10-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

(Mark One)

ý ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 2018 or

¨ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from                     to                     

Commission File Number 001-35243

SUNCOKE ENERGY, INC.

(Exact name of Registrant as specified in its charter)

Delaware	90-0640593
(State of or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
1011 Warrenville Road, Suite 600 Lisle, Illinois	60532
(Address of principal executive offices)	(zip code)

Registrant’s telephone number, including area code: (630) 824-1000

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

Title of Each Class	Name of Each Exchange on which Registered
Common Stock, $0.01 par value	New York Stock Exchange

Securities registered pursuant to Section 12(g) of the Act: None

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.    Yes  ¨    No  ý

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Act.    Yes  ¨    No  ý

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  ý    No  ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    Yes  ý    No  ¨

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.  ý

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer	ý	Accelerated filer	¨
Non-accelerated filer	¨	Smaller reporting company	¨
		Emerging growth company	¨

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

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

The aggregate market value of the registrant's common stock (based upon the June 30, 2018 closing price of $13.40 on the New York Stock Exchange) held by non-affiliates was approximately $863,299,596.

The number of shares of common stock outstanding as of February 8, 2019 was 64,756,093.

Portions of the SunCoke Energy, Inc. 2019 definitive Proxy Statement, which will be filed with the Securities and Exchange Commission within 120 days after December 31, 2018, are incorporated by reference in Part III of this Form 10-K.

1

SUNCOKE ENERGY, INC.

TABLE OF CONTENTS

PART I
Item 1.	Business	1
Item 1A.	Risk Factors	15
Item 1B.	Unresolved Staff Comments	33
Item 2.	Properties	33
Item 3.	Legal Proceedings	34
Item 4.	Mine Safety Disclosures	34
PART II
Item 5.	Market for Registrant’s Common Equity, Related Stockholders Matters and Issuer Purchases of Equity Securities	35
Item 6.	Selected Financial Data	37
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	38
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk	57
Item 8.	Financial Statements and Supplementary Data	58
Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	110
Item 9A.	Controls and Procedures	110
Item 9B.	Other Information	110
PART III
Item 10.	Directors, Executive Officers and Corporate Governance	111
Item 11.	Executive Compensation	111
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	111
Item 13.	Certain Relationships and Related Transactions, and Director Independence	111
Item 14.	Principal Accounting Fees and Services	113
PART IV
Item 15.	Exhibits, Financial Statement Schedules	114

PART I

Item 1. Business

Overview

SunCoke Energy, Inc. (“SunCoke Energy,” “SunCoke,” “Company,” “we,” “our” and “us”) is the largest independent producer of high-quality coke in the Americas, as measured by tons of coke produced each year, and has over 55 years of coke production experience. Coke is a principal raw material in the blast furnace steelmaking process and is produced by heating metallurgical coal in a refractory oven, which releases certain volatile components from the coal, thus transforming the coal into coke. We also provide handling and/or mixing services to steel, coke (including some of our domestic cokemaking facilities), electric utility, coal producing and other manufacturing based customers.

Our consolidated financial statements include SunCoke Energy Partners, L.P. (the “Partnership”), a publicly-traded master limited partnership. As of December 31, 2018, we owned the general partner of the Partnership, which owns a 2.0 percent general partner interest and incentive distribution rights (“IDRs”) in the Partnership, and owned a 60.4 percent limited partner interest in the Partnership. The remaining 37.6 percent interest in the Partnership was held by public unitholders.

On February 5, 2019, the Company and the Partnership announced that they have entered into a definitive agreement whereby SunCoke will acquire all outstanding common units of the Partnership not already owned by SunCoke in a stock-for-unit merger transaction (the “Simplification Transaction”). Pursuant to the terms of this agreement (“Merger Agreement”), the Partnership's unaffiliated common unitholders will receive 1.40 SunCoke common shares plus a fraction of a SunCoke common share, based on a ratio as further described in the Merger Agreement, for each Partnership common unit. On behalf of the Partnership and its public unitholders, the terms of the Simplification Transaction were negotiated, reviewed and approved by the conflicts committee of the Board of Directors of the Partnership's general partner, which consisted solely of independent directors. The transaction was approved by the Board of Directors of the general partner of the Partnership and the Board of Directors of SunCoke.

Following completion of the Simplification Transaction, the Partnership will become a wholly-owned subsidiary of SunCoke, the Partnership's common units will cease to be publicly traded and the Partnership's IDRs will be eliminated.  The Simplification Transaction is expected to close late in the second quarter of 2019 or early in the third quarter of 2019, subject to customary closing conditions, including the approval by holders of a majority of the outstanding SunCoke common shares and Partnership common units, as well as customary regulatory approvals. SunCoke indirectly owns the majority of the Partnership common units, which is sufficient to approve the transaction on behalf of the holders of Partnership common units.

Incorporated in Delaware since 2010 and headquartered in Lisle, Illinois, we became a publicly-traded company in 2011 and our stock is listed on the New York Stock Exchange (“NYSE”) under the symbol “SXC.”

1

Cokemaking Operations

The following table sets forth information about our cokemaking facilities:

Facility	Location	Customer	Year of Start Up	Contract Expiration	Number of Coke Ovens	Annual Cokemaking Nameplate Capacity (thousands of tons)	Use of Waste Heat
Owned and Operated:
Jewell	Vansant, Virginia	AM USA	1962	December 2020	142	720	Partially used for thermal coal drying
Indiana Harbor	East Chicago, Indiana	AM USA	1998	October 2023	268	1,220	Heat for power generation
Haverhill Phase I	Franklin Furnace, Ohio	AM USA	2005	December 2020	100	550	Process steam
Haverhill Phase II	Franklin Furnace,  Ohio	AK Steel	2008	December 2021	100	550	Power generation
Granite City	Granite City, Illinois	U.S. Steel	2009	December 2025	120	650	Steam for power generation
Middletown(1)	Middletown, Ohio	AK Steel	2011	December 2032	100	550	Power generation
Total					830	4,240
Operated:
Vitória	Vitória, Brazil	ArcelorMittal Brazil	2007	January 2023	320	1,700	Steam for power generation
Total					1,150	5,940

(1) Cokemaking nameplate capacity represents stated capacity for production of blast furnace coke. Middletown production and sales volumes are based on “run of oven” capacity, which includes both blast furnace coke and small coke. Using the stated capacity, Middletown nameplate capacity on a “run of oven” basis is approximately 578 thousand tons per year.

We are a technological leader in cokemaking. We have designed, developed, built, own and operate five cokemaking facilities in the United States (“U.S.”) with collective nameplate capacity to produce approximately 4.2 million tons of coke per year. Additionally, we have designed and operate one cokemaking facility in Brazil under licensing and operating agreements on behalf of ArcelorMittal Brasil S.A. ("ArcelorMittal Brazil”), which has approximately 1.7 million tons of annual cokemaking capacity.Our cokemaking ovens utilize efficient, modern heat recovery technology designed to combust the coal’s volatile components liberated during the cokemaking process and use the resulting heat to create steam or electricity for sale. This differs from by-product cokemaking, which repurposes the coal’s liberated volatile components for other uses. We have constructed the only greenfield cokemaking facilities in the U.S. in approximately 30years and are the only North American coke producer that utilizes heat recovery technology in the cokemaking process.

We believe our advanced heat recovery cokemaking process has numerous advantages over by-product cokemaking, including producing higher quality coke, using waste heat to generate derivative energy for resale and reducing the environmental impact. The Clean Air Act Amendments of 1990 specifically directed the U.S. Environmental Protection Agency (“EPA”) to evaluate our heat recovery coke oven technology as a basis for establishing Maximum Achievable Control Technology (“MACT”) standards for new cokemaking facilities. In addition, each of the four cokemaking facilities that we have built since 1990 has either met or exceeded the applicable Best Available Control Technology (“BACT”), or Lowest Achievable Emission Rate (“LAER”) standards, as applicable, set forth by the EPA for cokemaking facilities at that time.

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Our Granite City facility and the first phase of our Haverhill facility, or Haverhill I, have steam generation facilities, which use hot flue gas from the cokemaking process to produce steam for sale to customers pursuant to steam supply and purchase agreements. Granite City sells steam to United States Steel Corporation ("U.S. Steel") and Haverhill I provides steam, at minimal cost, to Altivia Petrochemicals, LLC. Our Middletown facility and the second phase of our Haverhill facility, or Haverhill II, have cogeneration plants that use the hot flue gas created by the cokemaking process to generate electricity, which either is sold into the regional power market or to AK Steel Holding Corporation ("AK Steel") pursuant to energy sales agreements.

Our core business model is predicated on providing steelmakers an alternative to investing capital in their own captive coke production facilities. We direct our marketing efforts principally towards steelmaking customers that require coke for use in their blast furnaces. Substantially all our coke sales are made pursuant to long-term, take-or-pay agreements with ArcelorMittal USA LLC and/or its affiliates (“AM USA”), AK Steel and U.S. Steel, who are three of the largest blast furnace steelmakers in North America, each of which individually accounts for greater than ten percent of our consolidated revenues. The take-or-pay provisions require us to produce the contracted volumes of coke and require our customers to purchase such volumes of coke up to a specified tonnage or pay the contract price for any tonnage they elect not to take. As a result, our ability to produce the contracted coke volume is a key determinant of our profitability. We generally do not have significant spot coke sales since our domestic capacity is consumed by long-term contracts; accordingly, spot prices for coke do not generally affect our revenues. To date, our coke customers have satisfied their obligations under these agreements.

Our coke sales agreements have an average remaining term of approximately six years and contain pass-through provisions for costs we incur in the cokemaking process, including coal and coal procurement costs, subject to meeting contractual coal-to-coke yields, operating and maintenance expenses, costs related to the transportation of coke to our customers, taxes (other than income taxes) and costs associated with changes in regulation. When targeted coal-to-coke yields are achieved, the price of coal is not a significant determining factor in the profitability of these facilities, although it does affect our revenue and cost of sales for these facilities in approximately equal amounts. However, to the extent that the actual coal-to-coke yields are less than the contractual standard, we are responsible for the cost of the excess coal used in the cokemaking process. Conversely, to the extent our actual coal-to-coke yields are higher than the contractual standard, we realize gains. As coal prices increase, the benefits associated with favorable coal-to-coke yields also increase. These features of our coke sales agreements reduce our exposure to variability in coal price changes and inflationary costs over the remaining terms of these agreements. The coal component of the Jewell coke price is typically fixed annually for each calendar year based on the weighted-average contract price of third-party coal purchases at our Haverhill facility applicable to AM USA coke sales.

Our coke prices include both an operating cost component and a fixed fee component. Operating costs under two of our coke sales agreements are fixed subject to an annual adjustment based on an inflation index. Under our other four coke sales agreements, operating costs are passed through to the respective customers subject to an annually negotiated budget, in some cases subject to a cap annually adjusted for inflation, and we share any difference in costs from the budgeted amounts with our customers. In 2018, the operating cost component of our contract at Indiana Harbor changed to an annually negotiated budget from a fixed recovery per ton mechanism, which had a favorable impact on our results. Accordingly, actual operating costs in excess of caps or budgets can have a significant impact on the profitability of all of our domestic cokemaking facilities. The fixed fee component for each ton of coke sold to the customer is determined at the time the coke sales agreement is signed and is effective for the term of each sales agreement. The fixed fee is intended to provide an adequate return on invested capital and may differ based on investment levels and other considerations. The actual return on invested capital at any facility is based on the fixed fee per ton and favorable or unfavorable performance on pass-through cost items.

The coke sales agreement and energy sales agreement with AK Steel at our Haverhill facility are subject to early termination by AK Steel only if AK Steel meets both of the following two criteria: (1) AK Steel permanently shuts down operation of the iron producing portion of its Ashland Works Plant and (2) AK Steel has not acquired or begun construction of a new blast furnace in the U.S. to replace, in whole or in part, the Ashland Works Plant iron production capacity. If AK Steel were able to satisfy both criteria and chose to elect early termination, AK Steel must provide two years advance notice of the termination. During the two-year notice period, AK Steel must continue to perform in full under the terms of the coke sales agreement and energy sales agreement. On January 28, 2019, AK Steel announced its intention to permanently close its Ashland Works Plant by the end of 2019. Were the Ashland Works Plant to permanently shut down, we believe AK Steel has not and would not satisfy the second criterion. No other coke sales agreement has an early termination clause.

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While our steelmaking customers continue to operate in an environment that is challenged by global overcapacity,throughout 2018 they benefited from improved steel selling prices, favorable U.S. trade policies, including imported U.S. steel tariffs signed into order during the first half of 2018, and solid end market demand. Imports of finished steel have decreased from 27 percent of U.S. steel consumption in 2017 to approximately 23 percent of U.S. steel consumption in 2018. U.S. Steel restarted both of the blast furnaces at its Granite City Works facility during 2018.

Our Brazil cokemaking operations are located in Vitoria, Brazil, where we operate our ArcelorMittal Brazil cokemaking facility for a Brazilian subsidiary of ArcelorMittal S.A. Revenues from our Brazilian cokemaking facility are derived from licensing and operating fees, which include a fixed annual licensing fee, a licensing fee based upon the level of production required by our customer and full pass-through of the operating costs of the facility.

Logistics Operations

Our logistics business consists of Convent Marine Terminal (“CMT”), Kanawha River Terminal (“KRT”), SunCoke Lake Terminal (“Lake Terminal”) and Dismal River Terminal (“DRT”). CMT, located in Convent, Louisiana, is one of the largest export terminals on the U.S. Gulf Coast. CMT provides strategic access to seaborne markets for coal and other industrial materials. Supporting low-cost Illinois basin coal producers, the terminal provides loading and unloading services and has direct rail access and the current capability to transload 15 million tons annually with its top of the line ship loader. The facility is supported by long-term contracts with volume commitments covering 10 million tons of its current capacity as well as 350 thousand liquid tons. The facility also serves other merchant business including aggregates (crushed stone) and petroleum coke. CMT's efficient barge unloading capabilities complement its rail and truck offerings and provide the terminal with the ability to transload and mix a significantly broader variety of materials, including coal, petroleum coke and other materials from barges at its dock. KRT is a leading metallurgical and thermal coal mixing and handling terminal service provider with collective capacity to mix and transload 25 million tons annually through its operations in Ceredo and Belle, West Virginia. Lake Terminal is located in East Chicago, Indiana and provides coal handling and mixing services to our Indiana Harbor cokemaking operations. DRT was formed in 2016 to accommodate our Jewell cokemaking facility in Vansant, Virginia in its direct procurement of third-party coal.

Our logistics business has the collective capacity to mix and/or transload more than 40 million tons of coal and other aggregates annually and has storage capacity of approximately 3 million tons. Our terminals act as intermediaries between our customers and end users by providing transloading and mixing services. Materials are transported in numerous ways, including rail, truck, barge or ship. We do not take possession of materials handled but instead derive our revenues by providing handling and/or mixing services to our customers on a per ton basis. Revenues are recognized when services are provided as defined by customer contracts. See Note 18 to our consolidated financial statements for further discussion of our revenue recognition policies. Logistics services provided to our domestic cokemaking facilities are provided under contracts with terms equivalent to those of arm's-length transactions.

The financial performance of our logistics business is substantially dependent upon a limited number of customers. Our CMT customers are impacted by seaborne export market dynamics. Fluctuations in the benchmark price for coal delivery into northwest Europe, as referenced in the Argus/McCloskey's Coal Price Index report (“API2 index price”), as well as Newcastle index coal prices, as referenced in the Argus/McCloskey's Coal Price Index report (“API5 index price”), which reflect high-ash coal prices shipped from Australia, contribute to our customers' decisions to place tons into the export market and thus impact transloading volumes through our terminal facility. Our KRT terminals serve two primary domestic markets, metallurgical coal trade and thermal coal trade. Metallurgical markets are primarily impacted by steel prices and blast furnace operating levels whereas thermal markets are impacted by natural gas prices and electricity demand.

Strong API2 and API5 index prices continued to provide attractive economics for Illinois Basin and Northern Appalachian coal producers during 2018, which resulted in record volumes at our CMT facility. In 2018, the Mississippi River experienced near-historic water levels, which adversely impacted our barge unloading and our vessel loading activities at CMT. At KRT, domestic metallurgical and thermal market conditions and volumes were favorable in 2018 compared to 2017 due to increased demand from steel and utility customers. However, KRT volumes were suppressed during 2018 by rail availability due to strong demand for dry bulk products in the export market.

4

Seasonality

Our revenues in our cokemaking business and much of our logistics business are tied to long-term, take-or-pay contracts and as such, are not seasonal. However, our cokemaking profitability is tied to coal-to-coke yields, which improve in drier weather.  Accordingly, the coal-to-coke yield component of our profitability tends to be more favorable in the third quarter. Extreme weather may also challenge our operating costs and production in the winter months for our domestic coke business. KRT service demand fluctuates due to changes in the domestic electricity markets. Excessively hot summer weather or cold winter weather may increase commercial and residential needs for heat or air conditioning, which in turn may increase electricity usage and the demand for thermal coal and, therefore, may favorably impact our logistics business. Additionally, at CMT, service fluctuates with global thermal coal prices and end market demand. Activity is generally lower in the third quarter, typically due to lower European demand for heat. Operating costs at CMT are impacted by water levels on the Mississippi River, which are often higher in the spring months.

Raw Materials

Metallurgical coal is the principal raw material for our cokemaking operations. All of the metallurgical coal used to produce coke at our domestic cokemaking facilities is purchased from third-parties. We believe there is an adequate supply of metallurgical coal available in the U.S. and worldwide, and we have been able to supply coal to our domestic cokemaking facilities without any significant disruption in coke production.

Each ton of coke produced at our facilities requires approximately 1.4 tons of metallurgical coal. We purchased 5.9 million tons of metallurgical coal in 2018. Coal is generally purchased on an annual basis via one-year contracts with costs passed through to our customers in accordance with the applicable coke sales agreements. Occasionally, shortfalls in deliveries by coal suppliers require us to procure supplemental coal volumes. As with typical annual purchases, the cost of these supplemental purchases is also generally passed through to our customers. In 2019, certain of our coal contracts contain an option to reduce our commitment by up to 15 percent at the Company's discretion. Most coal procurement decisions are made through a coal committee structure with customer participation. The customer can generally exercise an overriding vote on most coal procurement decisions.

Transportation and Freight

For inbound transportation of coal purchases, our facilities that access a single rail provider have long-term transportation agreements, and where necessary, coal-mixing agreements that run concurrently with the associated coke sales agreement for the facility. At facilities with multiple transportation options, including rail and barge, we enter into short-term transportation contracts from year to year.

For coke sales, the point of delivery varies by agreement and facility. The destination for coke sales from our Jewell and Haverhill cokemaking facilities is generally designated by the customer and shipments are made by railcar under long-term transportation agreements. All delivery costs are passed through to the customers. At our Middletown, Indiana Harbor and Granite City cokemaking facilities, coke is delivered primarily by a conveyor belt leading to the customer’s blast furnace, with the customer responsible for additional transportation costs, if any. Most transportation and freight costs in our Logistics segment are paid by the customer directly to the transportation provider.

Research and Development and Intellectual Property and Proprietary Rights

Our research and development program seeks to improve existing and develop promising new cokemaking technologies and enhance our heat recovery processes. Over the years, this program has produced numerous patents related to our heat recovery coking design and operation, including patents for pollution control systems, oven pushing and charging mechanisms, oven flue gas control mechanisms and various others.

At Vitória, Brazil, where we operate one cokemaking facility on behalf of ArcelorMittal Brazil, we have intellectual property and licensing agreements in place for the entity’s use of our technology, under which we receive a per ton licensing fee as well as an annual licensing fee.

We are party to an omnibus agreement with the Partnership, which grants the Partnership a royalty-free license to use the name “SunCoke” and related trademarks. Additionally, the omnibus agreement grants the Partnership a non-exclusive right to use all of our current and future cokemaking and related technology necessary for their operations.

5

Competition

Cokemaking

The cokemaking business is highly competitive. Most of the world’s coke production capacity is owned by blast furnace steel companies utilizing by-product coke oven technology. The international merchant coke market is largely supplied by Chinese, Colombian and Ukrainian producers, among others, though it is difficult to maintain high quality coke in the export market, and when coupled with transportation costs, coke imports into the U.S. are often not economical.

The principal competitive factors affecting our cokemaking business include coke quality and price, reliability of supply, proximity to market, access to metallurgical coals and environmental performance. Our oven design and heat recovery technology play a role in all of these factors. Competitors include merchant coke producers as well as the cokemaking facilities owned and operated by blast furnace steel companies.

In the past, there have been technologies which have sought to produce carbonaceous substitutes for coke in the blast furnace. While none have proven commercially viable thus far, we monitor the development of competing technologies carefully. We also monitor ferrous technologies, such as direct reduced iron production ("DRI"), as these could indirectly impact our blast furnace customers.

We believe we are well-positioned to compete with other coke producers. Our Domestic Coke segment accounts for approximately 30 percent of the U.S. coke market capacity, excluding the capacity used to produce foundry coke. Current production from our cokemaking business is largely committed under long-term take-or-pay contracts. As a result, competition mainly affects our ability to obtain new contracts supporting development of additional cokemaking capacity, re-contracting existing facilities, as well as the sale of coke in the spot market. Our facilities were constructed using proven, industry-leading technology with many proprietary features allowing us to produce consistently higher quality coke than our competitors produce. Additionally, our technology allows us to produce heat that can be converted into steam or electrical power.

Logistics

The principal competitors of CMT are located on the U.S. Gulf Coast or U.S. East Coast. CMT is one of the largest export terminals on the U.S. Gulf Coast and provides strategic access to seaborne markets for coal and other bulk materials. Additionally, CMT is the largest bulk material terminal in the lower U.S. with direct rail access on the Canadian National Railway. In 2018, CMT accounted for approximately 47 percent of U.S. thermal coal exports from the U.S. Gulf Coast and approximately 20 percent of total U.S. thermal coal exports. CMT has a state-of-the-art ship loader, the largest of its kind in the world. We believe this ship loader has the fastest loading rate available in the Gulf Region and should allow our customers to benefit from lower shipping costs. Additionally, CMT has a strategic alliance with a company that performs barge unloading services for the terminal, which provides CMT with the ability to transload and mix a significantly broader variety of materials.

Our KRT competitors are generally located within 100 miles of our operations. KRT has fully automated and computer-controlled mixing capabilities that mix coal to within two percent accuracy of customer specifications. KRT also has the ability to provide pad storage and has access to both CSX and Norfolk Southern rail lines as well as the Ohio River system.

Lake Terminal and DRT provide coal handling and/or mixing services to our Indiana Harbor and Jewell cokemaking facilities, respectively, and therefore, do not have any competitors.

Employees

As of December 31, 2018, we have approximately 895 employees in the U.S. Approximately 40 percent of our domestic employees, principally at our cokemaking operations, are represented by the United Steelworkers union under various contracts. Additionally, approximately 3 percent of our domestic employees are represented by the International Union of Operating Engineers. While the labor agreement at our Indiana Harbor cokemaking facility expired on August 31, 2015, the parties mutually agreed to extend the terms of this agreement through August 31, 2018. Currently both parties are working under the term of the contract extension while negotiating a new agreement. We do not anticipate any work stoppages during the extended period of the agreement. The labor agreements at KRT, Lake Terminal and Haverhill will expire on April 30, 2019, June 30, 2019 and November 1, 2019, respectively. We will negotiate the renewal of these agreements in 2019 and do not anticipate any work stoppages.

As of December 31, 2018, we have approximately 285 employees at the cokemaking facility in Vitória, Brazil, all of whom are represented by a union under a labor agreement. During 2018, the labor agreement at our Vitoria, Brazil facility was renewed for an additional year, and it expires on October 31, 2019.

6

Safety

We are committed to maintaining a safe work environment and ensuring environmental compliance across all of our operations, as the health and safety of our employees and the communities in which we operate are paramount. We employ practices and conduct training to help ensure that our employees work safely. Furthermore, we utilize processes for managing and monitoring safety and environmental performance.

We have consistently operated within the top quartilesfor the U.S. Occupational Safety and Health Administration’s ("OSHA") recordable injury rates as measured and reported by the American Coke and Coal Chemicals Institute.

Legal and Regulatory Requirements

The following discussion summarizes the principal legal and regulatory requirements that we believe may significantly affect us.

Permitting and Bonding

• Permitting Process for Cokemaking Facilities. The permitting process for our cokemaking facilities is administered by the individual states. However, the main requirements for obtaining environmental construction and operating permits are found in the federal regulations. Once all requirements are satisfied, a state or local agency produces an initial draft permit. Generally, the facility reviews and comments on the initial draft. After accepting or rejecting the facility’s comments, the agency typically publishes a notice regarding the issuance of the draft permit and makes the permit and supporting documents available for public review and comment. A public hearing may be scheduled, and the EPA also has the opportunity to comment on the draft permit. The state or local agency responds to comments on the draft permit and may make revisions before a final construction permit is issued. A construction permit allows construction and commencement of operations of the facility and is generally valid for at least 18 months. Generally, construction commences during this period, while many states allow this period to be extended in certain situations. A facility's operating permit may be a state operating permit or a Title V operating permit.

• Air Quality. Our cokemaking facilities employ MACT standards designed to limit emissions of certain hazardous air pollutants. Specific MACT standards apply to door leaks, charging, oven pressure, pushing and quenching. Certain MACT standards for new cokemaking facilities were developed using test data from SunCoke's Jewell cokemaking facility located in Vansant, Virginia. Under applicable federal air quality regulations, permitting requirements may differ among facilities, depending upon whether the cokemaking facility will be located in an “attainment” area—i.e., one that meets the national ambient air quality standards (“NAAQS”) for certain pollutants, or in a “non-attainment” or "unclassifiable" area. The status of an area may change over time as new NAAQS standards are adopted, resulting in an area change from one status or classification to another. In an attainment area, the facility must install air pollution control equipment or employ BACT. In a non-attainment area, the facility must install air pollution control equipment or employ procedures that meet LAER standards. LAER standards are the most stringent emission limitation achieved in practice by existing facilities. Unlike the BACT analysis, cost is generally not considered as part of a LAER analysis, and emissions in a non-attainment area must be offset by emission reductions obtained from other sources.

• Stringent NAAQS for ambient nitrogen dioxide and sulfur dioxide went into effect in 2010. In July 2013, the EPA identified or "designated" as non-attainment 29 areas in 16 states where monitored air quality showed violations of the 2010 1-hour SO2 NAAQS. In August 2015, the EPA finalized a new rulemaking to assist in implementation of the primary 1-hour SO2 NAAQS that requires either additional monitoring, or modeling of ambient air SO2 levels in various areas including where certain of our facilities are located. By July 2016, states subject to this rulemaking were required to provide the EPA with either a modeling approach using existing emissions data, or a plan to undertake ambient air monitoring for SO2 to begin in 2017. For states that choose to install ambient air SO2 monitoring stations, after three years of data has been collected, or sometime in 2020, the EPA will evaluate this data relative to the appropriate attainment designation for the areas under the 1-hour SO2 NAAQS. For states that chose to model, designations were made by December 2017. This rulemaking required certain of our facilities to undertake this ambient air monitoring or modeling. In December 2017, EPA issued a final designation of attainment or unclassifiable for all areas where our facilities are located. These designations mean that no future action is required for the facilities with respect to SO2 emissions at this time. However, legal challenges to these designations are possible. If redesignated, we may be required

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to install additional pollution controls and incur greater costs of operating at those of our facilities located in areas that EPA determines to be non-attainment with the 1-hour SO2 NAAQS based on its evaluation of this data. In 2012, a NAAQS for fine particulate matter, or PM 2.5, went into effect. In January 2015, the areas where the Granite City and Indiana Harbor facilities are located were designated unclassifiable for PM 2.5, and the areas where the Haverhill and Jewell facilities are located were designated unclassifiable/attainment for PM 2.5. In April 2015, the area where the Middletown facility is located was designated unclassifiable/attainment for PM 2.5. In November 2015, the EPA revised the existing NAAQS for ground level ozone to make the standard more stringent. In January 2018, EPA designated the areas where the Haverhill and Jewell facilities are located as attainment/unclassifiable for ozone. In June 2018, EPA designated the areas where the Granite City, Indiana Harbor, and Middletown facilities are located as marginal nonattainment for ozone. Nonattainment designations under the new standards and any future more stringent standard for ozone have two impacts on permitting: (1) demonstrating compliance with the standard using dispersion modeling from a new facility will be more difficult; and (2) facilities operating in areas that become non-attainment areas due to the application of new standards may be required to install Reasonably Available Control Technology (“RACT”). A number of states have filed or joined suits to challenge the EPA’s new standard in court. While we are not able to determine the extent to which this new standard will impact our business at this time, it does have the potential to have a material impact on our operations and cost structure.

• The EPA adopted a rule in 2010 requiring a new facility that is a major source of greenhouse gases (“GHGs”) to install equipment or employ BACT procedures. Currently, there is little information on what may be acceptable as BACT to control GHGs (primarily carbon dioxide from our facilities), but the database and additional guidance may be enhanced in the future.

• Several states have additional requirements and standards other than those in the federal statutes and regulations. Many states have lists of “air toxics” with emission limitations determined by dispersion modeling. States also often have specific regulations that deal with visible emissions, odors and nuisance. In some cases, the state delegates some or all of these functions to local agencies.

• Wastewater and Stormwater. Our heat recovery cokemaking technology does not produce wastewater as is typically associated with by-product cokemaking. Our cokemaking facilities, in some cases, have wastewater discharge and stormwater permits.

• Waste. The primary solid waste product from our heat recovery cokemaking technology is calcium sulfate from flue gas desulfurization, which is generally taken to a solid waste landfill. The material from periodic cleaning of heat recovery steam generators has been disposed of as hazardous waste. On the whole, our heat recovery cokemaking process does not generate substantial quantities of hazardous waste.

• U.S. Endangered Species Act. The U.S. Endangered Species Act and certain counterpart state regulations are intended to protect species whose populations allow for categorization as either endangered or threatened. With respect to permitting additional cokemaking facilities, protection of endangered or threatened species may have the effect of prohibiting, limiting the extent of or placing permitting conditions on soil removal, road building and other activities in areas containing the affected species. Based on the species that have been designated as endangered or threatened on our properties and the current application of these laws and regulations, we do not believe that they are likely to have a material adverse effect on our operations.

• Permitting Process for Former Coal Mining Operations. The U.S. coal mining permit application process is initiated by collecting baseline data to adequately assess and model the pre-mine environmental condition of the permit area, including geologic data, soil and rock structures, cultural resources, soils, surface and ground water hydrology, and coal that we intend to mine. We use this data to develop a mine and reclamation plan, which incorporate provisions of the Surface Mining Control and Reclamation Act of 1977 (“SMCRA”), state programs and complementary environmental programs that impact coal mining. The permit application includes the mine and reclamation plan, documents defining ownership and agreements pertaining to coal, minerals, oil and gas, water rights, rights of way and surface land and documents required by the Office of Surface Mining Reclamation and Enforcement’s (“OSM’s”) Applicant Violator System. Once a permit application is submitted to the regulatory agency, it goes through a completeness and technical review before a public notice and comment period. Some SMCRA mine permits take over a year to prepare, depending on the size and complexity of the mine, and often take six months to two years to be issued. Regulatory authorities have considerable discretion in the timing of the permit issuance and the public has the right to

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comment on and otherwise engage in the permitting process, including through public hearings and intervention in the courts. SMCRA mine permits also take a significant period of time to be transferred.

• Bonding Requirements for Permits Related to Former Coal Mining Operations and Coal Terminals with Surface Mining Permits. Before a SMCRA permit or a surface mining permit is issued in West Virginia, a mine operator must submit a bond or other form of financial security to guarantee the payment and performance of certain long-term mine closure and reclamation obligations. The costs of these bonds or other forms of financial security have fluctuated in recent years and the market terms of surety bonds generally have become less favorable to those entities with legacy mining obligations or terminal operators and others with such permits. These changes in the terms of such bonds have been accompanied, at times, by a decrease in the number of companies willing to issue surety bonds. As of December 31, 2018, we have posted $10.3 million in surety bonds or other forms of financial security for reclamation purposes.

Regulation of Operations

• Clean Air Act. The Clean Air Act and similar state laws and regulations affect our cokemaking operations, primarily through permitting and/or emissions control requirements relating to particulate matter (“PM”) and sulfur dioxide (“SO2”) and MACT standards. The Clean Air Act air emissions programs that may affect our operations, directly or indirectly, include, but are not limited to: the Acid Rain Program; NAAQS implementation for SO2, PM and nitrogen oxides (“NOx”), lead ozone and carbon monoxide; GHG rules; the Clean Air Interstate Rule; MACT emissions limits for hazardous air pollutants; the Regional Haze Program; New Source Performance Standards (“NSPS”); and New Source Review. The Clean Air Act requires, among other things, the regulation of hazardous air pollutants through the development and promulgation of various industry-specific MACT standards. Our cokemaking facilities are subject to two categories of MACT standards. The first category applies to pushing and quenching. The second category applies to emissions from charging and coke oven doors. The EPA is required to make a risk-based determination for pushing and quenching emissions and determine whether additional emissions reductions are necessary. In 2016, EPA issued a request for information and testing to our cokemaking facilities and other companies as part of its residual risk and technology review of the MACT standard for pushing and quenching, and a technology review of the MACT standard for coke ovens and charging emissions. Testing was conducted by our cokemaking facilities in 2017, but the EPA has yet to publish or propose any residual risk standards; therefore, the impact of potential additional EPA regulation in this area cannot be estimated at this time.

• Terminal Operations. Our terminal operations located along waterways and the Gulf of Mexico are also governed by permitting requirements under the CWA and CAA. These terminals are subject to U.S. Coast Guard regulations and comparable state statutes regarding design, installation, construction, and management. Many such terminals owned and operated by other entities that are also used to transport coal and petcoke, including for export, have been pursued by environmental interest groups for alleged violations of their permits’ requirements, or have seen their efforts to obtain or renew such permits contested by such groups. While we believe that our operations are in material compliance with these permits, it is possible that such challenges or claims will be made against our operations in the future. Moreover, our terminal operations may be affected by the impacts of additional regulation on petcoke or on the mining of all types of coal and use of thermal coal for fuel, which is restricting supply in some markets and may reduce the volumes of coal that our terminals manage.

• Federal Energy Regulatory Commission. The Federal Energy Regulatory Commission (“FERC”) regulates the sales of electricity from our Haverhill and Middletown facilities, including the implementation of the Federal Power Act (“FPA”) and the Public Utility Regulatory Policies Act of 1978 (“PURPA”). The nature of the operations of the Haverhill and Middletown facilities makes each facility a qualifying facility under PURPA, which exempts the facilities and the Company from certain regulatory burdens, including the Public Utility Holding Company Act of 2005 (“PUHCA”), limited provisions of the FPA, and certain state laws and regulation. FERC has granted requests for authority to sell electricity from the Haverhill and Middletown facilities at market-based rates and the entities are subject to FERC’s market-based rate regulations, which require regular regulatory compliance filings.

• Clean Water Act of 1972. Although our cokemaking facilities generally do not have water discharge permits, the Clean Water Act (“CWA”) may affect our operations by requiring water quality standards generally and through the National Pollutant Discharge Elimination System (“NPDES”). Regular monitoring, reporting requirements and performance standards are requirements of NPDES permits that govern the discharge of pollutants into water. Discharges must either meet state water quality standards or be authorized through

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available regulatory processes such as alternate standards or variances. Additionally, through the CWA Section 401 certification program, states have approval authority over federal permits or licenses that might result in a discharge to their waters. Similarly, for permitting or any future water intake and/or discharge projects, our facilities could be subject to the Army Corps of Engineers Section 404 permitting process.

• Resource Conservation and Recovery Act. We may generate wastes, including “solid” wastes and “hazardous” wastes that are subject to the Resource Conservation and Recovery Act (“RCRA”) and comparable state statutes, although certain mining and mineral beneficiation wastes and certain wastes derived from the combustion of coal currently are exempt from regulation as hazardous wastes under RCRA. The EPA has limited the disposal options for certain wastes that are designated as hazardous wastes under RCRA. Furthermore, it is possible that certain wastes generated by our operations that currently are exempt from regulation as hazardous wastes may in the future be designated as hazardous wastes, and therefore be subject to more rigorous and costly management, disposal and clean-up requirements. Certain of our wastes are also subject to Department of Transportation regulations for shipping of materials.

• Climate Change Legislation and Regulations. Our facilities are presently subject to the GHG reporting rule, which obligates us to report annual emissions of GHGs. The EPA also finalized a rule in 2010 requiring a new facility that is a major source of GHGs to install equipment or employ BACT procedures. In 2014, the Supreme Court issued an opinion holding that although EPA may not treat GHGs as a pollutant for the purpose of determining whether a source must obtain a PSD or Title V permit, EPA may continue to require GHG limitations in permits for sources classified as major based on their emission of other pollutants. Currently there is little information as to what may constitute BACT for GHG in most industries. Under this rule, certain modifications to our facilities could subject us to the additional permitting and other obligations relative to emissions of GHGs under the New Source Review/Prevention of Significant Deterioration ("NSR/PSD") and Title V programs of the Clean Air Act based on whether the facility triggered NSR/PSD because of emissions of another pollutant such as SO2, NOx, PM, ozone or lead. The EPA has engaged in rulemaking to regulate GHG emissions from existing and new coal fired power plants, and we expect continued legal challenges to this rulemaking and any future rulemaking for other industries. For instance, in August 2015, the EPA issued its final Clean Power Plan rules establishing carbon pollution standards for power plants. In February 2016, the U.S. Supreme Court granted a stay of the implementation of the Clean Power Plan before the U.S. Court of Appeals for the District of Columbia (“D.C. Circuit”) issued a decision on the rule. By its terms, this stay will remain in effect throughout the pendency of the appeals process including at the D.C. Circuit and the Supreme Court through any certiorari petition that may be granted. In October 2017, the EPA proposed to repeal the Clean Power Plan ("CPP") although the final outcome of this proposal and the pending litigation regarding the CPP is uncertain at this time. In connection with this proposed repeal, EPA issued an Advanced Notice of Proposed Rulemaking ("ANPRM") in December 2017 regarding emission guidelines to limit GHG emissions from existing electric utility generating units. The ANPRM seeks comment regarding what the EPA should include in a potential new, existing source regulation of GHG emissions under the Clean Air Act that the EPA may propose. On October 9, 2018, the U.S. Supreme Court rejected any further challenges to the decision to repeal the Clean Power Plan. Although EPA proposed the Affordable Clean Energy (“ACE”) rule as a replacement for the CPP in August 2018, the ACE rule has not yet been finalized.

Currently, we do not anticipate these new or existing power plan GHG rules to apply directly to our facilities. However, the impact current and future GHG-related legislation and regulations have on us will depend on a number of factors, including whether GHG sources in multiple sectors of the economy are regulated, the overall GHG emissions cap level, the degree to which GHG offsets are allowed, the allocation of emission allowances to specific sources, actions by the states in implementing these requirements and the indirect impact of carbon regulation on coal prices. We may not recover the costs related to compliance with regulatory requirements imposed on us from our customers due to limitations in our agreements. The imposition of a carbon tax or similar regulation could materially and adversely affect our revenues. Collectively, these requirements along with restrictions and requirements regarding the mining of all types of coal may reduce the volumes of coal that we manage and may ultimately adversely impact our revenues. Depending on whether another rule is promulgated in the future, it could increase the demand for natural gas-generated electricity.

• Mine Improvement and New Emergency Response Act of 2006. The Mine Improvement and New Emergency Response Act of 2006 (the “Miner Act”), has increased significantly the enforcement of safety and health standards and imposed safety and health standards on all aspects of mining operations. There also has been a significant increase in the dollar penalties assessed for citations issued.

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• Safety. Our facilities are subject to regulation by OSHA and other agencies with standards designed to ensure worker safety. As noted above, we have consistently operated within the top quartiles for OSHA’s recordable injury rates as measured and reported by the American Coke and Coal Chemicals Institute.

• Security. CMT is subject to regulation by the U.S. Coast Guard pursuant to the Maritime Transportation Security Act. We have an internal inspection program designed to monitor and ensure compliance by CMT with these requirements. We believe that we are in material compliance with all applicable laws and regulations regarding the security of the facility.

Reclamation and Remediation

• Surface Mining Control and Reclamation Act of 1977. The SMCRA established comprehensive operational, environmental, reclamation and closure standards for all aspects of U.S. surface mining as well as many aspects of deep mining. Where state regulatory agencies have adopted federal mining programs under SMCRA, the state becomes the regulatory authority, and states that operate federally approved state programs may impose standards that are more stringent than the requirements of SMCRA. Permitting under SMCRA generally has become more difficult in recent years, which adversely affects the cost and availability of coal. The Abandoned Mine Land Fund, which is part of SMCRA, assesses a fee on all coal produced in the U.S. From October 1, 2007 through September 30, 2012, the fee was $0.315 per ton of surface-mined coal and $0.135 per ton of underground mined coal. From October 1, 2012 through September 30, 2021, the fee has been reduced to $0.28 per ton of surface-mined coal and $0.12 per ton of underground mined coal. Our reclamation obligations under applicable environmental laws could be substantial. Under accounting principles generally accepted in the U.S. ("GAAP"), we are required to account for the costs related to the closure of mines and the reclamation of the land upon exhaustion of coal reserves. The fair value of an asset retirement obligation is recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. The present value of the estimated asset retirement costs is capitalized as part of the carrying amount of the long-lived asset. At December 31, 2018, we had an asset retirement obligation of $4.3 million related to estimated mine reclamation costs. The amounts recorded are dependent upon a number of variables, including the estimated future retirement costs, inflation rates, and the assumed credit-adjusted interest rates. Our future operating results would be adversely affected if these accruals were determined to be insufficient. These obligations are unfunded. Further, although specific criteria varies from state to state as to what constitutes an “owner” or “controller” relationship, under SMCRA the responsibility for reclamation or remediation, unabated violations, unpaid civil penalties and unpaid reclamation fees of independent contract mine operators can be imputed to other companies which are deemed, according to the regulations, to have “owned” or “controlled” the contract mine operator. Sanctions are quite severe and can include being denied new permits, permit amendments, permit revisions and revocation or suspension of permits issued since the violation or penalty or fee due date.

• Black Lung Benefits Revenue Act of 1977 and Black Lung Benefits Reform Act of 1977, as amended in 1981. Under these laws, each U.S. coal mine operator must pay federal black lung benefits and medical expenses to claimants who are current and former employees and last worked for the operator after July 1, 1973. The Patient Protection and Affordable Care Act (“PPACA”), which was implemented in 2010, amended previous legislation and provides for the automatic extension of awarded lifetime benefits to surviving spouses and changes the legal criteria used to assess and award claims. Our obligation related to black lung benefits at December 31, 2018 was $49.4 million and was estimated based on various assumptions, including actuarial estimates, discount rates, number of active claims, changes in health care costs and the impact of PPACA.

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• Comprehensive Environmental Response, Compensation, and Liability Act. Under the Comprehensive Environmental Response, Compensation, and Liability Act (“CERCLA”), also known as Superfund, and similar state laws, responsibility for the entire cost of clean-up of a contaminated site, as well as natural resource damages, can be imposed upon current or former site owners or operators, or upon any party who released one or more designated “hazardous substances” at the site, regardless of the lawfulness of the original activities that led to the contamination. In the course of our operations we may have generated and may generate wastes that fall within CERCLA’s definition of hazardous substances. We also may be an owner or operator of facilities at which hazardous substances have been released by previous owners or operators. Under CERCLA, we may be responsible for all or part of the costs of cleaning up facilities at which such substances have been released and for natural resource damages. We also must comply with reporting requirements under the Emergency Planning and Community Right-to-Know Act and the Toxic Substances Control Act.

Environmental Matters and Compliance

Our failure to comply with the aforementioned requirements may result in the assessment of administrative, civil and criminal penalties, the imposition of clean-up and site restoration costs and liens, the issuance of injunctions to limit or cease operations, the suspension or revocation of permits and other enforcement measures that could have the effect of limiting production from our operations. Please see Note 13 to our consolidated financial statements for a discussion of the Notices of Violation ("NOVs") issued by the EPA and state regulators for our Haverhill, Granite City, and Indiana Harbor cokemaking facilities.

Many other legal and administrative proceedings are pending or may be brought against us arising out of our current and past operations, including matters related to commercial and tax disputes, product liability, antitrust, employment claims, natural resource damage claims, premises-liability claims, allegations of exposures of third-parties to toxic substances and general environmental claims. Although the ultimate outcome of these proceedings cannot be ascertained at this time, it is reasonably possible that some of them could be resolved unfavorably to us. Management of the Company believes that any liability which may arise from such matters would not be material in relation to the financial position, results of operations or cash flows of the Company at December 31, 2018.

IRS Final Regulations on Qualifying Income

Section 7704 of the Internal Revenue Code (the "Code") provides that a publicly-traded partnership will be treated as a corporation for federal income tax purposes. However, if 90 percent or more of a partnership’s gross income for every taxable year it is publicly-traded consists of “qualifying income,” the publicly-traded partnership may continue to be treated as a partnership for federal income tax purposes.

At the time of the Partnership’s initial public offering, in January 2013, the Partnership believed, and received a legal opinion to the effect, that income from its cokemaking operations would be treated as generating qualifying income under the Code.  The Company and counsel believed at the time that this view was based on the correct interpretation of the Code and the legislative history of the relevant Code section, and since that time continued to believe that income from its cokemaking operations is qualifying income. 

On January 19, 2017, the Treasury Department and the Internal Revenue Service ("IRS") issued qualifying income regulations (the "Final Regulations") on the treatment of income from natural resource activities of publicly traded partnerships as qualifying income for purposes of the Code.  The Final Regulations were published in the Federal Register on January 24, 2017, and apply to taxable years beginning after January 19, 2017.  Under the Final Regulations, the Partnership’s cokemaking operations have been excluded from the definition of activities that generate qualifying income. 

The Final Regulations provide that if a partnership’s income from non-qualifying operations “was qualifying income under the statute as reasonably interpreted,” then that partnership will have a transition period ending on the last day of the partnership’s taxable year that included the date that is ten years after the date the Final Regulations are published in the Federal Register (i.e., December 31, 2027), during which it can treat income from such activities as qualifying income. After conferring with outside counsel, the Partnership and we are of the view that its interpretation was reasonable in concluding that the Partnership’s income from cokemaking was qualifying income, and that the Partnership will benefit from the ten-year transition period. Subsequent to the transition period, certain cokemaking entities in the Partnership will become taxable as corporations. Also see “Part I. Item 1A. Risk Factors" and Note 5 to our consolidated financial statements.

The present federal income tax treatment of publicly traded partnerships, including the Partnership, or an investment in its common units, may be modified by administrative, legislative or judicial interpretation at any time. Any

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modification to the federal income tax laws and interpretations thereof may or may not be applied retroactively. Moreover, any such modification could make it more difficult or impossible for the Partnership to meet the exception which allows publicly traded partnerships that generate qualifying income to be treated as partnerships (rather than corporations) for U.S. federal income tax purposes, affect or cause us to change our business activities, or affect the tax consequences of an investment in its common units. For example, as discussed above, on January 24, 2017, Final Regulations were published in the Federal Register and apply to taxable years beginning on or after January 19, 2017. The Final Regulations will likely affect the ability of partnerships to continue to qualify as a publicly traded partnership.

Available Information

We make available free of charge on our website, www.suncoke.com, our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and any amendments to such reports as soon as reasonably practicable after such materials are electronically filed with, or furnished to, the Securities and Exchange Commission ("SEC"). The SEC maintains an Internet site (www.sec.gov) that contains our electronically filed information. Our website also includes our Code of Business Conduct and Ethics, our Governance Guidelines, our Related Persons Transaction Policy and the charter of our Audit Committee.

A copy of any of these documents will be provided without charge upon written request to Investor Relations, SunCoke Energy, Inc., 1011 Warrenville Road, Suite 600, Lisle, Illinois 60532.

Executive Officers of the Registrant

Our executive officers and their ages as of February 15, 2019, were as follows:

Name	Age	Position
Michael G. Rippey	61	President and Chief Executive Officer
Fay West	49	Senior Vice President and Chief Financial Officer
Katherine T. Gates	42	Senior Vice President, General Counsel and Chief Compliance Officer
P. Michael Hardesty	56	Senior Vice President, Commercial Operations, Business Development, Terminals and International Coke
Allison S. Lausas	39	Vice President, Finance and Controller
Gary P. Yeaw	61	Senior Vice President of Human Resources

Michael G. Rippey. Mr. Rippey was appointed President and Chief Executive Officer of SunCoke Energy, Inc. on December 1, 2017. Also on December 1, 2017, Mr. Rippey was named President and Chief Executive Officer and appointed as Chairman of the Board of SunCoke Energy Partners, GP LLC. Prior to joining SunCoke Energy, Inc., he served as Senior Advisor to Nippon Steel & Sumitomo Metal Corporation (a leading global steelmaker), since 2015. From 2014 to 2015, he served as Chairman of the Board of ArcelorMittal USA LLC (a major domestic steel manufacturer), and from August 2006 through October 2014, he was ArcelorMittal USA LLC’s President and Chief Executive Officer. Mr. Rippey currently serves on the Board of Directors of Olympic Steel, Inc. (NASDAQ: ZEUS), a major steel service center headquartered in Ohio, where he is a member of the Nominating Committee, and serves as Chair of the Audit and Compliance Committee.

Fay West. Ms. West was appointed as Senior Vice President and Chief Financial Officer of SunCoke Energy, Inc. in October 2014. Prior to that time, she served as Vice President and Controller of SunCoke Energy, Inc. since February 2011. In addition, Ms. West was named Vice President and Controller and appointed to the Board of Directors of SunCoke Energy Partners GP LLC, the general partner of SunCoke Energy Partners, L.P. in July 2012. Prior to joining SunCoke Energy, Inc., she was Assistant Controller at United Continental Holdings, Inc. (an airline holding company) from April 2010 to January 2011. She was Vice President, Accounting and Financial Reporting for PepsiAmericas, Inc. (a manufacturer and distributor of beverage products) from December 2006 through March 2010 and Director of Financial Reporting from December 2005 to December 2006. Ms. West is a director of Quaker Chemical Corporation (a leading manufacturer and supplier of process fluids and specialty chemicals) where she also serves as the Chair of the Audit Committee, and is a member of the Governance Committee.

Katherine T. Gates. Ms. Gates was appointed Senior Vice President, General Counsel and Chief Compliance Officer, effective October 22, 2015. At that time, she also was appointed as a Director of SunCoke Energy Partners GP, LLC. Ms. Gates joined SunCoke in February 2013 as Senior Health, Environment and Safety Counsel. She was promoted to Vice President and Assistant General Counsel in July 2014, where she focused on litigation, regulatory and commercial matters. Ms. Gates began her legal career in private practice as a Partner at Beveridge & Diamond, P.C. She served on the

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firm’s Management Committee, where she addressed budget, compensation, commercial, and other issues. Ms. Gates also co-chaired the civil litigation section of the firm’s Litigation Practice Group.

P. Michael Hardesty. Mr. Hardesty was appointed Senior Vice President, Commercial Operations, Business Development, Terminals and International Coke of SunCoke Energy, Inc., effective October 1, 2015. At that time, he also was appointed as a Director of SunCoke Energy Partners GP, LLC. Mr. Hardesty joined SunCoke Energy, Inc. in 2011 as Senior Vice President, Sales and Commercial Operations, and has more than 30 years of experience in the mining industry. Before joining SunCoke, Mr. Hardesty served as Senior Vice President for International Coal Group, Inc. (“ICG”), where he was responsible for leading the sales and marketing functions and was a key member of the executive management team. Prior to ICG, Mr. Hardesty served as Vice President of Commercial Optimization at Arch Coal, where he developed and executed trade strategies, optimized production output and directed coal purchasing activities. He is a past board member and Secretary-Treasurer of the Putnam County Development Authority in West Virginia.

Allison S. Lausas. Ms. Lausas was appointed Vice President, Finance and Controller of both SunCoke Energy, Inc. and SunCoke Energy Partners GP LLC, in May 2018. Prior to that, from October 2014 to May 2018, Ms. Lausas was Vice President and Controller of both companies, and she served as Assistant Controller prior to 2014. Prior to joining SunCoke Energy, Inc., she worked as an auditor at KPMG LLP, an audit, advisory and tax services firm, from 2002 to 2011, where she served both public and private corporations in the consumer and industrial markets.

Gary P. Yeaw. Mr. Yeaw was appointed Senior Vice President, Human Resources of SunCoke Energy, Inc. on November 1, 2015. Prior to that, he was Vice President, Human Resources. Mr. Yeaw leads the human resources function at SunCoke Energy, Inc., and is responsible for key organizational activities. Prior to joining SunCoke Energy, Inc., he was Executive Vice President, Human Resources and Communications for Chemtura Corporation. Mr. Yeaw also served as Vice President, Human Resources for American Standard Companies, as well as Vice President, Human Resources Operational Excellence in charge of global benefit programs, labor relations, HR systems and employee services. Mr. Yeaw holds professional designations as a Senior Human Resources Professional, Certified Compensation Professional and was a charter member of the International Society of Employee Benefits Specialists.

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Item 1A. Risk Factors

In addition to the other information included in this Annual Report on Form 10-K, the following risk factors should be considered in evaluating our business and future prospects. These risk factors represent what we believe to be the known material risk factors with respect to us and our business. Our business, operating results, cash flows and financial condition are subject to these risks and uncertainties, any of which could cause actual results to vary materially from recent results or from anticipated future results.

These risks are not the only risks we face. Additional risks and uncertainties not currently known to us, or that we currently deem to be immaterial also may materially and adversely affect our business, financial condition, or results of operations.

Risks Inherent in Our Business and Industry

Sustained uncertainty in financial markets, or unfavorable economic conditions in the industries in which our customers operate, may lead to a reduction in the demand for our products and services, and adversely impact our cash flows, financial position or results of operations.

Sustained volatility and disruption in worldwide capital and credit markets in the U.S. and globally could restrict our ability to access the capital market at a time when we would like, or need, to raise capital for our business including for potential acquisitions, or other growth opportunities.

Deteriorating or unfavorable economic conditions in the industries in which our customers operate, such as steelmaking and electric power generation, may lead to reduced demand for steel products, coal, and other bulk commodities which, in turn, could adversely affect the demand for our products and services and negatively impact the revenues, margins and profitability of our business.

Additionally, the tightening of credit, or lack of credit availability to our customers, could adversely affect our ability to collect our trade receivables. We also are exposed to the credit risk of our coke and logistics customers, and any significant unanticipated deterioration of their creditworthiness and resulting increase in nonpayment or nonperformance by them could have a material adverse effect on the cash flows and/or results of our operations.

Adverse developments at our cokemaking and/or logistics operations, including equipment failures or deterioration of assets, may lead to production curtailments, shutdowns, impairments, or additional expenditures, which could have a material adverse effect on our results of operations.

Our cokemaking and logistics operations are subject to significant hazards and risks that include, but are not limited to, equipment malfunction, explosions, fires and the effects of severe weather conditions and extreme temperatures, any of which could result in production and transportation difficulties and disruptions, permit non-compliance, pollution, personal injury or wrongful death claims and other damage to our properties and the property of others.

Adverse developments at our cokemaking facilities could significantly disrupt our coke, steam and/or electricity production and our ability to supply coke, steam, and/or electricity to our customers. Adverse developments at our logistics operations could significantly disrupt our ability to provide handling, mixing, storage, terminalling, transloading and/or transportation services, of coal and other dry and liquid bulk commodities, to our customers. Any sustained disruption at our cokemaking and/or logistics operations could have a material adverse effect on our results of operations.

There is a risk of mechanical failure of our equipment both in the normal course of operations and following unforeseen events. Our cokemaking and logistics operations depend upon critical pieces of equipment that occasionally may be out of service for scheduled upgrades or maintenance or as a result of unanticipated failures. Our facilities are subject to equipment failures and the risk of catastrophic loss due to unanticipated events such as fires, accidents or violent weather conditions or extreme temperatures. As a result, we may experience interruptions in our processing and production capabilities, which could have a material adverse effect on our results of operations and financial condition. In particular, to the extent a disruption leads to our failure to maintain the temperature inside our coke oven batteries, we may not be able to maintain the integrity of the ovens or to continue operation of such coke ovens, which could adversely affect our ability to meet our customers’ requirements for coke and, in some cases, electricity and/or steam.

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Assets and equipment critical to the operations of our cokemaking and logistics operations also may deteriorate or become depleted materially sooner than we currently estimate. Such deterioration of assets may result in additional maintenance spending or additional capital expenditures. If these assets do not generate the amount of future cash flows that we expect, and we are not able to execute on capital maintenance or procure replacement assets in an economically feasible manner, our future results of operations may be materially and adversely affected.

Impairment in the carrying value of long-lived assets and goodwill could adversely affect our business and results of operations.

We have a significant amount of long-lived assets and goodwill on our Consolidated Balance Sheets. Under generally accepted accounting principles, long-lived assets must be reviewed for impairment whenever adverse events or changes in circumstances indicate a possible impairment. We are required to perform impairment tests on our assets whenever events or changes in circumstances lead to a reduction of the estimated useful life or estimated future cash flows that would indicate that the carrying amount may not be recoverable or whenever management’s plans change with respect to those assets.

If business conditions or other factors cause profitability and cash flows to decline, we may be required to record non-cash impairment charges. Goodwill must be evaluated for impairment annually or more frequently if events indicate it is warranted. If the carrying value of our reporting units exceeds their current fair value as determined based on the discounted future cash flows of the related business, the goodwill is considered impaired and is reduced to fair value by a non-cash charge to earnings.

Events and conditions that could result in impairment in the value of our long-lived assets and goodwill include: the impact of a downturn in the global economy, competition, advances in technology, adverse changes in the regulatory environment, and other factors leading to a reduction in expected long-term sales or profitability, or a significant decline in the trading price of our common stock or market capitalization, lower future cash flows, slower industry growth rates and other changes in the industries in which we or our customers operate.

The financial performance of our cokemaking and logistics businesses is substantially dependent upon a limited number of customers, and the loss of these customers, or any failure by them to perform under their contracts with us, could materially and adversely affect our financial condition, permit compliance, results of operations and cash flows.

Substantially all of our coke sales currently are made pursuant to long-term contracts with AM USA, U.S. Steel and AK Steel, and we expect these three customers to continue to account for a significant portion of our revenues for the foreseeable future. In our logistics business, a significant portion of our revenues and cash flows are derived from long-term contracts with Foresight Energy LLC and Murray American Coal, Inc. at CMT, and we expect these two customers to continue to account for a significant portion of the revenues of our logistics business for the foreseeable future.

We are subject to the credit risk of our major customers and other parties. If we fail to adequately assess the creditworthiness of existing or future customers or unanticipated deterioration of their creditworthiness, any resulting increase in nonpayment or nonperformance by them could have a material adverse effect on our cash flows, financial position or results of operations. During periods of weak demand for steel or coal, our customers may experience significant reductions in their operations, or substantial declines in the prices of the steel, or coal products, they sell. These and other factors such as labor relations or bankruptcy filings may lead certain of our customers to seek renegotiation or cancellation of their existing contractual commitments to us, or reduce their utilization of our services.

