SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Large accelerated filer o

Non-accelerated filer þ (Do not check if a smaller reporting company)

Smaller reporting company o

Emerging growth company o

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

OKLAHOMA GAS AND ELECTRIC COMPANY

FOR THE QUARTER ENDED ~~SEPTEMBER 30, 2017~~MARCH 31, 2018

The following is a glossary of frequently used abbreviations that are found throughout this Form 10-Q.



Abbreviation	Definition
~~2016~~2017 Form 10-K	Annual Report on Form 10-K for the year ended December 31, ~~2016~~2017
~~ALJ~~2017 Tax Act	~~Administrative Law Judge~~Tax Cuts and Jobs Act of 2017
APSC	Arkansas Public Service Commission
~~ASU~~ASC	~~Financial~~FASB Accounting Standards ~~Board~~Codification
ASU	FASB Accounting Standards Update
CO₂	Carbon dioxide
CSAPR	Cross-State Air Pollution Rule
Dry Scrubbers	Dry flue gas desulfurization units with spray dryer absorber
ECP	Environmental Compliance Plan
Enable	Enable Midstream Partners, LP, a midstream partnership formed between OGE Energy and CenterPoint Energy, Inc.
EPA	U.S. Environmental Protection Agency
FASB	Financial Accounting Standards Board
Federal Clean Water Act	Federal Water Pollution Control Act of 1972, as amended
FERC	Federal Energy Regulatory Commission
FIP	Federal ~~implementation plan~~Implementation Plan
GAAP	Accounting principles generally accepted in the ~~United States~~U.S.
IRP	Integrated Resource Plan
kV	~~Kilovolt~~
MATS	Mercury and Air Toxics Standards
Mustang Modernization Plan	~~OG&E's plan to replace the soon-to-be retired Mustang steam turbines in late 2017 and early 2018 with 462 MWs~~The construction of seven new, efficient combustion turbines ~~at the Mustang site~~
MW	~~Megawatt~~with generating capability of 462 megawatts
MWh	Megawatt-hour
NAAQS	National Ambient Air Quality Standards
NO_X	Nitrogen oxide
OCC	Oklahoma Corporation Commission
OG&E	Oklahoma Gas and Electric Company, wholly-owned subsidiary of OGE Energy
OGE Energy	OGE Energy Corp., parent company of OG&E
Pension Plan	Qualified defined benefit retirement plan
~~ppb~~Ppb	Parts per billion
~~PUD~~	~~Public Utility Division of the Oklahoma Corporation Commission~~
QF	~~Qualified cogeneration facilities~~
Regional Haze Rule	The EPA's ~~regional haze rule~~Regional Haze Rule
Restoration of Retirement Income Plan	Supplemental retirement plan to the Pension Plan
SIP	State ~~implementation plan~~Implementation Plan
SO₂	Sulfur dioxide
SPP	Southwest Power Pool
System sales	Sales to OG&E's customers
U.S.	United States of America

FORWARD-LOOKING STATEMENTS

Except for the historical statements contained herein, the matters discussed in this Form 10-Q, including those matters discussed in "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations," are forward-looking statements that are subject to certain risks, uncertainties and assumptions. Such forward-looking statements are intended to be identified in this document by the words "anticipate," "believe," "estimate," "expect," "intend," "objective," "plan," "possible," "potential," "project" and similar expressions. Actual results may vary materially from those expressed in forward-looking statements. In addition to the specific risk factors discussed in "Item 1A. Risk Factors" in OG&E's ~~2016~~2017 Form 10-K and "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations" herein, factorsthat could cause actual results to differ materially from the forward-looking statements include, but are not limited to:

the ability of OG&E and OGE Energy to access the capital markets and obtain financing on favorable terms as well as inflation rates and monetary fluctuations;

prices and availability of electricity, coal and natural gas;

business conditions in the energy industry;

competitive factors, including the extent and timing of the entry of additional competition in the markets served by OG&E;

the impact on demand for our services resulting from cost-competitive advances in technology, such as distributed electricity generation and customer energy efficiency programs;

technological developments, changing markets and other factors that result in competitive disadvantages and create the potential for impairment of existing assets;

the effect of retroactive pricing of transactions in the SPP markets or adjustments in market pricing mechanisms by the SPP;

~~Federal~~federal or state legislation and regulatory decisions and initiatives that affect cost and investment recovery, have an impact on rate structures or affect the speed and degree to which competition enters OG&E's markets;

environmental laws, safety laws or other regulations that may impact the cost of operations or restrict or change the way OG&E operates its facilities;

creditworthiness of suppliers, customers and other contractual parties;

identification of suitable investment opportunities to enhance shareholder returns and achieve long-term financial objectives through business acquisitions and divestitures;

costs and other effects of legal and administrative proceedings, settlements, investigations, claims and matters, including, but not limited to, those described in this Form 10-Q; and

other risk factors listed in the reports filed by OG&E with the Securities and Exchange Commission, including those listed in "Item 1A. Risk Factors" in OG&E's ~~2016~~2017 Form 10-K.

OG&E undertakes no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements.

OKLAHOMA GAS AND ELECTRIC COMPANY

CONDENSED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME

The accompanying Notes to Condensed Financial Statements are an integral part hereof.

OKLAHOMA GAS AND ELECTRIC COMPANY

CONDENSED STATEMENTS OF CASH FLOWS

The accompanying Notes to Condensed Financial Statements are an integral part hereof.

OKLAHOMA GAS AND ELECTRIC COMPANY

CONDENSED BALANCE SHEETS

The accompanying Notes to Condensed Financial Statements are an integral part hereof.

OKLAHOMA GAS AND ELECTRIC COMPANY

CONDENSED BALANCE SHEETS (Continued)

The accompanying Notes to Condensed Financial Statements are an integral part hereof.

OKLAHOMA GAS AND ELECTRIC COMPANY

CONDENSED STATEMENTS OF CHANGES IN STOCKHOLDER'S EQUITY

The accompanying Notes to Condensed Financial Statements are an integral part hereof.

OKLAHOMA GAS AND ELECTRIC COMPANY

NOTES TO CONDENSED FINANCIAL STATEMENTS

OG&E's significant accounting policies are detailed in "Note 1. Summary of Significant Accounting Policies" in OG&E's 2017 Form 10-K. Changes to OG&E's accounting policies as a result of adopting ASU 2014-09, "Revenue from Contracts with Customers (Topic 606)," are discussed in Note 3.

OG&E generates, transmits, distributes and sells electric energy in Oklahoma and western Arkansas. Its operations are subject to regulation by the OCC, the APSC and the FERC. OG&E was incorporated in 1902 under the laws of the Oklahoma Territory. OG&E is the largest electric utility in Oklahoma, and its franchised service territory includes Fort Smith, Arkansas and the surrounding communities. OG&E sold its retail natural gas business in 1928 and is no longer engaged in the natural gas distribution business. OG&E is a wholly-owned subsidiary of OGE Energy, an energy and energy services provider offering physical delivery and related services for both electricity and natural gas primarily in the south central ~~United States.~~U.S.

Basis of Presentation

The Condensed Financial Statements included herein have been prepared by OG&E, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations; however, OG&E believes that the disclosures are adequate to prevent the information presented from being misleading.

In the opinion of management, all adjustments necessary to fairly present the financial position of OG&E at ~~September 30, 2017~~March 31, 2018 and December 31, ~~2016,~~2017, the results of its operations for the three ~~and nine~~ months ended ~~September 30, 2017~~March 31, 2018 and ~~2016~~2017 and its cash flows for the ~~nine~~three months ended ~~September 30,~~March 31, 2018 and 2017 ~~and 2016~~ have been included and are of a normal, recurring nature except as otherwise disclosed. Management also has evaluated the impact of events occurring after ~~September 30, 2017~~March 31, 2018 up to the date of issuance of these Condensed Financial Statements, and these statements contain all necessary adjustments and disclosures resulting from that evaluation.

Due to seasonal fluctuations and other factors, OG&E's operating results for the three ~~and nine~~ months ended ~~September 30, 2017~~March 31, 2018 are not necessarily indicative of the results that may be expected for the year ending December 31, ~~2017~~2018 or for any future period. The Condensed Financial Statements and Notes thereto should be read in conjunction with the audited Financial Statements and Notes thereto included in OG&E's ~~2016~~2017 Form 10-K.

The accounting records of OG&E are maintained in accordance with the Uniform System of Accounts prescribed by the FERC and adopted by the OCC and the APSC. Additionally, OG&E, as a regulated utility, is subject to accounting principles for certain types of rate-regulated activities, which provide that certain incurred costs that would otherwise be charged to expense can be deferred as regulatory assets, based on the expected recovery from customers in future rates. Likewise, certain actual or anticipated credits that would otherwise reduce expense can be deferred as regulatory liabilities, based on the expected flowback to customers in future rates. Management's expected recovery of deferred costs and flowback of deferred credits generally results from specific decisions by regulators granting such ratemaking treatment.

OG&E records certain incurred costs and obligations as regulatory assets or liabilities if, based on regulatory orders or other available evidence, it is probable that the costs or obligations will be included in amounts allowable for recovery or refund in future rates.

The following table is a summary of OG&E's regulatory assets and ~~liabilities at:~~liabilities.

Management continuously monitors the future recoverability of regulatory assets. When in management's judgment future recovery becomes impaired, the amount of the regulatory asset is adjusted, as appropriate. If OG&E were required to discontinue the application of accounting principles for certain types of rate-regulated activities for some or all of its operations, it could result in writing off the related regulatory assets, which could have significant financial effects.

~~OG&E has asset retirement obligations primarily associated with the removal of company-owned wind turbines on leased land, as well as the removal of asbestos from certain power generating stations.~~Reclassifications

~~The following table summarizes changes~~Certain prior-year amounts have been reclassified to conform to the current year presentation.

Amounts for the three months ended March 31, 2017 have been adjusted for the reclassification of net periodic benefit cost components between Other Operation and Maintenance and Other Net Periodic Pension and Postretirement Benefit (Cost) on OG&E's ~~asset retirement obligations during~~Condensed Income Statements to be consistent with the ~~nine months ended~~ ~~September 30, 2017~~ 2018 presentation due to OG&E's adoption of ASU 2017-07, "Improving the Presentation of Net Periodic Pension Cost and~~2016~~.

Recently Adopted Accounting Standards

Revenue from Contracts with Customers. In May 2014, the FASB issued ASU 2014-09, "Revenue from Contracts with Customers (Topic 606)." ~~The new revenue standard is effective for fiscal years, and interim periods within those fiscal years, beginning after December 2017.~~ OG&E ~~has assessed the effect of~~adopted this new guidance on its tariff-based sales, bundled arrangements and alternative revenue program and is not aware of any issues that would have a material impact on the timing of revenue recognition. The new standard will not have a material impact on OG&E's results of operations and financial position but will change the income statement presentation of revenues and require new disclosures. OG&E does not intend to early adopt the new guidance and will implement in the first quarter of 2018 utilizing the modified retrospective transition ~~method.~~method and applied the new standard only to contracts that were not completed at the date of initial application. OG&E determined it was not necessary to change the timing or amounts of revenue recognized based on the adoption of Topic 606. Therefore, financial statement amounts in the period of adoption have not changed under Topic 606 as compared with the guidance that was in effect before the adoption of Topic 606. The adoption did change financial statement presentation as Operating Revenues are now separated between Revenues from Contracts with Customers and Revenues from Alternative Revenue Programs on the 2018 Condensed Statement of Income. In addition, gains and losses associated with OG&E's guaranteed flat bill program that were previously included in Net Other Income on the Condensed Statements of Income are now considered Revenues from Contracts with Customers and are presented as such since the gains and losses are included within the transaction price in the contract under Topic 606. Operating Revenues on the 2017 Condensed Statement of Income did not change from what had been disclosed in prior year. Alternative revenue programs are scoped out of Topic 606, as these programs are considered agreements between an entity and a regulator, not contracts between an entity and a customer; therefore, OG&E now presents revenues from alternative revenue programs separately from revenues from contracts with customers. Further discussion regarding revenue recognized through alternative revenue programs as well as additional disclosures resulting from OG&E's adoption of Topic 606 can be found in Note 3.

Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost. In May 2017, the FASB issued ASU 2017-07, "Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost." The new guidance is designed to improve the reporting of pension and other postretirement benefit costs by bifurcating the components of net benefit cost between those that are attributed to compensation for service and those that are not. The service cost component of benefit cost continues to be presented within operating income, but entities are now required to present the other components of benefit cost as non-operating within the income statement. Additionally, the new guidance only permits the capitalization of the service cost component of net benefit cost. The accounting change is required to be applied on a retrospective basis for the presentation of components of net benefit cost and on a prospective basis for the capitalization of only the service cost component of net benefit costs. OG&E adopted the new guidance beginning in the first quarter of 2018. The presentation and recognition impacts of OG&E's adoption of ASU 2017-07 are further discussed in Note 10.

Issued Accounting Standards Not Yet Adopted

Leases. In February 2016, the FASB issued ASU 2016-02, "Leases (Topic 842)." The main difference between current lease accounting and Topic 842 is the recognition of ~~right-to-use~~right-of-use assets and lease liabilities by lessees for those leases classified as operating leases under current accounting guidance. Lessees, such as OG&E, will need to recognize a right-of-use asset and a lease liability for virtually all of their leases, other than leases that meet the definition of a short-term lease. The liability will be equal to the present value of lease payments. The asset will be based on the liability, subject to adjustment, such as for initial direct costs. For income statement purposes, Topic 842 retains a dual model, requiring leases to be classified as either operating or finance. Operating leases will result in straight-line expense, while finance leases will result in a front-loaded expense pattern, similar to current capital leases. Classification of operating and finance leases will be based on criteria that are largely similar to those applied in current lease guidance but without the explicit thresholds. The new guidance is effective for fiscal years beginning after December 2018. The new guidance must be adopted using a modified retrospective transition method and provides for certain practical expedients. Transition will require application of the new guidance at the beginning of the earliest comparative period presented. OG&E has started evaluating its current lease contracts. OG&E has not ~~determined~~quantified the ~~amount of~~ impact on its Condensed Financial Statements, but it anticipates an increase in the recognition of right-of-use assets and lease liabilities.

~~Employee Share Based Payment Accounting.~~In ~~March 2016,~~January 2018, the FASB issued ASU ~~2016-09, "Improvements~~2018-01, "Leases (Topic 842): Land Easement Practical Expedient for Transition to ~~Employee Share-Based Payment Accounting,~~Topic 842," which ~~amends Accounting Standards Codification~~is an amendment to ASU 2016-02. Land easements (also commonly referred to as rights of way) represent the right to use, access or cross another entity's land for a specified purpose. This new guidance permits an entity to elect a transitional practical expedient, to be applied consistently, to not evaluate under Topic ~~718, Compensation - Stock Compensation. ASU 2016-09 includes provisions intended to simplify various aspects related to how share-based payments are~~842 land easements that exist or expired before the entity's adoption of Topic 842 and that were not previously accounted for and presented in the financial statements. The new guidance, among other requirements, requires all of the tax effects related to share-based payments at settlement (or expiration) to be recorded through the income statement. Previously, tax benefits in excess of compensation cost, or windfalls, were recorded in equity, and tax deficiencies, or shortfalls, were recorded in equity to the extent of previous windfalls and then to the income statement. Under the new guidance, the windfall tax benefitas leases under ASC 840, "Leases." Once Topic 842 is ~~recorded when it arises, subject to normal valuation allowance considerations. This change~~adopted, an entity is required to apply Topic 842 prospectively to all new (or modified) land easements to determine whether the arrangement should be ~~applied on~~accounted for as a modified retrospective basis, with a cumulative effect adjustment to opening retained earnings. All tax-related cash flows resulting from share-based payments are to be reported as operating activities on the statement of cash flows, which is a change from the previous requirement to present windfall tax benefits as an inflow from financing activities and an outflow from operating activities. OG&E adopted this standard in the first quarter of 2017, which resulted in no financial statement impact. Going forward, tax benefits in excess of compensation costs previously recorded in equity will be recorded within the income statement, and all tax-related cash flows resulting from share-based payments will be recorded as an operating activity within the statement of cash flows.

