		$	2,363	$	2,186
Commercial	361			356			1,018		981
Industrial(1)	166			166			488		487
Wholesale	198			129			435		254
Transmission	128			109		396		320
Other revenue from contracts with customers	1			2			3		7
Total revenues from contracts with customers	1,785			1,642			4,703		4,235
ARP(2)	—			—			13		—
Other revenue unrelated to contracts with customers(3)	25			11		231		28
Total Integrated	$	1,810			$	1,653		$	4,947	$	4,263

Stand-Alone Transmission
ATSI	$	262			$	273		$	839	$	791
TrAIL	60			66			188		197
MAIT	148			121			435		365
KATCo	26			23			80		67

Total revenues from contracts with customers	496			483			1,542		1,420
Other revenue unrelated to contracts with customers	5			5			19		15
Total Stand-Alone Transmission	$	501			$	488		$	1,561	$	1,435

Corporate/Other, Eliminations and Reconciling Adjustments(4)
Wholesale	$	8			$	4		$	22	$	12

Eliminations and reconciling adjustments	(15)			(17)			(50)		(48)
Total Corporate/Other, Eliminations and Reconciling Adjustments	$	(7)			$	(13)		$	(28)	$	(36)

FirstEnergy Total Revenues	$	4,557			$	4,148		$	12,437	$	11,293

(1) Includes street lighting.

(2) Related to lost distribution revenues associated with energy efficiency programs in New Jersey.

(3) Includes revenues from FTRs. Due to the ENEC, FTRs have no material impact to earnings.

(4) Includes eliminations and reconciling adjustments of inter-segment revenues.

FE PA

The following table represents a disaggregation of FE PA’s revenue from contracts with customers for the three and nine months ended September 30, 2026, and 2025:


	Three Months Ended September 30,		Nine Months Ended September 30,
Revenues by Type of Service	2026		2025		2026		2025
	(In millions)
Distribution services and retail generation
Residential	$	946			$	843		$	2,665	$	2,370
Commercial	208			190			584		541
Industrial(1)	89			85			271		240

Other(2)	12			12			31		28
Total revenues from contracts with customers	1,255			1,130			3,551		3,179

Other revenue unrelated to contracts with customers(3)	9			9			28		30
FE PA Total Revenues	$	1,264			$	1,139		$	3,579	$	3,209

(1) Includes street lighting.

(2) Includes pole attachment and wholesale revenue.

(3) Includes affiliated lease revenues from ATSI, MAIT, and KATCo, as well as late payment charges.

JCP&L

The following table represents a disaggregation of JCP&L’s revenue from contracts with customers for the three and nine months ended September 30, 2026, and 2025:


	Three Months Ended September 30,		Nine Months Ended September 30,
Revenues by Type of Service	2026		2025		2026		2025
	(In millions)
Retail generation and distribution services:
Residential	$	592			$	574		$	1,351	$	1,231
Commercial	190			194			524		516
Industrial(1)	21			23			68		68
Wholesale	1			2			3		3
Transmission	78			67			240		191
Other revenue from contracts with customers	3			3			9		10
Total revenues from contracts with customers	885			863			2,195		2,019
ARP(2)	—			—			13		—
Other revenue unrelated to contracts with customers	1			1			3		3
JCP&L Total Revenues	$	886			$	864		$	2,211	$	2,022

(1) Includes street lighting.

(2) Related to lost distribution revenues associated with energy efficiency programs in New Jersey.

Customer Receivables

Receivables from contracts with customers include distribution services and retail generation sales to residential, commercial and industrial customers. Billed and unbilled customer receivables as of September 30, 2026, and December 31, 2025, are included below:


	FirstEnergy		FE PA		JCP&L
	September 30, 2026		December 31, 2025		September 30, 2026		December 31, 2025	September 30, 2026		December 31, 2025
	(In millions)
Billed	$	1,147			$	939		$	463		$	437		$	257	$	178
Unbilled	707			844			234		314		138		152
	1,854			1,783			697		751		395		330
Less: Uncollectible Reserve	49			57			23		30		5		6
Total Customer Receivables	$	1,805			$	1,726		$	674		$	721		$	390	$	324

The allowance for uncollectible customer receivables is based on historical loss information comprised of a rolling 36-month average net write-off percentage of revenues, in conjunction with a qualitative assessment of elements that impact the collectability of receivables to determine if allowances for uncollectible customer receivables should be further adjusted in accordance with the accounting guidance for credit losses.

The Registrants review the allowance for uncollectible customer receivables utilizing a quantitative and qualitative assessment. Management contemplates available current information such as changes in economic factors, regulatory matters, industry trends, customer credit factors, amount of receivable balances that are past-due, payment options and programs available to customers, and the methods that the Electric Companies can utilize to ensure payment. FirstEnergy’s and JCP&L’s uncollectible risk on PJM receivables, resulting from transmission and wholesale sales, is minimal due to the nature of PJM’s settlement process and as a result there is no current allowance for doubtful accounts.

Activity in the allowance for uncollectible accounts on customer receivables for the nine months ended September 30, 2026, and for the year ended December 31, 2025, is as follows:


	FirstEnergy		FE PA		JCP&L
	(In millions)
Balance, January 1, 2025	$	55			$	28		$	6
Provision for expected credit losses(1)(2)	94			47			8
Charged to other accounts(3)	37			16			3
Write-offs	(129)			(61)			(11)
Balance, December 31, 2025	$	57			$	30		$	6
Provision for expected credit losses(1)(2)	57			23			5
Charged to other accounts(3)	34			15			4
Write-offs	(99)			(45)			(10)
Balance, September 30, 2026	$	49			$	23		$	5

(1) Approximately $18 million and $31 million of which was deferred for future recovery for FirstEnergy in the nine months ended September 30, 2026, and the year ended December 31, 2025, respectively.

(2) Approximately $5 million and $8 million of which was deferred for future recovery for JCP&L in the nine months ended September 30, 2026, and the year ended December 31, 2025, respectively.

(3) Represents recoveries and reinstatements of accounts written off for uncollectible accounts.

3. EARNINGS PER SHARE OF COMMON STOCK

The disclosures in this note apply to FirstEnergy only.

EPS is calculated by dividing earnings attributable to FE by the weighted average number of common shares outstanding.

Basic EPS is computed using the weighted average number of common shares outstanding during the relevant period as the denominator. The denominator for diluted EPS of common stock reflects the weighted average of common shares outstanding

plus the potential additional common shares that could result if dilutive securities and other agreements to issue common stock were exercised.

Diluted EPS reflects the dilutive effect of potential common shares from share-based awards and convertible securities. The dilutive effect of outstanding share-based awards was computed using the treasury stock method, which assumes any proceeds that could be obtained upon the exercise of the award would be used to purchase common stock at the average market price for the period. The dilutive effect of any conversion premium on the 2029 Convertible Notes and the 2031 Convertible Notes is computed using the if-converted method. At maturity in May 2026, FE settled the conversion premium on the 2026 Convertible Notes of approximately $25 million in cash, and as a result, there was no dilutive effect.

The following table reconciles basic and diluted EPS attributable to FE:


	For the Three Months Ended September 30,	For the Nine Months Ended September 30,
Reconciliation of Basic and Diluted EPS		2026		2025		2026		2025

(In millions, except per share amounts)

Earnings Attributable to FE		$	557			$	441		$	1,250	$	1,069



Share count information:
Weighted average number of basic shares outstanding		579			577			578		577
Assumed exercise of dilutive share-based awards		1			1			1		1
Assumed impact of the 2029 Convertible Notes and the 2031 Convertible Notes conversion premium		—			—			1		—
Weighted average number of diluted shares outstanding		580			578			580		578

EPS Attributable to FE:


Basic EPS		$	0.96			$	0.76		$	2.16	$	1.85



Diluted EPS		$	0.96			$	0.76		$	2.16	$	1.85

For the three and nine months ended September 30, 2026, and 2025, no shares from awards were excluded from the calculation of diluted shares outstanding, as their inclusion would have been antidilutive.

The dilutive effect of the 2029 Convertible Notes and the 2031 Convertible Notes is limited to the conversion obligation in excess of the aggregate principal amount of the convertible notes being converted. As of September 30, 2026, the conversion price was $47.74 per share for both the 2029 Convertible Notes and the 2031 Convertible Notes. See Note 6., \"Fair Value Measurements,\" of the Combined Notes to Financial Statements of the Registrants for additional information on the convertible notes.

4. PENSION AND OTHER POST-EMPLOYMENT BENEFITS

The disclosures in this note apply to all Registrants, unless indicated otherwise.

FirstEnergy provides qualified benefit plans, through the FirstEnergy Master Pension Plan and the FirstEnergy Welfare Plan, which cover substantially all employees, as well as non-qualified defined benefit plans that cover certain employees, including employees of FE PA and JCP&L. FirstEnergy’s pension and OPEB plans are neither multiemployer nor multiple-employer plans.

The Registrants recognize a pension and OPEB mark-to-market adjustment for the change in fair value of plan assets and net actuarial gains and losses annually in the fourth quarter of each fiscal year and whenever a plan is determined to qualify for remeasurement.

FirstEnergy does not currently expect to have a required contribution to the pension plan until 2027, which, based on various assumptions, is currently expected to be less than $300 million. However, FirstEnergy may elect to contribute to the pension plan voluntarily. FE PA and JCP&L are not expected to make a contribution to the pension plan.

FirstEnergy’s cash flows from operating activities for the nine months ended September 30, 2026, and 2025, include approximately $33 million and $38 million, respectively, of employee benefit plan funding and related payments. FE PA’s cash flows from operating activities for the nine months ended September 30, 2026, and 2025, include approximately $4 million and $4 million, respectively, of employee benefit plan funding and related payments. JCP&L did not have any employee benefit plan funding and related payments for the nine months ended September 30, 2026, and 2025. These payments are primarily related to short-term benefit payment liabilities owed to retirees under plan obligations in the respective periods.

Service costs, net of capitalization, are reported within “Other operating expenses” on the Registrants’ Consolidated Statements of Income and Comprehensive Income. Non-service costs, other than the pension and OPEB mark-to-market adjustment, which is separately shown, are reported within “Miscellaneous income, net”, within “Other income (expense)” on the Registrants’ Consolidated Statements of Income and Comprehensive Income.

FirstEnergy

The components of FirstEnergy’s net periodic benefit costs (credits) for pension and OPEB were as follows:


FirstEnergy Components of Net Periodic Benefit Costs (Credits)	Pension	OPEB
For the Three Months Ended September 30,	2026		2025		2026		2025
	(In millions)
Service costs	$	33			$	33		$	1	$	1
Interest costs	87			93			4		5
Expected return on plan assets	(114)			(115)			(10)		(9)
Amortization of prior service costs (credits)	—			1			—		(1)


Net periodic benefit costs (credits)	$	6			$	12		$	(5)	$	(4)
Net periodic benefit credits, net of amounts capitalized	$	(14)			$	(6)		$	(6)	$	(4)


Components of Net Periodic Benefit Costs (Credits)	Pension	OPEB
For the Nine Months Ended September 30,	2026		2025		2026		2025
	(In millions)
Service costs	$	98			$	98		$	2	$	2
Interest costs	261			280			13		15
Expected return on plan assets	(343)			(345)			(31)		(28)
Amortization of prior service costs (credit)	—			1			—		(1)



Net periodic benefit costs (credits)	$	16			$	34		$	(16)	$	(12)
Net periodic benefit credits, net of amounts capitalized	$	(42)			$	(19)		$	(17)	$	(13)

FE PA

FE PA recognizes its allocated portion of the expected cost of providing pension and OPEB to employees and their beneficiaries and covered dependents from the time employees are hired until they become eligible to receive those benefits. FE PA also recognizes its allocated portion of obligations to former or inactive employees after employment, but before retirement, for disability-related benefits.

FE PA’s net periodic benefit costs (credits) for pension and OPEB were as follows:


FE PA Net Periodic Benefit Costs (Credits)	Pension		OPEB
For the Three Months Ended September 30,	2026		2025	2026		2025
	(In millions)
FE PA’s share of net periodic benefit credits(1)	$	(6)		$	(4)		$	(1)	$	(1)
Allocated net periodic benefit costs from affiliates(1) (2)	$	4		$	4		$	—	$	—

For the Nine Months Ended September 30,
FE PA's share of net periodic benefit credits(1)	$	(17)		$	(13)		$	(4)	$	(3)
Allocated net periodic benefit costs from affiliates(1) (2)	$	12		$	13		$	1	$	1

(1) Includes amounts capitalized.

(2) In addition to the net periodic benefit costs for its current and former employees and retirees, FE PA is also allocated pension and OPEB net periodic benefit costs and credits from its affiliates, primarily FESC.

JCP&L

JCP&L recognizes its allocated portion of the expected cost of providing pension and OPEB to employees and their beneficiaries and covered dependents from the time employees are hired until they become eligible to receive those benefits. JCP&L also recognizes its allocated portion of obligations to former or inactive employees after employment, but before retirement, for

disability-related benefits.

JCP&L’s net periodic benefit costs (credits) for pension and OPEB were as follows:


JCP&L Net Periodic Benefit Costs (Credits)	Pension		OPEB
For the Three Months Ended September 30,	2026		2025	2026		2025
	(In millions)
JCP&L's share of net periodic benefit credits(1)	$	(2)		$	(1)		$	(4)	$	(4)
Allocated net periodic benefit costs from affiliates(1) (2)	$	2		$	2		$	—	$	—

For the Nine Months Ended September 30,
JCP&L's share of net periodic benefit credits(1)	$	(6)		$	(3)		$	(13)	$	(11)
Allocated net periodic benefit costs from affiliates(1) (2)	$	6		$	7		$	—	$	—

(1) Includes amounts capitalized.

(2) In addition to the net periodic benefit costs for its current and former employees and retirees, JCP&L is also allocated pension and OPEB net periodic benefit costs and credits from its affiliates, primarily FESC.

5. INCOME TAXES

The disclosures in this note apply to all Registrants, unless indicated otherwise.

The Registrants’ interim effective income tax rates reflect the estimated annual effective income tax rates for 2026 and 2025. These tax rates are affected by estimated annual permanent items, such as AFUDC equity and other flow-through items, as well as certain discrete items.

The following table reconciles the FirstEnergy effective income tax rate to the federal income tax statutory rate for the three and nine months ended September 30, 2026, and 2025:


FirstEnergy	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
(In millions)	2026		2025		2026		2025
	Amount		%		Amount		%		Amount		%		Amount		%
Income before income taxes	$	684					$	610					$	1,732				$	1,556
Federal statutory income tax	$	143			21.0	%		$	128			21.0	%		$	364		21.0	%	$	327	21.0	%
Federal:
Tax credits	—			—	%		(1)			(0.2)	%		(7)			(0.4)	%	(2)		(0.1)	%
Nontaxable and Nondeductible:
AFUDC equity income	(7)			(1.0)	%		(6)			(1.0)	%		(20)			(1.2)	%	(16)		(1.0)	%
AFUDC equity depreciation	1			0.1	%		1			0.2	%		3			0.2	%	2		0.1	%
Tax related to FE's equity investment in FET	4			0.6	%		4			0.7	%		14			0.8	%	12		0.8	%

Other:
Excess deferred tax amortization	(22)			(3.2)	%		(8)			(1.3)	%		(48)			(2.8)	%	(33)		(2.1)	%
Remeasurement of excess deferred income taxes	—			—	%		(70)			(11.5)	%		—			—	%	(70)		(4.5)	%
Federal and state related flow-through	(14)			(2.0)	%		(9)			(1.5)	%		(26)			(1.5)	%	(20)		(1.3)	%
Deferred taxes associated with FET Equity Interest Sale	—			—	%		6			1.0	%		—			—	%	6		0.4	%
Other	(4)			(0.5)	%		(1)			(0.2)	%		4			0.1	%	(4)		(0.3)	%
Changes in unrecognized tax benefits	(69)			(10.1)	%		—			—	%		(80)			(4.6)	%	—		—	%
State and municipal income taxes, net of federal effect (1)	37			5.4	%		34			5.6	%		95			5.5	%	90		5.8	%
Total income taxes (2)	$	69			10.1	%		$	78			12.8	%		$	299		17.3	%	$	292	18.8	%

(1) Pennsylvania makes up the majority of FirstEnergy’s domestic state income taxes, net of federal effect.

(2) There were no amounts for the three and nine months ended September 30, 2026, or 2025, related to cross-border tax laws, changes in laws or rates, changes in valuation allowance, or foreign tax effects.

The following table reconciles the FE PA effective income tax rate to the federal income tax statutory rate for the three and nine months ended September 30, 2026 and 2025:


FE PA	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
(In millions)	2026		2025		2026		2025
	Amount		%		Amount		%		Amount		%		Amount		%
Income before income taxes	$	192					$	166					$	529				$	509
Federal statutory income tax	$	40			21.0	%		$	35			21.0	%		$	111		21.0	%	$	107	21.0	%
Federal:
Tax credits	—			—	%		—			—	%		—			—	%	(1)		(0.2)	%
Nontaxable and Nondeductible -
AFUDC equity income	—			—	%		—			—	%		(1)			(0.2)	%	(1)		(0.2)	%


Other -
Excess deferred tax amortization	(6)			(3.1)	%		(2)			(1.2)	%		(11)			(2.1)	%	(5)		(1.0)	%

Federal and state related flow-through	(17)			(8.9)	%		(9)			(5.4)	%		(27)			(5.1)	%	(17)		(3.3)	%
Other	(3)			(1.7)	%		(2)			(1.1)	%		(1)			(0.2)	%	(1)		(0.2)	%
Changes in unrecognized tax benefits	—			—	%		—			—	%		(1)			(0.2)	%	—		—	%
State income taxes, net of federal effect (1)	11			5.7	%		10			6.0	%		31			5.9	%	32		6.3	%
Total income taxes (2)	$	25			13.0	%		$	32			19.3	%		$	101		19.1	%	$	114	22.4	%

(1) Pennsylvania makes up FE PA's domestic state income taxes, net of federal effect.

(2) There were no amounts for the three and nine months ended September 30, 2026 and 2025, for FE PA related to changes in valuation allowances, cross-border tax laws, changes in laws or rates, or foreign tax effects.

The following table reconciles the JCP&L effective income tax rate to the federal income tax statutory rate for the three and nine months ended September 30, 2026, and 2025:


JCP&L	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
(In millions)	2026		2025		2026		2025
	Amount		%		Amount		%		Amount		%		Amount		%
Income before income taxes	$	158					$	158					$	351				$	303
Federal statutory income tax	$	33			21.0	%		$	33			21.0	%		$	74		21.0	%	$	64	21.0	%
Federal:
Tax credits	—			—	%		—			—	%		(1)			(0.3)	%	—		—	%
Nontaxable and Nondeductible:
AFUDC equity income	(1)			(0.6)	%		(2)			(1.3)	%		(4)			(1.1)	%	(2)		(0.7)	%


Other:
Excess deferred tax amortization	(4)			(2.6)	%		(1)			(0.6)	%		(7)			(2.0)	%	(3)		(1.0)	%
Federal and state related flow-through	(1)			(0.6)	%		1			0.6	%		(1)			(0.3)	%	(3)		(1.0)	%
Other	(2)			(1.4)	%		(2)			(1.4)	%		(2)			(0.5)	%	(1)		(0.2)	%

State income taxes, net of federal effect (1)	11			7.0	%		11			7.0	%		25			7.1	%	21		7.0	%
Total income taxes (2)	$	36			22.8	%		$	40			25.3	%		$	84		23.9	%	$	76	25.1	%

(1) New Jersey makes up JCP&L’s domestic state income taxes, net of federal effect.

For federal income tax purposes, FE files a consolidated tax return, which includes JCP&L and FE PA, but excludes FET and its subsidiaries, and maintains an intercompany income tax allocation agreement for the allocation of consolidated tax liability, including corporate AMT. Subsequent to the closing of the FET Equity Interest Sale, FET and its subsidiaries file as their own consolidated group for federal income tax purposes and have their own intercompany income tax allocation agreement.

In the third quarter of 2026, FirstEnergy recognized a state tax benefit of approximately $69 million due to an uncertain tax position being effectively settled.

On February 18, 2026, the U.S. Treasury and IRS issued guidance that allows certain tax repair deductions in computing corporate AMT. As a result of this guidance, FirstEnergy reversed $18 million in corporate AMT credit carryforwards in the first quarter of 2026 related to corporate AMT incurred and paid in prior tax years by both the FE consolidated tax group and the FET consolidated tax group, none of which had an impact to the effective tax rate. Both the FE consolidated tax group and the FET consolidated tax group remain subject to the corporate AMT, but expect that this allowance for certain tax repair deductions will reduce future corporate AMT liability.

On July 4, 2025, President Trump signed into law the OBBBA, which makes permanent certain corporate tax incentives from the TCJA but which are not expected to materially impact FirstEnergy. The OBBBA also accelerates the phase out of tax credits for wind and solar projects and, accordingly, FirstEnergy is evaluating potential impacts those tax credit provisions and related IRS guidance may have on the proposed construction of solar generation facilities in West Virginia, as discussed in Note 9., “Regulatory Matters,” of the Combined Notes to Financial Statements of the Registrants.

During 2025, FERC issued orders to a non-affiliate concluding that, based on certain previously issued IRS private letter rulings, certain NOL carryforward deferred tax assets, as computed on a separate return basis, should be included in rate base for ratemaking purposes. FirstEnergy determined in the third quarter of 2025 that these rulings and orders also would apply to certain of its subsidiaries, resulting in a benefit from a reduction in regulatory liabilities, reflected as the remeasurement of excess deferred income taxes and an increase in accumulated deferred income tax assets for ratemaking purposes. FirstEnergy made the appropriate updates in its annual formula rates for the impacted subsidiaries.

FirstEnergy will continue to monitor and evaluate future tax legislation, guidance from the U.S. Treasury and/or the IRS, including guidance related to the corporate AMT, and developments concerning the regulatory treatment of income taxes by FERC and/or applicable state regulatory authorities, that could negatively impact the Registrants’ cash flows, results of operations and financial condition.

6. FAIR VALUE MEASUREMENTS

The disclosures in this note apply to all Registrants, unless indicated otherwise.

RECURRING FAIR VALUE MEASUREMENTS

Authoritative accounting guidance establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. This hierarchy gives the highest priority to Level 1 measurements and the lowest priority to Level 3 measurements. The three levels of the fair value hierarchy and a description of the valuation techniques are as follows:


Level 1	-	Quoted prices for identical instruments in active markets.

Level 2	-	Quoted prices for similar instruments in active markets.
	-	Quoted prices for identical or similar instruments in markets that are not active.
	-	Model-derived valuations for which all significant inputs are observable market data.

Models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors and current market and contractual prices for the underlying instruments, as well as other relevant economic measures.


Level 3	-	Valuation inputs are unobservable and significant to the fair value measurement.

FirstEnergy produces a long-term power and capacity price forecast annually with periodic updates as market conditions change. When underlying prices are not observable, prices from the long-term price forecast are used to measure fair value.

FTRs are financial instruments that entitle the holder to a stream of revenues (or charges) based on the hourly day-ahead congestion price differences across transmission paths. FTRs are acquired by FirstEnergy in the annual, monthly and long-term PJM auctions and are initially recorded using the auction clearing price less cost. After initial recognition, FTRs’ carrying values are periodically adjusted to fair value using a mark-to-model methodology, which approximates market. The primary inputs into the model, which are generally less observable than objective sources, are the most recent PJM auction clearing prices and the FTRs’ remaining hours. The model calculates the fair value by multiplying the most recent auction clearing price by the remaining FTR hours less the prorated FTR cost. Significant increases or decreases in inputs in isolation may result in a higher or lower fair value measurement.

The Registrants primarily apply the market approach for recurring fair value measurements using the best information available. Accordingly, the Registrants maximize the use of observable inputs and minimize the use of unobservable inputs. There were no changes in valuation methodologies used as of September 30, 2026, from those used as of December 31, 2025. The

determination of the fair value measures takes into consideration various factors, including but not limited to, nonperformance risk, counterparty credit risk and the impact of credit enhancements (such as cash deposits, LOCs and priority interests). The impact of these forms of risk was not significant to the fair value measurements.

The following table sets forth the recurring assets and liabilities that are accounted for at fair value by level within the fair value hierarchy as of September 30, 2026, and December 31, 2025. The balances attributable to FE PA were not material as of September 30, 2026, and December 31, 2025.


	September 30, 2026		December 31, 2025
FirstEnergy	Level 1		Level 2		Level 3		Total	Level 1		Level 2	Level 3		Total
Assets	(In millions)
Derivative assets FTRs(1)	$	—			$	—		$	43		$	43			$	—		$	—	$	21	$	21

Equity securities	2			—			—		2		2			—			—		2


Debt securities(2)	—			276			—		276		—			280			—		280
Cash, cash equivalents and restricted cash(3)	132			—			—		132		99			—			—		99
Other(4)	—			50			—		50		—			56			—		56
Total assets	$	134			$	326		$	43		$	503			$	101		$	336	$	21	$	458

Liabilities

Derivative liabilities FTRs(1)	$	—			$	—		$	(13)		$	(13)			$	—		$	—	$	(1)	$	(1)


Total liabilities	$	—			$	—		$	(13)		$	(13)			$	—		$	—	$	(1)	$	(1)

Net assets	$	134			$	326		$	30		$	490			$	101		$	336	$	20	$	457

(1) Contracts are subject to regulatory accounting treatment and changes in market values do not impact earnings.

(2) Related to JCP&L’s investments held in the spent nuclear fuel disposal trusts as further discussed below.

(3) Includes restricted cash of $84 million and $42 million as of September 30, 2026, and December 31, 2025, respectively, primarily related to cash of $25 million and $40 million, respectively, collected from MP, PE and the Ohio Companies’ customers that is specifically used to service debt of their respective funding companies, and $55 million related to ZECs at JCP&L as of September 30, 2026.

(4) Primarily consists of short-term investments, of which $10 million and $17 million as of September 30, 2026, and December 31, 2025, respectively, are held by JCP&L.

INVESTMENTS

All temporary cash investments purchased with an initial maturity of three months or less are reported as cash equivalents on the Consolidated Balance Sheets at cost, which approximates their fair market value. Investments other than cash and cash equivalents include AFS debt securities and other investments. The Registrants have no debt securities held for trading purposes.

Generally, unrealized gains and losses on equity securities are recognized in income whereas unrealized gains and losses on AFS debt securities are recognized in AOCI. However, the JCP&L spent nuclear fuel disposal trusts are subject to regulatory accounting with all gains and losses on equity and AFS debt securities offset against regulatory assets.

Spent Nuclear Fuel Disposal Trusts

FirstEnergy, through JCP&L, holds debt securities within the spent nuclear fuel disposal trusts, which are classified as AFS securities, recognized at fair market value. The trust is intended for funding spent nuclear fuel disposal fees to the DOE associated with the previously owned Oyster Creek and Three Mile Island Unit 1 nuclear power facilities.

The following table summarizes the amortized cost basis, unrealized gains, unrealized losses and fair values of investments held in spent nuclear fuel disposal trusts as of September 30, 2026, and December 31, 2025:


	September 30, 2026(1)		December 31, 2025(2)
	Cost Basis		Unrealized Gains	Unrealized Losses		Fair Value	Cost Basis		Unrealized Gains	Unrealized Losses		Fair Value
	(In millions)

Debt securities	$	303		$	—		$	(27)		$	276		$	290	$	2	$	(12)	$	280

(1) Excludes short-term cash investments of $10 million as of September 30, 2026.

(2) Excludes short-term cash investments of $17 million as of December 31, 2025.

Proceeds from the sale of investments in AFS debt securities, realized losses on those sales and interest and dividend income for the three and nine months ended September 30, 2026, and 2025, were as follows for FirstEnergy and JCP&L. There were no realized gains on sales of AFS debt securities during these periods. FE PA had no such activity during the periods.














	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
	2026		2025		2026	2025
	(In millions)
Sale proceeds	$	9			59		$	42		$	89

Realized losses	(1)			(6)		(4)			(9)
Interest and dividend income	4			4		10			10

Other Investments

The Registrants’ other investments include but are not limited to employee benefit trusts, which are primarily invested in corporate-owned life insurance policies, and equity method investments. Earnings and losses associated with corporate-owned life insurance policies and equity method investments are reflected in the “Miscellaneous Income, net” line on the Registrants’ Consolidated Statements of Income and Comprehensive Income, as applicable. See Note 1., \"Organization and Basis of Presentation,\" of the Combined Notes to Financial Statements of the Registrants for additional information on FirstEnergy's equity method investments.

FirstEnergy - Earnings and losses associated with corporate-owned life insurance policies were less than $1 million and $8 million for the three months ended September 30, 2026, and 2025, respectively, and $10 million and $17 million for the nine months ended September 30, 2026, and 2025, respectively. Other investments were $333 million and $344 million as of September 30, 2026, and December 31, 2025, respectively, and are excluded from the amounts reported in the recurring fair value measurements and the AFS securities tables above.

FE PA - Earnings and losses associated with corporate-owned life insurance policies were immaterial for the three and nine months ended September 30, 2026, and 2025. Other investments were $13 million and $12 million as of September 30, 2026, and December 31, 2025, respectively, and are excluded from the amounts reported in the recurring fair value measurements and the AFS securities tables above.

JCP&L - Earnings and losses associated with corporate-owned life insurance policies were immaterial for the three and nine months ended September 30, 2026 and 2025. Other investment balances associated with corporate-owned life insurance policies were immaterial as of September 30, 2026 and December 31, 2025.

LONG-TERM DEBT AND OTHER OBLIGATIONS

All borrowings with initial maturities of less than one year are defined as short-term financial instruments under GAAP and are reported as “Short-term borrowings” on the Registrants’ Balance Sheets at cost. Since these borrowings are short-term in nature, the Registrants believe that their costs approximate their fair market value. The following table provides the approximate fair value and related carrying amounts of long-term debt, which excludes finance lease obligations and net unamortized debt issuance costs, unamortized fair value adjustments, premiums and discounts as of September 30, 2026, and December 31, 2025:


	September 30, 2026		December 31, 2025
Registrant	Carrying value		Fair value	Carrying value		Fair value
	(In millions)
FirstEnergy	$	28,245		$	26,187		$	26,390	$	25,756
FE PA	$	4,300		$	3,872		$	3,750	$	3,514
JCP&L	$	3,400		$	3,194		$	3,050	$	3,059

The fair values of long-term debt and other long-term obligations reflect the present value of the cash outflows relating to those securities based on the current call price, the yield to maturity or the yield to call, as deemed appropriate at the end of each respective period. The yields assumed were based on securities with similar characteristics offered by corporations with credit ratings similar to those of the Registrants. The Registrants classified short-term borrowings, long-term debt and other long-term obligations as Level 2 in the fair value hierarchy as of September 30, 2026, and December 31, 2025.

The following table summarizes the redemptions and issuances of the Registrants and their subsidiaries, as applicable, during the nine months ended September 30, 2026:

Company

Type

Redemption / Issuance Date

Interest Rate

Maturity

Amount

(In millions)

Description

Redemptions

FE PA

Senior Unsecured

March, 2026

5.15%

2026

$300

Redeemed senior unsecured notes that became due.

ATSI(1)

Senior Unsecured

April, 2026

4.00%

2026

$75

Redeemed senior unsecured notes that became due.