The loss of any of these customers (or financial difficulties at any of these customers, which result in nonpayment or nonperformance) could have a significant adverse effect on our business. If one or more of these customers were to significantly reduce its purchases of coke or logistics services from us without a make-whole payment, or default on their agreements with us, or terminate or fail to renew their agreements with us, or if we were unable to sell such coke or logistics services to these customers on terms as favorable to us as the terms under our current agreements, our cash flows, financial position, permit compliance, or results of operations could be materially and adversely affected.

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Our cokemaking and logistics businesses are subject to operating risks, some of which are beyond our control, that could result in a material increase in our operating expenses.

Factors beyond our control could disrupt our cokemaking and logistics operations, adversely affect our ability to service the needs of our customers, and increase our operating costs, all of which could have a material adverse effect on our results of operations. Such factors could include:

• geological, hydrologic, or other conditions that may cause damage to infrastructure or personnel;

• fire, explosion, or other major incident causing injury to personnel and/or equipment, that causes a cessation, or significant curtailment, of all or part of our cokemaking or logics operations at a site for a period of time;

• processing and plant equipment failures, operating hazards and unexpected maintenance problems affecting our cokemaking or logistics operations, or our customers;

• adverse weather and natural disasters, such as severe winds, heavy rains or snow, flooding, extreme temperatures and other natural events affecting our cokemaking or logistics operations, transportation, or our customers; and

• possible legal challenges to the renewal of key permits, which may lead to their renewal on terms that restrict our cokemaking or logistics operations, or impose additional costs on us.

If any of these conditions or events occur, our cokemaking or logistics operations may be disrupted, operating costs could increase significantly, and we could incur substantial losses. Such disruptions in our operations could materially and adversely affect our financial condition, or results of operations.

We face competition, both in our cokemaking operations and in our logistics business, which has the potential to reduce demand for our products and services, and that could have an adverse effect on our results of operations.

We face competition, both in our cokemaking operations and in our logistics business:

• Cokemaking operations: Historically, coke has been used as a main input in the production of steel in blast furnaces. However, some blast furnace operators have relied upon natural gas, pulverized coal, and/or other coke substitutes. Many steelmakers also are exploring alternatives to blast furnace technology that require less or no use of coke. For example, electric arc furnace technology is a commercially proven process widely used in the U.S. As these alternative processes for production of steel become more widespread, the demand for coke, including the coke we produce, may be significantly reduced. We also face competition from alternative cokemaking technologies, including both by-product and heat recovery technologies. As these technologies improve and as new technologies are developed, competition in the cokemaking industry may intensify. As alternative processes for production of steel become more widespread, the demand for coke, including the coke we produce, may be significantly reduced.

• Logistics business: Decreased throughput and utilization of our logistics assets could result indirectly due to competition in the electrical power generation business from abundant and relatively inexpensive supplies of natural gas displacing thermal coal as a fuel for electrical power generation by utility companies. In addition, competition in the steel industry from processes such as electric arc furnaces, or blast furnace injection of pulverized coal or natural gas, may reduce the demand for metallurgical coals processed through our logistics facilities. In the future, additional coal handling facilities and terminals with rail and/or barge access may be constructed in the Eastern U.S. Such additional facilities could compete directly with us in specific markets now served by our logistics business. Certain coal mining companies and independent terminal operators in some areas may compete directly with our logistics facilities. In some markets, trucks may competitively deliver mined coal to certain shorter-haul destinations, resulting in reduced utilization of existing terminal capacity.

Such competition could reduce demand for our products and services, thus having a material and adverse effect on our results of operations.

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We are subject to extensive laws and regulations, which may increase our cost of doing business and have an adverse effect on our cash flows, financial position or results of operations.

Our operations are subject to strict regulation by federal, state and local authorities with respect to: discharges of substances into the air and water; emissions of greenhouse gases, or GHG, compliance with the NAAQS, management and disposal of hazardous substances and wastes, cleanup of contaminated sites, protection of groundwater quality and availability, protection of plants and wildlife, reclamation and restoration of properties after completion of mining or drilling, installation of safety equipment in our facilities, sales of electric power, and protection of employee health and safety. Complying with these and other regulatory requirements, including the terms of our permits, can be costly and time-consuming, and may hinder operations. In addition, these requirements are complex, change frequently and have become more stringent over time. Regulatory requirements may change in the future in a manner that could result in substantially increased capital, operating and compliance costs, and could have a material adverse effect on our business.

Failure to comply with applicable laws, regulations or permits may result in the assessment of administrative, civil and criminal penalties, the imposition of cleanup and site restoration costs and liens, the issuance of injunctions to limit or cease operations, the suspension or revocation of permits and other enforcement measures that could cause delays in permitting or development of projects or materially limit, or increase the cost of, our operations. We may not have been, or may not be, at all times, in complete compliance with all such requirements, and we may incur material costs or liabilities in connection with such requirements, or in connection with remediation at sites we own, or third-party sites where it has been alleged that we have liability, in excess of the amounts we have accrued. For a description of certain environmental laws and matters applicable to us, see “Item 1. Business-Legal and Regulatory Requirements.”

We may be unable to obtain, maintain or renew permits or leases necessary for our operations, which could materially reduce our production, cash flows or profitability.

Our cokemaking and logistics operations require us to obtain a number of permits that impose strict regulations on various environmental and operational matters. These, as well as our facilities and operations (including our generation of electricity), require permits issued by various federal, state and local agencies and regulatory bodies. The permitting rules, and the interpretations of these rules, are complex, change frequently, and are often subject to discretionary interpretations by our regulators, all of which may make compliance more difficult or impractical, and may possibly preclude the continuance of ongoing operations or the development of future cokemaking and/or logistics facilities. Non-governmental organizations, environmental groups and individuals have certain rights to engage in the permitting process, and may comment upon, or object to, the requested permits. Such persons also have the right to bring citizen’s lawsuits to challenge the issuance of permits, or the validity of environmental impact statements related thereto. If any permits or leases are not issued or renewed in a timely fashion or at all, or if permits issued or renewed are conditioned in a manner that restricts our ability to efficiently and economically conduct our operations, our cash flows or profitability could be materially and adversely affected.

We may incur costs and liabilities resulting from claims for damages to property or injury to persons arising from our operations, and such costs and liabilities could have a material and adverse effect on our financial condition or results of operations.

Our success depends, in part, on the quality, efficacy and safety of our products and services. If our operations do not meet applicable safety standards, or our products or services are found to be unsafe, our relationships with customers could suffer and we could lose business or become subject to liability or claims. In addition, our cokemaking and logistics operations have inherent safety risks that may give rise to events resulting in death, injury, or property loss to employees, customers, or unaffiliated third parties. Depending upon the nature and severity of such events, we could be exposed to significant financial loss, reputational damage, potential civil or criminal government or other regulatory enforcement actions, or private litigation, the settlement or outcome of which could have a material and adverse effect on our financial condition or results of operations.

Our businesses are subject to inherent risks, some for which we maintain third party insurance and some for which we self-insure. We may incur losses and be subject to liability claims that could have a material adverse effect on our financial condition, results of operations or cash flows.

We maintain insurance policies that provide limited coverage for some, but not all, potential risks and liabilities associated with our business. We may not obtain insurance if we believe the cost of available insurance is excessive relative to the risks presented. As a result of market conditions, premiums and deductibles for certain insurance policies can increase substantially, and in some instances, certain insurance may become unavailable or available only for reduced amounts of coverage. As a result, we may not be able to renew our existing insurance policies or procure other desirable insurance on commercially reasonable terms, if at all. In addition, certain risks, such as certain environmental and pollution

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risks, and certain cybersecurity risks, generally are not fully insurable. We must compensate employees for work-related injuries. If we do not make adequate provision for our workers' compensation liabilities, or we are pursued for applicable sanctions, costs, and liabilities, our operations and our profitability could be adversely affected. Even where insurance coverage applies, insurers may contest their obligations to make payments. Our financial condition, results of operations and cash flows could be materially and adversely affected by losses and liabilities from un-insured or under-insured events, as well as by delays in the payment of insurance proceeds, or the failure by insurers to make payments.

Divestitures and other significant transactions may adversely affect our business. In particular, if we are unable to realize the anticipated benefits from such transactions, or are unable to conclude such transactions upon favorable terms, our financial condition, results of operations or cash flows could be adversely affected.

We regularly review strategic opportunities to further our business objectives, and may eliminate assets that do not meet our return-on-investment criteria. If we are unable to complete such divestitures or other transactions upon favorable terms, or in a timely manner, or if the market conditions assumed in our project economics deteriorate, our financial condition, results of operations or cash flows could be adversely affected.

The anticipated benefits of divestitures and other strategic transactions may not be realized, or may be realized more slowly than we expected. Such transactions also could result in a number of financial consequences having a material effect on our results of operations and our financial position, including reduced cash balances; higher fixed expenses; the incurrence of debt and contingent liabilities (including indemnification obligations); restructuring charges; loss of customers, suppliers, distributors, licensors or employees; legal, accounting and advisory fees; and impairment charges.

We may not be able to successfully implement our growth strategies or plans, and we may experience significant risks associated with future acquisitions and/or investments. If we are unable to execute our strategic plans, whether as a result of unfavorable market conditions in the industries in which our customers operate, or otherwise, our future results of operations could be materially and adversely affected.

A portion of our strategy to grow our business is dependent upon our ability to acquire and operate new assets that result in an increase in our earnings. We may not derive the financial returns we expect on our investment in such additional assets or such operations may not be profitable. We cannot predict the effect that any failed expansion may have on our core businesses. The success of our future acquisitions and/or investments will depend substantially on the accuracy of our analysis concerning such businesses and our ability to complete such acquisitions or investments on favorable terms, as well as to finance such acquisitions or investments and to integrate the acquired operations successfully with existing operations. Antitrust and other laws may prevent us from completing acquisitions. If we are not able to execute our strategic plans effectively, or successfully integrate new operations, whether as a result of unfavorable market conditions in the industries in which our customers operate, or otherwise, our business reputation could suffer and future results of operations could be materially and adversely affected.

We may experience significant risks associated with future acquisitions and/or investments.

The success of our future acquisitions and/or investments will depend substantially on the accuracy of our analysis concerning such businesses and our ability to complete such acquisitions or investments on favorable terms, as well as to finance such acquisitions or investments and to integrate the acquired operations successfully with existing operations. Antitrust and other laws may prevent us from completing acquisitions. If we are unable to integrate new operations successfully, our financial results and business reputation could suffer.

Risks associated with acquisitions include the diversion of management’s attention from other business concerns, the potential loss of key employees and customers of the acquired business, the possible assumption of unknown liabilities, potential disputes with the sellers, and the inherent risks in entering markets or lines of business in which we have limited or no prior experience. Additionally, in the event we form joint ventures or other similar arrangements, we must pay close attention to the organizational formalities and time-consuming procedures for sharing information and making decisions. We may share ownership and management with other parties who may not have the same goals, strategies, priorities, or resources as we do. The benefits from a successful investment in an existing entity or joint venture will be shared among the co-owners, so we will not receive the exclusive benefits from a successful investment. Additionally, if a co-owner changes, our relationship may be materially and adversely affected.

Security breaches and other information systems failures could disrupt our operations, compromise the integrity of our data, expose us to liability, cause increased expenses and cause our reputation to suffer, any or all of which could have a material and adverse effect on our business or financial position.

Our business is dependent on financial, accounting and other data processing systems and other communications and information systems, including our enterprise resource planning tools. We process a large number of transactions on a

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daily basis and rely upon the proper functioning of computer systems. If a key system were to fail or experience unscheduled downtime for any reason, our operations and financial results could be affected adversely. Our systems could be damaged or interrupted by a security breach, terrorist attack, fire, flood, power loss, telecommunications failure or similar event.  Our disaster recovery plans may not entirely prevent delays or other complications that could arise from an information systems failure. Our business interruption insurance may not compensate us adequately for losses that may occur.

In the ordinary course of our business, we collect and store sensitive data in our data centers, on our networks, and in our cloud vendors.  In addition, we rely on third party service providers, for support of our information technology systems, including the maintenance and integrity of proprietary business information and other confidential company information and data relating to customers, suppliers and employees. The secure processing, maintenance and transmission of this information is critical to our operations and business strategy.  We have instituted data security measures for confidential company information and data stored on electronic and computing devices, whether owned or leased by us or a third party vendor. However, despite such measures, there are risks associated with customer, vendor, and other third-party access and our information technology and infrastructure may be vulnerable to attacks by hackers or breached due to: employee error or malfeasance, failure of third parties to meet contractual, regulatory and other obligations to us, or other disruptions. 

Any such breach could compromise our networks and the information stored there could be accessed, publicly disclosed, lost or stolen.  Any such access, disclosure or other loss of information could result in legal claims or proceedings, liability under laws that protect the privacy of personal information, and regulatory penalties, disrupt our operations, and damage our reputation, which could materially and adversely affect our business and financial position.

We are exposed to, and may be adversely affected by, interruptions to our computer and information technology systems and sophisticated cyber-attacks.

We rely on our information technology systems and networks in connection with many of our business activities. Some of these networks and systems are managed by third-party service providers and are not under our direct control. Our operations routinely involve receiving, storing, processing and transmitting sensitive information pertaining to our business, customers, dealers, suppliers, employees and other sensitive matters. Cyber-attacks could materially disrupt operational systems; result in loss of trade secrets or other proprietary or competitively sensitive information; compromise personally identifiable information regarding customers or employees; and jeopardize the security of our facilities. A cyber-attack could be caused by malicious outsiders using sophisticated methods to circumvent firewalls, encryption and other security defenses. Because techniques used to obtain unauthorized access or to sabotage systems change frequently and generally are not recognized until they are launched against a target, we may be unable to anticipate these techniques or to implement adequate preventative measures. Information technology security threats, including security breaches, computer malware and other cyber-attacks are increasing in both frequency and sophistication and could create financial liability, subject us to legal or regulatory sanctions or damage our reputation with customers, dealers, suppliers and other stakeholders. We continuously seek to maintain a robust program of information security and controls, but a cyber-attack could have a material adverse effect on our competitive position, reputation, results of operations, financial condition and cash flows. As cyber-attacks continue to evolve, we may be required to expend additional resources to continue to modify or enhance our protective measures or to investigate and remediate any information security vulnerabilities.

We are or may become subject to privacy and data protection laws, rules and directives relating to the processing of personal data in the countries where we operate.

The growth of cyber-attacks has resulted in an evolving legal landscape which imposes costs that are likely to increase over time. For example, new laws and regulations governing data privacy and the unauthorized disclosure of confidential information, including the European Union General Data Protection Regulation and recent California legislation (which, among other things, provides for a private right of action), pose increasingly complex compliance challenges and could potentially elevate our costs over time. Any failure by us to comply with such laws and regulations could result in penalties and liabilities. It is also possible under certain legislation that if we acquire a company that has violated or is not in compliance with applicable data protection laws, we may incur significant liabilities and penalties as a result.

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Our operating results have been and may continue to be affected by fluctuations in our costs of production, and, if we cannot pass increases in our costs of production to our customers, our financial condition, results of operations and cash flows may be negatively affected.

Our operations require a reliable supply of equipment, replacement parts and metallurgical coal. If the cost to produce coke and provide logistics services, including cost of supplies, equipment, metallurgical coal, labor, experience significant price inflation, and we cannot pass such increases in our costs of production to our customers, our profit margins may be reduced and our financial condition, results of operations and cash flows may be adversely affected.

Labor disputes with the unionized portion of our workforce could affect us adversely. Union represented labor creates an increased risk of work stoppages and higher labor costs.

We rely, at one or more of our facilities, on unionized labor, and there is always the possibility that we may be unable to reach agreement on terms and conditions of employment or renewal of a collective bargaining agreement. When collective bargaining agreements expire or terminate, we may not be able to negotiate new agreements on the same or more favorable terms as the current agreements, or at all, and without production interruptions, including labor stoppages. If we are unable to negotiate the renewal of a collective bargaining agreement before its expiration date, our operations and our profitability could be adversely affected. A prolonged labor dispute, which may include a work stoppage, could adversely affect our ability to satisfy our customers’ orders and, as a result, adversely affect our operations, or the stability of production and reduce our future revenues, or profitability. It is also possible that, in the future, additional employee groups may choose to be represented by a labor union.

Our ability to operate our company effectively could be impaired if we fail to attract and retain key personnel.

We have implemented recruitment, training and retention efforts to optimally staff our operations. Our ability to operate our business and implement our strategies depends in part on the efforts of our executive officers and other key employees. In addition, our future success will depend on, among other factors, our ability to attract and retain other qualified personnel. The loss of the services of any of our executive officers or other key employees or the inability to attract or retain other qualified personnel in the future could have a material adverse effect on our business or business prospects. With respect to our represented employees, we may be adversely impacted by the loss of employees who retire or obtain other employment during a layoff or a work stoppage.

We currently are, and likely will be, subject to litigation, the disposition of which could have a material adverse effect on our cash flows, financial position or results of operations.

The nature of our operations exposes us to possible litigation claims in the future, including disputes relating to our operations and commercial and contractual arrangements. Although we make every effort to avoid litigation, these matters are not totally within our control. We will contest these matters vigorously and have made insurance claims where appropriate, but because of the uncertain nature of litigation and coverage decisions, we cannot predict the outcome of these matters. Litigation is very costly, and the costs associated with prosecuting and defending litigation matters could have a material adverse effect on our financial condition and profitability. In addition, our profitability or cash flow in a particular period could be affected by an adverse ruling in any litigation currently pending in the courts or by litigation that may be filed against us in the future. We are also subject to significant environmental and other government regulation, which sometimes results in various administrative proceedings. For additional information, see “Item 3. Legal Proceedings.”

Risks Related to Indebtedness

We own a significant equity interest in the Partnership, and our consolidated financial statements include the Partnership’s substantial indebtedness. If effective control of the Partnership’s general partner is transferred to a third party, the Partnership’s indebtedness could become due and payable, which would materially and adversely affect our consolidated financial position.

Due to our significant equity ownership interest in the Partnership, our consolidated financial statements include the Partnership’s indebtedness.  If effective control of the Partnership’s general partner is transferred to a third party, resulting in the Partnership’s aggregate indebtedness becoming payable, our consolidated financial position would be materially and adversely affected.

If effective control of the Partnership’s general partner is transferred to a third party, the Partnership, pursuant to the indenture for its outstanding senior secured notes, could be required to repurchase such notes in an amount equal to 101 percent of the aggregate principal amount outstanding, which was $700.0 million at December 31, 2018. Under the Partnership’s revolving credit agreement, the lenders could declare the loans and other amounts (including letter of credit obligations), totaling $106.9 million at December 31, 2018, to be immediately due and payable.

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The Partnership faces material debt maturities which may adversely affect our consolidated financial position.

Over the next five years, we have approximately $159 million of total consolidated debt maturing at SunCoke and the Partnership. See Note 12 to the consolidated financial statements. We may not be able to refinance this debt, or may be forced to do so on terms substantially less favorable than our currently outstanding debt. We may be forced to delay or not make capital expenditures, which may adversely affect our competitive position and financial results.

Our indebtedness could adversely affect our financial condition and prevent us from fulfilling our obligations under our credit facilities and other debt documents.

Subject to the limits contained in our credit agreements, and our other debt instruments, we may be able to incur additional debt from time to time to finance working capital, capital expenditures, investments or acquisitions, or for other purposes. If we do so, the risks related to our level of debt could intensify. Specifically, a higher level of debt could have important consequences, including:

• making it more difficult for us to satisfy our obligations with respect to the notes and our other debt;

• limiting our ability to obtain additional financing to fund future working capital, capital expenditures, acquisitions or other general corporate requirements;

• requiring a substantial portion of our cash flows to be dedicated to debt service payments instead of other purposes, thereby reducing the amount of cash flows available for the payment of dividends, working capital, capital expenditures, acquisitions and other general corporate purposes;

• increasing our vulnerability to general adverse economic and industry conditions;

• exposing us to the risk of increased interest rates as certain of our borrowings, including borrowings under the credit facilities, are at variable rates of interest;

• limiting our flexibility in planning for and reacting to changes in the industry in which we compete;

• placing us at a competitive disadvantage to other, less leveraged competitors; and

• increasing our cost of borrowing.

In addition, the credit agreement governing our credit facilities contains restrictive covenants that limit our ability to engage in activities (such as incurring additional debt) that may be in our long-term best interest. Our failure to comply with those covenants could result in an event of default which, if not cured or waived, could result in the acceleration of all our debt.

Our level of indebtedness may increase, reducing our financial flexibility.

In the future, we may incur significant indebtedness in order to make future acquisitions or to develop or expand our facilities. Our level of indebtedness could affect our operations in several ways, including the following:

• a significant portion of our cash flows could be used to service our indebtedness;

• a high level of debt would increase our vulnerability to general adverse economic and industry conditions;

• the covenants contained in the agreements governing our outstanding indebtedness will limit our ability to borrow additional funds, dispose of assets, pay distributions and make certain investments;

• a high level of debt may place us at a competitive disadvantage compared to our competitors that are less leveraged, and therefore may be able to take advantage of opportunities that our indebtedness would prevent us from pursuing;

• our debt covenants may also affect our flexibility in planning for, and reacting to, changes in the economy and our industry; and

• a high level of debt may impair our ability to obtain additional financing in the future for working capital, capital expenditures, acquisitions, distributions or for general corporate or other purposes.

A high level of indebtedness increases the risk that we may default on our debt obligations. Our ability to meet our debt obligations and to reduce our level of indebtedness depends on our future performance. General economic conditions and financial, business and other factors affect our operations and our future performance. Many of these factors are beyond our control. We may not be able to generate sufficient cash flows to pay the interest on our debt, and future working capital, borrowings or equity financing may not be available to pay or refinance such debt. Factors that will affect our ability to raise cash through an offering of our units or a refinancing of our debt include financial market conditions, the value of our assets and our performance at the time we need capital.

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Our variable rate indebtedness subjects us to interest rate risk, which could cause our debt service obligations to increase significantly.

Borrowings under the credit facilities are at variable rates of interest and expose us to interest rate risk. If interest rates increase, our debt service obligations on the variable rate indebtedness will increase even though the amount borrowed remains the same, and our net income and cash flows, including cash available for servicing our indebtedness, will correspondingly decrease. From time to time, we may enter into, interest rate swaps that involve the exchange of floating for fixed rate interest payments in order to reduce interest rate volatility.

Rating agencies may downgrade our credit ratings, which would make it more difficult for us to raise capital and would increase our financing costs.

Any downgrades in our credit ratings may make raising capital more difficult, may increase the cost and affect the terms of future borrowings, may affect the terms under which we purchase goods and services and may limit our ability to take advantage of potential business opportunities.

Risks Related to Our Cokemaking Business

If a substantial portion of our agreements to supply coke, electricity, and/or steam are modified or terminated, our results of operations may be adversely affected if we are not able to replace such agreements, or if we are not able to enter into new agreements at the same level of profitability.

We make substantially all of our coke, electricity and steam sales under long-term agreements. If a substantial portion of these agreements are modified or terminated or if force majeure is exercised, our results of operations may be adversely affected if we are not able to replace such agreements, or if we are not able to enter into new agreements at the same level of profitability. The profitability of our long-term coke, energy and steam sales agreements depends on a variety of factors that vary from agreement to agreement and fluctuate during the agreement term. We may not be able to obtain long-term agreements at favorable prices, compared either to market conditions or to our cost structure. Price changes provided in long-term supply agreements may not reflect actual increases in production costs. As a result, such cost increases may reduce profit margins on our long-term coke and energy sales agreements. In addition, contractual provisions for adjustment or renegotiation of prices and other provisions may increase our exposure to short-term price volatility.

From time to time, we discuss the extension of existing agreements and enter into new long-term agreements for the supply of coke, steam, and energy to our customers, but these negotiations may not be successful and these customers may not continue to purchase coke, steam, or electricity from us under long-term agreements. In addition, declarations of bankruptcy by customers can result in changes in our contracts with less favorable terms. If any one or more of these customers were to become financially distressed and unable to pay us, significantly reduce their purchases of coke, steam, or electricity from us, or if we were unable to sell coke or electricity to them on terms as favorable to us as the terms under our current agreements, our cash flows, financial position, permit compliance, or results of operations may be materially and adversely affected.

Further, because of certain technological design constraints, we do not have the ability to shut down our cokemaking operations if we do not have adequate customer demand. If a customer refuses to take or pay for our coke, we must continue to operate our coke ovens even though we may not be able to sell our coke immediately and may incur significant additional costs for natural gas to maintain the temperature inside our coke oven batteries and fees under our rail contracts to account for reductions in inbound coal or outbound coke shipments at our plants, which may have a material and adverse effect on our cash flows, financial position or results of operations.

The coke sales agreement and the energy sales agreement with AK Steel at our Haverhill II facility are subject to early termination under certain circumstances and any such termination coupled with our inability to market the coke at similar prices could adversely affect our financial position.

The coke sales agreement and the energy sales agreement with AK Steel at our Haverhill II facility are subject to early termination by AK Steel upon satisfaction of two criteria. The Haverhill coke sales agreement with AK Steel expires on December 31, 2021. The Haverhill energy sales agreement with AK Steel runs concurrently with the term of the coke sales agreement, including any renewals, and automatically terminates upon the termination of the related coke sales agreement. Since January 1, 2014, the coke sales agreement may be terminated by AK Steel at any time on or after upon two years prior written notice, if AK Steel (i) permanently shuts down operation of the iron producing portion at its steel mill in Ashland, Kentucky (the Ashland Works Plant) and (ii) has not acquired or begun construction of a new blast furnace in the U.S. to replace, in whole or in part, the Ashland Works Plant’s iron production capacity. If AK Steel were able to satisfy both criteria and chose to elect early termination, AK Steel must provide two years advance notice of the

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termination. During the two year notice period, AK Steel must continue to perform in full under the terms of the coke sales agreement and energy sales agreement. On January 28, 2019, AK Steel announced its intention to permanently close its Ashland Works Plant by the end of 2019. Were the Ashland Works Plant to permanently shut down, we believe AK Steel has not and would not satisfy the second criterion.

If AK Steel were to terminate the coke sales agreement and we were unable to enter into similar long-term contracts with replacement customers for the coke previously purchased by AK Steel, then we may be forced to sell some or all of the previously contracted coke in the spot market.

Excess capacity in the global steel industry, and/or increased exports of coke from producing countries, may weaken our customers' demand for our coke and could materially and adversely affect our future revenues and profitability.

In some countries steelmaking capacity exceeds demand for steel products. Rather than reducing employment by matching production capacity to consumption, steel manufacturers in these countries (often with local government assistance or subsidies in various forms) may export steel at prices that are significantly below their home market prices and that may not reflect their costs of production or capital. Our steelmaking customers, may decrease the prices they charge for steel, or take other action, as the supply of steel increases. The profitability and financial position of our steelmaking customers may be adversely affected, causing such customers to reduce their demand for our coke and making it more likely that they may seek to renegotiate their contracts with us or fail to pay for the coke they are required to take under our contracts. In addition, future increases in exports of coke from China and/or other coke-producing countries also may reduce our customers' demand for coke capacity. Such reduced demand for our coke could adversely affect the certainty of our long-term relationships with our customers depress coke prices, and limit our ability to enter into new, or renew existing, commercial arrangements with our customers, as well as our ability to sell excess capacity in the spot market, and could materially and adversely affect our future revenues and profitability.

Income from operation of the Vitória, Brazil cokemaking facility may be affected by global and regional economic and political factors and the policies and actions of the Brazilian government.

The Vitória cokemaking facility is owned ArcelorMittal Brazil. We earn income from the Vitória, Brazil operations through licensing and operating fees earned at the Brazilian cokemaking facility payable to us under long-term agreements with ArcelorMittal Brazil. These revenues depend on continuing operations and, in some cases, certain minimum production levels being achieved at the Vitória cokemaking facility. In the past, the Brazilian economy has been characterized by frequent and occasionally extensive intervention by the Brazilian government and unstable economic cycles. The Brazilian government has changed in the past, and may change monetary, taxation, credit, tariff and other policies to influence Brazil’s economy in the future. If the operations at Vitória cokemaking facility are interrupted or if certain minimum production levels are not achieved, we will not be able to earn the same licensing and operating fees as we are currently earning, which could have an adverse effect on our financial position, results of operations and cash flows.

Certain provisions in our long-term coke agreements may result in economic penalties to us, or may result in termination of our coke sales agreements for failure to meet minimum volume requirements or other required specifications, and certain provisions in these agreements and our energy sales agreements may permit our customers to suspend performance.

Our agreements for the supply of coke, energy and/or steam, contain provisions requiring us to supply minimum volumes of our products to our customers. To the extent we do not meet these minimum volumes, we are generally required under the terms of our coke sales agreements to procure replacement supply to our customers at the applicable contract price or potentially be subject to cover damages for any shortfall. If future shortfalls occur, we will work with our customer to identify possible other supply sources while we implement operating improvements at the facility, but we may not be successful in identifying alternative supplies and may be subject to paying the contract price for any shortfall or to cover damages, either of which could adversely affect our future revenues and profitability. Our coke sales agreements also contain provisions requiring us to deliver coke that meets certain quality thresholds. Failure to meet these specifications could result in economic penalties, including price adjustments, the rejection of deliveries or termination of our agreements.

Our coke and energy sales agreements contain force majeure provisions allowing temporary suspension of performance by our customers for the duration of specified events beyond the control of our customers. Declaration of force majeure, coupled with a lengthy suspension of performance under one or more coke or energy sales agreements, may seriously and adversely affect our cash flows, financial position and results of operations.

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To the extent we do not meet coal-to-coke yield standards in our coke sales agreements, we are responsible for the cost of the excess coal used in the cokemaking process, which could adversely impact our results of operations and profitability.

Our ability to pass through our coal costs to our customers under our coke sales agreements is generally subject to our ability to meet some form of coal-to-coke yield standard. To the extent that we do not meet the yield standard in the contract, we are responsible for the cost of the excess coal used in the cokemaking process. We may not be able to meet the yield standards at all times, and as a result we may suffer lower margins on our coke sales and our results of operations and profitability could be adversely affected.

Failure to maintain effective quality control systems at our cokemaking facilities could have a material adverse effect on our results of operations.

The quality of our coke is critical to the success of our business. For instance, our coke sales agreements contain provisions requiring us to deliver coke that meets certain quality thresholds. If our coke fails to meet such specifications, we could be subject to significant contractual damages or contract terminations, and our sales could be negatively affected. The quality of our coke depends significantly on the effectiveness of our quality control systems, which, in turn, depends on a number of factors, including the design of our quality control systems, our quality-training program, our laboratories and our ability to ensure that our employees adhere to our quality control policies and guidelines. Any significant failure or deterioration of our quality control systems could have a material adverse effect on our results of operations.

If we are unable to realize the anticipated benefits from planned maintenance activities, oven re-builds, and additional measures to control costs at our Indiana Harbor cokemaking operations, our future financial performance, results of operations and cash flows could be materially and adversely affected.

Since the third quarter of 2015, when we implemented a plan to address deteriorating coke oven conditions and improve plant performance, and environmental compliance at our Indiana Harbor cokemaking operations, we have rebuilt approximately 80 percent of the coke ovens at that facility. However, unexpected costs and challenges may arise and there is a risk of continuing mechanical failures and deterioration of assets leading to production curtailments, shutdowns or additional expenditures at our Indiana Harbor operations, any or all of which could significantly disrupt our coke production and our ability to supply coke to our customer.

If the implementation of these systematic planned maintenance activities to improve operating performance of the remaining ovens to be rebuilt at Indiana Harbor (and related additional measures to control and benchmark costs) do not produce the expected benefits, our future financial performance, results of operations and cash flows could be materially and adversely affected.

Disruptions to our supply of coal and coal mixing services may reduce the amount of coke we produce and deliver, and if we are not able to cover the shortfall in coal supply or obtain replacement mixing services from other providers, our results of operations and profitability could be adversely affected.

Substantially all of the metallurgical coal used to produce coke at our cokemaking facilities, is purchased from third-parties under one-year contracts, except for the Jewell facility, which purchases a substantial portion of its metallurgical coal under a five-year contract with prices reset annually. We cannot assure that there will continue to be an ample supply of metallurgical coal available or that these facilities will be supplied without any significant disruption in coke production, as economic, environmental, and other conditions outside of our control may reduce our ability to source sufficient amounts of coal for our forecasted operational needs. If we are not able to make up the shortfalls resulting from such supply failures through purchases of coal from other sources, the failure of our coal suppliers to meet their supply commitments could materially and adversely impact our results of operations and, ultimately, impact the structural integrity of our coke oven batteries.

At our Granite City and Haverhill cokemaking facilities, we rely on third-parties to mix coals that we have purchased into coal mixes that we use to produce coke. We have entered into long-term agreements with coal mixing service providers that are coterminous with our coke sales agreements. However, there are limited alternative providers of coal mixing services and any disruptions from our current service providers could materially and adversely impact our results of operations. In addition, if our rail transportation agreements are terminated, we may have to pay higher rates to access rail lines or make alternative transportation arrangements.

Limitations on the availability and reliability of transportation, and increases in transportation costs, particularly rail systems, could materially and adversely affect our ability to obtain a supply of coal and deliver coke to our customers.

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Our ability to obtain coal depends primarily on third-party rail systems and to a lesser extent river barges. If we are unable to obtain rail or other transportation services, or are unable to do so on a cost-effective basis, our results of operations could be adversely affected. Alternative transportation and delivery systems are generally inadequate and not suitable to handle the quantity of our shipments or to ensure timely delivery. The loss of access to rail capacity could create temporary disruption until the access is restored, significantly impairing our ability to receive coal and resulting in materially decreased revenues. Our ability to open new cokemaking facilities may also be affected by the availability and cost of rail or other transportation systems available for servicing these facilities.

Our coke production obligations at our Jewell cokemaking facility and one half of our Haverhill cokemaking facility require us to deliver coke to certain customers via railcar. We have entered into long-term rail transportation agreements to meet these obligations. Disruption of these transportation services because of weather-related problems, mechanical difficulties, train derailments, infrastructure damage, strikes, lock-outs, lack of fuel or maintenance items, fuel costs, transportation delays, accidents, terrorism, domestic catastrophe or other events could temporarily, or over the long-term, impair our ability to produce coke, and therefore, could materially and adversely affect our business and results of operations.

If we are unable to effectively protect our intellectual property, third parties may use our technology, which would impair our ability to compete in our markets.

Our future success will depend in part on our ability to obtain and maintain meaningful patent protection for certain of our technologies and products throughout the world. The degree of future protection for our proprietary rights is uncertain. We rely on patents to protect a significant part our intellectual property portfolio and to enhance our competitive position. However, our presently pending or future patent applications may not issue as patents, and any patent previously issued to us or our subsidiaries may be challenged, invalidated, held unenforceable or circumvented. Furthermore, the claims in patents that have been issued to us or our subsidiaries or that may be issued to us in the future may not be sufficiently broad to prevent third parties from using cokemaking technologies and heat recovery processes similar to ours. In addition, the laws of various foreign countries in which we plan to compete may not protect our intellectual property to the same extent as do the laws of the United States. If we fail to obtain adequate patent protection for our proprietary technology, our ability to be commercially competitive may be materially impaired.  

Risks Related to Our Logistics Business

The growth and success of our logistics business depends upon our ability to find and contract for adequate throughput volumes, and an extended decline in demand for coal could affect the customers for our logistics business adversely. As a consequence, the operating results and cash flows of our logistics business could be materially and adversely affected.

The financial results of our logistics business segment are significantly affected by the demand for both thermal coal and metallurgical coal. An extended decline in our customers’ demand for either thermal or metallurgical coals could result in a reduced need for the coal mixing, terminalling and transloading services we offer, thus reducing throughput and utilization of our logistics assets. Demand for such coals may fluctuate due to factors beyond our control:

• Thermal coal demand: may be impacted by changes in the energy consumption pattern of industrial consumers, electricity generators and residential users, as well as weather conditions and extreme temperatures. The amount of thermal coal consumed for electric power generation is affected primarily by the overall demand for electricity, the availability, quality and price of competing fuels for power generation, and governmental regulation. For example, over the past few years, production of natural gas in the U.S. has increased dramatically, which has resulted in lower natural-gas prices. As a result of sustained low natural gas prices, coal-fuel generation plants have been displaced by natural-gas fueled generation plants. In addition, state and federal mandates for increased use of electricity from renewable energy sources, or the retrofitting of existing coal-fired generators with pollution control systems, also could adversely impact the demand for thermal coal. Finally, unusually warm winter weather may reduce the commercial and residential needs for heat and electricity which, in turn, may reduce the demand for thermal coal; and

• Metallurgical coal demand: may be impacted adversely by economic downturns resulting in decreased demand for steel and an overall decline in steel production. A decline in blast furnace production of steel may reduce the demand for furnace coke, an intermediate product made from metallurgical coal. Decreased demand for metallurgical coal also may result from increased steel industry utilization of processes that do not use, or reduce the need for, furnace coke, such as electric arc furnaces, or blast furnace injection of pulverized coal or natural gas.

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Additionally, fluctuations in the market price of coal can greatly affect production rates and investments by third-parties in the development of new and existing coal reserves. Mining activity may decrease as spot coal prices decrease. We have no control over the level of mining activity by coal producers, which may be affected by prevailing and projected coal prices, demand for hydrocarbons, the level of coal reserves, geological considerations, governmental regulation and the availability and cost of capital. A material decrease in coal mining production in the areas of operation for our logistics business, whether as a result of depressed commodity prices or otherwise, could result in a decline in the volume of coal processed through our logistics facilities, which would reduce our revenues and operating income.

Decreased demand for thermal or metallurgical coals, and extended or substantial price declines for coal could adversely affect our operating results for future periods and our ability to generate cash flows necessary to improve productivity and expand operations. The cash flows associated with our logistics business may decline unless we are able to secure new volumes of coal or other dry bulk products, by attracting additional customers to these operations. Future growth and profitability of our logistics business segment will depend, in part, upon whether we can contract for additional coal and other bulk commodity volumes at a rate greater than that of any decline in volumes from existing customers. Accordingly, decreased demand for coal, or other bulk commodities, or a decrease in the market price of coal, or other bulk commodities, could have a material adverse effect on the results of operations or financial condition of our logistics business.

The geographic location of the Convent Marine Terminal could expose us to potential significant liabilities, including operational hazards and unforeseen business interruptions, that could substantially and adversely affect our future financial performance.

CMT is located in the Gulf Coast region, and its operations are subject to operational hazards and unforeseen interruptions, including interruptions from hurricanes or floods, which have historically impacted the region with some regularity. If any of these events were to occur, we could incur substantial losses because of personal injury or loss of life, severe damage to and destruction of property and equipment, and pollution or other environmental damage resulting in curtailment or suspension of our related operations.

Risks Related to Ownership of Our Common Stock

Your percentage ownership in us may be diluted by future issuances of capital stock or securities or instruments that are convertible into our capital stock, which could reduce your influence over matters on which stockholders vote.

Our Board of Directors has the authority, without action or vote of our stockholders, to issue all or any part of our authorized but unissued shares of common stock, including shares issuable upon the exercise of options, shares that may be issued to satisfy our obligations under our incentive plans, shares of our authorized but unissued preferred stock and securities and instruments that are convertible into our common stock. Issuances of common stock or voting preferred stock would reduce your influence over matters on which our stockholders vote and, in the case of issuances of preferred stock, likely would result in your interest in us being subject to the prior rights of holders of that preferred stock.

Our ability to pay dividends on our common stock may be limited by restrictive covenants in our debt agreements and by other factors.

Any declaration and payment of future dividends to holders of our common stock will be limited by restrictive covenants contained in our debt agreements, and will be at the sole discretion of our Board of Directors and will depend on many factors, including our financial condition, earnings, capital requirements, level of indebtedness, statutory and contractual restrictions applying to the payment of dividends and other considerations that our Board of Directors deems relevant.

Further, we may not have sufficient surplus under Delaware law to be able to pay any dividends in the future. The absence of sufficient surplus may result from extraordinary cash expenses, actual expenses exceeding contemplated costs, funding of capital expenditures or increases in reserves.

Provisions of our amended and restated articles of incorporation, our amended and restated by-laws and the Delaware General Corporation Law (the “DGCL”) could discourage potential acquisition proposals and could deter or prevent a change in control.

Our amended and restated articles of incorporation and amended and restated by-laws contain provisions that are intended to deter coercive takeover practices and inadequate takeover bids and to encourage prospective acquirers to negotiate with our Board of Directors rather than to attempt a hostile takeover. These provisions include:

• a Board of Directors that is divided into three classes with staggered terms;

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• action by written consent of stockholders may only be taken unanimously by holders of all our shares of common stock;

• rules regarding how our stockholders may present proposals or nominate directors for election at stockholder meetings;

• the right of our Board of Directors to issue preferred stock without stockholder approval;

• limitations on the right of stockholders to remove directors; and

• limitations on our ability to be acquired.

The DGCL also imposes some restrictions on mergers and other business combinations between us and any holder of 15 percent or more of our outstanding common stock.

We believe that these provisions protect our stockholders from coercive or otherwise unfair takeover tactics by requiring potential acquirers to negotiate with our Board of Directors and by providing our Board of Directors with more time to assess any acquisition proposal. These provisions are not intended to make us immune from takeovers. However, these provisions apply even if the offer may be considered beneficial by some stockholders and could delay or prevent an acquisition that our Board of Directors determines is in our best interests and that of our stockholders.

Any or all of the foregoing provisions could limit the price that some investors might be willing to pay in the future for shares of our common stock.

A person or group could establish a substantial position in SunCoke Energy, Inc. stock.

We do not have a shareholder rights plan which may make it easier for a person or group to acquire a substantial position in SunCoke Energy, Inc. stock. Such person or group may have interests adverse to the interests of our other stockholders.

Risks Related to Our Master Limited Partnership

We own a significant equity interest in the Partnership.

We own the general partner of the Partnership, which holds a 2.0 percent ownership interest and IDRs, and we currently own a 60.4 percent limited partner interest in the Partnership. The Partnership holds a 98 percent interest in each of three entities that own our Haverhill, Ohio, Middletown, Ohio, and Granite City, Illinois cokemaking facilities and related assets. The Partnership also owns terminals and related assets that provide handling and/or mixing services of coal and other aggregates in Louisiana and West Virginia. All of the Partnership’s coke sales, and certain of its logistics services, are made pursuant to long-term, take-or-pay agreements, and our financial statements include the consolidated results of the Partnership. The Partnership is subject to operating and regulatory risks which are substantially similar to our own. The occurrence of any of these risks could directly or indirectly affect the Partnership’s, as well as our, financial condition, results of operations and cash flows as the Partnership is a consolidated subsidiary. For additional information about the Partnership, see “Cokemaking Operations” and “Formation of a Master Limited Partnership” in Business and Management’s Discussion and Analysis of Financial Condition and Operating Results (Items 1 and 7), respectively.

We derive a portion of our cash flows from the quarterly cash distributions we receive due to our equity ownership interest in the Partnership.  If the Partnership is unable to generate sufficient cash flow, its ability to pay quarterly distributions to unitholders (including us) at current levels, or to increase its quarterly distributions in the future, could adversely impact our cash position.

The Partnership’s ability to pay quarterly distributions depends primarily on cash flow. The Partnership’s ability to generate sufficient cash from operations is largely dependent upon its ability to successfully manage its business which may be affected by economic, financial, competitive, and regulatory factors beyond the Partnership’s control.  To the extent the Partnership does not have adequate cash reserves, its ability to pay quarterly distributions to its common unitholders (including us) at current levels, or to increase its quarterly distributions in the future, could be adversely affected.  Due to our equity ownership interest in the Partnership, we derive a portion of our cash flows from the quarterly cash distributions we receive.  If we are unable to obtain sufficient funds from the Partnership at current or increased levels, our cash position could be adversely affected.

We are party to an omnibus agreement with the Partnership that exposes us to various risks and uncertainties.

In connection with the initial public offering of the Partnership and the related contribution to the Partnership of an interest in each of our Haverhill, Ohio and Middletown, Ohio cokemaking facilities, we entered into an omnibus agreement with the Partnership. This omnibus agreement was later amended in connection with the contribution to the

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Partnership of an interest in our Granite City, Illinois cokemaking assets. Pursuant to this omnibus agreement, we have agreed to grant the Partnership preferential rights to pursue certain growth opportunities we identify in the U.S. and Canada and a right of first offer to acquire certain of our cokemaking assets located in the U.S. and Canada for so long as we control the Partnership’s general partner. Pursuant to this agreement, we have agreed to indemnify the Partnership for certain environmental remediation projects costs arising prior to the contribution of the interests in the Haverhill, Ohio, Middletown, Ohio and Granite City, Illinois cokemaking facilities. The omnibus agreement further provides that we will fully indemnify the Partnership with respect to certain tax liabilities arising prior to, or in connection with, the contribution of the interests in the Haverhill, Ohio, Middletown, Ohio and Granite City, Illinois cokemaking facilities, and that we will cure or fully indemnify the Partnership for losses resulting from certain title defects at the properties owned by the Partnership or its subsidiaries. Our obligations and the extent of our exposures that may arise under the omnibus agreement are subject to various contingencies and cannot be estimated with certainty at this time.

The value of our investment in the Partnership depends on the Partnership's status as a partnership for federal income tax purposes, as well as the Partnership not being subject to a material amount of entity-level taxation by individual states. The Internal Revenue Service (“IRS”) has issued final regulations which would result in the Partnership being treated as a corporation for federal income tax purposes and subject to entity-level taxation beginning January 1, 2028. In addition, the IRS may challenge the Partnership’s status as a partnership for federal income tax purposes from the time of the Partnership's initial public offering. If the IRS were to treat the Partnership as a corporation for federal income tax purposes or the Partnership were to become subject to material additional amounts of entity-level taxation for state tax purposes, then the value of our investment in the Partnership could be substantially reduced.

The anticipated after-tax economic benefit of our investment in the Partnership depends largely on the Partnership being treated as a partnership for federal income tax purposes. Despite the fact that the Partnership is organized as a limited partnership under Delaware law, the Partnership would be treated as a corporation for federal income tax purposes unless more than 90 percent of its income is from certain specified sources (the “Qualifying Income Exception”) under Section 7704 of the Internal Revenue Code of 1986, as amended (the “Code”).

On January 19, 2017, the IRS and the U.S. Department of Treasury issued qualifying income regulations (the “Final Regulations”) regarding the Qualifying Income Exception.  The Final Regulations were published in the Federal Register on January 24, 2017, and apply to taxable years beginning on or after January 19, 2017.  Under the Final Regulations, the Partnership’s cokemaking operations have been excluded from the definition of qualifying income activities, subject to a ten-year transition period.  As a result, the following consequences might ensue:

• If the Partnership’s income from cokemaking operations “was qualified income under the statute as reasonably interpreted prior to May 6, 2015,” then the Partnership will have a transition period ending on December 31, 2027, during which it can treat income from its existing cokemaking activities as qualifying income. The Partnership’s transitional status during this period is likely to impair the growth prospects of the Partnership, and we do not expect that the Partnership would acquire additional cokemaking operations from third parties or from us without receipt of an IRS private letter ruling confirming the availability of the transition period as applied to the income from such an acquisition. 

• The IRS might challenge treatment by the Partnership of income from its cokemaking operations as qualifying income by asserting that such treatment did not rely upon a reasonable interpretation of the statute prior to May 6, 2015. If so, nothing would preclude the IRS from challenging the Partnership’s status as a partnership for federal income tax purposes from the time of the Partnership’s initial public offering.  If this challenge were to occur and prevail, (i) the Partnership would be taxed retroactively as if it were a corporation at federal and state tax rates, likely resulting in a material amount of taxable income and taxes in certain open years, (ii) historical and future distributions would generally be taxed again as corporate distributions and (iii) no income, gains, losses, deductions or credits recognized by the Partnership would flow to unitholders of the Partnership. This would result in a material reduction in the Partnership’s cash flow and after-tax return to the Partnership’s unitholders and the recording of an income tax provision and a reduction in net income.

If, notwithstanding our confidence regarding the Partnership’s eligibility to use the transition period based on the Partnership’s belief and a legal opinion from outside counsel, the IRS were to challenge the Partnership’s eligibility to qualify for the transition period or the Partnership’s position that it has satisfied the Qualifying Income Exception from the time of its IPO, the Partnership would vigorously disagree with such a challenge, although we can provide no assurance of the Partnership’s likelihood of, or costs associated with, prevailing. For more information see "Item 1. Business IRS Final Regulations on Qualifying income."

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    A successful IRS contest of the federal income tax positions the Partnership takes may impact adversely the market for its common units, and the costs of any IRS contest could reduce the Partnership’s cash available for distribution to unitholders, including us. If the Partnership were treated as a corporation for federal income tax purposes, it would pay federal income tax on our taxable income at the corporate tax rate, which is currently a maximum of 21 percent, and would likely pay state income tax at varying rates. Because tax would be imposed upon the Partnership as a corporation, its after tax earnings and therefore its ability to distribute cash to us would be substantially reduced. Therefore, treatment of the Partnership as a corporation would result in a material reduction in the Partnership’s anticipated cash flow and after-tax return to the unitholders, likely causing a substantial reduction in the value of our investment in the Partnership.

The tax treatment of publicly traded partnerships or an investment in the Partnership’s common units could be subject to potential legislative, judicial or administrative changes and differing interpretations, possibly on a retroactive basis.

The present federal income tax treatment of publicly traded partnerships, including the Partnership, or an investment in its common units, may be modified by administrative, legislative or judicial interpretation at any time. Any modification to the federal income tax laws and interpretations thereof may or may not be applied retroactively. Moreover, any such modification could make it more difficult or impossible for the Partnership to meet the exception which allows publicly traded partnerships that generate qualifying income to be treated as partnerships (rather than corporations) for U.S. federal income tax purposes, affect or cause us to change our business activities, or affect the tax consequences of an investment in its common units. For example, as previously discussed, on January 24, 2017, Final Regulations were published in the Federal Register and apply to taxable years beginning on or after January 19, 2017. The Final Regulations will likely affect the Partnership’s ability to continue to qualify as a publicly traded partnership.

Risks Related to the Simplification Transaction

The proposed Simplification Transaction is subject to conditions, including some conditions that may not be satisfied on a timely basis, if at all. Failure to complete the Simplification Transaction, or significant delays in completing the Simplification Transaction, could negatively affect each party's future business and financial results and the trading prices of our common stock and the Partnership's common units.

Completion of the proposed Simplification Transaction is subject to a number of conditions, including approval of (i) the Merger Agreement by the Company's common stockholders, and (ii) the issuance of the Company’s common stock to be used as merger consideration which make the completion and timing of the consummation of the Simplification Transaction uncertain. Also, either the Company or the Partnership may terminate the Merger Agreement if the Simplification Transaction has not been completed by September 30, 2019, except that this termination right will not be available to any party whose failure to perform any obligation under the Merger Agreement has been the principal cause of, or resulted in, the failure of the proposed Simplification Transaction to be consummated by such date.

Completion of the proposed Simplification Transaction is not assured and is subject to several risks and uncertainties, including the risk that the required Company stockholder approval may not obtained, or even if obtained, still may not result in successful completion of the Simplification Transaction. In addition, the proposed Simplification Transaction is subject to a number of conditions, some of which are beyond the parties' control, that, if not satisfied or waived, may prevent, delay or otherwise result in the proposed Simplification Transaction not occurring.

If the proposed Simplification Transaction is not completed, or if there are significant delays in completing the proposed Simplification Transaction, the Company's and the Partnership's future business and financial results and the trading prices of our common stock and the Partnership's common units could be negatively affected, and each of the parties will be subject to several risks, including the following:

• the parties may be liable for fees or expenses to one another under the terms and conditions of the Merger Agreement;

• there may be negative reactions from the financial markets due to the fact that current prices of our common stock and the Partnership's common units may reflect a market assumption that the proposed Simplification Transaction will be completed; and

• the attention of management will have been diverted to the proposed Simplification Transaction rather than their own operations and pursuit of other opportunities that could have been beneficial to their respective businesses.

The Company and the Partnership are subject to business uncertainties and contractual restrictions while the proposed Simplification Transaction is pending, which could adversely affect each party's business and operations.

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In connection with the pendency of the proposed Simplification Transaction, it is possible that some customers and other persons with whom we or the Partnership have business relationships may delay or defer certain business decisions as a result of the Simplification Transaction, which could negatively affect our and the Partnership's respective revenues, earnings and cash flow, as well as the market price of our common stock and/or the Partnership's common units, regardless of whether the proposed Simplification Transaction is eventually completed. Under the terms of the Merger Agreement, the Company and the Partnership are each subject to certain restrictions on the conduct of its business prior to completing the Simplification Transaction, which may adversely affect the ability to execute certain business strategies including, in some cases, the ability to enter into contracts, acquire or dispose of assets, incur indebtedness, or incur capital expenditures. Such limitations could affect each party's businesses and operations negatively prior to the completion of the proposed Simplification Transaction.

Because the exchange ratio is fixed and because the market price of our common stock will fluctuate prior to the completion of the proposed Simplification Transaction, the Partnership's unaffiliated common unitholders cannot be sure of the market value of our common stock they will receive as Simplification Transaction consideration relative to the value of the Partnership's common units they exchange.

The market value of the consideration that the Partnership's unaffiliated common unitholders actually receive in the proposed Simplification Transaction will depend on the trading price of our common stock at the closing of the proposed Simplification Transaction. The exchange ratio that determines the number of shares of our common stock that the Partnership's unaffiliated common unitholders will receive in the proposed Simplification Transaction is fixed at 1.40 shares of our common stock for each common unit of the Partnership. There is no mechanism contained in the Merger Agreement, or otherwise, to adjust the number of shares of our common stock that the Partnership's unaffiliated common unitholders will receive based upon any decrease or increase in the trading price of our common stock. Stock or unit price changes may result from a variety of factors, many of which are beyond our and the Partnership's control, including:

• changes in our or the Partnership's business, operations and prospects;

• changes in market assessments of our or the Partnership's business, operations and prospects;

• changes in market assessments of the likelihood that the proposed Simplification Transaction will be completed;

• interest rates, commodity prices, general market, industry and economic conditions and other factors generally affecting the price of our common stock or the Partnership's common units; and

• federal, state and local legislation, governmental regulation and legal developments in the businesses in which we and the Partnership operate.

If the price of our common stock at the closing of the proposed Simplification Transaction is less than the price of our common stock on the date that the Merger Agreement was signed, then the market value of the merger consideration will be less than contemplated at the time the Merger Agreement was signed.

The date the Partnership's unaffiliated common unitholders will receive the merger consideration depends on the completion date of the proposed Simplification Transaction, which is uncertain.

Completion of the proposed Simplification Transaction is subject to several conditions, not all of which are controllable by us or the Partnership. Accordingly, even if the proposed Simplification Transaction is approved by our common stockholders, the date on which the Partnership's unaffiliated common unitholders will receive the merger consideration depends upon the completion date of the proposed Simplification Transaction, which is uncertain and subject to several other closing conditions.

We and the Partnership may incur transaction-related costs in connection with the proposed Simplification Transaction.

We and the Partnership each expect to incur a number of non-recurring transaction-related costs associated with completing the proposed Simplification Transaction, combining the operations of the two companies and attempting toachieve desired synergies. Non-recurring transaction costs include, but are not limited to, fees paid to legal, financial and accounting advisors, filing fees, proxy solicitation costs and printing costs. Many of the expenses that will be incurred are, by their nature, difficult to estimate accurately at the present time.

We are subject to provisions under the Merger Agreement that, in specified circumstances, could require us to pay a termination fee and to be responsible for the Partnership's expenses.

If the Merger Agreement is terminated by (i) the Partnership, pursuant to a material uncured breach by us of any of our covenants, representations or warranties, (ii) by the Partnership or us due to the failure to obtain the required Companystockholder approval or (iii) by the Partnership, in the event of our failure to recommend approval of the proposed Simplification

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Transaction to our stockholders, or the withdrawal, modification, or qualification of such recommendation, in a manner adverse to the Partnership, then we will reimburse the Partnership for all direct and indirect expenses and costs incurred and pay a termination fee of $6 million.

Certain executive officers and directors of the Partnership's general partner and of the Company have interests in the proposed Simplification Transaction that are different from, or in addition to, the interests they may have as the Partnership's unaffiliated common unitholders or our stockholders, respectively, which could have influenced their decision to support or approve the proposed Simplification Transaction.

Certain executive officers and/or directors of the partnership's general partner own equity interests in us, receive fees and other compensation from us and will have rights to ongoing indemnification and insurance coverage by the surviving company that give them interests in the proposed Simplification Transaction that may be different from, or in addition to, the interests of an unaffiliated unitholder of the Partnership. Additionally, certain of our executive officers and directors beneficially own Partnership common units and will receive the applicable merger consideration upon completion of the proposed Simplification Transaction, receive fees and other compensation from us and are entitled to indemnification arrangements with us that give them interests in the proposed Simplification Transaction that may be different from, or in addition to, the interests of our unaffiliated stockholders.

Financial projections by us and the Partnership may not prove to be reflective of actual future results.

In connection with the proposed Simplification Transaction, we and the Partnership have prepared and considered, among other things, internal financial forecasts for the Company and the Partnership, respectively. These forecasts speak only as of the date made and will not be updated. These financial projections were not provided with a view to public disclosure, are subject to significant economic, competitive, industry and other uncertainties and may not be achieved in full, at all or within projected time frames. In addition, the failure of our businesses to achieve projected results could have a material adverse effect on our share price, financial position and ability to institute or maintain a dividend on our stock following the proposed Simplification Transaction.

We and the Partnership may be unable to obtain the regulatory clearances required to complete the proposed Simplification Transaction or, in order to do so, we and the Partnership may be required to comply with material restrictions or satisfy material conditions.

The closing of the proposed Simplification Transaction is subject to the condition precedent that there is no law, injunction, judgment or ruling by a governmental authority in effect enjoining, restraining, preventing or prohibiting the consummation of the transactions contemplated by the Merger Agreement, or making the consummation of the transactions contemplated by the Merger Agreement illegal. Additionally, one or more state attorneys general could seek to block or challenge the proposed Simplification Transaction as they deem necessary or desirable in the public interest at any time, including after completion of the transaction. In addition, under certain circumstances, a third party could initiate a private action challenging or seeking to enjoin the proposed Simplification Transaction, before or after it is completed. We may not prevail and could incur significant costs in defending or settling any such action.

Shares of our common stock to be received by the Partnership's unaffiliated common unitholders as a result of the proposed Simplification Transaction have different rights from the Partnership's common units.

Following completion of the proposed Simplification Transaction, the Partnership's unaffiliated common unitholders no longer will hold the Partnership's unaffiliated common units, but instead will be stockholders of the Company. There are important differences between the rights of the Partnership's unaffiliated common unitholders and the rights of our stockholders. Ownership interests in a limited partnership are fundamentally different from ownership interests in a corporation. The Partnership's unaffiliated common unitholders will own our common stock following the completion of the proposed Simplification Transaction, and their rights associated with the common stock will be governed by our organizational documents and the Delaware General Corporation Law, which differ in a number of respects from the Partnership's partnership agreement and the Limited Partnership Act of the State of Delaware.