~~Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost.~~ ~~In May 2017, the FASB issued~~lease. ASU 2017-07, "Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost." The new guidance is designed to improve the reporting of pension and other postretirement benefit costs by bifurcating the components of net benefit expense between those that are attributed to compensation for service and those that are not. The service cost component of benefit expense will continue to be presented within operating income, but entities will now be required to present the other components of benefit expense as non-operating within the income statement. Additionally, the new guidance only permits the capitalization of the service cost component of net benefit expense.

The accounting change is required to be applied on a retrospective basis for the presentation of components of net benefit cost and on a prospective basis for the capitalization of only the service cost component of net benefit costs. The new guidance2018-01 is effective for ~~annual periods~~fiscal years beginning after December ~~2017, including interim periods within those annual periods. Early~~2018. OG&E intends to elect this practical expedient during its adoption ~~is permitted, subject to certain conditions.~~ of Topic 842 and will not evaluate all existing easement contracts under Topic 842, as these contracts have not previously been accounted for under Topic 840.

OG&E believes that the impact of the change in capitalization of only the service cost component of net periodic benefit costs will be immaterial from current practice. OG&E does not intend to early adopt the new guidance and will implement the change in the first quarter of 2018.

OG&E recognizes revenue from electric sales when power is delivered to customers. OG&E reads its customers' meters and sends bills to its customers throughout each month. As a result, there is a significant amount of customers' electricity consumption that has not been billed at the end of each month. OG&E accrues an estimate of the revenues for electric sales delivered since the latest billings. Unbilled revenue is presented in Accrued Unbilled Revenues on the Condensed Balance Sheets and in Revenue from Contracts with Customers on the Condensed Statements of Income based on estimates of usage and prices during the period. The estimates that management uses in this calculation could vary from the actual amounts to be paid by customers.

Revenue from Alternative Revenue Programs on the Condensed Statements of Income is comprised of certain rider revenue that includes alternative revenue measures as defined in ASC 980,“Regulated Operations,” which details two types of alternative revenue programs. The first type adjusts billings for the effects of weather abnormalities or broad external factors or to compensate OG&E for demand side management initiatives (i.e., no-growth plans and similar conservation efforts). The second type provides for additional billings (i.e., incentive awards) for the achievement of certain objectives, such as reducing costs, reaching specified milestones or demonstratively improving customer service. Once the specific events permitting billing of the additional revenues under either program type have been completed, OG&E recognizes the additional revenues if (i) the program is established by an order from OG&E's regulatory commission that allows for automatic adjustment of future rates; (ii) the amount of additional revenues for the period is objectively determinable and is probable of recovery; and (iii) the additional revenues will be collected within 24 months following the end of the annual period in which they are recognized.

SPP Purchases and Sales

OG&E currently owns and operates transmission and generation facilities as part of a vertically integrated utility. OG&E is a member of the SPP regional transmission organization and has transferred operational authority, but not ownership, of OG&E's transmission facilities to the SPP. The SPP has implemented FERC-approved regional day ahead and real-time markets for energy and operating services, as well as associated transmission congestion rights. Collectively the three markets operate together under the global name, SPP Integrated Marketplace. OG&E represents owned and contracted generation assets and customer load in the SPP Integrated Marketplace for the sole benefit of its customers. OG&E has not participated in the SPP Integrated Marketplace for any speculative trading activities. OG&E records the SPP Integrated Marketplace transactions as sales or purchases per FERC Order 668, which requires that purchases and sales be recorded on a net basis for each settlement period of the SPP Integrated Marketplace. These results are reported as Revenue from Contracts with Customers or Cost of Sales in the Condensed Financial Statements. OG&E revenues, expenses, assets and liabilities may be adversely affected by changes in the organization, operating and regulation by the FERC or the SPP.

The following table disaggregates OG&E's revenues from contracts with customers by customer classification. OG&E's operating revenues disaggregated by customer classification can be found in "Results of Operations" in "Item 2. Management's Discussion and Analysis."



	Three Months Ended
(In millions)	March 31, 2018
Residential	$	196.3
Commercial	117.8
Industrial	41.7
Oilfield	33.7
Public authorities and street light	41.7
System sales revenues	431.2
Provision for rate refund	(3.2		)
Integrated market	8.6
Transmission	35.8
Other	5.5
Revenues from contracts with customers	$	477.9

OGE Energy charged operating costs to OG&E of $~~30.2~~33.6 million and $~~30.1~~34.6 million during the three months ended ~~September 30, 2017~~March 31, 2018 and ~~2016~~2017, ~~respectively, and $97.9 million and $97.0 million during the nine months ended September 30, 2017 and 2016,~~ respectively. OGE Energy charges operating costs to OG&E based on several ~~factors. Operating~~factors, and operating costs directly related to OG&E are assigned as such. Operating costs incurred for the benefit of OG&E are allocated either as overhead based primarily on labor costs or using the "Distrigas" method.

Enable provides gas transportation services to OG&E pursuant to an agreement that expires in April 2019. This transportation agreement grants Enable the responsibility of delivering natural gas to OG&E’s generating facilities and performing an imbalance service. With this imbalance service, in accordance with the cash-out provision of the contract, OG&E purchases gas from Enable when Enable’s deliveries exceed OG&E’s pipeline receipts. Enable purchases gas from OG&E when OG&E’s pipeline receipts exceed Enable’s deliveries. The following table summarizes related party transactions between OG&E and Enable during the three ~~and nine~~ months ended ~~September 30, 2017~~March 31, 2018 and ~~2016~~2017.

During the ~~nine~~three months ended ~~September 30,~~March 31, 2018 and 2017,, OG&E declared no dividends ~~of $105.0 million~~ to OGE ~~Energy as compared to $125.0 million during the same period in 2016.~~Energy.

The classification of OG&E's fair value measurements requires judgment regarding the degree to which market data is observable or corroborated by observable market data. GAAP establishes a fair value hierarchy that prioritizes the inputs used to measure fair value based on observable and unobservable data. The hierarchy categorizes the inputs into three levels, with the highest priority given to quoted prices in active markets for identical unrestricted assets or liabilities (Level 1), and the lowest priority given to unobservable inputs (Level 3). Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The three levels defined in the fair value hierarchy are as follows:

Level 1 inputs are quoted prices in active markets for identical unrestricted assets or liabilities that are accessible at the measurement date.

Level 2 inputs are inputs other than quoted prices in active markets included within Level 1 that are either directly or indirectly observable at the reporting date for the asset or liability for substantially the full term of the asset or liability. Level 2 inputs include quoted prices for similar assets or liabilities in active markets and quoted prices for identical or similar assets or liabilities in markets that are not active.

Level 3 inputs are prices or valuation techniques for the asset or liability that require inputs that are both significant to the fair value measurement and unobservable (i.e., supported by little or no market activity). Unobservable inputs reflect the reporting entity's own assumptions about the assumptions that market participants would use in pricing the asset or liability (including assumptions about risk).

OG&E had nofinancial instruments measured at fair value on a recurring basis at~~September 30, 2017~~March 31, 2018 and December 31, ~~2016.~~

2017. The fair value of OG&E's long-term debt is based on quoted market prices and estimates of current rates available for similar issues with similar maturities and is classified as Level 2 in the fair value hierarchy, with the exception of the Tinker Debt which is classified as Level 3 in the fair value hierarchy as its fair value is based on calculating the net present value of the monthly payments discounted by OG&E's current borrowing ~~rate and is classified as Level 3 in the fair value hierarchy.~~

rate. The following table summarizes the fair value and carrying amount of OG&E's financial instruments at ~~September 30, 2017~~March 31, 2018 and December 31, ~~2016~~.2017.

The following table summarizes OG&E's pre-tax compensation expense and related income tax benefit during the three ~~and nine~~ months ended ~~September 30, 2017~~March 31, 2018 and ~~2016~~2017 related to OGE Energy performance units and restricted stock for OG&E employees.

During the three ~~and nine~~ months ended ~~September 30, 2017,~~March 31, 2018, OGE Energy issued ~~an immaterial number~~8,399 shares of ~~shares~~new common stock to OG&E employees pursuant to OGE Energy's Stock Incentive Plan to satisfy restricted stock ~~grants.~~grants and payouts of earned performance units.

The following table summarizes stock-based compensation grants to OG&E employees during the three months ended March 31, 2018.

As previously discussed in OG&E's 2017 Form 10-K, the 2017 Tax Act was signed into law in December 2017, reducing the corporate federal tax rate from 35 percent to 21 percent for tax years beginning in 2018. ASC 740, "Income Taxes," requires deferred tax assets and liabilities to be measured at the enacted tax rate expected to apply when temporary differences are to be realized and settled. Entities subject to ASC 980, "Accounting for Regulated Entities," such as OG&E, are required to recognize a regulatory liability for the decrease in taxes payable for the change in tax rates that are expected to be returned to customers through future rates and to recognize a regulatory asset for the increase in taxes receivable for the change in tax rates that are expected to be recovered from customers through future rates. At December 31, 2017, as a result of remeasuring existing deferred taxes at the lower 21 percent tax rate, OG&E reduced net deferred income tax liabilities and increased regulatory liabilities. As of March 31, 2018, OG&E's regulatory liability for income taxes refundable to customers, net was $951.3 million, as disclosed in Note 1.

Staff Accounting Bulletin No. 118 addresses the application of U.S. GAAP in situations when a registrant does not have the necessary information available, prepared or analyzed (including computations) in reasonable detail to complete the accounting for certain income tax effects of the 2017 Tax Act. OG&E recognized the provisional tax impacts related to the revaluation of deferred tax assets and liabilities as of December 31, 2017. The ultimate impact may differ from those provisional amounts, possibly materially, due to, among other things, additional analysis, changes in interpretations and assumptions OG&E has made, additional regulatory guidance that may be issued and the actions OG&E may take as a result of the 2017 Tax Act. OG&E continues to evaluate its computations, and any subsequent adjustments to the amounts recognized as of December 31, 2017 will be recorded in the quarter when the analysis is complete.

As a result of the 2017 Tax Act: (i) the OCC ordered OG&E to record a reserve, which should include accrued interest, to reflect the reduced federal corporate tax rate, among other tax implications, on an interim basis, subject to refund until utility rates are adjusted to reflect the federal tax savings and a final order is issued in OG&E's pending rate review filed in January 2018; (ii) the APSC ordered OG&E to book regulatory liabilities to record the current and deferred impacts of the 2017 Tax Act and will subsequently order how any resulting benefits, including carrying charges, should be returned to customers; and (iii) through a Section 206 filing with the FERC, modifications were requested to be made to OG&E's transmission formula rates to reflect the impacts of the 2017 Tax Act. OG&E is reserving the excess income taxes collected in current rates, plus interest, starting in January 2018 until the date of an order received from the OCC, APSC and FERC; as of March 31, 2018, the total recorded reserve was $6.5 million. Further discussion can be found in Note 12.

OG&E is a member of an affiliated group that files consolidated income tax returns in the U.S. ~~Federal~~federal jurisdiction and various state jurisdictions. With few exceptions, OG&E is no longer subject to U.S. ~~Federal~~federal tax examinations by tax authorities for years prior to 2014 or state and local tax examinations by tax authorities for years prior to 2013. Income taxes are generally allocated to each company in the affiliated group based on its stand-alone taxable income or loss. Federal investment tax credits previously claimed on electric utility property have been deferred and are being amortized to income over the life of the related property. OG&E earns both ~~Federal~~federal and Oklahoma state tax credits associated with production from its wind farms and earns Oklahoma state tax credits associated with its investments in electric generating facilities which further reduce OG&E's effective tax rate.


7.8.	Long-Term Debt

At ~~September 30, 2017~~March 31, 2018, OG&E was in compliance with all of its debt agreements.

Industrial Authority Bonds

OG&E has tax-exempt pollution control bonds with optional redemption provisions that allow the holders to request repayment of the bonds on any business day. The bonds, which can be tendered at the option of the holder during the next 12 months, are ~~as follows:~~included in the following table.

SERIES DATE DUE AMOUNT
(In millions)
0.65% - 1.03% Garfield Industrial Authority, January 1, 2025 $ 47.0
0.65% - 0.97% Muskogee Industrial Authority, January 1, 2025 32.4
0.66% - 0.98% Muskogee Industrial Authority, June 1, 2027 56.0
Total (redeemable during next 12 months) $ 135.4



SERIES			DATE DUE	AMOUNT
				(In millions)
1.06%	-	1.68%	Garfield Industrial Authority, January 1, 2025	$	47.0
1.05%	-	1.65%	Muskogee Industrial Authority, January 1, 2025	32.4
1.06%	-	1.67%	Muskogee Industrial Authority, June 1, 2027	56.0
Total (redeemable during next 12 months)				$	135.4

All of these bonds are subject to an optional tender at the request of the holders, at 100 percent of the principal amount, together with accrued and unpaid interest to the date of purchase. The bond holders, on any business day, can request repayment of the bond by delivering an irrevocable notice to the tender agent stating the principal amount of the bond, payment instructions for the purchase price and the business day the bond is to be purchased. The repayment option may only be exercised by the holder of a bond for the principal amount. When a tender notice has been received by the trustee, a third-party remarketing agent for the bonds will attempt to remarket any bonds tendered for purchase. This process occurs once per week. Since the original issuance of these series of bonds in 1995 and 1997, the remarketing agent has successfully remarketed all tendered bonds. If the remarketing agent is unable to remarket any such bonds, OG&E is obligated to repurchase such unremarketed bonds. As OG&E has both the intent and ability to refinance the bonds on a long-term basis and such ability is supported by an ability to consummate the refinancing, the bonds are classified as Long-term Debt in OG&E's Condensed Financial Statements. OG&E believes that it has sufficient liquidity to meet these obligations.

~~Issuance of New Long-Term Debt~~

In March 2017, OG&E issued $300.0 million of 4.15 percent senior notes due April 1, 2047. The proceeds from the issuance were used to repay short-term debt and were added to OG&E's general funds to be used for general corporate purposes, including to repay borrowings under the revolving credit facility, to fund the payment of OG&E's $125.0 million of 6.5 percent senior notes that matured on July 15, 2017 and to fund ongoing capital expenditures and working capital.

In August 2017, OG&E issued $300.0 million of 3.85 percent senior notes due August 15, 2047. The proceeds from the issuance were used for general corporate purposes, including to repay short-term debt, to repay borrowings under the revolving credit facility, to fund ongoing capital expenditures and for working capital.


8.9.	Short-Term Debt and Credit Facility

On March 8, 2017, OG&E entered into a new unsecured $450.0 million five-year revolving credit facility. The new facility is scheduled to terminate on March 8, 2022. However, OG&E has the right to request an extension of the revolving credit facility termination date under its facility for an additional one-year period, which can be exercised up to two times. All such extension requests are subject to majority lender group approval (and only the commitments of those lenders that consent to such extension (or that agree to replace any non-consenting lender) will be extended for such additional period).

Borrowings under OG&E’s new facility shall bear interest at rates equal to either the eurodollar base rate (reserve adjusted, if applicable), plus a margin of 0.69 percent to 1.275 percent, or an alternate base rate, plus a margin of 0.0 percent to 0.275 percent. OG&E’s new facility has a facility fee that ranges from 0.06 percent to 0.225 percent. Interest rate margins and facility fees are based on OG&E’s then-current senior unsecured credit ratings.

The new facility provides for issuance of letters of credit, provided that (i) the aggregate outstanding credit exposure shall not exceed the amount of the revolving credit facility and (ii) the aggregate outstanding stated amount of letters of credit issued under such facility shall not exceed a sublimit of $100.0 million. Advances under the new facility may be used to refinance existing indebtedness and for working capital and general corporate purposes, including commercial paper liquidity support, letters of credit, acquisitions and distributions.

The new facility is unsecured and, under certain circumstances, may be increased by up to $150.0 million, to a maximum revolving commitment limit of $600.0 million. Advances of revolving loans and letters of credit under the new facility are subject to certain conditions precedent, including the accuracy of certain representations and warranties and the absence of any default or unmatured default.

The new facility has a financial covenant requiring that OG&E maintain a maximum debt to capitalization ratio of 65 percent, as defined in the facility. OG&E's new facility also contains covenants which restrict, among other things, mergers and consolidations, sales of all or substantially all assets, incurrence of liens and transactions with affiliates. OG&E's new facility is subject to acceleration upon the occurrence of any default, including, among others, payment defaults on such facility, breach of representations, warranties and covenants, acceleration of indebtedness (other than intercompany and non-recourse indebtedness) of $100.0 million or more in the aggregate, change of control (as defined in the new facility), nonpayment of uninsured judgments in excess of $100.0 million and the occurrence of certain Employee Retirement Income Security Act and bankruptcy events, subject where applicable to specified cure periods.