Senior Unsecured Convertible Notes

May, 2026

4.00%

2026

$294

Redeemed senior unsecured convertible notes that became due.

Issuances

FE PA

Senior Unsecured

March, 2026

4.15%

2028

$300

Proceeds were used to: (i) refinance existing indebtedness, including the repayment of FE PA's 5.15% senior notes due 2026, and short-term borrowings; (ii) to fund capital expenditures; (iii) to fund working capital; and (iv) to fund general corporate purposes.

FE PA

Senior Unsecured

March, 2026

4.55%

2031

$550

MAIT(1)

Senior Unsecured

April, 2026

5.02%

2036

$250

Proceeds were used to: (i) repay short-term borrowings; (ii) to finance capital expenditures; (iii) to fund working capital; and (iv) to fund other general corporate purposes.

ATSI(1)

Senior Unsecured

April, 2026

5.19%

2033

$175

Proceeds were used to: (i) repay short-term borrowings, including short-term borrowings incurred to repay at maturity $75 million aggregate principal amount of ATSI's 4.00% senior unsecured notes due 2026; (ii) to finance capital expenditures; (iii) to fund working capital; and (iv) to fund general corporate purposes.

JCP&L

Senior Unsecured

May, 2026

4.60%

2030

$350

Proceeds were used to: (i) repay short-term borrowings; (ii) to finance capital expenditures; (iii) to fund working capital; and (iv) to fund general corporate purposes.

FMB

May, 2026

4.45%

2029

$300

Proceeds were used to: (i) repay short-term borrowings; (ii) to finance capital expenditures; (iii) to fund working capital; and (iv) to fund general corporate purposes.

CEI

Senior Unsecured

August, 2026

5.00%

2030

$500

Proceeds were used to: (i) repay short-term borrowings; (ii) to fund capital expenditures; (iii) to fund working capital; and (iv) to fund general corporate purposes.

(1) A wholly owned subsidiary of FET

FE Term Loan Facility

On April 28, 2026, FE entered into the $750 million FE Term Loan Facility with a maturity date of April 27, 2027, which was fully drawn upon execution. The FE Term Loan Facility contains covenants and other terms and conditions substantially similar to those applicable to FE under the Amended Credit Facilities, including the same requirement to maintain a consolidated interest coverage ratio of not less than 2.50 times, measured at the end of each fiscal quarter for the last four fiscal quarters. Proceeds were used to repay short-term borrowings outstanding under the Amended Credit Facilities.

PE Term Loan Facility

On June 16, 2026, PE entered into a $150 million PE Term Loan Facility, with a maturity date of September 16, 2027, which was fully drawn upon execution. The PE Term Loan Facility contains covenants and other terms and conditions substantially similar to those applicable to PE under the Amended Credit Facilities and includes a requirement to maintain a debt to capitalization ratio of no more than 0.65 to 1.00, measured as of the last day of each fiscal quarter. Proceeds were used to repay short-term borrowings, to finance capital expenditures, for working capital and for other general corporate purposes.

Loans (as defined in the PE Term Loan Facility) bear interest at a fluctuating interest rate per annum equal to the sum of 0.70% per annum plus the Term SOFR Rate for such interest period. Borrowings under the PE Term Loan Facility that are RFR Loans (as defined in the PE Term Loan Facility) bear interest at a fluctuating interest rate per annum equal to the sum of 0.70% per annum plus Daily Simple SOFR.

Borrowings under the PE Term Loan Facility are subject to acceleration upon the occurrence of events of default, including a cross-default to other indebtedness of FE in excess of $100 million and defaults for certain bankruptcy or insolvency events of FE or its significant subsidiaries.

FE maintains an ordinary banking and investment banking relationship with the lender under the PE Term Loan Facility.

2026 Convertible Notes Issuance and Conversion:

On May 4, 2023, FE issued $1.5 billion aggregate principal amount of 2026 Convertible Notes, at a rate of 4.00% per year, payable semiannually. The 2026 Convertible Notes were unsecured and unsubordinated obligations of FE, and were scheduled to mature on May 1, 2026, unless required to be converted or repurchased in accordance with their terms. Proceeds from the issuance were approximately $1.48 billion, net of issuance costs.

In June 2025, FE repurchased approximately $1.2 billion aggregate principal amount of the 2026 Convertible Notes, using a portion of the proceeds from the offering of the 2029 Convertible Notes and 2031 Convertible Notes described below.

On May 1, 2026, FE paid approximately $325 million in cash to satisfy and settle the then-outstanding 2026 Convertible Notes, consisting of $294 million in aggregate principal amount, $6 million of accrued and unpaid interest, and approximately $25 million, representing the conversion premium paid in excess of the aggregate principal amount.

2029 Convertible Notes and 2031 Convertible Notes Issuance

On June 12, 2025, FE issued $1.35 billion aggregate principal amount of its 2029 Convertible Notes, at a rate of 3.625% per year, and $1.15 billion aggregate principal amount of its 2031 Convertible Notes, at a rate of 3.875% per year, payable semiannually. The 2029 Convertible Notes and 2031 Convertible Notes are unsecured and unsubordinated obligations of FE and will mature on January 15, 2029 and January 15, 2031, respectively, unless earlier converted or repurchased in accordance with their terms.

The 2029 Convertible Notes and 2031 Convertible Notes are included within “Long-term debt and other long-term obligations” on the FirstEnergy Consolidated Balance Sheets. Proceeds from the issuance were approximately $2.47 billion, net of issuance costs.

Holders may convert the 2029 Convertible Notes and 2031 Convertible Notes at their option at any time prior to the close of business on the business day immediately preceding: (i) October 15, 2028, with respect to the 2029 Convertible Notes, and (ii) October 15, 2030, with respect to the 2031 Convertible Notes, only under certain conditions:

•During any calendar quarter, if the last reported sale price of FE’s common stock for at least 20 trading days during the period of 30 consecutive trading days ending on, and including, the last trading day of the immediately preceding calendar quarter is greater than or equal to 130% of the conversion price on each applicable trading day;

•During the five consecutive business day period immediately after any 10 consecutive trading day period in which the trading price per $1,000 principal amount of the 2029 Convertible Notes and 2031 Convertible Notes for each trading day of such 10 trading-day period was less than 98% of the product of the last reported sale price of FE’s common stock and the conversion rate on each such trading day; or

•Upon the occurrence of certain corporate events specified in the indenture governing the 2029 Convertible Notes and 2031 Convertible Notes.

On or after October 15, 2028, in the case of the 2029 Convertible Notes, and on or after October 15, 2030, in the case of the 2031 Convertible Notes, until the close of business on the second scheduled trading day immediately preceding the maturity date of the relevant series of notes, holders may convert all or any portion of their notes of such series at any time, regardless of the foregoing conditions. FE will settle conversions of such notes by paying cash up to the aggregate principal amount of the notes to be converted and paying or delivering, as the case may be, cash, shares of its common stock or a combination of cash and shares of its common stock, at its election, in respect of the remainder, if any, of its conversion obligation in excess of the aggregate principal amount of the notes being converted, subject to the applicable terms of the indentures.

The conversion rate for each of the series of notes will initially be 20.9275 shares of FE’s common stock per $1,000 principal amount of such notes (equivalent to an initial conversion price of approximately $47.78 per share of FE’s common stock). The initial conversion price of such notes represents a premium of approximately 20% over the last reported sale price of FE’s common stock on the New York Stock Exchange on June 9, 2025. The conversion rate and the corresponding conversion price will be subject to adjustment in some events but will not be adjusted for any accrued and unpaid interest. In addition, following certain corporate events that occur prior to the maturity date with respect to a series of notes (and, in the case of the 2031 Convertible Notes, if FE delivers a notice of redemption with respect to the 2031 Convertible Notes), FE will, in certain

circumstances, increase the conversion rate for a holder who elects to convert its notes of such series in connection with such corporate event or redemption as applicable.

FE may not redeem the 2029 Convertible Notes prior to the maturity date of the 2029 Convertible Notes. On or after January 15, 2029 and prior to the 40th trading day immediately before the maturity date of the 2031 Convertible Notes, FE may redeem for cash all or any portion of the 2031 Convertible Notes, subject to certain partial redemption limitations and only under certain conditions.

If FE undergoes a fundamental change (as defined in the relevant indenture), subject to certain conditions, holders of the 2029 Convertible Notes and/or 2031 Convertible Notes may require FE to repurchase for cash all or any portion of their notes at a repurchase price equal to 100% of the principal amount of the convertible notes to be repurchased, plus accrued and unpaid interest to, but excluding, the fundamental change repurchase date (as defined in the relevant indenture).

FE or its affiliates may, from time to time, seek to retire or purchase outstanding debt through open-market purchases, privately negotiated transactions or otherwise. Such repurchases, if any, will be upon such terms and at such prices as FE or its affiliates may determine, and will depend on prevailing market conditions, liquidity requirements, contractual restrictions and other factors.

JCP&L Senior Notes and Registration Rights

On September 4, 2025, JCP&L issued: (i) $350 million of senior unsecured notes due in 2029; (ii) $500 million of senior unsecured notes due in 2031; and (iii) $500 million of senior unsecured notes due in 2036, in a private offering that included registration rights agreements in which JCP&L agreed to conduct an exchange offer of these senior notes for the like principal amounts registered under the Securities Act. On April 9, 2026, JCP&L filed a registration statement on Form S-4 for the exchange offer with the SEC, which was declared effective on April 23, 2026. On June 15, 2026, JCP&L completed an exchange offer of these senior notes for like principal amounts registered under the Securities Act.

In May 2026, JCP&L issued $350 million of new 4.60% Senior Unsecured Notes due in 2030 in a private offering that included a registration rights agreement in which JCP&L agreed to conduct an exchange offer of these senior notes for the like principal amounts registered under the Securities Act within 366 days after the closing. Proceeds were used to repay short-term borrowings, to finance capital expenditures, for working capital and for other general corporate purposes. On June 25, 2026, JCP&L filed a registration statement on Form S-4 for the exchange offer with the SEC, which was declared effective on July 14, 2026, and an exchange offer was launched on July 16, 2026. The exchange offer was settled on August 17, 2026.

FE PA Senior Notes and Registration Rights

On March 19, 2026, FE PA issued $300 million of 4.15% senior unsecured notes due in 2028 and $550 million of 4.55% senior unsecured notes due in 2031, in a private offering that included registration rights agreements in which FE PA agreed to conduct an exchange offer of these senior notes for the like principal amounts registered under the Securities Act within 366 days after the closing. On September 1, 2026, FE PA filed a registration statement on Form S-4 with the SEC, which became effective on September 15, 2026, and an exchange offer was launched on September 17, 2026, which is scheduled to close on October 30, 2026.

Shelf Registration Statement

On May 29, 2026, FE filed a shelf registration statement on Form S-3 registering up to $3 billion in aggregate amount of securities, which was declared effective by the SEC on June 15, 2026.

7. VARIABLE INTEREST ENTITIES

The disclosures in this note apply to all Registrants, unless indicated otherwise.

The Registrants perform qualitative analyses to determine whether a variable interest qualifies them as the primary beneficiary (a controlling financial interest) of a VIE. An enterprise has a controlling financial interest if it has both: (i) the power to direct the activities of a VIE that most significantly impact the entity’s economic performance; and (ii) the obligation to absorb losses of the entity that could potentially be significant to the VIE or the right to receive benefits from the entity that could potentially be significant to the VIE. The Registrants consolidate a VIE when it is determined that it is the primary beneficiary. FE PA and JCP&L do not have any consolidated or unconsolidated VIEs.

In order to evaluate contracts for consolidation treatment and entities for which FirstEnergy has an interest, FirstEnergy aggregates variable interests into categories based on similar risk characteristics and significance.

FirstEnergy - Consolidated VIEs

VIEs in which FirstEnergy is the primary beneficiary consist of the following, and are included in FirstEnergy’s consolidated financial statements:

•Securitization Companies

•Ohio Securitization Companies - In June 2013, the SPEs formed by the Ohio Companies issued approximately $445 million of pass-through trust certificates supported by phase-in recovery bonds to securitize the recovery of certain all-electric customer heating discounts, fuel and purchased power regulatory assets. The phase-in recovery bonds are payable only from, and secured by, phase-in recovery property owned by the SPEs. The bondholders have no recourse to the general credit of FirstEnergy or any of the Ohio Companies. Each of the Ohio Companies, as servicer of its respective SPE, manages and administers the phase in recovery property including the billing, collection and remittance of usage-based charges payable by retail electric customers. The SPEs are considered VIEs and each one is consolidated into its applicable electric company. As of September 30, 2026, and December 31, 2025, $142 million and $159 million of the phase-in recovery bonds were outstanding, respectively.

•MP and PE Environmental Funding Companies - The consolidated financial statements of FirstEnergy include environmental control bonds issued by two bankruptcy remote, special purpose limited liability companies that are indirect subsidiaries of MP and PE. Proceeds from the bonds were used to construct environmental control facilities. Principal and interest owed on the environmental control bonds is secured by, and payable solely from, the proceeds of the environmental control charges. Creditors of FirstEnergy, other than the limited liability company SPEs, have no recourse to any assets or revenues of the special purpose limited liability companies. As of September 30, 2026, and December 31, 2025, $122 million and $156 million of environmental control bonds were outstanding, respectively.

•FirstEnergy’s Consolidated Balance Sheets include restricted cash of $25 million and $40 million, respectively, as of September 30, 2026, and December 31, 2025, which is related to cash collected from MP, PE and the Ohio Companies' customers that is specifically used to service debt of their respective funding companies.

•FET

•FET is a holding company that owns equity interests in ATSI, MAIT, and TrAIL. As further discussed above, on February 2, 2023, FE entered into an agreement with Brookfield to sell an incremental 30% equity interest in FET, which closed on March 25, 2024. As of September 30, 2026, FE’s equity ownership in FET is 50.1% and Brookfield’s is 49.9%. FirstEnergy has concluded that FET is a VIE and that FE is the primary beneficiary because FE has exposure to the economics of FET and the power to direct significant activities of FET through the FESC services agreement, which represents a separate variable interest.

•Although Brookfield was granted incremental consent rights upon the closing of the FET Equity Interest Sale, Brookfield will not have unilateral control over any activities that most significantly impact FET’s economic performance. However, FE will continue to retain power over the activities that most significantly impact FET’s economic performance through its incremental decision-making rights under the existing FESC services agreement, through which executive management and workforce services are provided to FET. As a result, FE is the primary beneficiary of FET, which will continue to be consolidated in FirstEnergy’s financial statements.

•The assets of FET can only be used to settle its obligations, and creditors of FET do not have recourse to the general credit of FirstEnergy.

FirstEnergy - Unconsolidated VIEs

•Valley Link - Investment balances as of September 30, 2026, and earnings during the first nine months of 2026 related to Valley Link were immaterial. See Note 1., \"Organization and Basis of Presentation – Equity Method Investments,” of the Combined Notes to Financial Statements of the Registrants for additional information related to Valley Link.

•Grid Growth - There were no investment balances as of September 30, 2026, and no earnings were recognized during the first nine months of 2026 related to Grid Growth. See Note 1., \"Organization and Basis of Presentation – Equity Method Investments,” of the Combined Notes to Financial Statements of the Registrants for additional information related to Grid Growth.

8. ASSET RETIREMENT OBLIGATIONS

The disclosures in this note apply to all Registrants, unless indicated otherwise.

The Registrants recognize an ARO for their legal obligation to perform asset retirement activities associated with their long-lived assets. The ARO liability represents an estimate of the fair value of the Registrants’ current obligation such that the ARO is accreted monthly to reflect the time value of money.

A fair value measurement inherently involves uncertainty in the amount and timing of settlement of the liability. An expected cash flow approach is used to measure the fair value of the remediation AROs, taking into account the expected timing of settlement of the ARO based on the expected economic useful life of associated assets and/or regulatory requirements. The fair value of an ARO is recognized in the period in which it is incurred. The associated asset retirement costs are capitalized as part of the carrying value of the long-lived asset and are depreciated over the life of the related asset. For instances where asset retirement costs relate to assets that have no future cash flows, the costs are recorded as an operating expense. In certain circumstances, the Registrants recover asset retirement costs and, as such, certain accretion and depreciation is offset against regulatory assets. Conditional retirement obligations associated with tangible long-lived assets are recognized at fair value in the period in which they are incurred if a reasonable estimate can be made, even though there may be uncertainty about timing or method of settlement. When settlement is conditional on a future event occurring, it is reflected in the measurement of the liability, not the timing of the liability recognition.

FirstEnergy has recognized applicable legal obligations for AROs and their associated costs, including reclamation of sludge disposal ponds, closure of CCR sites, underground and above-ground storage tanks and wastewater treatment lagoons. In addition, the Registrants have recognized conditional retirement obligations, primarily for asbestos remediation.

The following table summarizes the changes to the Registrants’ ARO balances as of September 30, 2026, and December 31, 2025.


	FirstEnergy		FE PA		JCP&L
	(In millions)
Balance, January 1, 2025	$	455			$	31		$	8
Changes in timing and amount of estimated cash flows	(51)			—			—
Liabilities incurred	1			—			—
Liabilities settled (1)	(154)			(1)			—
Accretion	26			2			—
Balance, December 31, 2025	$	277			$	32		$	8
Changes in timing and amount of estimated cash flows	(10)			—			—

Liabilities settled	(5)			(1)			—
Accretion	19			2			—
Balance, September 30, 2026	$	281			$	33		$	8

(1) FirstEnergy amounts include the transfer of the McElroy’s Run CCR impoundment facility as well as the adjacent dry landfill and related remediation obligations to a subsidiary of IDA Power, LLC.

AE Supply transferred the McElroy’s Run CCR impoundment facility and adjacent dry landfill and related remediation obligations on March 4, 2025, pursuant to the environmental liability transfer agreement dated February 3, 2025, with a subsidiary of IDA Power, LLC. Pursuant to the agreement, AE Supply established a $160 million escrow account that AE Supply will fund over five years and is secured by a surety bond, which is guaranteed by FE. In connection with the transfer, AE Supply recognized a $130 million liability in 2024, based on a 4.8% weighted average discount rate over the contract term, associated with its remaining obligation to fund the escrow account over the next five years, and derecognized the ARO, resulting in an immaterial impact to earnings. As of September 30, 2026, AE Supply has made cumulative cash payments of $68 million to the escrow account since the transfer in 2025.

During 2025 and the second quarter of 2026, FirstEnergy completed engineering studies and field analysis for certain of its legacy CCR disposal sites and determined that certain of those sites did not meet criteria to be applicable to the CCR rules. As a result, during the second quarter of 2026, FirstEnergy recorded a $10 million decrease to its ARO, all of which is included in \"Other operating expenses\" on the Consolidated Statements of Income and Comprehensive Income and was not capitalized as an asset retirement cost since the associated electric generation facilities are closed. See Note 10., “Commitments, Guarantees, and Contingencies - Regulation of Waste Disposal,” of the Combined Notes to Financial Statements of the Registrants.

9. REGULATORY MATTERS

The disclosures in this note apply to FirstEnergy.

Disclosures under “State Regulation,” “Pennsylvania,” “FERC Regulatory Matters,” “Transmission ROE Incentive,” “Transmission ROE Methodology,” “Transmission Planning Supplemental Projects,” “Local Transmission Planning Complaint,” “PJM Capacity Market Reforms,” and “Large Load Interconnection Rulemaking” are applicable to FE PA.

Disclosures under “State Regulation,” “New Jersey,” “FERC Regulatory Matters,” “Transmission ROE Incentive,” “Transmission ROE Methodology,” “Transmission Planning Supplemental Projects,” “Local Transmission Planning Complaint,” “PJM Capacity Market Reforms,” and “Large Load Interconnection Rulemaking” are applicable to JCP&L.

STATE REGULATION

Each of the Electric Companies’ retail rates, conditions of service, issuance of securities and other matters are subject to regulation in the states in which it operates - in Maryland by the MDPSC, in New Jersey by the NJBPU, in Ohio by the PUCO, in Pennsylvania by the PPUC, in West Virginia by the WVPSC and in New York by the NYPSC. The transmission operations of PE and TrAIL in Virginia, ATSI in Ohio, the Transmission Companies in Pennsylvania, PE and MP in West Virginia, and PE in Maryland are subject to certain regulations of the VSCC, PUCO, PPUC, WVPSC, and MDPSC, respectively. In addition, under Ohio law, municipalities may regulate rates of a public utility, subject to appeal to the PUCO if not acceptable to the utility. Further, if any of the FirstEnergy affiliates were to engage in the construction of significant new transmission facilities, depending on the state, they may be required to obtain state regulatory authorization to site, construct and operate the new transmission facility.

MARYLAND

PE operates under MDPSC-approved distribution base rates that were effective as of October 19, 2023, and that were subsequently modified by an MDPSC order dated January 3, 2024, which became effective as of March 1, 2024. PE also provides SOS pursuant to a combination of settlement agreements, MDPSC orders and regulations, and statutory provisions. SOS supply is competitively procured in the form of rolling contracts of varying lengths through periodic auctions that are overseen by the MDPSC and a third-party monitor. Although settlements with respect to SOS supply for PE customers have expired, service continues in the same manner until changed by order of the MDPSC. PE recovers its costs plus a return for providing SOS.

The EmPOWER Maryland program requires electric utilities to achieve specified energy efficiency and greenhouse gas reduction targets, which were modified by the Utility RELIEF Act to reduce certain targets for the 2027-2035 program cycles. PE's revised 2024-2026 EmPOWER plan, with a budget of approximately $314 million, was approved by the MDPSC in December 2024. PE filed its proposed 2027-2029 plan in September 2026. Beginning in 2026, PE is required to expense 100% of EmPOWER program costs as incurred, with previously deferred balances to be recovered through 2030. Legislation effective July 1, 2024 reduced the carrying costs recoverable on unamortized EmPOWER balances. PE challenged the legislation, and in August 2025 the Circuit Court for Washington County, Maryland ruled in PE's favor. The MDPSC and MDOPC appealed the decision, and oral argument before the Appellate Court of Maryland was held on September 4, 2026.

On September 1, 2026, PE filed its proposed large load tariff which would create a separate class of large load customers thereby insulating residential customers from bearing costs associated with the interconnection of large load customers to the electric system.

On September 4, 2026, PE filed with the MDPSC a distribution base rate case seeking to, among other things, increase PE’s Maryland annual base rate distribution revenues by approximately $53 million and approve a proposed three-year program focused on improving reliability. The case uses a historic test year of twelve months ending March 31, 2026, and requested an ROE of 10.6% and capital structure of approximately 54% equity and 46% debt. Evidentiary hearings are scheduled to begin January 11, 2027. A final order and new rates are expected to become effective in the second quarter of 2027.

NEW JERSEY

JCP&L operates under NJBPU approved rates that took effect as of February 15, 2024, and became effective for customers as of June 1, 2024. JCP&L provides BGS for retail customers who do not choose a third-party EGS and for customers of third-party EGSs that fail to provide the contracted service. All New Jersey EDCs participate in this competitive BGS procurement process and recover BGS costs directly from customers as a charge separate from base rates.

equity interest in Mid-Atlantic Offshore Development, LLC. On August 22, 2023, FERC approved an abandonment incentive that allowed recovery of certain prudently incurred project costs if the project were cancelled for reasons beyond JCP&L’s control.

Beginning in late 2023, major offshore wind developments in New Jersey were cancelled or abandoned. In response to these developments, JCP&L sought guidance from the NJBPU in 2025 regarding project scheduling while continuing to meet its contractual obligations. In August 2025, the NJBPU directed JCP&L to defer certain transmission investments for approximately 2.5 years and directed JCP&L to work with NJBPU staff and PJM to ensure alignment as to the work that is to be continued on the original timeline and the work that is to be delayed consistent with the order. Capital investments in the transmission projects totaled approximately $167 million as of September 30, 2026.

On April 22, 2026, the NJBPU issued an order finding that, among other things, continued investment in certain of the transmission infrastructure to connect offshore wind generated electricity to the grid is not in the best interest of the state or its ratepayers. In the order, the NJBPU authorized execution of an agreement with PJM to terminate the identified transmission projects, which it filed at FERC on April 23, 2026. The agreement included provisions to the effect that New Jersey’s ratepayers will remain responsible for JCP&L’s prudently incurred costs for the affected projects and a request for approval by June 23, 2026. On May 14, 2026, JCP&L filed supportive comments at FERC. On June 22, 2026, FERC accepted the termination agreement. On July 2, 2026, PJM notified JCP&L that PJM had terminated the agreements that obligated JCP&L to construct the identified projects. JCP&L expects to file an application for FERC authorization to recover the abandoned project costs.

In February 2025, the NJBPU certified the results of its annual basic generation service auctions through which New Jersey’s four EDCs – including JCP&L – satisfy their generation supply requirements for BGS customers for the period beginning June 1, 2025 through May 31, 2026. The certified results resulted in significant rate increases for New Jersey EDC customers and, by order dated April 23, 2025, the NJBPU directed the four EDCs to submit proposals to mitigate the impact of the rate increases that affected residential customers beginning June 1, 2025. On May 7, 2025, JCP&L filed a petition in response to the April 2025 order, modeling four potential mitigation scenarios. On June 18, 2025, the NJBPU approved a stipulation that provided residential customers with a $30 bill credit in July and August 2025, with JCP&L deferring the cost as a regulatory asset and recovering the amount through customer bill charges from September 2025 through February 2026; the regulatory asset has since been fully recovered.

On August 13, 2025, the NJBPU issued an Order to Show Cause reviewing JCP&L’s 2024 Annual System Performance Report, which includes information regarding JCP&L’s systems level of electric service reliability performance during the prior calendar year. Failure to attain NJBPU’s minimum reliability levels may subject JCP&L to a penalty. The NJBPU order alleges JCP&L has failed to achieve minimum reliability levels for calendar years 2022, 2023, and 2024, and directed JCP&L to file an answer demonstrating why the NJBPU should not impose certain penalties upon JCP&L for such failure, which JCP&L filed on October 10, 2025. On April 13, 2026, NJBPU staff issued a letter to JCP&L stating its intention to recommend that the NJBPU impose a penalty against JCP&L in the amount of $44 million, while also requesting a meeting with JCP&L to discuss the potential penalty recommendation and a possible resolution. On April 16, 2026, JCP&L responded in writing to the NJBPU staff welcoming the opportunity to discuss with NJBPU staff and disputing the magnitude of the recommended penalty and questioning the approach taken by NJBPU staff. JCP&L is engaged in settlement discussions with the parties and had a meeting with the NJBPU staff on July 17, 2026. A pre-hearing conference has been scheduled for October 29, 2026. JCP&L believes it is probable that it will incur a loss, but based on the status of the settlement discussions is unable to estimate the amount of any penalty and/or predict other actions that may be imposed by the NJBPU. On October 20, 2026, the NJBPU opened a new docket to review JCP&L’s attainment of the NJBPU’s minimum reliability levels for calendar year 2025.

On January 14, 2026, the NJBPU issued an order authorizing JCP&L to modify its Lost Revenue Adjustment Mechanism rate rider in its tariff. The modification allows JCP&L to recover the revenue impact of sales losses of approximately $16 million (pre-tax) primarily resulting from the implementation of JCP&L’s EE&C Plan during the one-year period from July 1, 2023, through June 30, 2024. The modification was effective February 1, 2026.

On May 21, 2026, the NJBPU issued an order concluding that certain nuclear generating units participating in the state’s ZEC program received duplicate compensation during 2024, and directed the owners of the affected generating units to refund the duplicate payments, with applicable interest, to the affected EDCs, including JCP&L. The order further directed that the refunded amounts be returned to customers through reinstated ZEC tariffs beginning June 1, 2026. On May 26, 2026, JCP&L received payment in the amount of $82 million. Also on May 26, 2026, JCP&L made the requisite compliance filing with the NJBPU requesting restoration of its ZEC tariff effective June 1, 2026, and began issuing customer refunds. Refunds are expected to continue through May 31, 2027, or until such time as the refunded balance is exhausted. As of September 30, 2026, JCP&L's regulatory liability associated with these amounts to be refunded to customers was approximately $56 million.

On July 15, 2026, the NJBPU issued an order directing a one-year transition period beginning on July 1, 2027, and ending on June 30, 2028, after which New Jersey EDCs would begin a full six-year cycle of energy efficiency programs. JCP&L’s EE&C Plan II ends on June 30, 2027. In accordance with the order, JCP&L filed its proposed transition plan with the NJBPU on September 30, 2026, which seeks to continue JCP&L’s existing cost recovery and lost revenue recovery mechanisms and contemplates a lower ROE for JCP&L’s energy efficiency programs by 150 basis points, at a proposed budget of approximately $178 million. The matter is pending before the NJBPU.

On August 6, 2026, JCP&L filed with the NJBPU a base rate case utilizing a historical test period for the 12 months ending June 30, 2026. JCP&L proposed a net increase in base distribution revenues of approximately $253 million, with an ROE of 10.2% and a capital structure of approximately 47% debt and approximately 53% equity, with an effective date of May 6, 2027. JCP&L has also proposed to offset the increase in rates for residential customers until January 1, 2028, through a new, temporary tax-adjustment rider and amortization of an existing regulatory liability during this period. The filing also proposes a new storm recovery charge rider and requests additional funding for enhanced storm response and expanded vegetation management. The NJBPU has referred the matter to the New Jersey Office of Administrative Law and discovery has begun.

OHIO

The Ohio Companies operated under ESP IV through May 31, 2024, which provided for the supply of power to non-shopping customers at a market-based price set through an auction process. From June 1, 2024, until January 31, 2025, the Ohio Companies operated under ESP V, as modified by the PUCO, and as further described below. On December 18, 2024, the PUCO approved the Ohio Companies’ notice to withdraw ESP V and approved the Ohio Companies’ proposal for returning to ESP IV, with modifications. ESP IV, as modified, continues the DCR rider, which supports continued investment related to the distribution system for the benefit of customers, with an annual revenue cap of $390 million. In addition, ESP IV, as modified, includes a goal across FirstEnergy to reduce CO2 emissions by 90% below 2005 levels by 2045; and contributions, totaling $6.39 million per year, to: (a) fund energy conservation, economic development and job retention programs in the Ohio Companies’ service territories; and (b) establish fuel-funds in each of the Ohio Companies’ service territories to assist low-income customers.

On April 5, 2023, the Ohio Companies filed an application with the PUCO for approval of ESP V, for an eight-year term beginning June 1, 2024, and continuing through May 31, 2032. On May 15, 2024, the PUCO issued an order approving ESP V with modifications, which became effective June 1, 2024, and would have continued through May 31, 2029. The Ohio Companies filed an application for rehearing challenging various aspects of the May 15, 2024, order, but due to the risks and uncertainty resulting from the Ohio Companies’ application for rehearing being denied by operation of law, on October 29, 2024, the Ohio Companies filed a notice of their intent to withdraw ESP V and proposed the terms under which they would resume operating under ESP IV. On December 18, 2024, the PUCO approved the Ohio Companies’ notice of withdrawal. Also on December 18, 2024, the PUCO approved the Ohio Companies’ proposal for returning to ESP IV, with modifications. Consistent with ESP IV, the PUCO authorized the Ohio Companies’ reinstatement of the DCR rider. Additionally, the PUCO ordered that storm costs deferred under ESP V since June 1, 2024, remain on the Ohio Companies’ books and subject to review in a future case. On January 22, 2025, the PUCO approved the Ohio Companies’ revised ESP IV tariffs, effective February 1, 2025, at which time the Ohio Companies resumed operating under ESP IV. On April 7, 2025, certain intervenors filed an appeal to the Supreme Court of Ohio challenging the Ohio Companies’ return to ESP IV. On May 22, 2025, the Supreme Court of Ohio granted the Ohio Companies’ motion to intervene in the appeal. On July 7, 2025, OCC and NOAC filed their Appellants’ brief. Appellees, including the PUCO and the Ohio Companies, filed their briefs on August 26, 2025, to which OCC and NOAC replied on September 15, 2025.