Litigation filed against us and/or the Partnership could prevent or delay the consummation of the Simplification Transaction or result in the payment of damages following completion of the Simplification Transaction.

Following announcement of the proposed Simplification Transaction, purported Partnership unitholders may file putative unitholder class action lawsuits against the Partnership, its general partner, and the general partner's Board of Directors, among others. Among other remedies, the plaintiffs may seek to enjoin the transactions contemplated by the Merger Agreement. The outcome of any such litigation is uncertain. If a dismissal is not granted or a settlement is not reached, such lawsuits

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could prevent or delay completion of the Simplification Transaction and result in substantial costs to the Partnership and/or us, including costs associated with indemnification. Additional lawsuits may be filed against the Partnership, us or our respective officers or directors in connection with the Simplification Transaction. The defense or settlement of any lawsuit or claim that remains unresolved at the time the Simplification Transaction is consummated may adversely affect the business, financial condition, results of operations and cash flows of the combined organization.

Risks Related to Our Legacy Coal Mining Business

Our former coal mining operations were subject to governmental regulations pertaining to employee health and safety and mandated benefits for retired coal miners. Following the divestiture of our coal mining operations, compliance with such regulations has continued to impose significant costs on our business.

Our former coal mining operations were subject to strict regulation by federal, state and local authorities with respect to environmental matters such as reclamation, and to matters such as employee health and safety and mandated benefits for retired coal miners. Even after divestiture of our coal mining business, compliance with these reclamation and benefits requirements has continued to impose significant costs on us. As a former coal mine operator, federal law requires us to secure payment of federal black lung benefits to claimants who were employees, and to contribute to a trust fund for payment of benefits and medical expenses to claimants who last worked in the coal industry before January 1, 1970. At December 31, 2018, our liabilities for coal workers’ black lung benefits totaled approximately $49.4 million. Our business could be materially and adversely harmed if these liabilities, including the number and award size of claims, were increased. See “Item 1. Business-Legal and Regulatory Requirements-Other Regulatory Requirements.”

Item 1B. Unresolved Staff Comments

None.

Item 2. Properties

We own the following real property:

• Approximately 66 acres in Vansant (Buchanan County), Virginia, on which the Jewell cokemaking facility is located, along with an additional approximately 1,675 acres including the offices, warehouse and support buildings for our Jewell coke affiliates located in Buchanan County, Virginia, as well as other general property holdings and unoccupied land in Buchanan County, Virginia and McDowell County, West Virginia.

• Approximately 400 acres in Franklin Furnace (Scioto County), Ohio, at and around the area where the Haverhill cokemaking facility (both the first and second phases) is located.

• Approximately 41 acres in Granite City (Madison County), Illinois, adjacent to the U.S. Steel Granite City Works facility, on which the Granite City cokemaking facility is located. Upon the earlier of ceasing production at the facility or the end of 2044, U.S. Steel has the right to repurchase the property, including the facility, at the fair market value of the land. Alternatively, U.S. Steel may require us to demolish and remove the facility and remediate the site to original condition upon exercise of its option to repurchase the land.

• Approximately 250 acres in Middletown (Butler County), Ohio near AK Steel’s Middletown Works facility, on which the Middletown cokemaking facility is located.

• Approximately 180 acres in Ceredo (Wayne County), West Virginia on which KRT has two terminals for its mixing and/or handling services along the Ohio and Big Sandy Rivers.

• Approximately 174 acres in Convent (St. James Parish), Louisiana, on which CMT is located.

We lease the following real property:

• Approximately 88 acres of land located in East Chicago (Lake County), Indiana, on which the Indiana Harbor cokemaking facility is located and the coal handling and/or mixing facilities (Lake Terminal) that service the Indiana Harbor cokemaking facility. The leased property is inside ArcelorMittal’s Indiana Harbor Works facility and is part of an enterprise zone. As lessee of the property, we are responsible for restoring the leased property to a safe and orderly condition.

• Approximately 22 acres of land located in Buchanan County, Virginia, on which our DRT coal handling terminal is located.

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• Approximately 25 acres in Belle (Kanawha County), West Virginia, on which KRT has a terminal for its mixing and/or handling services along the Kanawha River.

• Our corporate headquarters is located in leased office space in Lisle, Illinois under an 11-year lease that commenced in 2011.

While the Company completed the disposal of its coal mining business in April 2016, we continue to have rights to small parcels of land, mineral rights and coal mining rights for approximately 40 thousand acres of land in Buchanan and Russell Counties, Virginia. These agreements convey mining rights to us in exchange for payment of certain immaterial royalties and/or fixed fees.

Item 3. Legal Proceedings

The information presented in Note 13 to our consolidated financial statements within this Annual Report on Form 10-K is incorporated herein by reference.

Many legal and administrative proceedings are pending or may be brought against us arising out of our current and past operations, including matters related to commercial and tax disputes, product liability, employment claims, personal injury claims, premises-liability claims, allegations of exposures to toxic substances and general environmental claims. Although the ultimate outcome of these proceedings cannot be ascertained at this time, it is reasonably possible that some of them could be resolved unfavorably to us. Our management believes that any liabilities that may arise from such matters would not be material in relation to our business or our consolidated financial position, results of operations or cash flows at December 31, 2018.

Item 4. Mine Safety Disclosures

While the Company divested substantially all of its remaining coal mining assets in April 2016, certain retained coal mining assets remain subject to Mine Safety and Health Administration ("MSHA") regulatory purview and the Company continues to own certain logistics assets that are also regulated by MSHA. The information concerning mine safety violations and other regulatory matters that we are required to report in accordance with Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K (17 CFR 229.014) is included in Exhibit 95.1 to this Annual Report on Form 10-K.

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PART II

Item 5. Market for Registrant’s Common Equity, Related Stockholders Matters and Issuer Purchases of Equity Securities

Market Information

Shares of our common stock trade under the stock trading symbol “SXC” on the NYSE. The graph below matches the Company's cumulative 5-Year total shareholder return on common stock with the cumulative total returns of the S&P Small Cap 600 index and the Dow Jones U.S. Iron & Steel index. The graph tracks the performance of a $100 investment in our common stock and in each index (with the reinvestment of all dividends) from December 31, 2013 to December 31, 2018.

In selecting the indices for comparison, we considered market capitalization and industry or line-of-business. The S&P Small Cap 600 is a broad equity market index comprised of companies of between $450 million and $2.1 billion. The Company is a part of this index. The Dow Jones U.S. Iron & Steel index is comprised of both U.S.-based steel and metals manufacturing and coal and iron ore mining companies. While we do not manufacture steel, we do produce coke, an essential ingredient in the blast furnace production of steel. In addition, we have logistics operations. Accordingly, we believe the Dow Jones U.S. Iron & Steel index is appropriate for comparison purposes.

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Holders

As of February 8, 2019, we had a total of 72,233,750 issued shares and 64,756,093 outstanding shares of our common stock and had 10,730 holders of record of our common stock.

Company's Share Repurchase Program

On July 23, 2014, the Company's Board of Directors authorized a program to repurchase outstanding shares of the Company’s common stock, $0.01 par value, at any time and from time to time in the open market, through privately negotiated transactions, block transactions, or otherwise for a total aggregate cost to the Company not to exceed $150.0 million. There were no shares repurchased during 2018. At December 31, 2018 there was $39.4 million available under the authorized share repurchase program.

Partnership Common Unit Purchase Program

In 2017, the Company's Board of Directors authorized a program for the Company to purchase outstanding Partnership common units at any time and from time to time in the open market, through privately negotiated transactions, block transactions, or otherwise for a total aggregate cost to the Company not to exceed $100.0 million. During the first quarter of 2018, the Company purchased 231,171 of outstanding Partnership common units in the open market for total cash payments of $4.2 million, which increased our limited partner interest in the Partnership from 59.9 percent to 60.4 percent at December 31, 2018. At December 31, 2018 there was $47.1 million available under the authorized Partnership purchase program.

Partnership's Unit Repurchase Program

On July 20, 2015, the Partnership's Board of Directors authorized a program for the Partnership to repurchase up to $50.0 million of its common units. There were no unit repurchases during 2018 by the Partnership. At December 31, 2018, there was $37.2 million available under the authorized unit repurchase program.

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Item 6. Selected Financial Data

The following table presents summary consolidated operating results and other information of SunCoke Energy and should be read in conjunction with "Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations" and our consolidated financial statements and accompanying notes included elsewhere in this Annual Report on Form 10-K.

	Years Ended December 31,
	2018(1)		2017(1)		2016(1)		2015(1)			2014
	(Dollars in millions, except per share amounts)
Operating Results:
Total revenues	$	1,450.9	$	1,331.5	$	1,223.3	$	1,362.7		$	1,503.8
Operating income (loss)(2)	$	118.7	$	104.2	$	97.9	$	76.6		$	(67.8	)
Net income (loss)(3)(4)	$	47.0	$	103.5	$	59.5	$	10.3		$	(101.8	)
Net income (loss) attributable to SunCoke Energy, Inc.	$	26.2	$	122.4	$	14.4	$	(22.0	)	$	(126.1	)
Earnings (loss) attributable to SunCoke Energy, Inc. per common share:
Basic	$	0.40	$	1.90	$	0.22	$	(0.34	)	$	(1.83	)
Diluted	$	0.40	$	1.88	$	0.22	$	(0.34	)	$	(1.83	)
Dividends paid per share	$	—	$	—	$	—	$	0.4335		$	0.0585
Other Information:
Total assets	$	2,045.3	$	2,060.1	$	2,120.9	$	2,255.5		$	1,959.7
Long-term debt and financing obligation	$	834.5	$	861.1	$	849.2	$	997.7		$	633.5

(1) The results of CMT have been included in the consolidated financial statements since it was acquired on August 12, 2015. CMT added the following:

	Years Ended December 31,
	2018		2017		2016		2015
	(Dollars in millions)
Combined assets	$	370.9	$	394.6	$	411.7	$	426.1
Revenue	$	81.3	$	71.1	$	62.7	$	28.6
Operating income	$	40.2	$	42.3	$	46.5	$	18.4

(2) In April 2016, the Company recorded losses related to the divestiture of its coal mining business to Revelation Energy, LLC of $14.7 million. During 2014, we recorded total impairment charges related to our coal mining business of $150.3 million, which included both long-lived asset and goodwill impairment charges.

(3) On June 27, 2018, the Company sold its investment in VISA SunCoke Limited ("VISA SunCoke"), resulting in a net $5.4 million loss from equity method investment. During 2015 and 2014, we recorded other-than-temporary impairment charges on our investment in VISA SunCoke of $19.4 million and $30.5 million, respectively. The 2015 impairment charges brought our investment in VISA SunCoke to zero.

(4) During 2017, the Company recorded $154.7 million of net tax benefits, $125.0 million of which were attributable to SunCoke, related to the new Tax Legislation. Additionally, during 2017, the Company recorded deferred income tax expense of $64.2 million, all of which was attributable to noncontrolling interest, related to the Final Regulations. See Note 5 to our consolidated financial statements.

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Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

This Annual Report on Form 10-K contains certain forward-looking statements of expected future developments, as defined in the Private Securities Litigation Reform Act of 1995. This discussion contains forward-looking statements about our business, operations and industry that involve risks and uncertainties, such as statements regarding our plans, objectives, expectations and intentions. Our future results and financial condition may differ materially from those we currently anticipate as a result of the factors we describe under “Cautionary Statement Concerning Forward-Looking Statements” and “Risk Factors.”

This Management’s Discussion and Analysis of Financial Condition and Results of Operations ("MD&A") is based on financial data derived from the financial statements prepared in accordance with United States (“U.S.”) generally accepted accounting principles (“GAAP”) and certain other financial data that is prepared using non-GAAP measures. For a reconciliation of these non-GAAP measures to the most comparable GAAP components, see “Non-GAAP Financial Measures” at the end of this Item and Note 19 to our consolidated financial statements.

Our MD&A is provided in addition to the accompanying consolidated financial statements and notes to assist readers in understanding our results of operations, financial condition, and cash flows. Our results of operations include reference to our business operations and market conditions, which are further described in Part I of this document.

2018 Overview

Our consolidated results of operations in 2018 were as follows:

	Year Ended December 31, 2018
	(Dollars in millions)
Net income	$	47.0
Net cash provided by operating activities	$	185.8
Adjusted EBITDA	$	263.2

The Company successfully delivered against our key objectives in 2018, including:

• Achieved financial objectives. We delivered net income of $47.0 million and Adjusted EBITDA of $263.2 million, our highest annual Adjusted EBITDA performance since 2012 and above our guidance range of $240 million to $255 million. We also generated $185.8 million of operating cash flow, above our guidance of $150 million to $165 million. Domestic Coke contributed Adjusted EBITDA per ton of approximately $51.55, at the high-end of our guidance range of $50 to $52 per ton, on 4.0 million tons sold. Logistics delivered Adjusted EBITDA of $72.6 million, within our guidance range of $71 million to $76 million, reflecting the highest annual volumes in CMT’s history.

• Completed 67 oven rebuilds at Indiana Harbor. We successfully achieved our goal of rebuilding 67 ovens in 2018. In total, we have rebuilt 211 of 268 ovens, which represents approximately 80 percent of the entire facility. Indiana Harbor's 2018 Adjusted EBITDA was $15.2 million on 957 thousand tons of coke sales. Improved operating performance from rebuilt ovens and higher operating and maintenance cost recovery drove a $33.7 million increase in Adjusted EBITDA in 2018 compared to 2017.

• Achieved de-leveraging goals. We achieved our objective to pay down $25 million on the Partnership Revolver in 2018. We continue to maintain our focus on strengthening our balance sheet and continuing to reduce debt in 2019.

• Leveraged CMT capabilities to further diversify customer and product mix. We continued to further diversify the product mix by handling petroleum coke, aggregates and liquids, and we remain focused on adding additional dry bulk products to grow the terminal.  In 2018, we moved approximately one million merchant tons of bulk products through CMT.

• Delivered operational excellence and optimized our asset base. We continued to improve operational performance across both our coke and logistics businesses, which was reflected by the increase in volumes in both segments during 2018. We encountered operational challenges at our Granite City facility during 2018, which included an extended outage and a machinery fire. As part of the extended outage, we completed various upgrades on our heat recovery steam generators and flue gas desulfurization system in order to improve the long-term reliability and

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operational performance of these assets. These necessary upgrades will better position Granite City for long-term success. We also made significant progress on our environmental remediation project at Granite City and expect the project to be completed by the middle of 2019.

Our Focus and Outlook for 2019

During 2019, our primary focus will be to:

• Achieve financial objectives. We expect to deliver Adjusted EBITDA of between $265 million and $275 million and operating cash flow of between $180 million and $195 million. Significant operational improvements at Granite City, improved performance from rebuilt ovens at Indiana Harbor and solid ongoing operations across the remaining Domestic Coke fleet are expected to contribute to the growth in Adjusted EBITDA.

• Complete last phase of oven rebuilds at Indiana Harbor. We expect our Indiana Harbor cokemaking operation to deliver approximately $22 million in Adjusted EBITDA on approximately 1,025 thousand tons of coke sales. The 2019 oven rebuilds are expected to cost between $50 million to $60 million, including capital expenditures between $40 million to $48 million, and will be completed by the end of 2019. Once the final phase of the oven rebuild campaign is complete, we anticipate Indiana Harbor will produce at near nameplate coke capacity and generate run-rate Adjusted EBITDA of approximately $50 million.

• Complete the Simplification Transaction. On February 5, 2019, the Company and the Partnership announced that they have entered into a definitive agreement whereby SunCoke will acquire all outstanding common units of the Partnership not already owned by SunCoke in a stock-for-unit merger transaction (the “Simplification Transaction”).

We believe the Simplification Transaction will provide numerous benefits, including:

◦ Simplification of the organizational and governance structure, reducing complexity for investors

◦ Creation of a larger publicly-traded company, increasing public float and enhancing trading liquidity

◦ Immediately accretive to SunCoke shareholders

◦ SunCoke intends to initiate a $0.24 annual dividend per share, in the first full quarter after closing the transaction

◦ Improved credit profile and enhanced access to capital markets lowers cost of capital

◦ Consolidation of cash flow and elimination of master limited partnership distribution accelerates objective of reducing leverage

◦ Estimated cost synergies of approximately $2 million per year from eliminating dual public company requirements and estimated cash tax savings of $40 million over the next five years

◦ More cash flow available to deploy for organic growth projects, attractive merger and acquisition opportunities and/or to return capital to shareholders

◦ Elimination of master limited partnership qualifying income limitations on growth

• Pursue growth opportunities. Simplifying SunCoke’s structure will enable us to pursue an expanded universe of growth opportunities and enable us to be more competitive as we look to execute on our growth strategy. Our strategy focuses on four business initiatives, which include growing our coke market share in the North America, expanding and optimizing our logistics assets, developing additional business lines within the domestic steel and carbon markets and leveraging our technology to expand in select global markets. These are all areas that closely align with our core competencies, where our knowledge and technical expertise can create additional value for our shareholders.

• Deliver operational excellence and optimize our asset base. We remain focused on further improving operational performance across both our coke and logistics businesses, as well as successfully executing on our 2019 capital plan. We expect operational improvements at Granite City to generate an increase in production and higher energy revenues as well as lower operating and maintenance costs. We also continue to work to secure further new business and diversify our customer base.

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Items Impacting Comparability

• India Equity Method Investment. On June 27, 2018, the Company sold its 49 percent investment in VISA SunCoke Limited ("VISA SunCoke") for cash consideration of $4.0 million. Consequently, the Company recognized $9.0 million of accumulated currency translation losses and incurred $0.4 million of transaction costs, resulting in a net $5.4 million loss from equity method investment in 2018 on the Consolidated Statements of Income. Our investment in VISA SunCoke was previously accounted for as an equity method investment and was fully impaired in 2015.

• Debt Activities. On January 11, 2018, the Company redeemed all of its outstanding 2019 Notes for $46.1 million. The Company funded the redemption with a Term Loan in aggregate principal amount of $45.0 million, which will mature on May 24, 2022.

During 2017, the Partnership refinanced its debt obligations, which resulted in a loss on extinguishment of debt on the Consolidated Statements of Income of $20.4 million. During 2016, the Partnership de-levered its balance sheet by repurchasing $89.5 million face value of the Partnership's notes, resulting in a gain on debt extinguishment of $25.0 million on the Consolidated Statements of Income.

Weighted average debt balances during 2018, 2017 and 2016 were $883.8 million, $885.4 million and $920.2 million, respectively, and related interest expense, net was $65.8 million, $62.4 million and $58.8 million, respectively, or a weighted average interest rate of 7.45 percent, 7.05 percent and 6.39 percent, respectively. The increase in related interest expense in 2017 as compared to 2016 was driven by higher interest rates of as a result of the Partnership's debt refinancing activities in 2017. Interest expense in 2018 reflects a full year of the higher rates.

• Tax Rulings.

◦ Tax Legislation. On December 22, 2017, the Tax Cuts and Jobs Act (“Tax Legislation”) was enacted. The Tax Legislation significantly revised the U.S. corporate income tax structure, including lowering corporate income tax rates. As a result, in 2017, SunCoke recorded net income tax benefits of $154.7 million, of which $125.0 million was attributable to the Company, resulting from the remeasurement of U.S. deferred income tax liabilities and assets at the lower enacted corporate tax rates. During 2018, based on an updated analysis of the foreign tax credit rules relating to the new Tax Legislation, the Company revised its estimate of the realizability of its foreign tax credits, resulting in a $4.8 million benefit on the consolidated Statements of Income. See Note 5 to our consolidated financial statements.

◦ IRS Final Regulations on Qualifying Income. In January 2017, the Internal Revenue Service ("IRS") announced its decision to exclude cokemaking as a qualifying income generating activity in its final regulations (the "Final Regulations") issued under section 7704(d)(1)(E) of the Internal Revenue Code relating to the qualifying income exception for publicly traded partnerships. Subsequent to the 10-year transition period, certain cokemaking entities in the Partnership will become taxable as corporations. As a result, the Partnership recorded deferred income tax expense of $148.6 million to set up its initial deferred income tax liability during 2017, primarily related to differences in the book and tax basis of fixed assets, which are expected to exist at the end of the 10-year transition period when the cokemaking operations become taxable. However, the Company had previously recorded $84.4 million of the deferred income tax liability in its financial statements related to the Company's share of the deferred tax liability for the book and tax differences in its investment in the Partnership. As such, the Company's 2017 financial statements reflected the $64.2 million incremental impact from the Final Regulations solely attributable to the Partnership’s public unitholders, which was also recorded as an equal reduction to noncontrolling interest. As a result, the Final Regulations had no impact to net income attributable to the Company.

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• Redemption of Investment in Brazilian Cokemaking Operations. In November 2016, ArcelorMittal Brazil redeemed SunCoke’s indirectly held preferred and common equity interest in Sol Coqueria Tubarão S.A. ("Brazil Investment") for consideration of $41.0 million, an amount equal to our carrying value of the investment. The Company received $20.5 million in cash at closing in 2016 and received the remaining $20.5 million in cash, plus interest of $0.2 million, in 2017.

• Loss on Divestiture of Business. In April 2016, the Company completed the disposal of its coal mining business to Revelation Energy, LLC ("Revelation"). Revelation assumed substantially all of the Company's remaining coal mining assets, mineral leases, real estate and a substantial portion of our mining reclamation obligations. Under the terms of the agreement, Revelation received $12.8 million from the Company to take ownership of the assets and liabilities. During 2016, the Company recognized losses associated with this divestiture of $14.7 million.

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Consolidated Results of Operations

The following section includes analysis of consolidated results of operations for the years ended December 31, 2018, 2017 and 2016. See "Analysis of Segment Results" later in this section for further details of these results.

	Years Ended December 31,								Increase (Decrease)
	2018		2017			2016			2018 vs. 2017			2017 vs. 2016
	(Dollars in millions)
Revenues
Sales and other operating revenue	$	1,450.9	$	1,331.5		$	1,223.3		$	119.4		$	108.2
Costs and operating expenses
Cost of products sold and operating expenses	1,124.5		1,020.1			905.9			104.4			114.2
Selling, general and administrative expenses	66.1		79.0			90.6			(12.9		)	(11.6		)
Depreciation and amortization expense	141.6		128.2			114.2			13.4			14.0
Loss on divestiture of business(1)	—		—			14.7			—			(14.7		)
Total costs and operating expenses	1,332.2		1,227.3			1,125.4			104.9			101.9
Operating income	118.7		104.2			97.9			14.5			6.3
Interest expense, net(1)	61.4		61.9			54.8			(0.5		)	7.1
Loss (gain) on extinguishment of debt, net(1)	0.3		20.4			(25.0		)	(20.1		)	45.4
Income before income tax expense (benefit) and loss from equity method investment	57.0		21.9			68.1			35.1			(46.2		)
Income tax expense (benefit)	4.6		(81.6		)	8.6			86.2			(90.2		)
Loss from equity method investment(1)	5.4		—			—			5.4			—
Net income	47.0		103.5			59.5			(56.5		)	44.0
Less: Net income (loss) attributable to noncontrolling interests	20.8		(18.9		)	45.1			39.7			(64.0		)
Net income attributable to SunCoke Energy, Inc.	$	26.2	$	122.4		$	14.4		$	(96.2	)	$	108.0

(1) See year-over-year changes described in "Items Impacting Comparability."

Sales and Other Operating Revenue and Costs of Products Sold and Operating Expenses. Sales and other operating revenue and costs of products sold and operating expenses increased for 2018 and 2017 as compared to prior year periods, primarily due to the pass-through of higher coal prices in our Domestic Coke segment. Additionally, there were higher sales volumes in our Domestic Coke segment in 2018. Higher sales volumes in our Logistics segment increased revenues in both 2018 and 2017.

Selling, General and Administrative Expenses. The decrease in selling, general and administrative expense in 2018 as compared to 2017 was driven by lower employee-related costs, lower black lung costs and the absence of the write-off of costs associated with the termination of our project for a potential new cokemaking facility, which together decreased selling, general and administrative expense by $10.9 million. The decrease in 2017 as compared to 2016 was due to lower employee-related costs, lower costs to resolve certain legal matters and lower professional service fees, which together decreased selling, general and administrative expense by $12.4 million.

Depreciation and Amortization Expense. The increase in depreciation and amortization expense during 2018 was impacted by depreciation expense on the completed oven rebuilds at Indiana Harbor. The increase in depreciation and amortization expense during 2017 was impacted by incremental depreciation expense on CMT's ship loader and certain environmental remediation (i.e. gas sharing) assets at our Haverhill cokemaking facility, both placed in service during the fourth quarter of 2016. 

In 2018, we revised the estimate useful lives of certain heat recovery steam generators as a result of plans to replace major components with upgraded materials and design. Additionally, near the end of 2016, we revised the estimated useful lives of our Indiana Harbor ovens. These changes in estimates resulted in additional depreciation of $26.7 million, $22.4 million and $13.7 million, or $0.41, $0.35 and $0.17 per common share from operations, during 2018, 2017 and 2016, respectively.

Income Taxes. Income tax expense was $4.6 million and $8.6 million in 2018 and 2016, respectively, while 2017 had an income tax benefit of $81.6 million. The periods presented are not comparable as 2017 included net impacts to the Company’s deferred tax expense of $64.2 million associated with the Final Regulations as well as the $154.7 million tax

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benefit related to the Tax Legislation. The Company also recorded tax benefits of $1.4 million and $4.8 million in 2018 related to the Final Regulations and Tax Legislation, respectively. See "Items Impacting Comparability" and Note 5 to the consolidated financial statements.

Noncontrolling Interest.Income attributable to noncontrolling interest represents the common public unitholders' interest in SunCoke Energy Partners, L.P. as well as a third-party interest in our Indiana Harbor cokemaking facility. The following table provides details into net income (loss) attributable to noncontrolling interest.

	Years Ended December 31
	2018			2017			2016
Net income (loss) attributable to the Partnership's common public unitholders(1)	$	21.6		$	(13.5	)	$	46.1
Net loss attributable to third-party interest in our Indiana Harbor cokemaking facility(2)	(0.8		)	(5.4		)	(1.0		)
Net income (loss) attributable to noncontrolling interest	$	20.8		$	(18.9	)	$	45.1

(1) The loss in 2017 was primarily due to the net impacts of the Final Regulations and the new Legislation, previously discussed in "Items Impacting Comparability." Comparability between periods was also impacted by the gains and losses associated with the Partnership debt activities in 2017 and 2016, 38 percent of which is attributable to the public unitholders.

(2) The increase during 2018 as compared to 2017 is primarily due to increased volumes on improved performance from the rebuilt ovens at Indiana Harbor and a favorable change in the contractual recovery of operating costs at the facility as discussed in "Analysis of Segment Results." The decrease during 2017 as compared to 2016 was primarily driven by lower volumes and higher operating and maintenance spending as a result of ovens out of service associated with the Indiana Harbor oven rebuild initiative.

Results of Reportable Business Segments

We report our business results through three segments:

• Domestic Coke consists of our Jewell facility, located in Vansant, Virginia, our Indiana Harbor facility, located in East Chicago, Indiana, our Haverhill facility, located in Franklin Furnace, Ohio, our Granite City facility located in Granite City, Illinois, and our Middletown facility located in Middletown, Ohio.

• Brazil Coke consists of operations in Vitória, Brazil, where we operate the ArcelorMittal Brazil cokemaking facility.

• Logistics consists of Convent Marine Terminal ("CMT"), located in Convent, Louisiana, Kanawha River Terminal ("KRT"), located in Ceredo and Belle, West Virginia, SunCoke Lake Terminal ("Lake Terminal"), located in East Chicago, Indiana, and Dismal River Terminal ("DRT"), located in Vansant, Virginia. Lake Terminal and DRT are located adjacent to our Indiana Harbor and Jewell cokemaking facilities, respectively.

The operations of each of our segments are described in Part I of this document.

Corporate expenses that can be identified with a segment have been included in determining segment results. The remainder is included in Corporate and Other, including activity from our legacy coal mining business.

Management believes Adjusted EBITDA is an important measure of operating performance and liquidity and uses it as the primary basis for the chief operating decision maker to evaluate the performance of each of our reportable segments. Adjusted EBITDA should not be considered a substitute for the reported results prepared in accordance with GAAP. See Note 19 to our consolidated financial statements.

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Segment Operating Data

The following table sets forth financial and operating data by segment for the years ended December 31, 2018, 2017 and 2016:

	Years Ended December 31,									Increase (Decrease)
	2018			2017			2016			2018 vs. 2017			2017 vs. 2016
	(Dollars in millions, except per ton amounts)
Sales and other operating revenue:
Domestic Coke	$	1,308.3		$	1,195.0		$	1,097.6		$	113.3		$	97.4
Brazil Coke	40.4			43.4			39.5			(3.0		)	3.9
Logistics	102.2			93.1			84.7			9.1			8.4
Logistics intersegment sales	24.5			23.8			23.2			0.7			0.6
Corporate and Other(1)	—			—			1.5			—			(1.5		)
Corporate and Other intersegment sales(1)	—			—			22.0			—			(22.0		)
Elimination of intersegment sales	(24.5		)	(23.8		)	(45.2		)	(0.7		)	21.4
Total sales and other operating revenue	$	1,450.9		$	1,331.5		$	1,223.3		$	119.4		$	108.2
Adjusted EBITDA(2):
Domestic Coke	$	207.9		$	188.9		$	193.9		$	19.0		$	(5.0	)
Brazil Coke	18.4			18.2			16.2			0.2			2.0
Logistics	72.6			70.8			63.9			1.8			6.9
Corporate and Other, including legacy costs, net(3)	(35.7		)	(43.2		)	(57.0		)	7.5			13.8
Adjusted EBITDA	$	263.2		$	234.7		$	217.0		$	28.5		$	17.7
Coke Operating Data:
Domestic Coke capacity utilization (%)	95			91			93			4			(2		)
Domestic Coke production volumes (thousands of tons)	4,016			3,861			3,954			155			(93		)
Domestic Coke sales volumes (thousands of tons)	4,033			3,851			3,956			182			(105		)
Domestic Coke Adjusted EBITDA per ton(4)	$	51.55		$	49.05		$	49.01		$	2.50		$	0.04
Brazilian Coke production—operated facility (thousands of tons)	1,768			1,761			1,741			7			20
Logistics Operating Data:
Tons handled (thousands of tons)(5)	26,605			21,616			18,569			4,989			3,047
CMT take-or-pay shortfall tons (thousands of tons)(6)	220			2,918			6,076			(2,698		)	(3,158		)

(1) Corporate and Other revenues are related to our legacy coal mining business.

(2) See Note 19 in our consolidated financial statements for both the definition of Adjusted EBITDA and the reconciliations from GAAP to the non-GAAP measurement for the years ended December 31, 2018, 2017 and 2016.

(3) Corporate and Other includes the activity from our legacy coal mining business, which incurred Adjusted EBITDA losses of $9.8 million, $10.5 million, and $15.0 million for the years ended December 31, 2018, 2017 and 2016, respectively.

(4) Reflects Domestic Coke Adjusted EBITDA divided by Domestic Coke sales volumes.

(5) Reflects inbound tons handled during the period.

(6) Reflects tons billed under take-or-pay contracts where services were not performed.

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Analysis of Segment Results

Domestic Coke

The following table explains year-over-year changes in our Domestic Coke segment's sales and other operating revenues and Adjusted EBITDA results:

	Sales and other operating revenue						Adjusted EBITDA
	2018 vs. 2017			2017 vs. 2016			2018 vs. 2017			2017 vs. 2016
	(Dollars in millions)
Beginning	$	1,195.0		$	1,097.6		$	188.9		$	193.9
Volumes(1)	48.3			(23.8		)	8.5			(2.5		)
Coal cost recovery and yields(2)	58.4			118.8			12.2			7.1
Operating and maintenance costs(3)	14.6			1.0			1.5			(15.6		)
Energy and other(4)	(8.0		)	1.4			(3.2		)	6.0
Ending	$	1,308.3		$	1,195.0		$	207.9		$	188.9

(1) Sales volumes increased over 180 thousand tons in 2018, primarily due to improved operating performance from rebuilt ovens at Indiana Harbor. In 2017, sales volumes were 105 thousand tons lower than in 2016 and were negatively impacted by ovens that were out of service in connection with the ongoing oven rebuild initiative at Indiana Harbor as well as a decrease in volumes to AK Steel, for which AK Steel provided make whole payments.

(2) Revenues and the impact of coal-to-coke yields on Adjusted EBITDA move directionally with changes in coal prices, which increased in both 2018 and 2017 as compared to the prior year periods. Additionally, revenue and Adjusted EBITDA benefited from improved operational coal-to-coke yields, primarily at our Indiana Harbor facility in 2017 and again in 2018 as the facility realized benefits from the oven rebuild initiative.

(3) In 2018, the operating cost component of the contract at our Indiana Harbor facility changed from fixed recovery per ton to an annually negotiated budget, which drove favorable operating and maintenance cost recovery of $10.8 million as compared to 2017. This 2018 improvement was offset by the timing and scope of outage work at other facilities, which negatively impacted Adjusted EBITDA by $6.6 million. Higher operating and maintenance costs in 2017 as compared to 2016 was driven by an increase in the number of oven rebuilds at Indiana Harbor.

(4) The decrease in energy in 2018 as compared to 2017 was primarily driven by our extended Granite City outage and the impact a machinery fire had on coke production and energy. The improvement in 2017 as compared to 2016 was driven by the impact of a turbine failure at our Haverhill facility in October 2016, which was fully restored in January 2017. This turbine failure adversely affected energy production in 2016, although the impact was partially mitigated by insurance recoveries.

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Logistics

The following table explains year-over-year changes in our Logistics segment's sales and other operating revenues and Adjusted EBITDA results:

	Sales and other operating revenue, inclusive of intersegment sales					Adjusted EBITDA
	2018 vs. 2017			2017 vs. 2016		2018 vs. 2017			2017 vs. 2016
	(Dollars in millions)
Beginning	$	116.9		$	107.9	$	70.8		$	63.9
Transloading volumes(1)	9.3			3.1		3.6			2.4
Price/margin impact of mix in transloading services	1.7			3.0		1.7			3.0
Operating and maintenance costs and other(2)	(1.2		)	2.9		(3.5		)	1.5
Ending	$	126.7		$	116.9	$	72.6		$	70.8

(1) CMT achieved record volumes in 2017, which further increased in 2018. Volumes were 12.2 million tons, 8.0 million tons and 4.3 million tons in 2018, 2017 and 2016, respectively.

(2) In 2018, the Mississippi River experienced near-historic water levels, which negatively impacted Adjusted EBITDA during 2018 as compared to 2017.

Brazil Coke

2018 compared to 2017

Sales and other operating revenue decreased$3.0 million, or 6.9 percent, to $40.4 million in 2018 compared to $43.4 million in 2017, primarily due to unfavorable translation adjustments.

Adjusted EBITDA was consistent at $18.4 million in 2018 compared to $18.2 million in 2017.

2017 compared to 2016

Sales and other operating revenue increased$3.9 million, or 9.9 percent, to $43.4 million in 2017 compared to $39.5 million in 2016. The increase in sales and other operating revenue was primarily due to $1.8 million of favorable translation adjustments as well as higher reimbursable operating and maintenance costs of $1.1 million. The remaining increase of $1.0 million was primarily due to higher volumes, including higher production bonuses received from our customer in the current year for meeting certain volume targets beyond what was produced in the prior year.

Adjusted EBITDA increased$2.0 million, or 12.3 percent, to $18.2 million in 2017 compared to $16.2 million in 2016. The increase was primarily driven by higher volumes, including higher production bonuses as described above and favorable translation adjustments.

Corporate and Other

2018 compared to 2017

Corporate and Other Adjusted EBITDA results, which include costs related to our legacy coal mining business, improved$7.5 million, or 17.4 percent, to losses of $35.7 million in 2018 as compared to losses of $43.2 million in 2017. This improvement was driven by $4.5 million of lower employee-related costs and the absence of costs incurred to resolve certain corporate legal matters incurred in the prior year period. Costs related to our legacy coal mining business were generally consistent year over year as costs to resolve certain legal matters in the current year period were more than offset by a favorable adjustment to our black lung liability, driven by higher discount rates.

2017 compared to 2016

Corporate and Other Adjusted EBITDA results, improved $13.8 million, or 24.2 percent, to losses of $43.2 million in 2017 as compared to losses of $57.0 million in 2016. The improvement included a $4.5 million period-over-period benefit associated with the absence of our legacy coal mining business, which was disposed of in April 2016. The 2017 period also benefited from $4.6 million of lower employee-related and other costs and the $2.2 million favorable impact of period-over-period, mark-to-market adjustments in deferred compensation driven by changes in the Company's share price and the

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Partnership's unit price. The remaining improvement was driven by lower costs incurred to resolve certain legal matters as compared to the prior year period.     

Liquidity and Capital Resources

Our primary liquidity needs are to fund working capital, fund investments, service our debt, maintain cash reserves and replace partially or fully depreciated assets and other capital expenditures. Our sources of liquidity include cash generated from operations, borrowings under our revolving credit facility and, from time to time, debt and equity offerings. We believe our current resources are sufficient to meet our working capital requirements for our current business for the foreseeable future. As of December 31, 2018, together with the Partnership, we had $145.7 million of cash and cash equivalents and $254.2 million of borrowing availability under our credit facilities.

Debt Refinancing

On January 11, 2018, the Company redeemed all of its outstanding 2019 Notes for $46.1 million, which included accrued and unpaid interest of $1.5 million. As a result of the debt extinguishment, the Company recorded a loss on extinguishment of debt on the Consolidated Statements of Income of $0.3 million, representing a write-off of unamortized debt issuance costs. The Company funded the redemption with a Term Loan in aggregate principal amount of $45.0 million, resulting in additional debt issuance costs of $0.3 million. The Term Loan will mature on May 24, 2022. Borrowings under the Term Loan will bear interest, at the Company’s option, at either (i) a base rate plus an applicable margin or (ii) LIBOR plus an applicable margin. The applicable margin is based on the Company's consolidated leverage ratio, as defined in the credit agreement.

Covenants

As of December 31, 2018, the Company and the Partnership were in compliance with all debt covenants. We do not anticipate violation of these covenants nor do we anticipate that any of these covenants will restrict our operations or our ability to obtain additional financing. See Note 12 to the consolidated financial statements for details on debt covenants.

We expect the Partnership's current debt structure to remain unchanged at the time of the Simplification Transaction closing. The Simplification Transaction will not trigger any change-of-control provisions.

Credit Rating

In February 2018, S&P Global Ratings reaffirmed the Company and the Partnership's corporate credit rating of BB- (stable). Additionally, in May 2018, Moody’s Investors Service reaffirmed the Company’s corporate family rating of B1 (stable).

Distributions

On January 28, 2019, the Partnership's Board of Directors declared a quarterly cash distribution of $0.4000 per unit. This distribution will be paid on March 1, 2019 to unitholders of record on February 15, 2019.

The Partnership anticipates it will maintain the current quarterly distribution rate of $0.4000 per unit for each quarter until the closing of the Simplification Transaction. Partnership common unitholders will receive a prorated distribution per unit payable in SunCoke common shares based upon a quarterly distribution of $0.4000 per unit for the period beginning with the first day of the most recent full calendar quarter with respect to which any Partnership unitholder distribution record date has not occurred (or if there is no such full calendar quarter, then beginning with the first day of the partial calendar quarter in which the closing occurs) and ending on the day prior to the close of the Simplification Transaction.

Partnership Common Unit Purchase Program

In 2017, the Company's Board of Directors authorized a program for the Company to purchase outstanding Partnership common units at any time and from time to time in the open market, through privately negotiated transactions, block transactions, or otherwise for a total aggregate cost to the Company not to exceed $100.0 million. During the first quarter of 2018, the Company purchased 231,171 of outstanding Partnership common units in the open market for total cash payments of $4.2 million, which increased our limited partner interest in the Partnership from 59.9 percent to 60.4 percent at December 31, 2018. At December 31, 2018 there was $47.1 million available under the authorized Partnership purchase program.

Cash Flow Summary

The following table sets forth a summary of the net cash provided by (used in) operating, investing and financing activities for the years ended December 31, 2018, 2017 and 2016:

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	Years Ended December 31,
	2018			2017			2016
	(Dollars in millions)
Net cash provided by operating activities	$	185.8		$	148.5		$	219.1
Net cash used in investing activities	(95.8		)	(55.1		)	(53.9		)
Net cash used in financing activities	(64.5		)	(107.7		)	(172.3		)
Net increase (decrease) in cash, cash equivalents and restricted cash	$	25.5		$	(14.3	)	$	(7.1	)

Cash Provided by Operating Activities

Net cash provided by operating activities increased $37.3 million to $185.8 million in 2018 as compared to 2017. The increase reflects improved operations as compared to the prior year period. Additionally, there was a favorable year-over-year change of approximately $8 million in primary working capital, which is comprised of accounts receivable, inventories and accounts payable, primarily driven by rebuilding coal inventory to a normalized level in the prior year period. The current year period also benefited from $8.3 million of lower interest payments, net of capitalized interest, as a result of the Partnership's debt restructuring in the second quarter of 2017, which impacted the timing of interest payments and resulted in additional payments in 2017. These improvements were partly offset by payments of certain deferred compensation during 2018.

Net cash provided by operating activities decreased $70.6 million to $148.5 million in 2017 as compared to 2016. The decrease was primarily driven by the unfavorable year-over-year change in primary working capital, of which approximately $47 million was due to fluctuating coal prices and inventory levels. Further contributing to the decrease in operating cash flows were higher cash interest payments, net of capitalized interest, of $14.5 million during 2017 as compared to 2016 as a result of the Partnership refinancing its debt obligations. Additionally, income tax payments, net were $5.8 million in the current period as compared to income tax refunds, net of $2.3 million in 2016 and compensation-related benefit payments were higher in 2017 as compared to 2016.

Cash Used in Investing Activities

Net cash used in investing activities increased $40.7 million to $95.8 million in 2018 as compared to 2017. The current year period included higher capital spending of $24.7 million as compared to the prior year, primarily on the environmental remediation project at our Granite City facility as well as higher spending for ongoing capital expenditures. The change also reflects $4.0 million of cash received for the sale of an equity method investment in the current year period as well as the absence of the $20.5 million return of the Brazilian investment collected during the first quarter of 2017.

Net cash used in investing activities increased $1.2 million to $55.1 million in 2017 as compared to 2016. An increase in capital expenditures primarily due to the Indiana Harbor oven rebuild initiative and the environmental remediation project at Granite City during 2017 was partially offset by the $12.8 million payment related to the divestiture of the coal mining business in 2016.

Cash Used in Financing Activities

Net cash used in financing activities was $64.5 million in 2018 and was related to the Partnership's distribution payments to public unitholders of $31.9 million, the Partnership's repayment of $25.0 million on its revolving credit facility and the Company's acquisition of outstanding Partnership common units for $4.2 million. The January 2018 debt restructuring had a minimal net impact to financing cash flows. See Note 12 to our consolidated financial statements for further discussion of debt activities.

Net cash used in financing activities was $107.7 million in 2017 and was related to the Company's acquisition of outstanding Partnership common units for a total payment of $48.7 million and the Partnership's distribution payments to public unitholders of $47.0 million. Additionally, during 2017, the Partnership refinanced its debt obligations, for which the Partnership made repayments of debt, net of proceeds, of $13.1 million.

Net cash used in financing activities was $172.3 million in 2016 and was primarily in connection with the Partnership's de-levering activities, for which the Partnership and the Company made repayments of debt, net of proceeds from the sale-leaseback arrangement, of $121.5 million. Additionally, during 2016, the Partnership paid distributions to public unitholders of $49.4 million.

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Capital Requirements and Expenditures

Our operations are capital intensive, requiring significant investment to upgrade or enhance existing operations and to meet environmental and operational regulations. The level of future capital expenditures will depend on various factors, including market conditions and customer requirements, and may differ from current or anticipated levels. Material changes in capital expenditure levels may impact financial results, including but not limited to the amount of depreciation, interest expense and repair and maintenance expense.

Our capital requirements have consisted, and are expected to consist, primarily of:

• Ongoing capital expenditures required to maintain equipment reliability, the integrity and safety of our coke ovens and steam generators and to comply with environmental regulations. Ongoing capital expenditures are made to replace partially or fully depreciated assets in order to maintain the existing operating capacity of the assets and/or to extend their useful lives and also include new equipment that improves the efficiency, reliability or effectiveness of existing assets. Ongoing capital expenditures do not include normal repairs and maintenance expenses, which are expensed as incurred;

• Environmental remediation project expenditures required to implement design changes to ensure that our existing facilities operate in accordance with existing environmental permits; and

• Expansion capital expenditures to acquire and/or construct complementary assets to grow our business and to expand existing facilities as well as capital expenditures made to enable the renewal of a coke sales agreement and/or logistics service agreement and on which we expect to earn a reasonable return.

The following table summarizes ongoing, environmental remediation project and expansion capital expenditures:

	Years Ended December 31,
	2018		2017		2016
	(Dollars in millions)
Ongoing capital(1)	$	69.7	$	54.7	$	39.8
Environmental remediation project(2)	29.8		19.4		7.8
Expansion capital:
CMT ship loader(3)	—		1.1		13.5
Other capital expansion	0.8		0.4		2.6
Total expansion capital	0.8		1.5		16.1
Total capital expenditures	$	100.3	$	75.6	$	63.7

(1) Includes $33.6 million, $29.2 million and $11.9 million of capital expenditures in connection with our current oven rebuild initiative at our Indiana Harbor facility, which began in 2015, for the years ended December 31, 2018, 2017 and 2016, respectively.

(2) Includes $3.2 million, $1.1 million and $2.7 million of interest capitalized in connection with the gas sharing projects for the years ended December 31, 2018, 2017 and 2016, respectively.

(3) Represents capital expenditures for the ship loader expansion project funded with cash withheld in conjunction with the acquisition of CMT. Additionally, this includes capitalized interest of $2.3 million for the year ended December 31, 2016.

In 2019, we expect our capital expenditures to be between $110 million and $120 million, of which approximately $55 million to $60 million will be spent at the Partnership and approximately $40 million to $48 million will be spent on the Indiana Harbor oven rebuild project.

We anticipate spending approximately $150 million on our environmental remediation projects to comply with the expected terms of the consent decree at our Haverhill and Granite City cokemaking operations, of which we have spent approximately $138 million to date, including $7 million spent by the Company prior to the formation of the Partnership. The remaining capital is expected to be spent through the first half of 2019. A portion of the proceeds from the Partnership's initial public offering and subsequent dropdowns were used to fund $119 million of these environmental remediation projects. Pursuant to the omnibus agreement, the Company made capital contributions to the Partnership of $20 million during 2018 for these known environmental remediation projects. The Company expects to make additional capital

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contributions to the Partnership of approximately $5 million in the first half of 2019 for the estimated future spending related to these environmental remediation projects.

Contractual Obligations

The following table summarizes our significant contractual obligations as of December 31, 2018:

			Payment Due Dates
	Total		2019		2020-2021		2022-2023		Thereafter
	(Dollars in millions)
Total borrowings:(1)
Principal	$	859.0	$	3.9	$	14.1	$	141.0	$	700.0
Interest	365.0		60.5		120.1		107.8		76.6
Operating leases(2)	5.4		2.0		2.1		0.6		0.7
Purchase obligations:
Coal(3)(4)	830.2		797.6		32.6		—		—
Transportation and coal handling(5)	98.6		33.1		26.2		12.9		26.4
Other(6)	9.4		2.9		3.2		2.4		0.9
Total	$	2,167.6	$	900.0	$	198.3	$	264.7	$	804.6

(1) At December 31, 2018, debt consists of $700.0 million of Partnership Notes, $43.9 million of Term Loan, $10.1 million of Partnership Financing Obligation and $105.0 million of Partnership Revolver. Projected interest costs on variable rate instruments were calculated using market rates at December 31, 2018.

(2) Our operating leases include leases for land, locomotives, office equipment and other property and equipment. Operating leases include all operating leases that have initial noncancelable terms in excess of one year.

(3) Certain coal procurement contracts included in the table above were not executed at December 31, 2018. We estimate these contracts to be approximately $159 million of purchase obligations in 2019 and expect these to be finalized in the first quarter of 2019.

(4) One of the coal procurement contracts at our Jewell cokemaking facility has minimum volume requirements through 2020, with pricing set annually. Projected purchase obligations were calculated using 2019 pricing.

(5) Transportation and coal handling services consist primarily of railroad and terminal services attributable to delivery and handling of coal purchases and coke sales. Long-term commitments generally relate to locations for which limited transportation options exist and match the length of the related coke sales agreement.

(6) Primarily represents open purchase orders for materials, supplies and services.

A purchase obligation is an enforceable and legally binding agreement to purchase goods or services that specifies significant terms, including: fixed or minimum quantities to be purchased; fixed, minimum or variable price provisions; and the approximate timing of the transaction. Our principal purchase obligations in the ordinary course of business consist of coal and transportation and distribution services, including railroad services. We also have contractual obligations supporting financing arrangements of third-parties, contracts to acquire or construct properties, plants and equipment, and other contractual obligations, primarily related to services and materials. Most of our coal purchase obligations are based on fixed prices. These purchase obligations generally include fixed or minimum volume requirements. Transportation and distribution obligations also typically include required minimum volume commitments. The purchase obligation amounts in the table above are based on the minimum quantities or services to be purchased at estimated prices to be paid based on current market conditions. Accordingly, the actual amounts may vary significantly from the estimates included in the table.

Off-Balance Sheet Arrangements

We have letters of credit disclosed in Note 12 to the consolidated financial statements as well as operating leases disclosed in Note 13 to the consolidated financial statements. Additionally, we had outstanding surety bonds with third parties of approximately $24 million as of December 31, 2018 to secure reclamation and other performance commitments. Other than these arrangements, the Company has not entered into any transactions, agreements or other contractual arrangements that would result in material off-balance sheet liabilities.

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Impact of Inflation

Although the impact of inflation has been relatively low in recent years, it is still a factor in the U.S. economy and may increase the cost to acquire or replace properties, plants, and equipment and may increase the costs of labor and supplies. To the extent permitted by competition, regulation and existing agreements, we have generally passed along increased costs to our customers in the form of higher fees and we expect to continue this practice.

Critical Accounting Policies

A summary of our significant accounting policies is included in Note 2 to the consolidated financial statements. Our management believes that the application of these policies on a consistent basis enables us to provide the users of the financial statements with useful and reliable information about our operating results and financial condition. The preparation of our consolidated financial statements requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and the disclosures of contingent assets and liabilities. Significant items that are subject to such estimates and assumptions consist of: (1) accounting for impairments of goodwill and (2) black lung benefit obligations. Although our management bases its estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances, actual results may differ to some extent from the estimates on which our consolidated financial statements have been prepared at any point in time. Despite these inherent limitations, our management believes the “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and consolidated financial statements and footnotes provide a meaningful and fair perspective of our financial condition.

Accounting for Impairments of Goodwill

Goodwill, which represents the excess of the purchase price over the fair value of the net assets acquired, is tested for impairment as of October 1 of each year, or when events occur or circumstances change that would, more likely than not, reduce the fair value of the reporting unit to below its carrying value. We perform our annual goodwill impairment test by comparing the fair value of the reporting unit with its carrying amount. We would recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value.

The Logistics reporting unit had goodwill of $73.5 million as of December 31, 2018. The goodwill analysis as of October 1^st resulted in the fair value of the Logistics reporting unit, which was determined based on a discounted cash flow analysis, exceeding its carrying value by approximately 30 percent. A significant portion of our logistics business holds long-term, take-or-pay contracts with Murray American Coal Inc. ("Murray") and Foresight Energy LLC ("Foresight"). Key assumptions in our goodwill impairment test include continued customer performance against long-term, take-or-pay contracts, renewal of future long-term, take-or-pay contracts, incremental merchant businessand a 14 percent discount rate representing the estimated weighted average cost of capital for this business line. The use of different assumptions, estimates or judgments, such as the estimated future cash flows of Logistics and the discount rate used to discount such cash flows, could significantly impact the estimated fair value of a reporting unit, and therefore, impact the excess fair value above carrying value of the reporting unit. A 100 basis point change in the discount rate would not have reduced the fair value of the reporting unit below its carrying value.

Black Lung Benefit Liabilities

The Company has obligations related to coal workers’ pneumoconiosis, or black lung, benefits to certain of our former coal miners and their dependents. Such benefits are provided for under Title IV of the Federal Coal Mine and Safety Act of 1969 and subsequent amendments, as well as for black lung benefits provided in the states of Virginia, Kentucky and West Virginia pursuant to workers’ compensation legislation. The Patient Protection and Affordable Care Act (“PPACA”), which was implemented in 2010, amended previous legislation related to coal workers’ black lung obligations. PPACA provides for the automatic extension of awarded lifetime benefits to surviving spouses and changes the legal criteria used to assess and award claims. We act as a self-insurer for both state and federal black lung benefits and adjust our liability each year based upon actuarial calculations of our expected future payments for these benefits.

Our independent actuarial consultants calculate the present value of the estimated black lung liability annually based on actuarial models utilizing our population of former coal miners, historical payout patterns of both the Company and the industry, actuarial mortality rates, disability incidence, medical costs, death benefits, dependents, discount rates and the current federally mandated payout rates. The estimated liability may be impacted by future changes in the statutory mechanisms, modifications by court decisions and changes in filing patterns driven by perceptions of success by claimants and their advisors, the impact of which cannot be estimated.

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The following table summarizes discount rates utilized, active claims, and the total black lung liabilities:

	December 31,
	2018			2017
Discount rate(1)	4.0		%	3.3		%
Active claims	345			351
Black lung liability (dollars in millions)(2)	$	49.4		$	50.3

(1) The discount rate is determined based on a portfolio of high-quality corporate bonds with maturities that are consistent with the estimated duration of our black lung obligations. A decrease of 25 basis points in the discount rate would have increased black lung expense by $1.1 million in 2018.

(2) The current portion of the black lung liability was $4.5 million and $5.4 million at December 31, 2018 and 2017, respectively, and was included in accrued liabilities on the Consolidated Balance Sheets.

The following table summarizes annual black lung payments and expense:

	Years Ended December 31,
	2018		2017		2016
	(Dollars in millions)
Payments	$	6.3	$	7.4	$	7.8
Expense	$	5.4	$	7.5	$	8.1

Recent Accounting Standards

See Note 2 to our consolidated financial statements.

52

Non-GAAP Financial Measures

In addition to the GAAP results provided in the Annual Report on Form 10-K, we have provided a non-GAAP financial measure, Adjusted EBITDA. Our management, as well as certain investors, uses this non-GAAP measure to analyze our current and expected future financial performance and liquidity. This measure is not in accordance with, or a substitute for, GAAP and may be different from, or inconsistent with, non-GAAP financial measures used by other companies. See Note 19 in our consolidated financial statements for both the definition of Adjusted EBITDA and reconciliations from GAAP to the non-GAAP measurement for 2018, 2017 and 2016.

Below is a reconciliation of 2019 Adjusted EBITDA guidance from its closest GAAP measures:

	2019
	Low			High
Net Cash Provided by Operating activities	$	180		$	195
Subtract:
Depreciation and amortization expense	150			145
Changes in working capital and other	(14		)	(1		)
Net Income	$	44		$	51
Add:
Depreciation and amortization expense	150			145
Interest expense, net	65			65
Income tax expense	6			14
Adjusted EBITDA	$	265		$	275
Subtract: Adjusted EBITDA attributable to noncontrolling interest(1)	83			87
Adjusted EBITDA attributable to SunCoke Energy, Inc.	$	182		$	188

(1) Reflects non-controlling interests in Indiana Harbor and the portion of the Partnership owned by public unitholders.

53

CAUTIONARY STATEMENT CONCERNING FORWARD-LOOKING STATEMENTS

We have made forward-looking statements in this Annual Report on Form 10-K, including, among others, in the sections entitled “Business,” “Risk Factors,” "Quantitative and Qualitative Disclosures About Market Risk" and “Management’s Discussion and Analysis of Financial Condition and Results of Operations.” Such forward-looking statements are based on management’s beliefs and assumptions and on information currently available. Forward-looking statements include the information concerning our possible or assumed future results of operations, business strategies, financing plans, competitive position, potential growth opportunities, potential operating performance, the effects of competition and the effects of future legislation or regulations. Forward-looking statements include all statements that are not historical facts and may be identified by the use of forward-looking terminology such as the words “believe,” “expect,” “plan,” “intend,” “anticipate,” “estimate,” “predict,” “potential,” “continue,” “may,” “will,” “should” or the negative of these terms or similar expressions. In particular, statements in this Annual Report on Form 10-K concerning future dividend declarations are subject to approval by our Board of Directors and will be based upon circumstances then existing.

Forward-looking statements involve risks, uncertainties and assumptions. Actual results may differ materially from those expressed in these forward-looking statements. You should not put undue reliance on any forward-looking statements. We do not have any intention or obligation to update any forward-looking statement (or its associated cautionary language), whether as a result of new information or future events, after the date of this Annual Report on Form 10-K, except as required by applicable law.