At ~~September 30, 2017~~March 31, 2018, there was ~~$32.6~~$129.3 million in advances to OGE Energy compared to ~~$49.9~~$112.5 million ~~in advances from OGE Energy~~ at December 31, ~~2016~~2017. OG&E has an intercompany borrowing agreement with OGE Energy whereby OG&E has access to up to $350.0 million of OGE Energy's revolving credit amount. This agreement has a termination date of March 8, 2022. At ~~September 30, 2017~~March 31, 2018, there werenointercompany borrowings under this agreement. At At~~September 30, 2017~~March 31, 2018, there were $0.3 million supporting letters of credit at a weighted-average interest rate of 0.95 percent. There were no outstanding commercial paper borrowings at ~~September 30, 2017.~~March 31, 2018.

In March 2017, OG&E entered into an unsecured five-year $450.0 million revolving credit agreement. The facility contained an option, which could be exercised up to two times, to extend the term of the facility for an additional year. Effective March 9, 2018, OG&E utilized one of those extensions to extend the maturity of its credit facility from March 8, 2022 to March 8, 2023.

OGE Energy's and OG&E's ability to access the commercial paper market could be adversely impacted by a credit ratings downgrade or major market disruptions. Pricing grids associated with OGE Energy's and OG&E's credit facilities could cause annual fees and borrowing rates to increase if an adverse rating impact occurs. The impact of any future downgrade could include an increase in the costs of OGE Energy's and OG&E's short-term borrowings, but a reduction in OGE Energy's and OG&E's credit ratings would not result in any defaults or accelerations. Any future downgrade of OG&E could also lead to higher long-term borrowing costs and, if below investment grade, would require OG&E to post collateral or letters of credit.

OG&E must obtain regulatory approval from the FERC in order to borrow on a short-term basis. OG&E has the necessary regulatory approvals to incur up to $800.0 million in short-term borrowings at any one time for a two-year period beginning January 1, 2017 and ending December 31, 2018.


9.10.	Retirement Plans and Postretirement Benefit Plans

~~The details~~Net Periodic Benefit Cost

OG&E adopted ASU 2017-07 in the first quarter of 2018 and, as a result, presents the service cost component of net ~~periodic~~benefit cost in operating income and the other components of net benefit cost as non-operating within OG&E's Condensed Income Statements. Further, as required by ASU 2017-07, OG&E adjusted prior year income statement presentation of the net benefit cost components, which were previously disclosed in total within Other Operation and Maintenance on OG&E's Condensed Statements of Income. OG&E elected the practical expedient allowed by ASU 2017-07 to utilize amounts disclosed in OG&E's retirement plans and postretirement benefit plans note for the prior comparative period as the estimation basis for applying the retrospective presentation requirements.

The following table presents OG&E's portion of OGE Energy's Pension Plan, Restoration of Retirement Income Plan and postretirement benefit plans components of net benefit cost, before consideration of capitalized amounts, of ~~OG&E's portion~~grouped under the corresponding individual Condensed Statements of ~~OGE Energy's~~ ~~Pension Plan, the Restoration of Retirement~~ Income ~~Plan and the postretirement benefit plans included in the CondensedFinancial Statements are as follows:~~line item.

~~Net Periodic Benefit Cost~~


	Pension Plan												Restoration of Retirement Income Plan								Pension Plan						Restoration of Retirement Income Plan				Postretirement Benefit Plans
	Three Months Ended						Nine Months Ended						Three Months Ended				Nine Months Ended				Three Months Ended						Three Months Ended				Three Months Ended
	September 30,												September 30,								March 31,						March 31,				March 31,
(In millions)	2017 (A)			2016 (A)			2017 (B)			2016 (B)			2017 (A)		2016 (A)		2017 (B)		2016 (B)		2018			2017			2018		2017		2018			2017
Included in Other Operation and Maintenance:
Service cost	$	2.5		$	2.6		$	7.6		$	7.7		$	0.1	$	—	$	0.1	$	—	$	2.7		$	2.7		$	—	$	—	$	0.1		$	0.1
Included in Other Net Periodic Pension and Postretirement Benefit (Cost):
Interest cost	4.9			4.8			14.6			14.4			—		0.1		0.1		0.1		4.4			4.8			—		—		1.0			1.7
Expected return on plan assets	(8.2		)	(8.2		)	(24.6		)	(24.8		)	—		—		—		—		(8.5		)	(8.3		)	—		—		(0.5		)	(0.5		)
Amortization of net loss	3.2			3.1			9.7			9.3			0.1		—		0.3		0.1		3.0			3.0			0.1		0.1		1.0			0.6
Settlement	—			—			—			—			—		—		—		0.4
Net periodic benefit cost	$	2.4		$	2.3		$	7.3		$	6.6		$	0.2	$	0.1	$	0.5	$	0.6
Amortization of unrecognized prior service cost (A)																					—			—			—		—		(1.5		)	—
Total net periodic benefit cost																					1.6			2.2			0.1		0.1		0.1			1.9
Plus: Amount allocated from OGE Energy																					0.5			—			0.1		—		(0.2		)	—
Net periodic benefit cost (B)																					$	2.1		$	2.2		$	0.2	$	0.1	$	(0.1	)	$	1.9

~~In addition to the~~ ~~$2.6 million and $2.4 million~~ ~~of net periodic benefit cost recognizedduring the~~ ~~three months ended~~ ~~September 30, 2017and2016~~, ~~respectively~~, ~~OG&E recognized~~ an increase in pension expense during the three months ended September 30, 2017 and 2016 of $2.7 million and $2.4 million, respectively, to maintain the allowable amount to be recovered for pension expense in the Oklahoma jurisdiction, which are included in the pension tracker regulatory liability (see Note 1).

Postretirement Benefit Plans
Three Months Ended Nine Months Ended
September 30, September 30,
(In millions) 2017
(B) 2016
(B) 2017
(C) 2016
(C)
Service cost $ 0.1
$ 0.1
$ 0.3
$ 0.4
Interest cost 1.2
1.8
4.5
5.5
Expected return on plan assets (0.5 ) (0.6 ) (1.5 ) (1.6 )
Amortization of net loss 0.5
0.6
1.3
1.9
Amortization of unrecognized prior service cost (A) (1.0 ) (1.5 ) (1.0 ) (4.6 )
Settlement 0.4
—
0.4
—
Net periodic benefit cost $ 0.7
$ 0.4
$ 4.0
$ 1.6

Unamortized prior service cost is amortized on a straight-line basis over the average remaining service period to the first eligibility age of participants who are expected to receive a benefit and are active at the date of the plan amendment.

As required by ASU 2017-07, OG&E only capitalizes the service cost component of net benefit cost, beginning in the first quarter of 2018. Prior year capitalized amounts were not adjusted, as this change was implemented on a prospective basis.

~~Pension Plan Funding~~

~~In August 2017, OGE Energy contributed $20.0 million to its Pension Plan, of which $4.0 million was attributed to OG&E. No additional contributions are expected in 2017.~~

~~Postretirement Benefit Plans~~

OGE Energy provides certain medical and life insurance benefits for eligible retired members. Regular, full-time, active employees hired prior to February 1, 2000 whose age and years of credited service total or exceed 80 or have attained at least age 55 with 10 or more years of service at the time of retirement are entitled to postretirement medical benefits while employees hired on or after February 1, 2000 are not entitled to postretirement medical benefits. Eligible retirees must contribute such amount as OGE Energy specifies from time to time toward the cost of coverage for postretirement benefits. The benefits are subject to deductibles, co-payment provisions and other limitations. OG&E charges postretirement benefit costs to expense and includes an annual amount as a component of the cost-of-service in future ratemaking proceedings.

In August 2017, OGE Energy adopted an amendment to the retiree medical plan. Effective January 1, 2018, OGE Energy will reduce the amount of supplemental Medicare coverage for Medicare-eligible retirees, providing a fixed stipend based on current market analysis in August 2017. OGE Energy will continue to allow those Medicare-eligible retirees to acquire coverage from a company-provided third-party administrator. The effect of these plan amendments is reflected in OGE Energy’s

~~September 30, 2017 Condensed Consolidated Balance Sheet as a reduction to the postretirement benefit obligation of $42.9 million, of which $32.1 million was attributed to OG&E.~~

In August 2017, OGE Energy settled the retiree life plan in its entirety and paid $26.4 million to participants in August 2017. No gain or loss was recognized upon settlement, and the effect of the settlement is reflected in OGE Energy’s September 30, 2017 Condensed Consolidated Balance Sheet as a reduction in the benefit obligation of $27.9 million and related other comprehensive income and regulatory asset of $2.1 million, of which $19.9 million was attributed to OG&E.



	Three Months Ended
	March 31,
(In millions)	2018		2017
Capitalized portion of net periodic pension benefit cost	$	0.8	$	0.8
Capitalized portion of net periodic postretirement benefit cost	$	—	$	0.6

Except as set forth below, in Note 1112 and under "Environmental Laws and Regulations" in Item 2 of Part I and in Item 1 of Part II of this Form 10-Q, the circumstances set forth in Notes 12 and 13 to OG&E's Financial Statements included in OG&E's ~~2016~~2017 Form 10-K appropriately represent, in all material respects, the current status of OG&E's material commitments and contingent liabilities.

~~Public Utility Regulatory Policy Act of 1978~~

As previously disclosed in OG&E’s 2016 Form 10-K, OG&E has a QF contract with AES-Shady Point, Inc. ("AES") whereby OG&E purchases 100 percent of the electricity generated from AES’s 320 MW facility. The QF contract expires on January 15, 2023; however, OG&E had the option beginning in July 2017 to provide notice to AES to terminate the contract in January 2018.

~~On July 17, 2017, OG&E and AES amended the agreement to allow OG&E the ability, through July 17, 2018, to provide AES a termination notice that would terminate the agreement on January 15, 2019.~~

Environmental Laws and Regulations

The activities of OG&E are subject to numerous stringent and complex ~~Federal,~~federal, state and local laws and regulations governing environmental protection. These laws and regulations can change, restrict or otherwise impact OG&E's business activities in many ways, including the handling or disposal of waste material, future construction activities to avoid or mitigate harm to threatened or endangered species and requiring the installation and operation of emissions pollution control equipment. Failure to comply with these laws and regulations could result in the assessment of administrative, civil and criminal penalties, the imposition of remedial requirements and the issuance of orders enjoining future operations. Management believes that all of its operations are in substantial compliance with current ~~Federal,~~federal, state and local environmental standards.

Environmental regulation can increase the cost of planning, design, initial installation and operation of OG&E's facilities. ~~Compliance with these environmental standards is expected to increase the cost of conducting business.~~ OG&E is managing several potentially material uncertainties about the scope and timing for the acquisition, installation and operation of additional pollution control equipment and compliance costs for a variety of the EPA rules that are being challenged in court. OG&E is unable to predict the financial impact of these matters with certainty at this time. Management continues to evaluate its compliance with existing and proposed environmental legislation and regulations and implement appropriate environmental programs in a competitive market.

On September 10, 2014, OG&E executed a contract for the design, engineering and fabrication of two circulating Dry Scrubber systems to be installed at Sooner Units 1 and 2. OG&E entered into an agreement on February 9, 2015 to install the Dry Scrubber systems. The Dry Scrubbers are ~~scheduled~~expected to be completed ~~by 2019.~~mid to late 2018. More detail regarding the ECP can be found under "Pending Regulatory Matters" in Note ~~11.~~

In the normal course of business, OG&E is confronted with issues or events that may result in a contingent liability. These generally relate to lawsuits or claims made by third parties, including governmental agencies. When appropriate, management consults with legal counsel and other experts to assess the claim. If, in management's opinion, OG&E has incurred a probable loss as set forth by GAAP, an estimate is made of the loss, and the appropriate accounting entries are reflected in OG&E's Condensed Financial Statements. At the present time, based on currently available information, OG&E believes that any reasonably possible losses in excess of accrued amounts arising out of pending or threatened lawsuits or claims would not be quantitatively material to its financial statements and would not have a material adverse effect on OG&E's financial position, results of operations or cash flows.

Except as set forth below, the circumstances set forth in Note 13 to OG&E's Financial Statements included in OG&E's ~~2016~~2017 Form 10-K appropriately represent, in all material respects, the current status of OG&E's regulatory matters.

~~Completed Regulatory Matters~~

~~On August 25, 2016,~~ References to "March 2017 OCC rate order" indicate the general rate review order OG&E filed a general rate case with the APSC. The rate filing requested a $16.5 million rate increase based on a 10.25 percent return on equity. The rate increase was based on a June 30, 2016 test year and included a recovery of over $3.0 billion of electric infrastructure additions since the last Arkansas general rate case in 2011. The increase also reflects increases in operation and maintenance expenses, including vegetation management and increased recovery of depreciation and dismantlement costs.

In May 2017, the APSC approved a settlement between OG&E and the staff of the APSC and other intervenors. The settlement provides for a $7.1 million annual rate increase and a 9.5 percent return on equity on a 50.0 percent equity capital structure.

The settlement also provides that OG&E will be regulated under a formula rate rider, which should result in a more efficient process as the return on equity, depreciation rates and capital structure should not change from what is approved by the APSC in the current rate case proceeding. The formula rate rider provides for an adjustment to rates if the earned rate of return falls outside of a plus or minus 50 basis point dead-band around the allowed return on equity. Adjustments are limited to plus or minus four percent of revenue for each rate class for the 12 months preceding the projected year. The initial term for the formula rate rider is not to exceed five years, unless additional approval is obtainedreceived from the ~~APSC. OG&E expects to make its first filing under the Arkansas Formula~~OCC on March 20, 2017, as detailed further in "Note 13. Rate ~~Rider~~Matters and Regulation" in ~~October 2018.~~

~~Fuel Adjustment Clause Review for Calendar Year 2015~~

On September 8, 2016, the OCC staff filed an application to review OG&E’s fuel adjustment clause for calendar year 2015, including the prudence of OG&E’s electric generation, purchased power and fuel procurement costs. On October 12, 2017, the OCC issued an order, finding that, for the calendar year 2015, OG&E's ~~electric generation, purchased power and fuel procurement processes and costs were prudent.~~2017 Form 10-K.

Pending Regulatory Matters

Set forth below is a list of various proceedings pending before state or ~~Federal~~federal regulatory agencies. Unless stated otherwise, OG&E cannot predict when the regulatory agency will act or what action the regulatory agency will take. OG&E's financial results are dependent in part on timely and adequate decisions by the regulatory agencies that set OG&E's rates.

Environmental Compliance Plan

On August 6, 2014, OG&E filed an application under Oklahoma Statute Title 17, Section 286 (B) with the OCC for approval of its plan to comply with the EPA’s MATS and Regional Haze Rule FIP while serving the best long-term interests of customers in light of future environmental uncertainties. The application sought approval of the ECP and for a recovery mechanism for the associated costs. The ECP includes installing Dry Scrubbers at Sooner Units 1 and 2 and the conversion of Muskogee Units 4 and 5 to natural gas. The application also asked the OCC to predetermine the prudence of its Mustang Modernization Plan ~~which calls for replacing OG&E's soon-to-be retired Mustang steam turbines with 462 MWs of new, efficient combustion turbines at the Mustang site~~ and approval for a recovery mechanism for the associated costs.

On December 2, 2015, OG&E received an order from the OCC denying its plan to comply with the environmental mandates of the Federal Clean Air Act, Regional Haze Rule and MATS. The OCC also denied OG&E's request for pre-approval of its Mustang Modernization Plan, revised depreciation rates for both the retirement of the Mustang units and the replacement combustion turbines and pre-approval of early retirement and replacement of generating units at its Mustang site, including cost recovery through a rider.

On December 11, 2015, OG&E filed a motion requesting modification of the OCC order for the purposes of approving only the ECP under Oklahoma Statute Title 17, Section 286 (B), and on December 23, 2015, the OCC rejected OG&E's motion.

On February 12, 2016, OG&E filed an application under Oklahoma Statute Title 17, Section 151, et seq. requesting the OCC to issue an order approving its decision to install Dry Scrubbers at the Sooner facility. OG&E's application did not seek approval of the costs of the Dry Scrubber project. Instead, the reasonableness of the costs would be considered after the project is completed, and OG&E seeks recovery in ~~its rates.~~a general rate review. On April 28, 2016, the OCC approved the Dry Scrubber project.