On January 31, 2025, the Ohio Companies filed an application with the PUCO for ESP VI. On May 15, 2025, the Ohio Governor signed HB 15, which repealed the statute authorizing ESPs in Ohio, effective August 14, 2025. On December 17, 2025, the PUCO dismissed the Ohio Companies’ application for ESP VI due to the repeal of the ESP statute.

On March 14, 2025, as directed by the PUCO in its December 18, 2024, order approving the Ohio Companies’ revised ESP IV tariffs, the Ohio Companies filed with the PUCO a request to commence their statutorily required quadrennial review of ESP IV and establish a proposed schedule. On July 10, 2025, the Ohio Companies withdrew the request for the PUCO to establish a procedural schedule following the May 15, 2025, signing by the Ohio Governor of HB 15 ending the statutory mandate to conduct the quadrennial review, effective August 14, 2025. The OCC filed its response to the Ohio Companies’ notice of withdrawal on July 25, 2025, to which the Ohio Companies replied on August 1, 2025. The matter remains pending before the PUCO.

Companies’ compliance tariffs, effective March 1, 2026. On March 20, 2026, the Ohio Companies and certain other parties filed with the PUCO second applications for rehearing of the February 18, 2026, entry on rehearing. On April 14, 2026, the PUCO issued an entry on rehearing denying all applications for rehearing. On May 14, 2026, Retail Energy Supply Association and IGS Energy Supply, LLC jointly filed with the PUCO a request for clarification and application for rehearing, to which the OCC and the Ohio Companies responded on May 26, 2026. On June 10, 2026, the PUCO issued its Fourth Entry on Rehearing, denying the application for rehearing. On August 10, 2026, the Ohio Companies filed a notice of appeal with the Supreme Court of Ohio, appealing the PUCO’s actions on rehearing, including the extension of the Ohio Companies’ deferred storm cost amortization period, and the issuance of additional directives on rehearing without following procedural rules. On October 19, 2026, the Ohio Companies filed their initial brief.

On May 16, 2022, May 15, 2023, and May 15, 2024, the Ohio Companies filed their SEET applications for determination of the existence of significantly excessive earnings under ESP IV for calendar years 2021, 2022, and 2023, respectively. On May 15, 2025, the Ohio Companies filed their SEET application for determination of the existence of significantly excessive earnings under ESPs IV and V for calendar year 2024. Each application demonstrated that each of the individual Ohio Companies did not have significantly excessive earnings. On May 11, 2026, the Attorney Examiner issued an entry consolidating the SEET proceedings for calendar years 2021 through 2024. On July 21, 2026, the Ohio Companies and the PUCO staff entered into a settlement, unopposed by OCC, stipulating that the Ohio Companies did not have significantly excessive earnings in 2021, 2022, 2023 or 2024. An evidentiary hearing was held on August 11, 2026.

On January 7, 2026, the PUCO issued an order, which directed the Ohio Companies to pay their customers, among other things, restitution and refunds totaling approximately $275 million ($213 million after-tax), which was recognized in the fourth quarter of 2025. The restitution and refunds are being provided to customers over three billing cycles, which began in February 2026. As of September 30, 2026, the Ohio Companies have issued approximately $266 million in restitution and refunds.

On May 22, 2026, the Ohio Companies filed with the PUCO a three-year rate plan, requesting approval of three consecutive, annual test periods that begin July 1, 2027 and end June 30, 2030. The application proposes a net increase in the Ohio Companies’ base distribution revenues of approximately $254 million in the first year, approximately $59 million in the second year, and approximately $80 million in the third year, with an ROE of 10.2% and a capital structure of approximately 47% debt and approximately 53% equity for all three Ohio Companies. On June 12, 2026, PUCO staff issued a deficiency letter requesting additional supplementation in certain areas, which the Ohio Companies provided on June 22, 2026. On July 1, 2026, an administrative law judge deemed the application complete and set a procedural schedule. Evidentiary hearings are set to begin March 1, 2027.

On June 12, 2026, at the PUCO’s direction, the Ohio Companies filed an application requesting approval of a proposed data center tariff which will create a separate class for data centers and ensure proper allocation of costs associated with the interconnection of large load customers to the electric system. Comments and reply comments on the proposed data center tariff were filed by various parties in August 2026.

See Note 10., “Commitments, Guarantees and Contingencies” of the Combined Notes to Financial Statements of the Registrants below for additional details on the ongoing government investigations and ongoing litigation surrounding HB 6.

PENNSYLVANIA

FE PA has five rate districts in Pennsylvania – four that correspond to the territories previously serviced by ME, PN, Penn, and WP and one rate district that corresponds to WP’s service provided to The Pennsylvania State University. The rate districts created by the PA Consolidation will not reach full rate unity until the earlier of 2033 or the conclusion of three base rate cases filed after January 1, 2025. FE PA operates under rates approved by the PPUC, effective as of January 1, 2025. FE PA operates under a DSP through the May 31, 2027 delivery period, which provides for the competitive procurement of generation supply for customers who do not choose an alternative EGS or for customers of alternative EGSs that fail to provide the contracted service. In December 2024, the PPUC approved FE PA’s LTIIP III program, which contemplates an approximately $1.4 billion investment plan from 2025 through 2029 and the eligible costs of which are recoverable through FE PA’s distribution system improvement charge. FE PA may increase its LTIIP investment plan up to 20% without seeking additional PPUC approval.

Pursuant to Pennsylvania Act 129 of 2008 and PPUC orders, the Pennsylvania Companies implemented energy efficiency and peak demand reduction programs with demand reduction targets, relative to 2007-2008 peak demands, at 2.9% MW for ME, 3.3% MW for PN, 2.0% MW for Penn, and 2.5% MW for WP; and energy consumption reduction targets, as a percentage of the Pennsylvania Companies’ historic 2009 to 2010 reference load at 3.1% MWh for ME, 3.0% MWh for PN, 2.7% MWh for Penn, and 2.4% MWh for WP. The fourth phase of FE PA’s energy efficiency and peak demand reduction program, which runs for the five-year period beginning June 1, 2021, through May 31, 2026, was approved by the PPUC on June 18, 2020, providing cost recovery of approximately $390 million to be recovered through Energy Efficiency and Conservation Phase IV Riders for each FE PA rate district.

proposed plan includes cost recovery of approximately $390 million to be recovered through its Phase V Energy Efficiency and Conservation Charge Rider and runs for a five-year period beginning June 1, 2026, through May 31, 2031. Hearings were held on January 29, 2026. The parties reached a full settlement in principle and filed with the PPUC a Joint Petition for Complete Settlement on February 19, 2026. On March 12, 2026, the PPUC issued an order approving the settlement with limited modifications requiring FE PA to file revisions to the plan, which were filed on April 15, 2026.

On February 3, 2026, FE PA filed a proposed DSP for provision of generation for the June 1, 2027 through May 31, 2031 delivery period, to be sourced through competitive procurements for customers who do not receive service from an alternative EGS. Under this DSP, supply would be provided through a mix of 12, 24, and in the case of residential customers, 60-month energy contracts, as well as spot market purchases for industrial customers. A hearing was held on June 15, 2026. FE PA reached a comprehensive settlement with certain parties, which was filed with the PPUC on July 2, 2026. On August 21, 2026, the administrative law judges issued a decision recommending that the PPUC approve, without modification, the July 2, 2026, settlement agreement. On October 26, 2026, the PPUC issued an order approving the settlement agreement with one modification that opens a new statewide proceeding to be instituted and conducted by June 1, 2027, associated with certain customer shopping protections.

WEST VIRGINIA

MP and PE provide electric service to all customers through traditional cost-based, regulated utility ratemaking and operate under WVPSC-approved rates that became effective March 27, 2024, and, for applicable customers, a WVPSC-approved solar surcharge that was most recently adjusted effective January 15, 2026. MP and PE recover net power supply costs, including fuel costs, purchased power costs and related expenses, net of related market sales revenue through the ENEC. MP’s and PE’s ENEC rate is typically updated annually and MP and PE filed their ENEC filing on August 29, 2025, for rates effective January 1, 2026. During the first quarter of 2026, MP and PE incurred significant PJM charges during the Winter Storm Fern weather event totaling $145 million, which were deferred for future recovery as part of the ENEC.

On April 21, 2022, the WVPSC issued an order approving, effective May 1, 2022, a tariff to offer solar power on a voluntary basis to West Virginia customers and requiring MP and PE to subscribe at least 85% of the planned 50 MWs of solar generation before seeking approval for surcharge cost recovery. MP and PE must seek separate approval from the WVPSC to recover any solar generation costs in excess of the approved solar power tariff. Two of the five solar generation sites went into service in 2024, with the third in April 2025.

On August 29, 2025, MP and PE filed with the WVPSC their biennial review of their vegetation management program and surcharge. MP and PE have proposed an approximate $3.2 million decrease in the surcharge rates due to an over-recovery balance as of June 30, 2025, and higher costs for fuel and reagents. The WVPSC held a hearing regarding rate matters on December 15, 2025. The WVPSC issued an order on March 26, 2026, approving the MP and PE vegetation management program and granting rate recovery for its costs.

On October 1, 2025, MP and PE filed their integrated resource plan with the WVPSC. To ensure that MP and PE can meet their PJM adequacy requirements, the plan proposes, among other things, near-term market capacity purchases and the addition of 70 MWs of solar generation by 2028 and 1,200 MWs of natural gas combined cycle generation by 2031. On May 6, 2026, an evidentiary hearing was held. In an order dated August 28, 2026, the WVPSC instructed MP and PE to submit additional information by December 1, 2026 and further set the filing of the next integrated resource plan for December 1, 2028.

On February 13, 2026, MP and PE filed a CPCN to construct and operate the 1,200 MW combined cycle gas turbine plant, that will be known as Maidsville Energy Center, and the 70 MWs of solar generation capacity, each referenced in their integrated resource plan above, for an estimated capital investment totaling approximately $2.7 billion as of the date of the filing. The request also includes a surcharge designed to recover financing costs during development and construction of the projects, as well as to transition to recovery in base rates once the projects are placed in-service and approved through a base rate case. Evidentiary hearings were held on July 16 and 17, 2026. A final order is expected from the WVPSC in the fourth quarter of 2026.

To support the proposed Maidsville Energy Center project schedule, FirstEnergy has entered into a reservation agreement with Siemens Energy, Inc. for turbines scheduled for delivery in 2030. As described in the CPCN case, any contemplated data center agreements utilizing the Maidsville Energy Center's output, would be expected to address customer protections, pricing, risk transfer and long-term benefit sharing for existing West Virginia customers.

On May 15, 2026, MP and PE filed a base rate proceeding proposing an increase in electric rates of $188.4 million, an approximate 10.6% increase in total revenues. The filing includes a base rate increase of $174.6 million and a proposed reliability program and surcharge of $13.8 million. As an alternative, MP and PE requested a phased approach of two increases of $37.9 million effective August 1, 2026, and $37.6 million effective June 1, 2027, with a commitment to abstain from filing another base rate case until April 1, 2028. On June 11, 2026, the WVPSC staff filed a motion to dismiss, which the WVPSC denied on July 2, 2026. The WVPSC held a hearing on the alternative two-phase approach on July 9, 2026. On July 31, 2026, the WVPSC issued an order approving the alternative two-phase approach without modification. New rates associated with the first phase became effective on August 1, 2026. The matter was appealed to the Supreme Court of Appeals of West Virginia on August 31, 2026, and remains pending before the court. MP and PE cannot predict the outcome of this appeal.

FERC REGULATORY MATTERS

Under the FPA, FERC regulates rates for interstate wholesale sales and transmission of electric power, regulatory accounting and reporting under the Uniform System of Accounts, and other matters, including construction and operation of hydroelectric projects. With respect to their wholesale services and rates, the Electric Companies, AE Supply and the Transmission Companies are subject to regulation by FERC. FERC regulations require JCP&L, MP, PE and the Transmission Companies to provide open access transmission service at FERC-approved rates, terms and conditions. Transmission facilities of JCP&L, MP, PE and the Transmission Companies are subject to functional control by PJM, and transmission service using their transmission facilities is provided by PJM under the PJM Tariff.

FERC regulates the sale of power for resale in interstate commerce in part by granting authority to public utilities to sell wholesale power at market-based rates upon showing that the seller cannot exert market power in generation or transmission or erect barriers to entry into markets. The Electric Companies and AE Supply each have the necessary authorization from FERC to sell their wholesale power, if any, in interstate commerce at market-based rates, although, in the case of the Electric Companies, major wholesale purchases remain subject to review and regulation by the relevant state commissions. The Electric Companies and AE Supply are required to renew their respective authorizations every three years, and on December 16, 2025, the companies filed applications for the next renewal period.

Federally enforceable mandatory reliability standards apply to the bulk electric system and impose certain operating, record-keeping and reporting requirements on the Electric Companies, AE Supply, and the Transmission Companies. NERC is the ERO designated by FERC to establish and enforce these reliability standards, although NERC has delegated day-to-day implementation and enforcement of these reliability standards to six regional entities, including RFC. All of the facilities that FirstEnergy operates are located within the RFC region. FirstEnergy actively participates in the NERC and RFC stakeholder processes, and otherwise monitors and manages its companies in response to the ongoing development, implementation and enforcement of the reliability standards implemented and enforced by RFC.

FirstEnergy believes that it is in material compliance with all currently-effective and enforceable reliability standards. Nevertheless, in the course of operating its extensive electric utility systems and facilities, FirstEnergy occasionally learns of isolated facts or circumstances that could be interpreted as excursions from the reliability standards. If and when such occurrences are found, FirstEnergy develops information about the occurrence and develops a remedial response to the specific circumstances, including in appropriate cases “self-reporting” an occurrence to RFC. Moreover, it is clear that NERC, RFC and FERC will continue to refine existing reliability standards as well as to develop and adopt new reliability standards. Any inability on FirstEnergy’s part to comply with the reliability standards for its bulk electric system could result in the imposition of financial penalties, or obligations to upgrade or build transmission facilities, that could have a material adverse effect on its financial condition, results of operations, and cash flows.

Transmission ROE Incentive

On February 24, 2022, the OCC filed a complaint with FERC against ATSI, AEP’s Ohio affiliate and American Electric Power Service Corporation, and Duke Energy Ohio, Inc. asserting that FERC should reduce the ROE utilized in the utilities’ transmission formula rates by eliminating the 50 basis point adder associated with RTO membership, effective February 24, 2022. The OCC contended that this result is required because Ohio law mandates that transmission owning utilities join an RTO and that the 50 basis point adder is applicable only where RTO membership is voluntary. On December 15, 2022, FERC denied the complaint as to ATSI and Duke Energy Ohio, Inc., but granted it as to AEP’s Ohio affiliate. AEP’s Ohio affiliate and OCC appealed FERC’s orders to the Sixth Circuit. On January 17, 2025, the Sixth Circuit ruled that the 50 basis point adder is available only where RTO membership is voluntary, that Ohio law requires Ohio’s transmission utilities to be members of an RTO, and that it was unlawful for FERC to excise the adder from AEP’s Ohio affiliate rates, but not from the Duke Energy Ohio, Inc. and ATSI rates. During 2024, as a result of the ruling, ATSI recognized a $46 million pre-tax charge, with interest, of which $42 million is reported in “Transmission Revenues” and $4 million is reported in “Miscellaneous income, net” on the FirstEnergy Consolidated Statements of Income and Comprehensive Income at the Stand-Alone Transmission segment, to reflect the expected refund owed to transmission customers back to February 24, 2022. On June 20, 2025, and June 24, 2025, ATSI and AEP’s Ohio affiliate, respectively, applied for the Supreme Court of the U.S. to review the Sixth Circuit’s decision. On November 10, 2025, the Supreme Court of the U.S. denied ATSI’s petition for the court to review the case. On November 13, 2025, the Sixth Circuit issued a mandate sending the case back to FERC for further proceedings. On June 25, 2026, FERC issued an order on remand directing ATSI to submit a compliance filing within 30 days to remove the RTO incentive and make refunds with interest within 30 days for the period beginning February 24, 2022, through the date of the refund. On July 22, 2026, FERC approved ATSI’s subsequent request to defer the deadline to issue refunds until February 28, 2027, in order to accommodate the PJM and MISO processes for processing refunds as directed by FERC’s order. On July 27, 2026, ATSI submitted to FERC a filing to amend its formula rate to remove on a going-forward basis 50 basis points of authorized earnings in compliance with FERC’s orders. FirstEnergy also filed a request for rehearing on July 27, 2026, arguing that the Federal Power Act limited the refund period to 15 months. On August 27, 2026, FERC denied the request for rehearing by operation of law. On October 21, 2026, ATSI appealed FERC’s June 25, 2026, order to the Sixth Circuit. As of September 30, 2026, ATSI’s estimated refund obligation, including interest, totaled approximately $51 million, which is recorded in “Regulatory liabilities” on FirstEnergy’s Consolidated Balance Sheets.

Transmission ROE Methodology

A proposed rulemaking proceeding concerning transmission rate incentives provisions of Section 219 of the 2005 Energy Policy Act was initiated in March of 2020 and remains pending before FERC. Among other things, the rulemaking explored whether utilities should collect an “RTO membership” ROE incentive adder for more than three years. FirstEnergy is a member of PJM, and its transmission subsidiaries could be affected by the proposed rulemaking. FirstEnergy participated in comments on the supplemental rulemaking that were submitted by a group of PJM transmission owners and by various industry trade groups. If there were to be any changes to FirstEnergy's transmission incentive ROE, such changes will be applied on a prospective basis; provided however, due to the Sixth Circuit’s ruling in the Transmission ROE Incentive matter described above, ATSI revised the ROE in its transmission rates effective August 1, 2026.

Transmission Planning Supplemental Projects

On September 27, 2023, the OCC filed a complaint against ATSI, PJM and other transmission utilities in Ohio alleging that the PJM Tariff and operating agreement are unjust, unreasonable, and unduly discriminatory because they include no provisions to ensure PJM’s review and approval for the planning, need, prudence and cost-effectiveness of the PJM Tariff Attachment M-3 “Supplemental Projects.” Supplemental Projects are projects that are planned and constructed to address local needs on the transmission system. The OCC demands that FERC: (i) require PJM to review supplemental projects for need, prudence and cost-effectiveness; (ii) appoint an independent transmission monitor to assist PJM in such review; and (iii) require that Supplemental Projects go into rate base only through a “stated rate” procedure whereby prior FERC approval would be needed for projects with costs that exceed an established threshold. Subsequently, intervenors expanded the scope of this proceeding to all of the transmission utilities in the PJM market, including JCP&L. ATSI and the other transmission utilities in Ohio and in the PJM market filed comments. The matter is pending before FERC.

Local Transmission Planning Complaint

On December 19, 2024, the Industrial Energy Consumers of America, a group representing large industrial customers, and state consumer advocates filed a complaint at FERC that asserts that transmission owners are overbuilding “local transmission facilities” with corresponding unjustified increases in transmission rates. The complaint demands that FERC: (i) prohibit transmission owners from planning “local transmission facilities” that are rated at 100 kV or higher; (ii) appoint “independent transmission monitors” to conduct such planning; and (iii) condition construction of local transmission facilities on the facility having been planned by the “independent transmission monitor.” FirstEnergy is participating in this matter through a consortium of PJM transmission owners and through certain trade groups, including EEI. FirstEnergy, together with the PJM transmission owners, filed a motion to dismiss the complaint on March 20, 2025, which is pending before FERC. FirstEnergy is unable to predict the outcome or estimate the impact that this complaint may have on its Transmission Companies, however, whether this lawsuit moves forward could have a material impact on FirstEnergy and its transmission capital investment strategy.

Ghiorzi v. PJM

In December 2023, PJM assigned certain baseline RTEP projects to NextEra Energy Transmission, which subsequently informed PJM that it would not construct the projects. On April 3, 2025, following the reassignment by PJM of certain baseline RTEP projects in Maryland and Virginia to PE, two individuals filed a complaint at FERC challenging this outcome, which FERC denied on February 2, 2026. The complainants asserted that PJM erred in reassigning the work to PE because such reassignment projects: (i) did not reflect the cost estimates or cost caps included in NextEra Energy Transmission’s bid; and (ii) would be constructed with different routing than originally proposed. On February 2, 2026, FERC denied the complaint and on April 3, 2026, FERC denied the rehearing request filed by the complainants on March 4, 2026. On June 22, 2026, FERC affirmed its February 2, 2026, order denying the complaint. The deadline to appeal has passed and FERC’s order is final.

Abandonment Transmission Rate Incentive

On February 26, 2025, PJM completed its 2024 RTEP Open Window process and, among other actions, designated each of ATSI and PE to construct certain transmission projects. On July 11, 2025, ATSI and PE filed a joint application for the abandonment incentive with FERC, which was approved on September 9, 2025. Effective September 10, 2025, ATSI and PE each became eligible to recover 50% of the project costs incurred prior to September 10, 2025, and 100% of the project costs incurred thereafter for any projects subsequently cancelled for reasons beyond the control of utility management.

PJM Capacity Market Reforms

that, if a transmission owner exits PJM, at and after such exit, the costs are to be charged to the transmission owner. On August 21, 2026, FirstEnergy filed protests at FERC arguing, among other things, that PJM had failed to demonstrate that the proposal to charge the costs to exiting transmission owners is “just and reasonable” as required by the Federal Power Act. On September 29, 2026, FERC issued an order suspending PJM’s proposed reliability backstop procurement tariff amendments until February 28, 2027, and instituting further proceedings. FERC further invited PJM to submit a second set of tariff amendments to address the issues that were identified in the September 29, 2026, order. On September 30, 2026, PJM announced the procurement would not begin as previously scheduled. FirstEnergy expects it will continue to participate in the PJM stakeholder processes and FERC proceedings.

Large Load Interconnection Rulemaking

On October 23, 2025, the U.S. Secretary of Energy directed FERC to conduct a rulemaking procedure to develop regulations that would speed interconnection to the transmission system of large loads, including AI data centers and “hybrid” data center/electric generation facilities. The U.S. Secretary of Energy advanced 14 principles to guide this outcome, including that such large loads should be responsible for paying the costs of any network transmission system upgrades required for interconnection of such large loads. The U.S. Secretary of Energy requested that FERC take final action by April 30, 2026. On October 27, 2025, FERC noticed the U.S. Secretary of Energy’s directive for comment, and subsequently established November 21, 2025, as the deadline for initial comments and December 5, 2025, as the deadline for reply comments. FET and its transmission affiliates, as well as over 150 other parties, filed comments. On June 18, 2026, FERC established a “show cause” proceeding for PJM and the PJM transmission owners, while also establishing similar dockets for each of the other RTOs and ISOs and their respective transmission owners. FERC is using the “show cause” proceeding as a means for the affected transmission owners to submit tariff revisions to address the requirements needed to interconnect and serve customers seeking transmission service on behalf of large loads. On July 28, 2026, PJM filed a motion with FERC advising of its plans to submit the compliance filing in mid-November 2026, which FERC accepted on August 14, 2026. On August 17, 2026, the PJM transmission owners filed a partial compliance filing to set a rate for interim network integration transmission service. On September 22, 2026, FERC issued an order dismissing all requests for rehearing and clarified that the June 18, 2026, order made no final determination and that the matter is in abeyance pending submission of the compliance filing. FirstEnergy is unable to predict the outcome of this proceeding.

Utility RELIEF Act and Related FERC Complaint

The Utility RELIEF Act, which became effective July 1, 2026, requires all transmission utilities within Maryland to participate as members in an RTO. On July 2, 2026, the Maryland Energy Administration, MDOPC, and MDPSC filed a complaint at FERC against PE, Valley Link Maryland, and all other Maryland transmission owners. The complaint seeks a FERC order directing the Maryland transmission owners to remove the RTO 50 bps ROE adder incentive from each of their transmission rates. The Maryland Energy Administration, MDOPC, and MDPSC seek to apply FERC’s rulings that remove the RTO incentive from transmission rates when state laws require RTO participation. The complaint requested that any RTO incentive adders collected after July 1, 2026, be refunded. On August 5, 2026, PE and its affiliate, Valley Link Maryland, each responded to the complaint. The Maryland Energy Administration, MDOPC, and MDPSC filed a response on September 3, 2026, to which PE and Valley Link Maryland each responded on September 18, 2026. The Maryland Energy Administration, MDOPC, and MDPSC filed a response on October 5, 2026, to which PE responded on October 20, 2026.

PJM Interim Resource Adequacy Service

On August 13, 2026, PJM filed with FERC its interim resource adequacy service proposal, which would permit curtailment to data centers that did not bring their own supply of new generation resources. On September 3, 2026, FirstEnergy filed a limited protest of certain elements of PJM’s filing. On October 12, 2026, FERC issued an order accepting PJM’s proposed large load definition and PJM’s proposal to establish a registry to log and track such large loads. FERC rejected all of the remaining elements of PJM’s proposal without prejudice.

Winter Storm Fern

On October 6, 2026, MP filed a complaint at FERC against PJM alleging that PJM’s Day-Ahead Market dispatch order during Winter Storm Fern in January and February 2026 was not consistent with the PJM Tariff and resulted in approximately $145 million in Winter Storm Fern-related net wholesale power costs being incurred by MP, which otherwise would be recovered from MP’s and PE’s West Virginia retail customers through the ENEC. On October 26, 2026, PJM filed its answer to MP’s complaint and a motion to dismiss. The matter is pending before FERC.

10. COMMITMENTS, GUARANTEES AND CONTINGENCIES

The disclosures in this note apply to all Registrants, unless indicated otherwise.

GUARANTEES AND OTHER ASSURANCES


FirstEnergy Guarantees and Other Assurances	Maximum Exposure
	(In millions)
FE’s Guarantees on Behalf of its Consolidated Subsidiaries
Deferred compensation arrangements	$	388
Vehicle leases	75
Transfer of McElroy’s Run CCR impoundment facility	107
Other	15
	585
FE’s Guarantees on Other Assurances
Surety bonds	160
Deferred compensation arrangements	89
LOCs	187
	436
Total FirstEnergy Guarantees and Other Assurances	$	1,021


FE PA and JCP&L Guarantees and Other Assurances	Maximum Exposure
	FE PA		JCP&L
	(In millions)
Guarantees on Other Assurances
Surety bonds	$	27			$	20
LOCs	19			8
Total Guarantees and Other Assurances	46			28

In 2025, FET, DominionHV and Transource entered into an equity support agreement to enable Valley Link to enter into a credit facility with a third party. The equity support agreement expires once all Valley Link credit agreement obligations are satisfied or when FET has fulfilled its support obligations under the equity support agreement. As of September 30, 2026, the maximum exposure of FET’s support obligations relating to the Valley Link credit facility was $102 million. On October 21, 2026, Valley Link amended its credit facility, increasing FET’s maximum support obligation to $221 million.

COLLATERAL AND CONTINGENT-RELATED FEATURES

In the normal course of business, the Registrants may enter into physical or financially settled contracts for the sale and purchase of electric capacity, energy, fuel and emission allowances. Certain agreements contain provisions that require the Registrants to post collateral. This collateral may be posted in the form of cash or credit support with thresholds contingent upon the Registrants’ credit rating from each of the major credit rating agencies. The collateral and credit support requirements vary by contract and by counterparty.

disclose the potential additional credit rating contingent contractual collateral obligations of the Registrants as of September 30, 2026:


	Potential Collateral Obligations
FirstEnergy	Electric Companies and Transmission Companies		FE		Total
	(In millions)
Contractual obligations for additional collateral

Upon downgrade	$	63			$	1		$	64

Surety bonds (collateralized amount)(1)	113			131			244
Total FirstEnergy Exposure from Contractual Obligations	$	176			$	132		$	308

(1) Surety bonds are not tied to a credit rating. Surety bonds’ impact assumes maximum contractual obligations, which is ordinarily 100% of the face amount of the surety bond except with respect to $20 million of surety bond obligations for which the collateral obligation is capped at 60% of the face amount, and typical obligations require 30 days to cure.


	Potential Collateral Obligations
	FE PA		JCP&L
Contractual obligations for additional collateral	(In millions)

Upon downgrade	$	—			$	63

Surety bonds (collateralized amount)(1)	25			20
Total Exposure from Contractual Obligations	$	25			$	83

(1) Surety bonds are not tied to a credit rating, and their impact assumes maximum contractual obligations, which is ordinarily 100% of the face amount of the surety bond except with respect to $6 million of surety bond obligations for FE PA for which the collateral obligation is capped at 60% of the face amount, and typical obligations require 30 days to cure.

The following table provides the amount of collateral posted by the Registrants in the form of LOCs and the amount of net cash collateral that the Registrants are holding from certain generation suppliers as of September 30, 2026:


	As of September 30, 2026
Registrant	Collateral Posted in the Form of LOCs		Cash Collateral Held from Certain Generation Suppliers(1)
	(In millions)
FirstEnergy	$	187		$	42
FE PA	$	19		$	20
JCP&L	$	8		$	6

(1) These amounts are included in \"Other current liabilities\" on the Registrants’ respective Balance Sheets.

ENVIRONMENTAL MATTERS

Various federal, state and local authorities regulate the Registrants regarding air and water quality, hazardous and solid waste management and disposal, and other environmental matters. While the Registrants’ environmental policies and procedures are designed to achieve compliance with applicable environmental laws and regulations, such laws and regulations are subject to periodic review and potential revision by the implementing agencies. The Registrants cannot predict changes in regulations, regulatory guidance, legal interpretations, policy positions and implementation actions that may evolve.

On March 12, 2025, the EPA announced its intent to reevaluate or reconsider numerous environmental regulations, many of which apply to the Registrants. The final outcome of this initiative remains unknown, but regular required rulemaking processes and procedures still apply, and, as anticipated, litigation has occurred. The disclosures herein do not attempt to discern potential impacts of these deregulatory actions until and unless formal rulemaking or other regulatory actions are announced and the potential impacts to operations can be discerned.

The disclosures below apply to FirstEnergy and the disclosures under “Regulation of Waste Disposal,” are also applicable to FE PA and JCP&L.

Clean Air Act

FirstEnergy complies with SO2 and NOx emission reduction requirements under the CAA and SIP by burning lower-sulfur fuel,

utilizing combustion controls and post-combustion controls and/or using emission allowances.

CSAPR requires reductions of NOx and SO2 emissions in two phases (2015 and 2017), ultimately capping SO2 emissions in affected states to 2.4 million tons annually and NOx emissions to 1.2 million tons annually. CSAPR allows trading of NOx and SO2 emission allowances between electric generation facilities located in the same state and interstate trading of NOx and SO2 emission allowances with some restrictions. On July 28, 2015, the D.C. Circuit ordered the EPA to reconsider the CSAPR caps on NOx and SO2 emissions from electric generation facilities in 13 states, including West Virginia. This followed the 2014 Supreme Court of the U.S. ruling generally upholding the EPA’s regulatory approach under CSAPR but questioning whether the EPA required upwind states to reduce emissions by more than their contribution to air pollution in downwind states. The EPA issued a CSAPR Update on September 7, 2016, reducing summertime NOx emissions from electric generation facilities in 22 states in the eastern U.S., including West Virginia, beginning in 2017. Various states and other stakeholders appealed the CSAPR Update to the D.C. Circuit in November and December 2016. On September 13, 2019, the D.C. Circuit remanded the CSAPR Update to the EPA citing that the rule did not eliminate upwind states’ significant contributions to downwind states’ air quality attainment requirements within applicable attainment deadlines.