The risk factors discussed in “Risk Factors” could cause our results to differ materially from those expressed in the forward-looking statements made in this Annual Report on Form 10-K. There also may be other risks that we are unable to predict at this time. Such risks and uncertainties include, without limitation:

• changes in levels of production, production capacity, pricing and/or margins for coal and coke;

• variation in availability, quality and supply of metallurgical coal used in the cokemaking process, including as a result of non-performance by our suppliers;

• changes in the marketplace that may affect our logistics business, including the supply and demand for thermal and metallurgical coal;

• changes in the marketplace that may affect our cokemaking business, including the supply and demand for our coke products, as well as increased imports of coke from foreign producers;

• competition from alternative steelmaking and other technologies that have the potential to reduce or eliminate the use of coke;

• our dependence on, relationships with, and other conditions affecting our customers;

• our dependence on, relationships with, and other conditions affecting our suppliers;

• severe financial hardship or bankruptcy of one or more of our major customers, or the occurrence of a customer default or other event affecting our ability to collect payments from our customers;

• volatility and cyclical downturns in the steel industry and in other industries in which our customers and/or suppliers operate;

• volatility, cyclical downturns and other change in the business climate and market for coal, affecting customers or potential customers for the Partnership's logistics business;

• our significant equity interest in the Partnership;

• our ability to repair aging coke ovens to maintain operational performance;

• our ability to enter into new, or renew existing, long-term agreements upon favorable terms for the sale of coke, steam, or electric power, or for handling services of coal and other aggregates (including transportation, storage and mixing);

• the Partnership's ability to enter into new, or renew existing, agreements upon favorable terms for logistics services;

• our ability to identify acquisitions, execute them under favorable terms, and integrate them into our existing business operations;

54

• our ability to consummate investments under favorable terms, including with respect to existing cokemaking facilities, which may utilize by-product technology, and integrate them into our existing businesses and have them perform at anticipated levels;

• our ability to develop, design, permit, construct, start up, or operate new cokemaking facilities in the U.S. or in foreign countries;

• our ability to successfully implement domestic and/or our international growth strategies;

• our ability to realize expected benefits from investments and acquisitions;

• age of, and changes in the reliability, efficiency and capacity of the various equipment and operating facilities used in our cokemaking operations, and in the operations of our subsidiaries major customers, business partners and/or suppliers;

• changes in the expected operating levels of our assets;

• our ability to meet minimum volume requirements, coal-to-coke yield standards and coke quality standards in our coke sales agreements;

• changes in the level of capital expenditures or operating expenses, including any changes in the level of environmental capital, operating or remediation expenditures;

• our ability to service our outstanding indebtedness;

• our ability to comply with the restrictions imposed by our financing arrangements;

• our ability to comply with applicable federal, state or local laws and regulations, including, but not limited to, those relating to environmental matters;

• nonperformance or force majeure by, or disputes with, or changes in contract terms with, major customers, suppliers, dealers, distributors or other business partners;

• availability of skilled employees for our cokemaking, and/or logistics operations, and other workplace factors;

• effects of railroad, barge, truck and other transportation performance and costs, including any transportation disruptions;

• effects of adverse events relating to the operation of our facilities and to the transportation and storage of hazardous materials or regulated media (including equipment malfunction, explosions, fires, spills, impoundment failure and the effects of severe weather conditions);

• effects of adverse events relating to the business or commercial operations of our customers and/or suppliers;

• disruption in our information technology infrastructure and/or loss of our ability to securely store, maintain, or transmit data due to security breach by hackers, employee error or malfeasance, terrorist attack, power loss, telecommunications failure or other events;

• our ability to enter into joint ventures and other similar arrangements under favorable terms;

• our ability to consummate assets sales, other divestitures and strategic restructuring in a timely manner upon favorable terms, and/or realize the anticipated benefits from such actions;

• changes in the availability and cost of equity and debt financing;

• impacts on our liquidity and ability to raise capital as a result of changes in the credit ratings assigned to our indebtedness;

• changes in credit terms required by our suppliers;

• risks related to labor relations and workplace safety;

• proposed or final changes in existing, or new, statutes, regulations, rules, governmental policies and taxes, or their interpretations, including those relating to environmental matters and taxes;

• the existence of hazardous substances or other environmental contamination on property owned or used by us;

• the availability of future permits authorizing the disposition of certain mining waste and the management of reclamation areas;

55

• risks related to obligations under mineral leases retained by us in connection with the divestment of our legacy coal mining business;

• risks related to environmental compliance;

• risks related to the ability of the assignee(s) to perform in compliance with applicable requirements under mineral leases assigned in connection with the divestment of our legacy coal mining business;

• claims of noncompliance with any statutory or regulatory requirements;

• proposed or final changes in accounting and/or tax methodologies, laws, regulations, rules, or policies, or their interpretations, including those affecting inventories, leases, post-employment benefits, income, or other matters;

• historical consolidated financial data may not be reliable indicator of future results;

• public company costs;

• our indebtedness and certain covenants in our debt documents;

• our ability to secure new coal supply agreements or to renew existing coal supply agreements;

• required permits and other regulatory approvals and compliance with contractual obligations and/or bonding requirements in connection with our cokemaking, logistics operations, and/or former coal mining activities;

• changes in product specifications for the coke that we produce or the coals we mix, store and transport;

• changes in insurance markets impacting cost, level and/or types of coverage available, and the financial ability of our insurers to meet their obligations;

• changes in tax laws or their interpretations, including regulations governing the federal income tax treatment of the Partnership;

• volatility in foreign currency exchange rates affecting the markets and geographic regions in which we conduct business;

• the accuracy of our estimates of reclamation and other mine closure obligations;

• inadequate protection of our intellectual property rights; and

• effects of geologic conditions, weather, natural disasters and other inherent risks beyond our control.

The factors identified above are believed to be important factors, but not necessarily all of the important factors, that could cause actual results to differ materially from those expressed in any forward-looking statement made by us. Other factors not discussed herein also could have material adverse effects on us. All forward-looking statements included in this Annual Report on Form 10-K are expressly qualified in their entirety by the foregoing cautionary statements.

56

Item 7A. Quantitative and Qualitative Disclosures About Market Risk

Our primary areas of market risk include changes in: (1) the price of coal, which is the key raw material for our cokemaking business; (2) interest rates; and (3) foreign currency exchange rates. We do not enter into any market risk sensitive instruments for trading purposes.

Price of coal

We did not use derivatives to hedge any of our coal purchases or sales. Although we have not previously done so, we may enter into derivative financial instruments from time to time in the future to economically manage our exposure related to these market risks.

For our Domestic Coke segment, the largest component of the price of our coke is coal cost. However, under the coke sales agreements at all of our Domestic Coke cokemaking facilities, coal costs are a pass-through component of the coke price, provided that we are able to realize certain targeted coal-to-coke yields. As such, when targeted coal-to-coke yields are achieved, the price of coal is not a significant determining factor in the profitability of these facilities. The coal component of the Jewell coke price is based on the weighted-average contract price of third-party coal purchases at our Haverhill facility applicable to AM USA coke sales. Therefore, we are subject to market risk to the extent the cost to procure coal at Jewel differs from the amount allowable to be passed through to our customer based on Haverhill's coal price.

The provisions of our coke sales agreements require us to meet minimum production levels and generally require us to secure replacement coke supplies at the prevailing market price if we do not meet contractual minimum volumes. Because market prices for coke are generally highly correlated to market prices for metallurgical coal, to the extent any of our facilities are unable to produce their contractual minimum volumes, we are subject to market risk related to the procurement of replacement supplies.

Interest rates

We are exposed to changes in interest rates as a result of borrowing activities with variable interest rates and interest earned on our cash balances. During the years ended December 31, 2018 and 2017, the daily average outstanding balance on borrowings with variable interest rates was $172.5 million and $184.3 million, respectively. Assuming a 50 basis point change in LIBOR, interest expense would have been impacted by $0.9 million in 2018 and 2017, respectively. At December 31, 2018, we had outstanding borrowings with variable interest rates of $105.0 million under the Partnership Revolver and $43.9 million under the Term Loan.

At December 31, 2018 and 2017, we had cash and cash equivalents of $145.7 million and $120.2 million, respectively, which accrues interest at various rates. Assuming a 50 basis point change in the rate of interest associated with our cash and cash equivalents, interest income would have been impacted by $0.7 million and $0.6 million for the years ended December 31, 2018 and 2017, respectively.

Foreign currency

Because we operate outside the U.S., we are subject to risk resulting from changes in the Brazil Real currency exchange rates. The currency exchange rates are influenced by a variety of economic factors including local inflation, growth, interest rates and governmental actions, as well as other factors. Revenues and expenses of our foreign operations are translated at average exchange rates during the period and balance sheet accounts are translated at period-end exchange rates. Balance sheet translation adjustments are excluded from the results of operations and are recorded in equity as a component of accumulated other comprehensive loss. If the currency exchange rates had changed by 10 percent, we estimate the impact to our net income in 2018 and 2017 would have been approximately $0.4 million and $0.5 million, respectively.

57

Item 8. Financial Statements and Supplementary Data

INDEX TO FINANCIAL STATEMENTS

	Page
Report of Independent Registered Public Accounting Firm	59
Consolidated Statements of Income for the Years Ended December 31, 2018, 2017 and 2016	61
Consolidated Statements of Comprehensive Income for the Years Ended December 31, 2018, 2017 and 2016	62
Consolidated Balance Sheets at December 31, 2018 and 2017	63
Consolidated Statements of Cash Flows for the Years Ended December  31, 2018, 2017 and 2016	64
Consolidated Statements of Equity for the Years Ended December 31, 2018, 2017, and 2016	65
Notes to Consolidated Financial Statements	68
1. General and Basis of Presentation	68
2. Summary of Significant Accounting Policies	69
3. Acquisition of Noncontrolling Interest	72
4. Customer Concentrations	73
5. Income Taxes	75
6. Inventories	78
7. Properties, Plants, and Equipment, Net	78
8. Goodwill and Other Intangible Assets	78
9. Asset Retirement Obligations	80
10. Retirement Benefit Plans	80
11. Accrued Liabilities	83
12. Debt and Financing Obligation	83
13. Commitments and Contingent Liabilities	85
14. Accumulated Other Comprehensive Loss	87
15. Share-Based Compensation	88
16. Earnings Per Share	93
17. Fair Value Measurements	94
18. Revenue From Customers with Contracts	95
19. Business Segment Information	96
20. Selected Quarterly Data (unaudited)	100
21. Supplemental Condensed Combining and Consolidating Financial Information	101

58

Report of Independent Registered Public Accounting Firm

To the stockholders and board of directors

SunCoke Energy, Inc.:

Opinions on the Consolidated Financial Statements and Internal Control Over Financial Reporting

We have audited the accompanying consolidated balance sheets of SunCoke Energy, Inc. and subsidiaries (the “Company”) as of December 31, 2018 and 2017, the related consolidated statements of income, comprehensive income, equity, and cash flows for each of the years in the three-year period ended December 31, 2018, and the related notes (collectively, the “consolidated financial statements”). We also have audited the Company’s internal control over financial reporting as of December 31, 2018, based on criteria established in Internal Control - Integrated Framework(2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2018 and 2017, and the results of its operations and its cash flows for each of the years in the three-year period ended December 31, 2018, in conformity with U.S. generally accepted accounting principles. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2018, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.

Basis for Opinion

The Company’s management is responsible for these consolidated financial statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s consolidated financial statements and an opinion on the Company’s internal control over financial reporting based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (“PCAOB”) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material respects.

Our audits of the consolidated financial statements included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

Definition and Limitations of Internal Control Over Financial Reporting

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

59

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

/s/ KPMG LLP

We have served as the Company’s auditor since 2015.

Chicago, Illinois

February 15, 2019

60

SunCoke Energy, Inc.

Consolidated Statements of Income

	Years Ended December 31,
	2018		2017			2016
	(Dollars and shares in millions, except per share amounts)
Revenues
Sales and other operating revenue	$	1,450.9	$	1,331.5		$	1,223.3
Costs and operating expenses
Cost of products sold and operating expenses	1,124.5		1,020.1			905.9
Selling, general and administrative expenses	66.1		79.0			90.6
Depreciation and amortization expense	141.6		128.2			114.2
Loss on divestiture of business	—		—			14.7
Total costs and operating expenses	1,332.2		1,227.3			1,125.4
Operating income	118.7		104.2			97.9
Interest expense, net	61.4		61.9			54.8
Loss (gain) on extinguishment of debt	0.3		20.4			(25.0		)
Income before income tax expense (benefit) and loss from equity method investment	57.0		21.9			68.1
Income tax expense (benefit)	4.6		(81.6		)	8.6
Loss from equity method investment	5.4		—			—
Net income	47.0		103.5			59.5
Less: Net income (loss) attributable to noncontrolling interests	20.8		(18.9		)	45.1
Net income attributable to SunCoke Energy, Inc.	$	26.2	$	122.4		$	14.4
Earnings attributable to SunCoke Energy, Inc. per common share:
Basic	$	0.40	$	1.90		$	0.22
Diluted	$	0.40	$	1.88		$	0.22
Weighted average number of common shares outstanding:
Basic	64.7		64.3			64.2
Diluted	65.5		65.2			64.4

(See Accompanying Notes)

61

SunCoke Energy, Inc.

Consolidated Statements of Comprehensive Income

	Years Ended December 31,
	2018			2017			2016
	(Dollars in millions)
Net income	$	47.0		$	103.5		$	59.5
Other comprehensive income (loss):
Reclassifications of actuarial loss amortization and prior service benefit to earnings (net of related tax expense of zero for all years)	(0.1		)	0.2			—
Retirement benefit plans funded status adjustment (net of related tax benefit of $0.2 million, $0.3 million and $0.1 million, respectively)	0.6			(0.8		)	(0.2		)
Currency translation adjustment	(1.4		)	(0.5		)	1.0
Recognition of accumulated currency translation loss upon sale of equity method investment	9.0			—			—
Comprehensive income	55.1			102.4			60.3
Less: Comprehensive income (loss) attributable to noncontrolling interests	20.8			(18.9		)	45.1
Comprehensive income attributable to SunCoke Energy, Inc.	$	34.3		$	121.3		$	15.2

(See Accompanying Notes)

62

SunCoke Energy, Inc.

Consolidated Balance Sheets

	December 31,
	2018			2017
	(Dollars in millions,  except par value amounts)
Assets
Cash and cash equivalents	$	145.7		$	120.2
Receivables	75.4			68.5
Inventories	110.4			111.0
Income tax receivable	0.7			4.8
Other current assets	2.8			6.7
Total current assets	335.0			311.2
Properties, plants and equipment (net of accumulated depreciation of $855.8 million and $733.2 million at December 31, 2018 and 2017, respectively)	1,471.1			1,501.3
Goodwill	76.9			76.9
Other intangible assets, net	156.8			167.9
Deferred charges and other assets	5.5			2.8
Total assets	$	2,045.3		$	2,060.1
Liabilities and Equity
Accounts payable	$	115.0		$	115.5
Accrued liabilities	45.6			53.2
Deferred revenue	3.0			1.7
Current portion of long-term debt and financing obligation	3.9			2.6
Interest payable	3.6			5.4
Total current liabilities	171.1			178.4
Long-term debt and financing obligation	834.5			861.1
Accrual for black lung benefits	44.9			44.9
Retirement benefit liabilities	25.2			28.2
Deferred income taxes	254.7			257.8
Asset retirement obligations	14.6			14.0
Other deferred credits and liabilities	17.6			16.1
Total liabilities	1,362.6			1,400.5
Equity
Preferred stock, $0.01 par value. Authorized 50,000,000 shares; no issued shares at both December 31, 2018 and 2017	—			—
Common stock, $0.01 par value. Authorized 300,000,000 shares; issued 72,233,750 and 72,006,905 shares at December 31, 2018 and 2017, respectively	0.7			0.7
Treasury stock, 7,477,657 shares at both December 31, 2018 and 2017, respectively	(140.7		)	(140.7		)
Additional paid-in capital	488.8			486.2
Accumulated other comprehensive loss	(13.1		)	(21.2		)
Retained earnings	127.4			101.2
Total SunCoke Energy, Inc. stockholders' equity	463.1			426.2
Noncontrolling interests	219.6			233.4
Total equity	682.7			659.6
Total liabilities and equity	$	2,045.3		$	2,060.1

(See Accompanying Notes)

63

SunCoke Energy, Inc.

Consolidated Statements of Cash Flows

	Years Ended December 31,
	2018			2017			2016
	(Dollars in millions)
Cash Flows from Operating Activities:
Net income	$	47.0		$	103.5		$	59.5
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	141.6			128.2			114.2
Deferred income tax (benefit) expense	(3.4		)	(87.2		)	3.1
Payments in excess of expense for postretirement plan benefits	(2.4		)	(1.8		)	(2.6		)
Share-based compensation expense	3.1			4.8			6.5
Loss (gain) on extinguishment of debt, net	0.3			20.4			(25.0		)
Loss on divestiture of business	—			—			14.7
Loss from equity method investment	5.4			—			—
Changes in working capital pertaining to operating activities (net of the effects of divestiture):
Receivables	(6.9		)	(7.8		)	3.7
Inventories	0.6			(18.5		)	29.4
Accounts payable	(0.7		)	11.7			(0.8		)
Accrued liabilities	(7.3		)	2.6			6.8
Deferred revenue	1.3			(0.8		)	0.4
Interest payable	(1.8		)	(10.8		)	(2.7		)
Income taxes	4.5			(0.2		)	7.0
Other	4.5			4.4			4.9
Net cash provided by operating activities	185.8			148.5			219.1
Cash Flows from Investing Activities:
Capital expenditures	(100.3		)	(75.6		)	(63.7		)
Return of Brazilian investment	—			20.5			20.5
Divestiture of coal business	—			—			(12.8		)
Sale of equity method investment	4.0			—			—
Other investing activities	0.5			—			2.1
Net cash used in investing activities	(95.8		)	(55.1		)	(53.9		)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt	45.0			693.7			—
Repayment of long-term debt	(45.7		)	(644.9		)	(66.1		)
Debt issuance costs	(0.5		)	(17.4		)	(0.2		)
Proceeds from revolving facility	179.5			350.0			28.0
Repayment of revolving facility	(204.5		)	(392.0		)	(98.4		)
Proceeds from financing obligation	—			—			16.2
Repayment of financing obligation	(2.6		)	(2.5		)	(1.0		)
Cash distributions to noncontrolling interests	(31.9		)	(47.0		)	(49.4		)
Acquisition of additional interest in the Partnership	(4.2		)	(48.7		)	—
Other financing activities	0.4			1.1			(1.4		)
Net cash used in financing activities	(64.5		)	(107.7		)	(172.3		)
Net increase (decrease) in cash, cash equivalents and restricted cash	25.5			(14.3		)	(7.1		)
Cash, cash equivalents and restricted cash at beginning of year	120.2			134.5			141.6
Cash, cash equivalents and restricted cash at end of year	$	145.7		$	120.2		$	134.5
Supplemental Disclosure of Cash Flow Information
Interest paid, net of capitalized interest of $3.2 million, $1.1 million and $5.0 million, respectively	$	59.6		$	67.9		$	53.4
Income taxes paid, net of refunds of $4.3 million, $1.0 million and $8.2 million, respectively	$	3.7		$	5.8		$	(2.3	)

(See Accompanying Notes)

64

SunCoke Energy, Inc.

Consolidated Statements of Equity

	Common Stock			Treasury Stock				Additional Paid-In Capital			Accumulated Other Comprehensive Loss			Retained Earnings			Total SunCoke Energy, Inc. Equity			Non- controlling Interests			Total Equity
	Shares	Amount		Shares	Amount
	(Dollars in millions)
At December 31, 2015	71,489,448	$	0.7	7,477,657	$	(140.7	)	$	486.1		$	(19.8	)	$	(36.4	)	$	289.9		$	332.9		$	622.8
Net income	—	—		—	—			—			—			14.4			14.4			45.1			59.5
Retirement benefit plans funded status adjustment (net of related tax benefit of $0.1 million)	—	—		—	—			—			(0.2		)	—			(0.2		)	—			(0.2		)
Currency translation adjustment	—	—		—	—			—			1.0			—			1.0			—			1.0
Cash distribution to noncontrolling interests, net of unit issuances	—	—		—	—			—			—			—			—			(49.2		)	(49.2		)
Share-based compensation expense	—	—		—	—			6.5			—			—			6.5			—			6.5
Share issuances, net of shares withheld for taxes and other equity activities	217,856	—		—	—			(0.5		)	—			—			(0.5		)	—			(0.5		)
At December 31, 2016	71,707,304	$	0.7	7,477,657	$	(140.7	)	$	492.1		$	(19.0	)	$	(22.0	)	$	311.1		$	328.8		$	639.9

(See Accompanying Notes)

65

SunCoke Energy, Inc.

Consolidated Statements of Equity

	Common Stock			Treasury Stock				Additional Paid-In Capital			Accumulated Other Comprehensive Loss			Retained Earnings			Total SunCoke Energy, Inc. Equity			Non- controlling Interests			Total Equity
	Shares	Amount		Shares	Amount
	(Dollars in millions)
At December 31, 2016	71,707,304	$	0.7	7,477,657	$	(140.7	)	$	492.1		$	(19.0	)	$	(22.0	)	$	311.1		$	328.8		$	639.9
Net income (loss)	—	—		—	—			—			—			122.4			122.4			(18.9		)	103.5
Reclassifications of prior service cost and actuarial loss amortization to earnings (net of related tax expense of zero)	—	—		—	—			—			0.2			—			0.2			—			0.2
Retirement benefit plans funded status adjustment (net of related tax benefit of $0.3 million)	—	—		—	—			—			(0.8		)	—			(0.8		)	—			(0.8		)
Currency translation adjustment	—	—		—	—			—			(0.5		)	—			(0.5		)	—			(0.5		)
Cash distribution to noncontrolling interest	—	—		—	—			—			—			—			—			(47.0		)	(47.0		)
Share-based compensation expense	—	—		—	—			4.7			—			—			4.7			0.1			4.8
Share-issuances, net of shares withheld for taxes	299,601			—	—			1.1			—			—			1.1			—			1.1
Acquisition of additional interest in the Partnership:
Cash paid	—	—		—	—			(19.1		)	—			—			(19.1		)	(29.6		)	(48.7		)
Deferred tax adjustment	—	—		—	—			7.1			—			—			7.1			—			7.1
Cumulative effect from adoption of ASU 2016-09	—	—		—	—			0.3			—			(0.3		)	—			—			—
Cumulative effect from adoption of ASU 2018-02	—	—		—	—			—			(1.1		)	1.1			—			—			—
At December 31, 2017	72,006,905	$	0.7	7,477,657	$	(140.7	)	$	486.2		$	(21.2	)	$	101.2		$	426.2		$	233.4		$	659.6

(See Accompanying Notes)

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SunCoke Energy, Inc.

Consolidated Statements of Equity

	Common Stock			Treasury Stock				Additional Paid-In Capital			Accumulated Other Comprehensive Loss			Retained Earnings		Total SunCoke Energy, Inc. Equity			Non- controlling Interests			Total Equity
	Shares	Amount		Shares	Amount
	(Dollars in millions)
At December 31, 2017	72,006,905	$	0.7	7,477,657	$	(140.7	)	$	486.2		$	(21.2	)	$	101.2	$	426.2		$	233.4		$	659.6
Net income	—	—		—	—			—			—			26.2		26.2			20.8			47.0
Reclassification of prior service cost and actuarial loss amortization to earnings, net of tax	—	—		—	—			—			(0.1		)	—		(0.1		)	—			(0.1		)
Retirement benefit plans funded status adjustment (net of related tax benefit of $0.2 million)	—	—		—	—			—			0.6			—		0.6			—			0.6
Currency translation adjustment	—	—		—	—			—			(1.4		)	—		(1.4		)	—			(1.4		)
Recognition of accumulated currency translation loss upon sale of equity method investment	—	—		—	—			—			9.0			—		9.0			—			9.0
Cash distribution to noncontrolling interests	—	—		—	—			—			—			—		—			(31.9		)	(31.9		)
Share-based compensation expense	—	—		—	—			3.1			—			—		3.1			—			3.1
Share-issuances, net of shares withheld for taxes	226,845	—		—	—			0.7			—			—		0.7			—			0.7
Acquisition of additional interest in the Partnership:
Cash paid	—	—		—	—			(1.5		)	—			—		(1.5		)	(2.7		)	(4.2		)
Deferred tax adjustment	—	—		—	—			0.3			—			—		0.3			—			0.3
At December 31, 2018	72,233,750	$	0.7	7,477,657	$	(140.7	)	$	488.8		$	(13.1	)	$	127.4	$	463.1		$	219.6		$682.7

(See Accompanying Notes)

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SunCoke Energy, Inc.

Notes to Consolidated Financial Statements

1. General and Basis of Presentation

Description of Business

SunCoke Energy, Inc. (“SunCoke Energy,” “SunCoke,” “Company,” “we,” “our” and “us”) is the largest independent producer of high-quality coke in the Americas, as measured by tons of coke produced each year, and has over 55 years of coke production experience. Coke is a principal raw material in the blast furnace steelmaking process and is produced by heating metallurgical coal in a refractory oven, which releases certain volatile components from the coal, thus transforming the coal into coke. Additionally, we own and operate a logistics business, which primarily provides handling and/or mixing services of coal and other aggregates to third-party customers as well as to our own cokemaking facilities.

We have designed, developed, built, own and operate fivecokemaking facilities in the United States (“U.S.”) with collective nameplate capacity to produce approximately 4.2 million tons of coke per year. Additionally, we have designed and operate onecokemaking facility in Brazil under licensing and operating agreements on behalf of ArcelorMittal Brasil S.A. ("ArcelorMittal Brazil”), which has approximately 1.7 million tons of annual cokemaking capacity.

Our cokemaking ovens utilize efficient, modern heat recovery technology designed to combust the coal’s volatile components liberated during the cokemaking process and use the resulting heat to create steam or electricity for sale. This differs from by-product cokemaking, which repurposes the coal’s liberated volatile components for other uses. We have constructed the only greenfield cokemaking facilities in the U.S. in approximately 30years and are the only North American coke producer that utilizes heat recovery technology in the cokemaking process. We provide steam pursuant to steam supply and purchase agreements with our customers. Electricity is sold into the regional power market or pursuant to energy sales agreements.

Our logistics business provides handling and/or mixing services to steel, coke (including some of our domestic cokemaking facilities), electric utility, coal producing and other manufacturing based customers. The logistics business has terminals in Indiana, West Virginia, Virginia, and Louisiana with collective capacity to mix and/or transload more than 40 million tons of coal and other aggregates annually and has total storage capacity of approximately 3 million tons.

On June 27, 2018, we sold our 49 percent investment in VISA SunCoke Limited ("VISA SunCoke") for cash consideration of $4.0 million. Consequently, we recognized $9.0 million of accumulated currency translation losses and incurred $0.4 million of transaction costs, resulting in a net $5.4 million loss from equity method investment during 2018 on the Consolidated Statements of Income. Our investment in VISA SunCoke was previously accounted for as an equity method investment and was fully impaired in 2015. Therefore, its financial results had not been included in our financial statements since that time.

The Company disposed of its coal mining operations in Virginia and West Virginia to Revelation Energy, LLC ("Revelation") in April 2016. Revelation assumed substantially all of our remaining coal mining assets and real estate, and was assigned substantially all of our mineral leases and a substantial portion of our mining reclamation obligations. Under the terms of the agreement, Revelation received $12.8 million from the Company to take ownership of the assets and liabilities. During 2016, the Company recognized losses associated with this divestiture of $14.7 million.

Our consolidated financial statements include SunCoke Energy Partners, L.P. (the "Partnership"), a publicly-traded partnership. At December 31, 2018, we owned the general partner of the Partnership, which consists of a 2.0 percent ownership interest and incentive distribution rights ("IDRs"), and a 60.4 percent limited partner interest in the Partnership. The remaining 37.6 percent interest in the Partnership was held by public unitholders.

On February 5, 2019, the Company and the Partnership announced that they have entered into a definitive agreement whereby SunCoke will acquire all outstanding common units of the Partnership not already owned by SunCoke in a stock-for-unit merger transaction (the “Simplification Transaction”). Pursuant to the terms of this agreement (“Merger Agreement”), the Partnership's unaffiliated common unitholders will receive 1.40 SunCoke common shares plus a fraction of a SunCoke common share, based on a ratio as further described in the Merger Agreement, for each Partnership common unit. On behalf of the Partnership and its public unitholders, the terms of the Simplification Transaction were negotiated, reviewed and approved by the conflicts committee of the Board of Directors of the Partnership's general partner, which consisted solely of independent directors. The transaction was approved by the Board of Directors of the general partner of the Partnership and the Board of Directors of SunCoke.

Following completion of the Simplification Transaction, the Partnership will become a wholly-owned subsidiary of SunCoke, the Partnership's common units will cease to be publicly traded and the Partnership's IDRs will be eliminated.  The

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Simplification Transaction is expected to close late in the second quarter of 2019 or early in the third quarter of 2019, subject to customary closing conditions, including the approval by holders of a majority of the outstanding SunCoke common shares and Partnership common units, as well as customary regulatory approvals. SunCoke indirectly owns the majority of the Partnership common units, which is sufficient to approve the transaction on behalf of the holders of Partnership common units.

Incorporated in Delaware in 2010 and headquartered in Lisle, Illinois, we became a publicly-traded company in 2011, and our stock is listed on the New York Stock Exchange (“NYSE”) under the symbol “SXC.”

Consolidation and Basis of Presentation

The consolidated financial statements of the Company and its subsidiaries were prepared in accordance with accounting principles generally accepted in the U.S. ("GAAP") and include the assets, liabilities, revenues and expenses of the Company and all subsidiaries where we have a controlling financial interest. Intercompany transactions and balances have been eliminated in consolidation. Net income attributable to noncontrolling interest represents the common public unitholders’ interest in SunCoke Energy Partners, L.P. as well as a 14.8 percent third-party interest in our Indiana Harbor cokemaking facility.

2. Summary of Significant Accounting Policies

Use of Estimates

The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and accompanying notes. Actual amounts could differ from these estimates.

Reclassifications

Certain amounts in the prior period consolidated financial statements have been reclassified to conform to the current year presentation. See the "Recently Adopted Accounting Pronouncements" section of this footnote for further details.

Revenue Recognition

The Company sells coke as well as steam and electricity and also provides mixing and/or handling services of coal and other aggregates. The Company also receives fees for operating the cokemaking plant in Brazil and for the licensing of its proprietary technology for use at this facility as well as reimbursement of substantially all of its operating costs. See Note 18.

Substantially all of the coke produced by the Company is sold pursuant to long-term contracts with its customers. The Company evaluates each of its contracts to determine whether the arrangement contains a lease under the applicable accounting standards. If the specific facts and circumstances indicate that it is remote that parties other than the contracted customer will take more than a minor amount of the coke that will be produced by the property, plant and equipment during the term of the coke supply agreement, and the price that the customer is paying for the coke is neither contractually fixed per unit nor equal to the current market price per unit at the time of delivery, then the long-term contract is deemed to contain a lease. The lease component of the price of coke represents the rental payment for the use of the property, plant and equipment, and all such payments are accounted for as contingent rentals as they are only earned by the Company when the coke is delivered and title passes to the customer. The total amount of revenue recognized by the Company for these contingent rentals represents less than 10 percent of consolidated sales and other operating revenues for each of the years ended December 31, 2018, 2017 and 2016. Upon adoption of Accounting Standard Codification ("ASC") 842, "Leases", in 2019, these long-term contracts to sell coke will no longer be deemed to contain operating leases.

Cash Equivalents

The Company considers all highly liquid investments with a remaining maturity of three months or less at the time of purchase to be cash equivalents. These cash equivalents consist principally of certificates of deposit.

Inventories

Inventories are valued at the lower of cost or net realizable value. Cost is determined using the first-in, first-out method, except for the Company’s materials and supplies inventory, which are determined using the average-cost method. The Company utilizes the selling prices under its long-term coke supply contracts to record lower of cost or net realizable value inventory adjustments.

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Properties, Plants and Equipment

Plants and equipment are depreciated on a straight-line basis over their estimated useful lives. Coke and energy plant, machinery and equipment are generally depreciated over 25 to 30 years. Logistics plant and equipment are generally depreciated over 15 to 35 years. Depreciation and amortization is excluded from cost of products sold and operating expenses and is presented separately on the Consolidated Statements of Income. Gains and losses on the disposal or retirement of fixed assets are reflected in earnings when the assets are sold or retired. Amounts incurred that extend an asset’s useful life, increase its productivity or add production capacity are capitalized. The Company accounts for changes in useful lives, when appropriate, as a change in estimate, with prospective application only. The Company capitalized interest of $3.2 million, $1.1 million, and $5.0 million in 2018, 2017 and 2016, respectively. Direct costs, such as outside labor, materials, internal payroll and benefits costs incurred during capital projects are capitalized; indirect costs are not capitalized. Normal repairs and maintenance costs are expensed as incurred.

Impairment of Long-Lived Assets

Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. A long-lived asset, or group of assets, is considered to be impaired when the undiscounted net cash flows expected to be generated by the asset are less than its carrying amount. Such estimated future cash flows are highly subjective and are based on numerous assumptions about future operations and market conditions. The impairment recognized is the amount by which the carrying amount exceeds the fair market value of the impaired asset, or group of assets. It is also difficult to precisely estimate fair market value because quoted market prices for our long-lived assets may not be readily available. Therefore, fair market value is generally based on the present values of estimated future cash flows using discount rates commensurate with the risks associated with the assets being reviewed for impairment.

Goodwill and Other Intangibles

Goodwill, which represents the excess of the purchase price over the fair value of net assets acquired, is tested for impairment as of October 1 of each year, or when events occur or circumstances change that would, more likely than not, reduce the fair value of a reporting unit to below its carrying value. The Company performs its annual goodwill impairment test by comparing the fair value of the reporting unit with its carrying amount. The Company would recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value. See Note 8.

Intangible assets are primarily comprised of permits, customer contracts and customer relationships. Intangible assets are amortized over their useful lives in a manner that reflects the pattern in which the economic benefit of the intangible asset is consumed. Intangible assets are assessed for impairment when a triggering event occurs.

Investment in Brazilian Cokemaking Operations

On November 28, 2016, ArcelorMittal Brazil redeemed SunCoke’s indirectly held preferred and common equity interest in Sol Coqueria Tubarão S.A. ("Brazil Investment"), previously accounted for at cost, for consideration of $41.0 million. The Company received $20.5 million in cash at closing in 2016 and received the remaining $20.5 million in cash, plus interest of $0.2 million, in 2017. Starting in 2016, SunCoke receives $5.1 million in licensing fees per year, in addition to our per ton licensing fee, through 2023 related to the addition of certain patents to its existing intellectual property licensing agreement, which are currently in use by ArcelorMittal Brazil at the Brazil facility. The Company also extended the life of its patents with the Brazilian authorities through 2033, providing opportunity to extend the existing licensing agreement beyond 2023. Licensing fees are included in sales and other operating revenue on the Consolidated Statements of Income.

Income Taxes

Deferred tax asset and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those differences are projected to be recovered or settled. See Note 5.

The Company recognizes uncertain tax positions in its financial statements when minimum recognition threshold and measurement attributes are met in accordance with current accounting guidance. See Note 5.

Black Lung Benefit Liabilities

The Company has obligations related to coal workers’ pneumoconiosis, or black lung, benefits to certain of our former coal miners and their dependents. Such benefits are provided for under Title IV of the Federal Coal Mine and Safety Act of 1969 and subsequent amendments, as well as for black lung benefits provided in the states of Virginia, Kentucky and

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West Virginia pursuant to workers’ compensation legislation. The Patient Protection and Affordable Care Act (“PPACA”), which was implemented in 2010, amended previous legislation related to coal workers’ black lung obligations. PPACA provides for the automatic extension of awarded lifetime benefits to surviving spouses and changes the legal criteria used to assess and award claims. We act as a self-insurer for both state and federal black lung benefits and adjust our liability each year based upon actuarial calculations of our expected future payments for these benefits. See Note 13.

Postretirement Benefit Plan Liabilities

The postretirement benefit plans, which are frozen, are unfunded and the accumulated postretirement benefit obligation is fully recognized on the Consolidated Balance Sheets. Actuarial gains (losses) and prior service costs (benefits) which have not yet been recognized in net income are recognized as a credit (charge) to accumulated other comprehensive income (loss). The credit (charge) to accumulated other comprehensive income (loss), which is reflected net of related tax effects, is subsequently recognized in net income when amortized as a component of postretirement benefit plans expense included in interest expense, net on the Consolidated Statements of Income. See Note 10.

Asset Retirement Obligations

The fair value of a liability for an asset retirement obligation is recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. The associated asset retirement costs are capitalized as part of the carrying amount of the asset and depreciated over its remaining estimated useful life. The Company’s asset retirement obligations primarily relate to costs associated with restoring land to its original state. See Note 9.

Shipping and Handling Costs

Shipping and handling costs are included in cost of products sold and operating expenses on the Consolidated Statements of Income and are generally passed through to our customers. The Company has elected the practical expedient under ASC 606, "Revenue from Contracts with Customers", to account for shipping and handling activities as a promise to fulfill the transfer of coke.

Share-Based Compensation

We measure the cost of employee services in exchange for equity instrument awards and cash awards based on the grant-date fair value of the award. The cash awards and performance metrics of equity awards are remeasured on a quarterly basis. The market metrics of equity awards are not remeasured. The total cost is recognized over the requisite service period. Award forfeitures are accounted for as they occur. The costs of equity awards and cash awards were recorded to additional paid-in capital and accrued liabilities, respectively, on the Consolidated Balance Sheets. See Note 15.

Fair Value Measurements

The Company determines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. As required, the Company utilizes valuation techniques that maximize the use of observable inputs (levels 1 and 2) and minimize the use of unobservable inputs (level 3) within the fair value hierarchy included in current accounting guidance. Assets and liabilities are classified within the fair value hierarchy based on the lowest level (least observable) input that is significant to the measurement in its entirety. See Note 17.

Currency Translation

The functional currency of the Company’s Brazilian operations is the Brazilian real. The Company’s Brazil operations translate its assets and liabilities into U.S. dollars at the current exchange rates in effect at the end of the fiscal period. The gains or losses that result from this process are shown as cumulative translation adjustments within accumulated other comprehensive loss in the Consolidated Balance Sheets. The revenue and expense accounts of foreign operations are translated into U.S. dollars at the average exchange rates during the period.

Recently Adopted Accounting Pronouncements

In May 2014, Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2014-09, “Revenue from Contracts with Customers (Topic 606),” which supersedes the revenue recognition requirements in “Revenue Recognition (Topic 605),” and requires entities to recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The Company adopted this standard on January 1, 2018, using the modified retrospective method with no material impact on our revenue recognition model on an annual basis. See Note 18.

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In November 2016, the FASB issued ASU 2016-18, “Statement of Cash Flows (Topic 230): Restricted cash.” The Company retrospectively adopted this ASU in the first quarter 2018 and modified the Company's cash flow presentation to include restricted cash with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. Historical restricted cash balances were related to cash withheld from the 2015 acquisition of CMT to fund the completion of certain expansion capital improvements, and the related immaterial impacts have been reclassified on the statement of cash flows for the years ended December 31, 2017 and 2016. The restricted cash balance was zero at both December 31, 2018 and December 31, 2017.

In March 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 Company adopted this ASU in the first quarter 2018 and retrospectively presented net periodic postretirement benefit cost in the income statement separately from the service cost component and outside a subtotal of income from operations. In conjunction with the adoption of this standard, expense of $1.3 million was reclassified from operating income and was recorded in interest expense, net on the Consolidated Statements of Income for both the years ended December 31, 2017 and 2016, respectively. See Note 10.

In February 2018, the FASB issued ASU 2018-02, “Income Statement-Reporting Comprehensive Income (Topic 220) - Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income.” The Company adopted this ASU in the first quarter 2018 and reclassified $1.1 million of deferred tax adjustments to accumulated other comprehensive income (loss) from retained earnings on the December 31, 2017 balance sheet for the tax effects resulting from the Tax Cuts and Jobs Act of 2017.

Recently Issued Pronouncements

In February 2016, the FASB issued ASU 2016-02, "Leases (Topic 842)." ASU 2016-02 requires leases to be recognized as assets and liabilities on the balance sheet for the rights and obligations created by all leases with terms of more than 12 months. Subsequently, the FASB has issued various ASUs to provide further clarification around certain aspects of ASC 842, "Leases".  This standard is effective for annual and interim periods in fiscal years beginning after December 15, 2018, with early adoption permitted. A multi-disciplined implementation team has gained an understanding of the accounting and disclosure provisions of the standard and analyzed the impacts to our business, including the development of new accounting processes to account for our leases and support the required disclosures. We have implemented a technology tool to assist with the accounting and reporting requirements of this standard. While we are still finalizing the impact of adopting this standard, we expect that upon adoption the right-of-use assets and lease liabilities, such as land, the lease of our corporate office space and certain equipment rentals, will increase the reported assets and liabilities on our Consolidated Balance Sheets by approximately $5 million to $10 million. The Company adopted this standard on January 1, 2019, by applying the modified retrospective transition approach and electing not to adjust prior comparative periods.

Labor Concentrations

As of December 31, 2018, we have approximately 895 employees in the U.S. Approximately 40 percent of our domestic employees, principally at our cokemaking operations, are represented by the United Steelworkers union under various contracts. Additionally, approximately 3 percent of our domestic employees are represented by the International Union of Operating Engineers. While the labor agreement at our Indiana Harbor cokemaking facility expired on August 31, 2015, the parties mutually agreed to extend the terms of this agreement through August 31, 2018. Currently both parties are working under the term of the contract extension while negotiating a new agreement. We do not anticipate any work stoppages during the extended period of the agreement. The labor agreements at KRT, Lake Terminal and Haverhill will expire on April 30, 2019, June 30, 2019 and November 1, 2019, respectively. We will negotiate the renewal of these agreements in 2019 and do not anticipate any work stoppages.

As of December 31, 2018, we have approximately 285 employees at the cokemaking facility in Vitória, Brazil, all of whom are represented by a union under a labor agreement. During 2018, the labor agreement at our Vitoria, Brazil facility was renewed for an additional year, and it expires on October 31, 2019.

3. Acquisition of Noncontrolling Interest

In 2017, the Company's Board of Directors authorized a program for the Company to purchase outstanding Partnership common units at any time and from time to time in the open market, through privately negotiated transactions, block transactions, or otherwise for a total aggregate cost to the Company not to exceed $100.0 million. At December 31, 2018, there was $47.1 million available under the authorized program.

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The following table summarizes the Company's purchases of outstanding Partnership common units in the open market:

	Years Ended December 31
	2018		2017
	(Dollars in millions)
Units purchased	231,171		2,853,032
Cash paid	$	4.2	$	48.7
Decrease in noncontrolling interest (1)	$	2.7	$	29.6
Decrease in additional paid in capital (2)	$	1.2	$	12.0

(1) Represents Partnership's net book value acquired by the Company.

(2) Represents consideration paid in excess of the net book value of the noncontrolling interest acquired net of deferred tax adjustments of $0.3 million and $7.1 million for the years ended December 31, 2018 and 2017, respectively.

The following table summarizes the effects of the changes in the Company's ownership interest in the Partnership on SunCoke's equity:

	Years Ended December 31,
	2018			2017
	(Dollars in millions)
Net income attributable to SunCoke Energy, Inc	$	26.2		$	122.4
Decrease in SunCoke Energy, Inc. equity for the purchase of additional interest in the Partnership	(1.2		)	(12.0		)
Changes from net income attributable to SunCoke Energy, Inc and transfers to noncontrolling interest	$	25.0		$	110.4

4. Customer Concentrations

In 2018, the Company sold approximately 4 million tons of coke under long-term, take-or-pay contracts to its three primary customers in the U.S.: AK Steel Corporation ("AK Steel"), ArcelorMittal USA LLC and/or its affiliates (“AM USA”) and United States Steel Corporation ("U.S. Steel"). In addition, licensing and operating fees are payable to the Company under long-term contracts with ArcelorMittal Brazil.

The table below shows sales to the Company's significant customers:

	Years ended December 31,
	2018				2017				2016
	Sales and other operating revenue		Percent of Company sales and other operating revenue		Sales and other operating revenue		Percent of Company sales and other operating revenue		Sales and other operating revenue		Percent of Company sales and other operating revenue
	(Dollars in millions)
AM USA and ArcelorMittal Brazil(1)	$	735.8	50.7	%	$	678.2	50.9	%	$	596.6	48.8	%
AK Steel(2)	$	377.9	26.0	%	$	331.3	24.9	%	$	350.0	28.6	%
U.S. Steel(3)	$	206.8	14.3	%	$	214.1	16.1	%	$	185.3	15.1	%

(1) Represents revenues included in our Domestic Coke and Brazil Coke segments.

(2) Represents revenues included in our Domestic Coke segment.

(3) Represents revenues included in our Domestic Coke and Logistics segments.

The Company generally does not require any collateral with respect to its receivables. At both December 31, 2018 and 2017, the Company’s receivables balances were primarily due from AM USA and ArcelorMittal Brazil, AK Steel and U.S. Steel. As a result, the Company experiences concentrations of credit risk in its receivables with these three customers. These concentrations of credit risk may be affected by changes in economic or other conditions affecting the steel industry.

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The table below shows receivables due from the Company's significant customers:

	December 31,
	2018		2017
	(Dollars in millions)
AM USA and ArcelorMittal Brazil	$	34.3	$	25.7
AK Steel	$	25.3	$	13.2
U.S. Steel	$	5.2	$	5.6

Our logistics business provides coal handling and storage services to Murray Energy Corporation, Inc. ("Murray") and Foresight Energy LLC ("Foresight"), who are the two primary customers in the Logistics segment.

The table below shows sales to Murray and Foresight:

	Years ended December 31,
	2018			2017			2016
	(Dollars in millions)
Sales and other operating revenue	$	62.5		$	57.8		$	53.5
Percent of Company sales and other operating revenue	4.3		%	4.3		%	4.4		%
Percent of Logistics segment sales and other operating revenue, including intersegment sales	49.3		%	49.4		%	49.6		%

The table below shows receivables due from Murray and Foresight:

	December 31,
	2018		2017
	(Dollars in millions)
Murray and Foresight	$	3.2	$	9.7

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5. Income Taxes

The components of income before income tax (benefit) expense and loss from equity method investment are as follows:

	Years Ended December 31,
	2018		2017		2016
	(Dollars in millions)
Domestic	$	39.3	$	4.3	$	52.5
Foreign	17.7		17.6		15.6
Total	$	57.0	$	21.9	$	68.1

Income tax expense (benefit) consisted of the following:

	Years Ended December 31,
	2018			2017			2016
	(Dollars in millions)
Current tax expense:
U.S. federal	$	1.4		$	1.7		$	2.7
State	2.1			(1.0		)	(2.2		)
Foreign	4.5			4.9			5.0
Total current tax expense	8.0			5.6			5.5
Deferred tax expense:
U.S. federal	(3.1		)	(99.7		)	(1.5		)
State	(0.3		)	12.5			4.6
Total deferred tax (benefit) expense	(3.4		)	(87.2		)	3.1
Total	$	4.6		$	(81.6	)	$	8.6

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The reconciliation of income tax expense at the U.S. statutory rate to income tax expense (benefit) is as follows:

	Years Ended December 31,
	2018					2017					2016
	(Dollars in millions)
Income tax expense at U.S. statutory rate	$	12.0		21.0	%	$	7.7		35.0	%	$	23.8		35.0	%
Increase (reduction) in income taxes resulting from:
Impact of Final Regulations(1)	(1.4		)	(2.5	)%	64.2			293.2	%	—			—	%
Impact of Tax Legislation(2)	(4.8		)	(8.4	)%	(154.7		)	(706.4	)%	—			—	%
Income attributable to noncontrolling interests in partnerships(3)	(3.9		)	(6.8	)%	(5.4		)	(24.7	)%	(15.6		)	(23.0	)%
State and other income taxes, net of federal income tax effects	1.6			2.8	%	2.0			9.1	%	1.1			1.7	%
Change in valuation allowance(4)	0.7			1.2	%	3.9			17.8	%	0.4			0.6	%
Other	0.4			0.7	%	0.7			3.2	%	(1.1		)	(1.6	)%
Income tax (benefit) expense at effective tax rate	$	4.6		8.0	%	$	(81.6	)	(372.8	)%	$	8.6		12.7	%

(1) In January 2017, the Internal Revenue Service ("IRS") announced its decision to exclude cokemaking as a qualifying income generating activity in its final regulations (the "Final Regulations") issued under section 7704(d)(1)(E) of the Internal Revenue Code relating to the qualifying income exception for publicly traded partnerships. Subsequent to the 10-year transition period, certain cokemaking entities in the Partnership will become taxable as corporations. As a result, the Partnership recorded deferred income tax expense of $148.6 million to set up its initial deferred income tax liability during 2017, primarily related to differences in the book and tax basis of fixed assets, which are expected to exist at the end of the 10-year transition period when the cokemaking operations become taxable.  However, the Company had previously recorded $84.4 million of the deferred income tax liability in its financial statements related to the Company's share of the deferred tax liability for the book and tax differences in its investment in the Partnership. As such, the Company's 2017 financial statements reflect the $64.2 million incremental impact from the Final Regulations solely attributable to the Partnership’s public unitholders, which was also recorded as an equal reduction to noncontrolling interest.

In 2018, the Partnership recorded a deferred tax benefit of $3.6 million related to its changes in projected deferred tax liability associated with projected book and tax differences at the end of the 10-year transition period due to current period additions and changes in estimated useful lives of certain assets. The Company's 2018 financial statements reflect a $1.4 million benefit, which is solely attributable to the Partnership’s public unitholders and was also recorded as an equal reduction to noncontrolling interest. 

As a result, the Final Regulations have no impact to net income attributable to the Company.

(2) On December 22, 2017, the Tax Legislation was enacted. The Tax Legislation significantly revised the U.S. corporate income tax structure, including lowering corporate income tax rates. In addition, the SEC staff released Staff Accounting Bulletin 118 on December 23, 2017, which provided for companies to record a provisional impact of the Tax Legislation during a measurement period, not to exceed one year, in situations where companies do not have the necessary information available, prepared, or analyzed in reasonable detail to complete the accounting under ASC 740, "Income Taxes", for certain income tax effects of the Tax Legislation for the reporting period which includes enactment. During 2017, SunCoke recorded a provisional net income tax benefit of $154.7 million, of which $125.0 million was attributable to the Company, for the impact of this Tax Legislation. These benefits were primarily due to the $169.0 million net benefit resulting from the remeasurement of U.S. deferred income tax liabilities and assets at the lower enacted corporate tax rates. During 2017, based on information available at the time, the Company recorded provisional income tax expense of $14.3 million for a valuation allowance against $19.0 million of foreign tax credit carryforwards that the Company believed would not be realized prior to their expiration as a result of the Tax Legislation. Based on an updated analysis of the foreign tax credit rules relating to the new Tax Legislation, the Company revised its estimate of the realizability of its foreign tax credits, resulting in a net $4.8 million benefit during the third quarter of 2018. There were no other significant changes to previous estimates and amounts recorded in 2017 relating to this Tax Legislation.

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(3) Excludes the impact of the Final Regulations on qualifying income discussed above. No income tax expense is reflected in the Consolidated Statements of Income for income attributable to noncontrolling interests in partnership entities.

(4) In 2017, the Company recorded a valuation allowance as a result of changes in future state allocation assumptions.

The tax effects of temporary differences that comprise the net deferred income tax liability from operations are as follows:

	December 31,
	2018			2017
	(Dollars in millions)
Deferred tax assets:
Retirement benefit liabilities	$	6.4		$	7.1
Black lung benefit liabilities	11.3			11.6
Share-based compensation	6.4			6.1
Federal tax credit carryforward(1)	21.5			23.2
Foreign tax credit carryforward(2)	15.9			19.0
Federal net operating loss	—			2.5
Section 163(j) interest limitation carryforward(3)	1.8			—
State tax credit carryforward, net of federal income tax effects(4)	2.4			4.0
State net operating loss carryforward, net of federal income tax effects(5)	13.5			13.9
Other liabilities not yet deductible	4.9			4.3
Total deferred tax assets	84.1			91.7
Less valuation allowance(6)	(20.7		)	(26.2		)
Deferred tax asset, net	63.4			65.5
Deferred tax liabilities:
Properties, plants and equipment	(111.5		)	(114.9		)
Investment in partnerships	(206.6		)	(208.4		)
Total deferred tax liabilities	(318.1		)	(323.3		)
Net deferred tax liability	$	(254.7	)	$	(257.8	)

(1) Federal tax credit carryforward expires in 2032 through 2034.

(2) Foreign tax credit carryforward expires in 2023 through 2028.

(3) The Tax Legislation generally limits the deductibility of business interest expense to 30 percent of adjusted taxable income. This limitation resulted in a deferred tax asset as it is eligible for deduction in future taxable years and has no expiration.

(4) State tax credit carryforward, net of federal income tax effects expires in 2019 through 2023.

(5) State net operating loss carryforward, net of federal income tax effects expires in 2023 through 2038.

(6) Primarily related to state tax credit and net operating loss carryforwards and the $9.9 million allowance against the foreign tax credit carryforward.

The Company's consolidated federal income tax returns have been examined by the IRS for all years through the year ended December 31, 2014. SunCoke is currently open to examination by the IRS for tax years ended December 31, 2015 and forward.

State and foreign income tax returns are generally subject to examination for a period of three to five years after the filing of the respective returns. The state impact of any amended federal returns remains subject to examination by various states for a period of up to one year after formal notification of such amendments to the states.

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There were no uncertain tax positions at December 31, 2018 and 2017, and there were no associated interest or penalties recognized for the years ended December 31, 2018, 2017 or 2016. The Company does not expect that any unrecognized tax benefits pertaining to income tax matters will be required in the next twelve months.

6. Inventories

The Company’s inventory consists of metallurgical coal, which is the principal raw material for the Company’s cokemaking operations, coke, which is the finished good sold by the Company to its customers, and materials, supplies and other. These components of inventories were as follows:

	December 31,
	2018		2017
	(Dollars in millions)
Coal	$	59.9	$	61.4
Coke	8.6		12.3
Materials, supplies and other	41.9		37.3
Total inventories	$	110.4	$	111.0

7. Properties, Plants, and Equipment, Net

The components of net properties, plants and equipment were as follows:

	December  31,
	2018			2017
	(Dollars in millions)
Coke and energy plant, machinery and equipment(1)	$	1,876.3		$	1,812.0
Logistics plant, machinery and equipment	218.3			216.2
Land and land improvements	119.7			118.7
Construction-in-progress	72.7			51.9
Other	39.9			35.7
Gross investment, at cost	2,326.9			2,234.5
Less: accumulated depreciation(1)	(855.8		)	(733.2		)
Total properties, plants and equipment, net	$	1,471.1		$	1,501.3

(1) Includes assets, consisting mainly of coke and energy plant, machinery and equipment, with a gross investment totaling $1,416.2 million and $1,337.3 million and accumulated depreciation of $554.1 million and $475.8 million at December 31, 2018 and December 31, 2017, respectively, which are subject to long-term contracts to sell coke and are deemed to contain operating leases. Upon adoption of ASC 842, "Leases",in 2019, these contracts will no longer be deemed to contain operating leases.

8. Goodwill and Other Intangible Assets

Goodwill allocated to SunCoke's reportable segments is shown below. There were no changes in the carrying amount of goodwill during the years ended December 31, 2018 and 2017.

	December 31, 2018 and 2017
	(Dollars in millions)
Domestic Coke	$	3.4
Logistics	73.5
Total	$	76.9

The Company performed its annual goodwill impairment test as of October 1, 2018, with no indication of impairment. The fair value of the Logistics reporting unit, which was determined based on a discounted cash flow analysis, exceeded the carrying value of the reporting unit by approximately 30 percent. A significant portion of our logistics business holds long-term, take-or-pay contracts with Murray and Foresight. Key assumptions in our goodwill impairment test include

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continued customer performance against long-term, take-or-pay contracts, renewal of future long-term, take-or-pay contracts, incremental merchant businessand a 14 percent discount rate representing the estimated weighted average cost of capital for this business line. The use of different assumptions, estimates or judgments, such as the estimated future cash flows of Logistics and the discount rate used to discount such cash flows, could significantly impact the estimated fair value of a reporting unit, and therefore, impact the excess fair value above carrying value of the reporting unit. A 100 basis point change in the discount rate would not have reduced the fair value of the reporting unit below its carrying value.

The following table summarizes the components of gross and net intangible asset balances:

		December 31, 2018						December 31, 2017
	Weighted - Average Remaining Amortization Years	Gross Carrying Amount		Accumulated Amortization		Net		Gross Carrying Amount		Accumulated Amortization		Net
		(Dollars in millions)
Customer contracts	4	$	31.7	$	17.7	$	14.0	$	31.7	$	13.8	$	17.9
Customer relationships	13	28.7		7.5		21.2		28.7		5.7		23.0
Permits	24	139.0		17.4		121.6		139.0		12.2		126.8
Trade name	—	1.2		1.2		—		1.2		1.0		0.2
Total		$	200.6	$	43.8	$	156.8	$	200.6	$	32.7	$	167.9

The permits above represent the environmental and operational permits required to operate a coal export terminal in accordance with the U.S. Environmental Protection Agency ("EPA") and other regulatory bodies. Intangible assets are amortized over their useful lives in a manner that reflects the pattern in which the economic benefit of the asset is consumed. The permits’ useful lives were estimated to be 27 years at acquisition based on the expected useful life of the significant operating equipment at the facility. We have historical experience of renewing and extending similar arrangements at our other facilities and intend to continue to renew our permits as they come up for renewal for the foreseeable future. The permits were renewed regularly prior to our acquisition of CMT. These permits have an average remaining renewal term of approximately 2.4 years.

Total amortization expense for intangible assets subject to amortization was $11.1 million, $11.1 million and $11.2 million for the years ended December 31, 2018, 2017 and 2016, respectively. Based on the carrying value of finite-lived intangible assets as of December 31, 2018, we estimate amortization expense for each of the next five years as follows:

	(Dollars in millions)
2019	$	10.9
2020	10.7
2021	10.3
2022	10.3
2023	7.0
Thereafter	107.6
Total	$	156.8

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9. Asset Retirement Obligations

The Company has asset retirement obligations, primarily in the Domestic Coke segment, related to certain contractual obligations, mostly related to costs associated with restoring land to its original state, and may require the retirement and removal of long-lived assets from certain cokemaking properties as well as other reclamation obligations related to our former coal mining business. The Federal Surface Mining Control and Reclamation Act of 1977 and similar state statutes require that mine property be restored in accordance with specified standards and an approved reclamation plan. We do not have any unrecorded asset retirement obligations.

The following table provides a reconciliation of changes in the asset retirement obligation from operations during each period:

	(Dollars in millions)
Balance at December 31, 2016	$	13.9
Liabilities settled	(0.7		)
Accretion expense(1)	1.0
Revisions in estimated cash flows	(0.2		)
Balance at December 31, 2017	$	14.0
Liabilities settled	(0.4		)
Accretion expense(1)	0.9
Revisions in estimated cash flows	$	0.1
Balance at December 31, 2018	$	14.6

(1) Included in cost of products sold and operating expenses on the Consolidated Statements of Income.

10. Retirement Benefits Plans

Postretirement Health Care and Life Insurance Plans

The Company has plans which provide health care and life insurance benefits for many of its retirees (“postretirement benefit plans”). The postretirement benefit plans are unfunded and the costs are borne by the Company. Effective January 1, 2011, postretirement medical benefits for future retirees were phased out or eliminated for non-mining employees with less than ten years of service.

Postretirement benefit plans expense consisted of the following components:

	Years Ended December 31,
	2018			2017			2016
	(Dollars in millions)
Interest cost on benefit obligations	$	1.0		$	1.1		$	1.3
Amortization of:
Actuarial losses	0.6			0.9			0.7
Prior service benefit	(0.7		)	(0.7		)	(0.7		)
Total expense	$	0.9		$	1.3		$	1.3

Postretirement benefit plans expense is determined using actuarial assumptions as of the beginning of the year or using weighted-average assumptions when curtailments, settlements and/or other events require a plan remeasurement. The following assumptions were used to determine postretirement benefit plans expense:

	December 31,
	2018		2017		2016
Discount Rate	3.35	%	3.65	%	3.80	%

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The following amounts were recognized as components of other comprehensive income (loss) before related tax impacts:

		Years Ended December 31,
		2018			2017			2016
	(Dollars in millions)
Reclassifications to earnings of:
Actuarial loss amortization		$	0.6		$	0.9		$	0.7
Prior service benefit amortization		(0.7		)	(0.7		)	(0.7		)
Retirement benefit plan funded status    adjustments:
Actuarial gains (losses)		0.8			(1.1		)	(1.8		)
Prior service benefit(1)		—			—			1.5
		$	0.7		$	(0.9	)	$	(0.3	)

(1) Effective January 1, 2017, a plan change occurred resulting in Medicare-eligible disabled participants transitioning from a Company-sponsored group medical plan to a federal health care exchange plan. The Company provides a subsidy to these participants each year. The plan change resulted in a decrease in the benefit obligation of $1.5 million during 2016.