Two parties appealed the OCC's decision to the Oklahoma Supreme Court. ~~OG&E is unable to predict what action~~On April 24, 2018, the Oklahoma Supreme Court ~~may take or~~ruled that the ~~timing~~OCC did not have the authority to grant pre-approval of ~~any such action.~~OG&E’s Dry Scrubber project outside the authority of Oklahoma Statute Title 17, Section 286 (B). OG&E intends to seek recovery of the Dry Scrubber total cost in a general rate review after the project is completed.

OG&E anticipates the total cost of Dry Scrubbers will be $542.4 million, including allowance for funds used during construction and capitalized ad valorem ~~taxes.~~taxes and expects the project to be completed in mid to late 2018. As of ~~September 30, 2017,~~March 31, 2018, OG&E ~~had~~has invested ~~$352.7~~$416.0 million ~~of construction work~~ in ~~progress on~~ the Dry Scrubbers. OG&E anticipates the total cost for the Mustang Modernization Plan will be $390.0 million, including allowance for funds used during construction and capitalized ad valorem ~~taxes and expects the project to be completed in early 2018.~~taxes. As of ~~September 30, 2017,~~March 31, 2018, OG&E ~~had~~has invested ~~$306.0~~$373.2 million in the Mustang Modernization ~~Plan.~~Plan, and all seven combustion turbines have been placed in service. Remaining work on the project is expected to conclude in the second quarter of 2018.

Integrated Resource Plans

In October 2015, OG&E finalized the 2015 IRP and submitted it to the OCC. The 2015 IRP updated certain assumptions contained in the IRP submitted in 2014 but did not make any material changes to the ECP and other parts of the plan. Currently, OG&E is scheduled to update its IRP in Oklahoma by October 1, 2018 and in Arkansas by October 31, 2018.

~~Oklahoma Rate Case Filing~~Demand Program Rider - Energy Efficiency Lost Net Revenues

~~On December 18, 2015, OG&E filed a general rate case with~~During the ~~OCC requesting a rate increase~~May 2017 implementation of $92.5 million and a 10.25 percent return on equity based on a common equity percentage of 53 percent. The rate case was based on a June 30, 2015 test year and included recovery of $1.6 billion of electric infrastructure additions since its last general rate case in Oklahoma.

~~On July 1, 2016, OG&E implemented an annual interim rate increase of $69.5 million, subject to refund for amounts in excess of the rates approved by the OCC.~~

In December 2016, the ALJ issued a report and recommendations in the case. The ALJ's recommendations included, among other things, the use of OG&E's actual capital structure of 53.0 percent equity and 47.0 percent long-term debt and a return on equity of 9.87 percent resulting in an annual increase in OG&E's revenues of $40.7 million.

On March 20, 2017, the OCC held hearings and issued an order. The order results in an annual net increase of approximately $8.8 million in OG&E's rates to its Oklahoma retail customers. Although the order adopted certain recommendations set forth in the ALJ report, it differs in certain key respects.

The primary adjustments to the ALJ report consist of: (i) Oklahoma retail authorized rate of return on equity of 9.50 percent, (ii) depreciation expense is reduced by approximately $28.6 million from the ALJ report or $36.4 million from current rates on an annual basis, (iii) recovery of 50.0 percent of short-term incentive compensation and no recovery of long-term incentive compensation, (iv) recovery of OG&E's requested vegetation management expenses and (v) recovery of production tax credits expiring in 2017 and air quality control systems consumable costs through the fuel adjustment clause. The order maintained OG&E's existing capital structure of 53.0 percent equity and 47.0 percent long-term debt.

As a result of the March 2017 order, OG&E recorded, in the first quarter of 2017, adjustments to depreciation expense, amortization of regulatory assets and liabilities and impacts to the fuel adjustment clause effective July 1, 2016. On May 1, 2017, OG&E implemented new rates, ~~and began refunding excess amounts that it had collected in interim rates.~~

~~As of September 30, 2017,~~ OG&E ~~had refunded $45.6 million of the $47.5 million expected refund from the interim rate increase. Additionally, OG&E has~~ reserved $5.6 million, pending resolution of a dispute with ~~PUD~~the OCC's Public Utility Division staff, regarding recovery of certain lost revenues associated with energy efficiency incurred prior to the March ~~20,~~ 2017 OCC rate order. These lost revenues are included within the total Demand Program Rider regulatory asset balance of ~~$38.3~~$23.9 million as disclosed in Note 1. OG&E is unable to predict what actions the OCC may take regarding the unrecovered lost revenue or the timing of any actions. The remaining reserve for the interim rate refund and the lost revenues reserve are included in Other Current Liabilities on OG&E's Condensed Balance Sheets.

On August 3, 2017, the OCC staff filed an application to review OG&E's fuel adjustment clause for calendar year 2016, including the prudence of OG&E's electric generation, purchased power and fuel procurement costs. ~~A hearing date~~On February 7, 2018, an intervenor filed a recommendation to disallow the Oklahoma jurisdictional portion of $3.3 million related to wind sales in the SPP. On April 4, 2018, a Joint Stipulation and Settlement Agreement was filed with the OCC. As part of the agreement, the Stipulating Parties settled all claims regarding the issue of wind energy Settlement Costs for the period September 2016 through May 2017, and OG&E agreed to refund $2.4 million to customers related to wind sales in the SPP. On April 25, 2018, the OCC approved the Joint Stipulation and Settlement Agreement. OG&E has recorded a reserve for this settlement amount as of March ~~29, 2018 has been scheduled.~~31, 2018.

On August 15, 2017, OG&E filed for a determination with the APSC that the Mustang facility is in the public's interest. The filing does not seek recovery for any costs associated with the Mustang Modernization Plan, as request for recovery of costs will take place with the first formula rate filing expected to be made in October 2018.

On January 16, 2018, OG&E ~~intends to file~~filed a general rate ~~case~~review in Oklahoma, requesting a rate increase of $1.9 million per year, assuming a 9.9 percent return on equity. The filing seeks recovery of the seven combustion turbines that are part of the Mustang Modernization Plan, requests an increase in depreciation rates to levels similar with rates in existence prior to the March 2017 OCC rate order and credits customers for the impacts of the 2017 Tax Act, enacted on December 22, 2017.

On December 22, 2017, the Attorney General of Oklahoma requested that the OCC ~~during~~reduce the ~~fourth quarter~~rates and charges for electric service and provide for any refund due to the customers of ~~2017.~~ OG&E resulting from the 2017 Tax Act. In response, on January 4, 2018, the OCC ordered OG&E to record a reserve, beginning on January 4, 2018, to reflect the reduced federal corporate tax rate of 21 percent and the amortization of excess accumulated deferred income tax and any other tax implications of the 2017 Tax Act on an interim basis, subject to refund until utility rates are adjusted to reflect the federal tax savings and a final order is issued in OG&E's pending rate review filed on January 16, 2018. Further, the OCC ordered the amounts of any refunds of such reserves owed to customers should accrue interest at a rate equivalent to OG&E's cost of capital as previously recognized in the March 2017 OCC rate order. OG&E is reserving the excess income taxes collected in current rates, plus interest, from January 2018 to the date of an order received from the OCC.

The hearing on the merits for this rate ~~case~~review is scheduled to begin on June 15, 2018.

On January 12, 2018, as a result of the 2017 Tax Act, the APSC ordered OG&E to prepare and file an analysis, within 30 days of this order, of the ratemaking effects of the 2017 Tax Act on OG&E's revenue requirement and begin, effective January 1, 2018, to book regulatory liabilities to record the current and deferred impacts of the 2017 Tax Act. The APSC has established a procedural schedule to solicit comments or testimony regarding the extent of the impacts of the 2017 Tax Act and how any resulting benefits, including carrying charges, should be returned to customers. OG&E is reserving the excess income taxes collected in current rates, plus interest, from January 2018 to the date of an order received from the APSC. An evidentiary hearing is scheduled on May 23, 2018.

FERC - Section 206 Filing

In January 2018, the Oklahoma Municipal Power Authority filed a complaint at the FERC stating that the base return on common equity used by OG&E in calculating formula transmission rates under the SPP Open Access Transmission Tariff is unjust and unreasonable and should be reduced from 10.60 percent to 7.85 percent, effective upon the date of the complaint. OG&E is analyzing the potential impact of the complaint but estimates that if the FERC ultimately orders a reduction, each 25 basis point reduction in the requested return on equity would reduce OG&E's SPP Open Access Transmission Tariff transmission revenues by approximately $1.5 million annually. In addition to the request to reduce the return on equity, the Oklahoma Municipal Power Authority's complaint also requests that modifications be made to OG&E's transmission formula rates to reflect the impacts of the 2017 Tax Act. OG&E contested the reduction of its base return on equity. OG&E is unable to predict what action the FERC will ~~be based~~take in response to the Oklahoma Municipal Power Authority's complaint or the timing of such action. However, if the FERC orders revenue reductions as a result of the complaint, including refunds from the date of the complaint filing, it could have a material adverse effect on ~~a September 30, 2017 test year.~~OG&E's financial position, results of operations and cash flows. OG&E is reserving the excess income taxes collected in current rates, plus interest, from January 2018 to the date of an order received from the FERC.

Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.

OG&E Mission and Focus

OGE Energy's mission, through OG&E and its equity interest in Enable, is to fulfill its critical role in the nation's electric utility and natural gas midstream pipeline infrastructure and meet individual customer's needs for energy and related services, focusing on safety, efficiency, reliability, customer service and risk management.

Summary of Operating Results

Three Months Ended ~~September 30, 2017~~March 31, 2018 as compared to Three Months Ended ~~September 30, 2016~~March 31, 2017

OG&E reported net income of $~~161.5~~31.3 million and $~~159.9~~16.2 million during the three months ended ~~September 30, 2017~~March 31, 2018 and ~~2016~~2017, respectively, an increase of $~~1.6~~15.1 million, or ~~1.0~~93.2 percent, primarily due to higher ~~net other income~~gross margin and lower operation and maintenance expense, partially offset by higher depreciation and amortization expense, ~~as a result of the OCC's March 2017 order mandating~~primarily due to a reduction in depreciation ~~rates as discussed~~expense recorded in ~~Note 11, partially offset by lower gross margin primarily due~~March 2017 for the period from July 1, 2016 to ~~milder weather, higher operation and maintenance expense~~December 31, 2016 resulting from the March 2017 OCC rate order, and higher ~~income tax~~interest expense.

~~Nine Months Ended September 30, 2017~~ ~~as compared to~~ ~~Nine Months Ended September 30, 2016~~

OG&E reported net income of $263.9 million and $238.3 million during the nine months ended September 30, 2017 and 2016, respectively, an increase of $25.6 million, or 10.7 percent, primarily due to higher net other income and lower depreciation and amortization expense as a result of the OCC's March 2017 order mandating a reduction in depreciation rates, partially offset by lower gross margin primarily due to milder weather, higher income tax expense and higher operation and maintenance expense.

Recent Developments and Regulatory Matters

As discussed in Note ~~11, on March 20, 2017, the OCC issued an order~~12 within "Item 1. Financial Statements," in January 2018, OG~~&E's~~&E filed a general rate ~~case. The order results~~review in Oklahoma, seeking recovery of the seven combustion turbines that are part of the Mustang Modernization Plan, requesting an ~~annual net~~ increase ~~of approximately $8.8 million~~ in ~~OG&E's~~depreciation rates to ~~its Oklahoma retail customers. Although~~levels similar with rates in existence prior to the March 2017 OCC rate order ~~adopted certain~~and crediting customers for the impacts of the ~~recommendations set forth in~~2017 Tax Act. The hearing on the ~~ALJ report, it differs in certain key respects.~~merits for this rate review is scheduled to begin on June 15, 2018.

The primary adjustments to the ALJ report consist of: (i) Oklahoma retail authorized rate of return on equity of 9.50 percent, (ii) depreciation expense is reduced by approximately $28.6 million from the ALJ report or $36.4 million from current rates on an annual basis, (iii) recovery of only 50.0 percent of short-term incentive compensation and no recovery of long-term incentive compensation, (iv) recovery of OG&E's requested vegetation management expenses and (v) recovery of production tax credits expiring in 2017 and air quality control systems consumable costs through the fuel adjustment clause. The order maintained OG&E's existing capital structure of 53.0 percent equity and 47.0 percent long-term debt.

As a result of the ~~March~~ 2017 ~~order,~~Tax Act: (i) the OCC ordered OG&E ~~recorded~~to record a reserve, which should include accrued interest, to reflect the reduced federal corporate tax rate, among other tax implications, on an interim basis, subject to refund until utility rates are adjusted to reflect the federal tax savings and a final order is issued in OG&E's pending rate review filed in January 2018; (ii) the ~~first quarter of 2017 adjustments to depreciation expense, amortization of regulatory assets and liabilities and impacts to the fuel adjustment clause effective July 1, 2016. On May 1, 2017,~~APSC ordered OG&E ~~implemented new rates~~to book regulatory liabilities to record the current and ~~began refunding excess amounts that it had collected in interim rates.~~

~~As of September 30, 2017, OG&E had refunded $45.6 million~~deferred impacts of the ~~$47.5 million expected refund from~~2017 Tax Act and will subsequently order how any resulting benefits, including carrying charges, should be returned to customers; and (iii) through a Section 206 filing with the ~~interim rate increase. Additionally,~~FERC, modifications were requested to be made to OG~~&E has reserved $5.6 million, pending resolution~~&E's transmission formula rates to reflect the impacts of ~~a dispute with PUD staff, regarding recovery of certain lost revenues associated with energy efficiency incurred prior to~~ the ~~March 20,~~ 2017 ~~rate order. These lost revenues are included within the total Demand Program Rider regulatory asset balance of $38.3 million as disclosed in Note 1.~~Tax Act. OG&E is ~~unable~~reserving the excess income taxes collected in current rates, plus interest, from January 2018 to ~~predict what actions~~the date of an order received from the OCC, ~~may take regarding the unrecovered lost revenue or the timing of any actions. The remaining~~

~~reserve for the interim rate refund~~APSC and ~~the lost revenues reserve are included in Other Current Liabilities on OG&E's Condensed Balance Sheets.~~

~~Also as discussed~~FERC. Further discussion can be found in Note 11, in May 2017, the APSC approved a settlement between OG&E and the staff of the APSC and other intervenors. The settlement provides for a $7.1 million annual rate increase and a 9.5 percent return on equity on a 50.0 percent equity capital structure. The settlement also provides that OG&E will be regulated under a formula rate rider, which should result in a more efficient process as the return on equity, depreciation rates and capital structure should not change from what is approved by the APSC in the current rate case proceeding. The formula rate rider provides for an adjustment to rates if the earned rate of return falls outside of a plus or minus 50 basis point dead-band around the allowed return on equity. Adjustments are limited to plus or minus four percent of revenue for each rate class for the 12 months preceding the projected year. The initial term for the formula rate rider is not to exceed five years, unless additional approval is obtained from the APSC. OG&E expects to make its first filing under the Arkansas Formula Rate Rider in October 2018.within "Item 1. Financial Statements."

OG&E projects earnings guidance to be between $300 million to $304 million of net income in 2017, changed from the previously issued earnings guidance at the low end of the earnings range of $316 million to $340 million of net income in 2017 and based on the following assumptions:Key assumptions for 2018 include:

~~normal weather patterns are experienced~~The earnings outlook for OG&E is unchanged, and OG&E is projected to earn approximately $286 million to $306 million or $1.43 to $1.53 per average diluted share in 2018. Due to changes in certain accounting standards and the ~~remainder~~implementation of the ~~year;~~2017 Tax Act, some of the assumptions listed in OG&E's 2017 Form 10-K have changed. The changes do not impact earnings projections but are reclassifications on the income statement. The following are the key assumptions which have changed and are based on current projections:

gross margin on revenues of approximately ~~$1.359~~$1.376 billion to ~~$1.362~~$1.386 billion ~~on a weather adjusted basis;~~which includes the reclassification of gains/losses previously shown in other income associated with guaranteed flat bill program and lower revenues associated with the refinement of the average rate assumption method calculation resulting from the 2017 Tax Act;

operating expenses of approximately ~~$851~~$932 million to ~~$854~~$942 million with operation and maintenance expenses comprising approximately 5753 percent of the ~~total;~~

total. The change is due to reclassifications from the adoption of the new pension and postretirement accounting standard discussed in Note 2 in "Item 1. Financial Statements";

~~interest expense of approximately $140 million which assumes a $17 million allowance for borrowed funds used during construction reduction to interest expense; and~~

net other income of approximately ~~$69~~$31 million ~~including approximately $36 million~~with the change due to reclassifications in pension and postretirement accounting and the reclassification of ~~allowance for equity funds used during construction.~~gains/losses previously shown in other income associated with guaranteed flat bill program; and

an effective tax rate of 7.9 percent due to refinement of the average rate assumption method calculation resulting from the 2017 Tax Act. The reduction in revenue and taxes offset so there is no impact to earnings.