Also in March 2018, the State of New York filed a CAA Section 126 petition with the EPA alleging that NOx emissions from nine states (including West Virginia) significantly contribute to New York’s inability to attain the ozone NAAQS. The petition sought suitable emission rate limits for large stationary sources that are allegedly affecting New York’s air quality within the three years allowed by CAA Section 126. On September 20, 2019, the EPA denied New York’s CAA Section 126 petition. On October 29, 2019, the State of New York appealed the denial of its petition to the D.C. Circuit. On July 14, 2020, the D.C. Circuit reversed and remanded the New York petition to the EPA for further consideration. On March 15, 2021, the EPA issued a revised CSAPR Update that addressed, among other things, the remands of the prior CSAPR Update and the New York Section 126 petition. In December 2021, MP purchased NOx emissions allowances to comply with 2021 ozone season requirements. On April 6, 2022, the EPA published proposed rules seeking to impose further significant reductions in EGU NOx emissions in 25 upwind states, including West Virginia, with the stated purpose of allowing downwind states to attain or maintain compliance with the 2015 ozone NAAQS. On February 13, 2023, the EPA disapproved 21 SIPs, which was a prerequisite for the EPA to issue a final Good Neighbor Plan or FIP. On June 5, 2023, the EPA issued the final Good Neighbor Plan with an effective date 60 days thereafter. Certain states, including West Virginia, have appealed the disapprovals of their respective SIPs, and some of those states have obtained stays of those disapprovals precluding the Good Neighbor Plan from taking effect in those states. On August 10, 2023, the 4th Circuit granted West Virginia an interim stay of the disapproval of its SIP and on January 10, 2024, after a hearing held on October 27, 2023, granted a full stay which precludes the Good Neighbor Plan from going into effect in West Virginia. In addition to West Virginia, certain other states, and certain trade organizations, including the Midwest Ozone Group of which FE is a member, separately filed petitions for review and motions to stay the Good Neighbor Plan itself at the D.C. Circuit. On September 25, 2023, the D.C. Circuit denied the motions to stay the Good Neighbor Plan. On October 13, 2023, the aggrieved parties filed an Emergency Application for an Immediate Stay of the Good Neighbor Plan with the Supreme Court of the U.S. Oral argument was heard on February 21, 2024. On June 27, 2024, the Supreme Court of the U.S. granted a stay of the Good Neighbor Plan pending disposition of the petition for review in the D.C. Circuit. On February 6, 2025, the EPA filed a motion at the D.C. Circuit to hold the proceedings in abeyance for 60 days to allow the EPA time to familiarize itself with the Good Neighbor Plan and in particular, time to brief the new administration about these consolidated petitions and the underlying Rule to allow the EPA to decide what action, if any, is necessary. On March 10, 2025, the EPA filed a motion for remand with the D.C. Circuit identifying issues with the Good Neighbor Plan that make reconsideration appropriate. The D.C. Circuit granted the motion for remand and cancelled oral argument. Consistent with its March 12, 2025, announcement, the EPA intends to undertake reconsideration of the rule and complete any new rulemaking by the fourth quarter of 2026. On January 27, 2026, the EPA proposed phase 1 of its reconsideration of the rule applicable to eight states outside of FirstEnergy’s service area. FirstEnergy will continue to monitor any further actions by the EPA for any potential impact to its business and results of operations.

Climate Change

In recent years, certain regulators in the U.S. have focused efforts on increasing disclosures by companies related to climate change and mitigation efforts. At the federal level, presidential administrations have held differing views on prioritizing actions to address GHG emissions and, by extension, climate change. Those differing views have led to policy changes, creating uncertainty about environmental requirements and associated impacts.

In December 2009, the EPA released its final “Endangerment and Cause or Contribute Findings for GHGs under the Clean Air Act,” known as the 2009 Endangerment Finding, concluding that concentrations of several key GHGs constitute an “endangerment” and may be regulated as “air pollutants” under the CAA and mandated measurement and reporting of GHG emissions from certain sources, including electric generation facilities. The 2009 Endangerment Finding is the basis of the EPA’s authority to regulate GHG emissions under the CAA.

GHG emissions. On February 18, 2026, the first of several petitions for review were filed at the D.C. Circuit challenging the rescission by the EPA and multiple lawsuits opposing the EPA’s rescission were filed thereafter. Depending on the outcome of this litigation, which is expected to be extensive, and any future EPA actions, compliance with the GHG emissions limits could require additional capital expenditures or changes in operation at the Fort Martin and Harrison power stations.

On May 23, 2023, the EPA published a proposed rule pursuant to CAA Section 111 (b) and (d) in line with the decision in West Virginia v. Environmental Protection Agency intended to reduce power sector GHG emissions (primarily CO2 emissions) from fossil fuel based EGUs. On April 25, 2024, the EPA issued a final rule, which we refer to as the GHG rule, that imposed stringent GHG emissions limitations on power plants based on fuel type and unit retirement date. In May 2024, a group of 25 states, including West Virginia, filed a challenge to the rule in the D.C. Circuit. Also in May 2024, other utility groups, including the Midwest Ozone Group and Electric Generators for a Sensible Transition, both of which include MP as a member, filed petitions for review of the GHG rule in the D.C. Circuit. The D.C. Circuit subsequently granted a motion from the EPA placing the litigation in abeyance until further order of the Court. On June 17, 2025, the EPA published a proposed rule to repeal the GHG rule. On September 17, 2026, the EPA issued a final rule partially repealing the 2024 GHG Rule that eliminates the carbon capture and sequestration and co-firing requirement of fossil generation. At the same time, the EPA issued a proposed rule repealing all GHG rules. Legal challenges to the partial repeal have been filed. Midwest Ozone Group and Electric Generators for a Sensible Transition have filed as intervenors supporting the September 17, 2026, EPA rulemakings. The EPA’s repeal of the GHG rule is expected to be challenged in federal court. FirstEnergy continues to evaluate the impact of federal GHG regulations on its operations, it cannot predict the outcome of any of these regulatory actions or the associated litigation.

At the state level, there are several initiatives to reduce GHG emissions. Certain northeastern states are participating in the RGGI and western states, including California, have implemented programs to control emissions of certain GHGs and enhance public disclosures relating to the same. Additional policies reducing GHG emissions, such as demand reduction programs, renewable portfolio standards and renewable subsidies have been implemented across the nation.

FirstEnergy continues to monitor climate change policies at both the federal and state level. In light of the pending legal challenges discussed above, FirstEnergy is unable to predict the impact on its business and operations.

FirstEnergy has pledged to achieve carbon neutrality by 2050 with respect to GHGs within FirstEnergy’s direct operational control (known as Scope 1 emissions). FirstEnergy’s ability to achieve its GHG reduction goal is subject to its ability to make operational changes and is conditioned upon numerous risks, many of which are outside of its control. With respect to FirstEnergy’s coal-fired facilities in West Virginia, which serve as the primary source of its Scope 1 emissions, it has identified that the end of the useful life date is 2035 for Fort Martin and 2040 for Harrison. MP filed its 10-year integrated resource plan with the WVPSC on October 1, 2025, which highlighted, among other things, the need for new dispatchable generation in West Virginia. Determination of the useful life of the regulated coal-fired generation could result in changes in depreciation, and/or continued collection of net plant in rates after retirement, securitization, sale, impairment, or regulatory disallowances. If FirstEnergy is unable to recover these costs, it could have a material adverse effect on FirstEnergy’s financial condition, results of operations, and cash flow.

Clean Water Act

Various water quality regulations, the majority of which are the result of the federal Clean Water Act and its amendments, apply to FirstEnergy’s facilities. In addition, the states in which FirstEnergy operates have water quality standards applicable to FirstEnergy’s operations.

On September 30, 2015, the EPA finalized new, more stringent effluent limits for the Steam Electric Power Generating category (40 CFR Part 423) for arsenic, mercury, selenium and nitrogen for wastewater from wet scrubber systems and zero discharge of pollutants in ash transport water. The treatment obligations were to phase-in as permits were renewed on a five-year cycle from 2018 to 2023. However, on April 13, 2017, the EPA granted a Petition for Reconsideration and on September 18, 2017, the EPA postponed certain compliance deadlines for two years. On August 31, 2020, the EPA issued a final rule revising the effluent limits for discharges from wet scrubber systems, retaining the zero-discharge standard for ash transport water (with some limited discharge allowances), and extending the deadline for compliance to December 31, 2025, for both. In addition, the EPA allows for less stringent limits for sub-categories of generating units based on capacity utilization, flow volume from the scrubber system, and unit retirement date. On March 29, 2023, the EPA published proposed revised ELGs applicable to coal-fired electric generation facilities that include more stringent effluent limitations for wet scrubber systems and ash transport water, and new limits on landfill leachate. The rule was issued as final by the EPA on April 25, 2024. On May 30, 2024, the Utility Water Act Group, of which FirstEnergy is a member, filed a Petition for Review of the 2024 ELG Rule with the U.S. Court of Appeals for the Fifth and Eighth Circuit Courts, and on June 18, 2024, the Utility Water Act Group filed a motion to stay the rule pending disposition on the merits. A number of other parties have challenged the final rule in various petitions for review across several circuits. Those petitions and motions for stay have been consolidated in the U.S. Court of Appeals for the Eighth Circuit. On October 10, 2024, the U.S. Court of Appeals for the Eighth Circuit denied the motions for stay. Depending on the outcome of appeals and the EPA’s review, compliance with the 2024 ELG rule could require additional capital expenditures or changes in operation at closed and active landfills, and at the Fort Martin and Harrison power stations from what was approved by the WVPSC in September 2022 to comply with the 2020 ELG rule. On February 19, 2025, the U.S. Department of Justice filed a motion on behalf of the EPA in the U.S. Court of Appeals for the Eighth Circuit, seeking to hold the litigation in abeyance for a

period of 60 days while the new leadership at the EPA evaluates the rule and determines how it wishes to proceed. On February 28, 2025, the U.S. Court of Appeals for the Eighth Circuit granted the EPA’s motion. On March 12, 2025, the EPA announced a series of planned deregulatory actions, including reconsideration of the 2024 ELG rule. On December 31, 2025, the EPA published a final ELG Deadline Extensions Rule extending certain compliance deadlines included in the 2024 ELG Rule by five years.

Regulation of Waste Disposal

Federal and state hazardous waste regulations have been promulgated as a result of the Resource Conservation and Recovery Act, as amended, and the Toxic Substances Control Act. Certain CCRs, such as coal ash, were exempted from hazardous waste disposal requirements pending the EPA’s evaluation of the need for future regulation.

In April 2015, the EPA finalized regulations for the disposal of CCRs (non-hazardous), establishing national standards for landfill design, structural integrity design and assessment criteria for surface impoundments, groundwater monitoring and protection procedures and other operational and reporting procedures to assure the safe disposal of CCRs from electric generation facilities. On September 13, 2017, the EPA announced that it would reconsider certain provisions of the final regulations. On July 29, 2020, the EPA published a final rule again revising the date that certain CCR impoundments must cease accepting waste and initiate closure to April 11, 2021. The final rule allowed for an extension of the closure deadline based on meeting identified site-specific criteria. AE Supply transferred the McElroy’s Run CCR impoundment facility and adjacent dry landfill and related remediation obligations on March 4, 2025, pursuant to the environmental liability transfer agreement dated February 3, 2025, with a subsidiary of IDA Power, LLC. Pursuant to the agreement, AE Supply established a $160 million escrow account that AE Supply will fund over five years and is secured by a surety bond, which is guaranteed by FE. As of September 30, 2026, AE Supply has made cumulative cash payments of $68 million to the escrow account since the transfer in 2025.

On May 8, 2024, the EPA issued the legacy CCR rule, which finalized changes to the CCR regulations addressing inactive surface impoundments at inactive electric utilities, known as legacy CCR surface impoundments. The rule extends 2015 CCR Rule requirements for groundwater monitoring and protection, operational and reporting procedures as well as closure requirements to impoundments and landfills that were not originally included for coverage by the 2015 CCR Rule. Furthermore, the EPA’s interpretations of the EPA CCR regulations continue to evolve through enforcement and other regulatory actions. FirstEnergy is currently assessing the potential impacts of the final rule, including a review of additional sites to which the new rule might be applicable. On February 13, 2025, the U.S. Department of Justice filed a motion on behalf of the EPA in the D.C. Circuit, seeking to hold the litigation, which was filed on August 8, 2024, by the Utility Solid Waste Act Group with FE as a member, in abeyance for a period of 120 days while the new leadership at the EPA evaluates the rule and determines how it wishes to proceed, which the D.C. Circuit granted. On March 12, 2025, the EPA announced a series of planned deregulatory actions, including reconsideration of the final legacy CCR rule. FirstEnergy continues to monitor the EPA’s actions related to CCR regulations; however, the ultimate impact is unknown at this time and is subject to the outcome of the litigation and any future state regulatory actions. Depending on the outcome of appeals and the EPA’s rule, compliance with the final legacy CCR rule could require remedial actions, including removal of coal ash.

Certain of the FirstEnergy companies have been named as potentially responsible parties at waste disposal sites, which may require cleanup under the CERCLA. Allegations of disposal of hazardous substances at historical sites and the liability involved are often unsubstantiated and subject to dispute; however, federal law provides that all potentially responsible parties for a particular site may be liable on a joint and several basis. Environmental liabilities that are considered probable have been recognized on FirstEnergy’s Consolidated Balance Sheets as of September 30, 2026, based on estimates of the total costs of cleanup, FirstEnergy’s proportionate responsibility for such costs and the financial ability of other unaffiliated entities to pay. Total liabilities of approximately $92 million ($74 million at JCP&L, none at FE PA) have been accrued through September 30, 2026, of which approximately $66 million are for environmental remediation of former MGP and gas holder facilities in New Jersey, which are being recovered by JCP&L through a non-bypassable societal benefits charge. FE or its subsidiaries could be found potentially responsible for additional amounts or additional sites, but the loss or range of losses cannot be determined or reasonably estimated at this time.

OTHER LEGAL PROCEEDINGS

U.S. v. Larry Householder, et al.

On July 21, 2020, a complaint and supporting affidavit containing federal criminal allegations were unsealed against the now former Ohio House Speaker Larry Householder and other individuals and entities allegedly affiliated with Mr. Householder. In March 2023, a jury found Mr. Householder and his co-defendant, Matthew Borges, guilty and in June 2023, the two were sentenced to prison for 20 and five years, respectively. Messrs. Householder and Borges have appealed their sentences; the Sixth Circuit recently rejected their appeal upholding their convictions. Also, on July 21, 2020, and in connection with the U.S. Attorney’s Office’s investigation, FirstEnergy received subpoenas for records from the U.S. Attorney’s Office for the Southern District of Ohio. FirstEnergy was not aware of the criminal allegations, affidavit or subpoenas before July 21, 2020. On January 17, 2025, the U.S. Attorney’s Office announced that a federal grand jury charged two former FirstEnergy senior officers with one count of participating in a Racketeer Influenced and Corrupt Organizations Act conspiracy. The allegations in the indictment are

largely based on the conduct described in the DPA.

On July 21, 2021, FE entered into a three-year DPA with the U.S. Attorney’s Office that, subject to court proceedings, resolves this matter as to FE. Under the DPA, FE agreed to the filing of a criminal information charging FE with one count of conspiracy to commit honest services wire fraud. The DPA required that FirstEnergy, among other obligations: (i) continue to cooperate with the U.S. Attorney’s Office in all matters relating to the conduct described in the DPA and other conduct under investigation by the U.S. government; (ii) pay a criminal monetary penalty totaling $230 million within sixty days, consisting of (x) $115 million paid by FE to the U.S. Treasury and (y) $115 million paid by FE to the ODSA to fund certain assistance programs, as determined by the ODSA, for the benefit of low-income Ohio electric utility customers; (iii) publish a list of all payments made in 2021 to either 501(c)(4) entities or to entities known by FirstEnergy to be operating for the benefit of a public official, either directly or indirectly, and update the same on a quarterly basis during the term of the DPA; (iv) issue a public statement, as dictated in the DPA, regarding FE’s use of 501(c)(4) entities; and (v) continue to implement and review its compliance and ethics program, internal controls, policies and procedures designed, implemented and enforced to prevent and detect violations of U.S. laws throughout its operations, and to take certain related remedial measures. The $230 million payment will neither be recovered in rates nor charged to FirstEnergy customers, nor will FirstEnergy seek any tax deduction related to such payment. The entire amount of the monetary penalty was recognized as an expense in the second quarter of 2021 and paid in the third quarter of 2021. As of July 22, 2024, FirstEnergy had successfully completed the obligations required within the three-year term of the DPA. Under the DPA, FirstEnergy has an obligation to continue: (i) publishing quarterly a list of all payments to 501(c)(4) entities and all payments to entities known by FirstEnergy operating for the benefit of a public official, either directly or indirectly; (ii) not making any statements that contradict the DPA; (iii) notifying the U.S. Attorney’s Office of any changes in FirstEnergy’s corporate form; and (iv) cooperating with the U.S. Attorney’s Office until the conclusion of any related investigation, criminal prosecution, and civil proceeding brought by the U.S. Attorney’s Office, including the aforementioned federal indictment against two former FirstEnergy senior officers. Within 30 days of those matters concluding, and FirstEnergy’s successful completion of its remaining obligations, the U.S. Attorney’s Office will dismiss the criminal information. On February 26, 2025, the U.S. Attorney’s Office filed a status report confirming these commitments.

Legal Proceedings Relating to U.S. v. Larry Householder, et al.

Certain FE stockholders and FirstEnergy customers also filed several lawsuits against FirstEnergy and certain current and former directors, officers and other employees, and the complaints in each of these suits are related to allegations in the complaint and supporting affidavit relating to HB 6 and the now former Ohio House Speaker Larry Householder and other individuals and entities allegedly affiliated with Mr. Householder. The plaintiffs in each of the below cases seek, among other things, to recover an unspecified amount of damages (unless otherwise noted).

•In re FirstEnergy Corp. Securities Litigation (S.D. Ohio); on July 28, 2020, and August 21, 2020, purported stockholders of FE filed putative class action lawsuits alleging violations of the federal securities laws. Those actions have been consolidated and a lead plaintiff, the Los Angeles County Employees Retirement Association, has been appointed by the court. A consolidated complaint was filed on February 26, 2021. The consolidated complaint alleges, on behalf of a proposed class of persons who purchased FE securities between February 21, 2017, and July 21, 2020, that FE and certain current or former FE officers violated Sections 10(b) and 20(a) of the Exchange Act by making alleged misrepresentations or omissions concerning FE’s business and results of operations. The consolidated complaint also alleges that FE, certain current or former FE officers and directors, and a group of underwriters violated Sections 11, 12(a)(2) and 15 of the Securities Act as a result of alleged misrepresentations or omissions in connection with offerings of senior notes by FE in February and June 2020. On March 30, 2023, the court granted plaintiffs’ motion for class certification. On April 14, 2023, FE filed a petition in the Sixth Circuit seeking to appeal that order. On August 13, 2025, the Sixth Circuit vacated the S.D. Ohio’s order granting class certification. On November 6, 2025, the S.D. Ohio held oral argument to further consider class certification in light of the Sixth Circuit’s decision. On April 30, 2026, the S.D. Ohio issued an order recertifying plaintiffs’ proposed class. FE filed a petition in the Sixth Circuit to appeal that order on May 14, 2026, which was granted on September 28, 2026. FE believes that it is probable that it will incur a loss in connection with the resolution of this lawsuit. Given the ongoing nature and complexity of such litigation, FE cannot yet reasonably estimate a loss or range of loss.

•MFS Series Trust I, et al. v. FirstEnergy Corp., et al. and Brighthouse Funds II – MFS Value Portfolio, et al. v. FirstEnergy Corp., et al. (S.D. Ohio); on December 17, 2021, and February 21, 2022, purported stockholders of FE filed complaints against FE, certain current and former officers, and certain then-current and former officers of Energy Harbor Corp. The complaints allege that the defendants violated Sections 10(b) and 20(a) of the Exchange Act by making alleged misrepresentations or omissions regarding FE’s business and its results of operations, and seek the same relief as the In re FirstEnergy Corp. Securities Litigation described above. FE believes that it is probable that it will incur losses in connection with the resolution of these lawsuits. Given the ongoing nature and complexity of such litigation, FE cannot yet reasonably estimate a loss or range of loss.

The outcome of any of these lawsuits is uncertain and could have a material adverse effect on FE’s or its subsidiaries’ reputation, business, financial condition, results of operations, liquidity, and cash flows.

Other Legal Matters

There are various lawsuits, claims (including claims for asbestos exposure) and proceedings related to the Registrants’ normal business operations pending against them or their subsidiaries. The loss or range of loss in these matters is not expected to be material to the Registrants. The other potentially material items not otherwise discussed above are described under Note 9., “Regulatory Matters” of the Combined Notes to Financial Statements of the Registrants.

The Registrants accrue legal liabilities only when they conclude that it is probable that they have an obligation for such costs and can reasonably estimate the amount of such costs. In cases where the Registrants determine that it is not probable, but reasonably possible that they have a material obligation, they disclose such obligations and the possible loss or range of loss if such estimate can be made. If it were ultimately determined that the Registrants have legal liability or are otherwise made subject to liability based on any of the matters referenced above, it could have a material adverse effect on the Registrants’ financial condition, results of operations, and cash flows.

11. SEGMENT INFORMATION

The disclosures in this note apply to all Registrants, unless indicated otherwise.

FirstEnergy

FE and its subsidiaries are principally involved in the transmission, distribution and generation of electricity through its reportable segments: Distribution, Integrated and Stand-Alone Transmission. The external reportable segments are consistent with the internal financial reports used by FirstEnergy's Chairman, President and Chief Executive Officer, its CODM, to regularly assess the performance of each segment. FirstEnergy's CODM uses earnings attributable to FE from continuing operations to assess performance, including considering actual versus budget variances to make operating decisions and allocate resources to the segments.

FirstEnergy’s Distribution segment, which consists of the Ohio Companies and FE PA, distributes electricity through FirstEnergy’s electric operating companies in Ohio and Pennsylvania. The Distribution segment serves approximately 4.3 million customers in Ohio and Pennsylvania across its distribution footprint and purchases power for its default service or standard service offer requirements. The segment’s results reflect the costs of securing and delivering electric generation to customers, including the deferral and amortization of certain costs.

FirstEnergy’s Integrated segment includes the distribution and transmission operations of JCP&L, MP and PE, as well as MP’s regulated generation operations. The Integrated segment distributes electricity to approximately 2 million customers in New Jersey, West Virginia and Maryland across its distribution footprint; provides transmission infrastructure in New Jersey, West Virginia, Maryland and Virginia to transmit electricity and operates 3,610 MWs of regulated generation capacity located primarily in West Virginia and Virginia, which includes three solar generation sites, representing 30 MWs of generation capacity. The segment’s results reflect the costs of securing and delivering electric generation to customers, including the deferral and amortization of certain costs. Additionally, on February 13, 2026, MP and PE filed a CPCN to construct and operate the 1,200 MW combined cycle gas turbine plant, that will be known as Maidsville Energy Center, and the 70 MWs of solar generation capacity, each referenced in their integrated resource plan above, for an estimated capital investment totaling approximately $2.7 billion as of the date of the filing. See Note 9., “Regulatory Matters,” of the Combined Notes to Financial Statements of the Registrants for additional details.

FirstEnergy’s Stand-Alone Transmission segment, which consists of FE's ownership in FET and KATCo, includes transmission infrastructure owned and operated by the Transmission Companies and used to transmit electricity. The segment’s revenues are primarily derived from forward-looking formula rates, pursuant to which the revenue requirement is updated annually based on a projected rate base and projected costs, which is subject to an annual true-up based on actual rate base and costs. The segment’s results also reflect the net transmission expenses related to the delivery of electricity on FirstEnergy’s transmission facilities.

FirstEnergy’s Corporate/Other reflects corporate support and other costs not charged or attributable to the Electric Companies or Transmission Companies, including FE’s retained pension and OPEB assets and liabilities of former subsidiaries, interest expense on FE’s holding company debt and other investments or businesses that do not constitute an operating segment. Reconciling adjustments for the elimination of inter-segment transactions are shown separately in the following table of Segment Financial Information. Included in Corporate/Other for segment reporting is 67 MWs of generation capacity, representing AE Supply’s OVEC capacity entitlement. As of September 30, 2026, Corporate/Other had approximately $7.6 billion of external FE holding company debt.

Financial information for FirstEnergy’s reportable segments and reconciliations to consolidated amounts is presented below:


(In millions) For the Three Months Ended	Distribution		Integrated		Stand-Alone Transmission		Total Reportable Segments	Corporate/ Other		Reconciling Adjustments	FirstEnergy Consolidated

September 30, 2026
External revenues	$	2,244			$	1,809		$	496		$	4,549		$	8		$	—	$	4,557
Internal revenues	9			1			5		15		—		(15)			—
Total revenues	$	2,253			$	1,810		$	501		$	4,564		$	8		$	(15)	$	4,557
Other operating expenses(1)	656			600			82		1,338		(13)		(2)			1,323
Depreciation(1)	165			144			100		409		18		—			427
Amortization (deferral) of regulatory assets, net	42			(146)			1		(103)		—		—			(103)

Interest expense(1)	110			85			89		284		91		(30)			345
Income taxes (benefits)(1)	45			60			44		149		(80)		—			69
Other expense (income) items(2)	951			862			100		1,913		(4)		30			1,939
Earnings (losses) attributable to FE	284			205			85		574		(17)		—			557
Cash Flows from Investing Activities:
Capital investments	$	544			$	581		$	485		$	1,610		$	(23)		$	—	$	1,587

September 30, 2025
External revenues	$	2,010			$	1,651		$	483		$	4,144		$	4		$	—	$	4,148
Internal revenues	10			2			5		17		—		(17)			—
Total revenues	$	2,020			$	1,653		$	488		$	4,161		$	4		$	(17)	$	4,148
Other operating expenses(1)	570			337			75		982		(3)		(3)			976
Depreciation(1)	165			141			92		398		19		—			417
Amortization of regulatory assets, net	46			42			1		89		—		—			89

Interest expense(1)	101			75			83		259		85		(32)			312
Income taxes (benefits)(1)	48			60			(21)		87		(9)		—			78
Other expense (income) items(2)	860			815			136		1,811		(8)		32			1,835
Earnings (losses) attributable to FE	230			183			122		535		(94)		—			441
Cash Flows from Investing Activities:
Capital investments	$	416			$	508		$	412		$	1,336		$	(20)		$	—	$	1,316

For the Nine Months Ended
September 30, 2026
External revenues	$	5,929			$	4,944		$	1,542		$	12,415		$	22		$	—	$	12,437
Internal revenues	28			3			19		50		—		(50)			—
Total revenues	$	5,957			$	4,947		$	1,561		$	12,465		$	22		$	(50)	$	12,437
Other operating expenses(1)	2,034			1,690			256		3,980		(24)		(8)			3,948
Depreciation(1)	494			425			295		1,214		58		—			1,272
Amortization (deferral) of regulatory assets, net	(375)			(414)			4		(785)		—		—			(785)

Interest expense(1)	327			246			262		835		264		(91)			1,008
Income taxes (benefits)(1)	142			144			137		423		(124)		—			299
Other expense (income) items(2)	2,662			2,375			334		5,371		(17)		91			5,445
Earnings (losses) attributable to FE	673			481			273		1,427		(177)		—			1,250
Cash Flows from Investing Activities:
Capital investments	$	1,335			$	1,587		$	1,235		$	4,157		$	30		$	—	$	4,187


(In millions)	Distribution		Integrated		Stand-Alone Transmission		Total Reportable Segments	Corporate/ Other		Reconciling Adjustments	FirstEnergy Consolidated
September 30, 2025
External revenues	$	5,602			$	4,259		$	1,420		$	11,281		$	12		$	—	$	11,293
Internal revenues	29			4			15		48		—		(48)			—
Total revenues	$	5,631			$	4,263		$	1,435		$	11,329		$	12		$	(48)	$	11,293
Other operating expenses(1)	1,831			980			247		3,058		(45)		(8)			3,005
Depreciation(1)	490			418			275		1,183		60		—			1,243
Amortization (deferral) of regulatory assets, net	(71)			47			4		(20)		—		—			(20)

Interest expense(1)	301			208			237		746		253		(100)			899
Income taxes (benefits)(1)	151			135			55		341		(49)		—			292
Other expense (income) items(2)	2,320			2,040			339		4,699		6		100			4,805
Earnings (losses) attributable to FE	609			435			278		1,322		(253)		—			1,069
Cash Flows from Investing Activities:
Capital investments	$	976			$	1,336		$	1,161		$	3,473		$	66		$	—	$	3,539

As of September 30, 2026
Total assets	$	21,919			$	22,110		$	15,649		$	59,678		$	1,788		$	(1,638)	$	59,828
Total goodwill	$	3,222			$	1,953		$	443		$	5,618		$	—		$	—	$	5,618

As of December 31, 2025
Total assets	$	20,653			$	20,352		$	14,903		$	55,908		$	1,793		$	(1,797)	$	55,904
Total goodwill	$	3,222			$	1,953		$	443		$	5,618		$	—		$	—	$	5,618

(1) FirstEnergy considers this line to be a significant expense.

(2) Consists of Fuel, Purchased power, General taxes, Debt redemption costs, Miscellaneous income, net, Capitalized financing costs, and Income attributable to noncontrolling interest.

FE PA

FE PA has one operating segment, which is the entire entity. FE PA's Consolidated Statements of Income and Comprehensive Income are consistent with the internal financial reports used by FE PA's President, its CODM. FE PA's CODM uses net income to regularly assess performance and considers actual versus budget variances to make operating decisions and allocate resources. FE PA considers Other operating expenses, Provision for depreciation, General taxes, Interest expense and Income taxes to be significant expenses. See FE PA’s Consolidated Statements of Income and Comprehensive Income. Total Assets are reported on FE PA’s Consolidated Balance Sheets, and Capital investments are reported within Cash Flows from Investing on FE PA’s Consolidated Statements of Cash Flows.

JCP&L

As of January 1, 2026, JCP&L made changes in how management evaluates operating performance and allocates resources. As a result of these changes, JCP&L reassessed its operating segments and determined that its operations are now managed as a single integrated business. Historically, JCP&L reported two operating segments, Distribution and Transmission. Accordingly, JCP&L changed its external segment reporting to present its results, including comparative periods, as a single reportable segment for the first nine months of 2026, and reclassified prior periods for comparability. There are no changes to JCP&L’s significant expenses, measure of profit or loss, or other segment items. Similarly, JCP&L’s goodwill reporting units were also changed to a single reporting unit as of January 1, 2026.