The following table sets forth the components of the changes in benefit obligations:

	Years Ended December 31,
	2018			2017
	(Dollars in millions)
Benefit obligation at beginning of year	$	31.3		$	32.3
Interest cost	1.0			1.1
Actuarial (gain)/loss	(0.8		)	1.1
Benefits paid	(3.3		)	(3.2		)
Benefit obligation at end of year(1)	$	28.2		$	31.3

(1) Represents retirement benefit liabilities, including current portion, on the Consolidated Balance Sheets. The current portion of retirement liabilities, which totaled $3.0 million and $3.1 million at December 31, 2018 and 2017, respectively, is classified in accrued liabilities on the Consolidated Balance Sheets.

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The following table sets forth the cumulative amounts not yet recognized in net income:

	Years Ended December 31,
	2018			2017
	(Dollars in millions)
Cumulative amounts not yet recognized in net income:
Actuarial losses	$	10.4		$	11.8
Prior service benefits	(2.6		)	(3.4		)
Accumulated other comprehensive loss (before related tax benefit)	$	7.8		$	8.4

The expected benefit payments through 2028 for the postretirement benefit plan are as follows:

Year ending December 31:	(Dollars in millions)
2019	$	3.0
2020	2.9
2021	2.8
2022	2.6
2023	2.4
2024 through 2028	9.5

The measurement date for the Company’s postretirement benefit plans is December 31. The following discount rates were used to determine the benefit obligation:

	December 31,
	2018		2017
Discount rate	4.00	%	3.35	%

The health care cost trend assumption used at both December 31, 2018, and 2017 to compute the accumulated postretirement benefit obligation for the postretirement benefit plans was 6.50 percent, which is assumed to decline gradually to 5.00 percent in 2028 and to remain at that level thereafter.

Defined Contribution Plans

The Company has defined contribution plans which provide retirement benefits for certain of its employees. The Company’s contributions, which are principally based on the Company’s pretax income and the aggregate compensation levels of participating employees and are charged against income as incurred, amounted to $6.5 million, $6.4 million and $5.6 million for the years ended December 31, 2018, 2017 and 2016, respectively.

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11. Accrued Liabilities

Accrued liabilities consist of following:

	December 31,
	2018		2017
	(Dollars in millions)
Accrued benefits	$	21.2	$	21.3
Current portion of postretirement benefit obligation	3.0		3.1
Other taxes payable	9.1		10.5
Current portion of black lung liability	4.5		5.4
Accrued legal	4.2		5.6
Other	3.6		7.3
Total accrued liabilities	$	45.6	$	53.2

12. Debt and Financing Obligation

Total debt and financing obligation consisted of the following:

	December 31,
	2018			2017
	(Dollars in millions)
7.500 percent senior notes, due 2025 ("Partnership Notes")	$	700.0		$	700.0
7.625 percent senior notes, due 2019 ("2019 Notes")	—			44.6
Term loan, due 2022 ("Term Loan")	43.9			—
SunCoke's revolving credit facility, due 2022 ("Revolving Facility")	—			—
Partnership's revolving credit facility, due 2022 ("Partnership Revolver")	105.0			130.0
5.82 percent financing obligation, due 2021 ("Partnership Financing Obligation")	10.1			12.7
Total borrowings	$	859.0		$	887.3
Original issue discount	(5.4		)	(5.9		)
Debt issuance costs	(15.2		)	(17.7		)
Total debt and financing obligation	$	838.4		$	863.7
Less: current portion of long-term debt and financing obligation	3.9			2.6
Total long-term debt and financing obligation	$	834.5		$	861.1

Redemption of 2019 Notes

On January 11, 2018, the Company redeemed all of its outstanding 2019 Notes for $46.1 million, which included accrued and unpaid interest of $1.5 million. As a result of the debt extinguishment, the Company recorded a loss on extinguishment of debt on the Consolidated Statements of Income of $0.3 million, representing a write-off of unamortized debt issuance costs. The Company funded the redemption with a Term Loan in aggregate principal amount of $45.0 million, resulting in additional debt issuance costs of $0.3 million. The Term Loan will mature on May 24, 2022. Borrowings under the Term Loan will bear interest, at the Company’s option, at either (i) a base rate plus an applicable margin or (ii) LIBOR plus an applicable margin. The applicable margin is based on the Company's consolidated leverage ratio, as defined in the credit agreement.

Partnership Notes

The Partnership Notes are the senior unsecured obligations of the Partnership, and are guaranteed on a senior unsecured basis by each of the Partnership’s existing and certain future subsidiaries. Interest on the Partnership Notes is payable semi-annually in cash in arrears on June 15 and December 15 of each year.

The Partnership may redeem some or all of the Partnership Notes at any time on or after June 15, 2020 at specified redemption prices plus accrued and unpaid interest, if any, to the redemption date. Before June 15, 2020, and following certain equity offerings, the Partnership also may redeem up to 35 percent of the Partnership Notes at a price equal to 107.5 percent of the principal amount, plus accrued and unpaid interest, if any, to the redemption date. In addition, at any time

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prior to June 15, 2020, the Partnership may redeem some or all of the Partnership Notes at a price equal to 100 percent of the principal amount, plus accrued and unpaid interest, if any, to the redemption date, plus a “make-whole” premium.

The Partnership is obligated to offer to purchase all or a portion of the Partnership Notes at a price of (a) 101 percent of their principal amount, together with accrued and unpaid interest, if any, to the date of purchase, upon the occurrence of certain change of control events and (b) 100 percent of their principal amount, together with accrued and unpaid interest, if any, to the date of purchase, upon the occurrence of certain asset dispositions. These restrictions and prohibitions are subject to certain qualifications and exceptions set forth in the Indenture, including without limitation, reinvestment rights with respect to the proceeds of asset dispositions.

The Partnership Notes contain covenants that, among other things, limit the Partnership’s ability and the ability of certain of the Partnership’s subsidiaries to (i) incur indebtedness, (ii) pay dividends or make other distributions, (ii) prepay, redeem or repurchase certain subordinated debt, (iv) make loans and investments, (v) sell assets, (vi) incur liens, (vii) enter into transactions with affiliates, (viii) enter into agreements restricting the ability of subsidiaries to pay dividends and (ix) consolidate or merge.

Partnership Financing Obligation

The Partnership's sale-leaseback arrangement of certain coke and logistics equipment has an initial lease period of 60 months and an early buyout option after 48 months to purchase the equipment at 34.5 percent of the original lease equipment cost. The arrangement is accounted for as a financing transaction, resulting in a financing obligation on the Consolidated Balance Sheets. The financing obligation is guaranteed by the Partnership.

Revolving Facility

The proceeds of any borrowings made under the Revolving Facility can be used to finance working capital needs, acquisitions, capital expenditures and for other general corporate purposes. The obligations under the credit agreement are guaranteed by certain of the Company’s subsidiaries and secured by liens on substantially all of the Company’s and the guarantors’ assets pursuant to a guarantee and collateral agreement.

The capacity of the Revolving facility is $100.0 million. As of December 31, 2018, the Revolving Facility had letters of credit outstanding of $23.9 million and no outstanding balance, leaving $76.1 million available. Commitment fees are based on the unused portion of the Revolving Facility at a rate of 0.4 percent.

Borrowings under the Revolving Facility bear interest, at SunCoke Energy’s option, at either (i) a base rate plus an applicable margin or (ii) LIBOR plus 175 basis points. The spread is subject to change based on the Company's consolidated leverage ratio, as defined in the credit agreement. The weighted-average interest rate for borrowings outstanding under the Credit Agreement was 2.8 percent during 2016. There were no borrowings during 2018 or 2017.

Partnership Revolver

The proceeds of any borrowings made under the Partnership Revolver can be used to finance working capital needs, acquisitions, capital expenditures and for other general corporate purposes. The Partnership Revolver provides total aggregate commitments from lenders of $285.0 million and up to $200.0 million uncommitted incremental revolving capacity. The obligations under the Partnership Revolver are guaranteed by the Partnership’s subsidiaries and secured by liens on substantially all of the Partnership’s and the guarantors’ assets.

As of December 31, 2018, the Partnership had $1.9 million of letters of credit outstanding and an outstanding balance of $105.0 million, leaving $178.1 million available. Commitment fees are based on the unused portion of the Partnership Revolver at a rate of 0.4 percent.

Borrowings under the Partnership Revolver bear interest at either (i) a variable rate of LIBOR plus 250 basis points or (ii) an alternative base rate plus 150 basis points. The spread is subject to change based on the Partnership's consolidated leverage ratio, as defined in the credit agreement. The weighted-average interest rate for borrowings under the Partnership Revolver was 4.8 percent, 3.8 percent and 3.3 percent during 2018, 2017 and 2016, respectively.

Covenants

Under the terms of the Revolving Facility, the Company is subject to a maximum consolidated leverage ratio of 3.25:1.00 and a minimum consolidated interest coverage ratio of 2.75:1.00. Under the terms of the Partnership's credit agreement, the Partnership is subject to a maximum consolidated leverage ratio of 4.5:1.0 prior to June 30, 2020 and 4.0:1.0 after June 30, 2020 and a minimum consolidated interest coverage ratio of 2.5:1.0. The Company and Partnership's credit agreement contains other covenants and events of default that are customary for similar agreements and may limit our ability to take various actions including our ability to pay a dividend or repurchase our stock.

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If we fail to perform our obligations under these and other covenants, the lenders' credit commitment could be terminated and any outstanding borrowings, together with accrued interest, under the Revolving Facility and Partnership Revolver could be declared immediately due and payable. The Company and the Partnership have a cross default provision that applies to our indebtedness having a principal amount in excess of $35 million.

As of December 31, 2018, the Company and the Partnership were in compliance with all debt covenants. We do not anticipate violation of these covenants nor do we anticipate that any of these covenants will restrict our operations or our ability to obtain additional financing.

Maturities

As of December 31, 2018, the combined aggregate amount of maturities for long-term borrowings for each of the next five years is as follows:

	(Dollars in millions)
2019	$	3.9
2020(1)	10.7
2021	3.4
2022	141.0
2023	—
2024-Thereafter	700.0
Total	$	859.0

(1) Assumes the Partnership Financing Obligation early buyout option is exercised in 2020.

13. Commitments and Contingent Liabilities

Lease obligations

The Company, as lessee, has noncancelable operating leases for land, office space, equipment and railcars. The aggregate amount of future minimum annual rental payments applicable to noncancelable operating leases is as follows:

	Minimum Rental Payments
	(Dollars in millions)
Year ending December 31:
2019	$	2.0
2020	1.1
2021	1.0
2022	0.5
2023	0.1
2024-Thereafter	0.7
Total	$	5.4

Total rental expense for all operating leases was $9.8 million, $7.3 million and $8.7 million in 2018, 2017 and 2016, respectively.

Legal Matters

SunCoke Energy is party to an omnibus agreement, pursuant to which we have agreed to indemnify the Partnership for costs and expenses related to remediation of certain identified environmental matters in existence prior to the Partnership's initial public offering on January 24, 2013 ("IPO") at the Partnership’s Haverhill and Middletown facilities and certain identified environmental matters at the Partnership's Granite City facility in existence prior to its dropdown in January of 2015 ("Granite City Dropdown"). However, under the terms of the omnibus agreement, SunCoke Energy is not obligated to indemnify the Partnership for any new environmental matters coming into existence after the IPO at the Partnership’s Haverhill and Middletown facilities, or any new environmental matters coming into existence after the Granite City Dropdown at the Partnership's Granite City facility.

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The EPA issued Notices of Violations (“NOVs”) for our Haverhill and Granite City cokemaking facilities which stemmed from alleged violations of our air emission operating permits for these facilities. We are working in a cooperative manner with the EPA, the Ohio Environmental Protection Agency and the Illinois Environmental Protection Agency to address the allegations, and have entered into a consent decree in federal district court with these parties. The consent decree includes a $2.2 million civil penalty payment, which was paid in December 2014, as well as capital projects underway to improve the reliability of the energy recovery systems and enhance environmental performance at the Haverhill and Granite City facilities. In the third quarter of 2018, the Court entered an amendment to the consent decree which provides the Haverhill and Granite City facilities with additional time to perform necessary maintenance on the flue gas desulfurization systems without exceeding consent decree limits. The emissions associated with this maintenance will be mitigated in accordance with the amendment, and there are no civil penalty payments associated with this amendment. The project at Granite City was due to be completed in February 2019, but the Company now expects to complete the project in July 2019 and is in discussions with the government entities regarding, among other things, the timing thereof.

We anticipate spending approximately $150 million related to these projects, of which we have spent approximately $138 million to date, including $7 million spent by the Company prior to the formation of the Partnership. The remaining capital is expected to be spent through the first half of 2019. A portion of the proceeds from the Partnership's initial public offering and subsequent dropdowns were used to fund $119 million of these environmental remediation projects. Pursuant to the omnibus agreement, the Company made capital contributions to the Partnership of $20 million during 2018 for these known environmental remediation projects. The Company expects to make additional capital contributions to the Partnership of approximately $5 million in the first half of 2019 for the estimated future spending related to these environmental remediation projects.

SunCoke Energy has also received NOVs, Findings of Violations ("FOVs"), and information requests from the EPA related to our Indiana Harbor cokemaking facility, which allege violations of certain air operating permit conditions for this facility. The Clean Air Act (the "CAA") provides the EPA with the authority to issue, among other actions, an order to enforce a State Implementation Plan ("SIP") 30 days after an NOV. The CAA also authorizes EPA enforcement of other non-SIP requirements immediately after an FOV. Generally, an NOV applies to SIPs and requires the EPA to wait 30 days, while an FOV applies to all other provisions (such as federal regulations) of the CAA, and has no waiting period. The NOVs and/or FOVs were received in 2010, 2012, 2013, 2015 and 2016. After discussions with the EPA and the Indiana Department of Environmental Management (“IDEM”) in 2010, resolution of the NOVs/FOVs was postponed by mutual agreement because of ongoing discussions regarding the NOVs at Haverhill and Granite City. In January 2012, the Company began working in a cooperative manner to address the allegations with the EPA, the IDEM and Cokenergy, LLC., an independent power producer that owns and operates an energy facility, including heat recovery equipment and a flue gas desulfurization system, that processes hot flue gas from our Indiana Harbor facility to produce steam and electricity and to reduce the sulfur and particulate content of such flue gas.

The EPA, IDEM, SunCoke Energy and Cokenergy, LLC met regularly since those discussions commenced to reach a settlement of the NOVs and FOVs. Capital projects were underway during this time to address items that would be included in conjunction with a settlement. A consent decree among the parties was entered by the federal district court during the fourth quarter of 2018. The settlement includes a $2.5 million civil penalty that was paid in the fourth quarter of 2018. Further, the settlement consists of capital projects already underway to improve reliability and environmental performance of the coke ovens at the facility.

The Company is a party to certain other pending and threatened claims, including matters related to commercial and tax disputes, product liability, employment claims, personal injury claims, premises-liability claims, allegations of exposures to toxic substances and environmental claims. Although the ultimate outcome of these claims cannot be ascertained at this time, it is reasonably possible that some portion of these claims could be resolved unfavorably to the Company. Management of the Company believes that any liability which may arise from claims would not have a material adverse impact on our consolidated financial statements.

Black Lung Benefit Liabilities

Our independent actuarial consultants calculate the present value of the estimated black lung liability annually based on actuarial models utilizing our population of former coal miners, historical payout patterns of both the Company and the industry, actuarial mortality rates, disability incidence, medical costs, death benefits, dependents, discount rates and the current federally mandated payout rates. The estimated liability may be impacted by future changes in the statutory mechanisms, modifications by court decisions and changes in filing patterns driven by perceptions of success by claimants and their advisors, the impact of which cannot be estimated.

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The following table summarizes discount rates utilized, active claims, and the total black lung liabilities:

	December 31,
	2018			2017
Discount rate(1)	4.0		%	3.3		%
Active claims	345			351
Black lung liability (dollars in millions)(2)	$	49.4		$	50.3

(1) The discount rate is determined based on a portfolio of high-quality corporate bonds with maturities that are consistent with the estimated duration of our black lung obligations. A decrease of 25 basis points in the discount rate would have increased black lung expense by $1.1 million in 2018.

(2) The current portion of the black lung liability was $4.5 million and $5.4 million at December 31, 2018 and 2017, respectively, and was included in accrued liabilities on the Consolidated Balance Sheets.

The following table summarizes annual black lung payments and expense:

	Years Ended December 31,
	2018		2017		2016
	(Dollars in millions)
Payments	$	6.3	$	7.4	$	7.8
Expense	$	5.4	$	7.5	$	8.1

14. Accumulated Other Comprehensive Loss

The following tables set forth the changes in the balance of accumulated other comprehensive loss, net of tax, by component:

	Benefit Plans			Currency Translation Adjustments			Total
	(Dollars in millions)
At December 31, 2016	$	(4.8	)	$	(14.2	)	$	(19.0	)
Other comprehensive loss before reclassifications	—			(0.5		)	(0.5		)
Amounts reclassified from accumulated other comprehensive loss	0.2			—			0.2
Retirement benefit plans funded status adjustment	(0.8		)	—			(0.8		)
Net current period change in accumulated other comprehensive loss	(0.6		)	(0.5		)	(1.1		)
Cumulative effect from adoption of ASU 2018-02(1)	(1.1		)	—			(1.1		)
At December 31, 2017	$	(6.5	)	$	(14.7	)	$	(21.2	)
Other comprehensive loss before reclassifications	—			(1.4		)	(1.4		)
Amounts reclassified from accumulated other comprehensive loss	(0.1		)	—			(0.1		)
Retirement benefit plans funded status adjustment	0.6			—			0.6
Recognition of accumulated currency translation loss upon sale of equity method investment(2)	—			9.0			9.0
Net current period change in accumulated other comprehensive loss	0.5			7.6			8.1
At December 31, 2018	$	(6.0	)	$	(7.1	)	$	(13.1	)

(1) As a result of the Tax Legislation, the Company revalued its deferred tax asset for our postretirement benefit plan for the impact of lower income tax rates, the impact of which was reclassified from accumulated other comprehensive loss to retained earnings.

(2) These accumulated currency translation losses were recognized into income as a result of the sale of our equity method investment in VISA SunCoke.

The tax benefit associated with the Company's benefit plans as of December 31, 2018 and 2017 was $1.8 million and $1.9 million, respectively.

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The increase (decrease) on net income due to reclassification adjustments from accumulated other comprehensive income were as follows⁽¹⁾:

	December 31,
	2018			2017			2016
	(Dollars in millions)
Recognition of accumulated currency translation loss upon sale of equity method investment	$	(9.0	)	$	—		$	—
Amortization of benefit plans to net income:(2)
Actuarial loss	$	(0.6	)	$	(0.9	)	$	(0.7	)
Prior service benefit	0.7			0.7			0.7
Total, net of tax(3)	(8.9		)	(0.2		)	—

(1) Amounts in parentheses indicate debits to net income.

(2) These accumulated other comprehensive (income) loss components are included in the computation of postretirement benefit plan expense (benefit) and included in interest expense, net on the Consolidated Statements of Income. See Note 10.

(3) The related tax cost (benefit) was zero for all years presented.

15. Share-Based Compensation

Equity Classified Awards

Effective July 13, 2011, SunCoke Energy’s Board of Directors approved the SunCoke Energy, Inc. Long-Term Performance Enhancement Plan (“SunCoke LTPEP”). The SunCoke LTPEP provides for the grant of equity-based awards including stock options and share units, or restricted stock, to the Company’s directors, officers, and other employees, advisors, and consultants who are selected by the plan committee for participation in the SunCoke LTPEP.  All awards vest immediately upon a change in control and a qualifying termination of employment as defined by the SunCoke LTPEP. The plan authorizes the issuance of (i) 1,600,000 shares of SunCoke Energy common stock issuable upon the adjustment of Sunoco equity awards in connection with the Separation and Distribution Agreement between Sunoco and SunCoke and (ii) up to 7,500,000 shares, which reflects the 6,000,000 shares initially authorized under the Plan and an additional 1,500,000 shares to be issued under the Plan pursuant to an amendment effective February 14, 2018, of SunCoke Energy common stock pursuant to new awards under the SunCoke LTPEP.

The Company measures the cost of employee services in exchange for an award of equity instruments based on the grant-date fair value of the award. The performance metrics of equity awards are remeasured on a quarterly basis for updates to the probability of achievement. The market metrics of equity awards are not remeasured. The total cost is recognized over the requisite service period. Award forfeitures are accounted for as they occur.

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Stock Options

The Company granted the following stock options during the years ended December 31, 2018, 2017 and 2016, with an exercise price equal to the closing price of our common stock on the date of grant:

		Weighted Average Per Share
	No. of Shares	Exercise Price		Weighted Average Grant Date Fair Value
Traditional stock options:
2018 grant	78,447	$	10.49	$	5.38
2017 grant	157,196	$	10.29	$	5.32
2016 March grant	90,925	$	6.03	$	2.78
2016 February grant	95,001	$	3.80	$	1.71
Performance based options:
2017 grant	80,595	$	9.85	$	5.17
2016 March grant	90,925	$	6.03	$	2.42
2016 February grant	58,448	$	3.80	$	1.06

The stock options vest in three equal annual installments beginning one year from the date of grant. In order to become exercisable, the performance based options also require the closing price of the Company's common stock to reach or exceed $14.78 per share for the 2017 grants and $9.50 per share for the February and March 2016 grants for any 15 trading days during the three-year period beginning on the grant date. The February and March 2016 grants met the required stock price performance during 2016. The stock options expire ten years from the date of grant.

The Company calculates the value of each employee stock option, estimated on the date of grant, using the Black-Scholes option pricing model with a Monte Carlo simulation for the performance based options. The weighted-average fair value of employee stock options granted during the years ended December 31, 2018, 2017 and 2016 was based on using the following weighted-average assumptions:

	Years Ended December 31,
	2018		2017		2016
Risk free interest rate	3	%	2	%	1	%
Expected term	6 years		6 years		5 years
Volatility	52	%	53	%	52	%
Dividend yield	—	%	—	%	—	%

The risk-free interest rate assumption is based on the U.S. Treasury yield curve at the date of grant for periods which approximate the expected life of the option. The expected term of the employee options represent the average contractual term adjusted by the average vesting period of each option tranche. We based our expected volatility on our historical volatility over our entire available trading history. The dividend yield assumption is based on the Company’s expectation of dividend payouts at the time of grant.

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The following table summarizes information with respect to common stock option awards outstanding as of December 31, 2018 and stock option activity during the fiscal year then ended:

	Number of Options		Weighted Average Exercise Price		Weighted Average Remaining Contractual Term (years)	Aggregate Intrinsic Value (millions)
Outstanding at December 31, 2017	3,146,115		$	15.31	5.6	$	2.8
Granted	78,447		$	10.49
Exercised	(127,107	)	$	6.49
Forfeited	(211,667	)	$	17.07
Outstanding at December 31, 2018	2,885,788		$	15.46	4.8	$	2.1
Exercisable at December 31, 2018	2,546,059		$	16.38	4.1	$	0.4
Expected to vest at December 31, 2018	339,729		$	8.59	8.2	$	0.9

Intrinsic value for stock options is defined as the difference between the current market value of our common stock and the exercise price of the stock options. Total intrinsic value of stock options exercised during 2018 and 2017 was $0.8 million and $0.3 million, respectively. No stock options were exercised during 2016.

Restricted Stock Units

The Company granted the following restricted stock units ("RSUs") during the years ended December 31, 2018 and 2017:

	Shares	Weighted Average Grant-Date Fair Value		Grant Date Fair Value
				(Dollars in millions)
2018 grants	32,128	10.49		$	0.3
2017 grants	22,628	$	9.85	$	0.2

No RSUs were granted during 2016. The RSUs vest in three annual installments beginning one year from the date of grant.

The following table summarizes information with respect to RSUs outstanding as of December 31, 2018 and RSU activity during the fiscal year then ended:

	Number of RSUs		Weighted Average Grant- Date Fair Value
Nonvested at December 31, 2017	106,397		$	13.53
Granted	32,128		$	10.49
Vested	(87,131	)	$	14.27
Forfeited	(4,181	)	$	8.37
Nonvested at December 31, 2018	47,213		$	10.29

Total grant date fair value of RSUs vested was $1.2 million, $2.3 million and $3.7 million during 2018, 2017 and 2016, respectively.

Performance Share Units

The Company grants performance share units ("PSUs"), which represent the right to receive shares of the Company's common stock, contingent upon the attainment of Company performance and market goals and continued employment.

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The Company granted the following PSUs during the years ended December 31, 2018 and 2017:

	Shares	Fair Value per Share		Grant Date Fair Value
				(Dollars in millions)
2018 grant(1)	96,389	$	11.36	$	1.1
2017 grant(2)	385,758	$	11.61	$	4.5

(1) The service period for the 2018 PSUs ends on December 31, 2020 and the awards will vest during the first quarter of 2021.

(2) The Company granted 237,610 PSUs in February 2017, for which the service period will end on December 31, 2019, and 148,148 PSUs in December 2017, for which the service period will end on December 31, 2020. These awards will vest during the first quarter of 2020 and 2021, respectively.

The 2018 and 2017 PSU grants were both split 50/50 between the Company's three-year cumulative Adjusted EBITDA performance measure and the Company's three-year average pre-tax return on capital ("ROIC") performance measure for its coke and logistics businesses and unallocated corporate expenses. The number of PSU's ultimately awarded will be determined by the Adjusted EBITDA and ROIC performance versus targets and the Company's three-year total shareholder return ("TSR") as compared to the TSR of the companies making up the Nasdaq Iron & Steel Index ("TSR Modifier"). The TSR Modifier can impact the payout between 50 percent and 150 percent of the Company's final performance measure results. The award may vest between zero and 250 percent of the original units granted. The fair value of the PSUs granted during 2018 and 2017 is based on the closing price of our common stock on the date of grant as well as a Monte Carlo simulation for the valuation of the TSR Modifier.

The Company granted the following PSUs during the year ended December 31, 2016:

	ROIC Portion(1)			TSR Portion(2)			Total
	Shares	Fair Value per Share		Shares	Fair Value per Share		Grant Date Fair Value
							(Dollars in millions)
2016 March grant(3)	67,167	$	10.51	201,500	$	6.35	$	2.0
2016 February grant	105,210	$	5.66	105,210	$	5.81	$	1.2

(1) The number of PSUs that ultimately vest will be determined by the Company's three-year average pre-tax return on capital for the Company's coke and logistics businesses. Additionally, only applicable to the 2016 grants, if at any time during the vesting period the closing price of the Company's common stock equals or exceeds $9.00 per share for any 15 trading days, which was met during 2016, the pre-tax return on capital portion of the award, as adjusted, will be multiplied by two.

(2) The number of PSUs that ultimately vest will be determined by the Company's three-year total shareholder return ("TSR") as compared to the TSR of the companies making up the S&P 600.

(3) The final vesting value of the TSR portion of this award cannot exceed $4.9 million.

Each portion of the award may vest between zero and 200 percent of the original units granted. The fair value of the PSUs granted are based on the closing price of our common stock on the date of grant as well as a Monte Carlo simulation for the portion of the award subject to a market condition. The service period for the 2016 grant ends on December 31, 2018 and the awards will vest during the first quarter of 2019.

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The following table summarizes information with respect to unearned PSUs outstanding as of December 31, 2018 and PSU activity during the fiscal year then ended:

	Number of PSUs		Weighted Average Grant- Date Fair Value
Nonvested at December 31, 2017	782,781		$	10.06
Granted	96,389		$	11.36
Vested	(1,710	)	$	16.90
Forfeited	(125,085	)	$	17.59
Nonvested at December 31, 2018	752,375		$	8.86

Liability Classified Awards

Restricted Stock Units Settled in Cash

During the years ended December 31, 2018, 2017 and 2016, the Company issued 108,522, 98,364 and 198,668 restricted stock units to be settled in cash ("Cash RSUs"), respectively, which vest in three annual installments beginning one year from the grant date. The weighted average grant date fair value of the Cash RSUs granted during the years ended December 31, 2018, 2017 and 2016, was $10.71, $9.82 and $3.82, respectively, and was based on the closing price of our common stock on the day of grant. The Cash RSU liability at December 31, 2018 was adjusted based on the closing price of our common stock on December 31, 2018 of $8.55 per share. The cash RSU liability at December 31, 2018 was not material.

Cash Incentive Award

The Company also granted share-based compensation to eligible participants under the SunCoke Energy, Inc. Long-Term Cash Incentive Plan ("SunCoke LTCIP"), which became effective January 1, 2016. The SunCoke LTCIP is designed to provide for performance-based, cash-settled awards. All awards vest immediately upon a change in control and a qualifying termination of employment as defined by the SunCoke LTCIP.

The Company issued a grant date fair value award of $1.0 million, $0.7 million and $0.9 million during the years ended December 31, 2018, 2017 and 2016, respectively, for which the service periods end on December 31, 2021, 2020 and 2019, respectively, and the awards will vests during the first quarter of 2022, 2021 and 2020, respectively. The 2018 and 2017 awards are split 50/50 between the Company's three cumulative Adjusted EBITDA performance and the Company's three-year average pre-tax return on capital performance measure for its coke and logistics businesses and unallocated corporate expense. The ultimate award value will be determined by the performance versus targets and the Company's three year TSR Modifier performance, but will be capped at 250 percent of the target award.

The 2016 award value will be adjusted based upon the Company's three-year average pre-tax return on capital for the Company's coke and logistics businesses, and if at any time during the vesting period the closing price of the Company's common stock equals or exceeds $9.00 per share for any 15 trading days, which was met in 2016, the award, as adjusted, will be multiplied by two, but will be capped at 200 percent of the target award.

The cash incentive award liability at December 31, 2018 was adjusted based on the Company's current performance related to the above awards. The cash incentive award liability at December 31, 2018 was not material.

Summary of Share-Based Compensation Expense

Below is a summary of the compensation expense, unrecognized compensation costs, the period for which the unrecognized compensation cost is expected to be recognized over and the estimated forfeiture rate for each award:

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	Years ended December 31,
	2018		2017		2016		2018		2017		2016		December 31, 2018
	Compensation Expense(1)						Net of tax						Unrecognized Compensation Cost		Recognition Period
	(Dollars in millions)												(Dollars in millions)		(Years)
Equity Awards:
Stock Options	$	0.5	$	1.3	$	2.1	$	0.4	$	0.8	$	1.3	$	0.5	1.6
RSUs	0.4		1.1		2.6		0.3		0.7		1.7		$	0.3	1.7
PSUs	1.9		1.9		1.4		1.7		1.2		0.9		$	2.6	1.9
Total equity awards	$	2.8	$	4.3	$	6.1	$	2.4	$	2.7	$	3.9
Liability Awards:
Cash RSUs	$	0.8	$	1.0	$	0.7	$	0.6	$	0.6	$	0.5	$	0.7	1.4
Cash incentive award	0.9		0.2		0.1		0.7		0.1		0.1		$	0.9	1.8
Total liability awards	$	1.7	$	1.2	$	0.8	$	1.3	$	0.7	$	0.6

(1) Compensation expense is recognized by the Company in selling, general and administrative expenses on the Consolidated Statements of Income.

The Company issued $0.3 million, $0.5 million, and $0.4 million of share-based compensation to the Company's Board of Directors during the years ended December 31, 2018, 2017 and 2016, respectively.

16. Earnings Per Share

Basic earnings per share (“EPS”) has been computed by dividing net income (loss) available to SunCoke Energy, Inc. by the weighted average number of shares outstanding during the period. Except where the result would be anti-dilutive, diluted earnings per share has been computed to give effect to share-based compensation awards using the treasury stock method.

The following table sets forth the reconciliation of the weighted-average number of common shares used to compute basic earnings per share to those used to compute diluted EPS:

	Years Ended December 31,
	2018	2017	2016
	(Shares in millions)
Weighted-average number of common shares outstanding-basic	64.7	64.3	64.2
Add: effect of dilutive share-based compensation awards	0.8	0.9	0.2
Weighted-average number of shares-diluted	65.5	65.2	64.4

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The following table shows stock options, restricted stock units, and performance stock units that are excluded from the computation of diluted earnings per share as the shares would have been anti-dilutive:

	Years Ended December 31,
	2018	2017	2016
	(Shares in millions)
Stock options	2.7	2.9	3.0
Restricted stock units	—	—	0.2
Performance stock units	0.1	0.1	0.2
Total	2.8	3.0	3.4

17. Fair Value Measurements

The Company measures certain financial and non-financial assets and liabilities at fair value on a recurring basis. Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in the principal or most advantageous market in an orderly transaction between market participants on the measurement date. Fair value disclosures are reflected in a three-level hierarchy, maximizing the use of observable inputs and minimizing the use of unobservable inputs.

The valuation hierarchy is based upon the transparency of inputs to the valuation of an asset or liability on the measurement date. The three levels are defined as follows:

• Level 1—inputs to the valuation methodology are quoted prices (unadjusted) for an identical asset or liability in an active market.

• Level 2—inputs to the valuation methodology include quoted prices for a similar asset or liability in an active market or model-derived valuations in which all significant inputs are observable for substantially the full term of the asset or liability.

• Level 3—inputs to the valuation methodology are unobservable and significant to the fair value measurement of the asset or liability.

Financial Assets and Liabilities Measured at Fair Value on a Recurring Basis

Cash Equivalents

Certain assets and liabilities are measured at fair value on a recurring basis. The Company’s cash equivalents, which amounted to $3.2 million and $5.5 million at December 31, 2018 and 2017, respectively, were measured at fair value based on quoted prices in active markets for identical assets. These inputs are classified as Level 1 within the valuation hierarchy.

CMT Contingent Consideration

In connection with the CMT acquisition, the Partnership entered into a contingent consideration arrangement that runs through 2022 and requires the Partnership to make future payments to The Cline Group based on future volume over a specified threshold, price and contract renewals.The fair value of the contingent consideration was estimated based on a probability-weighted analysis using significant inputs that are not observable in the market, or Level 3 inputs. Key assumptions included probability adjusted levels of handling services provided by CMT, anticipated price per ton on future sales and probability of contract renewal, including length of future contracts, volume commitment, and anticipated price per ton. The fair value of the contingent consideration was $5.0 million and $2.5 million at December 31, 2018 and 2017, respectively, and was primarily included in other deferred credits and liabilities on the Consolidated Balance Sheets. 

During 2018, CMT achieved record volumes and the Partnership increased CMT’s throughput volume projections in future periods for certain customers due to favorable coal prices, which are expected to increase export volume through CMT. The combined impact of the strong 2018 volumes and improved volume projections resulted in an increase to the fair value of the Partnership's contingent consideration balance of $2.5 million, which was recorded as a charge to costs of products sold and operating expenses in the Consolidated Statements of Income during 2018.

During 2017 and 2016, as a result of adverse mining conditions faced by one of our thermal coal customers, as well as fluctuating export coal pricing, the Partnership lowered CMT's throughput volume, which reduced the Partnership's contingent consideration liability balance by $1.7 million and $6.4 million, respectively. Additionally, during March 2016, as a part of commercial activities subsequent to the acquisition of CMT, the Partnership and The Cline Group signed an amended agreement, which modified the contingent consideration terms by increasing the volume threshold required for the

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Partnership to make payments to The Cline Group in exchange for future pricing modifications, resulting in a $3.7 million reduction to the contingent consideration liability. These decreases in fair value were recorded as reductions to costs of products sold and operating expenses on the Consolidated Statements of Income during 2017 and 2016.

Certain Financial Assets and Liabilities not Measured at Fair Value

At December 31, 2018 and 2017, the fair value of the Company’s long-term debt was estimated to be $822.8 million and $919.7 million, respectively, compared to a carrying amount of $859.0 million and $887.3 million, respectively. These fair values were estimated by management based upon estimates of debt pricing provided by financial institutions which are considered Level 2 inputs.

18. Revenue from Contracts with Customers

Cokemaking

Substantially all our coke sales are made pursuant to long-term, take-or-pay agreements with AM USA, AK Steel and U.S. Steel, who are three of the largest blast furnace steelmakers in North America. The take-or-pay provisions of our agreements require us to deliver minimum annual tonnage, which varies by contract, but covers at least 90 percent of each facility's nameplate capacity. The take-or-pay provisions also require our customers to purchase such volumes of coke or pay the contract price for any tonnage they elect not to take. These coke sales agreements have an average remaining term of approximately six years, and to date, our coke customers have satisfied their obligations under these agreements.

Our coke sales prices include an operating cost component, a coal cost component and a return of capital component. Operating costs under two of our coke sales agreements are contractual, subject to an annual adjustment based on an inflation index. Under our other four coke sales agreements operating costs are passed through to the respective customers subject to an annually negotiated budget, in some cases subject to a cap annually adjusted for inflation, and generally we share any difference in costs from the budgeted amounts with our customers. Our coke sales agreements contain pass-through provisions for coal and coal procurement costs, subject to meeting contractual coal-to-coke yields. To the extent that the actual coal-to-coke yields are less than the contractual standard, we are responsible for the cost of the excess coal used in the cokemaking process. Conversely, to the extent our actual coal-to-coke yields are higher than the contractual standard, we realize gains. The reimbursement of pass-through operating and coal costs from these coke sales agreements are considered to be variable consideration components included in the cokemaking sales price. The return of capital component for each ton of coke sold to the customer is determined at the time the coke sales agreement is signed and is effective for the term of each sales agreement. This component of our coke sales prices is intended to provide an adequate return on invested capital and may differ based on investment levels and other considerations. The actual return on invested capital at any facility is also impacted by favorable or unfavorable performance on pass-through cost items. Revenues are recognized when performance obligations to our customers are satisfied in an amount that reflects the consideration that we expect to receive in exchange for the coke.

Logistics

In our logistics business, handling and/or mixing services are provided to steel, coke (including some of our domestic cokemaking facilities), electric utility, coal producing and other manufacturing based customers. Materials are transported in numerous ways, including rail, truck, barge or ship. We do not take possession of materials handled, but rather act as intermediaries between our customers and end users, deriving our revenues from services provided on a per ton basis. The handling and mixing services consist primarily of two performance obligations, unloading and loading of materials. Our logistics business has long-term, take-or-pay agreements requiring us to handle over 13 million tons annually. The take-or-pay provisions in these agreements require our customers to purchase such handling services or pay the contract price for services they elect not to take. Estimated take-or-pay revenue of approximately $305 million from all of our long-term logistics contracts is expected to be recognized over the next five years for unsatisfied or partially unsatisfied performance obligations as of December 31, 2018. To date, our customers have satisfied their obligations under these agreements. Included with these long-term, take-or-pay arrangements are our contracts with Murray and Foresight, which cover 10 million tons of CMT's annual transloading capacity of 15 million tons. Revenues are recognized when the customer receives the benefits of the services provided, in an amount that reflects the consideration that we will receive in exchange for those services. Billings to CMT customers for take-or-pay volume shortfalls based on pro-rata volume commitments under take-or-pay contracts that are in excess of billings earned for services provided are recorded as contract liabilities and characterized as deferred revenue on the Consolidated Balance Sheets. Deferred revenue is recognized at the earliest of i) when the performance obligation is satisfied; ii) when the performance obligation has expired, based on the terms of the contract; or iii) when the likelihood that the customer would exercise its right to the performance obligation becomes remote.

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The following table provides changes in the Company's deferred revenue:

	2018			2017
	(Dollars in millions)
Beginning balance at December 31, 2017 and 2016, respectively	$	1.7		$	2.5
Reclassification of the beginning contract liabilities to revenue, as a result of performance obligation satisfied	(1.4		)	(2.1		)
Billings in excess of services performed, not recognized as revenue	2.7			1.3
Ending balance at December 31, 2018 and 2017, respectively	$	3.0		$	1.7

Energy

Our energy sales are made pursuant to either steam or energy supply and purchase agreements or is sold into the regional power market. Our cokemaking ovens utilize efficient, modern heat recovery technology designed to combust the coal’s volatile components liberated during the cokemaking process and use the resulting heat to create steam or electricity for sale. The energy provided under these arrangements result in transfer of control over time. Revenues are recognized over time as energy is delivered to our customers, in an amount based on the terms of each arrangement.

Operating and Licensing Fees

Operating and licensing fees are made pursuant to long-term contracts with ArcelorMittal Brazil, where we operate a Brazilian cokemaking facility. The licensing fees are based upon the level of production required by our customer as well as a fixed annual fee. Operating fees include the full pass-through of the operating costs of the Brazilian facility as well as a per ton fee based on the level of production required by our customer. Revenues are recognized over time as our customers receive and consume the benefits in an amount that corresponds directly with the value provided to the customer to date.

Disaggregated Sales and Other Operating Revenue

The following table provides disaggregated sales and other operating revenue by product or service, excluding intersegment revenues:

	Years Ended December 31,
	2018		2017		2016
	(Dollars in millions)
Sales and other operating revenue:
Cokemaking	$	1,250.5	$	1,140.8	$	1,038.2
Energy	49.7		53.2		54.3
Logistics	101.0		89.7		82.9
Operating and licensing fees	40.4		43.4		39.5
Other	9.3		4.4		8.4
Sales and other operating revenue	$	1,450.9	$	1,331.5	$	1,223.3

Disaggregated sales and other operating revenue by customer is discussed in Note 4.

19. Business Segment Information

The Company reports its business through three segments: Domestic Coke, Brazil Coke and Logistics. The Domestic Coke segment includes the Jewell, Indiana Harbor, Haverhill, Granite City and Middletown cokemaking facilities. Each of these facilities produces coke, and all facilities except Jewell recover waste heat, which is converted to steam or electricity through a similar production process.

The Brazil Coke segment includes the licensing and operating fees payable to us under long-term contracts with ArcelorMittal Brazil, under which we operate a cokemaking facility located in Vitória, Brazil through at least 2023.

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Logistics operations are comprised of CMT, KRT, Lake Terminal, which provides services to our Indiana Harbor cokemaking facility, and DRT, which provides services to our Jewell cokemaking facility. Handling and mixing results are presented in the Logistics segment.

Corporate expenses that can be identified with a segment have been included in determining segment results. The remainder is included in Corporate and Other. Corporate and Other also includes activity from our legacy coal mining business.

Segment assets are those assets utilized within a specific segment and exclude taxes.

The following table includes Adjusted EBITDA, which is the measure of segment profit or loss and liquidity reported to the chief operating decision maker for purposes of allocating resources to the segments and assessing their performance:

	Years Ended December 31,
	2018			2017			2016
	(Dollars in millions)
Sales and other operating revenue:
Domestic Coke	$	1,308.3		$	1,195.0		$	1,097.6
Brazil Coke	40.4			43.4			39.5
Logistics	102.2			93.1			84.7
Logistics intersegment sales	24.5			23.8			23.2
Corporate and Other(1)	—			—			1.5
Corporate and Other intersegment sales(1)	—			—			22.0
Elimination of intersegment sales	(24.5		)	(23.8		)	(45.2		)
Total sales and other operating revenue	$	1,450.9		$	1,331.5		$	1,223.3
Adjusted EBITDA
Domestic Coke	$	207.9		$	188.9		$	193.9
Brazil Coke	18.4			18.2			16.2
Logistics	72.6			70.8			63.9
Corporate and Other(2)	(35.7		)	(43.2		)	(57.0		)
Total Adjusted EBITDA	$	263.2		$	234.7		$	217.0
Depreciation and amortization expense:
Domestic Coke(3)	$	114.4		$	102.6		$	84.0
Brazil Coke	0.7			0.7			0.7
Logistics	25.1			24.4			24.8
Corporate and Other	1.4			0.5			4.7
Total depreciation and amortization expense	$	141.6		$	128.2		$	114.2
Capital expenditures:
Domestic Coke	$	95.1		$	68.8		$	44.6
Logistics	5.2			4.4			17.4
Corporate and Other	—			2.4			1.7
Total capital expenditures	$	100.3		$	75.6		$	63.7

(1) Corporate and Other revenues are related to our legacy coal mining business, which was disposed in April 2016.

(2) Corporate and Other includes the activity from our legacy coal mining business, which incurred Adjusted EBITDA losses of $9.8 million, $10.5 million, and $15.0 million for the years ended December 31, 2018, 2017 and 2016, respectively.

(3) We revised the estimated useful lives of certain assets in our Domestic Coke segment, primarily as a result of plans to replace major components of certain heat recovery steam generators with upgraded materials and design, resulting in additional depreciation of $9.2 million, or $0.14 per common share, during the year ended December 31, 2018.

97

The following table sets forth the Company’s segment assets:

	December 31,
	2018		2017
	(Dollars in millions)
Segment assets
Domestic Coke	$	1,446.5	$	1,439.7
Brazil Coke	15.1		10.9
Logistics	463.0		491.9
Corporate and Other	120.0		112.8
Segment assets, excluding income tax receivable	2,044.6		2,055.3
Tax assets	0.7		4.8
Total assets	$	2,045.3	$	2,060.1

The Company evaluates the performance of its segments based on segment Adjusted EBITDA, which is defined as earnings before interest, (gain) loss on extinguishment of debt, taxes, depreciation and amortization (“EBITDA”), adjusted for impairments, coal rationalization costs, changes to our contingent consideration liability related to our acquisition of CMT, the expiration of certain acquired contractual obligations, and loss on disposal of our interest in VISA SunCoke. EBITDA and Adjusted EBITDA do not represent and should not be considered alternatives to net income or operating income under GAAP and may not be comparable to other similarly titled measures in other businesses.

Management believes Adjusted EBITDA is an important measure of the operating performance and liquidity of the Company's net assets and its ability to incur and service debt, fund capital expenditures and make distributions. Adjusted EBITDA provides useful information to investors because it highlights trends in our business that may not otherwise be apparent when relying solely on GAAP measures and because it eliminates items that have less bearing on our operating performance and liquidity. EBITDA and Adjusted EBITDA are not measures calculated in accordance with GAAP, and they should not be considered a substitute for net income, operating cash flow or any other measure of financial performance presented in accordance with GAAP. Set forth below is additional discussion of the limitations of Adjusted EBITDA as an analytical tool.

Limitations. Other companies may calculate Adjusted EBITDA differently than we do, limiting its usefulness as a comparative measure. Adjusted EBITDA also has limitations as an analytical tool and should not be considered in isolation or as a substitute for an analysis of our results as reported under GAAP. Some of these limitations include that Adjusted EBITDA:

• does not reflect our cash expenditures, or future requirements, for capital expenditures or contractual commitments;

• does not reflect items such as depreciation and amortization;

• does not reflect changes in, or cash requirement for, working capital needs;

• does not reflect our interest expense, or the cash requirements necessary to service interest on or principal payments of our debt;

• does not reflect certain other non-cash income and expenses

• excludes income taxes that may represent a reduction in available cash; and

• includes net income attributable to noncontrolling interests

98

Below are reconciliations of Adjusted EBITDA to net income and Adjusted EBITDA to net cash provided by operating activities, which are its most directly comparable financial measures calculated and presented in accordance with GAAP:

	Years Ended December 31,
	2018			2017			2016
	(Dollars in millions)
Net cash provided by operating activities	$	185.8		$	148.5		$	219.1
Subtract:
Depreciation and amortization expense	141.6			128.2			114.2
Deferred income tax (benefit) expense	(3.4		)	(87.2		)	3.1
Loss (gain) on extinguishment of debt	0.3			20.4			(25.0		)
Loss on divestiture of business	—			—			14.7
Loss from equity method investment	5.4			—			—
Changes in working capital and other	(5.1		)	(16.4		)	52.6
Net income	$	47.0		$	103.5		$	59.5
Add:
Depreciation and amortization expense	141.6			128.2			114.2
Interest expense, net(1)	61.4			60.6			53.5
Loss (gain) on extinguishment of debt	0.3			20.4			(25.0		)
Income tax expense (benefit)	4.6			(81.6		)	8.6
Contingent consideration adjustments(2)	2.5			(1.7		)	(10.1		)
Transaction costs(3)	0.4			—			—
Expiration of land deposits and write-off of costs related to potential new cokemaking facility(4)	—			5.3			1.9
Non-cash reversal of acquired contractual obligation(5)	—			—			(0.7		)
Loss on divestiture of business	—			—			14.7
Coal rationalization costs(6)	—			—			0.4
Loss from equity method investment	5.4			—			—
Adjusted EBITDA	$	263.2		$	234.7		$	217.0
Subtract: Adjusted EBITDA attributable to noncontrolling interest(7)	82.0			86.4			86.6
Adjusted EBITDA attributable to SunCoke Energy, Inc.	$	181.2		$	148.3		$	130.4

(1) In conjunction with the adoption of ASU 2017-07, the non-service type expense associated with the postretirement benefit plans was excluded from operating income and recorded in interest expense, net on the Consolidated Statements of Income during the periods presented. Amounts in prior periods were immaterial, and therefore, were not reclassified in the reconciliation of Adjusted EBITDA to net income and net cash provided by operating activities.

(2) Adjustments to the fair value of the contingent consideration in 2018, 2017 and 2016 were primarily the result of modifications to the volume forecast. See Note 17.

(3) Represents costs incurred in connection with the Simplification Transaction.

(4) In 2014, we finalized the required permitting and engineering plan for a potential new cokemaking facility, however, the project was terminated. As a result, during 2017 and 2016, the Company wrote-off previously capitalized engineering costs and land deposits for a potential new cokemaking facility of $5.3 million and $1.9 million, respectively. These costs were included in selling, general and administrative expenses on the Consolidated Statements of Income.

(5) In association with the acquisition of CMT, we assumed certain performance obligations under existing contracts and recorded liabilities related to such obligations. In 2016, the Partnership reversed the liability as we no longer had any obligations under the contracts.

99

(6) Prior to the divestiture of our coal mining business, the Company incurred coal rationalization costs including employee severance, contract termination costs and other costs to idle mines during the execution of our coal rationalization plan.

(7) Reflects noncontrolling interests in Indiana Harbor and the portion of the Partnership owned by public unitholders.

20. Selected Quarterly Data (unaudited)

	2018								2017
	First Quarter		Second Quarter		Third Quarter		Fourth Quarter(1)		First Quarter(2)			Second Quarter(3)			Third Quarter		Fourth Quarter(1)(4)
	(Dollars in millions)
Sales and other operating revenue	$	350.5	$	367.0	$	364.5	$	368.9	$	309.7		$	323.2		$	339.0	$	359.6
Gross profit(5)	$	47.0	$	52.3	$	45.8	$	39.7	$	42.2		$	32.9		$	51.3	$	56.8
Net income (loss)	$	13.0	$	11.4	$	17.1	$	5.5	$	(57.7	)	$	(31.5	)	$	18.8	$	173.9
Less: Net income (loss) attributable to noncontrolling interests	$	4.3	$	7.2	$	5.6	$	3.7	$	(58.7	)	$	(7.3	)	$	7.2	$	39.9
Net income (loss) attributable to SunCoke Energy, Inc.	$	8.7	$	4.2	$	11.5	$	1.8	$	1.0		$	(24.2	)	$	11.6	$	134.0
Earnings (loss) attributable to SunCoke Energy, Inc. per common share:
Basic(6)	$	0.13	$	0.06	$	0.18	$	0.03	$	0.02		$	(0.38	)	$	0.18	$	2.08
Diluted(6)	$	0.13	$	0.06	$	0.18	$	0.03	$	0.02		$	(0.38	)	$	0.18	$	2.05

(1) The Partnership recognized deferred revenue from Logistics take-or-pay billings for minimum volume shortfalls of $16.4 million into revenue in the fourth quarter of 2017. As a result of the increase in tons handled throughout 2018, there were no shortfalls to be recognized during the fourth quarter.

(2) The first quarter of 2017 reflects the net impact to the Company’s deferred tax expense of $64.2 million related to the IRS Final Regulations on qualifying income all of which was attributable to unitholders of the Partnership. See Note 5.

(3) During the second quarter of 2017, the Partnership incurred $20.2 million of losses in connection with debt refinancing.

(4) During the fourth quarter of 2017, the Company recorded $154.7 million of tax benefits as a result of the new Tax Legislation, $125.0 million of which was attributable to the Company. See Note 5.

(5) Gross profit equals sales and other operating revenue less cost of products sold and operating expenses and depreciation and amortization.

(6) Basic and diluted earnings per share are computed independently for each of the quarters presented. Therefore, the sum of quarterly basic and diluted per share information may not equal annual basic and diluted earnings per share.

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21. Supplemental Condensed Combining and Consolidating Financial Information

Certain 100 percent owned subsidiaries of the Company serve as guarantors of the obligations under the Credit Agreement (“Guarantor Subsidiaries”). These guarantees are full and unconditional (subject, in the case of the Guarantor Subsidiaries, to customary release provisions as described below) and joint and several. For purposes of the following information, SunCoke Energy is referred to as “Issuer.” The indenture dated July 26, 2011 among the Company, the guarantors party thereto and The Bank of New York Mellon Trust Company, N.A., governs subsidiaries designated as “Guarantor Subsidiaries.” All other consolidated subsidiaries of the Company are collectively referred to as “Non-Guarantor Subsidiaries.”

The ability of the Partnership and Indiana Harbor to pay dividends and make loans to the Company is restricted under the partnership agreements of the Partnership and Indiana Harbor, respectively. The credit agreement governing the Partnership’s credit facility and the indenture governing the Partnership Notes contain customary provisions which would potentially restrict the Partnership’s ability to make distributions or loans to the Company under certain circumstances. For the year ended December 31, 2018, less than 25 percent of net assets were restricted. Additionally, certain coal mining entities are designated as unrestricted subsidiaries. As such, all the subsidiaries described above are presented as "Non-Guarantor Subsidiaries."

The guarantee of a Guarantor Subsidiary will terminate upon:

• a sale or other disposition of the Guarantor Subsidiary or of all or substantially all of its assets;

• a sale of the majority of the Capital Stock of a Guarantor Subsidiary to a third-party, after which the Guarantor Subsidiary is no longer a "Restricted Subsidiary" in accordance with the indenture governing the Notes;

• the liquidation or dissolution of a Guarantor Subsidiary so long as no "Default" or "Event of Default", as defined under the indenture governing the Notes, has occurred as a result thereof;

• the requirements for defeasance or discharge of the indentures governing the Notes having been satisfied; or

• the release, other than the discharge through payments by a Guarantor Subsidiary, from its guarantee under the Credit Agreement or other indebtedness that resulted in the obligation of the Guarantor Subsidiary under the indenture governing the Notes

The following supplemental condensed combining and consolidating financial information reflects the Issuer’s separate accounts, the combined accounts of the Guarantor Subsidiaries, the combined accounts of the Non-Guarantor Subsidiaries, the combining and consolidating adjustments and eliminations and the Issuer’s consolidated accounts for the dates and periods indicated. For purposes of the following condensed combining and consolidating information, the Issuer’s investments in its subsidiaries and the Guarantor and Non-Guarantor Subsidiaries’ investments in its subsidiaries are accounted for under the equity method of accounting.

101

SunCoke Energy, Inc.

Condensed Consolidating Statement of Income

Years Ended December 31, 2018

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Revenues
Sales and other operating revenue	$	—		$	216.0		$	1,239.5		$	(4.6	)	$	1,450.9
Equity in earnings of subsidiaries	34.3			25.2			—			(59.5		)	—
Total revenues, net of equity in earnings of subsidiaries	34.3			241.2			1,239.5			(64.1		)	1,450.9
Costs and operating expenses
Cost of products sold and operating expenses	—			165.7			963.4			(4.6		)	1,124.5
Selling, general and administrative expenses	6.5			11.8			47.8			—			66.1
Depreciation and amortization expenses	—			8.8			132.8			—			141.6
Total costs and operating expenses	6.5			186.3			1,144.0			(4.6		)	1,332.2
Operating income	27.8			54.9			95.5			(59.5		)	118.7
Interest (income) expense, net - affiliate	—			(6.0		)	6.0			—			—
Interest expense (income), net	3.1			(1.6		)	59.9			—			61.4
Total interest expense (income), net	3.1			(7.6		)	65.9			—			61.4
Loss on extinguishment of debt	0.3			—			—			—			0.3
Income before income tax (benefit) expense	24.4			62.5			29.6			(59.5		)	57.0
Income tax (benefit) expense	(1.8		)	12.1			(5.7		)	—			4.6
Loss from equity method investment	—			—			5.4			—			5.4
Net income	26.2			50.4			29.9			(59.5		)	47.0
Less: Net income attributable to noncontrolling interests	—			—			20.8			—			20.8
Net income attributable to SunCoke Energy, Inc.	$	26.2		$	50.4		$	9.1		$	(59.5	)	$	26.2
Comprehensive income	$	34.3		$	50.6		$	37.8		$	(67.6	)	$	55.1
Less: Comprehensive income attributable to noncontrolling interests	—			—			20.8			—			20.8
Comprehensive income attributable to SunCoke Energy, Inc.	$	34.3		$	50.6		$	17.0		$	(67.6	)	$	34.3

102

SunCoke Energy, Inc.

Condensed Consolidating Statement of Income

Years Ended December 31, 2017

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Revenues
Sales and other operating revenue	$	—		$	209.6		$	1,126.3		$	(4.4	)	$	1,331.5
Equity in earnings (loss) of subsidiaries	109.9			(54.5		)	—			(55.4		)	—
Total revenues, net of equity in earnings (loss) of subsidiaries	109.9			155.1			1,126.3			(59.8		)	1,331.5
Costs and operating expenses
Cost of products sold and operating expenses	—			156.6			867.9			(4.4		)	1,020.1
Selling, general and administrative expenses	8.7			22.7			47.6			—			79.0
Depreciation and amortization expenses	—			7.5			120.7			—			128.2
Total costs and operating expenses	8.7			186.8			1,036.2			(4.4		)	1,227.3
Operating income (loss)	101.2			(31.7		)	90.1			(55.4		)	104.2
Interest (income) expense, net - affiliate	—			(7.5		)	7.5			—			—
Interest expense, net	4.9			0.1			56.9			—			61.9
Total interest expense (income), net	4.9			(7.4		)	64.4			—			61.9
Gain on extinguishment of debt	0.4			—			20.0			—			20.4
Income (loss) before income tax (benefit) expense	95.9			(24.3		)	5.7			(55.4		)	21.9
Income tax (benefit) expense	(26.5		)	(150.2		)	95.1			—			(81.6		)
Net income (loss)	122.4			125.9			(89.4		)	(55.4		)	103.5
Less: Net loss attributable to noncontrolling interests	—			—			(18.9		)	—			(18.9		)
Net income (loss) attributable to SunCoke Energy, Inc.	$	122.4		$	125.9		$	(70.5	)	$	(55.4	)	$	122.4
Comprehensive income (loss)	$	121.3		$	125.3		$	(91.0	)	$	(53.2	)	$	102.4
Less: Comprehensive loss attributable to noncontrolling interests	—			—			(18.9		)	—			(18.9		)
Comprehensive income (loss) attributable to SunCoke Energy, Inc.	$	121.3		$	125.3		$	(72.1	)	$	(53.2	)	$	121.3

103

SunCoke Energy, Inc.