OG&E has significant seasonality in its earnings. OG&E typically shows minimal earnings in the first and fourth quarters with a majority of earnings in the third quarter due to the seasonal nature of air conditioning demand.

Non-GAAP Financial Measures

Gross margin is defined by OG&E as operating revenues less cost of sales. Cost of sales, as reflected on the income statement, includes fuel, purchased power and certain transmission expenses. Gross margin is a non-GAAP financial measure because it excludes depreciation and amortization and other operation and maintenance expenses. Expenses for fuel and purchased power are recovered through fuel adjustment clauses, and as a result, changes in these expenses are offset in operating revenues with no impact on net income. OG&E believes gross margin provides a more meaningful basis for evaluating its operations across periods than operating revenues because gross margin excludes the revenue effect of fluctuations in these expenses. Gross margin is used internally to measure performance against budget and in reports for management and the Board of Directors. OG&E's definition of gross margin may be different from similar terms used by other companies.

~~Reconciliation~~ Further, gross margin is not intended to replace operating revenues as determined in accordance with GAAP as an indicator of ~~Gross Margin~~operating performance. For a reconciliation of gross margin to ~~Revenue~~revenue, which is the most directly comparable financial measure calculated and presented in accordance with GAAP, for the three months ended March 31, 2018 and 2017, see "Results of Operations" below.

Detailed below is a reconciliation of gross margin to revenue included in the ~~2017~~2018 Outlook.

Results of Operations

The following discussion and analysis presents factors that affected OG&E's results of operations for the three ~~and nine~~ months ended ~~September 30, 2017~~March 31, 2018 as compared to the same ~~periods~~period in ~~2016~~2017 and OG&E's financial position at ~~September 30, 2017~~March 31, 2018. Due to seasonal fluctuations and other factors, OG&E's operating results for the three ~~and nine~~ months ended ~~September 30, 2017~~March 31, 2018 are not necessarily indicative of the results that may be expected for the year ending December 31, ~~2017~~2018 or for any future period. The following information should be read in conjunction with the Condensed Financial Statements and Notes thereto. Known trends and contingencies of a material nature are discussed to the extent considered relevant.


	Three Months Ended					Nine Months Ended					Three Months Ended
	September 30,										March 31,
(Dollars in millions)	2017		2016			2017		2016			2018			2017
Operating revenues	$	716.8	$	743.9		$	1,759.2	$	1,728.4		$	492.7		$	456.0
Cost of sales	255.7		269.8			696.5		645.4			210.5			208.7
Other operation and maintenance	120.2		115.2			362.8		356.3			119.7			124.7
Depreciation and amortization	76.2		80.8			204.6		235.9			78.8			54.7
Taxes other than income	21.7		20.9			64.2		63.6			22.7			22.3
Operating income	243.0		257.2			431.1		427.2			61.0			45.6
Allowance for equity funds used during construction	11.8		3.9			27.2		9.2			7.0			6.9
Other net periodic pension and postretirement benefit (cost)											1.3			(1.4		)
Other income	13.4		2.9			27.5		11.3			3.1			6.4
Other expense	0.5		0.8			1.5		2.2			0.8			0.4
Interest expense	34.5		34.3			103.7		104.8			37.3			33.6
Income tax expense	71.7		69.0			116.7		102.4			3.0			7.3
Net income	$	161.5	$	159.9		$	263.9	$	238.3		$	31.3		$	16.2
Operating revenues by classification
Operating revenues by classification:
Residential	$	295.1	$	351.9		$	700.0	$	750.0		$	202.1		$	192.3
Commercial	174.2		188.4			450.6		434.2			122.7			124.3
Industrial	58.0		60.4			156.3		147.4			43.1			44.3
Oilfield	43.4		47.3			124.6		118.4			34.6			38.1
Public authorities and street light	60.6		66.8			159.4		154.4			43.5			44.5
Sales for resale	—		—			0.1		0.2			0.1			—
System sales revenues	631.3		714.8			1,591.0		1,604.6			446.1			443.5
Provision for rate refund	29.2		(21.0		)	25.0		(21.0		)	(3.2		)	(20.8		)
Integrated market	14.0		13.2			16.8		33.0			8.6			(3.5		)
Transmission											35.8			32.0
Other	42.3		36.9			126.4		111.8			5.4			4.8
Total operating revenues	$	716.8	$	743.9		$	1,759.2	$	1,728.4		$	492.7		$	456.0
Reconciliation of gross margin to revenue
Reconciliation of gross margin to revenue:
Operating revenues	$	716.8	$	743.9		$	1,759.2	$	1,728.4		$	492.7		$	456.0
Cost of sales	255.7		269.8			696.5		645.4			210.5			208.7
Gross margin	$	461.1	$	474.1		$	1,062.7	$	1,083.0		$	282.2		$	247.3
MWh sales by classification (In millions)
Residential	2.9		3.2			6.9		7.3			2.4			2.0
Commercial	2.1		2.1			5.7		5.7			1.7			1.6
Industrial	0.9		1.0			2.7		2.8			0.9			0.8
Oilfield	0.8		0.8			2.4		2.4			0.8			0.8
Public authorities and street light	0.8		0.9			2.3		2.4			0.7			0.7
System sales	7.5		8.0			20.0		20.6			6.5			5.9
Integrated market	0.6		0.7			1.4		1.5			0.3			0.3
Total sales	8.1		8.7			21.4		22.1			6.8			6.2
Number of customers	840,519		832,234			840,519		832,234			843,322			836,099
Weighted-average cost of energy per kilowatt-hour (In cents)
Natural gas	2.747		2.688			2.795		2.366			2.794			2.817
Coal	2.049		2.222			2.100		2.251			2.007			2.110
Total fuel	2.253		2.337			2.231		2.175			2.072			2.135
Total fuel and purchased power	2.966		2.984			3.093		2.796			2.941			3.132
Degree days (A)
Heating - Actual	4		3			1,574		1,714			1,880			1,381
Heating - Normal	19		19			2,021		2,020			1,798			1,799
Cooling - Actual	1,223		1,450			1,847		2,082			10			57
Cooling - Normal	1,380		1,380			2,018		2,018			13			13

Degree days are calculated as follows: The high and low degrees of a particular day are added together and then averaged. If the calculated average is above 65 degrees, then the difference between the calculated average and 65 is expressed as cooling degree days, with each degree of difference equaling one cooling degree day. If the calculated average is below 65 degrees, then the difference between the calculated average and 65 is expressed as heating degree days, with each degree of difference equaling one heating degree day. The daily calculations are then totaled for the particular reporting period.

degree days, with each degree of difference equaling one cooling degree day. If the calculated average is below 65 degrees, then the difference between the calculated average and 65 is expressed as heating degree days, with each degree of difference equaling one heating degree day. The daily calculations are then totaled for the particular reporting period.

OG&E's net income increased ~~$1.6 million and $25.6~~$15.1 million during the three ~~and nine~~ months ended ~~September 30, 2017, respectively,~~March 31, 2018, as compared to the same ~~periods~~period in ~~2016.~~2017. The three month increase of ~~$1.6~~$15.1 million, or ~~1.0~~93.2 percent, was primarily due to higher other income, higher allowance for equity funds used during construction, lower depreciation and amortization expense as a result of the OCC's March 2017 order mandating a reduction in depreciation rates as discussed in Note 11, and higher allowance for borrowed funds used during construction, partially offset by lower gross margin ~~higher~~and lower operation and maintenance expense, partially offset by higher ~~interest on long-term debt and higher income tax expense. The nine month increase of$25.6 million, or 10.7 percent, was primarily due to lower~~ depreciation and amortization expense as a result of the OCC's March 2017 order mandating a reduction in depreciation rates, higher allowance for equity funds used during construction, higher other income and higher allowance for borrowed funds used during construction, partially offset by lower gross margin, higher income tax expense, higher operation and maintenance expense and higher interest on long-term debt.

Gross margin was $461.1 million and $1,062.7 million during the three and nine months ended September 30, 2017, respectively, as compared to $474.1 million and $1,083.0 million during the same periods in 2016, respectively. Gross margin decreased $13.0increased $34.9 million, or ~~2.7 percent, and $20.3 million, or 1.9~~14.1 percent, during the three ~~and nine~~ months ended ~~September 30, 2017, respectively,~~March 31, 2018, as compared to the same ~~periods~~period in ~~2016.~~2017. The below factors contributed to the change in gross ~~margin:~~margin.

Increased primarily due to higher demand prices.

~~Decreased primarily due~~Further discussion of OG&E's reserve for tax refund in response to ~~riders moving to base rates~~OCC, APSC and FERC proceedings can be found in ~~the March 2017 OCC order.~~Note 12 in "Item 1. Financial Statements."

Cost of sales for OG&E consists of fuel used in electric generation, purchased power and transmission related charges. The actual cost of fuel used in electric generation and certain purchased power costs are passed through to OG&E's customers through fuel adjustment clauses. The fuel adjustment clauses are subject to periodic review by the OCC and the APSC. OG&E's cost of sales ~~decreased $14.1~~increased $1.8 million, or ~~5.2 percent, and increased $51.1 million, or 7.9~~0.9 percent, during the three ~~and nine~~ months ended ~~September 30, 2017, respectively,~~March 31, 2018, as compared to the same ~~periods~~period in ~~2016.~~2017. The changes are detailed in the table below.

Decrease in fuel expense was primarily due to decreased utilization of company-owned generation.

Increase of ~~$9.9~~$13.7 million in the cost of purchases from the SPP for the three months ended ~~September 30, 2017~~March 31, 2018 was due to a ~~51.1~~63.1 percent increase in MWhs purchased offset by a decrease of ~~17.3~~24.0 percent in cost per MWh purchased. The decrease in cost per MWh purchased was due to a decrease in fuel prices. Increase of $50.5 million in the cost of purchases from the SPP for the nine months ended September 30, 2017 was due to an increase of 5.9 percent in MWh purchased and an increase of 29.8 percent in cost per MWhs purchased. The increase in cost per MWh purchased was due to an increase in fuel prices and higher grid congestion costs during 2017.

Increase in transmission-related charges was primarily due to higher SPP charges for the base plan projects of other utilities.

Other operation and maintenance expense ~~increased~~decreased $5.0 million, or ~~4.3 percent, and $6.5 million, or 1.8~~4.0 percent, during the three ~~and nine~~ months ended ~~September 30, 2017, respectively,~~March 31, 2018, as compared to the same ~~periods~~period in ~~2016.~~2017. The below factors contributed to the changes in other operation and maintenance ~~expense:~~expense.

Depreciation and amortization expense ~~decreased $4.6~~increased $24.1 million, or ~~5.7 percent, and $31.3 million, or 13.3~~44.1 percent, for the three ~~and nine~~ months ended ~~September 30, 2017, respectively,~~March 31, 2018, as compared to the same ~~periods~~period in ~~2016,~~2017, primarily due to ~~lower depreciation expense related to the~~a reduction in depreciation ~~rates approved~~expense of approximately $20 million recorded in ~~the OCC's~~ March 2017 for the period from July 1, 2016 to December 31, 2016 resulting from the March 2017 OCC rate order, as ~~discussed~~detailed further in ~~Note 11, partially offset by~~"Note 13. Rate Matters and Regulation" in OG&E's 2017 Form 10-K, and additional assets being placed into service.

~~Allowance for equity funds used during construction~~Interest on long-term debt increased ~~$7.9~~$4.1 million, ~~and $18.0 million~~or 11.5 percent, during the three ~~and nine~~ months ended ~~September 30, 2017, respectively,~~March 31, 2018, as compared to the same ~~periods~~period in ~~2016,~~2017, primarily due to ~~higher construction work~~interest paid on the issuance of long-term debt by OG&E in ~~progress balances resulting from increased spending for environmental projects.~~

~~Other income increased $10.5 million~~March 2017 and ~~$16.2 million during the three and nine months ended September 30,~~August 2017, ~~respectively, as compared to the same periods~~partially offset by long-term debt paid off in ~~2016, primarily due to an increase in the tax gross-up related to higher allowance for funds used during construction and an increase in gains on guaranteed flat bill margins.~~

Allowance for borrowed funds used during construction increased $3.2 million and $7.9 million during the three and nine months ended September 30, 2017, respectively, as compared to the same periods in 2016, primarily due to higher construction work in progress balances resulting from increased spending for environmental projects.July 2017.

Income tax expense ~~increased $2.7~~decreased $4.3 million, or ~~3.9 percent, and $14.3 million, or 14.0~~58.9 percent, during the three ~~and nine~~ months ended ~~September 30, 2017, respectively,~~March 31, 2018, as compared to the same ~~periods~~period in ~~2016,~~2017, primarily due to increased state tax credit generation, an increase in the amortization of net unfunded deferred taxes and a reduction in the corporate federal tax rate, partially offset by higher pre-tax income.

Off-Balance Sheet Arrangements

There have been no significant changes in OG&E's off-balance sheet arrangements from those discussed in OG&E's ~~2016~~2017 Form 10-K.

Liquidity and Capital Resources

Working Capital

Working capital is defined as the difference in current assets and current liabilities. OG&E's working capital requirements are driven generally by changes in accounts receivable, accounts payable, commodity prices, credit extended to and the timing of collections from customers, the level and timing of spending for maintenance and expansion activity, inventory levels and fuel recoveries.

Accounts Receivable and Accrued Unbilled Revenues. The balance of Accounts Receivable and Accrued Unbilled Revenues was $~~331.3~~235.3 million and $~~232.7~~255.0 million at ~~September 30, 2017~~March 31, 2018 and December 31, ~~2016~~2017, respectively, ~~an increase~~a decrease of $~~98.6~~19.7 million, or ~~42.4~~7.7 percent, primarily due to ~~an increase~~a decrease in billings to OG&E's retail customers reflecting ~~higher~~lower usage due to ~~warmer~~milder weather in ~~September 2017~~March 2018 as compared to December ~~2016~~2017.

Advances to ~~Parent/Advances from~~ Parent. The balance in Advances to Parent was ~~$32.6~~$129.3 million and $112.5 million at ~~September 30, 2017 compared to an Advances from Parent balance of $49.9 million at~~March 31, 2018 and December 31, ~~2016. The change in Advances with Parent is~~2017, respectively, an increase of $16.8 million, or 14.9 percent, primarily due to an increase of cash from customers, ~~due to increased rates and long-term debt issued in 2017,~~ partially offset by daily operational expenses and capital expenditures.

Fuel Inventories. The balance in Fuel Inventories was $95.4 million and $84.3 million at March 31, 2018 and December 31, 2017, respectively, an increase of $11.1 million, or 13.2 percent, primarily due to increased coal inventory.

Other Current Assets. The balance of Other Current Assets was $40.3 million and $48.6 million at March 31, 2018 and December 31, 2017, respectively, a decrease of $8.3 million, or 17.1 percent, primarily due to increased revenue collections from customers associated with various rate riders.

Accounts Payable. The balance of Accounts Payable was $171.3 million and $216.8 million at March 31, 2018 and December 31, 2017, respectively, a decrease of $45.5 million, or 21.0 percent, primarily due to accruals, the timing of vendor payments and fuel and purchased power payables.

Accrued Compensation. The balance of Accrued Compensation was $18.4 million and $25.6 million at March 31, 2018 andDecember 31, 2017, respectively, a decrease of $7.2 million, or 28.1 percent, primarily due to lower accruals for incentive compensation payouts.

Long-Term Debt Due Within One Year. The balance of Long-term Debt Due Within One Year was $499.7 million and $249.8 million at March 31, 2018 andDecember 31, 2017, respectively, an increase of $249.9 million, primarily due to the reclassification of long-term debt that will mature in January 2019.