JCP&L’s Statements of Income and Comprehensive Income are consistent with the internal financial reports used by JCP&L's President, its CODM. JCP&L’s CODM uses net income to regularly assess performance, including considering actual versus budget variances to make operating decisions and allocate resources. JCP&L considers Other operating expenses, Provision for depreciation and Interest expense to be significant expenses. See JCP&L’s Statements of Income and Comprehensive Income. Total Assets are reported on JCP&L’s Balance Sheets and Capital investments are reported within Cash Flows from Investing on JCP&L’s Statement of Cash Flows.

12. TRANSACTIONS WITH AFFILIATES

The disclosures in this note apply to FE PA and JCP&L only.

FE does not bill directly or allocate any of its costs to any subsidiary company. FESC provides corporate support and other services, including executive administration, accounting and finance, risk management, human resources, corporate affairs, communications, information technology, legal services and other similar services at cost, in accordance with its cost allocation manual, to affiliated FirstEnergy companies under FESC agreements. Allocated costs are for services that are provided on behalf of more than one company, or costs that cannot be precisely identified and are allocated using formulas developed by FESC. Intercompany transactions are generally settled under commercial terms within thirty days. FE PA and JCP&L can also receive charges from and charge affiliates other than FESC at cost.

FE PA and JCP&L recognize an allocation of the net periodic pension and OPEB costs/credits from their affiliates, primarily FESC.

Under the FirstEnergy regulated money pool, FE PA and JCP&L have the ability to borrow from their regulated affiliates and FE to meet their short-term working capital requirements. Affiliated company notes receivables and payables related to the money pool are reported as Notes receivable from affiliated companies or Short-term borrowings - affiliated companies on their respective Balance Sheets. Affiliate accounts receivable and accounts payable balances relate to intercompany transactions that have not yet settled through the FirstEnergy money pool.

FE PA and JCP&L are party to an intercompany income tax allocation agreement with FE and its subsidiaries (excluding FET and its subsidiaries) that provides for the allocation of consolidated tax liabilities.

FE PA

The affiliated company transactions for FE PA for the three and nine months ended September 30, 2026, and 2025, respectively, are as follows:


	Three Months Ended September 30,		Nine Months Ended September 30,
	2026		2025		2026		2025
	(In millions)
Revenues (1)	$	4			$	5		$	13	$	16

Expenses:
FESC support services (2)	74			67			211		212
Other affiliate support services (2)	(12)			(11)			(35)		(33)
Interest income	4			4			15		13
Interest expense	6			6			18		18

(1) Includes ground lease revenues from MAIT, KATCo and ATSI.

(2) Includes amounts capitalized of $35 million and $27 million for the three months ended September 30, 2026, and 2025, respectively, and $92 million and $79 million for the nine months ended September 30, 2026, and 2025, respectively.

JCP&L

The affiliated company transactions for JCP&L for the three and nine months ended September 30, 2026, and 2025, respectively, are as follows:


	Three Months Ended September 30,		Nine Months Ended September 30,
	2026		2025		2026		2025
	(In millions)
Revenues	$	—			$	—		$	1	$	1

Expenses:
FESC support services (1)	46			43			131		135
Other affiliate support services (1)	5			3			18		8
Interest income	—			1			—		1
Interest expense	4			3			9		6

(1) Includes amounts capitalized of $23 million and $19 million for the three months ended September 30, 2026, and 2025, respectively, and $64 million and $57 million for the nine months ended September 30, 2026, and 2025, respectively.

ITEM 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

FIRSTENERGY CORP.

MANAGEMENT’S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following Management’s Discussion and Analysis of Financial Condition and Results of Operations in this Form 10-Q discusses the three and nine months ended September 30, 2026, and year-over-year comparisons between the three and nine months ended September 30, 2026, and 2025, and should be read in conjunction with FirstEnergy’s interim financial statements and notes included in this Form 10-Q, and FirstEnergy’s audited financial statements, notes and “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Part II, Item 7 of its Annual Report on Form 10-K for the year ended December 31, 2025, filed with the SEC on February 18, 2026.

EXECUTIVE SUMMARY AND RECENT DEVELOPMENTS

Company Overview

FirstEnergy is dedicated to integrity, safety, reliability and operational excellence and is principally involved in the transmission, distribution and generation of electricity through its reportable segments: Distribution, Integrated and Stand-Alone Transmission. Its electric distribution companies form one of the nation's largest investor-owned electric systems, serving over 6 million customers in Ohio, Pennsylvania, New Jersey, West Virginia, Maryland and New York. FirstEnergy’s transmission subsidiaries operate more than 24,000 miles of transmission lines that connect the Midwest and Mid-Atlantic regions and two regional transmission operation centers. As of September 30, 2026, AGC and MP control 3,610 MWs of net maximum generation capacity.

Segment Overview

See Note 11., “Segment Information,” of the Combined Notes to Financial Statements of the Registrants.

Investment Strategy

FirstEnergy invests in both its regulated operations to improve reliability and the customer experience, and its people to attract, retain and develop talented and engaged employees to carry out its strategy.

FirstEnergy is uniquely positioned to take advantage of data center growth, both in its service territory and across the region. As of October 27, 2026, FirstEnergy has contracted approximately 8 GWs of capacity and was in active negotiations concerning approximately 4 GWs of additional load. FirstEnergy expects this load growth to drive an increase in the 2027 to 2031 Energize365 investment plan, compared to the current 2026 to 2030 Energize365 investment plan, which is expected to further enhance FirstEnergy’s long-term earnings growth profile.

FirstEnergy’s customer-focused Energize365 investment plan for 2026 to 2030 is $36 billion, approximately 25% higher than the previous 2025 to 2029 five-year plan, and aims to strengthen the grid, improve reliability and support growing customer demand. Through the Energize365 program, system-wide capital investments from 2026 to 2030 are expected to include 28% in the Distribution segment, 35% in the Integrated segment, and 35% in the Stand-Alone Transmission segment, focused on the following:

•Distribution and Transmission investments to enhance grid reliability and resiliency and support growing customer demand, including through:

•Programs to drive system resiliency through automation technology and communication, including the Ohio Companies’ distribution grid modernization plans, Pennsylvania's LTIIP, New Jersey's EnergizeNJ, and implementing advanced metering infrastructure;

•Operational flexibility projects that are expected to build capacity and support the evolving grid such as projects to support increased data center load;

•Enhancing system performance by implementing new designs and technologies to reduce load at risk;

•Upgrading system conditions that enhance reliability; and

•Transmission projects awarded through the PJM RTEP Open Window to address regional expansion projects, including incremental opportunities submitted by FET through its subsidiaries.

•Base distribution projects to address aging infrastructure.

•Generation maintenance projects that maintain operations of fossil electric generation facilities and remain compliant with environmental regulations through the end of their useful life.

FirstEnergy believes there is a continued long-term pipeline of investment opportunities for its existing distribution and transmission infrastructure beyond those opportunities identified through 2030, which are expected to strengthen the grid and cyber security and make the transmission system more reliable, robust, secure and resistant to extreme weather events, with improved operational flexibility.

Finance

FirstEnergy aims to execute its Energize365 investment plan through a strengthened financial position. Energize365 capital investments included in the current five-year plan are expected to be funded with a combination of organic cash flows and the issuance of debt, including hybrid securities. The financing plan for the current $36 billion 2026 to 2030 investment program includes up to $2 billion of equity or equity-like securities through 2030. Additionally, FirstEnergy may issue its common equity to fund capital expenditures in its 2026 through 2030 planning period averaging approximately 1% of its now current market capitalization in each year of the planning period, subject to market conditions and other factors. FirstEnergy believes it has optimized its financing plan to retain flexibility in an uncertain interest rate environment.

On March 30, 2026, Moody’s revised FE’s outlook to positive from stable. Moody’s also affirmed FE’s ratings, including its Baa3 Issuer and senior unsecured ratings.

On September 15, 2026, Fitch affirmed the ratings of FE and all subsidiaries. Fitch also affirmed the outlook of FE and all subsidiaries excluding OE, CEI, and TE whose outlooks were revised to stable.

On October 23, 2026, FE, the Electric Companies, Transmission Companies, and FET, each entered into an amended credit facility to, among other things: (i) extend the maturity date of each credit facility for an additional one-year period (a) from October 20, 2029 to October 18, 2030 for the KATCo credit facility, (b) from October 20, 2030 to October 20, 2031 for the FET credit facility and (c) from October 18, 2029 to October 18, 2030 for the remaining Amended Credit Facilities; (ii) allow for the option to extend the Credit Agreement by up to two additional one-year periods; and (iii) increase the letters of credit commitment amount from $100 million to $400 million for the MP and PE credit facility.

Dividend Growth

FirstEnergy continues to return value to shareholders. In February 2026, the FE Board declared a $0.02 per share increase in the quarterly cash common stock dividend to $0.465 per share, payable June 1, 2026, representing a 4.5% increase compared to dividends declared in 2025. In September 2026, the FE Board declared a quarterly cash common stock dividend of $0.465 per share payable December 1, 2026. Modest dividend growth is expected to enable enhanced shareholder returns, while still allowing for continued substantial regulated investments. Dividend payments are subject to declaration by the FE Board, and future dividend decisions determined by the FE Board may be impacted by earnings, cash flows, credit metrics and general economic and other business conditions.

Significant PJM RTEP Open Window Projects

On February 21, 2025, FET, DominionHV and Transource entered into the Valley Link Operating Agreement, which established the general framework for Valley Link and the Valley Link Subsidiaries to accept, design, develop, construct, own, operate and finance those transmission projects awarded by PJM to Valley Link. This general framework includes parameters regarding the relationship among the three members, confers governance rights to its members so long as certain ownership percentages are maintained, as described below, and defines the list of projects that Valley Link will have the right to develop. Valley Link is the owner of the Valley Link Subsidiaries, which are organized in various states. On February 26, 2025, in response to the 2024 PJM RTEP Open Window, PJM awarded two electric transmission projects to Valley Link estimated to be approximately $3 billion, with FET’s share estimated to be approximately $1 billion.

On February 13, 2026, FET and Transource entered into the Grid Growth Operating Agreement, which established the general framework for Grid Growth to accept, design, develop, construct, own, operate and finance certain transmission projects awarded by PJM to certain of the subsidiaries of Grid Growth. This general framework includes parameters regarding the relationship between the two members, confers governance rights to its members so long as certain ownership percentages are maintained and defines the list of projects that Grid Growth will have the right to develop. The relative ownership interests of the members under the Grid Growth Operating Agreement are 50% for each of FET and Transource. Grid Growth is the sole owner of Grid Growth Ohio and owns an 80% interest in Grid Growth EHV, with Transource owning the remaining interest. On February 12, 2026, in response to the 2025 PJM RTEP Open Window, PJM awarded a project to Grid Growth estimated to be approximately $1 billion, with FET’s share estimated to be approximately $448 million.

Regulatory Matters - Maryland

On September 4, 2026, PE filed with the MDPSC a distribution base rate case seeking to, among other things, increase PE’s Maryland annual base rate distribution revenues by approximately $53 million and approve a proposed three-year program focused on improving reliability. The case uses a historic test year of twelve months ending March 31, 2026, and contemplates a requested ROE of 10.6% with no proposed changes to PE’s current capital structure of approximately 54% equity and 46% debt. Evidentiary hearings are scheduled to begin January 11, 2027. A final order and new effective rates are expected in the second quarter of 2027.

On May 12, 2026, the governor of Maryland signed the Utility RELIEF Act into law. Among other things, the legislation temporarily limits the use of forecasted costs in certain rate proceedings, modifies the standards by which the MDPSC may

approve multi-year rate plans, mandates RTO participation, requires additional review of utility spending and cost recovery, eliminates certain utility earnings incentives, imposes restrictions on recovery of certain administrative compensation costs and includes provisions designed to allocate certain transmission and distribution upgrade costs associated with large-load customers, including data centers, to those customers rather than to the broader customer base. FirstEnergy continues to monitor the full extent of the legislation’s impacts, but the Utility RELIEF Act may affect PE’s timing and amount of cost recovery, authorized returns, customer rate structures, infrastructure investment planning, and future earnings opportunities. See “Outlook - State Regulation - Maryland” and “Outlook – FERC Regulatory Matters – Utility RELIEF Act and Related FERC Complaint,” in Item 2., \"Management's Discussion and Analysis of Financial Condition and Results of Operations\" for a more fulsome discussion of the current Utility RELIEF Act impacts to PE.

Regulatory Matters – New Jersey

Regulatory Matters - Ohio

On May 31, 2024, the Ohio Companies filed their application for an increase in base distribution rates based on a 2024 calendar year test period. The PUCO issued an order in the base rate case on November 19, 2025. A number of applications for rehearing were subsequently filed and on June 10, 2026, the PUCO issued its last entry on rehearing. On August 10, 2026, the Ohio Companies appealed the matter to the Supreme Court of Ohio where it remains pending. The Ohio Companies cannot predict the outcome of the matter. See “Outlook - State Regulation - Ohio,” in Item 2., \"Management's Discussion and Analysis of Financial Condition and Results of Operations.”

On April 22, 2026, the Ohio Companies filed with the PUCO a notice of their intent to file a three-year rate plan, requesting approval of three consecutive, annual test periods that begin July 1, 2027 and end June 30, 2030. The Ohio Companies filed their applications for an increase in their distribution rates on May 22, 2026. The application proposes net increases in the Ohio Companies’ base distribution revenues of approximately $254 million in the first year, approximately $59 million in the second year, and approximately $80 million in the third year, with an ROE of 10.2% and a capital structure of approximately 47% debt and approximately 53% equity for all three Ohio Companies. On June 12, 2026, PUCO staff issued a deficiency letter requesting additional supplementation in certain areas, which the Ohio Companies provided on June 22, 2026. On July 1, 2026, an administrative law judge deemed the application complete and set a procedural schedule. Evidentiary hearings are set to begin March 1, 2027.

Regulatory Matters - West Virginia

On October 1, 2025, MP and PE filed their integrated resource plan with the WVPSC. To allow MP and PE to meet their PJM adequacy requirements, the plan proposes, among other things, near-term market capacity purchases and the addition of 70 MWs of solar generation by 2028 and 1,200 MWs of natural gas combined cycle generation by 2031. On February 13, 2026, MP and PE filed a CPCN to construct and operate the proposed generation resources, including a 1,200 MW combined cycle gas turbine plant, that will be known as the Maidsville Energy Center, and 70 MWs of solar generation capacity, for an estimated capital investment of approximately $2.7 billion as of the filing date. The request also includes a surcharge designed to recover financing costs during development and construction of the projects, as well as a transition to recovery in base rates once the projects are placed in service and approved through a base rate case. An evidentiary hearing on the integrated resource plan was held on May 6, 2026, and evidentiary hearings on the CPCN application were held on July 16 and 17, 2026. A final order is expected from the WVPSC in the fourth quarter of 2026.

FirstEnergy expects to finalize the remaining major contracts shortly after receiving a satisfactory final WVPSC order. To support the proposed Maidsville Energy Center project schedule, FirstEnergy has entered into a reservation agreement with Siemens Energy, Inc. for turbines scheduled for delivery in 2030. As described in the CPCN case, any contemplated data center agreements utilizing the Maidsville Energy Center's output, would be expected to address customer protections, pricing, risk transfer and long-term benefit sharing for existing West Virginia customers. Separately from the Maidsville Energy Center, FirstEnergy has issued a request for proposals for an initial 3 GWs of additional combined-cycle turbines to support potential large-load customers in West Virginia and expects to provide an update in early 2027. FirstEnergy is also exploring bridge-power options and temporary behind-the-meter solutions as it develops the grid to support these customers with permanent transmission and generation service.

another base rate case until April 1, 2028. The WVPSC issued a procedural order on May 21, 2026, on the alternative two-phase approach setting it for hearing on July 9, 2026. On June 11, 2026, the WVPSC staff filed a motion to dismiss, which the WVPSC denied on July 2, 2026. The WVPSC held a hearing on the alternative two-phase approach on July 9, 2026. On July 31, 2026, the WVPSC issued an order approving the alternative two-phase approach without modification. New rates associated with the first phase became effective on August 1, 2026. The matter was appealed to the Supreme Court of Appeals of West Virginia on August 31, 2026 and remains pending before the court. MP and PE cannot predict the outcome of this appeal.

FIRSTENERGY’S CONSOLIDATED RESULTS OF OPERATIONS

Third Quarter of 2026 Compared with Third Quarter of 2025


(In millions, except per share amounts)	For the Three Months Ended September 30,
	2026		2025		Increase (Decrease)

Revenues	$	4,557			$	4,148		$	409		10	%

Operating expenses	(3,622)			(3,318)			304		9	%

Other expenses, net	(251)			(220)			31		14	%

Income taxes	(69)			(78)			(9)		(12)	%

Income attributable to noncontrolling interest	(58)			(91)			(33)		(36)	%

Earnings attributable to FE	$	557			$	441		$	116		26	%

EPS Attributable to FE:
Basic	$	0.96			$	0.76		$	0.20		26	%
Diluted	$	0.96			$	0.76		$	0.20		26	%

Earnings attributable to FE increased $116 million primarily due to the following:

•Higher transmission revenues from regulated capital investments that increased rate base;

•Higher rider revenues and customer demand;

•The absence in 2026 of customer credits associated with the PUCO-approved Ohio Stipulation recognized in 2025;

•Higher pension and OPEB non-service credits;

•Lower investigation and other related costs associated with the ongoing government investigations and ongoing litigation;

•Higher capitalized financing costs; and

•The recognition of a state tax benefit related to an uncertain tax position being effectively settled in 2026 and absence of a discrete tax charge recognized in 2025 related to the FET Equity Interest Sale.

These factors were partially offset by the following:

•Higher interest expenses from new long-term debt and convertible note issuances, net of redemptions and repayments; and

•The absence of a discrete tax benefit related to a remeasurement of excess deferred income taxes recognized in 2025.

Detailed segment reporting explanations are included below.

Distribution services by customer class are summarized in the following table:


	For the Three Months Ended September 30,
(In thousands)	Actual	Weather-Adjusted
Electric Distribution MWh Deliveries	2026	2025		Increase	2026		2025		Increase (Decrease)

Residential	15,597		15,448		1.0	%		15,206		15,295	(0.6)	%
Commercial(1)	10,850		10,597		2.4	%		10,747		10,634	1.1	%
Industrial	14,124		13,667		3.3	%		14,124		13,667	3.3	%

Total Electric Distribution MWh Deliveries	40,571		39,712		2.2	%		40,077		39,596	1.2	%

(1) Includes street lighting.

Cooling degree days in the third quarter of 2026 were 5% above the same period of 2025 and 4% above normal. Heating degree days in the third quarter of 2026 were 20% above the same period of 2025 and 16% below normal. Industrial deliveries in the third quarter of 2026 compared to the same period of 2025 increased primarily due to growth in the manufacturing, oil and gas extraction, and advanced technologies sectors.

FIRSTENERGY’S CONSOLIDATED RESULTS OF OPERATIONS

First Nine Months of 2026 Compared with First Nine Months of 2025


(In millions, except per share amounts)	For the Nine Months Ended September 30,
	2026		2025		Increase (Decrease)

Revenues	$	12,437			$	11,293		$	1,144		10	%

Operating expenses	(9,997)			(9,063)			934		10	%

Other expenses, net	(708)			(674)			34		5	%

Income taxes	(299)			(292)			7		2	%

Income attributable to noncontrolling interest	(183)			(195)			(12)		(6)	%

Earnings attributable to FE	$	1,250			$	1,069		$	181		17	%

EPS Attributable to FE:
Basic	$	2.16			$	1.85		$	0.31		17	%
Diluted	$	2.16			$	1.85		$	0.31		17	%

Earnings attributable to FE were increased $181 million primarily due to the following:

•Higher transmission revenues from regulated capital investments that increased rate base and true-up adjustments from the annual forward-looking transmission rate filing;

•Higher rider revenues and customer demand;

•The absence in 2026 of customer credits associated with the PUCO-approved Ohio Stipulation recognized in 2025;

•The absence in 2026 of severance and related costs that were recognized in the first quarter of 2025;

•Higher pension and OPEB non-service credits;

•A reduction in ARO liabilities associated with CCR rules based on the completion of engineering studies and field analysis of certain sites during 2026;

•The absence in 2026 of debt redemption costs recognized in 2025; and

These factors were partially offset by the following:

•Higher investigation and other related costs associated with the ongoing government investigations and ongoing litigation;

•Higher interest expenses from new long-term debt and convertible note issuances, net of redemptions and repayments, and higher capitalized financing costs; and

•The absence of a discrete tax benefit related to a remeasurement of excess deferred income taxes recognized in 2025.

Detailed segment reporting explanations are included below.

Distribution services by customer class are summarized in the following table:


	For the Nine Months Ended September 30,
(In thousands)	Actual	Weather-Adjusted
Electric Distribution MWh Deliveries	2026	2025		Increase	2026		2025		Increase (Decrease)

Residential	42,883		42,896		—	%		42,276		42,429	(0.4)	%
Commercial(1)	30,424		30,025		1.3	%		30,207		30,038	0.6	%
Industrial	40,570		39,474		2.8	%		40,570		39,474	2.8	%

Total Electric Distribution MWh Deliveries	113,877		112,395		1.3	%		113,053		111,941	1.0	%

(1) Includes street lighting.

Cooling degree days in the first nine months of 2026 were 4% above the same period of 2025 and 5% above normal. Heating degree days in the first nine months of 2026 were 1% above the same period of 2025 and near normal. Industrial deliveries in the first nine months of 2026 compared to the same period of 2025 increased primarily due to growth in the manufacturing, oil and gas extraction and advanced technologies sectors.

The financial results discussed below in Segment Results of Operations include revenues and expenses from transactions among FirstEnergy’s business segments. A reconciliation of segment financial results is provided in Note 11., “Segment Information,” of the Combined Notes to Financial Statements of the Registrants.

Summary of Results of Operations — Third Quarter 2026 Compared with Third Quarter 2025

Financial results for FirstEnergy’s business segments for the third quarter of 2026 and 2025 were as follows:


Third Quarter 2026 Financial Results (In millions)	Distribution		Integrated		Stand-Alone Transmission		Corporate/Other and Reconciling Adjustments	FirstEnergy Consolidated
Revenues:
Electric	$	2,214			$	1,784		$	496	$	8	$	4,502
Other	39			26			5		(15)	55
Total Revenues	2,253			1,810			501		(7)	4,557

Operating Expenses:
Fuel	—			189			—		—	189
Purchased power	783			684			—		4	1,471
Other operating expenses	656			600			82		(15)	1,323
Provision for depreciation	165			144			100		18	427
Amortization (deferral) of regulatory assets, net	42			(146)			1		—	(103)
General taxes	203			35			64		13	315
Total Operating Expenses	1,849			1,506			247		20	3,622



Other Income (Expense):


Miscellaneous income (expense), net	26			28			(6)		(9)	39

Interest expense	(110)			(85)			(89)		(61)	(345)
Capitalized financing costs	9			18			28		—	55
Total Other Expense	(75)			(39)			(67)		(70)	(251)


Income taxes (benefits)	45			60			44		(80)	69





Income attributable to noncontrolling interest	—			—			58		—	58

Earnings (Loss) Attributable to FE	$	284			$	205		$	85	$	(17)	$	557


Third Quarter 2025 Financial Results (In millions)	Distribution		Integrated		Stand-Alone Transmission		Corporate/Other and Reconciling Adjustments	FirstEnergy Consolidated
Revenues:
Electric	$	1,977			$	1,640		$	483	$	4	$	4,104
Other	43			13			5		(17)	44
Total Revenues	2,020			1,653			488		(13)	4,148

Operating Expenses:
Fuel	—			163			—		—	163
Purchased power	681			655			—		5	1,341
Other operating expenses	570			337			75		(6)	976
Provision for depreciation	165			141			92		19	417
Amortization of regulatory assets, net	46			42			1		—	89
General taxes	209			37			73		13	332
Total Operating Expenses	1,671			1,375			241		31	3,318



Other Income (Expense):


Miscellaneous income (expense), net	22			22			4		(7)	41

Interest expense	(101)			(75)			(83)		(53)	(312)
Capitalized financing costs	8			18			24		1	51
Total Other Expense	(71)			(35)			(55)		(59)	(220)


Income taxes (benefits)	48			60			(21)		(9)	78




Income attributable to noncontrolling interest	—			—			91		—	91

Earnings (Loss) Attributable to FE	$	230			$	183		$	122	$	(94)	$	441


Changes Between Third Quarter 2026 and Third Quarter 2025 Financial Results (In millions)	Distribution		Integrated		Transmission		Corporate/Other and Reconciling Adjustments	FirstEnergy Consolidated
Revenues:
Electric	$	237			$	144		$	13	$	4	$	398
Other	(4)			13			—		2	11

Total Revenues	233			157			13		6	409

Operating Expenses:
Fuel	—			26			—		—	26
Purchased power	102			29			—		(1)	130
Other operating expenses	86			263			7		(9)	347
Provision for depreciation	—			3			8		(1)	10
Amortization (deferral) of regulatory assets, net	(4)			(188)			—		—	(192)
General taxes	(6)			(2)			(9)		—	(17)
Total Operating Expenses	178			131			6		(11)	304



Other Income (Expense):


Miscellaneous income (expense), net	4			6			(10)		(2)	(2)

Interest expense	(9)			(10)			(6)		(8)	(33)
Capitalized financing costs	1			—			4		(1)	4
Total Other Expense	(4)			(4)			(12)		(11)	(31)


Income taxes (benefits)	(3)			—			65		(71)	(9)





Income attributable to noncontrolling interest	—			—			(33)		—	(33)

Earnings (Loss) Attributable to FE	$	54			$	22		$	(37)	$	77	$	116

Distribution Segment — Third Quarter of 2026 Compared with Third Quarter of 2025

Distribution segment’s earnings attributable to FE increased $54 million in the third quarter of 2026, as compared to the same period of 2025, primarily due to the absence in 2026 of customer credits associated with the PUCO-approved Ohio Stipulation recognized in 2025, higher rider revenues, increased customer demand, lower property taxes, higher pension and OPEB non-service credits, and lower operating expenses, partially offset by higher net financing costs.

Revenues —

Distribution segment’s total revenues increased $233 million as a result of the following sources:


		For the Three Months Ended September 30,
Revenues by Type of Service	2	2026		2025		Increase (Decrease)
		(In millions)
Distribution services		$	1,356		2		$	1,239		$	117
Generation sales:
Retail		851			732			119
Wholesale		7			6			1
Total generation sales		858			738			120




Other		39			43			(4)
Total Revenues		$	2,253			$	2,020		$	233

Distribution services revenues increased $117 million in the third quarter of 2026, as compared to the same period of 2025, primarily due to higher customer usage, higher rider revenues associated with certain regulated investment programs and the absence in 2026 of customer credits associated with the PUCO-approved Ohio Stipulation recognized in 2025. Additionally, revenues increased due to the higher recovery of transmission expenses, which have no material impact to earnings.

Generation sales revenues increased $120 million in the third quarter of 2026, as compared to the same period in 2025, primarily due to higher non-shopping generation auction rates. Total generation provided by alternative suppliers as a percentage of total MWh deliveries for the Ohio Companies and FE PA was flat in the third quarter of 2026, as compared to the same period of 2025. Retail and wholesale generation sales revenues have no material impact to earnings.

Operating Expenses —

Total operating expenses increased $178 million, primarily due to:

•Purchased power costs, which have no material impact to earnings, increased $102 million during the third quarter of 2026, as compared to the same period of 2025, primarily due to higher unit costs as described above.

•Other operating expenses increased $86 million in the third quarter of 2026, as compared to the same period of 2025, primarily due to:

•Higher storm restoration expenses of $122 million, which were deferred for future recovery; and

•Higher vegetation management expenses of $9 million in Ohio, as approved and recovering in the base rate case.

The increase was partially offset by:

•Lower other operating expenses of $21 million, primarily due to accelerated vegetation management work in 2025 in Pennsylvania;

•Lower energy efficiency and other state mandated program costs of $7 million, which were deferred for future recovery, resulting in no material impact to earnings; and

•Lower network transmission expenses of $17 million, which are deferred for future recovery, resulting in no material impact to earnings.

•Depreciation expense was flat in the third quarter of 2026, as compared to the same period of 2025, primarily due to a higher asset base, offset by a change in depreciation rates effective March 1, 2026, as a result of the Ohio Base Rate Case.

•Amortization of regulatory assets, net decreased $4 million in the third quarter of 2026, as compared to the same period of 2025, primarily due to higher deferred storm restoration expenses of $122 million, partially offset by a $79 million net decrease in generation and transmission deferrals, a $12 million decrease from lower deferral of costs associated with customer assistance programs, a $14 million increase in amortization associated with recovery of previously incurred storm costs and a $13 million net decrease in other deferrals.

•General taxes decreased $6 million in the third quarter of 2026, as compared to the same period of 2025, primarily due to lower property taxes, partially offset by higher gross receipts taxes.

Other Expense —

Other expense increased $4 million in the third quarter of 2026, as compared to the same period of 2025, primarily due to higher interest expense as a result of new debt issuances since the third quarter of 2025, partially offset by higher pension and OPEB non-service credits.

Income Taxes —

Distribution segment’s effective tax rate was 13.7% and 17.3% for the three months ended September 30, 2026, and 2025, respectively. The decrease in the effective tax rate was primarily due to increases in state flow-through tax benefits.

Integrated Segment — Third Quarter of 2026 Compared with Third Quarter of 2025

Integrated segment’s earnings attributable to FE increased $22 million in the third quarter of 2026, as compared to the same period of 2025, primarily due to higher transmission revenues from regulated capital investments that increased rate base, lower operating expenses, higher pension and OPEB non-service credits and increased customer usage and demand, partially offset by higher net financing costs.

Revenues —

Integrated segment’s total revenues increased $157 million as a result of the following sources:


		For the Three Months Ended September 30,
Revenues by Type of Service	2	2026		2025		Increase
		(In millions)
Distribution services		$	500			$	498		$	2
Generation sales:
Retail		958			904			54
Wholesale		198			129			69
Total generation sales		$	1,156			$	1,033		$	123
Transmission revenues:



JCP&L		80			67			13
MP & PE		48			42			6
Total transmission revenues		$	128			$	109		$	19
Other		26			13			13
Total Revenues		$	1,810			$	1,653		$	157

Distribution services revenues increased $2 million in the third quarter of 2026, as compared to the same period of 2025, primarily due to higher customer usage and higher recovery of transmission expenses, the recovery of which has no material impact to earnings, partially offset by the return of certain ZEC refunds in New Jersey, as further described below. These refunds were offset by the amortization of a regulatory liability resulting in no impact to earnings.

Generation sales revenues increased $123 million in the third quarter of 2026, as compared to the same period of 2025, primarily due to:

•Retail generation sales increased $54 million in the third quarter of 2026, as compared to the same period in 2025, primarily due to higher non-shopping generation auction rates and higher volumes as a result of the warmer weather temperatures. Retail generation sales, other than those in West Virginia, have no material impact to earnings.

•Wholesale generation revenues increased $69 million in the third quarter of 2026, as compared to the same period in 2025, primarily due to higher wholesale rates, capacity revenues and higher sales volumes. The difference between current wholesale generation revenues and certain energy costs incurred is deferred for future recovery or refund, with no material impact to earnings.

Transmission revenues increased $19 million in the third quarter of 2026, as compared to the same period of 2025, primarily due to higher recovery of transmission operating expenses and higher rate base from regulated investment programs.