Condensed Consolidating Statement of Income

Years Ended December 31, 2016

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Revenues
Sales and other operating revenue	$	—		$	176.7		$	1,050.5		$	(3.9	)	$	1,223.3
Equity in earnings of subsidiaries	19.7			51.3			—			(71.0		)	—
Total revenues, net of equity in earnings of subsidiaries	19.7			228.0			1,050.5			(74.9		)	1,223.3
Costs and operating expenses
Cost of products sold and operating expenses	—			130.7			779.1			(3.9		)	905.9
Selling, general and administrative expenses	12.9			25.6			52.1			—			90.6
Depreciation and amortization expenses	—			9.2			105.0			—			114.2
Loss on divestiture of business and impairments	—			—			14.7			—			14.7
Total costs and operating expenses	12.9			165.5			950.9			(3.9		)	1,125.4
Operating income	6.8			62.5			99.6			(71.0		)	97.9
Interest (income) expense, net - affiliate	—			(7.6		)	7.6			—			—
Interest expense, net	6.0			0.3			48.5			—			54.8
Total interest expense (income), net	6.0			(7.3		)	56.1			—			54.8
Gain on extinguishment of debt, net	—			—			(25.0		)	—			(25.0		)
Income before income tax (benefit) expense and loss (gain) from equity method investment	0.8			69.8			68.5			(71.0		)	68.1
Income tax (benefit) expense	(13.6		)	38.7			(16.5		)	—			8.6
Net income	14.4			31.1			85.0			(71.0		)	59.5
Less: Net income attributable to noncontrolling interests	—			—			45.1			—			45.1
Net income attributable to SunCoke Energy, Inc.	$	14.4		$	31.1		$	39.9		$	(71.0	)	$	14.4
Comprehensive income	$	15.2		$	30.8		$	86.1		$	(71.8	)	$	60.3
Less: Comprehensive income attributable to noncontrolling interests	—			—			45.1			—			45.1
Comprehensive income attributable to SunCoke Energy, Inc.	$	15.2		$	30.8		$	41.0		$	(71.8	)	$	15.2

104

SunCoke Energy, Inc.

Condensed Consolidating Balance Sheet

December 31, 2018

(Dollars in millions, except per share amounts)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Assets
Cash and cash equivalents	$	—		$	123.2		$	22.5		$	—		$	145.7
Receivables	—			13.3			62.1			—			75.4
Inventories	—			10.6			99.8			—			110.4
Income tax receivable	—			—			96.1			(95.4		)	0.7
Other current assets	—			1.8			1.0			—			2.8
Advances to affiliates	—			281.1			—			(281.1		)	—
Total current assets	—			430.0			281.5			(376.5		)	335.0
Notes receivable from affiliate	—			—			200.0			(200.0		)	—
Properties, plants and equipment, net	—			54.3			1,416.8			—			1,471.1
Goodwill	—			3.4			73.5			—			76.9
Other intangibles assets, net	—			1.1			155.7			—			156.8
Deferred income taxes	7.0			—			—			(7.0		)	—
Deferred charges and other assets	—			5.1			0.4			—			5.5
Total assets	$	7.0		$	493.9		$	2,127.9		$	(583.5	)	$	2,045.3
Liabilities and Equity
Advances from affiliate	$	167.3		$	—		$	113.8		$	(281.1	)	$	—
Accounts payable	—			14.7			100.3			—			115.0
Accrued liabilities	1.8			13.7			30.1			—			45.6
Deferred revenue	—			—			3.0			—			3.0
Current portion of long-term debt and financing obligation	1.1			—			2.8			—			3.9
Interest payable	0.4			—			3.2			—			3.6
Income taxes payable	1.9			93.5			—			(95.4		)	—
Total current liabilities	172.5			121.9			253.2			(376.5		)	171.1
Long term-debt and financing obligation	41.2			—			793.3			—			834.5
Payable to affiliate	—			200.0			—			(200.0		)	—
Accrual for black lung benefits	—			10.9			34.0			—			44.9
Retirement benefit liabilities	—			12.2			13.0			—			25.2
Deferred income taxes	—			194.9			66.8			(7.0		)	254.7
Asset retirement obligations	—			—			14.6			—			14.6
Other deferred credits and liabilities	3.5			6.6			7.5			—			17.6
Total liabilities	217.2			546.5			1,182.4			(583.5		)	1,362.6
Equity
Preferred stock, $0.01 par value. Authorized 50,000,000 shares; no issued and outstanding shares at December 31, 2018	—			—			—			—			—
Common stock, $0.01 par value. Authorized 300,000,000 shares; issued 72,223,750 shares at December 31, 2018	0.7			—			—			—			0.7
Treasury stock, 7,477,657 shares at December 31, 2018	(140.7		)	—			—						(140.7		)
Additional paid-in capital	488.9			61.0			612.8			(673.9		)	488.8
Accumulated other comprehensive loss	(13.1		)	(2.0		)	(11.1		)	13.1			(13.1		)
Retained earnings	127.5			526.1			124.2			(650.4		)	127.4
Equity investment eliminations	(673.5		)	(637.7		)	—			1,311.2			—
Total SunCoke Energy, Inc. stockholders’ equity	(210.2		)	(52.6		)	725.9			—			463.1
Noncontrolling interests	—			—			219.6			—			219.6
Total equity	(210.2		)	(52.6		)	945.5			—			682.7
Total liabilities and equity	$	7.0		$	493.9		$	2,127.9		$	(583.5	)	$	2,045.3

105

SunCoke Energy, Inc.

Condensed Consolidating Balance Sheet

December 31, 2017

(Dollars in millions, except per share amounts)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Assets
Cash and cash equivalents	$	—		$	103.6		$	16.6		$	—		$	120.2
Receivables	—			17.1			51.4			—			68.5
Inventories	—			9.1			101.9			—			111.0
Income taxes receivable	—			—			88.1			(83.3		)	4.8
Other current assets	—			4.6			2.1			—			6.7
Advances to affiliate	—			245.8			—			(245.8		)	—
Total current assets	—			380.2			260.1			(329.1		)	311.2
Notes receivable from affiliate	—			89.0			300.0			(389.0		)	—
Properties, plants and equipment, net	—			59.8			1,441.5			—			1,501.3
Goodwill	—			3.4			73.5			—			76.9
Other intangible assets, net	—			1.7			166.2			—			167.9
Deferred income taxes	7.1			—			—			(7.1		)	—
Deferred charges and other assets	—			2.3			0.5			—			2.8
Total assets	$	7.1		$	536.4		$	2,241.8		$	(725.2	)	$	2,060.1
Liabilities and Equity
Advances from affiliate	$	162.2		$	—		$	83.6		$	(245.8	)	$	—
Accounts payable	—			16.4			99.1			—			115.5
Accrued liabilities	1.5			19.7			32.0			—			53.2
Deferred Revenue	—			—			1.7			—			1.7
Current portion of long-term debt and financing obligation	—			—			2.6			—			2.6
Interest payable	1.4			—			4.0			—			5.4
Income taxes payable	1.9			81.4			—			(83.3		)	—
Total current liabilities	167.0			117.5			223.0			(329.1		)	178.4
Long-term debt and financing obligation	42.7			—			818.4			—			861.1
Payable to affiliate	—			300.0			89.0			(389.0		)	—
Accrual for black lung benefits	—			11.8			33.1			—			44.9
Retirement benefit liabilities	—			13.7			14.5			—			28.2
Deferred income taxes	—			193.8			71.1			(7.1		)	257.8
Asset retirement obligations	—			—			14.0			—			14.0
Other deferred credits and liabilities	3.7			6.4			6.0			—			16.1
Total liabilities	213.4			643.2			1,269.1			(725.2		)	1,400.5
Equity
Preferred stock, $0.01 par value. Authorized 50,000,000 shares; no issued and outstanding shares at December 31, 2017	—			—			—			—			—
Common stock, $0.01 par value. Authorized 300,000,000 shares; issued 71,707,304 shares at December 31, 2017	0.7			—			—			—			0.7
Treasury stock, 7,477,657 shares at December 31, 2017	(140.7		)	—			—			—			(140.7		)
Additional paid-in capital	486.2			141.0			641.9			(782.9		)	486.2
Accumulated other comprehensive loss	(21.2		)	(2.2		)	(19.0		)	21.2			(21.2		)
Retained earnings	101.2			475.6			116.4			(592.0		)	101.2
Equity investment eliminations	(632.5		)	(721.2		)	—			1,353.7			—
Total SunCoke Energy, Inc. stockholders’ equity	(206.3		)	(106.8		)	739.3			—			426.2
Noncontrolling interests	—			—			233.4			—			233.4
Total equity	(206.3		)	(106.8		)	972.7			—			659.6
Total liabilities and equity	$	7.1		$	536.4		$	2,241.8		$	(725.2	)	$	2,060.1

106

SunCoke Energy, Inc.

Condensed Consolidating Statement of Cash Flows

Years Ended December 31, 2018

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Cash Flows from Operating Activities:
Net income (loss)	$	26.2		$	50.4		$	29.9		$	(59.5	)	$	47.0
Adjustments to reconcile net income to net cash (used in) provided by operating activities:
Loss from equity method investment	—			—			5.4			—			5.4
Depreciation and amortization expense	—			8.8			132.8			—			141.6
Deferred income tax (benefit) expense	(0.2		)	1.2			(4.4		)	—			(3.4		)
Gain on curtailment and payments in excess of expense for postretirement plan benefits	—			(1.0		)	(1.4		)	—			(2.4		)
Share-based compensation expense	3.1			—			—			—			3.1
Equity in loss of subsidiaries	(34.3		)	(25.2		)	—			59.5			—
Loss on extinguishment of debt	0.3			—			—			—			0.3
Changes in working capital pertaining to operating activities:
Receivables	—			3.8			(10.7		)	—			(6.9		)
Inventories	—			(1.5		)	2.1			—			0.6
Accounts payable	—			(1.6		)	0.9			—			(0.7		)
Accrued liabilities	0.4			(5.9		)	(1.8		)	—			(7.3		)
Deferred revenue	—			—			1.3			—			1.3
Interest payable	(1.0		)	—			(0.8		)	—			(1.8		)
Income taxes	0.3			12.2			(8.0		)	—			4.5
Other	0.3			(0.9		)	5.1			—			4.5
Net cash (used in) provided by operating activities	(4.9		)	40.3			150.4			—			185.8
Cash Flows from Investing Activities:
Capital expenditures	—			(2.8		)	(97.5		)	—			(100.3		)
Sale of equity method investment	—			—			4.0			—			4.0
Other investing activities	—			—			0.5			—			0.5
Net cash used in investing activities	—			(2.8		)	(93.0		)	—			(95.8		)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt	45.0			—			—			—			45.0
Repayment of long-term debt	(45.7		)	—			—			—			(45.7		)
Debt issuance costs	(0.5		)	—			—			—			(0.5		)
Proceeds from revolving facility	—			—			179.5			—			179.5
Repayment of revolving facility	—			—			(204.5		)	—			(204.5		)
Repayment of financing obligation	—			—			(2.6		)	—			(2.6		)
Cash distributions to noncontrolling interests	—			—			(31.9		)	—			(31.9		)
Acquisition of additional interest in the Partnership	—			(4.2		)	—			—			(4.2		)
Other financing activities	0.7			—			(0.3		)	—			0.4
Net increase (decrease) in advances from affiliates	5.4			(13.7		)	8.3			—			—
Net cash provided by (used in) financing activities	4.9			(17.9		)	(51.5		)	—			(64.5		)
Net increase in cash, cash equivalents and restricted cash	—			19.6			5.9			—			25.5
Cash, cash equivalents and restricted cash at beginning of year	—			103.6			16.6			—			120.2
Cash, cash equivalents and restricted cash at end of year	$	—		$	123.2		$	22.5		$	—		$	145.7

107

SunCoke Energy, Inc.

Condensed Consolidating Statement of Cash Flows

Years Ended December 31, 2017

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Cash Flows from Operating Activities:
Net income (loss)	$	122.4		$	125.9		$	(89.4	)	$	(55.4	)	$	103.5
Adjustments to reconcile net income (loss) to net cash (used in) provided by operating activities:
Depreciation and amortization expense	—			7.5			120.7			—			128.2
Deferred income tax (benefit) expense	(22.8		)	(170.1		)	105.7			—			(87.2		)
Gain on curtailment and payments in excess of expense for postretirement plan benefits	—			(1.0		)	(0.8		)	—			(1.8		)
Share-based compensation expense	4.7			—			0.1			—			4.8
Equity in (loss) earnings of subsidiaries	(109.9		)	54.5			—			55.4			—
Loss on extinguishment of debt	0.4			—			20.0			—			20.4
Changes in working capital pertaining to operating activities (net of the effects of divestiture):
Receivables	—			(4.9		)	(2.9		)	—			(7.8		)
Inventories	—			(0.1		)	(18.4		)	—			(18.5		)
Accounts payable	—			3.0			8.7			—			11.7
Accrued liabilities	(0.2		)	(1.3		)	4.1			—			2.6
Deferred revenue	—			—			(0.8		)	—			(0.8		)
Interest payable	(0.1		)	—			(10.7		)	—			(10.8		)
Income taxes	(2.7		)	16.3			(13.8		)	—			(0.2		)
Other	1.3			—			3.1			—			4.4
Net cash (used in) provided by operating activities	(6.9		)	29.8			125.6			—			148.5
Cash Flows from Investing Activities:
Capital expenditures	—			(4.1		)	(71.5		)	—			(75.6		)
Return of Brazilian investment	—			—			20.5			—			20.5
Net cash used in investing activities	—			(4.1		)	(51.0		)	—			(55.1		)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt	—			—			693.7			—			693.7
Repayment of long-term debt	—			—			(644.9		)	—			(644.9		)
Debt issuance costs	(1.6		)	—			(15.8		)	—			(17.4		)
Proceeds from revolving facility	—			—			350.0			—			350.0
Repayment of revolving facility	—			—			(392.0		)	—			(392.0		)
Repayment of financing obligation	—			—			(2.5		)	—			(2.5		)
Cash distributions to noncontrolling interests	—			—			(47.0		)	—			(47.0		)
Acquisition of additional interest in the Partnership	—			(48.7		)	—			—			(48.7		)
Other financing activities	1.1			—			—			—			1.1
Net increase (decrease) in advances from affiliates	7.4			66.9			(74.3		)	—			—
Net cash provided by (used in) financing activities	6.9			18.2			(132.8		)	—			(107.7		)
Net increase (decrease) in cash, cash equivalents and restricted cash	—			43.9			(58.2		)	—			(14.3		)
Cash, cash equivalents and restricted cash at beginning of year	—			59.7			74.8			—			134.5
Cash, cash equivalents and restricted cash at end of year	$	—		$	103.6		$	16.6		$	—		$	120.2

108

SunCoke Energy, Inc.

Condensed Consolidating Statement of Cash Flows

December 31, 2016

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Cash Flows from Operating Activities:
Net income	$	14.4		$	31.1		$	85.0		$	(71.0	)	$	59.5
Adjustments to reconcile net income to net cash (used in) provided by operating activities:
Depreciation and amortization expense	—			9.2			105.0			—			114.2
Deferred income tax (benefit) expense	(16.6		)	8.7			11.0			—			3.1
Gain on curtailment and payments in excess of expense for postretirement plan benefits	—			(1.5		)	(1.1		)	—			(2.6		)
Share-based compensation expense	6.5			—			—			—			6.5
Equity in loss of subsidiaries	(19.7		)	(51.3		)	—			71.0			—
Gain on extinguishment of debt	—			—			(25.0		)	—			(25.0		)
Loss on divestiture of business and impairments	—			—			14.7			—			14.7
Changes in working capital pertaining to operating activities (net of acquisitions):
Receivables	—			(4.3		)	8.0			—			3.7
Inventories	—			(3.7		)	33.1			—			29.4
Accounts payable	—			4.6			(5.4		)	—			(0.8		)
Accrued liabilities	1.5			4.8			0.5			—			6.8
Deferred revenue	—			—			0.4			—			0.4
Interest payable	0.1			—			(2.8		)	—			(2.7		)
Income taxes	(6.9		)	28.2			(14.3		)	—			7.0
Other	2.5			8.9			(6.5		)	—			4.9
Net cash (used in) provided by operating activities	(18.2		)	34.7			202.6			—			219.1
Cash Flows from Investing Activities:
Capital expenditures	—			(5.7		)	(58.0		)	—			(63.7		)
Return of Brazilian investment	—			—			20.5			—			20.5
Divestiture of coal business	—			—			(12.8		)	—			(12.8		)
Other investing activities	—			—			2.1			—			2.1
Net cash used in investing activities	—			(5.7		)	(48.2		)	—			(53.9		)
Cash Flows from Financing Activities:
Repayment of long-term debt	—			—			(66.1		)	—			(66.1		)
Debt issuance costs	—			—			(0.2		)	—			(0.2		)
Proceeds from revolving facility	—			—			28.0			—			28.0
Repayment of revolving facility	(60.4		)	—			(38.0		)	—			(98.4		)
Proceeds from financing obligation	—			—			16.2			—			16.2
Repayment of financing obligation	—			—			(1.0		)	—			(1.0		)
Cash distributions to noncontrolling interests	—			—			(49.4		)	—			(49.4		)
Other financing activities	(0.3		)	(1.1		)	—			—			(1.4		)
Net increase (decrease) in advances from affiliates	78.9			(38.8		)	(40.1		)	—			—
Net cash provided by (used in) financing activities	18.2			(39.9		)	(150.6		)	—			(172.3		)
Net (decrease) increase in cash, cash equivalents and restricted cash	—			(10.9		)	3.8			—			(7.1		)
Cash, cash equivalents and restricted cash at beginning of year	—			70.6			71.0			—			141.6
Cash, cash equivalents and restricted cash at end of year	$	—		$	59.7		$	74.8		$	—		$	134.5

109

Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

None.

Item 9A. Controls and Procedures

Management’s Evaluation of Disclosure Controls and Procedures

Our management, with the participation of our principal executive officer and principal financial officer, is responsible for evaluating the effectiveness of our disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)). Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by us in reports that we file or submit under the Exchange Act is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate to allow timely decisions regarding required disclosure and is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC. Based upon that evaluation, our principal executive officer and principal financial officer concluded that, as of the end of the period covered by this report, our disclosure controls and procedures were effective at the reasonable assurance level.

Management’s Report on Internal Control over Financial Reporting

Our management, with the participation of our principal executive officer and principal financial officer, is responsible for establishing and maintaining adequate internal control over our financial reporting, as such term is defined under Exchange Act Rule 13a-15(f). Our internal control system was designed to provide reasonable assurance to management regarding the preparation and fair presentation of published financial statements.

In evaluating the effectiveness of our internal control over financial reporting as of December 31, 2018, management used the framework set forth by the Committee of Sponsoring Organizations of the Treadway Commission in Internal Control -Integrated Framework (2013). Based on such evaluation, management concluded that our internal control over financial reporting was effective as of December 31, 2018.

Our management, including our principal executive officer and principal financial officer, does not expect that our disclosure controls and procedures or our internal controls over financial reporting will prevent all error and all fraud. A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues, misstatements, errors, and instances of fraud, if any, within our company have been or will be prevented or detected. These inherent limitations include the realities that judgments in decision-making can be faulty and that breakdowns can occur because of simple error or mistake. Controls also can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the controls. The design of any system of controls is based in part on certain assumptions about the likelihood of future events, and there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions. Projections of any evaluation of controls effectiveness to future periods are subject to risks that internal controls may become inadequate as a result of changes in conditions, or through the deterioration of the degree of compliance with policies or procedures.

KPMG LLP, our independent registered public accounting firm, issued an attestation report on our internal control over financial reporting, which is contained in Item 8, “Financial Statements and Supplementary Data.”

Changes in Internal Control over Financial Reporting

During the first quarter of 2018, we implemented a new enterprise resource planning ("ERP") system. Accordingly, we modified the design and documentation of certain internal control processes and procedures relating to the new ERP system at that time. Other than the ERP and related systems implementation, there have been no changes in the Company’s internal control over financial reporting that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Item 9B. Other Information

None.

110

PART III

Item 10. Directors, Executive Officers and Corporate Governance

The information called for by this Item 10 required by Item 401 of Regulation S-K relating to Directors and Nominees for election to the Board of Directors is incorporated herein by reference to the section entitled “Proposal 1- Election of Directors” in our definitive Proxy Statement for our 2018 Annual Meeting of Stockholders to be held on May 9, 2019, (the “Proxy Statement”). Information called for by this Item 10 required by Item 401 of Regulation S-K concerning the Company’s executive officers appears in Part I of this Annual Report on Form 10-K.

The information called for by this Item 10 required by Item 405 of Regulation S-K is incorporated herein by reference to the section entitled “Section 16(a) Beneficial Ownership Reporting Compliance” under the heading “Other Information,” in the Proxy Statement.

The information called for by this Item 10 required by Item 406 of Regulation S-K is incorporated herein by reference to the section entitled “Code of Business Conduct and Ethics” under the heading “Corporate Governance” in the Proxy Statement.

The information called for by this Item 10 required by Item 407(c)(3) of Regulation S-K is incorporated herein by reference to the section entitled “Governance Committee Process for Director Nominations” under the heading “Corporate Governance” in the Proxy Statement.

The information called for by this Item 10 required by Items 407(d)(4) and 407(d)(5) of Regulation S-K is incorporated herein by reference to the information under the heading entitled “The Board of Directors and its Committees” and in the section entitled “Audit Committee Report” under the heading entitled “Audit Committee Matters,” in the Proxy Statement.

Item 11. Executive Compensation

The information called for by this Item 11 required by Item 402 of Regulation S-K is incorporated herein by reference to the sections of the Proxy Statement appearing under the heading “Executive Compensation,” including the sections entitled “Compensation Discussion and Analysis,” “Summary Compensation Table,” “Grants of Plan-Based Awards Table,” “Outstanding Equity Awards at Fiscal Year-End Table,” “Option Exercises and Stock Vested Table,” “Pension Benefits,” “Nonqualified Deferred Compensation” and “Potential Payments Upon Termination or Change in Control,” and the sections of the Proxy Statement appearing under the heading “Directors Compensation.”

The information called for by this Item 11 required by Items 407(e)(4) and 407(e)(5) of Regulation S-K is incorporated herein by reference to the sections of the Proxy Statement appearing under the heading “Executive Compensation,” including the sections entitled “Compensation Committee Report” and “Compensation Committee Interlocks and Insider Participation.”

Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

The information called for by this Item 12 required by Item 201(d) of Regulation S-K is incorporated herein by reference to the section of the Proxy Statement entitled “Equity Compensation Plan Information,” appearing under the heading “Other Information.”

The information called for by this Item 12 required by Item 403 of Regulation S-K is incorporated herein by reference to the sections of the Proxy Statement appearing under the heading “Beneficial Stock Ownership of Directors, Executive Officers and Persons Owning More Than Five Percent of Common Stock.”

Item 13. Certain Relationships and Related Transactions, and Director Independence

Omnibus Agreement

The omnibus agreement with SunCoke and the Partnership's general partner addresses certain aspects of our relationship, including:

Business Opportunities. The Partnership has a preferential right to invest in, acquire and construct cokemaking facilities in the U.S. and Canada. SunCoke has a preferential right to all other business opportunities. If the Partnership decides not to pursue an opportunity to construct a new cokemaking facility and SunCoke or any of its controlled affiliates undertake such construction, then upon completion of such construction, the Partnership will have the option to acquire such facility at a price sufficient to give SunCoke an internal rate of return on its invested capital equal to the sum of SunCoke’s weighted average cost of capital (as determined in good faith by SunCoke) and 6.0 percent. If the Partnership decides not to

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pursue an opportunity to invest in or acquire a cokemaking facility, SunCoke or any of its controlled affiliates may undertake such an investment or acquisition and if such acquisition is completed by SunCoke, the cokemaking facility so acquired will be subject to the right of first offer described below. If a business opportunity includes cokemaking facilities but such facilities represent a minority of the value of such business opportunity as determined by SunCoke in good faith, SunCoke will have a preferential right as to such business opportunity. These agreements as to business opportunities shall apply only so long as SunCoke controls the Partnership, and shall not apply with respect to any business opportunity SunCoke or any of its controlled affiliates was actively pursuing at the time of the closing of the Partnership's initial public offering on January 24, 2013 ("IPO").

Right of First Offer. If SunCoke or any of its controlled affiliates decides to sell, convey or otherwise transfer to a third-party a cokemaking facility located in the U.S. or Canada or an interest therein, the Partnership shall have a right of first offer as to such facility. SunCoke shall have the same right of first offer if the Partnership decides to sell, convey or otherwise transfer to a third-party any cokemaking facility or an interest therein. In the event a party decides to sell, convey or otherwise transfer a cokemaking facility, it will offer the other party, referred to as the ROFO Party, such facility with a proposed price for such assets. If the ROFO Party does not exercise its right, the seller shall have the right to complete the proposed transaction, on terms not materially more favorable to the buyer than the last written offer proposed during negotiations with the ROFO Party, with a third-party within 270 days. If the seller fails to complete such a transaction within 270 days, then the right of first offer is reinstated. This right of first offer shall apply only so long as SunCoke controls the Partnership.

Indemnity.SunCoke will indemnify the Partnership with respect to remediation arising from any environmental matter discovered and identified as requiring remediation prior to the contribution by SunCoke to the Partnership of an interest in the Haverhill, Middletown and Granite City (Gateway) cokemaking facilities, except for any liability or increase in liability resulting from changes in environmental regulations; provided, however, that, in each case, SunCoke will be deemed to have contributed in satisfaction of this obligation, as of the effective date of the contribution of an interest in these cokemaking facilities, the amount identified in the applicable contribution agreement as being reserved to pre-fund existing environmental remediation projects.

Post-closing. The Partnership will indemnify SunCoke for events relating to the Partnership's operations except to the extent that it is entitled to indemnification by SunCoke.

Tax Matters. SunCoke will fully indemnify the Partnership with respect to any tax liability arising prior to or in connection with the closing of its IPO.

Real Property. SunCoke will either cure or fully indemnify the Partnership for losses resulting from any material title defects at the properties owned by the entities in which the Partnership has acquired an interest from SunCoke, to the extent that such defects interfere with, or reasonably could be expected to interfere with, the operations of the related cokemaking facilities.

License. SunCoke has granted the Partnership a royalty-free license to use the name “SunCoke” and related marks. Additionally, SunCoke will grant the Partnership a non-exclusive right to use all of SunCoke’s current and future cokemaking and related technology. The Partnership has not paid and will not pay a separate license fee for the rights it receives under the license.

Expenses and Reimbursement. SunCoke will continue to provide the Partnership with certain general and administrative services, and the Partnership will reimburse SunCoke for all direct costs and expenses incurred on the Partnership's behalf and the portion of SunCoke’s corporate and other costs and expenses attributable to the Partnership's operations. Additionally, the Partnership has agreed to pay all fees (i) due under its revolving credit facility and/or existing senior notes; and (iii) in connection with any future financing arrangement entered into for the purpose of amending, modifying, or replacing its revolving credit facility or its senior notes.

The omnibus agreement can be amended by written agreement of all parties to the agreement. However, the Partnership may not agree to any amendment or modification that would, in the reasonable discretion of its general partner, be adverse in any material respect to the holders of its common units without prior approval of the conflicts committee. So long as SunCoke controls the Partnership's general partner, the omnibus agreement will remain in full force and effect unless mutually terminated by the parties. If SunCoke ceases to control the Partnership's general partner, the omnibus agreement will terminate, provided (i) the indemnification obligations described above and (ii) the Partnership's non-exclusive right to use all of SunCoke’s existing cokemaking and related technology will remain in full force and effect in accordance with their terms.

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Additional information called for by this Item 13 required by Item 404 of Regulation S-K is incorporated herein by reference to the sections of the Proxy Statement entitled “Transactions with Related Persons” under the heading “Governance Matters.”

The information called for by this Item 14 required by Item 407(a) of Regulation S-K is incorporated herein by reference to the section of the Proxy Statement entitled “Corporate Governance,” under the heading “Director Independence.”

Item 14. Principal Accounting Fees and Services

The information called for by this Item 14 required by Item 9(e) of Schedule 14A is incorporated herein by reference to the sections of the Proxy Statement appearing under the heading “Audit Committee Matters.”    

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PART IV

Item 15. Exhibits, Financial Statement Schedules

(a)The following documents are filed as a part of this report:
	1.	Consolidated Financial Statements: The consolidated financial statements are set forth under Item 8 of this report.
	2.	Financial Statements Schedules: Financial statement schedules are omitted because required information is shown elsewhere in this report, is not necessary or is not applicable.
	3.	Exhibits:
2.1		Contribution Agreement, dated January 12, 2015, by and among SunCoal & SunCoke LLC, SunCoke Energy Partners, L.P., SunCoke Energy, Inc. and agreed to for purposes of Section 2.9 thereof by Gateway Energy & Coke Company, LLC (incorporated by reference herein to Exhibit 2.1 to the Company's Current Report on Form 8-K, filed on January 13, 2015, File No. 001-35243)
2.2		Contribution Agreement, dated as of July 20, 2015, by and between Raven Energy Holdings, LLC and SunCoke Energy Partners, L.P., incorporated by reference to Exhibit 2.1 to the Company's Current Report on Form 8-K (File No. 001-35243) filed on August 18, 2015
2.3		Agreement and Plan of Merger dated as of February 4, 2019 by and among SunCoke Energy, Inc., SC Energy Acquisition LLC, SunCoke Energy Partners, L.P., and SunCoke Energy Partners GP LLC. (incorporated by reference herein to Exhibit 2.1 to the Company's Current Report on Form 8-K, filed on February 5, 2019 File No. 001-35243
3.1		Amended and Restated Certificate of Incorporation of the Company (incorporated by reference herein to Exhibit 3.1 to the Company’s Amendment No. 4 to Registration Statement on Form S-1 filed on July 6, 2011, File No. 333-173022)
3.2		Amended and Restated Bylaws of SunCoke Energy, Inc., effective as of February 1, 2016 (incorporated by reference herein to Exhibit 3.1 to the Company’s Current Report on Form 8-K, filed on February 2, 2016, File No. 001-35243)
4.1		Form of Common Stock Certificate of the Registrant (incorporated by reference herein to Exhibit 4.1 to the Company's Amendment No. 2 to Registration Statement on Form S-1, filed on June 3, 2011, File No. 333-173022)
10.1		Amended and Restated Credit Agreement, dated as of May 24, 2017, by and among SunCoke Energy, Inc., Bank of America, as Administrative Agent and the several lenders party thereto, (incorporated by reference herein to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on May 25, 2017 File No. 001-35243)
10.2		Omnibus Agreement, dated January 24, 2013, by and among SunCoke Energy Partners, L.P., SunCoke Energy Partners GP LLC and SunCoke Energy, Inc. (incorporated by reference herein to Exhibit 10.1 to the Company’s Current Report on Form 8-K, filed on January 24, 2013, File No. 001-35243)
10.2.1		Amendment No. 1 to Omnibus Agreement, dated as of March 17, 2014, by and among SunCoke Energy Partners, L.P., SunCoke Energy Partners GP LLC and SunCoke Energy, Inc. (incorporated by reference herein to Exhibit 10.3 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2014 filed on October 28, 2014, File No. 001-35243)
10.2.2		Amendment No. 2 to Omnibus Agreement, dated as of January 13, 2015, by and among SunCoke Energy Partners, L.P., SunCoke Energy Partners GP LLC and SunCoke Energy, Inc. (incorporated by reference to Exhibit 10.5.2 to the Company's Annual Report on Form 10-K filed on February 24, 2015, File No. 001-35243)
10.3**		SunCoke Energy, Inc. Senior Executive Incentive Plan, amended and restated effective as of December 9, 2015 (incorporated by reference herein to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on January 8, 2016, File No. 001-35243)
10.4**		SunCoke Energy, Inc. Annual Incentive Plan, amended and restated as of December 9, 2015 (incorporated by reference to Exhibit 10.2 to the Company's Current Report on Form 8-K filed on January 8, 2016, File No. 001-35243)

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10.5**	SunCoke Energy, Inc. Long-Term Performance Enhancement Plan, amended and restated effective as of February 22, 2013 (incorporated by reference herein to Exhibit A to the Company’s Notice of Annual Meeting of Stockholders and Definitive Proxy Statement on Schedule 14A, filed on March 28, 2013, File No. 001-35243)
10.5.1**	Form of Stock Option Agreement under the SunCoke Energy, Inc. Long-Term Performance Enhancement Plan by and between SunCoke Energy, Inc. and employees of SunCoke Energy, Inc. or one of its Affiliates (incorporated by reference herein to Exhibit 10.2 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2016 filed on April 27, 2016, File No. 001-35243)
10.5.2**	Amendment to Stock Option Agreements under the SunCoke Energy, Inc. Long-Term Performance Enhancement Plan, entered into as of July 18, 2013, applicable to all Stock Option Awards outstanding as of July 18, 2012 (incorporated by reference herein to Exhibit 10.24 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2012, filed on February 22, 2013, File No. 001-35243)
10.5.3**	Form of Performance Stock Option Agreement under the SunCoke Energy, Inc. Long-Term Performance Enhancement Plan by and between SunCoke Energy, Inc. and employees of SunCoke Energy, Inc. or one of its Affiliates (incorporated by reference herein to Exhibit 10.5.3 to the Company's Annual Report on Form 10-K, filed on February 16, 2017, File No. 001-35243))
10.5.4**	Form of Restricted Share Unit Agreement under the SunCoke Energy, Inc. Long-Term Performance Enhancement Plan by and between SunCoke Energy, Inc. and employees of SunCoke Energy, Inc. or one of its Affiliates (incorporated by reference herein to Exhibit 10.4 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2016 filed on April 27, 2016, File No. 001-35243)
10.5.5	Form of Performance Share Unit Agreement under the SunCoke Energy, Inc. Long-Term Performance Enhancement Plan by and between SunCoke Energy, Inc. and employees of SunCoke Energy, Inc. or one of its Affiliates (incorporated by reference herein to Exhibit 10.5.5 to the Company's Annual Report on Form 10-K for the years ended December 31, 2017, filed on February 15, 2018, File No. 001-35243)
10.6**	SunCoke Energy, Inc. Long-Term Cash Incentive Plan (effective as of January 1, 2016) (incorporated by reference herein to Exhibit 10.1 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2016 filed on April 27, 2016, File No. 001-35243)
10.6.1	Form of Award Agreement under the SunCoke Energy, Inc. Long-Term Cash Incentive Plan by and between SunCoke Energy, Inc. and employees of SunCoke Energy, Inc. or one of its Affiliates (incorporated by reference herein to Exhibit 10.6.1 to the Company's Annual Report on Form 10-K for the year ended December 31, 2017, filed on February 15, 2018, File No. 001-35243)
10.7**	SunCoke Energy, Inc. Savings Restoration Plan (incorporated by reference herein to Exhibit 10.1 to the Company’s Form 8-K filed on December 9, 2011, File No. 001-35243)
10.7.1**	Amendment Number One to the SunCoke Energy, Inc. Savings Restoration Plan, effective as of January 1, 2012 (incorporated by reference herein to Exhibit 10.3 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2012 filed on May 2, 2012, File No. 001-35243)
10.7.2**	Second Amendment to the SunCoke Energy, Inc. Savings Restoration Plan, effective as of June 1, 2015 (incorporated by reference herein to Exhibit 10.7 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2016 filed on April 27, 2016, File No. 001-35243)
10.7.3**	Third Amendment to the SunCoke Energy, Inc. Savings Restoration Plan, effective as of January 1, 2016 (incorporated by reference herein to Exhibit 10.8 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2016 filed on April 27, 2016, File No. 001-35243)
10.8	SunCoke Energy, Inc. Special Executive Severance Plan, amended and restated effective as of November 7, 2017 (incorporated by reference herein to Exhibit 10.8 to the Company's Annual Report on Form 10-K for the years ended December 31, 2017, filed on February 15, 2018, File No. 001-35243)
10.9	SunCoke Energy, Inc. Executive Involuntary Severance Plan, amended and restated effective as of November 7, 2017 (incorporated by reference herein to Exhibit 10.9 to the Company's Annual Report on Form 10-K for the year ended December 31, 2017, filed on February 15, 2018, File No. 001-35243)

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10.10**	SunCoke Energy, Inc. Retainer Stock Plan for Outside Directors, effective as of June 1, 2011 (incorporated by reference herein to Exhibit 10.36 to the Company’s Amendment No. 4 to Registration Statement on Form S-1 filed on July 6, 2011, File No. 333-173022)
10.11**	SunCoke Energy, Inc. Directors’ Deferred Compensation Plan, effective as of June 1, 2011 (incorporated by reference herein to Exhibit 10.35 to the Company’s Amendment No. 4 to Registration Statement on Form S-1 filed on July 6, 2011, File No. 333-173022)
10.12**	Form of Indemnification Agreement, individually entered into between SunCoke Energy, Inc. and each director of the Company (incorporated by reference herein to Exhibit 10.16 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2011 filed on November 2, 2011, File No. 001-35243)
10.13†	Amended and Restated Coke Supply Agreement, dated as of October 28, 2003, by and between Jewell Coke Company, L.P., ArcelorMittal Cleveland Inc. (f/k/a ISG Cleveland Inc.) and ArcelorMittal Indiana Harbor (f/k/a ISG Indiana Harbor Inc.) (incorporated by reference herein to Exhibit 10.18 to the Company’s Amendment No. 4 to Registration Statement on Form S-1 filed on July 6, 2011, File No. 333-173022)
10.13.1†	Amendment No. 1 to Amended and Restated Coke Supply Agreement, dated as of December 5, 2003, by and between Jewell Coke Company, L.P., ArcelorMittal Cleveland Inc. (f/k/a ISG Cleveland Inc.) and ArcelorMittal Indiana Harbor (f/k/a ISG Indiana Harbor Inc.) (incorporated by reference herein to Exhibit 10.19 to the Company’s Amendment No. 2 to Registration Statement on Form S-1 filed on June 3, 2011, File No. 333-173022)
10.13.2†	Letter Agreement, dated as of May 7, 2008, between ArcelorMittal USA Inc., Haverhill North Coke Company, Jewell Coke Company, L.P. and ISG Sparrows Point LLC, serving as (1) Amendment No. 2 to the Amended and Restated Coke Supply Agreement, by and between Jewell Coke Company, L.P., ArcelorMittal Cleveland Inc. (f/k/a ISG Cleveland Inc.) and ArcelorMittal Indiana Harbor (f/k/a ISG Indiana Harbor Inc.) and (2) Amendment No. 2 to the Coke Purchase Agreement, by and between Haverhill North Coke Company, ArcelorMittal Cleveland Inc. (f/k/a ISG Cleveland Inc.) and ArcelorMittal Indiana Harbor (f/k/a ISG Indiana Harbor Inc.) (incorporated by reference herein to Exhibit 10.20 to the Company’s Amendment No. 3 to Registration Statement on Form S-1 filed on June 3, 2011, File No. 333-173022)
10.13.3†	Amendment No. 3 to Amended and Restated Coke Supply Agreement, dated as of January 26, 2011, by and between Jewell Coke Company, L.P., ArcelorMittal Cleveland Inc. (f/k/a ISG Cleveland Inc.) and ArcelorMittal Indiana Harbor (f/k/a ISG Indiana Harbor Inc.) (incorporated by reference herein to Exhibit 10.21 to the Company’s Amendment No. 2 to Registration Statement on Form S-1 filed on June 3, 2011, File No. 333-173022)
10.14†	Coke Purchase Agreement, dated as of October 28, 2003, by and between Haverhill North Coke Company, ArcelorMittal Cleveland Inc. (f/k/a ISG Cleveland Inc.) and ArcelorMittal Indiana Harbor (f/k/a ISG Indiana Harbor Inc.) (incorporated by reference herein to Exhibit 10.22 to the Company’s Amendment No. 4 to Registration Statement on Form S-1 filed on July 6, 2011, File No. 333-173022)
10.14.1†	Amendment No. 1 to Coke Purchase Agreement, dated as of December 5, 2003, by and between Haverhill North Coke Company, ArcelorMittal Cleveland Inc. (f/k/a ISG Cleveland Inc.) and ArcelorMittal Indiana Harbor (f/k/a ISG Indiana Harbor Inc.) (incorporated by reference herein to Exhibit 10.23 to the Company’s Amendment No. 2 to Registration Statement on Form S-1 filed on June 3, 2011, File No. 333-17302)
10.14.2†	Amendment No. 3 to Coke Purchase Agreement, dated as of May 8, 2008, by and between Haverhill North Coke Company, ArcelorMittal Cleveland Inc. (f/k/a ISG Cleveland Inc.) and ArcelorMittal Indiana Harbor (f/k/a ISG Indiana Harbor Inc.) (incorporated by reference herein to Exhibit 10.25 to the Company’s Amendment No. 2 to Registration Statement on Form S-1 filed on June 3, 2011, File No. 333-17302)
10.14.3†	Amendment No. 4 to Coke Purchase Agreement, dated as of January 26, 2011, by and between Haverhill North Coke Company, ArcelorMittal Cleveland Inc. (f/k/a ISG Cleveland Inc.) and ArcelorMittal Indiana Harbor (f/k/a ISG Indiana Harbor Inc.) (incorporated by reference herein to Exhibit 10.26 to the Company’s Amendment No. 2 to Registration Statement on Form S-1 filed on June 3, 2011, File No. 333-17302)
10.15†	Coke Purchase Agreement, dated as of August 31, 2009, by and between Haverhill North Coke Company and AK Steel Corporation (incorporated by reference herein to Exhibit 10.27 to the Company’s Amendment No. 5 to Registration Statement on Form S-1 filed on July 18, 2011, File No. 333-17302)

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10.16†	Amended and Restated Coke Purchase Agreement, dated as of February 19, 1998, by and between Indiana Harbor Coke Company, L.P. and ArcelorMittal USA Inc. (f/k/a Inland Steel Company) (incorporated by reference herein to Exhibit 10.1 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2013 filed on October 30, 2013, File No. 001-35243)
10.16.1†	Amendment No. 1 to Amended and Restated Coke Purchase Agreement, dated as of November 22, 2000, by and between Indiana Harbor Coke Company, L.P., a subsidiary of the Company, and ArcelorMittal USA Inc. (f/k/a Inland Steel Company) (incorporated by reference herein to Exhibit 10.29 to the Company’s Amendment No. 2 to Registration Statement on Form S-1 filed on June 3, 2011, File No. 333-17302)
10.16.2†	Amendment No. 2 to Amended and Restated Coke Purchase Agreement, dated as of March 31, 2001, by and between Indiana Harbor Coke Company, L.P. and ArcelorMittal USA Inc. (f/k/a Inland Steel Company) (incorporated by reference herein to Exhibit 10.2 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2013 filed on October 30, 2013, File No. 001-35243)
10.16.3†	Supplement to Amended and Restated Coke Purchase Agreement, dated as of February 3, 2011, by and between Indiana Harbor Coke Company, L.P. and ArcelorMittal USA Inc. (f/k/a Inland Steel Company) (incorporated by reference herein to Exhibit 10.3 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2013 filed on October 30, 2013, File No. 001-35243)
10.16.4†	Extension Agreement, dated as of September 5, 2013, by and between Indiana Harbor Coke Company, L.P. and ArcelorMittal USA Inc. (incorporated by reference herein to Exhibit 10.4 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2013 filed on October 30, 2013, File No. 001-35243)
10.16.5†	Supplement to the ArcelorMittal USA LLC and Indiana Harbor Coke Company, L.P. Coke Purchase Agreement Term Sheet and the ArcelorMittal Cleveland LLC, ArcelorMital Indiana Harbor LLC and Jewell Coke Company, L.P. Coke Supply Agreement , dated as of September 10, 2014 (incorporated by reference herein to Exhibit 10.2 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2014 filed on October 28, 2014, File No. 001-35243)
10.17†	Coke Sale and Feed Water Processing Agreement, dated as of February 28, 2008, by and between Gateway Energy & Coke Company, LLC and U.S. Steel Corporation (incorporated by reference herein to Exhibit 10.32 to the Company’s Amendment No. 7 to Registration Statement on Form S-1 filed on July 20, 2011, File No. 333-17302)
10.17.1†	Amendment No. 1 to Coke Sale and Feed Water Processing Agreement, dated as of November 1, 2010, by and between Gateway Energy & Coke Company, LLC and U.S. Steel Corporation (incorporated by reference herein to Exhibit 10.33 to the Company’s Amendment No. 2 to Registration Statement on Form S-1 filed on June 3, 2011, File No. 333-17302)
10.17.2	Amendment No. 2 to Coke Sale and Feed Water Processing Agreement, dated as of July 6, 2011, by and between Gateway Energy & Coke Company, LLC and U.S. Steel Corporation (incorporated by reference to Exhibit 10.23.2 to the Company's Annual Report on Form 10-K filed on February 24, 2015, File No. 001-35243)
10.17.3†	Amendment No. 3 to Coke Sale and Feed Water Processing Agreement, dated as of January 12, 2015, by and among Gateway Energy & Coke Company, LLC, Gateway Cogeneration Company LLC and U.S. Steel Corporation (incorporated by reference to Exhibit 10.23.3 to the Company's Annual Report on Form 10-K filed on February 24, 2015, File No. 001-35243)
10.18†	Amended and Restated Coke Purchase Agreement, dated as of September 1, 2009, by and between Middletown Coke Company, LLC, a subsidiary of the Company and AK Steel Corporation (incorporated by reference herein to Exhibit 10.34 to the Company’s Amendment No. 5 to Registration Statement on Form S-1 filed on July 18, 2011, File No. 333-17302)
10.19	Support Agreement, dated as of February 4, 2019, by and between SunCoke Energy Partners, L.P., and Sun Coal & Coke LLC (incorporated by reference Ex. 10.1) to the Company's Current Report on Form 8-K, filed on February 5, 2019, File No. 001-35243
21.1*	Subsidiaries of the Registrant (filed herewith)
23.1*	Consent of KPMG LLP (filed herewith)
24.1*	Powers of Attorney (filed herewith)

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31.1*	Chief Executive Officer Certification Pursuant to Exchange Act Rule 13a-14(a) or Rule 15d-14(a), as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith)
31.2*	Chief Financial Officer Certification Pursuant to Exchange Act Rule 13a-14(a) or Rule 15d-14(a), as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith)
32.1*	Chief Executive Officer Certification Pursuant to Exchange Act Rule 13a-14(b) or Rule 15d-14(b) and Section 1350 of Chapter 63 of Title 18 of the U.S. Code, as Adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith)
32.2*	Chief Financial Officer Certification Pursuant to Exchange Act Rule 13a-14(b) or Rule 15d-14(b) and Section 1350 of Chapter 63 of Title 18 of the U.S. Code, as Adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith)
95.1*	Mine Safety Disclosure (filed herewith)
101.INS*	XBRL Instance Document
101.SCH*	XBRL Taxonomy Extension Schema Document
101.CAL*	XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF*	XBRL Taxonomy Extension Definition Linkbase Document
101.LAB*	XBRL Taxonomy Extension Label Linkbase Document
101.PRE*	XBRL Taxonomy Extension Presentation Linkbase Document
*	Provided herewith.
**	Management contract or compensatory plan or arrangement.
†	Certain portions have been omitted pursuant to a confidential treatment request. Omitted information has been separately filed with the Securities and Exchange Commission.

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SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) 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, on February 15, 2019.

SUNCOKE ENERGY, INC.
By:	/s/ Fay West
	Fay West Senior Vice President and Chief Financial Officer

Pursuant to the requirements of the Securities Act of 1934, this report has been signed by the following persons on behalf of the registrant and in the capacities indicated on February 15, 2019.

Signature	Title
/s/ Michael G. Rippey*	President and Chief Executive Officer (Principal Executive Officer)
Michael G. Rippey
/s/ Fay West	Senior Vice President and Chief Financial Officer (Principal Financial Officer)
Fay West
/s/ Allison S. Lausas*	Vice President, Finance and Controller (Principal Accounting Officer)
Allison S. Lausas
/s/ Alvin Bledsoe*	Director
Alvin Bledsoe
/s/ Susan Landahl*	Director
Susan Landahl
/s/ Peter B. Hamilton*	Director
Peter B. Hamilton
/s/ Robert A. Peiser*	Director
Robert A. Peiser
/s/ John W. Rowe*	Chairman of the Board
John W. Rowe
/s/ James E. Sweetnam*	Director
James E. Sweetnam
* Fay West, pursuant to powers of attorney duly executed by the above officers and directors of SunCoke Energy, Inc. and filed with the SEC in Washington, D.C., hereby executes this Annual Report on Form 10-K on behalf of each of the persons named above in the capacity set forth opposite his or her name.
/s/ Fay West	February 15, 2019
Fay West

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EX-21.1

Exhibit 21.1

Subsidiary Name	Ownership Percentage (if < 100%)		Jurisdiction of Organization
The Claymont Investment Company LLC			Delaware
SunCoke Technology and Development LLC			Delaware
•Sun Coke East Servicios de Coqueificação Ltda.	1.0	%	Brazil
Sun Coke International, Inc.			Delaware
•Sun Coke East Servicios de Coqueificação Ltda.	99.0	%	Brazil
•SXC Holding BV			Netherlands
§SunCoke India Private Limited	99.0	%	India
•India Sub Holding BV			Netherlands
§SunCoke India Private Limited	1.0	%	India
Sun Coal & Coke LLC			Delaware
•SunCoke Domestic Finance Corp.			Delaware
§SC Energy Acquisition LLC			Delaware
•Indiana Harbor Coke Corporation			Indiana
§Indiana Harbor Coke Company L.P.	84.2	%	Delaware
•Indiana Harbor Coke Company			Delaware
§Indiana Harbor Coke Company L.P.	1.0	%	Delaware
•Gateway Energy & Coke Company, LLC	2.0	%	Delaware
§Gateway Cogeneration Company LLC			Delaware
•Haverhill Coke Company LLC	2.0	%	Delaware
§Haverhill Cogeneration Company LLC			Delaware
§FF Farms Holdings LLC			Delaware
•Middletown Coke Company, LLC	2.0	%	Delaware
§Middletown Cogeneration Company LLC			Delaware
•SunCoke Energy South Shore, LLC			Delaware
•Elk River Minerals Corporation			Delaware
•Jewell Coke Acquisition Company			Virginia
§Jewell Coke Company, L.P.	2.0	%	Delaware
•SunCoke Energy Partners GP LLC			Delaware
§SunCoke Energy Partners, L.P.	2.0	%	Delaware

(Continued)

Sun Coal & Coke LLC			Delaware
•SunCoke Energy Partners, L.P.	60.4	%	Delaware
§SunCoke Energy Partners Finance Corp.			Delaware
§Haverhill Coke Company LLC	98	%	Delaware
§Middletown Coke Company, LLC	98	%	Delaware
§Gateway Energy & Coke Company, LLC	98	%	Delaware
§SunCoke Logistics LLC			Delaware
oSunCoke Lake Terminal LLC			Delaware
oKanawha River Terminals LLC			Delaware
*Marigold Dock, Inc.			Delaware
*Ceredo Liquid Terminal LLC			Delaware
§Raven Energy LLC			Delaware
oCMT Liquids Terminal, LLC			Delaware
Jewell Resources Corporation			Virginia
•Jewell Coke Company, L.P.	98	%	Virginia
•Jewell Smokeless Coal Corporation			Virginia
•Jewell Coal & Coke Company, Inc.			Virginia
•Dismal River Terminal, LLC			Virginia
•Oakwood Red Ash Coal Corporation			Virginia

NOTE: First-tier subsidiaries of SunCoke Energy, Inc. [NYSE: SXC] appear in bolded type.

Page 1 of 1

EX-23.1

Exhibit 23.1

Consent of Independent Registered Public Accounting Firm

The Board of Directors

SunCoke Energy, Inc.:

We consent to the incorporation by reference in the registration statements (Nos. 333-183015, 333-176403 and 333-224733) on Form S-8 of SunCoke Energy, Inc. and registration statement (No. 333-212785) on Form S-3 of SunCoke Energy, Inc. of our reports dated February 15, 2019, with respect to the consolidated balance sheets of SunCoke Energy, Inc. as of December 31, 2018 and 2017, and the related consolidated statements of income, comprehensive income, equity, and cash flow for each of the years in the three-year period ended December 31, 2018, and the related notes (collectively, the “consolidated financial statements”), and the effectiveness of internal control over financial reporting as of December 31, 2018, which reports appear in the December 31, 2018 annual report on Form 10‑K of SunCoke Energy, Inc.

/s/ KPMG LLP

Chicago, Illinois

February 15, 2019

EX-24.1

Exhibit 24.1

POWER OF ATTORNEY

The undersigned officer and director of SunCoke Energy, Inc. (the “Company”), hereby constitutes and appoints Michael G. Rippey, Fay West and Katherine T. Gates and each of them, his or her true and lawful attorneys-in-fact and agents with full power of substitution and re-substitution, for him or her and in his or her name place and stead, in any and all capacities, to sign for him or her in the capacities indicated below, the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2018 and any and all amendments to such Annual Report on Form 10-K, and to cause the same to be filed with all exhibits thereto, and all documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents, and each of them, full power and authority to do and perform each and every act and thing requisite and desirable to be done in and about the premises as fully and to all intents and purposes as the undersigned might or could do in person, hereby ratifying and confirming all acts and things that said attorneys-in-fact and agents or any of them, or their or his or her substitute or substitutes may lawfully do or cause to be done by virtue hereof.

IN WITNESS WHEREOF, the undersigned has executed this Power of Attorney as of this 15th day of February 2019.

Signature:	/s/ Michael G. Rippey
Name:	Michael G. Rippey
Title:	President and Chief Executive
	Officer
	(Principal Executive Officer)

POWER OF ATTORNEY

The undersigned officer of SunCoke Energy, Inc. (the “Company”), hereby constitutes and appoints Michael G. Rippey, Fay West and Katherine T. Gates and each of them, his or her true and lawful attorneys-in-fact and agents with full power of substitution and re-substitution, for him or her and in his or her name place and stead, in any and all capacities, to sign for him or her in the capacities indicated below, the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2018 and any and all amendments to such Annual Report on Form 10-K, and to cause the same to be filed with all exhibits thereto, and all documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents, and each of them, full power and authority to do and perform each and every act and thing requisite and desirable to be done in and about the premises as fully and to all intents and purposes as the undersigned might or could do in person, hereby ratifying and confirming all acts and things that said attorneys-in-fact and agents or any of them, or their or his or her substitute or substitutes may lawfully do or cause to be done by virtue hereof.

IN WITNESS WHEREOF, the undersigned has executed this Power of Attorney as of this 15th day of February 2019.

Signature:	/s/ Fay West
Name:	Fay West
Title:	Senior Vice President and Chief Financial Officer
	(Principal Financial Officer)

POWER OF ATTORNEY

The undersigned officer of SunCoke Energy, Inc. (the “Company”), hereby constitutes and appoints Michael G. Rippey, Fay West and Katherine T. Gates and each of them, his or her true and lawful attorneys-in-fact and agents with full power of substitution and re-substitution, for him or her and in his or her name place and stead, in any and all capacities, to sign for him or her in the capacities indicated below, the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2018 and any and all amendments to such Annual Report on Form 10-K, and to cause the same to be filed with all exhibits thereto, and all documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents, and each of them, full power and authority to do and perform each and every act and thing requisite and desirable to be done in and about the premises as fully and to all intents and purposes as the undersigned might or could do in person, hereby ratifying and confirming all acts and things that said attorneys-in-fact and agents or any of them, or their or his or her substitute or substitutes may lawfully do or cause to be done by virtue hereof.

IN WITNESS WHEREOF, the undersigned has executed this Power of Attorney as of this 15th day of February 2019.

Signature:	/s/ Allison Lausas
Name:	Allison Lausas
Title:	Vice President, Finance and
	Controller
	(Principal Accounting Officer)

POWER OF ATTORNEY

The undersigned, a director of SunCoke Energy, Inc. (the “Company”), hereby constitutes and appoints Michael G. Rippey, Fay West and Katherine T. Gates and each of them, his or her true and lawful attorneys-in-fact and agents with full power of substitution and re-substitution, for him or her and in his or her name place and stead, in any and all capacities, to sign for him or her in the capacities indicated below, the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2018 and any and all amendments to such Annual Report on Form 10-K, and to cause the same to be filed with all exhibits thereto, and all documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents, and each of them, full power and authority to do and perform each and every act and thing requisite and desirable to be done in and about the premises as fully and to all intents and purposes as the undersigned might or could do in person, hereby ratifying and confirming all acts and things that said attorneys-in-fact and agents or any of them, or their or his or her substitute or substitutes may lawfully do or cause to be done by virtue hereof.

IN WITNESS WHEREOF, the undersigned has executed this Power of Attorney as of this 15th day of February 2019.

Signature:	/s/ Alvin Bledsoe
Name:	Alvin Bledsoe
Title:	Director

POWER OF ATTORNEY

The undersigned, a director of SunCoke Energy, Inc. (the “Company”), hereby constitutes and appoints Michael G. Rippey, Fay West and Katherine T. Gates and each of them, his or her true and lawful attorneys-in-fact and agents with full power of substitution and re-substitution, for him or her and in his or her name place and stead, in any and all capacities, to sign for him or her in the capacities indicated below, the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2018 and any and all amendments to such Annual Report on Form 10-K, and to cause the same to be filed with all exhibits thereto, and all documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents, and each of them, full power and authority to do and perform each and every act and thing requisite and desirable to be done in and about the premises as fully and to all intents and purposes as the undersigned might or could do in person, hereby ratifying and confirming all acts and things that said attorneys-in-fact and agents or any of them, or their or his or her substitute or substitutes may lawfully do or cause to be done by virtue hereof.

IN WITNESS WHEREOF, the undersigned has executed this Power of Attorney as of this 15th day of February 2019.

Signature:	/s/ Susan R. Landahl
Name:	Susan R. Landahl
Title:	Director

POWER OF ATTORNEY

The undersigned, a director of SunCoke Energy, Inc. (the “Company”), hereby constitutes and appoints Michael G. Rippey, Fay West and Katherine T. Gates and each of them, his or her true and lawful attorneys-in-fact and agents with full power of substitution and re-substitution, for him or her and in his or her name place and stead, in any and all capacities, to sign for him or her in the capacities indicated below, the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2018 and any and all amendments to such Annual Report on Form 10-K, and to cause the same to be filed with all exhibits thereto, and all documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents, and each of them, full power and authority to do and perform each and every act and thing requisite and desirable to be done in and about the premises as fully and to all intents and purposes as the undersigned might or could do in person, hereby ratifying and confirming all acts and things that said attorneys-in-fact and agents or any of them, or their or his or her substitute or substitutes may lawfully do or cause to be done by virtue hereof.