Fuel Clause ~~Under~~ Recoveries. The balance of Fuel Clause ~~Under~~Over Recoveries was ~~$35.5~~$49.9 million and ~~$51.3~~$1.7 million at ~~September 30, 2017~~March 31, 2018 and December 31, ~~2016,~~2017, respectively, ~~a decrease~~an increase of ~~$15.8~~$48.2 million, ~~or 30.8 percent,~~ primarily due to higher recoveries from OG&E retail customers as compared to the actual cost of fuel and purchased power.

Other Current ~~Assets.~~ The balance of Other Current Assets was $53.5 million and $78.3 million at September 30, 2017 and December 31, 2016, respectively, a decrease of $24.8 million, or 31.7 percent, primarily due to increased revenue collections from customers associated with various rate riders.

~~Accounts Payable.~~ The balance of Accounts Payable was $135.9 million and $196.4 million at September 30, 2017 and December 31, 2016, respectively, a decrease of $60.5 million, or 30.8 percent, primarily due to the timing of vendor payments.

~~Accrued Taxes.~~ The balance of Accrued Taxes was $58.9 million and $40.8 million at September 30, 2017 and December 31, 2016, respectively, an increase of $18.1 million, or 44.4 percent, primarily resulting from ad valorem tax accruals offset by payments.

~~Accrued Compensation.~~ ~~The balance of Accrued Compensation was~~ ~~$21.3 million~~ ~~and~~ ~~$31.3 million~~ ~~at September 30, 2017 andDecember 31, 2016, respectively, a decrease of $10.0 million, or 31.9 percent, primarily due to the payment of 2016 incentive compensation in 2017, partially offset by 2017 accruals.~~

~~Long-Term Debt Due Within One Year. The balance of Long-term Debt Due Within One Year was $249.7 million and $125.0 million at September 30, 2017 andDecember 31, 2016, respectively, an increase of $124.7 million, or 99.8 percent, primarily due to the reclassification of long-term debt that will mature on September 1, 2018.~~

~~Other Current~~ Liabilities. The balance of Other Current Liabilities was ~~$36.2~~$46.5 million and ~~$95.8~~$28.5 million at ~~September 30, 2017~~March 31, 2018 and December 31, ~~2016,~~2017, respectively, ~~a decrease~~an increase of ~~$59.6~~$18.0 million, or ~~62.2~~63.2 percent, primarily due to amounts ~~refunded~~owed to ~~customers in 2017.~~customers.

Cash Flows


	Nine Months Ended											Three Months Ended
	September 30,						2017 vs. 2016					March 31,						2018 vs. 2017
(In millions)	2017			2016			$ Change			% Change		2018			2017			$ Change			% Change
Net cash provided from operating activities	$	384.4		$	385.8		$	(1.4	)	(0.4	)%	$	145.8		$	64.4		$	81.4		*
Net cash used in investing activities	(662.4		)	(466.4		)	(196.0		)	42.0	%	$	(137.4	)	$	(219.9	)	$	82.5		(37.5	)%
Net cash provided from financing activities	278.0			80.6			197.4			*
Net cash (used in) provided from financing activities												$	(8.4	)	$	155.5		$	(163.9	)	*

* Change is greater than 100 percent variance.

Operating Activities

The ~~decrease~~increase of $~~1.4~~81.4 million~~, or 0.4 percent,~~ in net cash provided from operating activities during the ~~nine~~three months ended ~~September 30, 2017~~March 31, 2018 as compared to the same period in ~~2016~~2017 was primarily due to increased amounts received from customers, partially offset by an increase in vendor payments ~~partially offset by increased~~and an increase in interest, net of amounts ~~received from customers.~~capitalized.

Investing Activities

The ~~increase~~decrease of $~~196.0~~82.5 million, or ~~42.0~~37.5 percent, in net cash used in investing activities during the ~~nine~~three months ended ~~September 30, 2017~~March 31, 2018 as compared to the same period in ~~2016~~2017 was primarily due to~~an increase~~ a decrease in capital expenditures related to environmental ~~projects~~.and reliability projects.

Financing Activities

The~~increase~~ decrease of $~~197.4~~163.9 million in net cash provided from financing activities during the ~~nine~~three months ended ~~September 30, 2017~~March 31, 2018 as compared to the same period in ~~2016~~2017 was primarily due to the issuance of ~~$300.0 million in~~ long-term debt in March ~~2017 and the issuance of $300.0 million in long-term debt in August~~ 2017, partially offset by changes in cash advances with ~~parent.~~parent and lower dividends paid on common stock.

Future Capital Requirements

OG&E's primary needs for capital are related to acquiring or constructing new facilities and replacing or expanding existing facilities. Other working capital requirements are expected to be primarily related to maturing debt, operating lease obligations, fuel clause under and over recoveries and other general corporate purposes. OG&E generally meets its cash needs through a combination of cash generated from operations, short-term borrowings (through a combination of bank borrowings, commercial paper and borrowings from OGE Energy) and permanent financings.

Capital Expenditures

OG&E's estimates of capital expenditures, ~~for the years 2017 through 2021 are shown in the following table.These capital expenditures~~which represent ~~the~~ base maintenance capital expenditures ~~(i.e., capital expenditures to maintain and operate~~ ~~OG&E's business)~~ plus capital expenditures for known and committed ~~projects.~~projects, for the years 2018 through 2022 are discussed in detail in "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" in

(In millions) 2017 2018 2019 2020 2021
OG&E Base Transmission $ 35
$ 30
$ 30
$ 30
$ 30
OG&E Base Distribution 200
175
175
175
175
OG&E Base Generation 35
75
75
75
75
OG&E Other 45
25
25
25
25
Total Base Transmission, Distribution, Generation and Other 315
305
305
305
305
OG&E Known and Committed Non-Base Projects:
Transmission Projects:
Other Regionally Allocated Projects (A) 50
30
20
20
20
Large SPP Integrated Transmission Projects (B) (C) 140
20
—
—
—
Total Transmission Projects 190
50
20
20
20
Other Projects:
Solar 15
—
—
—
—
Environmental - low NO_X burners (D)
15
—
—
—
—
Environmental - Dry Scrubbers (D) 160
95
15
—
—
Combustion turbines - Mustang 145
30
—
—
—
Environmental - natural gas conversion (D) 10
35
15
—
—
Allowance of funds used during construction and ad valorem taxes 55
40
5
—
—
Total Other Projects 400
200
35
—
—
Total Known and Committed Non-Base Projects 590
250
55
20
20
Total $ 905
$ 555
$ 360
$ 325
$ 325


~~(A)~~	~~Typically 100kV to 299kV projects. Approximately 30 percent of revenue requirement allocated to SPP members other than OG&E.~~


~~(B)~~	~~Typically 300kV and above projects. Approximately 85 percent of revenue requirement allocated to SPP members other than OG&E.~~



~~(C)~~	~~Project Type~~	~~Project Description~~	~~Estimated Cost~~ ~~(In millions)~~	~~Projected In-Service Date~~
	~~Integrated Transmission Project~~	~~30 miles of transmission line from OG&E's Gracemont substation to an AEP companion transmission line to its Elk City substation. $5.0 million of the estimated cost has been spent prior to 2017.~~	~~$45~~	~~Late 2017~~
	~~Integrated Transmission Project~~	126 miles of transmission line from OG&E's Woodward District Extra High Voltage substation to OG&E's Cimarron substation and construction of the Mathewson substation on this transmission line. $50.0 million of the estimated cost associated with the Mathewson to Cimarron line and substations went into service in 2016; $55.0 million has been spent prior to 2017.	~~$160~~	~~Mid 2018~~


~~(D)~~	Represent capital costs associated with OG&E’s ECP to comply with the EPA’s MATS and Regional Haze Rule. More detailed discussion regarding the Regional Haze Rule and OG&E’s ECP can be found in Note 11 and under "Environmental Laws and Regulations" within "Management's Discussion and Analysis of Financial Condition and Results of Operations" under Part I, Item 2 of this Form 10-Q.

OG&E's 2017 Form 10-K. Additional capital expenditures beyond those identified in ~~the table above,~~ OG&E's 2017 Form 10-K, including additional incremental growth opportunities in electric transmission assets,, will be evaluated based onupon their impact onupon achieving OG&E's financial objectives.

Financing Activities and Future Sources of Financing

Management expects that cash generated from operations, proceeds from the issuance of long- and short-term debt and funds received from OGE Energy ((from proceeds from the sales of OGE Energy's common stock to the public through OGE Energy's Automatic Dividend Reinvestment and Stock Purchase Plan or other ~~offerings~~)offerings) will be adequate over the next three years to meet anticipated cash needs and to fund future growth opportunities. OG&E utilizes short-term borrowings (through a combination of bank borrowings, commercial paper and borrowings from OGE Energy) to satisfy temporary working capital needs and as an interim source of financing capital expenditures until permanent financing is arranged.

Short-Term Debt and Credit Facility

At ~~September 30, 2017~~March 31, 2018, there was ~~$32.6~~$129.3 million in advances to OGE Energy compared to ~~$49.9~~$112.5 million ~~in advances from OGE Energy~~ at December 31, ~~2016~~2017. OG&E has an intercompany borrowing agreement with OGE Energy whereby OG&E has access to up to $350.0 million of OGE Energy's revolving credit amount. This agreement has a termination date of March 8, 2022. At ~~September 30, 2017, there were no intercompany borrowings under this agreement. On March 8, 2017,~~ OG&E ~~entered into~~has a ~~new~~ $450.0 million revolving credit facility which is available to back up OG&E's commercial paper borrowings and to provide revolving credit borrowings. This bank facility can also be used as a letter of credit facility.At~~September 30, 2017~~, ~~there were~~ ~~$0.3 million~~ ~~supporting letters~~ The following table highlights OG&E's short-term debt activity as of ~~credit at a weighted-average interest rate of~~March 31, 2018.



(In millions)	March 31, 2018
Balance of outstanding supporting letters of credit	$	0.3
Weighted-average interest rate of outstanding supporting letters of credit	0.95		%
Balance of outstanding commercial paper borrowings	$	—
Net available liquidity under revolving credit agreements	$	449.7
Balance of outstanding intercompany borrowings with OGE Energy	$	—

~~0.95 percent. There were no outstanding commercial paper borrowings at September 30, 2017. At September 30,~~In March 2017, OG&E ~~had $449.7~~entered into an unsecured five-year $450.0 million ~~of net available liquidity under its~~ revolving credit agreement. The facility contained an option, which could be exercised up to two times, to extend the term of the facility for an additional year. Effective March 9, 2018, OG&E utilized one of those extensions to extend the maturity of its credit facility from March 8, 2022 to March 8, 2023.

OG&E has the necessary regulatory approvals to incur up to $800.0 million in short-term borrowings at any one time for a two-year period beginning January 1, 2017 and ending December 31, 2018. See Note 89 in "Item 1. Financial Statements" for afurther discussion of OG&E's short-term debt activity.

Expected Issuance of ~~New~~ Long-Term Debt

~~In March 2017,~~ OG&E ~~issued~~expects to issue up to $300.0 million of ~~4.15 percent senior notes due April 1, 2047. The proceeds from~~long-term debt during the ~~issuance were used to repay short-term debt and were added to OG&E's general funds to be used~~second half of 2018, depending on market conditions, for general corporate purposes, including to repay ~~borrowings under the revolving credit facility, to fund the payment of OG&E's $125.0 million of 6.5 percent senior notes that matured on July 15, 2017~~short or long-term debt and to fund ongoing capital expenditures and ~~working capital.~~

Security Ratings

Access to reasonably priced capital is dependent in part on credit and security ratings. Generally, lower ratings lead to higher financing costs. Pricing grids associated with OGE Energy's and OG&E's credit facilities could cause annual fees and borrowing rates to increase if an adverse rating impact occurs. The impact of any future downgrade could include an increase in the costs of OGE Energy's and OG&E's short-term borrowings, but a reduction in OGE Energy's and OG&E's credit ratings would not result in any defaults or accelerations. Any future downgrade of OGE Energy or OG&E could also lead to higher long-term borrowing costs and, if below investment grade, would require OG&E to post collateral or letters of credit.

A security rating is not a recommendation to buy, sell or hold securities. Such rating may be subject to revision or withdrawal at any time by the credit rating agency, and each rating should be evaluated independently of any other rating.

On ~~June 29, 2017, Moody's Investors Service ("Moody's")~~March 5, 2018, S&P Global Ratings revised the rating outlooks on OGE Energy and OG&E from stable to negative. ~~Moody's~~S&P Global Ratings indicated that the revised outlooks reflect the ~~potential for a decline~~limited cushion in company financial ~~metrics amidst some~~measures, which incorporate higher capital spending plans and the effects of tax reform, and uncertainty ~~over cost recovery and earned returns in Oklahoma.~~regarding regulatory risk. The revised outlooks did not trigger any collateral requirements or change fees under the revolving credit agreements.

Critical Accounting Policies and Estimates

The Condensed Financial Statements and Notes to Condensed Financial Statements contain information that is pertinent to Management's Discussion and Analysis. In preparing the Condensed Financial Statements, management is required to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and contingent liabilities at the date of the Condensed Financial Statements and the reported amounts of revenues and expenses during the reporting period. Changes to these assumptions and estimates could have a material effect on OG&E's Condensed Financial Statements. However, OG&E believes it has taken reasonable positions where assumptions and estimates are used in order to minimize the negative financial impact to OG&E that could result if actual results vary from the assumptions and estimates.

In management's opinion, the areas of OG&E where the most significant judgment is exercised include the determination of Pension Plan assumptions, income taxes, contingency reserves, asset retirement obligations ~~and~~, depreciable lives of property, plant and equipment,, ~~the determination of~~ regulatory assets and liabilities and unbilled revenues. The selection, application and disclosure of OG&E's critical accounting estimates have been discussed with OGE Energy's Audit Committee and are discussed in detail in ~~Item~~"Item 7. ~~"Management's~~Management's Discussion and Analysis of Financial Condition and Results of Operations" in OG&E's ~~2016~~2017 Form 10-K.

Commitments and Contingencies

In the normal course of business, OG&E is confronted with issues or events that may result in a contingent liability. These generally relate to lawsuits or claims made by third parties, including governmental agencies. When appropriate, management consults with legal counsel and other experts to assess the claim. If, in management's opinion, OG&E has incurred a probable loss as set forth by GAAP, an estimate is made of the loss, and the appropriate accounting entries are reflected in OG&E's Condensed Financial Statements. At the present time, based on available information, OG&E believes that any reasonably possible losses in excess of accrued amounts arising out of pending or threatened lawsuits or claims would not be quantitatively material to its financial statements and would not have a material adverse effect on OG&E's financial position, results of operations or cash flows. See Notes 1011 and 1112 in "Item 1. Financial Statements" for a discussion of OG&E's commitments and contingencies.

Environmental Laws and Regulations

The activities of OG&E are subject to numerous, stringent and complex ~~Federal,~~federal, state and local laws and regulations governing environmental protection. These laws and regulations can change, restrict or otherwise impact OG&E's business activities in many ways, including the handling or disposal of waste material, planning for future construction activities to avoid or mitigate harm to threatened or endangered species and requiring the installation and operation of emissions ~~pollution~~ control equipment. Failure to comply with these laws and regulations could result in the assessment of administrative, civil and criminal penalties, the imposition of remedial requirements and the issuance of orders enjoining future operations. ~~OG&E~~Management believes that all of its operations are in substantial compliance with current ~~Federal,~~federal, state and local environmental standards. These environmental laws and regulations are also discussed in detail in ~~"Management's~~"Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" in OG&E's ~~2016~~2017 Form 10-K.

Air

Federal Clean Air Act Overview

OG&E’s operations are subject to the Federal Clean Air Act as amended and comparable state laws and regulations. These laws and regulations regulate emissions of air pollutants from various industrial sources, including electric generating units and also impose various monitoring and reporting requirements. Such laws and regulations may require that OG&E obtain pre-approval for the construction or modification of certain projects or facilities expected to produce air emissions or result in the increase of existing air emissions, obtain and strictly comply with air permits containing various emissions and operational limitations or install emission control equipment. OG&E likely will ~~likely~~ be required to incur certain capital expenditures in the future for air pollution control equipment and technology in connection with obtaining and maintaining operating permits and approvals for air emissions.