Other revenues increased $13 million in the third quarter of 2026, as compared to the same period of 2025, due to higher FTR credits, which offset higher transmission congestion charges. Due to the ENEC, FTRs have no material impact to earnings.

Operating Expenses —

Total operating expenses increased $131 million, primarily due to:

•Fuel costs increased $26 million during the third quarter of 2026, as compared to the same period of 2025, primarily due to higher consumption volumes and unit costs. Due to the ENEC, fuel expense has no material impact to earnings.

•Purchased power costs, which have no material impact to earnings, increased $29 million during the third quarter of 2026, as compared to the same period of 2025, primarily due to higher capacity expenses and prices.

•Other operating expenses increased $263 million in the third quarter of 2026, as compared to the same period of 2025, primarily due to:

•Higher network transmission expenses of $31 million, which were deferred for future recovery, resulting in no material impact to earnings;

•Higher transmission congestion charges of $14 million. Due to the ENEC, congestion charges, net of FTR revenue, have no material impact to earnings;

•Higher storm restoration expenses of $201 million, which were mostly deferred for future recovery;

•Higher formula rate transmission operating and maintenance expenses of $3 million, which have no material impact to earnings;

•$5 million pre-tax impairment charge related to JCP&L’s Morristown, New Jersey general office; and

•Higher energy efficiency and other state mandated program costs of $24 million, which were deferred for future recovery, resulting in no material impact to earnings.

The increase was partially offset by:

•Lower regulated generation outage expenses of $9 million, primarily due to fewer planned outages; and

•Lower other operating expenses of $6 million, primarily due to planned maintenance expenses.

•Depreciation expense increased $3 million in the third quarter of 2026, as compared to the same period of 2025, primarily due to a higher asset base.

•Deferral of regulatory assets increased $188 million in the third quarter of 2026, as compared to the same period of 2025, primarily due to $193 million in higher deferral of storm related expenses and $13 million related to net increases in other deferrals, partially offset by an $18 million net decrease from lower generation and transmission related deferrals.

Other Expense —

Other expense increased $4 million in the third quarter of 2026, as compared to the same period of 2025, primarily due to higher interest expense as a result of new debt issuances since the third quarter 2025, partially offset by higher capitalized interest and higher pension and OPEB non-service credits.

Income Taxes —

Integrated segment’s effective tax rate was 22.6% and 24.7% for the three months ended September 30, 2026, and 2025, respectively. The decrease in the effective tax rate was primarily due to an increase in the tax benefit from the amortization of excess deferred income taxes.

Stand-Alone Transmission Segment — Third Quarter of 2026 Compared with Third Quarter of 2025

Stand-Alone Transmission segment’s earnings attributable to FE decreased $37 million in the third quarter of 2026, as compared to the same period of 2025, primarily due to the absence of a discrete tax benefit related to a remeasurement of excess deferred income taxes recognized in 2025 and higher net financing costs, partially offset by higher revenues from regulated capital investments that increased overall rate base.

Revenues —

Stand-Alone Transmission segment’s total revenues increased $13 million, primarily due to a higher overall rate base.

The following table shows revenues by transmission asset owner:


		For the Three Months Ended September 30,
Revenues by Transmission Asset Owner	1	2026		2025		Increase (Decrease)
		(In millions)
ATSI		$	264			$	275		$	(11)
TrAIL		62			68			(6)
MAIT		149			121			28
KATCo		26			24			2

Total Revenues		$	501			$	488		$	13

Operating Expenses —

Total operating expenses increased $6 million in the third quarter of 2026, as compared to the same period of 2025, primarily due to higher depreciation and higher operating and maintenance expenses, partially offset by lower property tax expenses. Nearly all operating expenses are recovered through formula rates.

Other Expense —

Total other expense increased $12 million in the third quarter of 2026, as compared to the same period of 2025, primarily due to higher interest expenses from new long-term debt issuances and higher interest on transmission revenue collection balances, partially offset by higher capitalized financing costs.

Income Taxes —

Stand-Alone Transmission segment’s effective tax rate was 23.5% and (10.9)% for the three months ended September 30, 2026, and 2025, respectively. The increase in the effective tax rate was primarily due to the absence of a tax benefit related to a remeasurement of excess deferred income taxes recognized in 2025.

Corporate / Other — Third Quarter 2026 Compared with Third Quarter 2025

Financial results at Corporate/Other resulted in a $77 million decrease in losses attributable to FE in the third quarter of 2026, as compared to the same period of 2025, primarily due to:

•Higher discrete tax benefits in 2026 compared to 2025, primarily due to recognition of a $69 million state tax benefit related to an uncertain tax position being effectively settled in 2026 and absence of a discrete tax charge recognized in 2025 related to the FET Equity Interest Sale; and

•$5 million (after-tax) of lower investigation and other related costs associated with the ongoing government investigations and ongoing litigation.

The decrease in losses was partially offset by:

•$3 million (after-tax) of higher interest expense from higher average short-term borrowings.

Summary of Results of Operations — First Nine Months of 2026 Compared with First Nine Months of 2025

Financial results for FirstEnergy’s business segments for the first nine months of 2026 and 2025 were as follows:


First Nine Months 2026 Financial Results (In millions)	Distribution		Integrated		Stand-Alone Transmission		Corporate/Other and Reconciling Adjustments	FirstEnergy Consolidated
Revenues:
Electric	$	5,843			$	4,713		$	1,542	$	22	$	12,120
Other	114			234			19		(50)	317
Total Revenues	5,957			4,947			1,561		(28)	12,437

Operating Expenses:
Fuel	—			506			—		—	506
Purchased power	2,153			1,891			—		13	4,057
Other operating expenses	2,034			1,690			256		(32)	3,948
Provision for depreciation	494			425			295		58	1,272
Amortization (deferral) of regulatory assets, net	(375)			(414)			4		—	(785)
General taxes	620			111			231		37	999
Total Operating Expenses	4,926			4,209			786		76	9,997



Other Income (Expense):


Miscellaneous income (expense), net	86			78			—		(25)	139

Interest expense	(327)			(246)			(262)		(173)	(1,008)
Capitalized financing costs	25			55			80		1	161
Total Other Expense	(216)			(113)			(182)		(197)	(708)


Income taxes (benefits)	142			144			137		(124)	299





Income attributable to noncontrolling interest	—			—			183		—	183



Earnings (Loss) Attributable to FE	$	673			$	481		$	273	$	(177)	$	1,250


First Nine Months 2025 Financial Results (In millions)	Distribution		Integrated		Stand-Alone Transmission		Corporate/Other and Reconciling Adjustments	FirstEnergy Consolidated
Revenues:

Electric	$	5,508			$	4,228		$	1,420	$	12	$	11,168
Other	123			35			15		(48)	125

Total Revenues	5,631			4,263			1,435		(36)	11,293

Operating Expenses:
Fuel	—			480			—		—	480
Purchased power	1,808			1,559			—		15	3,382
Other operating expenses	1,831			980			247		(53)	3,005
Provision for depreciation	490			418			275		60	1,243
Amortization (deferral) of regulatory assets, net	(71)			47			4		—	(20)
General taxes	605			108			222		38	973
Total Operating Expenses	4,663			3,592			748		60	9,063



Other Income (Expense):
Debt redemption costs	—			—			—		(24)	(24)

Miscellaneous income (expense), net	73			59			17		(31)	118

Interest expense	(301)			(208)			(237)		(153)	(899)
Capitalized financing costs	20			48			61		2	131
Total Other Expense	(208)			(101)			(159)		(206)	(674)


Income taxes (benefits)	151			135			55		(49)	292




Income attributable to noncontrolling interest	—			—			195		—	195

Earnings (Loss) Attributable to FE	$	609			$	435		$	278	$	(253)	$	1,069


Changes Between First Nine Months 2026 and First Nine Months 2025 Financial Results (In millions)	Distribution		Integrated		Stand-Alone Transmission		Corporate/Other and Reconciling Adjustments	FirstEnergy Consolidated
Revenues:

Electric	$	335			$	485		$	122	$	10	$	952
Other	(9)			199			4		(2)	192

Total Revenues	326			684			126		8	1,144

Operating Expenses:
Fuel	—			26			—		—	26
Purchased power	345			332			—		(2)	675
Other operating expenses	203			710			9		21	943
Provision for depreciation	4			7			20		(2)	29
Amortization (deferral) of regulatory assets, net	(304)			(461)			—		—	(765)
General taxes	15			3			9		(1)	26
Total Operating Expenses	263			617			38		16	934



Other Income (Expense):
Debt redemption costs	—			—			—		24	24

Miscellaneous income (expense), net	13			19			(17)		6	21

Interest expense	(26)			(38)			(25)		(20)	(109)
Capitalized financing costs	5			7			19		(1)	30
Total Other Expense	(8)			(12)			(23)		9	(34)


Income taxes (benefits)	(9)			9			82		(75)	7





Income attributable to noncontrolling interest	—			—			(12)		—	(12)

Earnings (Loss) Attributable to FE	$	64			$	46		$	(5)	$	76	$	181

Distribution Segment — First Nine Months of 2026 Compared with First Nine Months of 2025

Distribution segment’s earnings attributable to FE increased $64 million in the first nine months of 2026, as compared to the same period of 2025, primarily driven by the absence in 2026 of customer credits associated with the PUCO-approved Ohio Stipulation and severance-related costs recognized in the first quarter of 2025, a reduction in ARO liabilities, higher rider revenues, increased customer demand, lower property taxes, higher pension and OPEB non-service credits, and lower operating expenses, partially offset by higher net financing costs.

Revenues —

Distribution segment’s total revenues increased $326 million as a result of the following sources:


	For the Nine Months Ended September 30,
Revenues by Type of Service	2026		2025		Increase (Decrease)
	(In millions)
Distribution services	$	3,460			$	3,474		$	(14)
Generation sales:
Retail	2,367			2,024			343
Wholesale	16			10			6
Total generation sales	2,383			2,034			349




Other	114			123			(9)
Total Revenues	$	5,957			$	5,631		$	326

Distribution services revenues decreased $14 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to customer restitution and refunds resulting from the Ohio Companies’ PUCO-approved settlement. These restitution and refunds were recognized in the fourth quarter of 2025 and are offset by the amortization of a regulatory liability resulting in no impact to earnings in 2026. The revenue decrease was partially offset by higher rider revenues associated with certain regulated investment programs and the absence in 2026 of customer credits associated with the PUCO-approved Ohio Stipulation recognized in 2025 and higher customer usage. Additionally, revenues increased due to the higher recovery of transmission expenses, which have no material impact to earnings.

Generation sales revenues increased $349 million in the first nine months of 2026, as compared to the same period in 2025, primarily due to higher non-shopping generation auction rates. Total generation provided by alternative suppliers as a percentage of total MWh deliveries for the Ohio Companies and FE PA was flat in the first nine months of 2026, as compared to the same period of 2025. Retail and wholesale generation sales revenue have no material impact to earnings.

Operating Expenses —

Total operating expenses increased $263 million, primarily due to:

•Purchased power costs, which have no material impact to earnings, increased $345 million during the first nine months of 2026, as compared to the same period of 2025, primarily due to higher unit costs.

•Other operating expenses increased $203 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to:

•Higher network transmission expenses of $20 million, which were deferred for future recovery, resulting in no material impact to earnings;

•Higher energy efficiency and other state mandated program costs of $18 million, which were deferred for future recovery, resulting in no material impact to earnings;

•Higher other operating expenses of $20 million, primarily due to planned maintenance expenses;

•Higher vegetation management expenses of $9 million in Ohio, as approved and recovering in the base rate case; and

•Higher storm restoration expenses of $204 million, which were deferred for future recovery.

The increase was partially offset by:

•Lower planned vegetation management expenses of $34 million in Pennsylvania, primarily due to accelerated work in 2025;

•Lower uncollectible expenses of $8 million; which were deferred for future recovery, resulting in no material impact to earnings;

•A $10 million reduction in ARO liabilities recognized in the second quarter of 2026 and associated with CCR rules based on the completion of engineering studies and field analysis of certain sites; and

•The absence in 2026 of $16 million of severance and related costs associated with FirstEnergy’s organizational changes announced and recognized in the first quarter of 2025.

•Depreciation expense increased $4 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to a higher asset base, partially offset by a change in depreciation rates effective March 1, 2026, as a result of the Ohio Base Rate Case.

•Deferral of regulatory assets increased $304 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to higher deferred storm restoration expenses of $204 million and a $250 million increase in the amortization of a regulatory liability as a result of providing restitution and refunds to Ohio customers, partially offset by a $31 million increase in amortization associated with recovery of previously incurred storm costs, a $30 million decrease from lower deferral of costs associated with customer assistance programs, a $57 million net decrease in generation and transmission deferrals and a $32 million net decrease in other deferrals.

•General taxes increased $15 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to higher property and gross receipts taxes, partially offset by lower property taxes.

Other Expense —

Other expense increased $8 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to higher interest expense as a result of new debt issuances since the first quarter of 2025, partially offset by higher capitalized interest and higher pension and OPEB non-service credits.

Income Taxes —

Distribution segment’s effective tax rate was 17.4% and 19.9% for the nine months ended September 30, 2026, and 2025, respectively. The decrease in the effective tax rate was primarily due to increases in state flow-through tax benefits and a remeasurement of the reserve for an uncertain tax position in the second quarter of 2026.

Integrated Segment — First Nine Months of 2026 Compared with First Nine Months of 2025

Integrated segment’s earnings attributable to FE increased $46 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to the absence in 2026 of severance and related costs that were recognized in the first quarter of 2025, higher transmission revenues from regulated capital investments that increased rate base, true-up adjustments from the annual forward-looking transmission rate filing, increased customer usage and demand, lower operating expenses and higher pension and OPEB non-service credits, partially offset by higher net financing costs.

Revenues —

Integrated segment’s total revenues increased $684 million as a result of the following sources:


	For the Nine Months Ended September 30,
Revenues by Type of Service	2026		2025		Increase
	(In millions)
Distribution services (1)	$	1,318			$	1,312		$	6
Generation sales:
Retail	2,564			2,342			222
Wholesale	435			254			181
Total generation sales	2,999			2,596			403
Transmission revenues:



JCP&L	240			191			49
MP & PE	156			129			27
Total transmission revenues	396			320			76
Other	234			35			199
Total Revenues	$	4,947			$	4,263		$	684

(1) Includes $13 million of ARP revenues in 2026, related to lost distribution revenues associated with energy efficiency in New Jersey.

Distribution services revenues increased $6 million in the first nine months of 2026, as compared to the same period of 2025, primarily resulting from higher customer usage and higher rider revenues associated with certain regulated investment programs, partially offset by the conclusion of the New Jersey ZEC program effective June 1, 2025 and the return of certain ZEC refunds in New Jersey as further described below. These refunds were offset by the amortization of a regulatory liability resulting in no impact to earnings. Additionally, revenues increased due to the higher recovery of transmission expenses, which have no material impact to earnings.

Generation sales revenues increased $403 million in the first nine months of 2026, as compared to the same period of 2025.

•Retail generation sales increased $222 million in the first nine months of 2026, as compared to the same period in 2025, primarily due to higher non-shopping generation auction rates and higher volumes as a result of the weather temperatures. Retail generation sales, other than those in West Virginia, have no material impact to earnings.

•Wholesale generation revenues increased $181 million in the first nine months of 2026, as compared to the same period in 2025, primarily due to higher wholesale rates and capacity revenues, partially offset by lower sales volumes. The difference between current wholesale generation revenues and certain energy costs incurred is deferred for future recovery or refund, with no material impact to earnings.

Transmission revenues increased $76 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to higher recovery of transmission operating expenses, higher rate base from regulated investment programs, and true-up adjustments from the annual forward-looking transmission rate filing.

Other revenues increased $199 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to higher FTR credits, which offset higher transmission congestion charges. Due to the ENEC, FTRs have no material impact to earnings.

Operating Expenses —

Total operating expenses increased $617 million, primarily due to:

•Fuel costs increased $26 million during the first nine months of 2026, as compared to the same period of 2025, primarily due to higher unit costs, offset by lower consumption volumes. Due to the ENEC, fuel expense has no material impact to earnings.

•Purchased power costs, which have no material impact to earnings, increased $332 million during the first nine months of 2026, as compared to the same period of 2025, primarily due to higher volumes, capacity expenses and prices, which were impacted by the Winter Storm Fern weather event in the first quarter of 2026.

•Other operating expenses increased $710 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to:

•Higher network transmission expenses of $72 million, which were deferred for future recovery, resulting in no material impact to earnings;

•Higher transmission congestion charges of $256 million, primarily in the first quarter of 2026 from the net impacts of the Winter Storm Fern weather event. Due to the ENEC, congestion charges, net of FTR revenue, have no material impact to earnings;

•Higher storm restoration expenses of $318 million, of which $311 million were deferred for future recovery;

•Higher formula rate transmission operating and maintenance expenses of $19 million, which have no material impact to earnings;

•Higher vegetation management expenses of $27 million, which were mostly deferred for future recovery, resulting in no material impact to earnings;

•$5 million pre-tax impairment charge related to JCP&L’s Morristown, New Jersey general office; and

•Higher energy efficiency and other state mandated program costs of $62 million, which were deferred for future recovery, resulting in no material impact to earnings.

The increase was partially offset by:

•Lower regulated generation outage spend of $6 million, primarily due to fewer planned outages;

•The absence in 2026 of $12 million of severance and related costs associated with FirstEnergy’s organizational changes announced and recognized in the first quarter of 2025; and

•Lower other operating expenses of $31 million, primarily due to the absence in 2026 of a legal reserve recognized in the second quarter of 2025 and lower planned maintenance expenses.

•Deferral of regulatory assets increased $461 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to $305 million in higher deferral of storm related expenses, a $5 million increase related to the

amortization of a regulatory liability associated with ZEC refunds, further described below, a $137 million net increase from higher generation and transmission related deferrals and a $14 million related to net increases in other deferrals.

•General taxes increased $3 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to higher property taxes.

Other Expense —

Other expense increased $12 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to higher interest expense as a result of new debt issuances since the first quarter of 2025, partially offset by higher capitalized interest and higher pension and OPEB non-service credits.

Income Taxes —

Integrated segment’s effective tax rate was 23.0% and 23.7% for the nine months ended September 30, 2026, and 2025, respectively.

Stand-Alone Transmission Segment — First Nine Months of 2026 Compared with First Nine Months of 2025

Stand-Alone Transmission segment’s earnings attributable to FE decreased $5 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to the absence of a discrete tax benefit related to a remeasurement of excess deferred income taxes recognized in 2025 and higher net financing costs, partially offset by higher revenues from regulated capital investments that increased overall rate base and true-up adjustments from the annual forward-looking transmission rate filings.

Revenues —

Stand-Alone Transmission segment’s total revenues increased $126 million, primarily due to a higher overall rate base, higher recovery of transmission operating expenses, and true-up adjustments from the annual forward-looking transmission rate filings.

The following table shows revenues by transmission asset owner:


	For the Nine Months Ended September 30,
Revenues by Transmission Asset Owner	2026		2025		Increase (Decrease)
	(In millions)
ATSI	$	849			$	799		$	50
TrAIL	193			201			(8)
MAIT	438			367			71
KATCo	81			68			13

Total Revenues	$	1,561			$	1,435		$	126

Operating Expenses —

Total operating expenses increased $38 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to higher depreciation and property tax expenses from a higher asset base and planned operating and maintenance expenses. Nearly all operating expenses are recovered through formula rates.

Other Expense —

Total other expense increased $23 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to higher interest expenses from new long-term debt issuances and higher interest on transmission revenue collection balances, partially offset by higher capitalized financing costs.

Income Taxes —

Stand-Alone Transmission segment’s effective tax rate was 23.1% and 10.4% for the nine months ended September 30, 2026, and 2025, respectively. The increase in the effective tax rate was primarily due to the absence of a tax benefit related to a remeasurement of excess deferred income taxes recognized in 2025.

Corporate / Other — First Nine Months of 2026 Compared with First Nine Months of 2025

Financial results at Corporate/Other resulted in a $76 million decrease in losses attributable to FE in the first nine months of 2026, as compared to the same period of 2025, primarily due to:

•$18 million (after-tax) due to the absence in 2026 of debt redemption costs recognized in 2025; and

•$5 million (after-tax) of higher income associated with a legacy purchase power contract.

The decrease in losses was partially offset by:

•$12 million (after-tax) of higher investigation and other related costs associated with the ongoing government investigations and ongoing litigation; and

•$7 million (after-tax) of higher interest expense associated with the convertible notes issuances, net of redemptions and repayments, and higher average short-term borrowings.

REGULATORY ASSETS AND LIABILITIES

Regulatory assets represent incurred costs that have been deferred because of their probable future recovery from customers through regulated rates. Regulatory liabilities represent amounts that are expected to be credited to customers through future regulated rates or amounts collected from customers for costs not yet incurred. The Registrants net their regulatory assets and liabilities based on federal and state jurisdictions.

Management assesses the probability of recovery of regulatory assets, and settlement of regulatory liabilities, at each balance sheet date and whenever new events occur. Factors that may affect probability relate to changes in the regulatory environment, issuance of a regulatory commission order or passage of new legislation. Upon material changes to these factors, where applicable, FirstEnergy will record new regulatory assets and liabilities and will assess whether it is probable that currently recorded regulatory assets and liabilities will be recovered or settled in future rates.

FirstEnergy has regulatory assets of approximately $1.6 billion and $829 million, and regulatory liabilities of $923 million and approximately $1.2 billion as of September 30, 2026, and December 31, 2025, respectively. The following table provides information about the composition of FirstEnergy’s net regulatory assets and liabilities as of September 30, 2026, and December 31, 2025, and the changes during the nine months ended September 30, 2026:


Net Regulatory Assets (Liabilities) by Source - FirstEnergy	September 30, 2026		December 31, 2025		Change
	(In millions)
Customer payables for future income taxes	$	(1,919)			$	(2,041)		$	122
Spent nuclear fuel disposal costs	(58)			(76)			18
Asset removal costs	(587)			(675)			88
Deferred transmission costs	(136)			(43)			(93)
Deferred generation costs	440			405			35
Deferred distribution costs	561			466			95
Storm-related costs	1,612			1,122			490
Energy efficiency program costs	570			462			108
New Jersey societal benefit costs	54			80			(26)
Vegetation management costs	173			153			20
Ohio settlement charges	—			(250)			250
New Jersey ZEC refunds	(56)			(4)			(52)
Other	16			45			(29)
Net Regulatory Assets (Liabilities) included on FirstEnergy’s Consolidated Balance Sheets	$	670			$	(356)		$	1,026

The following table provides information about the composition of FE PA’s net regulatory assets and liabilities as of September 30, 2026, and December 31, 2025, and the changes during the nine months ended September 30, 2026:


Net Regulatory Assets (Liabilities) by Source - FE PA	September 30, 2026		December 31, 2025		Change
	(In millions)
Customer payables for future income taxes	$	(289)			$	(341)		$	52

Asset removal costs	131			84			47
Deferred transmission costs	(6)			(14)			8
Deferred generation costs	(26)			(26)			—
Deferred distribution costs	16			13			3
Storm-related costs	511			356			155
Energy efficiency program costs	(3)			19			(22)



Other	15			18			(3)
Net Regulatory Assets included on FE PA’s Balance Sheets	$	349			$	109		$	240

The following table provides information about the composition of JCP&L’s net regulatory assets and liabilities as of September 30, 2026, and December 31, 2025, and the changes during the nine months ended September 30, 2026:


Net Regulatory Assets (Liabilities) by Source - JCP&L	September 30, 2026		December 31, 2025		Change
	(In millions)
Customer payables for future income taxes	$	(377)			$	(393)		$	16
Spent nuclear fuel disposal costs	(58)			(76)			18
Asset removal costs	(68)			(87)			19
Deferred transmission costs	(25)			(25)			—
Deferred generation costs	(2)			(10)			8
Deferred distribution costs	357			318			39
Storm-related costs	638			367			271
Energy efficiency program costs	462			316			146
New Jersey societal benefit costs	54			80			(26)

New Jersey ZEC refunds	(56)			(4)			(52)
Other	25			29			(4)
Net Regulatory Assets included on JCP&L’s Balance Sheets	$	950			$	515		$	435

The following is a description of the regulatory assets and liabilities described above:

Customer payables for future income taxes - Reflects amounts to be recovered or refunded through future rates to pay income taxes that become payable when rate revenue is provided to recover items such as AFUDC equity and depreciation of property, plant and equipment for which deferred income taxes were not recognized for ratemaking purposes, including amounts attributable to federal and state tax rate changes such as the TCJA and Pennsylvania House Bill 1342. These amounts are being amortized over the period in which the related deferred tax assets reverse, which is generally over the expected life of the underlying asset.

Spent nuclear fuel disposal costs - Reflects amounts collected from customers, and the investment income, losses and changes in fair value of the trusts for spent nuclear fuel disposal costs related to former nuclear generation facilities, Oyster Creek and Three Mile Island Unit 1.

Asset removal costs - Primarily represents the rates charged to customers that include a provision for the cost of future activities to remove assets, including obligations for which an ARO has been recognized, that are expected to be incurred at the time of retirement.

Deferred transmission costs - Reflects differences between revenues earned based on actual costs for the formula-rate Transmission Companies and the amounts billed. Also included is the recovery of non-market based costs or fees charged to certain of the Electric Companies by various regulatory bodies including FERC and RTOs, which can include PJM charges and credits for service including, but not limited to, procuring transmission services and transmission enhancement.

Deferred generation costs - Primarily relates to regulatory assets associated with the securitized recovery of certain fuel and purchased power regulatory assets at the Ohio Companies (amortized through 2034), the Warrior Run purchased power agreement termination fee at PE (amortized through 2029), and the ENEC at MP and PE. MP and PE recover net power supply costs, including fuel costs, purchased power costs and related expenses, net of related market sales revenue through the ENEC, which reflects the impact of Winter Storm Fern in 2026. Generally, the ENEC rate is updated annually.

Deferred distribution costs - Primarily relates to the Ohio Companies' deferral of certain distribution-related expenses, including interest (amortized through 2034) and JCP&L’s AMI program costs.

Storm-related costs - Relates to the deferral of storm restoration costs, which vary by jurisdiction. The following table provides the amount of storm-related restoration costs for the Registrants that were being recovered through rates as of September 30, 2026, and December 31, 2025:


Storm-Related Costs Currently Being Recovered Through Rates	September 30, 2026		December 31, 2025
	(In millions)
FirstEnergy	$	664		$	335
FE PA	$	219		$	234
JCP&L	$	94		$	73

Energy efficiency program costs - Relates to the recovery of costs in excess of revenues associated with energy efficiency programs including New Jersey energy efficiency and renewable energy programs, FE PA's Energy Efficiency and Conservation programs, the Ohio Companies' Demand Side Management and Energy Efficiency Rider, and PE's EmPOWER Maryland Surcharge. Investments in certain of these energy efficiency programs earn a long-term return.

New Jersey societal benefit costs - Primarily relates to regulatory assets associated with MGP remediation, universal service and lifeline funds, and the New Jersey Clean Energy Program.

Vegetation management costs - Relates to regulatory assets associated with the recovery of certain distribution vegetation management costs in New Jersey, certain distribution and transmission vegetation management costs in West Virginia, and certain transmission vegetation management costs at ATSI (amortized through 2030) and KATCo (amortized through 2036).

Ohio settlement charges - Reflects restitution and refunds owed to customers associated with the Ohio Companies' PUCO-approved settlement order, which began to be provided to customers in February 2026, and has been refunded to customers as of September 30, 2026. See Note 9., \"Regulatory Matters,\" of the Combined Notes to Financial Statements of the Registrants for additional details.

New Jersey ZEC refunds - Reflects refunds owed to customers associated with the NJBPU's order requiring certain nuclear generating units to return duplicate ZEC payments received during 2024. See Note 9., \"Regulatory Matters,\" of the Combined Notes to Financial Statements of the Registrants for additional details.

The following table provides information about the composition of FirstEnergy’s regulatory assets that do not earn a current return as of September 30, 2026, and December 31, 2025, of which approximately $894 million and $802 million, respectively, are currently being recovered through rates over varying periods, through 2068, depending on the nature of the deferral and the jurisdiction:


Regulatory Assets by Source Not Earning a Current Return - FirstEnergy	September 30, 2026		December 31, 2025		Change
	(In millions)

Deferred generation costs	$	362			$	280		$	82
Deferred distribution costs	185			199			(14)
Storm-related costs	1,278			844			434

Other	87			102			(15)
FirstEnergy Regulatory Assets Not Earning a Current Return	$	1,912			$	1,425		$	487

The following table provides information about the composition of FE PA’s regulatory assets that do not earn a current return as of September 30, 2026, and December 31, 2025, of which approximately $329 million and $347 million, respectively, are currently being recovered through rates over varying periods, through 2029, depending on the nature of the deferral:


Regulatory Assets by Source Not Earning a Current Return - FE PA	September 30, 2026		December 31, 2025		Change
	(In millions)



Storm-related costs	$	511			$	356		$	155
Energy efficiency program costs	14			23			(9)
Other	14			17			(3)
FE PA Regulatory Assets Not Earning a Current Return	$	539			$	396		$	143

The following table provides information about the composition of JCP&L’s regulatory assets that do not earn a current return as of September 30, 2026, and December 31, 2025, of which approximately $98 million and $76 million, respectively, are currently being recovered through rates over varying periods, through 2068, depending on the nature of the deferral:


Regulatory Assets by Source Not Earning a Current Return - JCP&L	September 30, 2026		December 31, 2025		Change
	(In millions)


Deferred distribution costs	$	131			$	147		$	(16)
Storm-related costs	629			367			262

Other	25			24			1
JCP&L Regulatory Assets Not Earning a Current Return	$	785			$	538		$	247

CAPITAL RESOURCES AND LIQUIDITY

The Registrants’ businesses are capital intensive, requiring significant resources to fund operating expenses, construction and other investment expenditures, scheduled debt maturities and interest payments, dividend payments and potential contributions to the pension plan.

The Registrants expect their existing sources of liquidity to remain sufficient to meet their respective anticipated obligations. In addition to internal sources to fund liquidity and capital requirements for the remainder of 2026 and beyond, the Registrants expect to rely on external sources of funds. Short-term cash requirements not met by cash provided from operations are generally satisfied through short-term borrowings. Long-term cash needs may be met through the issuance of long-term debt by the Registrants, which may include hybrid securities by FE to, among other things, fund capital expenditures and other capital-like investments, and refinance short-term and maturing long-term debt, subject to market conditions and other factors. Additionally, FE may issue its common equity to fund capital expenditures in its 2026 through 2030 planning period averaging approximately 1% of its current market capitalization in each year of the planning period, subject to market conditions and other factors.

In alignment with FirstEnergy’s strategy to invest in its segments as a fully regulated company, FirstEnergy is focused on maintaining balance sheet strength and flexibility. Specifically, at the regulated businesses, regulatory authority has been obtained for various regulated subsidiaries to issue and/or refinance debt.

Any financing plans by FE or any of its consolidated subsidiaries, including the issuance of equity and debt, and the refinancing of short-term and maturing long-term debt are subject to market conditions and other factors. No assurance can be given that any such issuances, financing or refinancing, as the case may be, will be completed as anticipated or at all. Any delay in the completion of financing plans could require FE or any of its subsidiaries to utilize short-term borrowing capacity, which could impact available liquidity. In addition, FE and its subsidiaries expect to continually evaluate any planned financings, which may result in changes from time to time.

supply chain disruptions that could, in turn, have an adverse effect on the Registrants’ results of operations, cash flow and financial condition.