IN WITNESS WHEREOF, the undersigned has executed this Power of Attorney as of this 15th day of February 2019.

Signature:	/s/ Peter B. Hamilton
Name:	Peter B. Hamilton
Title:	Director

POWER OF ATTORNEY

The undersigned, a director of SunCoke Energy, Inc. (the “Company”), hereby constitutes and appoints Michael G. Rippey, Fay West and Katherine T. Gates and each of them, his or her true and lawful attorneys-in-fact and agents with full power of substitution and re-substitution, for him or her and in his or her name place and stead, in any and all capacities, to sign for him or her in the capacities indicated below, the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2018 and any and all amendments to such Annual Report on Form 10-K, and to cause the same to be filed with all exhibits thereto, and all documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents, and each of them, full power and authority to do and perform each and every act and thing requisite and desirable to be done in and about the premises as fully and to all intents and purposes as the undersigned might or could do in person, hereby ratifying and confirming all acts and things that said attorneys-in-fact and agents or any of them, or their or his or her substitute or substitutes may lawfully do or cause to be done by virtue hereof.

IN WITNESS WHEREOF, the undersigned has executed this Power of Attorney as of this 15th day of February 2019.

Signature:	/s/ Robert A. Peiser
Name:	Robert A. Peiser
Title:	Director

POWER OF ATTORNEY

The undersigned, a director of SunCoke Energy, Inc. (the “Company”), hereby constitutes and appoints Michael G. Rippey, Fay West and Katherine T. Gates and each of them, his or her true and lawful attorneys-in-fact and agents with full power of substitution and re-substitution, for him or her and in his or her name place and stead, in any and all capacities, to sign for him or her in the capacities indicated below, the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2018 and any and all amendments to such Annual Report on Form 10-K, and to cause the same to be filed with all exhibits thereto, and all documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents, and each of them, full power and authority to do and perform each and every act and thing requisite and desirable to be done in and about the premises as fully and to all intents and purposes as the undersigned might or could do in person, hereby ratifying and confirming all acts and things that said attorneys-in-fact and agents or any of them, or their or his or her substitute or substitutes may lawfully do or cause to be done by virtue hereof.

IN WITNESS WHEREOF, the undersigned has executed this Power of Attorney as of this 15th day of February 2019.

Signature:	/s/ John W. Rowe
Name:	John W. Rowe
Title:	Director

POWER OF ATTORNEY

The undersigned, a director of SunCoke Energy, Inc. (the “Company”), hereby constitutes and appoints Michael G. Rippey, Fay West and Katherine T. Gates and each of them, his or her true and lawful attorneys-in-fact and agents with full power of substitution and re-substitution, for him or her and in his or her name place and stead, in any and all capacities, to sign for him or her in the capacities indicated below, the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2018 and any and all amendments to such Annual Report on Form 10-K, and to cause the same to be filed with all exhibits thereto, and all documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents, and each of them, full power and authority to do and perform each and every act and thing requisite and desirable to be done in and about the premises as fully and to all intents and purposes as the undersigned might or could do in person, hereby ratifying and confirming all acts and things that said attorneys-in-fact and agents or any of them, or their or his or her substitute or substitutes may lawfully do or cause to be done by virtue hereof.

IN WITNESS WHEREOF, the undersigned has executed this Power of Attorney as of this 15th day of February 2019.

Signature:	/s/ James E. Sweetnam
Name:	James E. Sweetnam
Title:	Director

EX-31.1

Exhibit 31.1

CERTIFICATION

I, Michael G. Rippey, certify that:

1.    I have reviewed this Annual Report on Form 10-K for the fiscal year ended December 31, 2018 of SunCoke Energy, Inc. (the “registrant”);

2.    Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.    Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.    The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)    Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)    Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)    Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d).    Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s fourth fiscal quarter that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.    The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)    All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)    Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/ Michael G. Rippey

Michael G. Rippey

President and Chief Executive Officer

February 15, 2019

EX-31.2

Exhibit 31.2

CERTIFICATION

I, Fay West, certify that:

1.    I have reviewed this Annual Report on Form 10-K for the fiscal year ended December 31, 2018 of SunCoke Energy, Inc. (the “registrant”);

2.    Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.    Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.    The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)    Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)    Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)    Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d).    Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s fourth fiscal quarter that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.    The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)    All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)    Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/ Fay West

Fay West

Senior Vice President and

Chief Financial Officer

February 15, 2019

EX-32.1

Exhibit 32.1

CERTIFICATION OF

CHIEF EXECUTIVE OFFICER OF SUNCOKE ENERGY, INC.

PURSUANT TO 18 U.S.C. SECTION 1350

In connection with this Annual Report on Form 10-K of SunCoke Energy, Inc. for the fiscal year ended December 31, 2018, I, Michael G. Rippey, President and Chief Executive Officer of SunCoke Energy, Inc., hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1.This Annual Report on Form 10-K for the fiscal year ended December 31, 2018 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2.The information contained in this Annual Report on Form 10-K for the fiscal year ended December 31, 2018 fairly presents, in all material respects, the financial condition and results of operations of SunCoke Energy, Inc. for the periods presented therein.

/s/ Michael G. Rippey

Michael G. Rippey

President and Chief Executive Officer

February 15, 2019

EX-32.2

Exhibit 32.2

CERTIFICATION OF

CHIEF FINANCIAL OFFICER OF SUNCOKE ENERGY, INC.

PURSUANT TO 18 U.S.C. SECTION 1350

In connection with this Annual Report on Form 10-K of SunCoke Energy, Inc. for the fiscal year ended December 31, 2018, I, Fay West, Senior Vice President and Chief Financial Officer and Chairman of SunCoke Energy, Inc., hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1.This Annual Report on Form 10-K for the fiscal year ended December 31, 2018 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2.The information contained in this Annual Report on Form 10-K for the fiscal year ended December 31, 2018 fairly presents, in all material respects, the financial condition and results of operations of SunCoke Energy, Inc. for the periods presented therein.

/s/ Fay West

Fay West

Senior Vice President and

Chief Financial Officer

February 15, 2019

EX-95.1

Exhibit 95.1

SunCoke Energy, Inc.

Mine Safety Disclosures for the Period Ended December 31, 2018

We are committed to maintaining a safe work environment and working to ensure environmental compliance across all of our operations. The health and safety of our employees and limiting the impact to communities in which we operate are critical to our long-term success. We employ practices and conduct training to help ensure that our employees work safely. Furthermore, we utilize processes for managing, monitoring and improving safety and environmental performance.

We have consistently operated within the top quartile for the U.S. Occupational Safety and Health Administration’s recordable injury rates as measured and reported by the American Coke and Coal Chemicals Institute. We also have worked to maintain low injury rates reportable to the U.S. Department of Labor’s Mine Safety and Health Administration (“MSHA”).

The following table presents the information concerning mine safety violations and other regulatory matters that we are required to report in accordance with Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act. Whenever MSHA believes that a violation of the Federal Mine Safety and Health Act of 1977 (the “Mine Act”), any health or safety standard, or any regulation has occurred, it may issue a citation which describes the alleged violation and fixes a time within which the operator must abate the violation. In these situations, MSHA typically proposes a civil penalty, or fine, that the operator is ordered to pay. In evaluating the following table regarding mine safety, investors should take into account factors such as: (1) the number of citations and orders will vary depending on the size of a coal mine, (2) the number of citations issued will vary from inspector to inspector, mine to mine and MSHA district to district and (3) citations and orders can be contested and appealed, and during that process are often reduced in severity and amount, and are sometimes dismissed.

The mine data retrieval system maintained by MSHA may show information that is different than what is provided in the table below. Any such difference may be attributed to the need to update that information on MSHA’s system or other factors. Orders and citations issued to independent contractors who work at our mine sites are not reported in the table below. All section references in the table below refer to provisions of the Mine Act.

Mine or Operating Name/MSHA Identification Number	Section 104 S&S Citations (#)(2)	Section 104(b) Orders (#)(3)	Section 104(d) Citations and Orders (#)(4)	Section 110(b)(2) Violations (#)(5)	Section 107(a) Orders (#)(6)	Total Dollar Value of MSHA Assessments Proposed ($)(7)		Total Number of Mining Related Fatalities (#)	Received Notice of Pattern of Violations Under Section 104(e) (yes/no)(8)	Received Notice of Potential to Have Pattern Under Section 104(e) (yes/no)(9)	Legal Actions Pending as of Last Day of Period (#)(10)(11)	Legal Actions Initiated During Period (#)(12)	Legal Actions Resolved During Period (#)(13)
4400649/ #2 Prep Plant	0	0	0	0	0	$	236	0	no	no	n/a	n/a	n/a
Total	0	0	0	0	0	$	236	0	0	0	0	0	0

(1) The table does not include the following: (i) facilities which have been idle or closed unless they received a citation or order issued by MSHA, (ii) permitted mining sites where we have not begun operations or (iii) mines that are operated on our behalf by contractors who hold the MSHA numbers and have the MSHA liabilities.

(2) Alleged violations of mandatory health or safety standards that could significantly and substantially contribute to the cause and effect of a coal or other mine safety or health hazard.

(3) Alleged failures to totally abate a citation within the period of time specified in the citation.

(4) Alleged unwarrantable failure (i.e., aggravated conduct constituting more than ordinary negligence) to comply with a mining safety standard or regulation.

(5) Alleged flagrant violations issued.

(6) Alleged conditions or practices which could reasonably be expected to cause death or serious physical harm before such condition or practice can be abated.

(7) Amounts shown include assessments proposed during the year ended December 31, 2018 and do not necessarily relate to the citations or orders reflected in this table. Assessments for citations or orders reflected in this table may be proposed by MSHA after December 31, 2018.

(8) Alleged pattern of violations of mandatory health or safety standards that are of such nature as could have significantly and substantially contributed to the cause and effect of coal or other mine health or safety hazards.

(9) Alleged potential to have a pattern of violations of mandatory health or safety standards that are of such nature as could have significantly and substantially contributed to the cause and effect of coal or other mine health or safety hazards.

(10) This number reflects legal proceedings which remain pending before the Federal Mine Safety and Health Review Commission (the “FMSHRC”) as of December 31, 2018. The pending legal actions may relate to the citations or orders issued by MSHA during the reporting period or to citations or orders issued in prior periods. The FMSHRC has jurisdiction to hear not only challenges to citations, orders, and penalties but also certain complaints by miners. The number of “pending legal actions” reported here reflects the number of contested citations, orders, penalties or complaints which remain pending as of December 31, 2018.

(11) The legal proceedings which remain pending before the FMSHRC as of December 31, 2018 are categorized as follows in accordance with the categories established in the Procedural Rules of the FMSHRC:

Mine or Operating Name/MSHA Identification Number	Contests of Citations and Orders (#)	Contests of Proposed Penalties (#)	Complaints for Compensation (#)	Complaints for Discharge, Discrimination or Interference Under Section 105 (#)	Applications for Temporary Relief (#)	Appeals of Judges’ Decisions or Orders (#)
4400649/ #2 Prep Plant	n/a	n/a	0	0	0	0
Total	0	0	0	0	0	0

(12) This number reflects legal proceedings initiated before the FMSHRC during the year ended December 31, 2018. The number of “initiated legal actions” reported here may not have remained pending as of December 31, 2018.

(13) This number reflects legal proceedings before the FMSHRC that were resolved during the year ended December 31, 2018.

XML

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2018	Feb. 08, 2019	Jun. 30, 2018
Document and Entity Information [Abstract]
Entity Registrant Name	SunCoke Energy, Inc.
Entity Central Index Key	0001514705
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2018
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		64,756,093
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 863,299,596

XML

Consolidated Statements of Income - USD ($) shares in Millions, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Revenues
Sales and other operating revenue	$ 368.9	$ 364.5	$ 367.0	$ 350.5	$ 359.6	$ 339.0	$ 323.2	$ 309.7	$ 1,450.9	$ 1,331.5	$ 1,223.3
Costs and operating expenses
Cost of products sold and operating expenses									1,124.5	1,020.1	905.9
Selling, general and administrative expenses									66.1	79.0	90.6
Depreciation and amortization expense									141.6	128.2	114.2
Loss on divestiture of business									0.0	0.0	14.7
Total costs and operating expenses									1,332.2	1,227.3	1,125.4
Operating income									118.7	104.2	97.9
Interest expense, net									61.4	61.9	54.8
Loss (gain) on extinguishment of debt							20.2		0.3	20.4	(25.0)
Income before income tax expense (benefit) and loss from equity method investment									57.0	21.9	68.1
Income tax expense (benefit)									4.6	(81.6)	8.6
Loss from equity method investment									5.4	0.0	0.0
Net income	5.5	17.1	11.4	13.0	173.9	18.8	(31.5)	(57.7)	47.0	103.5	59.5
Less: Net income (loss) attributable to noncontrolling interests	3.7	5.6	7.2	4.3	39.9	7.2	(7.3)	(58.7)	20.8	(18.9)	45.1
Net income attributable to SunCoke Energy, Inc.	$ 1.8	$ 11.5	$ 4.2	$ 8.7	$ 134.0	$ 11.6	$ (24.2)	$ 1.0	$ 26.2	$ 122.4	$ 14.4
Earnings attributable to SunCoke Energy, Inc. per common share:
Basic (in dollars per share)	$ 0.03	$ 0.18	$ 0.06	$ 0.13	$ 2.08	$ 0.18	$ (0.38)	$ 0.02	$ 0.40	$ 1.90	$ 0.22
Diluted (in dollars per share)	$ 0.03	$ 0.18	$ 0.06	$ 0.13	$ 2.05	$ 0.18	$ (0.38)	$ 0.02	$ 0.40	$ 1.88	$ 0.22
Weighted average number of common shares outstanding:
Basic (in shares)									64.7	64.3	64.2
Diluted (in shares)									65.5	65.2	64.4

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Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Statement of Comprehensive Income [Abstract]
Net income	$ 5.5	$ 17.1	$ 11.4	$ 13.0	$ 173.9	$ 18.8	$ (31.5)	$ (57.7)	$ 47.0	$ 103.5	$ 59.5
Other comprehensive income (loss):
Reclassifications of actuarial loss amortization and prior service benefit to earnings (net of related tax expense of zero for all years)									(0.1)	0.2	0.0
Retirement benefit plans funded status adjustment (net of related tax benefit of $0.2 million, $0.3 million and $0.1 million, respectively)									0.6	(0.8)	(0.2)
Currency translation adjustment									(1.4)	(0.5)	1.0
Recognition of accumulated currency translation loss upon sale of equity method investment									9.0	0.0	0.0
Comprehensive income									55.1	102.4	60.3
Less: Comprehensive income (loss) attributable to noncontrolling interests									20.8	(18.9)	45.1
Comprehensive income attributable to SunCoke Energy, Inc.									$ 34.3	$ 121.3	$ 15.2

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Consolidated Statements of Comprehensive Income (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Statement of Comprehensive Income [Abstract]
Net of related tax benefit, reclassifications of prior service benefit and actuarial loss amortization to earnings	$ 0.0	$ 0.0	$ 0.0
Retirement expense (benefit) plans funded status adjustment, tax	$ 0.2	$ 0.3	$ 0.1

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Consolidated Balance Sheets - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Assets
Cash and cash equivalents	$ 145.7	$ 120.2
Receivables	75.4	68.5
Inventories	110.4	111.0
Income tax receivable	0.7	4.8
Other current assets	2.8	6.7
Total current assets	335.0	311.2
Properties, plants and equipment (net of accumulated depreciation of $855.8 million and $733.2 million at December 31, 2018 and 2017, respectively)	1,471.1	1,501.3
Goodwill	76.9	76.9
Other intangible assets, net	156.8	167.9
Deferred charges and other assets	5.5	2.8
Total assets	2,045.3	2,060.1
Liabilities and Equity
Accounts payable	115.0	115.5
Accrued liabilities	45.6	53.2
Deferred revenue	3.0	1.7
Current portion of long-term debt and financing obligation	3.9	2.6
Interest payable	3.6	5.4
Total current liabilities	171.1	178.4
Long-term debt and financing obligation	834.5	861.1
Accrual for black lung benefits	44.9	44.9
Retirement benefit liabilities	25.2	28.2
Deferred income taxes	254.7	257.8
Asset retirement obligations	14.6	14.0
Other deferred credits and liabilities	17.6	16.1
Total liabilities	1,362.6	1,400.5
Equity
Preferred stock, $0.01 par value. Authorized 50,000,000 shares; no issued shares at both December 31, 2018 and 2017	0.0	0.0
Common stock, $0.01 par value. Authorized 300,000,000 shares; issued 72,233,750 and 72,006,905 shares at December 31, 2018 and 2017, respectively	0.7	0.7
Treasury stock, 7,477,657 shares at both December 31, 2018 and 2017, respectively	(140.7)	(140.7)
Additional paid-in capital	488.8	486.2
Accumulated other comprehensive loss	(13.1)	(21.2)
Retained earnings	127.4	101.2
Total SunCoke Energy, Inc. stockholders' equity	463.1	426.2
Noncontrolling interests	219.6	233.4
Total equity	682.7	659.6
Total liabilities and equity	$ 2,045.3	$ 2,060.1

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Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Statement of Financial Position [Abstract]
Accumulated depreciation	$ 855.8	$ 733.2
Preferred stock, par value (in dollars per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000
Preferred stock, shares issued (in shares)	0	0
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	300,000,000	300,000,000
Common stock, shares, issued (in shares)	72,233,750	72,006,905
Treasury stock, shares (in shares)	7,477,657	7,477,657

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Consolidated Statements of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Cash Flows from Operating Activities:
Net income	$ 47.0	$ 103.5	$ 59.5
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	141.6	128.2	114.2
Deferred income tax (benefit) expense	(3.4)	(87.2)	3.1
Payments in excess of expense for postretirement plan benefits	(2.4)	(1.8)	(2.6)
Share-based compensation expense	3.1	4.8	6.5
Loss (gain) on extinguishment of debt, net	0.3	20.4	(25.0)
Loss on divestiture of business	0.0	0.0	14.7
Loss from equity method investment	5.4	0.0	0.0
Changes in working capital pertaining to operating activities (net of the effects of divestiture):
Receivables	(6.9)	(7.8)	3.7
Inventories	0.6	(18.5)	29.4
Accounts payable	(0.7)	11.7	(0.8)
Accrued liabilities	(7.3)	2.6	6.8
Deferred revenue	1.3	(0.8)	0.4
Interest payable	(1.8)	(10.8)	(2.7)
Income taxes	4.5	(0.2)	7.0
Other	4.5	4.4	4.9
Net cash provided by operating activities	185.8	148.5	219.1
Cash Flows from Investing Activities:
Capital expenditures	(100.3)	(75.6)	(63.7)
Return of Brazilian investment	0.0	20.5	20.5
Divestiture of coal business	0.0	0.0	(12.8)
Sale of equity method investment	4.0	0.0	0.0
Other investing activities	0.5	0.0	2.1
Net cash used in investing activities	(95.8)	(55.1)	(53.9)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt	45.0	693.7	0.0
Repayment of long-term debt	(45.7)	(644.9)	(66.1)
Debt issuance costs	(0.5)	(17.4)	(0.2)
Proceeds from revolving facility	179.5	350.0	28.0
Repayment of revolving facility	(204.5)	(392.0)	(98.4)
Proceeds from financing obligation	0.0	0.0	16.2
Repayment of financing obligation	(2.6)	(2.5)	(1.0)
Cash distributions to noncontrolling interests	(31.9)	(47.0)	(49.4)
Acquisition of additional interest in the Partnership	(4.2)	(48.7)	0.0
Other financing activities	0.4	1.1	(1.4)
Net cash used in financing activities	(64.5)	(107.7)	(172.3)
Net increase (decrease) in cash, cash equivalents and restricted cash	25.5	(14.3)	(7.1)
Cash, cash equivalents and restricted cash at beginning of year	120.2	134.5	141.6
Cash, cash equivalents and restricted cash at end of year	145.7	120.2	134.5
Supplemental Disclosure of Cash Flow Information
Interest paid, net of capitalized interest of $3.2 million, $1.1 million and $5.0 million, respectively	59.6	67.9	53.4
Income taxes paid, net of refunds of $4.3 million, $1.0 million and $8.2 million, respectively	$ 3.7	$ 5.8	$ (2.3)

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Consolidated Statements of Cash Flows (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Statement of Cash Flows [Abstract]
Capitalized interest	$ 3.2	$ 1.1	$ 5.0
Tax refunds	$ 4.3	$ 1.0	$ 8.2

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Consolidated Statements of Equity - USD ($) $ in Millions	Total	Common Stock	Treasury Stock	Additional Paid-In Capital	Accumulated Other Comprehensive Loss	Retained Earnings	Total SunCoke Energy, Inc. Equity	Non-controlling Interests
Beginning balance at Dec. 31, 2015	$ 622.8	$ 0.7	$ (140.7)	$ 486.1	$ (19.8)	$ (36.4)	$ 289.9	$ 332.9
Beginning balance, shares at Dec. 31, 2015		71,489,448	7,477,657
Stockholders' Equity
Net income	59.5					14.4	14.4	45.1
Reclassifications of prior service cost and actuarial loss amortization to earnings (net of related tax expense of $3.4 million)	0.0
Retirement benefit plans funded status adjustment (net of related tax benefit of $0.2 million, $0.3 million and $0.1 million, respectively)	(0.2)				(0.2)		(0.2)
Currency translation adjustment	1.0				1.0		1.0
Recognition of accumulated currency translation loss upon sale of equity method investment	0.0
Cash distributions to noncontrolling interests	(49.2)							(49.2)
Share-based compensation expense	6.5			6.5			6.5
Share issuances, net of shares withheld for taxes and other equity activities	(0.5)			(0.5)			(0.5)
Share issuances, net of shares withheld for taxes and other equity activities, shares		217,856
Ending balance. shares at Dec. 31, 2016		71,707,304	7,477,657
Ending balance at Dec. 31, 2016	639.9	$ 0.7	$ (140.7)	492.1	(19.0)	(22.0)	311.1	328.8
Stockholders' Equity
Net income	103.5					122.4	122.4	(18.9)
Reclassifications of prior service cost and actuarial loss amortization to earnings (net of related tax expense of $3.4 million)	0.2				0.2		0.2
Retirement benefit plans funded status adjustment (net of related tax benefit of $0.2 million, $0.3 million and $0.1 million, respectively)	(0.8)				(0.8)		(0.8)
Currency translation adjustment	(0.5)				(0.5)		(0.5)
Recognition of accumulated currency translation loss upon sale of equity method investment	0.0
Cash distributions to noncontrolling interests	(47.0)							(47.0)
Share-based compensation expense	4.8			4.7			4.7	0.1
Share issuances, net of shares withheld for taxes and other equity activities	1.1			1.1			1.1
Share issuances, net of shares withheld for taxes and other equity activities, shares		299,601
Acquisition of additional interest in the Partnership:
Partnership unit repurchases and cash paid	(48.7)			(19.1)			(19.1)	(29.6)
Deferred tax adjustment	7.1			7.1			7.1
Ending balance. shares at Dec. 31, 2017		72,006,905	7,477,657
Ending balance at Dec. 31, 2017	659.6	$ 0.7	$ (140.7)	486.2	(21.2)	101.2	426.2	233.4
Acquisition of additional interest in the Partnership:
Cumulative effect from adoption of ASU 2016-09 | ASU 2016-09	0.0			0.3		(0.3)
Cumulative effect from adoption of ASU 2016-09 | ASU 2018-02	0.0			(1.1)		1.1
Net income	47.0					26.2	26.2	20.8
Reclassifications of prior service cost and actuarial loss amortization to earnings (net of related tax expense of $3.4 million)	(0.1)				(0.1)		(0.1)
Retirement benefit plans funded status adjustment (net of related tax benefit of $0.2 million, $0.3 million and $0.1 million, respectively)	0.6				0.6		0.6
Currency translation adjustment	(1.4)				(1.4)		(1.4)
Recognition of accumulated currency translation loss upon sale of equity method investment	9.0				9.0		9.0	0.0
Cash distributions to noncontrolling interests	(31.9)							(31.9)
Share-based compensation expense	3.1			3.1			3.1	0.0
Share issuances, net of shares withheld for taxes and other equity activities	0.7			0.7			0.7
Share issuances, net of shares withheld for taxes and other equity activities, shares		226,845
Partnership unit repurchases and cash paid	(4.2)			(1.5)			(1.5)	(2.7)
Deferred tax adjustment	0.3			0.3			0.3
Ending balance. shares at Dec. 31, 2018		72,233,750	7,477,657
Ending balance at Dec. 31, 2018	$ 682.7	$ 0.7	$ (140.7)	$ 488.8	$ (13.1)	$ 127.4	$ 463.1	$ 219.6

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Consolidated Statements of Equity (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Statement of Stockholders' Equity [Abstract]
Retirement expense (benefit) plans funded status adjustment, tax	$ 0.2	$ 0.3	$ 0.1
Net of related tax benefit, reclassifications of prior service benefit and actuarial loss amortization to earnings	$ 0.0	$ 0.0	$ 0.0

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General and Basis of Presentation

12 Months Ended

Dec. 31, 2018

Organization, Consolidation and Presentation of Financial Statements [Abstract]

General and Basis of Presentation

1. General and Basis of Presentation

Description of Business

SunCoke Energy, Inc. (“SunCoke Energy,” “SunCoke,” “Company,” “we,” “our” and “us”) is the largest independent producer of high-quality coke in the Americas, as measured by tons of coke produced each year, and has over 55 years of coke production experience. Coke is a principal raw material in the blast furnace steelmaking process and is produced by heating metallurgical coal in a refractory oven, which releases certain volatile components from the coal, thus transforming the coal into coke. Additionally, we own and operate a logistics business, which primarily provides handling and/or mixing services of coal and other aggregates to third-party customers as well as to our own cokemaking facilities.

We have designed, developed, built, own and operate fivecokemaking facilities in the United States (“U.S.”) with collective nameplate capacity to produce approximately 4.2 million tons of coke per year. Additionally, we have designed and operate onecokemaking facility in Brazil under licensing and operating agreements on behalf of ArcelorMittal Brasil S.A. ("ArcelorMittal Brazil”), which has approximately 1.7 million tons of annual cokemaking capacity.

Our cokemaking ovens utilize efficient, modern heat recovery technology designed to combust the coal’s volatile components liberated during the cokemaking process and use the resulting heat to create steam or electricity for sale. This differs from by-product cokemaking, which repurposes the coal’s liberated volatile components for other uses. We have constructed the only greenfield cokemaking facilities in the U.S. in approximately 30years and are the only North American coke producer that utilizes heat recovery technology in the cokemaking process. We provide steam pursuant to steam supply and purchase agreements with our customers. Electricity is sold into the regional power market or pursuant to energy sales agreements.

Our logistics business provides handling and/or mixing services to steel, coke (including some of our domestic cokemaking facilities), electric utility, coal producing and other manufacturing based customers. The logistics business has terminals in Indiana, West Virginia, Virginia, and Louisiana with collective capacity to mix and/or transload more than 40 million tons of coal and other aggregates annually and has total storage capacity of approximately 3 million tons.

On June 27, 2018, we sold our 49 percent investment in VISA SunCoke Limited ("VISA SunCoke") for cash consideration of $4.0 million. Consequently, we recognized $9.0 million of accumulated currency translation losses and incurred $0.4 million of transaction costs, resulting in a net $5.4 million loss from equity method investment during 2018 on the Consolidated Statements of Income. Our investment in VISA SunCoke was previously accounted for as an equity method investment and was fully impaired in 2015. Therefore, its financial results had not been included in our financial statements since that time.

The Company disposed of its coal mining operations in Virginia and West Virginia to Revelation Energy, LLC ("Revelation") in April 2016. Revelation assumed substantially all of our remaining coal mining assets and real estate, and was assigned substantially all of our mineral leases and a substantial portion of our mining reclamation obligations. Under the terms of the agreement, Revelation received $12.8 million from the Company to take ownership of the assets and liabilities. During 2016, the Company recognized losses associated with this divestiture of $14.7 million.

Our consolidated financial statements include SunCoke Energy Partners, L.P. (the "Partnership"), a publicly-traded partnership. At December 31, 2018, we owned the general partner of the Partnership, which consists of a 2.0 percent ownership interest and incentive distribution rights ("IDRs"), and a 60.4 percent limited partner interest in the Partnership. The remaining 37.6 percent interest in the Partnership was held by public unitholders.

On February 5, 2019, the Company and the Partnership announced that they have entered into a definitive agreement whereby SunCoke will acquire all outstanding common units of the Partnership not already owned by SunCoke in a stock-for-unit merger transaction (the “Simplification Transaction”). Pursuant to the terms of this agreement ("Merger Agreement"), the Partnership's unaffiliated common unitholders will receive 1.40 SunCoke common shares plus a fraction of a SunCoke common share, based on a ratio as further described in the Merger Agreement, for each Partnership common unit. On behalf of the Partnership and its public unitholders, the terms of the Simplification Transaction were negotiated, reviewed and approved by the conflicts committee of the Board of Directors of the Partnership's general partner, which consisted solely of independent directors. The transaction was approved by the Board of Directors of the general partner of the Partnership and the Board of Directors of SunCoke.

Following completion of the Simplification Transaction, the Partnership will become a wholly-owned subsidiary of SunCoke, the Partnership's common units will cease to be publicly traded and the Partnership's IDRs will be eliminated.  The Simplification Transaction is expected to close late in the second quarter of 2019 or early in the third quarter of 2019, subject to customary closing conditions, including the approval by holders of a majority of the outstanding SunCoke common shares and Partnership common units, as well as customary regulatory approvals. SunCoke indirectly owns the majority of the Partnership common units, which is sufficient to approve the transaction on behalf of the holders of Partnership common units.

Incorporated in Delaware in 2010 and headquartered in Lisle, Illinois, we became a publicly-traded company in 2011, and our stock is listed on the New York Stock Exchange (“NYSE”) under the symbol “SXC.”

Consolidation and Basis of Presentation

The consolidated financial statements of the Company and its subsidiaries were prepared in accordance with accounting principles generally accepted in the U.S. ("GAAP") and include the assets, liabilities, revenues and expenses of the Company and all subsidiaries where we have a controlling financial interest. Intercompany transactions and balances have been eliminated in consolidation. Net income attributable to noncontrolling interest represents the common public unitholders’ interest in SunCoke Energy Partners, L.P. as well as a 14.8 percent third-party interest in our Indiana Harbor cokemaking facility.

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Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2018

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

2. Summary of Significant Accounting Policies

Use of Estimates

The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and accompanying notes. Actual amounts could differ from these estimates.

Reclassifications

Certain amounts in the prior period consolidated financial statements have been reclassified to conform to the current year presentation. See the "Recently Adopted Accounting Pronouncements" section of this footnote for further details.

Revenue Recognition

The Company sells coke as well as steam and electricity and also provides mixing and/or handling services of coal and other aggregates. The Company also receives fees for operating the cokemaking plant in Brazil and for the licensing of its proprietary technology for use at this facility as well as reimbursement of substantially all of its operating costs. See Note 18.

Substantially all of the coke produced by the Company is sold pursuant to long-term contracts with its customers. The Company evaluates each of its contracts to determine whether the arrangement contains a lease under the applicable accounting standards. If the specific facts and circumstances indicate that it is remote that parties other than the contracted customer will take more than a minor amount of the coke that will be produced by the property, plant and equipment during the term of the coke supply agreement, and the price that the customer is paying for the coke is neither contractually fixed per unit nor equal to the current market price per unit at the time of delivery, then the long-term contract is deemed to contain a lease. The lease component of the price of coke represents the rental payment for the use of the property, plant and equipment, and all such payments are accounted for as contingent rentals as they are only earned by the Company when the coke is delivered and title passes to the customer. The total amount of revenue recognized by the Company for these contingent rentals represents less than 10 percent of consolidated sales and other operating revenues for each of the years ended December 31, 2018, 2017 and 2016. Upon adoption of Accounting Standard Codification ("ASC") 842, "Leases", in 2019, these long-term contracts to sell coke will no longer be deemed to contain operating leases.

Cash Equivalents

The Company considers all highly liquid investments with a remaining maturity of three months or less at the time of purchase to be cash equivalents. These cash equivalents consist principally of certificates of deposit.

Inventories

Inventories are valued at the lower of cost or net realizable value. Cost is determined using the first-in, first-out method, except for the Company’s materials and supplies inventory, which are determined using the average-cost method. The Company utilizes the selling prices under its long-term coke supply contracts to record lower of cost or net realizable value inventory adjustments.

Properties, Plants and Equipment

Plants and equipment are depreciated on a straight-line basis over their estimated useful lives. Coke and energy plant, machinery and equipment are generally depreciated over 25 to 30 years. Logistics plant and equipment are generally depreciated over 15 to 35 years. Depreciation and amortization is excluded from cost of products sold and operating expenses and is presented separately on the Consolidated Statements of Income. Gains and losses on the disposal or retirement of fixed assets are reflected in earnings when the assets are sold or retired. Amounts incurred that extend an asset’s useful life, increase its productivity or add production capacity are capitalized. The Company accounts for changes in useful lives, when appropriate, as a change in estimate, with prospective application only. The Company capitalized interest of $3.2 million, $1.1 million, and $5.0 million in 2018, 2017 and 2016, respectively. Direct costs, such as outside labor, materials, internal payroll and benefits costs incurred during capital projects are capitalized; indirect costs are not capitalized. Normal repairs and maintenance costs are expensed as incurred.

Impairment of Long-Lived Assets

Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. A long-lived asset, or group of assets, is considered to be impaired when the undiscounted net cash flows expected to be generated by the asset are less than its carrying amount. Such estimated future cash flows are highly subjective and are based on numerous assumptions about future operations and market conditions. The impairment recognized is the amount by which the carrying amount exceeds the fair market value of the impaired asset, or group of assets. It is also difficult to precisely estimate fair market value because quoted market prices for our long-lived assets may not be readily available. Therefore, fair market value is generally based on the present values of estimated future cash flows using discount rates commensurate with the risks associated with the assets being reviewed for impairment.

Goodwill and Other Intangibles

Goodwill, which represents the excess of the purchase price over the fair value of net assets acquired, is tested for impairment as of October 1 of each year, or when events occur or circumstances change that would, more likely than not, reduce the fair value of a reporting unit to below its carrying value. The Company performs its annual goodwill impairment test by comparing the fair value of the reporting unit with its carrying amount. The Company would recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value. See Note 8.

Intangible assets are primarily comprised of permits, customer contracts and customer relationships. Intangible assets are amortized over their useful lives in a manner that reflects the pattern in which the economic benefit of the intangible asset is consumed. Intangible assets are assessed for impairment when a triggering event occurs.

Investment in Brazilian Cokemaking Operations

On November 28, 2016, ArcelorMittal Brazil redeemed SunCoke’s indirectly held preferred and common equity interest in Sol Coqueria Tubarão S.A. ("Brazil Investment"), previously accounted for at cost, for consideration of $41.0 million. The Company received $20.5 million in cash at closing in 2016 and received the remaining $20.5 million in cash, plus interest of $0.2 million, in 2017. Starting in 2016, SunCoke receives $5.1 million in licensing fees per year, in addition to our per ton licensing fee, through 2023 related to the addition of certain patents to its existing intellectual property licensing agreement, which are currently in use by ArcelorMittal Brazil at the Brazil facility. The Company also extended the life of its patents with the Brazilian authorities through 2033, providing opportunity to extend the existing licensing agreement beyond 2023. Licensing fees are included in sales and other operating revenue on the Consolidated Statements of Income.

Income Taxes

Deferred tax asset and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those differences are projected to be recovered or settled. See Note 5.

The Company recognizes uncertain tax positions in its financial statements when minimum recognition threshold and measurement attributes are met in accordance with current accounting guidance. See Note 5.

Black Lung Benefit Liabilities

The Company has obligations related to coal workers’ pneumoconiosis, or black lung, benefits to certain of our former coal miners and their dependents. Such benefits are provided for under Title IV of the Federal Coal Mine and Safety Act of 1969 and subsequent amendments, as well as for black lung benefits provided in the states of Virginia, Kentucky and West Virginia pursuant to workers’ compensation legislation. The Patient Protection and Affordable Care Act (“PPACA”), which was implemented in 2010, amended previous legislation related to coal workers’ black lung obligations. PPACA provides for the automatic extension of awarded lifetime benefits to surviving spouses and changes the legal criteria used to assess and award claims. We act as a self-insurer for both state and federal black lung benefits and adjust our liability each year based upon actuarial calculations of our expected future payments for these benefits. See Note 13.

Postretirement Benefit Plan Liabilities

The postretirement benefit plans, which are frozen, are unfunded and the accumulated postretirement benefit obligation is fully recognized on the Consolidated Balance Sheets. Actuarial gains (losses) and prior service costs (benefits) which have not yet been recognized in net income are recognized as a credit (charge) to accumulated other comprehensive income (loss). The credit (charge) to accumulated other comprehensive income (loss), which is reflected net of related tax effects, is subsequently recognized in net income when amortized as a component of postretirement benefit plans expense included in interest expense, net on the Consolidated Statements of Income. See Note 10.

Asset Retirement Obligations

The fair value of a liability for an asset retirement obligation is recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. The associated asset retirement costs are capitalized as part of the carrying amount of the asset and depreciated over its remaining estimated useful life. The Company’s asset retirement obligations primarily relate to costs associated with restoring land to its original state. See Note 9.

Shipping and Handling Costs

Shipping and handling costs are included in cost of products sold and operating expenses on the Consolidated Statements of Income and are generally passed through to our customers. The Company has elected the practical expedient under ASC 606, "Revenue from Contracts with Customers", to account for shipping and handling activities as a promise to fulfill the transfer of coke.

Share-Based Compensation

We measure the cost of employee services in exchange for equity instrument awards and cash awards based on the grant-date fair value of the award. The cash awards and performance metrics of equity awards are remeasured on a quarterly basis. The market metrics of equity awards are not remeasured. The total cost is recognized over the requisite service period. Award forfeitures are accounted for as they occur. The costs of equity awards and cash awards were recorded to additional paid-in capital and accrued liabilities, respectively, on the Consolidated Balance Sheets. See Note 15.

Fair Value Measurements

The Company determines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. As required, the Company utilizes valuation techniques that maximize the use of observable inputs (levels 1 and 2) and minimize the use of unobservable inputs (level 3) within the fair value hierarchy included in current accounting guidance. Assets and liabilities are classified within the fair value hierarchy based on the lowest level (least observable) input that is significant to the measurement in its entirety. See Note 17.

Currency Translation

The functional currency of the Company’s Brazilian operations is the Brazilian real. The Company’s Brazil operations translate its assets and liabilities into U.S. dollars at the current exchange rates in effect at the end of the fiscal period. The gains or losses that result from this process are shown as cumulative translation adjustments within accumulated other comprehensive loss in the Consolidated Balance Sheets. The revenue and expense accounts of foreign operations are translated into U.S. dollars at the average exchange rates during the period.

Recently Adopted Accounting Pronouncements

In May 2014, Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2014-09, “Revenue from Contracts with Customers (Topic 606),” which supersedes the revenue recognition requirements in “Revenue Recognition (Topic 605),” and requires entities to recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The Company adopted this standard on January 1, 2018, using the modified retrospective method with no material impact on our revenue recognition model on an annual basis. See Note 18.

In November 2016, the FASB issued ASU 2016-18, “Statement of Cash Flows (Topic 230): Restricted cash.” The Company retrospectively adopted this ASU in the first quarter 2018 and modified the Company's cash flow presentation to include restricted cash with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. Historical restricted cash balances were related to cash withheld from the 2015 acquisition of CMT to fund the completion of certain expansion capital improvements, and the related immaterial impacts have been reclassified on the statement of cash flows for the years ended December 31, 2017 and 2016. The restricted cash balance was zero at both December 31, 2018 and December 31, 2017.

In March 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 Company adopted this ASU in the first quarter 2018 and retrospectively presented net periodic postretirement benefit cost in the income statement separately from the service cost component and outside a subtotal of income from operations. In conjunction with the adoption of this standard, expense of $1.3 million was reclassified from operating income and was recorded in interest expense, net on the Consolidated Statements of Income for both the years ended December 31, 2017 and 2016, respectively. See Note 10.

In February 2018, the FASB issued ASU 2018-02, “Income Statement-Reporting Comprehensive Income (Topic 220) - Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income.” The Company adopted this ASU in the first quarter 2018 and reclassified $1.1 million of deferred tax adjustments to accumulated other comprehensive income (loss) from retained earnings on the December 31, 2017 balance sheet for the tax effects resulting from the Tax Cuts and Jobs Act of 2017.

Recently Issued Pronouncements

In February 2016, the FASB issued ASU 2016-02, "Leases (Topic 842)." ASU 2016-02 requires leases to be recognized as assets and liabilities on the balance sheet for the rights and obligations created by all leases with terms of more than 12 months. Subsequently, the FASB has issued various ASUs to provide further clarification around certain aspects of ASC 842, "Leases".  This standard is effective for annual and interim periods in fiscal years beginning after December 15, 2018, with early adoption permitted. A multi-disciplined implementation team has gained an understanding of the accounting and disclosure provisions of the standard and analyzed the impacts to our business, including the development of new accounting processes to account for our leases and support the required disclosures. We have implemented a technology tool to assist with the accounting and reporting requirements of this standard. While we are still finalizing the impact of adopting this standard, we expect that upon adoption the right-of-use assets and lease liabilities, such as land, the lease of our corporate office space and certain equipment rentals, will increase the reported assets and liabilities on our Consolidated Balance Sheets by approximately $5 million to $10 million. The Company adopted this standard on January 1, 2019, by applying the modified retrospective transition approach and electing not to adjust prior comparative periods.

Labor Concentrations

As of December 31, 2018, we have approximately 895 employees in the U.S. Approximately 40 percent of our domestic employees, principally at our cokemaking operations, are represented by the United Steelworkers union under various contracts. Additionally, approximately 3 percent of our domestic employees are represented by the International Union of Operating Engineers. While the labor agreement at our Indiana Harbor cokemaking facility expired on August 31, 2015, the parties mutually agreed to extend the terms of this agreement through August 31, 2018. Currently both parties are working under the term of the contract extension while negotiating a new agreement. We do not anticipate any work stoppages during the extended period of the agreement. The labor agreements at KRT, Lake Terminal and Haverhill will expire on April 30, 2019, June 30, 2019 and November 1, 2019, respectively. We will negotiate the renewal of these agreements in 2019 and do not anticipate any work stoppages.

As of December 31, 2018, we have approximately 285 employees at the cokemaking facility in Vitória, Brazil, all of whom are represented by a union under a labor agreement. During 2018, the labor agreement at our Vitoria, Brazil facility was renewed for an additional year, and it expires on October 31, 2019.

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Acquisition of Noncontrolling Interest

12 Months Ended

Dec. 31, 2018

Noncontrolling Interest [Abstract]

Acquisition of Noncontrolling Interest

3. Acquisition of Noncontrolling Interest

In 2017, the Company's Board of Directors authorized a program for the Company to purchase outstanding Partnership common units at any time and from time to time in the open market, through privately negotiated transactions, block transactions, or otherwise for a total aggregate cost to the Company not to exceed $100.0 million. At December 31, 2018, there was $47.1 million available under the authorized program.

The following table summarizes the Company's purchases of outstanding Partnership common units in the open market:

	Years Ended December 31
	2018		2017
	(Dollars in millions)
Units purchased	231,171		2,853,032
Cash paid	$	4.2	$	48.7
Decrease in noncontrolling interest (1)	$	2.7	$	29.6
Decrease in additional paid in capital (2)	$	1.2	$	12.0

(1) Represents Partnership's net book value acquired by the Company.

(2) Represents consideration paid in excess of the net book value of the noncontrolling interest acquired net of deferred tax adjustments of $0.3 million and $7.1 million for the years ended December 31, 2018 and 2017, respectively.

The following table summarizes the effects of the changes in the Company's ownership interest in the Partnership on SunCoke's equity:

	Years Ended December 31,
	2018			2017
	(Dollars in millions)
Net income attributable to SunCoke Energy, Inc	$	26.2		$	122.4
Decrease in SunCoke Energy, Inc. equity for the purchase of additional interest in the Partnership	(1.2		)	(12.0		)
Changes from net income attributable to SunCoke Energy, Inc and transfers to noncontrolling interest	$	25.0		$	110.4

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Customer Concentrations

12 Months Ended

Dec. 31, 2018

Risks and Uncertainties [Abstract]

Customer Concentrations

4. Customer Concentrations

In 2018, the Company sold approximately 4 million tons of coke under long-term, take-or-pay contracts to its three primary customers in the U.S.: AK Steel Corporation ("AK Steel"), ArcelorMittal USA LLC and/or its affiliates (“AM USA”) and United States Steel Corporation ("U.S. Steel"). In addition, licensing and operating fees are payable to the Company under long-term contracts with ArcelorMittal Brazil.

The table below shows sales to the Company's significant customers:

	Years ended December 31,
	2018				2017				2016
	Sales and other operating revenue		Percent of Company sales and other operating revenue		Sales and other operating revenue		Percent of Company sales and other operating revenue		Sales and other operating revenue		Percent of Company sales and other operating revenue
	(Dollars in millions)
AM USA and ArcelorMittal Brazil(1)	$	735.8	50.7	%	$	678.2	50.9	%	$	596.6	48.8	%
AK Steel(2)	$	377.9	26.0	%	$	331.3	24.9	%	$	350.0	28.6	%
U.S. Steel(3)	$	206.8	14.3	%	$	214.1	16.1	%	$	185.3	15.1	%

(1) Represents revenues included in our Domestic Coke and Brazil Coke segments.

(2) Represents revenues included in our Domestic Coke segment.

(3) Represents revenues included in our Domestic Coke and Logistics segments.

The Company generally does not require any collateral with respect to its receivables. At both December 31, 2018 and 2017, the Company’s receivables balances were primarily due from AM USA and ArcelorMittal Brazil, AK Steel and U.S. Steel. As a result, the Company experiences concentrations of credit risk in its receivables with these three customers. These concentrations of credit risk may be affected by changes in economic or other conditions affecting the steel industry.

The table below shows receivables due from the Company's significant customers:

	December 31,
	2018		2017
	(Dollars in millions)
AM USA and ArcelorMittal Brazil	$	34.3	$	25.7
AK Steel	$	25.3	$	13.2
U.S. Steel	$	5.2	$	5.6

Our logistics business provides coal handling and storage services to Murray Energy Corporation, Inc. ("Murray") and Foresight Energy LLC ("Foresight"), who are the two primary customers in the Logistics segment.

The table below shows sales to Murray and Foresight:

	Years ended December 31,
	2018			2017			2016
	(Dollars in millions)
Sales and other operating revenue	$	62.5		$	57.8		$	53.5
Percent of Company sales and other operating revenue	4.3		%	4.3		%	4.4		%
Percent of Logistics segment sales and other operating revenue, including intersegment sales	49.3		%	49.4		%	49.6		%

The table below shows receivables due from Murray and Foresight:

	December 31,
	2018		2017
	(Dollars in millions)
Murray and Foresight	$	3.2	$	9.7

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Income Taxes

12 Months Ended

Dec. 31, 2018

Income Tax Disclosure [Abstract]

Income Taxes

5. Income Taxes

The components of income before income tax (benefit) expense and loss from equity method investment are as follows:

	Years Ended December 31,
	2018		2017		2016
	(Dollars in millions)
Domestic	$	39.3	$	4.3	$	52.5
Foreign	17.7		17.6		15.6
Total	$	57.0	$	21.9	$	68.1

Income tax expense (benefit) consisted of the following:

	Years Ended December 31,
	2018			2017			2016
	(Dollars in millions)
Current tax expense:
U.S. federal	$	1.4		$	1.7		$	2.7
State	2.1			(1.0		)	(2.2		)
Foreign	4.5			4.9			5.0
Total current tax expense	8.0			5.6			5.5
Deferred tax expense:
U.S. federal	(3.1		)	(99.7		)	(1.5		)
State	(0.3		)	12.5			4.6
Total deferred tax (benefit) expense	(3.4		)	(87.2		)	3.1
Total	$	4.6		$	(81.6	)	$	8.6

The reconciliation of income tax expense at the U.S. statutory rate to income tax expense (benefit) is as follows:

	Years Ended December 31,
	2018					2017					2016
	(Dollars in millions)
Income tax expense at U.S. statutory rate	$	12.0		21.0	%	$	7.7		35.0	%	$	23.8		35.0	%
Increase (reduction) in income taxes resulting from:
Impact of Final Regulations(1)	(1.4		)	(2.5	)%	64.2			293.2	%	—			—	%
Impact of Tax Legislation(2)	(4.8		)	(8.4	)%	(154.7		)	(706.4	)%	—			—	%
Income attributable to noncontrolling interests in partnerships(3)	(3.9		)	(6.8	)%	(5.4		)	(24.7	)%	(15.6		)	(23.0	)%
State and other income taxes, net of federal income tax effects	1.6			2.8	%	2.0			9.1	%	1.1			1.7	%
Change in valuation allowance(4)	0.7			1.2	%	3.9			17.8	%	0.4			0.6	%
Other	0.4			0.7	%	0.7			3.2	%	(1.1		)	(1.6	)%
Income tax (benefit) expense at effective tax rate	$	4.6		8.0	%	$	(81.6	)	(372.8	)%	$	8.6		12.7	%

(1) In January 2017, the Internal Revenue Service ("IRS") announced its decision to exclude cokemaking as a qualifying income generating activity in its final regulations (the "Final Regulations") issued under section 7704(d)(1)(E) of the Internal Revenue Code relating to the qualifying income exception for publicly traded partnerships. Subsequent to the 10-year transition period, certain cokemaking entities in the Partnership will become taxable as corporations. As a result, the Partnership recorded deferred income tax expense of $148.6 million to set up its initial deferred income tax liability during 2017, primarily related to differences in the book and tax basis of fixed assets, which are expected to exist at the end of the 10-year transition period when the cokemaking operations become taxable.  However, the Company had previously recorded $84.4 million of the deferred income tax liability in its financial statements related to the Company's share of the deferred tax liability for the book and tax differences in its investment in the Partnership. As such, the Company's 2017 financial statements reflect the $64.2 million incremental impact from the Final Regulations solely attributable to the Partnership’s public unitholders, which was also recorded as an equal reduction to noncontrolling interest.

In 2018, the Partnership recorded a deferred tax benefit of $3.6 million related to its changes in projected deferred tax liability associated with projected book and tax differences at the end of the 10-year transition period due to current period additions and changes in estimated useful lives of certain assets. The Company's 2018 financial statements reflect a $1.4 million benefit, which is solely attributable to the Partnership’s public unitholders and was also recorded as an equal reduction to noncontrolling interest. 

As a result, the Final Regulations have no impact to net income attributable to the Company.

(2) On December 22, 2017, the Tax Legislation was enacted. The Tax Legislation significantly revised the U.S. corporate income tax structure, including lowering corporate income tax rates. In addition, the SEC staff released Staff Accounting Bulletin 118 on December 23, 2017, which provided for companies to record a provisional impact of the Tax Legislation during a measurement period, not to exceed one year, in situations where companies do not have the necessary information available, prepared, or analyzed in reasonable detail to complete the accounting under ASC 740, "Income Taxes", for certain income tax effects of the Tax Legislation for the reporting period which includes enactment. During 2017, SunCoke recorded a provisional net income tax benefit of $154.7 million, of which $125.0 million was attributable to the Company, for the impact of this Tax Legislation. These benefits were primarily due to the $169.0 million net benefit resulting from the remeasurement of U.S. deferred income tax liabilities and assets at the lower enacted corporate tax rates. During 2017, based on information available at the time, the Company recorded provisional income tax expense of $14.3 million for a valuation allowance against $19.0 million of foreign tax credit carryforwards that the Company believed would not be realized prior to their expiration as a result of the Tax Legislation. Based on an updated analysis of the foreign tax credit rules relating to the new Tax Legislation, the Company revised its estimate of the realizability of its foreign tax credits, resulting in a net $4.8 million benefit during the third quarter of 2018. There were no other significant changes to previous estimates and amounts recorded in 2017 relating to this Tax Legislation.

(3) Excludes the impact of the Final Regulations on qualifying income discussed above. No income tax expense is reflected in the Consolidated Statements of Income for income attributable to noncontrolling interests in partnership entities.

(4) In 2017, the Company recorded a valuation allowance as a result of changes in future state allocation assumptions.

The tax effects of temporary differences that comprise the net deferred income tax liability from operations are as follows:

	December 31,
	2018			2017
	(Dollars in millions)
Deferred tax assets:
Retirement benefit liabilities	$	6.4		$	7.1
Black lung benefit liabilities	11.3			11.6
Share-based compensation	6.4			6.1
Federal tax credit carryforward(1)	21.5			23.2
Foreign tax credit carryforward(2)	15.9			19.0
Federal net operating loss	—			2.5
Section 163(j) interest limitation carryforward(3)	1.8			—
State tax credit carryforward, net of federal income tax effects(4)	2.4			4.0
State net operating loss carryforward, net of federal income tax effects(5)	13.5			13.9
Other liabilities not yet deductible	4.9			4.3
Total deferred tax assets	84.1			91.7
Less valuation allowance(6)	(20.7		)	(26.2		)
Deferred tax asset, net	63.4			65.5
Deferred tax liabilities:
Properties, plants and equipment	(111.5		)	(114.9		)
Investment in partnerships	(206.6		)	(208.4		)
Total deferred tax liabilities	(318.1		)	(323.3		)
Net deferred tax liability	$	(254.7	)	$	(257.8	)

(1) Federal tax credit carryforward expires in 2032 through 2034.

(2) Foreign tax credit carryforward expires in 2023 through 2028.

(3) The Tax Legislation generally limits the deductibility of business interest expense to 30 percent of adjusted taxable income. This limitation resulted in a deferred tax asset as it is eligible for deduction in future taxable years and has no expiration.

(4) State tax credit carryforward, net of federal income tax effects expires in 2019 through 2023.

(5) State net operating loss carryforward, net of federal income tax effects expires in 2023 through 2038.

(6) Primarily related to state tax credit and net operating loss carryforwards and the $9.9 million allowance against the foreign tax credit carryforward.

The Company's consolidated federal income tax returns have been examined by the IRS for all years through the year ended December 31, 2014. SunCoke is currently open to examination by the IRS for tax years ended December 31, 2015 and forward.

State and foreign income tax returns are generally subject to examination for a period of three to five years after the filing of the respective returns. The state impact of any amended federal returns remains subject to examination by various states for a period of up to one year after formal notification of such amendments to the states.

There were no uncertain tax positions at December 31, 2018 and 2017, and there were no associated interest or penalties recognized for the years ended December 31, 2018, 2017 or 2016. The Company does not expect that any unrecognized tax benefits pertaining to income tax matters will be required in the next twelve months.

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Inventories

12 Months Ended

Dec. 31, 2018

Inventory Disclosure [Abstract]

Inventories

6. Inventories

The Company’s inventory consists of metallurgical coal, which is the principal raw material for the Company’s cokemaking operations, coke, which is the finished good sold by the Company to its customers, and materials, supplies and other. These components of inventories were as follows:

	December 31,
	2018		2017
	(Dollars in millions)
Coal	$	59.9	$	61.4
Coke	8.6		12.3
Materials, supplies and other	41.9		37.3
Total inventories	$	110.4	$	111.0

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Properties, Plants, and Equipment, Net

12 Months Ended

Dec. 31, 2018

Property, Plant and Equipment [Abstract]

Properties, Plants, and Equipment, Net

7. Properties, Plants, and Equipment, Net

The components of net properties, plants and equipment were as follows:

	December  31,
	2018			2017
	(Dollars in millions)
Coke and energy plant, machinery and equipment(1)	$	1,876.3		$	1,812.0
Logistics plant, machinery and equipment	218.3			216.2
Land and land improvements	119.7			118.7
Construction-in-progress	72.7			51.9
Other	39.9			35.7
Gross investment, at cost	2,326.9			2,234.5
Less: accumulated depreciation(1)	(855.8		)	(733.2		)
Total properties, plants and equipment, net	$	1,471.1		$	1,501.3

(1) Includes assets, consisting mainly of coke and energy plant, machinery and equipment, with a gross investment totaling $1,416.2 million and $1,337.3 million and accumulated depreciation of $554.1 million and $475.8 million at December 31, 2018 and December 31, 2017, respectively, which are subject to long-term contracts to sell coke and are deemed to contain operating leases. Upon adoption of ASC 842, "Leases",in 2019, these contracts will no longer be deemed to contain operating leases.

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Goodwill and Other Intangible Assets

12 Months Ended

Dec. 31, 2018

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill and Other Intangible Assets

8. Goodwill and Other Intangible Assets

Goodwill allocated to SunCoke's reportable segments is shown below. There were no changes in the carrying amount of goodwill during the years ended December 31, 2018 and 2017.

	December 31, 2018 and 2017
	(Dollars in millions)
Domestic Coke	$	3.4
Logistics	73.5
Total	$	76.9

The Company performed its annual goodwill impairment test as of October 1, 2018, with no indication of impairment. The fair value of the Logistics reporting unit, which was determined based on a discounted cash flow analysis, exceeded the carrying value of the reporting unit by approximately 30 percent. A significant portion of our logistics business holds long-term, take-or-pay contracts with Murray and Foresight. Key assumptions in our goodwill impairment test include continued customer performance against long-term, take-or-pay contracts, renewal of future long-term, take-or-pay contracts, incremental merchant businessand a 14 percent discount rate representing the estimated weighted average cost of capital for this business line. The use of different assumptions, estimates or judgments, such as the estimated future cash flows of Logistics and the discount rate used to discount such cash flows, could significantly impact the estimated fair value of a reporting unit, and therefore, impact the excess fair value above carrying value of the reporting unit. A 100 basis point change in the discount rate would not have reduced the fair value of the reporting unit below its carrying value.

The following table summarizes the components of gross and net intangible asset balances:

		December 31, 2018						December 31, 2017
	Weighted - Average Remaining Amortization Years	Gross Carrying Amount		Accumulated Amortization		Net		Gross Carrying Amount		Accumulated Amortization		Net
		(Dollars in millions)
Customer contracts	4	$	31.7	$	17.7	$	14.0	$	31.7	$	13.8	$	17.9
Customer relationships	13	28.7		7.5		21.2		28.7		5.7		23.0
Permits	24	139.0		17.4		121.6		139.0		12.2		126.8
Trade name	—	1.2		1.2		—		1.2		1.0		0.2
Total		$	200.6	$	43.8	$	156.8	$	200.6	$	32.7	$	167.9

The permits above represent the environmental and operational permits required to operate a coal export terminal in accordance with the U.S. Environmental Protection Agency ("EPA") and other regulatory bodies. Intangible assets are amortized over their useful lives in a manner that reflects the pattern in which the economic benefit of the asset is consumed. The permits’ useful lives were estimated to be 27 years at acquisition based on the expected useful life of the significant operating equipment at the facility. We have historical experience of renewing and extending similar arrangements at our other facilities and intend to continue to renew our permits as they come up for renewal for the foreseeable future. The permits were renewed regularly prior to our acquisition of CMT. These permits have an average remaining renewal term of approximately 2.4 years.