Regional Haze Control Measures

The EPA's 2005 Regional Haze Rule is intended to protect visibility in certain national parks and wilderness areas throughout the ~~United States~~U.S. that may be impacted by air pollutant emissions. On December 28, 2011, the EPA issued a final Regional Haze Rule for Oklahoma which adopted a FIP for SO₂ emissions at Sooner Units 1 and 2 and Muskogee Units 4 and 5. The FIP compliance date is ~~now~~ January 4, 2019 as a result of ~~the~~an appeal filed by OG&E and others.

OG&E's ~~current~~ strategy for satisfying the FIP includes installing Dry Scrubbers at Sooner Units 1 and 2 and the conversion of Muskogee Units 4 and 5 to natural gas. As described in Note ~~11,~~12 in "Item 1. Financial Statements," the OCC has approved OG&E's decision to install Dry Scrubbers at the Sooner ~~Units.~~units. As of ~~September 30, 2017,~~March 31, 2018, OG&E has ~~incurred $352.7~~invested $416.0 million ~~of construction work~~ in ~~progress on~~ the Dry ~~Scrubbers.~~Scrubbers and $16.1 million in the Muskogee gas conversion.

Cross-State Air Pollution Rule

In August 2011, the EPA finalized its CSAPR that required 27 states in the eastern half of the ~~United States~~U.S. (including Oklahoma) to reduce power plant emissions that contribute to ozone and particulate matter pollution in other states. Litigation challenging the rule prevented it from entering into effect until 2014. Several parties to that litigation, including OG&E, have petitions for

review that remain pending although the rule is now effective. Compliance with the CSAPR began in 2015 using the amount of allowances originally scheduled to be available in 2012. As of ~~September 30, 2017,~~March 31, 2018, OG&E has installed seven low NO_X burner systems on two Muskogee units, two Sooner units and three Seminole units and is in compliance.

On September 7, 2016, the EPA finalized an update to the 2011 CSAPR. The new rule applies to ozone-season NO_X in 22 eastern states (including Oklahoma), utilizes a cap and trade program for NO_X emissions and took effect on May 1, 2017. The rule reduces the 2016 CSAPR emissions cap for all seven of OG&E's coal and gas facilities by 47 percent combined. ~~On December 23, 2016,~~ OG&E and numerous other parties filed a petition for reconsideration of the 2016 rule with the EPA. OG&E is asking the agency to reconsider the methodology used to calculate state ozone-season emissions budgets. OG&E's petition, along with the petitions for ~~reconsideration filed by various other parties, is currently pending. Also on December 23, 2016, OG&E filed a petition for~~judicial and administrative review of the 2016 ~~rule in~~rule. Those petitions all are pending without any relevant substantive decisions by the United States Court of Appeals for the District of Columbia Circuit, asking the court to set aside the rule on the grounds that it is arbitrary, capricious, an abuse of the EPA's discretion and not otherwise in accordance with the law. OG&E's case has been consolidated with several other petitions for review, all of which are currently pending.authorities.

Due to the pending litigation and administrative proceedings, the ultimate timing and impact of the 2016 CSAPR update rule on our operations cannot be determined with certainty at this time. However, OG&E does not anticipate additional capital expenditures beyond what has already been disclosed and does not expect that the reduced emissions cap, if upheld, will have a material impact on OG&E's financial position, results of operations or cash flows.

Hazardous Air Pollutants Emission Standards

On February 16, 2012, the EPA published the final MATS rule regulating the emissions of certain hazardous air pollutants from electric generating units, which became effective April 16, 2012. OG&E believes that it complied with the MATS rule by the April 16, 2016 deadline that applied to OG&E. Nonetheless, there is continuing litigation, to which OG&E is not a party, challenging whether the EPA had statutory authority to issue the MATS rule. OG&E cannot predict the outcome of this litigation or how it will affect OG&E.

National Ambient Air Quality Standards

The EPA is required to set NAAQS for certain pollutants considered to be harmful to public health or the environment. The Clean Air Act requires the EPA to review each NAAQS every five years. As a result of these reviews, the EPA periodically has taken action to adopt more stringent NAAQS for those pollutants. If any areas of Oklahoma were to be designated as not attaining the NAAQS for a particular pollutant, OG&E could be required to install additional emission controls on its facilities to help the state achieve attainment with the NAAQS. As of ~~September 30, 2017,~~March 31, 2018, no areas of Oklahoma had been designated as non-attainment for pollutants that are likely to affect OG&E's operations. Several processes are under way to designate areas in Oklahoma as attaining or not attaining revised NAAQS. OG&E is monitoring those processes and their possible impact on its operations but, at this time, cannot determine with any certainty whether they will cause a material impact to OG&E's financial results.

The EPA proposed to designate part of Muskogee County, in which OG&E's Muskogee Power Plant is located, as non-attainment for the 2010 SO₂ NAAQS on March 1, 2016, even though nearby monitors indicate compliance with the NAAQS. The proposed designation is based on modeling that does not reflect the planned conversion of two of the coal units at Muskogee to natural gas. OG&E commented that the EPA should defer a designation of the area to allow time for additional monitoring. The State of Oklahoma's revised monitoring plan was approved by the EPA, and the required monitoring commenced at the beginning of 2017 and will continue through the end of 2019. Nonetheless, the EPA has a deadline for making a decision on the designation pursuant to a consent decree entered by the U.S. District Court for the Northern District of California to resolve a citizen suit. The deadline has been extended several times, with the ~~latest~~current deadline being August 26, 2017, but a decision has yet to be reached. It is unclear what impact, if any, the consent decree deadline will have on the monitoring plan. At this time, OG&E cannot determine with any certainty whether the proposed designation of Muskogee County will cause a material impact to OG&E's financial results. The EPA has published final decisions on all ~~but two~~ other areas of Oklahoma. In this decision, Noble County, in which the Sooner plant is located, was deemed to be in ~~unclassifiable~~ attainment with the 2010 standard. ~~At this time, OG&E cannot determine with any certainty whether any of these determinations will cause a material impact to OG&E's financial results.~~

On September 30, 2015, the EPA finalized a NAAQS for ozone at 70 ppb, which is more stringent than the previous standard of 75 ppb set in 2008. In September 2016, Governor Mary Fallin submitted to the EPA the recommendation of "attainment/unclassifiable" for all 77 counties in Oklahoma. This recommendation is subject to approval by the EPA. In a letter to Oklahoma dated December 20, 2017, the EPA proposed to approve this recommendation.

OG&E is monitoring those processes and their possible impact on its operations but, at this time, cannot determine with any certainty whether they will cause a material impact to OG&E's financial results.

Climate Change and Greenhouse Gas Emissions

There is continuing discussion and evaluation of possible global climate change in certain regulatory and legislative arenas. The focus is generally on emissions of greenhouse gases, including CO₂, sulfur hexafluoride and methane and whether these emissions are contributing to the warming of the earth's atmosphere. On June 1, 2017, President Trump announced that the U.S. will withdraw from the Paris Climate Accord and begin negotiations to re-enter the agreement with different terms. ~~The~~A new agreement may result in future additional emissions reductions in the ~~United States;~~U.S.; however, it is not possible to determine what the international legal standards for greenhouse gas emissions will be in the future and the extent to which these commitments will be implemented through the Clean Air Act, or any other existing statutes and new legislation.

If legislation or regulations are passed at the ~~Federal~~federal or state levels in the future requiring mandatory reductions of CO₂ and other greenhouse gases on OG&E's facilities, this could result in significant additional compliance costs that would affect OG&E’s future financial position, results of operations and cash flows if such costs are not recovered through regulated rates. Several states outside the area where OG&E operates have passed laws, adopted regulations or undertaken regulatory initiatives to reduce the emission of greenhouse gases, primarily through the planned development of greenhouse gas emission inventories and/or regional greenhouse gas cap and trade programs.

On October 23, 2015, the EPA published the final Clean Power Plan that established standards of performance for CO₂ emissions from existing fossil-fuel-fired power plants along with state-specific CO₂ reduction standards expressed as both rate-based ~~(lbs/~~(lbs./MWh) and mass-based (tons/~~yr)~~yr.) goals. The 2030 rate-based reduction requirement for all existing generating units in Oklahoma has decreased from a proposed 43 percent reduction to 32 percent in the final rule. The mass-based approach for existing units calls for a 24 percent reduction by 2030 in Oklahoma. However, the rule was challenged in court when it was issued, and the U.S. Supreme Court issued orders staying implementation of the Clean Power Plan on February 9, 2016 pending resolution of the court challenges. ~~In addition, the~~The EPA published a proposal on October 16, 2017 to repeal the Clean Power Plan. ~~Due to~~In addition, the ~~pending litigation and the uncertainties created by the proposed repeal~~EPA published an Advance Notice of ~~the rule, it is increasingly unlikely that~~Proposed Rulemaking seeking comments on regulatory options for replacing the Clean Power ~~Plan will be implemented as it was issued in 2015, and the~~Plan. The ultimate timing and impact of these standards on OG&E's operations cannot be determined with certainty at this time, although ~~the standards~~a requirement for significant reduction of CO₂ emissions from existing fossil-fuel-fired power plants ultimately could result in significant additional compliance costs that would affect ~~its~~OG&E's future ~~consolidated~~ financial position, results of operations and cash flows if such costs are not recovered through regulated rates.

Nonetheless, OG&E’s current business strategy will result in a reduced carbon emissions rate compared to current levels. As discussed in Note 12 in "Item 1. Financial Statements" under "Pending Regulatory ~~Matters" in Note 11,~~Matters," OG&E's plan to comply with the EPA’s MATS rule and Regional Haze Rule FIP includes converting two coal-fired generating units at the Muskogee Station to natural gas, among other measures. OG&E’s deployment of Smart Grid technology helps to reduce the peak load demand. OG&E is also ~~seeks to utilize~~deploying more renewable energy sources that do not emit greenhouse gases. OG&E's service territory borders one of the nation's best wind resource ~~areas.~~areas, and OG&E has leveraged its geographic position to develop renewable energy resources and completed transmission investments to deliver the renewable energy. The SPP has begun to authorize the construction of transmission lines capable of bringing renewable energy out of the wind resource ~~area~~areas in western Oklahoma, the Texas Panhandle and western Kansas to load centers by planning for more transmission to be built in the area. In addition to increasing overall system reliability, these new transmission resources should provide greater access to additional wind resources that are currently constrained due to existing transmission delivery limitations.

EPA Startup, Shutdown and Malfunction Policy

On May 22, 2015, the EPA issued a final rule to address the ~~outdated~~ provisions in the SIPs of 36 states ~~including Oklahoma,~~(including Oklahoma) regarding the treatment of emissions that occur during startup, shutdown and malfunction operations. The final rule clarifies the EPA's Startup, Shutdown and Malfunction ~~Policy~~Policy. Although judicial challenges to ~~assure consistency with~~ the ~~Clean Air Act and other recent court decisions. The~~rule are ongoing, the Oklahoma Department of Environmental Quality submitted a SIP revision for the EPA's approval on November 7, 2016 to comply with this rule. ~~Although the extent of impact is not known, this~~This rule ~~will impact~~has resulted in permit modifications for certain OG&E units. OG&E does not anticipate capital expenditures or a material impact to its financial position, results of operations or cash flows, as a result of adoption of this rule.

Air Quality Control System

On September 10, 2014, OG&E executed a contract for the design, engineering and fabrication of two circulating Dry Scrubber systems to be installed at Sooner Units 1 and 2. OG&E entered into an agreement on February 9, 2015 to install the Dry Scrubber systems. The Dry Scrubbers are expected to be completed mid to late 2018. More detail regarding the ECP can be found in Note 12 in "Item 1. Financial Statements."

Endangered Species

Certain ~~Federal~~federal laws, including the Bald and Golden Eagle Protection Act, the Migratory Bird Treaty Act and the Endangered Species Act, provide special protection to certain designated species. These laws and any state equivalents provide for significant civil and criminal penalties for unpermitted activities that result in harm to or harassment of certain protected animals and plants, including damage to their habitats. If such species are located in an area in which OG&E conducts operations, or if additional species in those areas become subject to protection, OG&E’s operations and development projects, particularly transmission, wind or pipeline projects, could be restricted or delayed, or OG&E could be required to implement expensive mitigation measures.

In 2014, OG&E enrolled in the Western Association of Fish and Wildlife Agencies range-wide conservation plan which consists of industry-specific conservation practices that apply to projects and activities in the impacted area. The range-wide conservation plan was approved by the U.S. Fish and Wildlife Service and incorporated as part of the agency’s final decision on March 27, 2014 to list the lesser prairie chicken as a threatened species. On September 1, 2015, the U.S. District Court Western District of Texas vacated federal protections for the lesser prairie chicken based on the U.S. Fish and Wildlife Service's failure to thoroughly consider the active conservation efforts in making the listing decision. On July 19, 2016, the U.S. Fish and Wildlife Service issued a final rule to amend its regulations to remove the lesser prairie chicken from the list of threatened species under the Endangered Species Act. On September 8, 2016, WildEarth Guardians, Defenders of Wildlife and the Center for Biological Diversity filed a petition with the U.S. Fish and Wildlife Services to list the lesser prairie chicken as "endangered" under the Endangered Species Act. On November 30, 2016, the U.S. Fish and Wildlife Services published a notice in the Federal Register announcing its finding that the September 2016 petition presents information indicating that listing of the lesser prairie chicken may be warranted. The agency has initiated a 12-month status review. OG&E will continue to monitor the progress of the petition.

~~Air Quality Control System~~

On September 10, 2014, OG&E executed a contract for the design, engineering and fabrication of two circulating Dry Scrubber systems to be installed at Sooner Units 1 and 2. OG&E entered into an agreement on February 9, 2015 to install the Dry Scrubber systems. The Dry Scrubbers are scheduled to be completed by 2019. More detail regarding the ECP can be found under "Pending Regulatory Matters" in Note 11.

Waste

OG&E's operations generate wastes that are subject to the Federal Resource Conservation and Recovery Act of 1976 as well as comparable state laws which impose detailed requirements for the handling, storage, treatment and disposal of waste.

~~On December 19, 2014,~~In 2015, the EPA finalized a rule under the Federal Resource Conservation and Recovery Act for the handling and disposal of coal combustion residuals or coal ash. The ~~final~~ rule regulates coal ash as a solid waste rather than a hazardous waste, which would have made the management of coal ash more costly. The ~~final~~ rule is currently being appealed at the D.C. Circuit Court of Appeals. OG&E is monitoring other regulatory developments relating to this rule, none of which appear to be material to OG&E at this time. OG&E is in compliance with this rule at this time.

OG&E has sought and will continue to seek pollution prevention opportunities and to evaluate the effectiveness of its waste reduction, reuse and recycling efforts. OG&E obtains refunds from the recycling of scrap metal, salvaged transformers and used transformer oil. Additional savings ~~are~~ gained through the reduction and/or avoidance of disposal costs and the reduction in material purchases due to the reuse of existing materials. Similar savings are anticipated in future years.

Water

OG&E's operations are subject to the Federal Clean Water Act and comparable state laws and regulations. These laws and regulations impose detailed requirements and strict controls regarding the discharge of pollutants into state and ~~Federal~~federal waters.

The EPA issued a final rule on May 19, 2014 to implement Section 316(b) of the Federal Clean Water Act, which requires that power plant cooling water intake structure location, design, construction and capacity reflect the best available technology for minimizing their adverse environmental impact via the impingement and entrainment of aquatic organisms. OG&E submitted compliance plans to the ~~state~~State of Oklahoma in April 2015. On December 22, 2017, the Oklahoma Department of Environmental Quality issued a final permit for Muskogee Power Plant in compliance with the final 316(b) rule, which did not incur material cost. OG&E expects to be able to provide a reasonable estimate of any material costs associated with the rule's implementation at other facilities following the future issuance of ~~the~~ permits from the ~~state.~~State of Oklahoma.

On September 30, 2015, the EPA issued a final rule addressing the effluent limitation guidelines for power plants under the Federal Clean Water Act. The final rule establishes technology- and performance-based standards that may apply to discharges of six waste streams including bottom ash transport water. ~~On June 6, 2017, the EPA proposed to delay the compliance deadlines~~

for the 2015 final rule following granting numerous petitions for reconsideration that were filed with the EPA. On September 13, 2017, the EPA finalized an extension of initial deadlines which would take effect in 2018. The earliest applicable date for complianceCompliance with this rule ~~is now November 1, 2020, rather than November 1, 2018. The latest applicability date of December 31, 2023 did not change.~~occurs between 2018 and 2023. OG&E is evaluating what, if any, compliance actions are needed but is not able to quantify with any certainty what costs may be incurred. OG&E expects to be able to provide a reasonable estimate of any material costs associated with the rule's implementation following issuance of the permits from the ~~state.~~State of Oklahoma.