As of September 30, 2026, FirstEnergy’s, FE PA’s and JCP&L’s net deficit in working capital (current assets less current liabilities) was approximately $5.5 billion, $102 million and $542 million, respectively, primarily due to current portion of long-term debt, accounts payable, short-term borrowings and accrued interest, taxes, and compensation and benefits. The Registrants believe their cash from operations and available liquidity will be sufficient to meet their current working capital needs. See further discussion on cash from operations below.

Short-Term Borrowings / Revolving Credit Facilities

Borrowings under each of the Amended Credit Facilities may be used for working capital and other general corporate purposes. Generally, borrowings under each of the credit facilities are available to each borrower separately and mature on the earlier of 364 days from the date of borrowing or the commitment termination date, as the same may be extended. Each of the Amended Credit Facilities contains financial covenants requiring each borrower, with the exception of FE, to maintain a consolidated debt-to-total-capitalization ratio (as defined under each of the Amended Credit Facilities) of no more than 65%, and 75% for FET, measured at the end of each fiscal quarter. FE is required under its credit facility to maintain a consolidated interest coverage ratio of not less than 2.50 times, measured at the end of each fiscal quarter for the last four fiscal quarters.

Each of the Amended Credit Facilities bears interest at fluctuating interest rates, primarily based on SOFR, including term SOFR and daily simple SOFR. FirstEnergy has not hedged its interest rate exposure with respect to its floating rate debt. Accordingly, FirstEnergy’s interest expense for any particular period will fluctuate based on SOFR and other variable interest rates. Restricted access to capital markets and/or increased borrowing costs could have an adverse effect on FirstEnergy’s results of operations, cash flows, financial condition and liquidity.

FE Term Loan Facility

FirstEnergy had $1,970 million and $325 million of outstanding short-term borrowings as of September 30, 2026, and December 31, 2025, respectively. FirstEnergy’s available liquidity as of October 27, 2026, was as follows:


Revolving Credit Facilities	Maturity	Commitment		Available Liquidity
		(In millions)
FE	October 2030	$	1,000			$	722
FET	October 2031	1,000			620
Ohio Companies	October 2030	800			618
FE PA	October 2030	950			949
JCP&L	October 2030	750			150
MP and PE	October 2030	400			369
ATSI, MAIT and TrAIL	October 2030	850			849
KATCo	October 2030	150			150
	Subtotal	$	5,900			$	4,427
Cash and cash equivalents	—		21
	Total	$	5,900			$	4,448

The following table summarizes the limitations on short-term indebtedness applicable to each borrower under current regulatory approvals and applicable statutory and/or charter limitations as of September 30, 2026:


Individual Borrower	Regulatory Debt Limitations		Credit Facility Commitment	Actual Debt-to-Total-Capitalization Ratio
	(In millions)
FE		N/A		$	1,000			N/A(2)
ATSI(1)		$	500			350			40.8	%
CEI(1)		750			300			51.9	%
FET		N/A		1,000			65.9	%
FE PA(1)		1,250			950			48.4	%
JCP&L(1)		1,500			750			42.4	%
KATCo(1)		200			150			30.7	%
MAIT(1)		400			350			38.3	%
MP(1)		900			250			47.9	%
OE(1)		500			300			50.2	%
PE(1)		450			150			49.3	%
TE(1)		300			200			49.4	%
TrAIL(1)		400			150			39.0	%

(1) Regulatory debt limitations include amounts which may be borrowed under the regulated companies’ money pool.

(2) FE is not required to maintain a debt-to-total-capitalization ratio under its credit facility. However, FE is required to maintain a consolidated interest coverage ratio of not less than 2.50 times, measured at the end of each fiscal quarter for the last four fiscal quarters. FE's consolidated interest coverage ratio as of September 30, 2026, was approximately 4.0 times.

Subject to each borrower’s sublimit, the amounts noted below are available for the issuance of LOCs (subject to borrowings drawn under the Amended Credit Facilities) expiring up to one year from the date of issuance. The stated amount of outstanding LOCs will count against total commitments available under each of the Amended Credit Facilities and against the applicable borrower’s borrowing sublimit. As of September 30, 2026, FirstEnergy had $187 million in outstanding LOCs, $63 million of which are issued under the Amended Credit Facilities.


Revolving Credit Facility	LOC Availability as of September 30, 2026		LOC Utilized as of September 30, 2026
	(In millions)
FE	$	100			$	3
FET	100			—
Ohio Companies	150			27
FE PA	200			1
JCP&L	100			—
MP and PE	100			31
ATSI, MAIT and TrAIL	200			1
KATCo	35			—

Each of the Amended Credit Facilities does not contain provisions that restrict the ability to borrow or accelerate payment of outstanding advances in the event of any change in credit ratings of the borrowers. Pricing is defined in “pricing grids,” whereby the cost of funds borrowed under the Amended Credit Facilities is related to the credit ratings of the company borrowing the funds. Additionally, borrowings under each of the credit facilities are subject to the usual and customary provisions for acceleration upon the occurrence of events of default, including a cross-default for other indebtedness in excess of $100 million.

As of September 30, 2026, FE was in compliance with its applicable consolidated interest coverage ratio and the Electric Companies, the Transmission Companies, and FET were each in compliance with their debt-to-total-capitalization ratio covenants under each of their Amended Credit Facilities.

FirstEnergy Money Pools

FirstEnergy’s regulated operating subsidiary companies also have the ability to borrow from each other and FE to meet their short-term working capital requirements. Similar but separate arrangements exist among FirstEnergy’s unregulated companies with AE Supply, FE, FET, FEV and certain other unregulated subsidiaries. FESC administers these money pools and tracks

surplus funds of FE and the respective regulated and unregulated subsidiaries, as the case may be, as well as proceeds available from bank borrowings. Companies receiving a loan under the money pool agreements must repay the principal amount of the loan, together with accrued interest, within 364 days of borrowing the funds. The rate of interest is the same for each company receiving a loan from their respective pool and is based on the average cost of funds available through the pool.


Average Interest Rates	Regulated Companies’ Money Pool		Unregulated Companies’ Money Pool
	2026		2025		2026	2025
For the Three Months Ended September 30,	4.48	%		4.35	%	4.25	%	4.34	%
For the Nine Months Ended September 30,	4.35	%		4.67	%	4.10	%	5.16	%

Long-Term Debt Capacity

FE’s and its subsidiaries’ access to capital markets and costs of financing are influenced by the credit ratings of their securities. The following table displays FE’s and its subsidiaries’ credit ratings as of October 27, 2026:

Corporate Credit Rating

Senior Secured

Senior Unsecured

Outlook/Credit Watch(1)

Issuer

S&P

Moody’s

Fitch

S&P

Moody’s

Fitch

S&P

Moody’s

Fitch

S&P

Moody’s

Fitch

BBB+

Baa3

BBB

—

BBB

Baa3

BBB

Distribution:

CEI

BBB+

Baa3

BBB+

—

BBB+

Baa3

A-

BBB+

A-

BBB+

Baa2

BBB+

—

FE PA

A-

—

A-

Integrated:

JCP&L

BBB+

A-

—

BBB+

BBB

Baa2

A-

A+

—

Baa2

—

AGC

BBB-

Baa2

A-

—

BBB

Baa2

BBB+

A-

—

Stand-Alone Transmission:

FET

Baa2

BBB+

—

A-

Baa2

BBB+

ATSI

—

A+

MAIT

—

A+

TrAIL

—

A+

KATCo

—

A-

—

(1) S = Stable, P = Positive

On March 30, 2026, Moody’s revised FE’s outlook to positive from stable. Moody’s also affirmed FE’s ratings, including its Baa3 Issuer and senior unsecured ratings.

The applicable undrawn and drawn margin on the credit facilities are subject to ratings-based pricing grids. The applicable fee paid on the undrawn commitments and on actual borrowings under the credit facilities are based on FE’s senior unsecured non-credit enhanced debt ratings as determined by S&P and Moody’s.

The interest rates payable on approximately $2.1 billion in FE’s senior unsecured notes are subject to adjustments from time to time if the ratings on the notes from any one or more of S&P, Moody’s and Fitch decreases to a rating set forth in the applicable governing documents. Generally, a one-notch downgrade by the applicable rating agency may result in a 25 basis point coupon rate increase beginning at BB, Ba1, and BB+ for S&P, Moody’s and Fitch, respectively, to the extent such rating is applicable to the series of outstanding senior unsecured notes, during the next interest period, subject to an aggregate cap of 2% from issuance interest rate.

Debt capacity is subject to the consolidated interest coverage ratio in FE's credit facility. As of September 30, 2026, FirstEnergy could incur approximately $0.8 billion of incremental interest expense or incur a $2.0 billion reduction to the consolidated interest coverage earnings numerator, as defined under the covenant, and FE would remain within the limitations of the financial covenant requirements of FE's credit facility.

As of September 30, 2026, FE PA could incur approximately $4.4 billion of additional debt or incur an approximate $2.4 billion reduction to equity, as defined under the debt to capital covenant, and FE PA would remain within the limitations of the financial covenant requirements of FE PA's credit facility.

As of September 30, 2026, JCP&L could incur approximately $6.1 billion of additional debt or incur an approximate $3.3 billion reduction to equity, as defined under the debt to capital covenant, and JCP&L would remain within the limitations of the financial covenant requirements of JCP&L's credit facility.

Cash Requirements and Commitments

The Registrants have certain obligations and commitments to make future payments under contracts. For an in-depth discussion of the Registrants’ cash requirements and commitments, see “Capital Resources and Liquidity - Cash Requirements and Commitments\" in Item 7, \"Management's Discussion and Analysis of Financial Condition and Results of Operations\" within FirstEnergy and JCP&L’s Form 10-K for the year ended December 31, 2025 (filed with the SEC on February 18, 2026) and FE PA’s Registration Statement on Form S-4 (filed with the SEC on September 1, 2026).

Changes in Cash Position

As of September 30, 2026, FirstEnergy had $48 million of cash and cash equivalents and $84 million of restricted cash as compared to $57 million of cash and cash equivalents and $42 million of restricted cash as of December 31, 2025, on the Consolidated Balance Sheets.

The following table summarizes the major classes of cash flow items:


	For the Nine Months Ended September 30,
(In millions)	2026		2025		Change

Net cash provided from operating activities	$	2,058			$	2,564		$	(506)
Net cash used for investing activities	(4,579)			(3,805)			(774)
Net cash provided from financing activities	2,554			2,518			36
Net change in cash, cash equivalents, and restricted cash	33			1,277			(1,244)

Cash, cash equivalents, and restricted cash at beginning of period	99			154			(55)
Cash, cash equivalents, and restricted cash at end of period	$	132			$	1,431		$	(1,299)

Cash Flows From Operating Activities

FirstEnergy’s most significant sources of cash are derived from electric service provided by its operating subsidiaries. The most significant use of cash from operating activities is buying electricity to serve non-shopping customers, return of cash collateral associated with certain generation suppliers that serve shopping customers, and paying fuel suppliers, employees, tax authorities, lenders and others for a wide range of materials and services.

Net cash provided from operating activities was $2.1 billion in the first nine months of 2026, as compared to net cash provided from operating activities of $2.6 billion in the first nine months of 2025. The decrease in cash provided from operating activities in 2026, compared to the same period of 2025, is primarily due to:

•Restitution and refunds returned to Ohio customers resulting from the PUCO-approved settlement, which began to be provided to customers in February 2026;

•Higher storm restoration costs;

•Higher transmission and purchased power costs, primarily from the net impacts of the Winter Storm Fern weather event in the first quarter of 2026;

•Lower net transmission revenue collections based on the timing of formula rate collections; and

•Decreased working capital due to the timing of accounts payable and higher employee benefit payments in the first quarter of 2026, as compared to the same period in 2025.

The decrease in cash provided from operating activities was partially offset by:

•Receipt of New Jersey ZEC refunds, which are in the process of being returned to customers over the next approximately 8 months;

•Higher return on regulated capital investment programs; and

•Temporary rate credits that were provided to JCP&L residential customers during the third quarter of 2025 that were recovered in the first quarter of 2026.

Cash Flows From Investing Activities

Net cash used for investing activities in the first nine months of 2026 principally represented cash used for capital investments. The following table summarizes investing activities for the first nine months of 2026 and 2025:


	For the Nine Months Ended September 30,
Investing Activities	2026		2025		Change
	(In millions)
Capital investments:
Distribution Segment	$	1,335			$	976		$	359
Integrated Segment	1,587			1,336			251
Stand-Alone Transmission Segment	1,235			1,161			74
Corporate / Other	30			66			(36)

Asset removal costs	378			290			88
Other	14			(24)			38
	$	4,579			$	3,805		$	774

Net cash used for investing activities for the first nine months of 2026 increased $774 million, compared to the same period of 2025, primarily due to higher capital investments.

Cash Flows From Financing Activities

In the first nine months of 2026 and 2025, net cash provided from financing activities was $2,554 million and $2,518 million, respectively. The following table summarizes financing activities for the first nine months of 2026 and 2025:


	For the Nine Months Ended September 30,
Financing Activities	2026		2025		Change
	(In millions)

New Issues:
Unsecured convertible notes	$	—			$	2,500		$	(2,500)
Senior unsecured notes	2,125			3,125			(1,000)
Senior secured notes	—			100			(100)
FMBs	300			200			100
Term Loan	150			—			150
	$	2,575			$	5,925		$	(3,350)

Redemptions / Repayments:
Unsecured convertible notes	$	(294)			$	(1,206)		$	912
Senior unsecured notes	(375)			(925)			550


Senior secured notes	(51)			(48)			(3)
	$	(720)			$	(2,179)		$	1,459


Short-term borrowings, net	$	1,645			$	(259)		$	1,904

Noncontrolling interest cash distributions	(75)			(74)			(1)


Common stock dividend payments	(795)			(759)			(36)
Debt issuance and redemption costs, and other	(76)			(136)			60
	$	2,554			$	2,518		$	36

The following table summarizes the redemptions and issuances during the nine months ended September 30, 2026:

Company

Type

Redemption / Issuance Date

Interest Rate

Maturity

Amount

(In millions)

Description

Redemptions

FE PA

Senior Unsecured

March, 2026

5.15%

2026

$300

Redeemed senior unsecured notes that became due.

ATSI(1)

Senior Unsecured

April, 2026

4.00%

2026

$75

Redeemed senior unsecured notes that became due.

Senior Unsecured Convertible Notes

May, 2026

4.00%

2026

$294

Redeemed senior unsecured convertible notes that became due.

Issuances

FE PA

Senior Unsecured

March, 2026

4.15%

2028

$300

FE PA

Senior Unsecured

March, 2026

4.55%

2031

$550

MAIT(1)

Senior Unsecured

April, 2026

5.02%

2036

$250

Proceeds were used to: (i) repay short-term borrowings; (ii) to finance capital expenditures; (iii) to fund working capital; and (iv) to fund other general corporate purposes.

ATSI(1)

Senior Unsecured

April, 2026

5.19%

2033

$175

JCP&L

Senior Unsecured

May, 2026

4.60%

2030

$350

Proceeds were used to: (i) refinance existing indebtedness and short-term borrowings; (ii) to fund capital expenditures; (iii) to fund working capital; and (iv) to fund general corporate purposes.

FMB

May, 2026

4.45%

2029

$300

Proceeds were used to: (i) repay short-term borrowings; (ii) to finance capital expenditures; (iii) to fund working capital; and (iv) to fund general corporate purposes.

CEI

Senior Unsecured

August, 2026

5.00%

2030

$500

Proceeds were used to: (i) repay short-term borrowings; (ii) to fund capital expenditures; (iii) to fund working capital; and (iv) to fund general corporate purposes.

(1) A wholly owned subsidiary of FET

PE Term Loan Facility

Borrowings under the PE Term Loan Facility that are Alternate Base Rate Loans (as defined in the PE Term Loan Facility) bear interest at a fluctuating interest rate per annum equal to the highest of: (i) the “prime rate” published by the Wall Street Journal from time to time, (ii) the sum of 1/2 of 1% per annum plus the federal funds rate in effect from time to time and (iii) the Term SOFR Rate for a one-month interest period plus 1%. Borrowings under the PE Term Loan Facility that are Term Benchmark Loans (as defined in the PE Term Loan Facility) bear interest at a fluctuating interest rate per annum equal to the sum of 0.70% per annum plus the Term SOFR Rate for such interest period. Borrowings under the PE Term Loan Facility that are RFR Loans (as defined in the PE Term Loan Facility) bear interest at a fluctuating interest rate per annum equal to the sum of 0.70% per annum plus Daily Simple SOFR.

FE or its significant subsidiaries.

FE maintains an ordinary banking and investment banking relationship with the lender under the PE Term Loan Facility.

2026 Convertible Notes Issuance and Conversion:

2029 Convertible Notes and 2031 Convertible Notes Issuance

JCP&L Senior Notes and Registration Rights

FE PA Senior Notes and Registration Rights

Shelf Registration Statement

On May 29, 2026, FE filed a shelf registration statement on Form S-3 registering up to $3 billion in aggregate amount of securities, which was declared effective by the SEC on June 15, 2026.

GUARANTEES AND OTHER ASSURANCES

The Registrants have various financial and performance guarantees and indemnifications, which are issued in the normal course of business. These contracts include performance guarantees, stand-by LOCs, debt guarantees, surety bonds and indemnifications. The Registrants enter into these arrangements to facilitate commercial transactions with third parties by enhancing the value of the transaction to the third party. As of September 30, 2026, FirstEnergy’s outstanding guarantees and other assurances aggregated approximately $1 billion, consisting of parental guarantees on behalf of its consolidated subsidiaries ($585 million) and other assurances of ($436 million). The maximum potential amounts of future payments FE PA and JCP&L could be required to make under these guarantees as of September 30, 2026, were $46 million and $28 million, respectively.

Collateral and Contingent-Related Features

These credit-risk-related contingent features stipulate that if any such subsidiary were downgraded or lost its investment grade credit rating (based on its senior unsecured debt rating), it would be required to provide additional collateral. See Note 10., “Commitments, Guarantees and Contingencies,” of the Combined Notes to Financial Statements of the Registrants for more information.

MARKET RISK INFORMATION

FirstEnergy uses various market risk sensitive instruments, including derivative contracts, primarily to manage the risk of price and interest rate fluctuations. FirstEnergy’s Enterprise Risk Management Committee, comprised of members of senior management, provides general oversight for risk management activities throughout FirstEnergy, including market risk.

Commodity Price Risk

FirstEnergy has limited exposure to financial risks resulting from fluctuating commodity prices, including prices for electricity, coal and energy transmission.

The valuation of derivative contracts is based on observable market information. As of September 30, 2026, FirstEnergy has a net asset of $30 million in non-hedge derivative contracts that are related to FTRs at certain of the Electric Companies. FTRs are subject to regulatory accounting and do not impact earnings.

Equity Price Risk

As of September 30, 2026, the FirstEnergy pension plan assets were allocated approximately as follows: 32% in equity securities, 20% in fixed income securities, 6% in alternatives, 9% in real estate, 22% in private debt/equity, 8% in derivatives and 3% in cash and short-term securities. FirstEnergy does not currently expect to have a required contribution to the pension plan until 2027, which, based on various assumptions, is currently expected to be less than $300 million. However, FirstEnergy may elect to contribute to the pension plan voluntarily. FE PA and JCP&L are not expected to make a contribution to the pension plan.

As of September 30, 2026, FirstEnergy’s OPEB plan assets were allocated approximately as follows: 62% in equity securities, 34% in fixed income securities and 4% in cash and short-term securities.

In the nine months ended September 30, 2026, FirstEnergy’s pension plan assets have lost approximately 2.7% as compared to an annual expected return on plan assets of 8%. In the nine months ended September 30, 2026, FirstEnergy’s qualified OPEB plan assets have gained approximately 9.7% as compared to an annual expected return on plan assets of 7%. FirstEnergy determines the annual expected return on plan asset assumption based on historical asset performance, target asset allocations and other economic indicators, including current market conditions and forward-looking capital market expectations, among other factors. FirstEnergy periodically evaluates target asset allocations to support long-term funding and volatility mitigation objectives, which could impact future expected return on plan asset assumptions.

See Note 4., “Pension and Other Post-Employment Benefits,” of the Combined Notes to Financial Statements of the Registrants for additional details on FirstEnergy’s pension and OPEB plans.

Interest Rate Risk

FirstEnergy recognizes net actuarial gains or losses for its pension and OPEB plans in the fourth quarter of each fiscal year and whenever a plan is determined to qualify for a remeasurement. A primary factor contributing to these actuarial gains and losses are changes in the discount rates used to value pension and OPEB obligations as of the measurement date and the difference between expected and actual returns on the plans’ assets.

The remaining components of pension and OPEB expense, primarily service costs, interest cost on obligations, expected return on plan assets and amortization of prior service costs, are set at the beginning of the calendar year (unless a remeasurement is triggered) and are recorded on a monthly basis. Changes in asset performance and discount rates will not impact these pension and OPEB costs for 2026, unless an additional remeasurement were to be triggered during the year, however, future years could be impacted by changes in the market.

FirstEnergy utilizes a spot rate approach in the estimation of the components of benefit cost by applying specific spot rates along the full yield curve to the relevant projected cash flows. As of September 30, 2026, the spot rate was 6.62% and 6.46% for pension and OPEB obligations, respectively, as compared to 5.59% and 5.37% as of December 31, 2025, respectively.

The final discount rate and return or loss on plan assets as of the year-end remeasurement date is difficult to predict based on the currently volatile equity markets and interest rate environment. As a result, FirstEnergy is unable to determine or meaningfully project the mark-to-market adjustment, or estimate a reasonable range of adjustment, that will be recorded as of December 31, 2026.

Economic Conditions

CREDIT RISK

Credit risk is the risk that the Registrants would incur a loss as a result of nonperformance by counterparties of their contractual obligations. The Registrants maintain credit policies and procedures with respect to counterparty credit (including requirements that counterparties maintain specified credit ratings) and require other assurances in the form of credit support or collateral in certain circumstances in order to limit counterparty credit risk. The Registrants have concentrations of suppliers and customers among electric utilities, financial institutions and energy marketing and trading companies. These concentrations may impact the Registrants’ overall exposure to credit risk, positively or negatively, as counterparties may be similarly affected by changes in economic, regulatory or other conditions. In the event an energy supplier of the Ohio Companies, FE PA, JCP&L or PE defaults on its obligation, the affected company would be required to seek replacement power in the market. In general, subject to regulatory review or other processes, it is expected that appropriate incremental costs incurred by these entities would be recoverable from customers through applicable rate mechanisms, thereby mitigating the financial risk for these entities. The Registrants' credit policies to manage credit risk include the use of an established credit approval process and daily credit mitigation provisions, such as margin, prepayment or collateral requirements. FirstEnergy and its subsidiaries, including FE PA and JCP&L, may request additional credit assurance, in certain circumstances, in the event that the counterparties' credit ratings fall below investment grade, their tangible net worth falls below specified percentages or their exposures exceed an established credit limit.

OUTLOOK

INCOME TAXES

STATE REGULATION

MARYLAND

NEW JERSEY

In 2021, JCP&L, in connection with Mid-Atlantic Offshore Development, LLC, a transmission company jointly owned by Shell New Energies US LLC and EDF Renewables North America, proposed transmission upgrades to connect offshore wind-generated electricity to the New Jersey power grid. The NJBPU approved portions of the proposal on October 26, 2022, authorizing approximately $723 million of transmission investments and providing JCP&L the option to acquire up to a 20% equity interest in Mid-Atlantic Offshore Development, LLC. On August 22, 2023, FERC approved an abandonment incentive that allowed recovery of certain prudently incurred project costs if the project were cancelled for reasons beyond JCP&L’s control.

OHIO

the quadrennial review, effective August 14, 2025. The OCC filed its response to the Ohio Companies’ notice of withdrawal on July 25, 2025, to which the Ohio Companies replied on August 1, 2025. The matter remains pending before the PUCO.

On May 31, 2024, the Ohio Companies filed their application for an increase in base distribution rates based on a 2024 calendar year test period. On November 19, 2025, the PUCO issued an order in the rate case lifting the rate freeze and approving a net increase in base distribution revenues of the Ohio Companies of approximately $34 million, with an ROE of 9.63% and a hypothetical capital structure of 48.8% debt and 51.2% equity for all three Ohio Companies, which reflects a roll-in of current riders such as DCR and AMI. The PUCO authorized continuance of Rider DCR with a cap increase commensurate with capital investments through January 31, 2025, and approved the Ohio Companies’ proposal to change pension and OPEB recovery to the delayed recognition method. Additionally, the order authorizes recovery of certain deferred costs for storm restoration, operations and maintenance, and energy efficiency programs. As a result of the order, the Ohio Companies recognized a $352 million pre-tax impairment charge related to future recovery disallowances of certain previously capitalized amounts. On November 26, 2025, the Ohio Companies filed proposed compliance tariffs. On December 19, 2025, the Ohio Companies and other parties filed applications for rehearing and on December 29, 2025, the Ohio Companies filed a memorandum against intervenors’ applications for rehearing. On January 7, 2026, the PUCO issued an entry granting rehearing in order to determine whether its November 19, 2025, base rate case opinion and order should be affirmed, abrogated, or modified on rehearing. On February 18, 2026, the PUCO issued an entry on rehearing, which extended the amortization period for recovery of deferred storm restoration costs from five years to twenty-five years, subject to prudency review, and clarified the amount of the authorized increase in Rider DCR revenue caps is $14 million, subject to the Ohio Companies meeting reliability standards. With these adjustments, the rate case’s outcome is a net decrease in base distribution revenues of the Ohio Companies of approximately $5 million. The entry further ordered the Ohio Companies to file revised final tariffs and approved the Ohio Companies’ compliance tariffs, effective March 1, 2026. On March 20, 2026, the Ohio Companies and certain other parties filed with the PUCO second applications for rehearing of the February 18, 2026, entry on rehearing. On April 14, 2026, the PUCO issued an entry on rehearing denying all applications for rehearing. On May 14, 2026, Retail Energy Supply Association and IGS Energy Supply, LLC jointly filed with the PUCO a request for clarification and application for rehearing, to which the OCC and the Ohio Companies responded on May 26, 2026. On June 10, 2026, the PUCO issued its Fourth Entry on Rehearing, denying the application for rehearing. On August 10, 2026, the Ohio Companies filed a notice of appeal with the Supreme Court of Ohio, appealing the PUCO’s actions on rehearing, including the extension of the Ohio Companies’ deferred storm cost amortization period, and the issuance of additional directives on rehearing without following procedural rules. On October 19, 2026, the Ohio Companies filed their initial brief.

See below for additional details on the ongoing government investigations and ongoing litigation surrounding HB 6.

PENNSYLVANIA

created by the PA Consolidation will not reach full rate unity until the earlier of 2033 or the conclusion of three base rate cases filed after January 1, 2025. FE PA operates under rates approved by the PPUC, effective as of January 1, 2025. FE PA operates under a DSP through the May 31, 2027 delivery period, which provides for the competitive procurement of generation supply for customers who do not choose an alternative EGS or for customers of alternative EGSs that fail to provide the contracted service. In December 2024, the PPUC approved FE PA’s LTIIP III program, which contemplates an approximately $1.4 billion investment plan from 2025 through 2029 and the eligible costs of which are recoverable through FE PA’s distribution system improvement charge. FE PA may increase its LTIIP investment plan up to 20% without seeking additional PPUC approval.

On November 26, 2025, FE PA submitted a petition for approval of its Phase V EE&C Plan, which includes energy efficiency and peak demand reduction programs with demand reduction targets, relative to 2007-2008 peak demands, at 2.01% MW, and energy consumption reduction targets, as a percentage of FE PA’s historic 2009 to 2010 reference load, at 2.00% MWh. The proposed plan includes cost recovery of approximately $390 million to be recovered through its Phase V Energy Efficiency and Conservation Charge Rider and runs for a five-year period beginning June 1, 2026, through May 31, 2031. Hearings were held on January 29, 2026. The parties reached a full settlement in principle and filed with the PPUC a Joint Petition for Complete Settlement on February 19, 2026. On March 12, 2026, the PPUC issued an order approving the settlement with limited modifications requiring FE PA to file revisions to the plan, which were filed on April 15, 2026.

WEST VIRGINIA

FERC REGULATORY MATTERS

Transmission ROE Incentive

the complaint as to ATSI and Duke Energy Ohio, Inc., but granted it as to AEP’s Ohio affiliate. AEP’s Ohio affiliate and OCC appealed FERC’s orders to the Sixth Circuit. On January 17, 2025, the Sixth Circuit ruled that the 50 basis point adder is available only where RTO membership is voluntary, that Ohio law requires Ohio’s transmission utilities to be members of an RTO, and that it was unlawful for FERC to excise the adder from AEP’s Ohio affiliate rates, but not from the Duke Energy Ohio, Inc. and ATSI rates. During 2024, as a result of the ruling, ATSI recognized a $46 million pre-tax charge, with interest, of which $42 million is reported in “Transmission Revenues” and $4 million is reported in “Miscellaneous income, net” on the FirstEnergy Consolidated Statements of Income and Comprehensive Income at the Stand-Alone Transmission segment, to reflect the expected refund owed to transmission customers back to February 24, 2022. On June 20, 2025, and June 24, 2025, ATSI and AEP’s Ohio affiliate, respectively, applied for the Supreme Court of the U.S. to review the Sixth Circuit’s decision. On November 10, 2025, the Supreme Court of the U.S. denied ATSI’s petition for the court to review the case. On November 13, 2025, the Sixth Circuit issued a mandate sending the case back to FERC for further proceedings. On June 25, 2026, FERC issued an order on remand directing ATSI to submit a compliance filing within 30 days to remove the RTO incentive and make refunds with interest within 30 days for the period beginning February 24, 2022, through the date of the refund. On July 22, 2026, FERC approved ATSI’s subsequent request to defer the deadline to issue refunds until February 28, 2027, in order to accommodate the PJM and MISO processes for processing refunds as directed by FERC’s order. On July 27, 2026, ATSI submitted to FERC a filing to amend its formula rate to remove on a going-forward basis 50 basis points of authorized earnings in compliance with FERC’s orders. FirstEnergy also filed a request for rehearing on July 27, 2026, arguing that the Federal Power Act limited the refund period to 15 months. On August 27, 2026, FERC denied the request for rehearing by operation of law. On October 21, 2026, ATSI appealed FERC’s June 25, 2026, order to the Sixth Circuit. As of September 30, 2026, ATSI’s estimated refund obligation, including interest, totaled approximately $51 million, which is recorded in “Regulatory liabilities” on FirstEnergy’s Consolidated Balance Sheets.

Transmission ROE Methodology

Transmission Planning Supplemental Projects

Local Transmission Planning Complaint

Ghiorzi v. PJM

reassignment projects: (i) did not reflect the cost estimates or cost caps included in NextEra Energy Transmission’s bid; and (ii) would be constructed with different routing than originally proposed. On February 2, 2026, FERC denied the complaint and on April 3, 2026, FERC denied the rehearing request filed by the complainants on March 4, 2026. On June 22, 2026, FERC affirmed its February 2, 2026, order denying the complaint. The deadline to appeal has passed and FERC’s order is final.