Site Remediation

The Comprehensive Environmental Response, Compensation and Liability Act of 1980 and comparable state laws impose liability, without regard to the legality of the original conduct, on certain classes of persons responsible for the release of hazardous substances into the environment. Because OG&E utilizes various products and generate wastes that are considered hazardous substances for purposes of the Comprehensive Environmental Response, Compensation and Liability Act of 1980, OG&E could be subject to liability for the costs of cleaning up and restoring sites where those substances have been released to the environment. At this time, it is not anticipated that any associated liability will cause a significant impact to OG&E.

For a further discussion regarding contingencies relating to environmental laws and regulations, see Note ~~10.~~11 in "Item 1. Financial Statements."

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

Under the reduced disclosure format permitted by General Instruction H(2)(c) of Form 10-Q, the information otherwise required by Item 3 has been omitted.

Item 4. Controls and Procedures.

OG&E maintains a set of disclosure controls and procedures designed to ensure that information required to be disclosed by OG&E in reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission rules and forms. In addition, the disclosure controls and procedures ensure that information required to be disclosed is accumulated and communicated to management, including the chief executive officer and chief financial officer, allowing timely decisions regarding required disclosure. As of the end of the period covered by this report, based on an evaluation carried out under the supervision and with the participation of OG&E's management, including the chief executive officer and chief financial officer, of the effectiveness of OG&E's disclosure controls and procedures (as such term is defined in Rules 13a-15(e) and 15(d)-15(e) under the Securities Exchange Act of 1934), the chief executive officer and chief financial officer have concluded that OG&E's disclosure controls and procedures are effective.

No change in OG&E's internal control over financial reporting has occurred during OG&E's most recently completed fiscal quarter that has materially affected, or is reasonably likely to materially affect, OG&E's internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934).

PART II. OTHER INFORMATION

Item 1. Legal Proceedings.

Reference is made to Item 3 of Part I of OG&E's ~~2016~~2017 Form 10-K for a description of certain legal proceedings presently pending. Except as described above under ~~Item~~"Environmental Laws and Regulations" in "Item 2. ~~"Management's~~Management's Discussion and Analysis of Financial Condition and Results of Operations, ~~- Environmental Laws and Regulations,~~" there are no new significant cases to report against OG&E and there have been no material changes in the previously reported proceedings.

Item 1A. Risk Factors.

There have been no significant changes in OG&E's risk factors from those discussed in OG&E's ~~2016~~2017 Form 10-K, which are incorporated herein by reference.

Item 6. Exhibits.



Exhibit No.	Description
~~4.01~~10.01	~~Supplemental Indenture No. 17~~Letter of extension dated as of ~~August 1,~~March 9, 2018 for OG&E's and OGE Energy's credit agreements dated as of March 8, 2017, ~~between~~by and among Wells Fargo Bank, National Association, as Administrative Agent, JPMorgan Chase Bank, N.A., Syndication Agent, Mizuho Bank, Ltd., MUFG Union Bank, N.A., Royal Bank of Canada and U.S. Bank National Association, as Co-Documentation Agents, the Lenders thereto, and OG&E and ~~UMB Bank, N.A., as trustee. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed August 11, 2017 (File No. 1-1097) and incorporated by reference herein).~~OGE Energy, for their respective credit facility.
31.01	Certifications Pursuant to Rule 13a-14(a)/15d-14(a) As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.01	Certification Pursuant to 18 U.S.C. Section 1350 As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS	XBRL Instance Document.
101.SCH	XBRL Taxonomy Schema Document.
101.PRE	XBRL Taxonomy Presentation Linkbase Document.
101.LAB	XBRL Taxonomy Label Linkbase Document.
101.CAL	XBRL Taxonomy Calculation Linkbase Document.
101.DEF	XBRL Definition Linkbase Document.

SIGNATURE

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



	OKLAHOMA GAS AND ELECTRIC COMPANY
	(Registrant)

By:	/s/ ~~Scott Forbes~~Sarah R. Stafford
	~~Scott Forbes~~Sarah R. Stafford
	Controller and Chief Accounting Officer
	(On behalf of the Registrant and in ~~his~~her capacity as Chief Accounting Officer)

~~November 1, 2017~~May 2, 2018

3633



Oklahoma		73-0382390
(State or other jurisdiction of		(I.R.S. Employer
incorporation or organization)		Identification No.)



	Page
GLOSSARY OF TERMS	ii
FORWARD-LOOKING STATEMENTS	1

Part I - FINANCIAL INFORMATION
Item 1. Financial Statements (Unaudited)
Condensed Statements of Income and Comprehensive Income	2
Condensed Statements of Cash Flows	3
Condensed Balance Sheets	4
Condensed Statements of Changes in Stockholder's Equity	6
Notes to Condensed Financial Statements	7

Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations	2019

Item 3. Quantitative and Qualitative Disclosures About Market Risk	3430

Item 4. Controls and Procedures	3431

Part II - OTHER INFORMATION
Item 1. Legal Proceedings	3532

Item 1A. Risk Factors	3532

Item 6. Exhibits	3532

Signature	3633


	September 30,		December 31,		March 31,		December 31,
(In millions)	2017		2016		2018		2017
ASSETS
CURRENT ASSETS
Accounts receivable, less reserve of $1.5 and $1.5, respectively	$	261.5	$	173.0
Accounts receivable, less reserve of $1.0 and $1.5, respectively					$	177.5	$	188.5
Accrued unbilled revenues	69.8		59.7		57.8		66.5
Advances to parent	32.6		—		129.3		112.5
Fuel inventories	77.2		79.8		95.4		84.3
Materials and supplies, at average cost	78.9		80.3		101.4		80.8
Fuel clause under recoveries	35.5		51.3
Other	53.5		78.3		40.3		48.6
Total current assets	609.0		522.4		601.7		581.2
OTHER PROPERTY AND INVESTMENTS	6.0		6.6		6.0		5.9
PROPERTY, PLANT AND EQUIPMENT
In service	10,791.4		10,572.3		11,468.3		11,035.1
Construction work in progress	893.9		495.1		525.7		867.5
Total property, plant and equipment	11,685.3		11,067.4		11,994.0		11,902.6
Less accumulated depreciation	3,494.7		3,385.6		3,607.0		3,568.8
Net property, plant and equipment	8,190.6		7,681.8		8,387.0		8,333.8
DEFERRED CHARGES AND OTHER ASSETS
Regulatory assets	373.4		404.8		275.6		283.0
Other	51.9		53.8		33.0		51.7
Total deferred charges and other assets	425.3		458.6		308.6		334.7
TOTAL ASSETS	$	9,230.9	$	8,669.4	$	9,303.3	$	9,255.6


	September 30,		December 31,		March 31,		December 31,
(In millions)	2017		2016		2018		2017
LIABILITIES AND STOCKHOLDER'S EQUITY
CURRENT LIABILITIES
Accounts payable - affiliates	$	1.0	$	0.1
Accounts payable - other	134.9		196.3
Advances from parent	—		49.9
Accounts payable					$	171.3	$	216.8
Customer deposits	79.5		77.7		81.4		80.7
Accrued taxes	58.9		40.8		25.1		41.5
Accrued interest	38.9		40.2		38.9		44.0
Accrued compensation	21.3		31.3		18.4		25.6
Long-term debt due within one year	249.7		125.0		499.7		249.8
Fuel clause over recoveries					49.9		1.7
Other	36.2		95.8		46.5		28.5
Total current liabilities	620.4		657.1		931.2		688.6
LONG-TERM DEBT	2,749.5		2,405.8		2,500.1		2,749.6
DEFERRED CREDITS AND OTHER LIABILITIES
Accrued benefit obligations	106.9		167.7		108.0		110.3
Deferred income taxes	1,870.6		1,752.3		840.6		832.2
Regulatory liabilities	331.7		299.7		1,292.7		1,283.4
Other	138.9		134.7		142.7		135.8
Total deferred credits and other liabilities	2,448.1		2,354.4		2,384.0		2,361.7
Total liabilities	5,818.0		5,417.3		5,815.3		5,799.9
COMMITMENTS AND CONTINGENCIES (NOTE 10)
COMMITMENTS AND CONTINGENCIES (NOTE 11)
STOCKHOLDER'S EQUITY
Common stockholder's equity	1,026.0		1,024.1		1,028.2		1,027.2
Retained earnings	2,386.9		2,228.0		2,459.8		2,428.5
Total stockholder's equity	3,412.9		3,252.1		3,488.0		3,455.7
TOTAL LIABILITIES AND STOCKHOLDER'S EQUITY	$	9,230.9	$	8,669.4	$	9,303.3	$	9,255.6


(In millions)	Common Stock		Premium on Common Stock		Retained Earnings			Total			Shares Outstanding	Common Stock		Premium on Common Stock		Retained Earnings		Total
Balance at December 31, 2017											40.4	$	100.9	$	926.3	$	2,428.5	$	3,455.7
Net income											—	—		—		31.3		31.3
Stock-based compensation											—	—		1.0		—		1.0
Balance at March 31, 2018											40.4	$	100.9	$	927.3	$	2,459.8	$	3,488.0

Balance at December 31, 2016	$	100.9	$	923.2	$	2,228.0		$	3,252.1		40.4	$	100.9	$	923.2	$	2,228.0	$	3,252.1
Net income	—		—		263.9			263.9			—	—		—		16.2		16.2
Dividends declared on common stock	—		—		(105.0		)	(105.0		)
Stock-based compensation	—		1.9		—			1.9			—	—		0.8		—		0.8
Balance at September 30, 2017	$	100.9	$	925.1	$	2,386.9		$	3,412.9

Balance at December 31, 2015	$	100.9	$	920.9	$	2,133.9		$	3,155.7
Net income	—		—		238.3			238.3
Dividends declared on common stock	—		—		(125.0		)	(125.0		)
Stock-based compensation	—		1.7		—			1.7
Balance at September 30, 2016	$	100.9	$	922.6	$	2,247.2		$	3,270.7
Balance at March 31, 2017											40.4	$	100.9	$	924.0	$	2,244.2	$	3,269.1



Large accelerated filer o	Accelerated filer o
Non-accelerated filer þ (Do not check if a smaller reporting company)	Smaller reporting company o
	Emerging growth company o



	Three Months Ended September 30,						Nine Months Ended September 30,
(In millions)	2017			2016			2017			2016
OPERATING REVENUES	$	716.8		$	743.9		$	1,759.2		$	1,728.4
COST OF SALES	255.7			269.8			696.5			645.4
OPERATING EXPENSES
Other operation and maintenance	120.2			115.2			362.8			356.3
Depreciation and amortization	76.2			80.8			204.6			235.9
Taxes other than income	21.7			20.9			64.2			63.6
Total operating expenses	218.1			216.9			631.6			655.8
OPERATING INCOME	243.0			257.2			431.1			427.2
OTHER INCOME (EXPENSE)
Allowance for equity funds used during construction	11.8			3.9			27.2			9.2
Other income	13.4			2.9			27.5			11.3
Other expense	(0.5		)	(0.8		)	(1.5		)	(2.2		)
Net other income	24.7			6.0			53.2			18.3
INTEREST EXPENSE
Interest on long-term debt	38.3			35.4			112.4			106.3
Allowance for borrowed funds used during construction	(5.2		)	(2.0		)	(12.6		)	(4.7		)
Interest on short-term debt and other interest charges	1.4			0.9			3.9			3.2
Interest expense	34.5			34.3			103.7			104.8
INCOME BEFORE TAXES	233.2			228.9			380.6			340.7
INCOME TAX EXPENSE	71.7			69.0			116.7			102.4
NET INCOME	161.5			159.9			263.9			238.3
Other comprehensive income (loss), net of tax	—			—			—			—
COMPREHENSIVE INCOME	$	161.5		$	159.9		$	263.9		$	238.3



	Three Months Ended March 31,
(In millions)	2018			2017
OPERATING REVENUES
Revenues from contracts with customers	$	477.9		$	—
Revenues from alternative revenue programs	14.8			—
Operating revenues	492.7			456.0
COST OF SALES	210.5			208.7
OPERATING EXPENSES
Other operation and maintenance	119.7			124.7
Depreciation and amortization	78.8			54.7
Taxes other than income	22.7			22.3
Total operating expenses	221.2			201.7
OPERATING INCOME	61.0			45.6
OTHER INCOME (EXPENSE)
Allowance for equity funds used during construction	7.0			6.9
Other net periodic pension and postretirement benefit (cost)	1.3			(1.4		)
Other income	3.1			6.4
Other expense	(0.8		)	(0.4		)
Net other income	10.6			11.5
INTEREST EXPENSE
Interest on long-term debt	39.6			35.5
Allowance for borrowed funds used during construction	(3.7		)	(3.3		)
Interest on short-term debt and other interest charges	1.4			1.4
Interest expense	37.3			33.6
INCOME BEFORE TAXES	34.3			23.5
INCOME TAX EXPENSE	3.0			7.3
NET INCOME	31.3			16.2
Other comprehensive income (loss), net of tax	—			—
COMPREHENSIVE INCOME	$	31.3		$	16.2


(A)	Included in Other Current Assets on the Condensed Balance Sheets.


(B)	Included in Other Current Liabilities on the Condensed Balance Sheets.


	September 30, 2017				December 31, 2016				March 31, 2018				December 31, 2017
(In millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term Debt (including Long-term Debt due within one year)
Long-term Debt (including Long-term Debt due within one year):
Senior Notes	$	2,854.1	$	3,179.4	$	2,385.5	$	2,657.2	$	2,854.7	$	3,155.3	$	2,854.3	$	3,242.8
OG&E Industrial Authority Bonds	135.4		135.4		135.4		135.4		$	135.4	$	135.4	$	135.4	$	135.4
Tinker Debt	9.7		9.6		9.9		9.5		$	9.7	$	9.4	$	9.7	$	9.8



	Units/Shares	Fair Value Per Share
Grants:
Performance units (Total shareholder return)	91,940	$	36.86
Performance units (Earnings per share)	30,649	$	31.03


~~(B)~~	~~In addition to the $7.8 million and $7.2 million of net periodic benefit cost recognized during the nine months ended September 30, 2017 and 2016, respectively, OG&E recognized the following:~~


(A)	Based on the midpoint of OG&E earnings guidance for ~~2017.~~2018.


	Change for
	September 30, 2017
(In millions)	Three Months Ended			Nine Months Ended			Change
Weather (price and quantity) (A)	$	(14.9	)	$	(29.3	)
Price variance (B)	(7.3		)	(13.4		)
Other	(0.4		)	0.1
New customer growth	6.4			12.1
Price variance (A)							$	19.0
Weather (price and quantity) (B)							14.6
Wholesale transmission revenue	1.7			4.4			2.5
Non-residential demand and related revenues	0.9			3.6			1.5
Industrial and oilfield sales	0.6			2.2			1.5
New customer growth							1.4
Other							0.9
Reserve for tax refund (C)							(6.5		)
Change in gross margin	$	(13.0	)	$	(20.3	)	$	34.9


2.	Accounting Pronouncements


4.	Related Party Transactions


4.5.	Fair Value Measurements


5.6.	Stock-Based Compensation


(A)	Cooling degree days decreased approximately 16 percent during the three months ended September 30, 2017. Cooling degree days decreased approximately 11 percent, and heating degree days decreased approximately eight percent during the nine months ended September 30, 2017. Increased primarily due to higher demand prices.


(B)	Heating degree days increased approximately 36 percent during the three months ended March 31, 2018.


(A)	~~Increased during~~Decreased primarily due to the ~~three months ended September 30, 2017~~timing of normal plant maintenance.


(B)	Increased primarily due to mutual assistance ~~which was~~ provided ~~during~~in the aftermath of natural disasters. Increased during the nine months ended September 30, 2017 primarily due to more storm costs exceeding the $2.7 million OCC-allowed threshold, which were moved to a regulatory asset, as well as mutual assistance.Hurricane Maria.