Abandonment Transmission Rate Incentive

PJM Capacity Market Reforms

On January 16, 2026, the Trump administration and the governors of all thirteen PJM states released a Statement of Principles Regarding PJM. This Statement of Principles is designed to, among other things, increase capacity available in the PJM market. On July 27, 2026, the PJM Board of Managers announced its plans to procure up to 6,800 MWs of capacity resources, the costs of which would be allocated to load-serving entities. On July 31, 2026, PJM filed its proposed reliability backstop procurement set of tariff amendments at FERC, which proposal called for PJM to procure 6,800 MWs of new capacity resources in the fourth quarter of 2026 and calls for the costs of the procurement to be charged to load-serving entities. PJM’s proposal also provides that, if a transmission owner exits PJM, at and after such exit, the costs are to be charged to the transmission owner. On August 21, 2026, FirstEnergy filed protests at FERC arguing, among other things, that PJM had failed to demonstrate that the proposal to charge the costs to exiting transmission owners is “just and reasonable” as required by the Federal Power Act. On September 29, 2026, FERC issued an order suspending PJM’s proposed reliability backstop procurement tariff amendments until February 28, 2027, and instituting further proceedings. FERC further invited PJM to submit a second set of tariff amendments to address the issues that were identified in the September 29, 2026, order. On September 30, 2026, PJM announced the procurement would not begin as previously scheduled. FirstEnergy expects it will continue to participate in the PJM stakeholder processes and FERC proceedings.

Large Load Interconnection Rulemaking

Utility RELIEF Act and Related FERC Complaint

PJM Interim Resource Adequacy Service

Winter Storm Fern

ENVIRONMENTAL MATTERS

The disclosures below apply to FirstEnergy and the disclosures under “Regulation of Waste Disposal,” are also applicable to FE PA and JCP&L.

Clean Air Act

FirstEnergy complies with SO2 and NOx emission reduction requirements under the CAA and SIP by burning lower-sulfur fuel, utilizing combustion controls and post-combustion controls and/or using emission allowances.

addition to West Virginia, certain other states, and certain trade organizations, including the Midwest Ozone Group of which FE is a member, separately filed petitions for review and motions to stay the Good Neighbor Plan itself at the D.C. Circuit. On September 25, 2023, the D.C. Circuit denied the motions to stay the Good Neighbor Plan. On October 13, 2023, the aggrieved parties filed an Emergency Application for an Immediate Stay of the Good Neighbor Plan with the Supreme Court of the U.S. Oral argument was heard on February 21, 2024. On June 27, 2024, the Supreme Court of the U.S. granted a stay of the Good Neighbor Plan pending disposition of the petition for review in the D.C. Circuit. On February 6, 2025, the EPA filed a motion at the D.C. Circuit to hold the proceedings in abeyance for 60 days to allow the EPA time to familiarize itself with the Good Neighbor Plan and in particular, time to brief the new administration about these consolidated petitions and the underlying Rule to allow the EPA to decide what action, if any, is necessary. On March 10, 2025, the EPA filed a motion for remand with the D.C. Circuit identifying issues with the Good Neighbor Plan that make reconsideration appropriate. The D.C. Circuit granted the motion for remand and cancelled oral argument. Consistent with its March 12, 2025, announcement, the EPA intends to undertake reconsideration of the rule and complete any new rulemaking by the fourth quarter of 2026. On January 27, 2026, the EPA proposed phase 1 of its reconsideration of the rule applicable to eight states outside of FirstEnergy’s service area. FirstEnergy will continue to monitor any further actions by the EPA for any potential impact to its business and results of operations.

Climate Change

In January 2025, Executive Order 14154 was issued and, among other deregulatory actions, directed the EPA Administrator to make recommendations on the “legality and continuing applicability” of the EPA’s 2009 Endangerment Finding, which forms the basis for the EPA's GHG regulations. On March 12, 2025, the EPA announced a series of planned deregulatory actions that it would be taking related to such executive order, including reconsideration of the regulations to limit power plant GHG emissions. On July 29, 2025, the EPA announced a proposal to rescind its 2009 Endangerment Finding. On February 12, 2026, the EPA issued a final rule rescinding its 2009 Endangerment Finding, thereby eliminating the basis for much of the EPA’s regulation of GHG emissions. On February 18, 2026, the first of several petitions for review were filed at the D.C. Circuit challenging the rescission by the EPA and multiple lawsuits opposing the EPA’s rescission were filed thereafter. Depending on the outcome of this litigation, which is expected to be extensive, and any future EPA actions, compliance with the GHG emissions limits could require additional capital expenditures or changes in operation at the Fort Martin and Harrison power stations.

FirstEnergy’s coal-fired facilities in West Virginia, which serve as the primary source of its Scope 1 emissions, it has identified that the end of the useful life date is 2035 for Fort Martin and 2040 for Harrison. MP filed its 10-year integrated resource plan with the WVPSC on October 1, 2025, which highlighted, among other things, the need for new dispatchable generation in West Virginia. Determination of the useful life of the regulated coal-fired generation could result in changes in depreciation, and/or continued collection of net plant in rates after retirement, securitization, sale, impairment, or regulatory disallowances. If FirstEnergy is unable to recover these costs, it could have a material adverse effect on FirstEnergy’s financial condition, results of operations, and cash flow.

Clean Water Act

Regulation of Waste Disposal

Circuit, seeking to hold the litigation, which was filed on August 8, 2024, by the Utility Solid Waste Act Group with FE as a member, in abeyance for a period of 120 days while the new leadership at the EPA evaluates the rule and determines how it wishes to proceed, which the D.C. Circuit granted. On March 12, 2025, the EPA announced a series of planned deregulatory actions, including reconsideration of the final legacy CCR rule. FirstEnergy continues to monitor the EPA’s actions related to CCR regulations; however, the ultimate impact is unknown at this time and is subject to the outcome of the litigation and any future state regulatory actions. Depending on the outcome of appeals and the EPA’s rule, compliance with the final legacy CCR rule could require remedial actions, including removal of coal ash.

OTHER LEGAL PROCEEDINGS

U.S. v. Larry Householder, et al.

Legal Proceedings Relating to U.S. v. Larry Householder, et al.

NEW ACCOUNTING PRONOUNCEMENTS

See Note 1., \"Organization and Basis of Presentation,\" of the Combined Notes to Financial Statements of the Registrants for a discussion of new accounting pronouncements.

FIRSTENERGY PENNSYLVANIA ELECTRIC COMPANY AND SUBSIDIARIES

MANAGEMENT’S NARRATIVE DISCUSSION AND
ANALYSIS OF RESULTS OF OPERATIONS

FE PA is incorporated in Pennsylvania and is a wholly owned subsidiary of FirstEnergy Pennsylvania Holding Company LLC, which is a wholly owned subsidiary of FE. FE PA owns property and does business as an electric public utility in Pennsylvania and New York, providing distribution services to approximately 2.1 million customers in Pennsylvania and approximately 4,000 customers in Waverly, New York, with a rate base of $6.9 billion as of December 31, 2025. FE PA had 1,916 employees as of December 31, 2025, and serves an area that has a population of approximately 4.5 million. FE PA complied with the regulations, orders, policies and practices prescribed by FERC, PPUC and the NYPSC.

On January 1, 2024, FirstEnergy consolidated the Pennsylvania Companies into FE PA, including then-OE subsidiary, Penn, making FE PA a new, single operating entity. In addition to merging each of the Pennsylvania Companies with and into FE PA, with FE PA surviving such mergers as the successor-in-interest to all assets and liabilities of the Pennsylvania Companies, (i) WP transferred certain of its Pennsylvania-based transmission assets to KATCo, and (ii) PN and ME contributed their respective Class B equity interests of MAIT to FE. FE PA operates under the rate districts of the former Pennsylvania Companies.

For additional information with respect to FE PA, please see the information contained in FirstEnergy’s Management’s Discussion and Analysis of Financial Condition and Results of Operations under the following subheadings, which information is incorporated by reference herein: Executive Summary and Recent Developments, Regulatory Assets and Liabilities, Capital Resources and Liquidity, Guarantees and Other Assurances, Market Risk Information, Credit Risk, Outlook and New Accounting Pronouncements.

FE PA Summary of Results of Operations—First Nine Months of 2026 Compared with First Nine Months of 2025

FE PA’s financial results for the nine months ended September 30, 2026, and 2025, were as follows:


	For the Nine Months Ended September 30,
(In millions)	2026		2025		Change

Revenues:
Revenues - non-affiliates	$	3,359			$	3,007		$	352
Revenues - affiliates	13			16			(3)
Gross receipts tax collections	207			186			21
Total revenues	3,579			3,209			370

Operating Expenses:
Purchased power	1,698			1,436			262
Other operating expenses	910			770			140
Provision for depreciation	255			238			17
Deferral of regulatory assets, net	(139)			(50)			(89)
General taxes	228			208			20
Total operating expenses	2,952			2,602			350

Other Income (Expense):
Interest income - affiliates	15			13			2
Miscellaneous income, net	47			39			8

Interest expense - other	(156)			(142)			(14)
Interest expense - affiliates	(18)			(18)			—
Capitalized financing costs	14			10			4
Total other expense	(98)			(98)			—

Income taxes	101			114			(13)

Net Income	$	428			$	395		$	33

Distribution services by customer class are summarized in the following table:


	For the Nine Months Ended September 30,
(In thousands)	Actual	Weather-Adjusted
Electric Distribution MWh Deliveries	2026	2025		Increase (Decrease)	2026		2025		Increase (Decrease)

Residential	14,302		14,429		(0.9)	%		14,161		14,325	(1.1)	%
Commercial(1)	8,258		8,257		—	%		8,205		8,279	(0.9)	%
Industrial	16,400		15,902		3.1	%		16,400		15,902	3.1	%

Total Electric Distribution MWh Deliveries	38,960		38,588		1.0	%		38,766		38,506	0.7	%

(1) Includes street lighting.

Distribution deliveries for the residential and commercial customer classes were impacted by the weather temperatures. Heating degree days in the first nine months of 2026 were 2% above the same period of 2025 and near normal. Cooling degree days in the first nine months of 2026 were 5% above the same period of 2025 and 9% above normal.

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FE PA Results of Operations — First Nine Months of 2026 Compared with First Nine Months of 2025

Net income increased $33 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to the absence in 2026 of severance and related costs that were recognized in the first quarter of 2025, higher rider revenues and customer demand, higher pension and OPEB non-service credits and a lower effective tax rate, partially offset by higher financing costs.

Revenues

The $370 million increase in total revenues resulted from the following sources:


	For the Nine Months Ended September 30,
Revenues by Type of Service	2026		2025		Increase / (Decrease)
	(In millions)
Distribution services	$	1,588			$	1,491		$	97

Generation sales:
Retail	1,932			1,660			272
Wholesale	11			7			4
Total generation sales	1,943			1,667			276



Other	48			51			(3)
Total Revenues	$	3,579			$	3,209		$	370

Distribution services revenue increased $97 million during the first nine months of 2026, as compared to the same period of 2025, primarily resulting from higher rider revenues and customer usage.

Generation sales revenues increased $276 million during the first nine months of 2026, as compared to the same period of 2025, primarily due to higher non-shopping generation auction rates. Retail and wholesale generation sales revenue have no material impact to earnings.

Operating Expenses

Total operating expenses increased $350 million primarily due to:

•Purchased power costs, which have no material impact to earnings, increased $262 million during the first nine months of 2026, as compared to the same period of 2025, primarily due to higher unit costs.

•Other operating expenses increased $140 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to:

•Higher network transmission expenses of $10 million, which were deferred for future recovery, resulting in no material impact to earnings;

•Higher energy efficiency and other state mandated program costs of $13 million, which were deferred for future recovery, resulting in no material impact to earnings; and

•Higher storm restoration expenses of $142 million, which were deferred for future recovery resulting in no material impact to earnings.

The increase was partially offset by:

▪Lower uncollectible expenses of $9 million;

▪Lower other operating expenses of $11 million, primarily due to accelerated vegetation work in 2025, partially offset by planned maintenance activities; and

▪The absence in 2026 of $5 million of severance and related costs associated with FirstEnergy’s organizational changes announced and recognized in the first quarter of 2025.

•Depreciation expense increased $17 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to a higher asset base.

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•Deferral of regulatory assets, net increased $89 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to a $142 million increase from higher deferred storm restoration expenses and a $15 million net increase in generation and transmission related deferrals, partially offset by $30 million of higher net amortization expenses resulting from recovery of customer assistance programs from the implementation of the base rate case in 2025, and $38 million net decrease in other deferrals.

•General taxes increased $20 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to higher gross receipts taxes.

Other Expenses

Total other expenses were flat in the first nine months of 2026, as compared to the same period of 2025, primarily due to higher interest expense as a result of new debt issued since the third quarter of 2025, offset by higher capitalized interest and higher pension and OPEB non-service credits.

Income Taxes

The effective tax rate for the nine months ended September 30, 2026, and 2025, was 19.1% and 22.4%, respectively. The decrease in the effective tax rate was primarily due to increases in state flow-through tax benefits and higher amortization of excess deferred income taxes.

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JERSEY CENTRAL POWER & LIGHT COMPANY

MANAGEMENT’S NARRATIVE DISCUSSION AND
ANALYSIS OF RESULTS OF OPERATIONS

JCP&L is a wholly owned subsidiary of FE. JCP&L conducts business in New Jersey by providing regulated electric transmission and distribution services in northern, western and east central New Jersey, representing $5.1 billion in rate base as of December 31, 2025. JCP&L is subject to regulation by the NJBPU and FERC.

JCP&L distributes electricity to approximately 1.2 million customers in New Jersey across its distribution footprint. JCP&L owns and operates transmission infrastructure that is used to transmit electricity, with revenues derived from forward-looking formula rates, pursuant to which the revenue requirement is updated annually based on a projected rate base and projected costs, which are subject to an annual true-up based on actual rate base and costs. JCP&L procures electric supply to serve its BGS customers through a statewide auction process approved by the NJBPU. JCP&L’s results reflect the costs of securing and delivering electric generation to customers and net transmission expenses related to the delivery of electricity on JCP&L’s transmission facilities, including the deferral and amortization of certain costs.

As discussed in Note 1., \"Organization and Basis of Presentation,\" of the Combined Notes to Financial Statements of the Registrants, during the fourth quarter of 2025, JCP&L identified an error in the recording of certain expenses for smart meter cost of removal associated with the deployment of its AMI program, resulting in an understatement of expense on the Statements of Income and Comprehensive Income and Regulatory assets/liabilities on the Balance Sheets since 2023. JCP&L evaluated the error, and the specific impact on each affected prior period was not material, however, as a result of the cumulative impact, JCP&L determined it should revise previously issued financial statements to correct the error and, in doing so, also corrected other immaterial errors. As such, JCP&L has revised the previously issued interim Results of Operations for the three and nine months ended September 30, 2025.

For additional information with respect to JCP&L, please see the information contained in FirstEnergy’s Management’s Discussion and Analysis of Financial Condition and Results of Operations under the following subheadings, which information is incorporated by reference herein: Executive Summary and Recent Developments, Regulatory Assets and Liabilities, Capital Resources and Liquidity, Guarantees and Other Assurances, Market Risk Information, Credit Risk, Outlook and New Accounting Pronouncements.

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JCP&L Summary of Results of Operations — First Nine Months of 2026 Compared with First Nine Months of 2025

JCP&L’s financial results for the nine months ended September 30, 2026, and 2025, were as follows:


	For the Nine Months Ended September 30,
(In millions)	2026		2025 (1)		Change

Revenues	$	2,211			$	2,022		$	189

Operating Expenses:
Purchased power	1,173			1,052			121
Other operating expenses	763			440			323
Provision for depreciation	187			196			(9)
Deferral of regulatory assets, net	(338)			(19)			(319)
General taxes	19			18			1
Total operating expenses	1,804			1,687			117

Other Income (Expense):
Miscellaneous income, net	41			36			5

Interest expense - other	(123)			(93)			(30)
Interest expense - affiliates	(9)			(6)			(3)
Capitalized financing costs	35			31			4
Total other expense	(56)			(32)			(24)

Income taxes	84			76			8

Net Income	$	267			$	227		$	40

(1) Previously issued 2025 JCP&L amounts have been revised due to the correction of immaterial errors as discussed in Note 1., \"Organization and Basis of Presentation,\" of the Combined Notes to Financial Statements of the Registrants.

Distribution services by customer class are summarized in the following table:


	For the Nine Months Ended September 30,
(In thousands)	Actual	Weather-Adjusted
Electric Distribution MWh Deliveries	2026	2025		Increase	2026		2025		Increase (Decrease)

Residential	7,904		7,812		1.2	%		7,587		7,657	(0.9)	%
Commercial(1)	6,425		6,309		1.8	%		6,352		6,309	0.7	%
Industrial	1,301		1,301		—	%		1,301		1,301	—	%

Total Electric Distribution MWh Deliveries	15,630		15,422		1.3	%		15,240		15,267	(0.2)	%

(1) Includes street lighting.

Distribution deliveries for the residential and commercial classes were impacted by higher customer usage and demand as a result of the weather temperatures. Cooling degree days in the first nine months of 2026 were 6% above the same period of 2025 and 8% above normal. Heating degree days in the first nine months of 2026 were 10% above the same period of 2025 and 5% above normal.

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JCP&L Results of Operations — First Nine Months of 2026 Compared with First Nine Months of 2025

Net income increased $40 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to the absence in 2026 of severance and related costs that were recognized in the first quarter of 2025, true-up adjustments from the annual forward-looking transmission rate filing, lower other operating expenses, higher transmission revenues from regulated capital investments that increased rate base and increased customer usage, partially offset by financing costs.

Revenues

The $189 million increase in total revenues resulted from the following sources:


	For the Nine Months Ended September 30,
Revenues by Type of Service	2026		2025		Increase / (Decrease)
	(In millions)
Distribution services	$	758			$	769		$	(11)

Generation sales:
Retail	1,198			1,046			152
Wholesale	3			3			—
Total generation sales	1,201			1,049			152

Transmission	240			191			49

Other	12			13			(1)
Total Revenues	$	2,211			$	2,022		$	189

Distribution services revenue decreased $11 million during the first nine months of 2026, as compared to the same period of 2025, primarily due to the conclusion of the New Jersey ZEC program effective June 1, 2025 and the return of certain ZEC refunds as further described above. These refunds were offset by the amortization of a regulatory liability resulting in no impact to earnings. The revenue decrease was partially offset by higher rider revenues associated with certain regulated investment programs and higher customer usage.

Generation sales revenues increased $152 million during the first nine months of 2026, as compared to the same period of 2025, primarily due to higher non-shopping generation auction rates.

Transmission revenues increased $49 million during the first nine months of 2026, as compared to the same period of 2025, primarily due to higher recovery of transmission operating expenses, true-up adjustments from the annual forward-looking transmission rate filing, and higher rate base from regulated investment programs.

Operating Expenses

Total operating expenses increased $117 million primarily due to:

•Purchased power costs, which have no material impact to earnings, increased $121 million during the first nine months of 2026, as compared to the same period of 2025, primarily due to higher unit costs.

•Other operating expenses increased $323 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to:

•Higher storm restoration expenses of $300 million, which were mostly deferred for future recovery;

•Higher energy efficiency and other state mandated program costs of $34 million, which were deferred for future recovery, resulting in no material impact to earnings;

•$5 million pre-tax impairment charge related to JCP&L’s Morristown, New Jersey general office; and

•Higher formula rate transmission operating and maintenance expenses of $13 million, which have no material impact to earnings.

The increase was partially offset by:

•The absence in 2026 of $6 million of severance and related costs associated with FirstEnergy’s organizational changes announced and recognized in the first quarter of 2025; and

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•Lower other operating expenses of $23 million, primarily due to planned maintenance expenses and the absence in 2026 of a legal reserve recognized in the second quarter of 2025.

•Depreciation expense decreased $9 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to the accelerated amortization of legacy smart meters in New Jersey, which concluded in December 2025, partially offset by a higher asset base.

•Deferral of regulatory assets, net increased $319 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to a $290 million increase from higher deferral of storm restoration costs, a $22 million increase from higher general and transmission deferrals, a $5 million increase related to the amortization of a regulatory liability associated with ZEC refunds, as further described above, and $2 million related to net increases in other deferrals.

Other Expenses

Total other expenses increased $24 million in the first nine months of 2026, as compared to the same period of 2025, primarily due to higher interest expense as a result of new debt issued since the third quarter of 2025, partially offset by higher capitalized interest and higher pension and OPEB non-service credits.

Income Taxes

The effective tax rate for the nine months ended September 30, 2026, and 2025, was 23.9% and 25.1%, respectively. The decrease in the effective tax rate was primarily due to an increase in the amortization of excess deferred income taxes.

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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

See “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Market Risk Information” in Item 2 above.

ITEM 4. CONTROLS AND PROCEDURES

(a) Evaluation of Disclosure Controls and Procedures

The management of the Registrants, with the participation of their respective principal executive officer and principal financial officer, has established and evaluated the effectiveness of their disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of the end of the period covered by this report. Based on that evaluation, the principal executive officers and principal financial officers of the Registrants have concluded that the disclosure controls and procedures in place were effective as of the end of the period covered by this report.

(b) Changes in Internal Control over Financial Reporting

During the quarter ended September 30, 2026, there were no changes in internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) that have materially affected, or are reasonably likely to materially affect, the Registrants’ internal control over financial reporting.

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

Information required for Part II, Item 1 is incorporated by reference to the discussions in Note 9., “Regulatory Matters,” and Note 10., “Commitments, Guarantees and Contingencies,” of the Combined Notes to Financial Statements of the Registrants in Part I, Item 1 of this Form 10-Q.

ITEM 1A. RISK FACTORS

As of September 30, 2026, there has been no material change to the risk factors as disclosed in FirstEnergy’s and JCP&L’s Annual Report on Form 10-K for the year ended December 31, 2025. You should carefully consider FirstEnergy’s and JCP&L’s risk factors discussed in \"Item 1A. Risk Factors\" in FirstEnergy’s and JCP&L’s Annual Report on Form 10-K for the year ended December 31, 2025, filed with the SEC on February 18, 2026.

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

None.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5. OTHER INFORMATION

Trading Arrangements

During the quarter ended September 30, 2026, no director or officer (as defined in Rule 16a-1(f) promulgated under the Exchange Act) of the Registrants adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement” (as each term is defined in Item 408 of Regulation S-K).

Amendments to Existing Revolving Credit Facilities

The information set forth below is included for the purpose of providing disclosure under \"Item 1.01 - Entry into a Material Definitive Agreement\" and \"Item 2.03 - Creation of a Direct Financial Obligation or an Obligation Under an Off-Balance Sheet Arrangement of a Registrant\" of Form 8-K.

On October 23, 2026, FE, the Ohio Companies, MP and PE, KATCo, FET and ATSI, MAIT and TrAIL, FE PA, and JCP&L, entered into amendments to their respective credit facilities (collectively, and as amended on October 23, 2026), to, among other things: (i) extend the maturity date of each credit facility for an additional one-year period (a) from October 20, 2029 to October 20, 2030 for the KATCo credit facility, (b) from October 20, 2030 to October 20, 2031 for the FET credit facility and (c) from

107

October 18, 2029 to October 18, 2030 for the remaining Amended Credit Facilities; and (ii) allow for the option to extend the Credit Agreement by up to two additional one-year periods; and (iii) increase the letters of credit commitment amount from $100 million to $400 million for the MP and PE credit facility.

The amendments to the Amended Credit Facilities are as follows:

•Amendment No. 5 to Credit Agreement, dated as of October 23, 2026, among FE, as borrower, the banks and other financial institutions party thereto, as lenders, and JPMorgan Chase Bank, N.A., as administrative agent;

•Amendment No. 5 to Credit Agreement, dated as of October 23, 2026, among CEI, OE and TE, as borrowers, the banks and other financial institutions party thereto, as lenders, and JPMorgan Chase Bank, N.A., as administrative agent;

•Amendment No. 5 to Credit Agreement, dated as of October 23, 2026, among MP and PE, as borrowers, the banks and other financial institutions party thereto, as lenders, and Mizuho Bank, Ltd., as administrative agent;

•Amendment No. 3 to Credit Agreement, dated as of October 23, 2026, among KATCo, as borrower, the banks and other financial institutions party thereto, as lenders, and PNC Bank, National Association, as administrative agent;

•Amendment No. 3 to Credit Agreement, dated as of October 23, 2026, among FET, as borrower, the banks and other financial institutions party thereto, as lenders, and JPMorgan Chase Bank, N.A., as administrative agent;

•Amendment No. 5 to Credit Agreement, dated as of October 23, 2026, among ATSI, MAIT and TrAIL, as borrowers, the banks and other financial institutions party thereto, as lenders, and PNC Bank, National Association, as administrative agent;

•Amendment No. 5 to Credit Agreement, dated as of October 23, 2026, among FE PA, as borrower, the banks and other financial institutions party thereto, as lenders, and Mizuho Bank, Ltd., as administrative agent; and

•Amendment No. 5 to Credit Agreement, dated as of October 23, 2026, among JCP&L, as borrower, the banks and other financial institutions party thereto, as lenders, and Mizuho Bank, Ltd., as administrative agent.

The foregoing description of the Amended Credit Facilities is qualified in its entirety by reference to each such amendment entered into by FE, the Ohio Companies, MP and PE, KATCo, FET, ATSI, MAIT and TrAIL, FE PA, and JCP&L, each of which is filed hereto as Exhibits 10.1, 10.2, 10.3, 10.4, 10.5 and 10.6 under FE, 10.1 under FE PA and 10.1 under JCP&L, and incorporated herein by reference.

ITEM 6. EXHIBITS


Exhibit Number	Description

FirstEnergy
(A)	10.1	Amendment No. 5 to Credit Agreement, dated as of October 23, 2026, among FE, as borrower, the banks and other financial institutions party thereto, as lenders, and JPMorgan Chase Bank, N.A., as administrative agent.
(A)	10.2	Amendment No. 5 to Credit Agreement, dated as of October 23, 2026, among CEI, OE and TE, as borrowers, the banks and other financial institutions party thereto, as lenders, and JPMorgan Chase Bank, N.A., as administrative agent.
(A)	10.3	Amendment No. 5 to Credit Agreement, dated as of October 23, 2026, among MP and PE, as borrowers, the banks and other financial institutions party thereto, as lenders, and Mizuho Bank, Ltd., as administrative agent.
(A)	10.4	Amendment No. 3 to Credit Agreement, dated as of October 23, 2026, among KATCo, as borrower, the banks and other financial institutions party thereto, as lenders, and PNC Bank, National Association, as administrative agent.
(A)	10.5	Amendment No. 3 to Credit Agreement, dated as of October 23, 2026, among FET, as borrower, the banks and other financial institutions party thereto, as lenders, and JPMorgan Chase Bank, N.A., as administrative agent.
(A)	10.6	Amendment No. 5 to Credit Agreement, dated as of October 23, 2026, among ATSI, MAIT and TrAIL, as borrowers, the banks and other financial institutions party thereto, as lenders, and PNC Bank, National Association, as administrative agent.
(A)	31.1	Certification of chief executive officer, as adopted pursuant to Rule 13a-14(a).
(A)	31.2	Certification of chief financial officer, as adopted pursuant to Rule 13a-14(a).
(A)	32	Certification of chief executive officer and chief financial officer, pursuant to 18 U.S.C. Section 1350.
	101	The following materials from the Quarterly Report on Form 10-Q of FirstEnergy Corp. for the period ended September 30, 2026, formatted in iXBRL (Inline Extensible Business Reporting Language): (i) Consolidated Statements of Income and Comprehensive Income, (ii) Consolidated Balance Sheets, (iii) Consolidated Statements of Equity, (iv) Consolidated Statements of Cash Flows, (v) related notes to these financial statements and (vi) document and entity information.
	104	Cover Page Interactive Data File (the cover page XBRL (Extensible Business Reporting Language) tags are embedded within the Inline XBRL document contained in Exhibit 101)

FE PA
(A)	10.1	Amendment No. 5 to Credit Agreement, dated as of October 23, 2026, among FE PA, as borrower, the banks and other financial institutions party thereto, as lenders, and Mizuho Bank, Ltd., as administrative agent.
(A)	31.1	Certification of principal executive officer, as adopted pursuant to Rule 13a-14(a)
(A)	31.2	Certification of principal financial officer, as adopted pursuant to Rule 13a-14(a)
(A)	32	Certification of principal executive officer and principal financial officer, pursuant to 18 U.S.C. Section 1350

108


	101	The following materials from the Quarterly Report on Form 10-Q of FirstEnergy Pennsylvania Electric Company for the period ended September 30, 2026, formatted in iXBRL (Inline Extensible Business Reporting Language): (i) Consolidated Statements of Income and Comprehensive Income, (ii) Consolidated Balance Sheets, (iii) Consolidated Statements of Common Stockholder's Equity, (iv) Consolidated Statements of Cash Flows, (v) related notes to these financial statements and (vi) document and entity information.
	104	Cover Page Interactive Data File (the cover page XBRL (Extensible Business Reporting Language) tags are embedded within the Inline XBRL document contained in Exhibit 101)

JCP&L
(A)	10.1	Amendment No. 5 to Credit Agreement, dated as of October 23, 2026, among JCP&L, as borrower, the banks and other financial institutions party thereto, as lenders, and Mizuho Bank, Ltd., as administrative agent.
(A)	31.1	Certification of principal executive officer, as adopted pursuant to Rule 13a-14(a)
(A)	31.2	Certification of principal financial officer, as adopted pursuant to Rule 13a-14(a)
(A)	32	Certification of principal executive officer and principal financial officer, pursuant to 18 U.S.C. Section 1350
	101	The following materials from the Quarterly Report on Form 10-Q of Jersey Central Power & Light Company for the period ended September 30, 2026, formatted in iXBRL (Inline Extensible Business Reporting Language): (i) Statements of Income and Comprehensive Income, (ii) Balance Sheets, (iii) Statements of Common Stockholder's Equity, (iv) Statements of Cash Flows, (v) related notes to these financial statements and (vi) document and entity information.
	104	Cover Page Interactive Data File (the cover page XBRL (Extensible Business Reporting Language) tags are embedded within the Inline XBRL document contained in Exhibit 101)

(A) Provided herein in electronic format as an exhibit.

Pursuant to paragraph (b)(4)(iii)(A) of Item 601 of Regulation S-K, the Registrants have not filed as an exhibit to this Form 10-Q any instrument with respect to long-term debt if the respective total amount of securities authorized thereunder does not exceed 10% of their respective total assets, but hereby agree to furnish to the SEC on request any such documents.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, each Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized. The signature for each undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.

October 28, 2026


	FIRSTENERGY CORP.
	Registrant

	/s/ Jason J. Lisowski
	Jason J. Lisowski
	Vice President, Controller and Chief Accounting Officer
	(Principal Accounting Officer)


	FIRSTENERGY PENNSYLVANIA ELECTRIC COMPANY
	Registrant

	/s/ Jason J. Lisowski
	Jason J. Lisowski
	Vice President and Controller
	(Principal Accounting Officer)


	JERSEY CENTRAL POWER & LIGHT COMPANY
	Registrant

	/s/ Lisa A. Schultz
	Lisa A. Schultz
	Controller
	(Principal Accounting Officer)

110

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