Total amortization expense for intangible assets subject to amortization was $11.1 million, $11.1 million and $11.2 million for the years ended December 31, 2018, 2017 and 2016, respectively. Based on the carrying value of finite-lived intangible assets as of December 31, 2018, we estimate amortization expense for each of the next five years as follows:

	(Dollars in millions)
2019	$	10.9
2020	10.7
2021	10.3
2022	10.3
2023	7.0
Thereafter	107.6
Total	$	156.8

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Asset Retirement Obligations

12 Months Ended

Dec. 31, 2018

Asset Retirement Obligation [Abstract]

Asset Retirement Obligations

9. Asset Retirement Obligations

The Company has asset retirement obligations, primarily in the Domestic Coke segment, related to certain contractual obligations, mostly related to costs associated with restoring land to its original state, and may require the retirement and removal of long-lived assets from certain cokemaking properties as well as other reclamation obligations related to our former coal mining business. The Federal Surface Mining Control and Reclamation Act of 1977 and similar state statutes require that mine property be restored in accordance with specified standards and an approved reclamation plan. We do not have any unrecorded asset retirement obligations.

The following table provides a reconciliation of changes in the asset retirement obligation from operations during each period:

	(Dollars in millions)
Balance at December 31, 2016	$	13.9
Liabilities settled	(0.7		)
Accretion expense(1)	1.0
Revisions in estimated cash flows	(0.2		)
Balance at December 31, 2017	$	14.0
Liabilities settled	(0.4		)
Accretion expense(1)	0.9
Revisions in estimated cash flows	$	0.1
Balance at December 31, 2018	$	14.6

(1) Included in cost of products sold and operating expenses on the Consolidated Statements of Income.

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Retirement Benefits Plans

12 Months Ended

Dec. 31, 2018

Retirement Benefits [Abstract]

Retirement Benefits Plans

10. Retirement Benefits Plans

Postretirement Health Care and Life Insurance Plans

The Company has plans which provide health care and life insurance benefits for many of its retirees (“postretirement benefit plans”). The postretirement benefit plans are unfunded and the costs are borne by the Company. Effective January 1, 2011, postretirement medical benefits for future retirees were phased out or eliminated for non-mining employees with less than ten years of service.

Postretirement benefit plans expense consisted of the following components:

	Years Ended December 31,
	2018			2017			2016
	(Dollars in millions)
Interest cost on benefit obligations	$	1.0		$	1.1		$	1.3
Amortization of:
Actuarial losses	0.6			0.9			0.7
Prior service benefit	(0.7		)	(0.7		)	(0.7		)
Total expense	$	0.9		$	1.3		$	1.3

Postretirement benefit plans expense is determined using actuarial assumptions as of the beginning of the year or using weighted-average assumptions when curtailments, settlements and/or other events require a plan remeasurement. The following assumptions were used to determine postretirement benefit plans expense:

	December 31,
	2018		2017		2016
Discount Rate	3.35	%	3.65	%	3.80	%

The following amounts were recognized as components of other comprehensive income (loss) before related tax impacts:

		Years Ended December 31,
		2018			2017			2016
	(Dollars in millions)
Reclassifications to earnings of:
Actuarial loss amortization		$	0.6		$	0.9		$	0.7
Prior service benefit amortization		(0.7		)	(0.7		)	(0.7		)
Retirement benefit plan funded status    adjustments:
Actuarial gains (losses)		0.8			(1.1		)	(1.8		)
Prior service benefit(1)		—			—			1.5
		$	0.7		$	(0.9	)	$	(0.3	)

(1) Effective January 1, 2017, a plan change occurred resulting in Medicare-eligible disabled participants transitioning from a Company-sponsored group medical plan to a federal health care exchange plan. The Company provides a subsidy to these participants each year. The plan change resulted in a decrease in the benefit obligation of $1.5 million during 2016.

The following table sets forth the components of the changes in benefit obligations:

	Years Ended December 31,
	2018			2017
	(Dollars in millions)
Benefit obligation at beginning of year	$	31.3		$	32.3
Interest cost	1.0			1.1
Actuarial (gain)/loss	(0.8		)	1.1
Benefits paid	(3.3		)	(3.2		)
Benefit obligation at end of year(1)	$	28.2		$	31.3

(1) Represents retirement benefit liabilities, including current portion, on the Consolidated Balance Sheets. The current portion of retirement liabilities, which totaled $3.0 million and $3.1 million at December 31, 2018 and 2017, respectively, is classified in accrued liabilities on the Consolidated Balance Sheets.

The following table sets forth the cumulative amounts not yet recognized in net income:

	Years Ended December 31,
	2018			2017
	(Dollars in millions)
Cumulative amounts not yet recognized in net income:
Actuarial losses	$	10.4		$	11.8
Prior service benefits	(2.6		)	(3.4		)
Accumulated other comprehensive loss (before related tax benefit)	$	7.8		$	8.4

The expected benefit payments through 2028 for the postretirement benefit plan are as follows:

Year ending December 31:	(Dollars in millions)
2019	$	3.0
2020	2.9
2021	2.8
2022	2.6
2023	2.4
2024 through 2028	9.5

The measurement date for the Company’s postretirement benefit plans is December 31. The following discount rates were used to determine the benefit obligation:

	December 31,
	2018		2017
Discount rate	4.00	%	3.35	%

The health care cost trend assumption used at both December 31, 2018, and 2017 to compute the accumulated postretirement benefit obligation for the postretirement benefit plans was 6.50 percent, which is assumed to decline gradually to 5.00 percent in 2028 and to remain at that level thereafter.

Defined Contribution Plans

The Company has defined contribution plans which provide retirement benefits for certain of its employees. The Company’s contributions, which are principally based on the Company’s pretax income and the aggregate compensation levels of participating employees and are charged against income as incurred, amounted to $6.5 million, $6.4 million and $5.6 million for the years ended December 31, 2018, 2017 and 2016, respectively.

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Accrued Liabilities

12 Months Ended

Dec. 31, 2018

Balance Sheet Related Disclosures [Abstract]

Accrued Liabilities

11. Accrued Liabilities

Accrued liabilities consist of following:

	December 31,
	2018		2017
	(Dollars in millions)
Accrued benefits	$	21.2	$	21.3
Current portion of postretirement benefit obligation	3.0		3.1
Other taxes payable	9.1		10.5
Current portion of black lung liability	4.5		5.4
Accrued legal	4.2		5.6
Other	3.6		7.3
Total accrued liabilities	$	45.6	$	53.2

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Debt and Financing Obligation

12 Months Ended

Dec. 31, 2018

Debt Disclosure [Abstract]

Debt and Financing Obligation

12. Debt and Financing Obligation

Total debt and financing obligation consisted of the following:

	December 31,
	2018			2017
	(Dollars in millions)
7.500 percent senior notes, due 2025 ("Partnership Notes")	$	700.0		$	700.0
7.625 percent senior notes, due 2019 ("2019 Notes")	—			44.6
Term loan, due 2022 ("Term Loan")	43.9			—
SunCoke's revolving credit facility, due 2022 ("Revolving Facility")	—			—
Partnership's revolving credit facility, due 2022 ("Partnership Revolver")	105.0			130.0
5.82 percent financing obligation, due 2021 ("Partnership Financing Obligation")	10.1			12.7
Total borrowings	$	859.0		$	887.3
Original issue discount	(5.4		)	(5.9		)
Debt issuance costs	(15.2		)	(17.7		)
Total debt and financing obligation	$	838.4		$	863.7
Less: current portion of long-term debt and financing obligation	3.9			2.6
Total long-term debt and financing obligation	$	834.5		$	861.1

Redemption of 2019 Notes

On January 11, 2018, the Company redeemed all of its outstanding 2019 Notes for $46.1 million, which included accrued and unpaid interest of $1.5 million. As a result of the debt extinguishment, the Company recorded a loss on extinguishment of debt on the Consolidated Statements of Income of $0.3 million, representing a write-off of unamortized debt issuance costs. The Company funded the redemption with a Term Loan in aggregate principal amount of $45.0 million, resulting in additional debt issuance costs of $0.3 million. The Term Loan will mature on May 24, 2022. Borrowings under the Term Loan will bear interest, at the Company’s option, at either (i) a base rate plus an applicable margin or (ii) LIBOR plus an applicable margin. The applicable margin is based on the Company's consolidated leverage ratio, as defined in the credit agreement.

Partnership Notes

The Partnership Notes are the senior unsecured obligations of the Partnership, and are guaranteed on a senior unsecured basis by each of the Partnership’s existing and certain future subsidiaries. Interest on the Partnership Notes is payable semi-annually in cash in arrears on June 15 and December 15 of each year.

The Partnership may redeem some or all of the Partnership Notes at any time on or after June 15, 2020 at specified redemption prices plus accrued and unpaid interest, if any, to the redemption date. Before June 15, 2020, and following certain equity offerings, the Partnership also may redeem up to 35 percent of the Partnership Notes at a price equal to 107.5 percent of the principal amount, plus accrued and unpaid interest, if any, to the redemption date. In addition, at any time prior to June 15, 2020, the Partnership may redeem some or all of the Partnership Notes at a price equal to 100 percent of the principal amount, plus accrued and unpaid interest, if any, to the redemption date, plus a “make-whole” premium.

The Partnership is obligated to offer to purchase all or a portion of the Partnership Notes at a price of (a) 101 percent of their principal amount, together with accrued and unpaid interest, if any, to the date of purchase, upon the occurrence of certain change of control events and (b) 100 percent of their principal amount, together with accrued and unpaid interest, if any, to the date of purchase, upon the occurrence of certain asset dispositions. These restrictions and prohibitions are subject to certain qualifications and exceptions set forth in the Indenture, including without limitation, reinvestment rights with respect to the proceeds of asset dispositions.

The Partnership Notes contain covenants that, among other things, limit the Partnership’s ability and the ability of certain of the Partnership’s subsidiaries to (i) incur indebtedness, (ii) pay dividends or make other distributions, (ii) prepay, redeem or repurchase certain subordinated debt, (iv) make loans and investments, (v) sell assets, (vi) incur liens, (vii) enter into transactions with affiliates, (viii) enter into agreements restricting the ability of subsidiaries to pay dividends and (ix) consolidate or merge.

Partnership Financing Obligation

The Partnership's sale-leaseback arrangement of certain coke and logistics equipment has an initial lease period of 60 months and an early buyout option after 48 months to purchase the equipment at 34.5 percent of the original lease equipment cost. The arrangement is accounted for as a financing transaction, resulting in a financing obligation on the Consolidated Balance Sheets. The financing obligation is guaranteed by the Partnership.

Revolving Facility

The proceeds of any borrowings made under the Revolving Facility can be used to finance working capital needs, acquisitions, capital expenditures and for other general corporate purposes. The obligations under the credit agreement are guaranteed by certain of the Company’s subsidiaries and secured by liens on substantially all of the Company’s and the guarantors’ assets pursuant to a guarantee and collateral agreement.

The capacity of the Revolving facility is $100.0 million. As of December 31, 2018, the Revolving Facility had letters of credit outstanding of $23.9 million and no outstanding balance, leaving $76.1 million available. Commitment fees are based on the unused portion of the Revolving Facility at a rate of 0.4 percent.

Borrowings under the Revolving Facility bear interest, at SunCoke Energy’s option, at either (i) a base rate plus an applicable margin or (ii) LIBOR plus 175 basis points. The spread is subject to change based on the Company's consolidated leverage ratio, as defined in the credit agreement. The weighted-average interest rate for borrowings outstanding under the Credit Agreement was 2.8 percent during 2016. There were no borrowings during 2018 or 2017.

Partnership Revolver

The proceeds of any borrowings made under the Partnership Revolver can be used to finance working capital needs, acquisitions, capital expenditures and for other general corporate purposes. The Partnership Revolver provides total aggregate commitments from lenders of $285.0 million and up to $200.0 million uncommitted incremental revolving capacity. The obligations under the Partnership Revolver are guaranteed by the Partnership’s subsidiaries and secured by liens on substantially all of the Partnership’s and the guarantors’ assets.

As of December 31, 2018, the Partnership had $1.9 million of letters of credit outstanding and an outstanding balance of $105.0 million, leaving $178.1 million available. Commitment fees are based on the unused portion of the Partnership Revolver at a rate of 0.4 percent.

Borrowings under the Partnership Revolver bear interest at either (i) a variable rate of LIBOR plus 250 basis points or (ii) an alternative base rate plus 150 basis points. The spread is subject to change based on the Partnership's consolidated leverage ratio, as defined in the credit agreement. The weighted-average interest rate for borrowings under the Partnership Revolver was 4.8 percent, 3.8 percent and 3.3 percent during 2018, 2017 and 2016, respectively.

Covenants

Under the terms of the Revolving Facility, the Company is subject to a maximum consolidated leverage ratio of 3.25:1.00 and a minimum consolidated interest coverage ratio of 2.75:1.00. Under the terms of the Partnership's credit agreement, the Partnership is subject to a maximum consolidated leverage ratio of 4.5:1.0 prior to June 30, 2020 and 4.0:1.0 after June 30, 2020 and a minimum consolidated interest coverage ratio of 2.5:1.0. The Company and Partnership's credit agreement contains other covenants and events of default that are customary for similar agreements and may limit our ability to take various actions including our ability to pay a dividend or repurchase our stock.

If we fail to perform our obligations under these and other covenants, the lenders' credit commitment could be terminated and any outstanding borrowings, together with accrued interest, under the Revolving Facility and Partnership Revolver could be declared immediately due and payable. The Company and the Partnership have a cross default provision that applies to our indebtedness having a principal amount in excess of $35 million.

As of December 31, 2018, the Company and the Partnership were in compliance with all debt covenants. We do not anticipate violation of these covenants nor do we anticipate that any of these covenants will restrict our operations or our ability to obtain additional financing.

Maturities

As of December 31, 2018, the combined aggregate amount of maturities for long-term borrowings for each of the next five years is as follows:

	(Dollars in millions)
2019	$	3.9
2020(1)	10.7
2021	3.4
2022	141.0
2023	—
2024-Thereafter	700.0
Total	$	859.0

(1) Assumes the Partnership Financing Obligation early buyout option is exercised in 2020.

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Commitments and Contingent Liabilities

12 Months Ended

Dec. 31, 2018

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingent Liabilities

13. Commitments and Contingent Liabilities

Lease obligations

The Company, as lessee, has noncancelable operating leases for land, office space, equipment and railcars. The aggregate amount of future minimum annual rental payments applicable to noncancelable operating leases is as follows:

	Minimum Rental Payments
	(Dollars in millions)
Year ending December 31:
2019	$	2.0
2020	1.1
2021	1.0
2022	0.5
2023	0.1
2024-Thereafter	0.7
Total	$	5.4

Total rental expense for all operating leases was $9.8 million, $7.3 million and $8.7 million in 2018, 2017 and 2016, respectively.

Legal Matters

SunCoke Energy is party to an omnibus agreement, pursuant to which we have agreed to indemnify the Partnership for costs and expenses related to remediation of certain identified environmental matters in existence prior to the Partnership's initial public offering on January 24, 2013 ("IPO") at the Partnership’s Haverhill and Middletown facilities and certain identified environmental matters at the Partnership's Granite City facility in existence prior to its dropdown in January of 2015 ("Granite City Dropdown"). However, under the terms of the omnibus agreement, SunCoke Energy is not obligated to indemnify the Partnership for any new environmental matters coming into existence after the IPO at the Partnership’s Haverhill and Middletown facilities, or any new environmental matters coming into existence after the Granite City Dropdown at the Partnership's Granite City facility.

The EPA issued Notices of Violations (“NOVs”) for our Haverhill and Granite City cokemaking facilities which stemmed from alleged violations of our air emission operating permits for these facilities. We are working in a cooperative manner with the EPA, the Ohio Environmental Protection Agency and the Illinois Environmental Protection Agency to address the allegations, and have entered into a consent decree in federal district court with these parties. The consent decree includes a $2.2 million civil penalty payment, which was paid in December 2014, as well as capital projects underway to improve the reliability of the energy recovery systems and enhance environmental performance at the Haverhill and Granite City facilities. In the third quarter of 2018, the Court entered an amendment to the consent decree which provides the Haverhill and Granite City facilities with additional time to perform necessary maintenance on the flue gas desulfurization systems without exceeding consent decree limits. The emissions associated with this maintenance will be mitigated in accordance with the amendment, and there are no civil penalty payments associated with this amendment. The project at Granite City was due to be completed in February 2019, but the Company now expects to complete the project in July 2019 and is in discussions with the government entities regarding, among other things, the timing thereof.

We anticipate spending approximately $150 million related to these projects, of which we have spent approximately $138 million to date, including $7 million spent by the Company prior to the formation of the Partnership. The remaining capital is expected to be spent through the first half of 2019. A portion of the proceeds from the Partnership's initial public offering and subsequent dropdowns were used to fund $119 million of these environmental remediation projects. Pursuant to the omnibus agreement, the Company made capital contributions to the Partnership of $20 million during 2018 for these known environmental remediation projects. The Company expects to make additional capital contributions to the Partnership of approximately $5 million in the first half of 2019 for the estimated future spending related to these environmental remediation projects.

SunCoke Energy has also received NOVs, Findings of Violations ("FOVs"), and information requests from the EPA related to our Indiana Harbor cokemaking facility, which allege violations of certain air operating permit conditions for this facility. The Clean Air Act (the "CAA") provides the EPA with the authority to issue, among other actions, an order to enforce a State Implementation Plan ("SIP") 30 days after an NOV. The CAA also authorizes EPA enforcement of other non-SIP requirements immediately after an FOV. Generally, an NOV applies to SIPs and requires the EPA to wait 30 days, while an FOV applies to all other provisions (such as federal regulations) of the CAA, and has no waiting period. The NOVs and/or FOVs were received in 2010, 2012, 2013, 2015 and 2016. After discussions with the EPA and the Indiana Department of Environmental Management (“IDEM”) in 2010, resolution of the NOVs/FOVs was postponed by mutual agreement because of ongoing discussions regarding the NOVs at Haverhill and Granite City. In January 2012, the Company began working in a cooperative manner to address the allegations with the EPA, the IDEM and Cokenergy, LLC., an independent power producer that owns and operates an energy facility, including heat recovery equipment and a flue gas desulfurization system, that processes hot flue gas from our Indiana Harbor facility to produce steam and electricity and to reduce the sulfur and particulate content of such flue gas.

The EPA, IDEM, SunCoke Energy and Cokenergy, LLC met regularly since those discussions commenced to reach a settlement of the NOVs and FOVs. Capital projects were underway during this time to address items that would be included in conjunction with a settlement. A consent decree among the parties was entered by the federal district court during the fourth quarter of 2018. The settlement includes a $2.5 million civil penalty that was paid in the fourth quarter of 2018. Further, the settlement consists of capital projects already underway to improve reliability and environmental performance of the coke ovens at the facility.

The Company is a party to certain other pending and threatened claims, including matters related to commercial and tax disputes, product liability, employment claims, personal injury claims, premises-liability claims, allegations of exposures to toxic substances and environmental claims. Although the ultimate outcome of these claims cannot be ascertained at this time, it is reasonably possible that some portion of these claims could be resolved unfavorably to the Company. Management of the Company believes that any liability which may arise from claims would not have a material adverse impact on our consolidated financial statements.

Black Lung Benefit Liabilities

Our independent actuarial consultants calculate the present value of the estimated black lung liability annually based on actuarial models utilizing our population of former coal miners, historical payout patterns of both the Company and the industry, actuarial mortality rates, disability incidence, medical costs, death benefits, dependents, discount rates and the current federally mandated payout rates. The estimated liability may be impacted by future changes in the statutory mechanisms, modifications by court decisions and changes in filing patterns driven by perceptions of success by claimants and their advisors, the impact of which cannot be estimated.

The following table summarizes discount rates utilized, active claims, and the total black lung liabilities:

	December 31,
	2018			2017
Discount rate(1)	4.0		%	3.3		%
Active claims	345			351
Black lung liability (dollars in millions)(2)	$	49.4		$	50.3

(1) The discount rate is determined based on a portfolio of high-quality corporate bonds with maturities that are consistent with the estimated duration of our black lung obligations. A decrease of 25 basis points in the discount rate would have increased black lung expense by $1.1 million in 2018.

(2) The current portion of the black lung liability was $4.5 million and $5.4 million at December 31, 2018 and 2017, respectively, and was included in accrued liabilities on the Consolidated Balance Sheets.

The following table summarizes annual black lung payments and expense:

	Years Ended December 31,
	2018		2017		2016
	(Dollars in millions)
Payments	$	6.3	$	7.4	$	7.8
Expense	$	5.4	$	7.5	$	8.1

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Accumulated Other Comprehensive Loss

12 Months Ended

Dec. 31, 2018

Equity [Abstract]

Accumulated Other Comprehensive Loss

14. Accumulated Other Comprehensive Loss

The following tables set forth the changes in the balance of accumulated other comprehensive loss, net of tax, by component:

	Benefit Plans			Currency Translation Adjustments			Total
	(Dollars in millions)
At December 31, 2016	$	(4.8	)	$	(14.2	)	$	(19.0	)
Other comprehensive loss before reclassifications	—			(0.5		)	(0.5		)
Amounts reclassified from accumulated other comprehensive loss	0.2			—			0.2
Retirement benefit plans funded status adjustment	(0.8		)	—			(0.8		)
Net current period other comprehensive loss	(0.6		)	(0.5		)	(1.1		)
Cumulative effect from adoption of ASU 2018-02(1)	(1.1		)	—			(1.1		)
At December 31, 2017	$	(6.5	)	$	(14.7	)	$	(21.2	)
Other comprehensive loss before reclassifications	—			(1.4		)	(1.4		)
Amounts reclassified from accumulated other comprehensive loss	(0.1		)	—			(0.1		)
Retirement benefit plans funded status adjustment	0.6			—			0.6
Recognition of accumulated currency translation loss upon sale of equity method investment(2)	—			9.0			9.0
Net current period other comprehensive loss	0.5			7.6			8.1
At December 31, 2018	$	(6.0	)	$	(7.1	)	$	(13.1	)

(1) As a result of the Tax Legislation, the Company revalued its deferred tax asset for our postretirement benefit plan for the impact of lower income tax rates, the impact of which was reclassified from accumulated other comprehensive loss to retained earnings.

(2) These accumulated currency translation losses were recognized into income as a result of the sale of our equity method investment in VISA SunCoke.

The tax benefit associated with the Company's benefit plans as of December 31, 2018 and 2017 was $1.8 million and $1.9 million, respectively.

The increase (decrease) on net income due to reclassification adjustments from accumulated other comprehensive income were as follows⁽¹⁾:

	December 31,
	2018			2017			2016
	(Dollars in millions)
Recognition of accumulated currency translation loss upon sale of equity method investment	$	(9.0	)	$	—		$	—
Amortization of benefit plans to net income:(2)
Actuarial loss	$	(0.6	)	$	(0.9	)	$	(0.7	)
Prior service benefit	0.7			0.7			0.7
Total, net of tax(3)	(8.9		)	(0.2		)	—

(1) Amounts in parentheses indicate debits to net income.

(2) These accumulated other comprehensive (income) loss components are included in the computation of postretirement benefit plan expense (benefit) and included in interest expense, net on the Consolidated Statements of Income. See Note 10.

(3) The related tax cost (benefit) was zero for all years presented.

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Share-Based Compensation

12 Months Ended

Dec. 31, 2018

Share-based Compensation [Abstract]

Share-Based Compensation

15. Share-Based Compensation

Equity Classified Awards

Effective July 13, 2011, SunCoke Energy’s Board of Directors approved the SunCoke Energy, Inc. Long-Term Performance Enhancement Plan (“SunCoke LTPEP”). The SunCoke LTPEP provides for the grant of equity-based awards including stock options and share units, or restricted stock, to the Company’s directors, officers, and other employees, advisors, and consultants who are selected by the plan committee for participation in the SunCoke LTPEP.  All awards vest immediately upon a change in control and a qualifying termination of employment as defined by the SunCoke LTPEP. The plan authorizes the issuance of (i) 1,600,000 shares of SunCoke Energy common stock issuable upon the adjustment of Sunoco equity awards in connection with the Separation and Distribution Agreement between Sunoco and SunCoke and (ii) up to 7,500,000 shares, which reflects the 6,000,000 shares initially authorized under the Plan and an additional 1,500,000 shares to be issued under the Plan pursuant to an amendment effective February 14, 2018, of SunCoke Energy common stock pursuant to new awards under the SunCoke LTPEP.

The Company measures the cost of employee services in exchange for an award of equity instruments based on the grant-date fair value of the award. The performance metrics of equity awards are remeasured on a quarterly basis for updates to the probability of achievement. The market metrics of equity awards are not remeasured. The total cost is recognized over the requisite service period. Award forfeitures are accounted for as they occur.

Stock Options

The Company granted the following stock options during the years ended December 31, 2018, 2017 and 2016, with an exercise price equal to the closing price of our common stock on the date of grant:

		Weighted Average Per Share
	No. of Shares	Exercise Price		Weighted Average Grant Date Fair Value
Traditional stock options:
2018 grant	78,447	$	10.49	$	5.38
2017 grant	157,196	$	10.29	$	5.32
2016 March grant	90,925	$	6.03	$	2.78
2016 February grant	95,001	$	3.80	$	1.71
Performance based options:
2017 grant	80,595	$	9.85	$	5.17
2016 March grant	90,925	$	6.03	$	2.42
2016 February grant	58,448	$	3.80	$	1.06

The stock options vest in three equal annual installments beginning one year from the date of grant. In order to become exercisable, the performance based options also require the closing price of the Company's common stock to reach or exceed $14.78 per share for the 2017 grants and $9.50 per share for the February and March 2016 grants for any 15 trading days during the three-year period beginning on the grant date. The February and March 2016 grants met the required stock price performance during 2016. The stock options expire ten years from the date of grant.

The Company calculates the value of each employee stock option, estimated on the date of grant, using the Black-Scholes option pricing model with a Monte Carlo simulation for the performance based options. The weighted-average fair value of employee stock options granted during the years ended December 31, 2018, 2017 and 2016 was based on using the following weighted-average assumptions:

	Years Ended December 31,
	2018		2017		2016
Risk free interest rate	3	%	2	%	1	%
Expected term	6 years		6 years		5 years
Volatility	52	%	53	%	52	%
Dividend yield	—	%	—	%	—	%

The risk-free interest rate assumption is based on the U.S. Treasury yield curve at the date of grant for periods which approximate the expected life of the option. The expected term of the employee options represent the average contractual term adjusted by the average vesting period of each option tranche. We based our expected volatility on our historical volatility over our entire available trading history. The dividend yield assumption is based on the Company’s expectation of dividend payouts at the time of grant.

The following table summarizes information with respect to common stock option awards outstanding as of December 31, 2018 and stock option activity during the fiscal year then ended:

	Number of Options		Weighted Average Exercise Price		Weighted Average Remaining Contractual Term (years)	Aggregate Intrinsic Value (millions)
Outstanding at December 31, 2017	3,146,115		$	15.31	5.6	$	2.8
Granted	78,447		$	10.49
Exercised	(127,107	)	$	6.49
Forfeited	(211,667	)	$	17.07
Outstanding at December 31, 2018	2,885,788		$	15.46	4.8	$	2.1
Exercisable at December 31, 2018	2,546,059		$	16.38	4.1	$	0.4
Expected to vest at December 31, 2018	339,729		$	8.59	8.2	$	0.9

Intrinsic value for stock options is defined as the difference between the current market value of our common stock and the exercise price of the stock options. Total intrinsic value of stock options exercised during 2018 and 2017 was $0.8 million and $0.3 million, respectively. No stock options were exercised during 2016.

Restricted Stock Units

The Company granted the following restricted stock units ("RSUs") during the years ended December 31, 2018 and 2017:

	Shares	Weighted Average Grant-Date Fair Value		Grant Date Fair Value
				(Dollars in millions)
2018 grants	32,128	10.49		$	0.3
2017 grants	22,628	$	9.85	$	0.2

No RSUs were granted during 2016. The RSUs vest in three annual installments beginning one year from the date of grant.

The following table summarizes information with respect to RSUs outstanding as of December 31, 2018 and RSU activity during the fiscal year then ended:

	Number of RSUs		Weighted Average Grant- Date Fair Value
Nonvested at December 31, 2017	106,397		$	13.53
Granted	32,128		$	10.49
Vested	(87,131	)	$	14.27
Forfeited	(4,181	)	$	8.37
Nonvested at December 31, 2018	47,213		$	10.29

Total grant date fair value of RSUs vested was $1.2 million, $2.3 million and $3.7 million during 2018, 2017 and 2016, respectively.

Performance Share Units

The Company grants performance share units ("PSUs"), which represent the right to receive shares of the Company's common stock, contingent upon the attainment of Company performance and market goals and continued employment.

The Company granted the following PSUs during the years ended December 31, 2018 and 2017:

	Shares	Fair Value per Share		Grant Date Fair Value
				(Dollars in millions)
2018 grant(1)	96,389	$	11.36	$	1.1
2017 grant(2)	385,758	$	11.61	$	4.5

(1) The service period for the 2018 PSUs ends on December 31, 2020 and the awards will vest during the first quarter of 2021.

(2) The Company granted 237,610 PSUs in February 2017, for which the service period will end on December 31, 2019, and 148,148 PSUs in December 2017, for which the service period will end on December 31, 2020. These awards will vest during the first quarter of 2020 and 2021, respectively.

The 2018 and 2017 PSU grants were both split 50/50 between the Company's three-year cumulative Adjusted EBITDA performance measure and the Company's three-year average pre-tax return on capital ("ROIC") performance measure for its coke and logistics businesses and unallocated corporate expenses. The number of PSU's ultimately awarded will be determined by the Adjusted EBITDA and ROIC performance versus targets and the Company's three-year total shareholder return ("TSR") as compared to the TSR of the companies making up the Nasdaq Iron & Steel Index ("TSR Modifier"). The TSR Modifier can impact the payout between 50 percent and 150 percent of the Company's final performance measure results. The award may vest between zero and 250 percent of the original units granted. The fair value of the PSUs granted during 2018 and 2017 is based on the closing price of our common stock on the date of grant as well as a Monte Carlo simulation for the valuation of the TSR Modifier.

The Company granted the following PSUs during the year ended December 31, 2016:

	ROIC Portion(1)			TSR Portion(2)			Total
	Shares	Fair Value per Share		Shares	Fair Value per Share		Grant Date Fair Value
							(Dollars in millions)
2016 March grant(3)	67,167	$	10.51	201,500	$	6.35	$	2.0
2016 February grant	105,210	$	5.66	105,210	$	5.81	$	1.2

(1) The number of PSUs that ultimately vest will be determined by the Company's three-year average pre-tax return on capital for the Company's coke and logistics businesses. Additionally, only applicable to the 2016 grants, if at any time during the vesting period the closing price of the Company's common stock equals or exceeds $9.00 per share for any 15 trading days, which was met during 2016, the pre-tax return on capital portion of the award, as adjusted, will be multiplied by two.

(2) The number of PSUs that ultimately vest will be determined by the Company's three-year total shareholder return ("TSR") as compared to the TSR of the companies making up the S&P 600.

(3) The final vesting value of the TSR portion of this award cannot exceed $4.9 million.

Each portion of the award may vest between zero and 200 percent of the original units granted. The fair value of the PSUs granted are based on the closing price of our common stock on the date of grant as well as a Monte Carlo simulation for the portion of the award subject to a market condition. The service period for the 2016 grant ends on December 31, 2018 and the awards will vest during the first quarter of 2019.

The following table summarizes information with respect to unearned PSUs outstanding as of December 31, 2018 and PSU activity during the fiscal year then ended:

	Number of PSUs		Weighted Average Grant- Date Fair Value
Nonvested at December 31, 2017	782,781		$	10.06
Granted	96,389		$	11.36
Vested	(1,710	)	$	16.90
Forfeited	(125,085	)	$	17.59
Nonvested at December 31, 2018	752,375		$	8.86

Liability Classified Awards

Restricted Stock Units Settled in Cash

During the years ended December 31, 2018, 2017 and 2016, the Company issued 108,522, 98,364 and 198,668 restricted stock units to be settled in cash ("Cash RSUs"), respectively, which vest in three annual installments beginning one year from the grant date. The weighted average grant date fair value of the Cash RSUs granted during the years ended December 31, 2018, 2017 and 2016, was $10.71, $9.82 and $3.82, respectively, and was based on the closing price of our common stock on the day of grant. The Cash RSU liability at December 31, 2018 was adjusted based on the closing price of our common stock on December 31, 2018 of $8.55 per share. The cash RSU liability at December 31, 2018 was not material.

Cash Incentive Award

The Company also granted share-based compensation to eligible participants under the SunCoke Energy, Inc. Long-Term Cash Incentive Plan ("SunCoke LTCIP"), which became effective January 1, 2016. The SunCoke LTCIP is designed to provide for performance-based, cash-settled awards. All awards vest immediately upon a change in control and a qualifying termination of employment as defined by the SunCoke LTCIP.

The Company issued a grant date fair value award of $1.0 million, $0.7 million and $0.9 million during the years ended December 31, 2018, 2017 and 2016, respectively, for which the service periods end on December 31, 2021, 2020 and 2019, respectively, and the awards will vests during the first quarter of 2022, 2021 and 2020, respectively. The 2018 and 2017 awards are split 50/50 between the Company's three cumulative Adjusted EBITDA performance and the Company's three-year average pre-tax return on capital performance measure for its coke and logistics businesses and unallocated corporate expense. The ultimate award value will be determined by the performance versus targets and the Company's three year TSR Modifier performance, but will be capped at 250 percent of the target award.

The 2016 award value will be adjusted based upon the Company's three-year average pre-tax return on capital for the Company's coke and logistics businesses, and if at any time during the vesting period the closing price of the Company's common stock equals or exceeds $9.00 per share for any 15 trading days, which was met in 2016, the award, as adjusted, will be multiplied by two, but will be capped at 200 percent of the target award.

The cash incentive award liability at December 31, 2018 was adjusted based on the Company's current performance related to the above awards. The cash incentive award liability at December 31, 2018 was not material.

Summary of Share-Based Compensation Expense

Below is a summary of the compensation expense, unrecognized compensation costs, the period for which the unrecognized compensation cost is expected to be recognized over and the estimated forfeiture rate for each award:

	Years ended December 31,
	2018		2017		2016		2018		2017		2016		December 31, 2018
	Compensation Expense(1)						Net of tax						Unrecognized Compensation Cost		Recognition Period
	(Dollars in millions)												(Dollars in millions)		(Years)
Equity Awards:
Stock Options	$	0.5	$	1.3	$	2.1	$	0.4	$	0.8	$	1.3	$	0.5	1.6
RSUs	0.4		1.1		2.6		0.3		0.7		1.7		$	0.3	1.7
PSUs	1.9		1.9		1.4		1.7		1.2		0.9		$	2.6	1.9
Total equity awards	$	2.8	$	4.3	$	6.1	$	2.4	$	2.7	$	3.9
Liability Awards:
Cash RSUs	$	0.8	$	1.0	$	0.7	$	0.6	$	0.6	$	0.5	$	0.7	1.4
Cash incentive award	0.9		0.2		0.1		0.7		0.1		0.1		$	0.9	1.8
Total liability awards	$	1.7	$	1.2	$	0.8	$	1.3	$	0.7	$	0.6

(1) Compensation expense is recognized by the Company in selling, general and administrative expenses on the Consolidated Statements of Income.

The Company issued $0.3 million, $0.5 million, and $0.4 million of share-based compensation to the Company's Board of Directors during the years ended December 31, 2018, 2017 and 2016, respectively.

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Earnings Per Share

12 Months Ended

Dec. 31, 2018

Earnings Per Share [Abstract]

Earnings Per Share

16. Earnings Per Share

Basic earnings per share (“EPS”) has been computed by dividing net income (loss) available to SunCoke Energy, Inc. by the weighted average number of shares outstanding during the period. Except where the result would be anti-dilutive, diluted earnings per share has been computed to give effect to share-based compensation awards using the treasury stock method.

The following table sets forth the reconciliation of the weighted-average number of common shares used to compute basic earnings per share to those used to compute diluted EPS:

	Years Ended December 31,
	2018	2017	2016
	(Shares in millions)
Weighted-average number of common shares outstanding-basic	64.7	64.3	64.2
Add: effect of dilutive share-based compensation awards	0.8	0.9	0.2
Weighted-average number of shares-diluted	65.5	65.2	64.4

The following table shows stock options, restricted stock units, and performance stock units that are excluded from the computation of diluted earnings per share as the shares would have been anti-dilutive:

	Years Ended December 31,
	2018	2017	2016
	(Shares in millions)
Stock options	2.7	2.9	3.0
Restricted stock units	—	—	0.2
Performance stock units	0.1	0.1	0.2
Total	2.8	3.0	3.4

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Fair Value Measurements

12 Months Ended

Dec. 31, 2018

Fair Value Disclosures [Abstract]

Fair Value Measurements

17. Fair Value Measurements

The Company measures certain financial and non-financial assets and liabilities at fair value on a recurring basis. Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in the principal or most advantageous market in an orderly transaction between market participants on the measurement date. Fair value disclosures are reflected in a three-level hierarchy, maximizing the use of observable inputs and minimizing the use of unobservable inputs.

The valuation hierarchy is based upon the transparency of inputs to the valuation of an asset or liability on the measurement date. The three levels are defined as follows:

• Level 1—inputs to the valuation methodology are quoted prices (unadjusted) for an identical asset or liability in an active market.

• Level 2—inputs to the valuation methodology include quoted prices for a similar asset or liability in an active market or model-derived valuations in which all significant inputs are observable for substantially the full term of the asset or liability.

• Level 3—inputs to the valuation methodology are unobservable and significant to the fair value measurement of the asset or liability.

Financial Assets and Liabilities Measured at Fair Value on a Recurring Basis

Cash Equivalents

Certain assets and liabilities are measured at fair value on a recurring basis. The Company’s cash equivalents, which amounted to $3.2 million and $5.5 million at December 31, 2018 and 2017, respectively, were measured at fair value based on quoted prices in active markets for identical assets. These inputs are classified as Level 1 within the valuation hierarchy.

CMT Contingent Consideration

In connection with the CMT acquisition, the Partnership entered into a contingent consideration arrangement that runs through 2022 and requires the Partnership to make future payments to The Cline Group based on future volume over a specified threshold, price and contract renewals.The fair value of the contingent consideration was estimated based on a probability-weighted analysis using significant inputs that are not observable in the market, or Level 3 inputs. Key assumptions included probability adjusted levels of handling services provided by CMT, anticipated price per ton on future sales and probability of contract renewal, including length of future contracts, volume commitment, and anticipated price per ton. The fair value of the contingent consideration was $5.0 million and $2.5 million at December 31, 2018 and 2017, respectively, and was primarily included in other deferred credits and liabilities on the Consolidated Balance Sheets. 

During 2018, CMT achieved record volumes and the Partnership increased CMT’s throughput volume projections in future periods for certain customers due to favorable coal prices, which are expected to increase export volume through CMT. The combined impact of the strong 2018 volumes and improved volume projections resulted in an increase to the fair value of the Partnership's contingent consideration balance of $2.5 million, which was recorded as a charge to costs of products sold and operating expenses in the Consolidated Statements of Income during 2018.

During 2017 and 2016, as a result of adverse mining conditions faced by one of our thermal coal customers, as well as fluctuating export coal pricing, the Partnership lowered CMT's throughput volume, which reduced the Partnership's contingent consideration liability balance by $1.7 million and $6.4 million, respectively. Additionally, during March 2016, as a part of commercial activities subsequent to the acquisition of CMT, the Partnership and The Cline Group signed an amended agreement, which modified the contingent consideration terms by increasing the volume threshold required for the Partnership to make payments to The Cline Group in exchange for future pricing modifications, resulting in a $3.7 million reduction to the contingent consideration liability. These decreases in fair value were recorded as reductions to costs of products sold and operating expenses on the Consolidated Statements of Income during 2017 and 2016.

Certain Financial Assets and Liabilities not Measured at Fair Value

At December 31, 2018 and 2017, the fair value of the Company’s long-term debt was estimated to be $822.8 million and $919.7 million, respectively, compared to a carrying amount of $859.0 million and $887.3 million, respectively. These fair values were estimated by management based upon estimates of debt pricing provided by financial institutions which are considered Level 2 inputs.

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Revenue from Contracts with Customers

12 Months Ended

Dec. 31, 2018

Revenue from Contract with Customer [Abstract]

Revenue from Contracts with Customers

18. Revenue from Contracts with Customers

Cokemaking

Substantially all our coke sales are made pursuant to long-term, take-or-pay agreements with AM USA, AK Steel and U.S. Steel, who are three of the largest blast furnace steelmakers in North America. The take-or-pay provisions of our agreements require us to deliver minimum annual tonnage, which varies by contract, but covers at least 90 percent of each facility's nameplate capacity. The take-or-pay provisions also require our customers to purchase such volumes of coke or pay the contract price for any tonnage they elect not to take. These coke sales agreements have an average remaining term of approximately six years, and to date, our coke customers have satisfied their obligations under these agreements.

Our coke sales prices include an operating cost component, a coal cost component and a return of capital component. Operating costs under two of our coke sales agreements are contractual, subject to an annual adjustment based on an inflation index. Under our other four coke sales agreements operating costs are passed through to the respective customers subject to an annually negotiated budget, in some cases subject to a cap annually adjusted for inflation, and generally we share any difference in costs from the budgeted amounts with our customers. Our coke sales agreements contain pass-through provisions for coal and coal procurement costs, subject to meeting contractual coal-to-coke yields. To the extent that the actual coal-to-coke yields are less than the contractual standard, we are responsible for the cost of the excess coal used in the cokemaking process. Conversely, to the extent our actual coal-to-coke yields are higher than the contractual standard, we realize gains. The reimbursement of pass-through operating and coal costs from these coke sales agreements are considered to be variable consideration components included in the cokemaking sales price. The return of capital component for each ton of coke sold to the customer is determined at the time the coke sales agreement is signed and is effective for the term of each sales agreement. This component of our coke sales prices is intended to provide an adequate return on invested capital and may differ based on investment levels and other considerations. The actual return on invested capital at any facility is also impacted by favorable or unfavorable performance on pass-through cost items. Revenues are recognized when performance obligations to our customers are satisfied in an amount that reflects the consideration that we expect to receive in exchange for the coke.

Logistics

In our logistics business, handling and/or mixing services are provided to steel, coke (including some of our domestic cokemaking facilities), electric utility, coal producing and other manufacturing based customers. Materials are transported in numerous ways, including rail, truck, barge or ship. We do not take possession of materials handled, but rather act as intermediaries between our customers and end users, deriving our revenues from services provided on a per ton basis. The handling and mixing services consist primarily of two performance obligations, unloading and loading of materials. Our logistics business has long-term, take-or-pay agreements requiring us to handle over 13 million tons annually. The take-or-pay provisions in these agreements require our customers to purchase such handling services or pay the contract price for services they elect not to take. Estimated take-or-pay revenue of approximately $305 million from all of our long-term logistics contracts is expected to be recognized over the next five years for unsatisfied or partially unsatisfied performance obligations as of December 31, 2018. To date, our customers have satisfied their obligations under these agreements. Included with these long-term, take-or-pay arrangements are our contracts with Murray and Foresight, which cover 10 million tons of CMT's annual transloading capacity of 15 million tons. Revenues are recognized when the customer receives the benefits of the services provided, in an amount that reflects the consideration that we will receive in exchange for those services. Billings to CMT customers for take-or-pay volume shortfalls based on pro-rata volume commitments under take-or-pay contracts that are in excess of billings earned for services provided are recorded as contract liabilities and characterized as deferred revenue on the Consolidated Balance Sheets. Deferred revenue is recognized at the earliest of i) when the performance obligation is satisfied; ii) when the performance obligation has expired, based on the terms of the contract; or iii) when the likelihood that the customer would exercise its right to the performance obligation becomes remote.

The following table provides changes in the Company's deferred revenue:

	2018			2017
	(Dollars in millions)
Beginning balance at December 31, 2017 and 2016, respectively	$	1.7		$	2.5
Reclassification of the beginning contract liabilities to revenue, as a result of performance obligation satisfied	(1.4		)	(2.1		)
Billings in excess of services performed, not recognized as revenue	2.7			1.3
Ending balance at December 31, 2018 and 2017, respectively	$	3.0		$	1.7

Energy

Our energy sales are made pursuant to either steam or energy supply and purchase agreements or is sold into the regional power market. Our cokemaking ovens utilize efficient, modern heat recovery technology designed to combust the coal’s volatile components liberated during the cokemaking process and use the resulting heat to create steam or electricity for sale. The energy provided under these arrangements result in transfer of control over time. Revenues are recognized over time as energy is delivered to our customers, in an amount based on the terms of each arrangement.

Operating and Licensing Fees

Operating and licensing fees are made pursuant to long-term contracts with ArcelorMittal Brazil, where we operate a Brazilian cokemaking facility. The licensing fees are based upon the level of production required by our customer as well as a fixed annual fee. Operating fees include the full pass-through of the operating costs of the Brazilian facility as well as a per ton fee based on the level of production required by our customer. Revenues are recognized over time as our customers receive and consume the benefits in an amount that corresponds directly with the value provided to the customer to date.

Disaggregated Sales and Other Operating Revenue

The following table provides disaggregated sales and other operating revenue by product or service, excluding intersegment revenues:

	Years Ended December 31,
	2018		2017		2016
	(Dollars in millions)
Sales and other operating revenue:
Cokemaking	$	1,250.5	$	1,140.8	$	1,038.2
Energy	49.7		53.2		54.3
Logistics	101.0		89.7		82.9
Operating and licensing fees	40.4		43.4		39.5
Other	9.3		4.4		8.4
Sales and other operating revenue	$	1,450.9	$	1,331.5	$	1,223.3

Disaggregated sales and other operating revenue by customer is discussed in Note 4.

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Business Segment Information

12 Months Ended

Dec. 31, 2018

Segment Reporting [Abstract]

Business Segment Information

19. Business Segment Information

The Company reports its business through three segments: Domestic Coke, Brazil Coke and Logistics. The Domestic Coke segment includes the Jewell, Indiana Harbor, Haverhill, Granite City and Middletown cokemaking facilities. Each of these facilities produces coke, and all facilities except Jewell recover waste heat, which is converted to steam or electricity through a similar production process.

The Brazil Coke segment includes the licensing and operating fees payable to us under long-term contracts with ArcelorMittal Brazil, under which we operate a cokemaking facility located in Vitória, Brazil through at least 2023.

Logistics operations are comprised of CMT, KRT, Lake Terminal, which provides services to our Indiana Harbor cokemaking facility, and DRT, which provides services to our Jewell cokemaking facility. Handling and mixing results are presented in the Logistics segment.

Corporate expenses that can be identified with a segment have been included in determining segment results. The remainder is included in Corporate and Other. Corporate and Other also includes activity from our legacy coal mining business.

Segment assets are those assets utilized within a specific segment and exclude taxes.

The following table includes Adjusted EBITDA, which is the measure of segment profit or loss and liquidity reported to the chief operating decision maker for purposes of allocating resources to the segments and assessing their performance:

	Years Ended December 31,
	2018			2017			2016
	(Dollars in millions)
Sales and other operating revenue:
Domestic Coke	$	1,308.3		$	1,195.0		$	1,097.6
Brazil Coke	40.4			43.4			39.5
Logistics	102.2			93.1			84.7
Logistics intersegment sales	24.5			23.8			23.2
Corporate and Other(1)	—			—			1.5
Corporate and Other intersegment sales(1)	—			—			22.0
Elimination of intersegment sales	(24.5		)	(23.8		)	(45.2		)
Total sales and other operating revenue	$	1,450.9		$	1,331.5		$	1,223.3
Adjusted EBITDA
Domestic Coke	$	207.9		$	188.9		$	193.9
Brazil Coke	18.4			18.2			16.2
Logistics	72.6			70.8			63.9
Corporate and Other(2)	(35.7		)	(43.2		)	(57.0		)
Total Adjusted EBITDA	$	263.2		$	234.7		$	217.0
Depreciation and amortization expense:
Domestic Coke(3)	$	114.4		$	102.6		$	84.0
Brazil Coke	0.7			0.7			0.7
Logistics	25.1			24.4			24.8
Corporate and Other	1.4			0.5			4.7
Total depreciation and amortization expense	$	141.6		$	128.2		$	114.2
Capital expenditures:
Domestic Coke	$	95.1		$	68.8		$	44.6
Logistics	5.2			4.4			17.4
Corporate and Other	—			2.4			1.7
Total capital expenditures	$	100.3		$	75.6		$	63.7

(1) Corporate and Other revenues are related to our legacy coal mining business, which was disposed in April 2016.

(2) Corporate and Other includes the activity from our legacy coal mining business, which incurred Adjusted EBITDA losses of $9.8 million, $10.5 million, and $15.0 million for the years ended December 31, 2018, 2017 and 2016, respectively.

(3) We revised the estimated useful lives of certain assets in our Domestic Coke segment, primarily as a result of plans to replace major components of certain heat recovery steam generators with upgraded materials and design, resulting in additional depreciation of $9.2 million, or $0.14 per common share, during the year ended December 31, 2018.

The following table sets forth the Company’s segment assets:

	December 31,
	2018		2017
	(Dollars in millions)
Segment assets
Domestic Coke	$	1,446.5	$	1,439.7
Brazil Coke	15.1		10.9
Logistics	463.0		491.9
Corporate and Other	120.0		112.8
Segment assets, excluding income tax receivable	2,044.6		2,055.3
Tax assets	0.7		4.8
Total assets	$	2,045.3	$	2,060.1

The Company evaluates the performance of its segments based on segment Adjusted EBITDA, which is defined as earnings before interest, (gain) loss on extinguishment of debt, taxes, depreciation and amortization (“EBITDA”), adjusted for impairments, coal rationalization costs, changes to our contingent consideration liability related to our acquisition of CMT, the expiration of certain acquired contractual obligations, and loss on disposal of our interest in VISA SunCoke. EBITDA and Adjusted EBITDA do not represent and should not be considered alternatives to net income or operating income under GAAP and may not be comparable to other similarly titled measures in other businesses.

Management believes Adjusted EBITDA is an important measure of the operating performance and liquidity of the Company's net assets and its ability to incur and service debt, fund capital expenditures and make distributions. Adjusted EBITDA provides useful information to investors because it highlights trends in our business that may not otherwise be apparent when relying solely on GAAP measures and because it eliminates items that have less bearing on our operating performance and liquidity. EBITDA and Adjusted EBITDA are not measures calculated in accordance with GAAP, and they should not be considered a substitute for net income, operating cash flow or any other measure of financial performance presented in accordance with GAAP. Set forth below is additional discussion of the limitations of Adjusted EBITDA as an analytical tool.

Limitations. Other companies may calculate Adjusted EBITDA differently than we do, limiting its usefulness as a comparative measure. Adjusted EBITDA also has limitations as an analytical tool and should not be considered in isolation or as a substitute for an analysis of our results as reported under GAAP. Some of these limitations include that Adjusted EBITDA:

• does not reflect our cash expenditures, or future requirements, for capital expenditures or contractual commitments;

• does not reflect items such as depreciation and amortization;

• does not reflect changes in, or cash requirement for, working capital needs;

• does not reflect our interest expense, or the cash requirements necessary to service interest on or principal payments of our debt;

• does not reflect certain other non-cash income and expenses

• excludes income taxes that may represent a reduction in available cash; and

• includes net income attributable to noncontrolling interests

Below are reconciliations of Adjusted EBITDA to net income and Adjusted EBITDA to net cash provided by operating activities, which are its most directly comparable financial measures calculated and presented in accordance with GAAP:

	Years Ended December 31,
	2018			2017			2016
	(Dollars in millions)
Net cash provided by operating activities	$	185.8		$	148.5		$	219.1
Subtract:
Depreciation and amortization expense	141.6			128.2			114.2
Deferred income tax (benefit) expense	(3.4		)	(87.2		)	3.1
Loss (gain) on extinguishment of debt	0.3			20.4			(25.0		)
Loss on divestiture of business	—			—			14.7
Loss from equity method investment	5.4			—			—
Changes in working capital and other	(5.1		)	(16.4		)	52.6
Net income	$	47.0		$	103.5		$	59.5
Add:
Depreciation and amortization expense	141.6			128.2			114.2
Interest expense, net(1)	61.4			60.6			53.5
Loss (gain) on extinguishment of debt	0.3			20.4			(25.0		)
Income tax expense (benefit)	4.6			(81.6		)	8.6
Contingent consideration adjustments(2)	2.5			(1.7		)	(10.1		)
Transaction costs(3)	0.4			—			—
Expiration of land deposits and write-off of costs related to potential new cokemaking facility(4)	—			5.3			1.9
Non-cash reversal of acquired contractual obligation(5)	—			—			(0.7		)
Loss on divestiture of business	—			—			14.7
Coal rationalization costs(6)	—			—			0.4
Loss from equity method investment	5.4			—			—
Adjusted EBITDA	$	263.2		$	234.7		$	217.0
Subtract: Adjusted EBITDA attributable to noncontrolling interest(7)	82.0			86.4			86.6
Adjusted EBITDA attributable to SunCoke Energy, Inc.	$	181.2		$	148.3		$	130.4

(1) In conjunction with the adoption of ASU 2017-07, the non-service type expense associated with the postretirement benefit plans was excluded from operating income and recorded in interest expense, net on the Consolidated Statements of Income during the periods presented. Amounts in prior periods were immaterial, and therefore, were not reclassified in the reconciliation of Adjusted EBITDA to net income and net cash provided by operating activities.

(2) Adjustments to the fair value of the contingent consideration in 2018, 2017 and 2016 were primarily the result of modifications to the volume forecast. See Note 17.

(3) Represents costs incurred in connection with the Simplification Transaction.

(4) In 2014, we finalized the required permitting and engineering plan for a potential new cokemaking facility, however, the project was terminated. As a result, during 2017 and 2016, the Company wrote-off previously capitalized engineering costs and land deposits for a potential new cokemaking facility of $5.3 million and $1.9 million, respectively. These costs were included in selling, general and administrative expenses on the Consolidated Statements of Income.

(5) In association with the acquisition of CMT, we assumed certain performance obligations under existing contracts and recorded liabilities related to such obligations. In 2016, the Partnership reversed the liability as we no longer had any obligations under the contracts.

(6) Prior to the divestiture of our coal mining business, the Company incurred coal rationalization costs including employee severance, contract termination costs and other costs to idle mines during the execution of our coal rationalization plan.

(7) Reflects noncontrolling interests in Indiana Harbor and the portion of the Partnership owned by public unitholders.

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Selected Quarterly Data (unaudited)

12 Months Ended

Dec. 31, 2018

Quarterly Financial Information Disclosure [Abstract]

Selected Quarterly Data (unaudited)

20. Selected Quarterly Data (unaudited)

	2018								2017
	First Quarter		Second Quarter		Third Quarter		Fourth Quarter(1)		First Quarter(2)			Second Quarter(3)			Third Quarter		Fourth Quarter(1)(4)
	(Dollars in millions)
Sales and other operating revenue	$	350.5	$	367.0	$	364.5	$	368.9	$	309.7		$	323.2		$	339.0	$	359.6
Gross profit(5)	$	47.0	$	52.3	$	45.8	$	39.7	$	42.2		$	32.9		$	51.3	$	56.8
Net income (loss)	$	13.0	$	11.4	$	17.1	$	5.5	$	(57.7	)	$	(31.5	)	$	18.8	$	173.9
Less: Net income (loss) attributable to noncontrolling interests	$	4.3	$	7.2	$	5.6	$	3.7	$	(58.7	)	$	(7.3	)	$	7.2	$	39.9
Net income (loss) attributable to SunCoke Energy, Inc.	$	8.7	$	4.2	$	11.5	$	1.8	$	1.0		$	(24.2	)	$	11.6	$	134.0
Earnings (loss) attributable to SunCoke Energy, Inc. per common share:
Basic(6)	$	0.13	$	0.06	$	0.18	$	0.03	$	0.02		$	(0.38	)	$	0.18	$	2.08
Diluted(6)	$	0.13	$	0.06	$	0.18	$	0.03	$	0.02		$	(0.38	)	$	0.18	$	2.05

(1) The Partnership recognized deferred revenue from Logistics take-or-pay billings for minimum volume shortfalls of $16.4 million into revenue in the fourth quarter of 2017. As a result of the increase in tons handled throughout 2018, there were no shortfalls to be recognized during the fourth quarter.

(2) The first quarter of 2017 reflects the net impact to the Company’s deferred tax expense of $64.2 million related to the IRS Final Regulations on qualifying income all of which was attributable to unitholders of the Partnership. See Note 5.

(3) During the second quarter of 2017, the Partnership incurred $20.2 million of losses in connection with debt refinancing.

(4) During the fourth quarter of 2017, the Company recorded $154.7 million of tax benefits as a result of the new Tax Legislation, $125.0 million of which was attributable to the Company. See Note 5.

(5) Gross profit equals sales and other operating revenue less cost of products sold and operating expenses and depreciation and amortization.

(6) Basic and diluted earnings per share are computed independently for each of the quarters presented. Therefore, the sum of quarterly basic and diluted per share information may not equal annual basic and diluted earnings per share.

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Supplemental Condensed Combining and Consolidating Financial Information

12 Months Ended

Dec. 31, 2018

Condensed Financial Information Disclosure [Abstract]

Supplemental Condensed Combining and Consolidating Financial Information

21. Supplemental Condensed Combining and Consolidating Financial Information

Certain 100 percent owned subsidiaries of the Company serve as guarantors of the obligations under the Credit Agreement (“Guarantor Subsidiaries”). These guarantees are full and unconditional (subject, in the case of the Guarantor Subsidiaries, to customary release provisions as described below) and joint and several. For purposes of the following information, SunCoke Energy is referred to as “Issuer.” The indenture dated July 26, 2011 among the Company, the guarantors party thereto and The Bank of New York Mellon Trust Company, N.A., governs subsidiaries designated as “Guarantor Subsidiaries.” All other consolidated subsidiaries of the Company are collectively referred to as “Non-Guarantor Subsidiaries.”

The ability of the Partnership and Indiana Harbor to pay dividends and make loans to the Company is restricted under the partnership agreements of the Partnership and Indiana Harbor, respectively. The credit agreement governing the Partnership’s credit facility and the indenture governing the Partnership Notes contain customary provisions which would potentially restrict the Partnership’s ability to make distributions or loans to the Company under certain circumstances. For the year ended December 31, 2018, less than 25 percent of net assets were restricted. Additionally, certain coal mining entities are designated as unrestricted subsidiaries. As such, all the subsidiaries described above are presented as "Non-Guarantor Subsidiaries."

The guarantee of a Guarantor Subsidiary will terminate upon:

• a sale or other disposition of the Guarantor Subsidiary or of all or substantially all of its assets;

• a sale of the majority of the Capital Stock of a Guarantor Subsidiary to a third-party, after which the Guarantor Subsidiary is no longer a "Restricted Subsidiary" in accordance with the indenture governing the Notes;

• the liquidation or dissolution of a Guarantor Subsidiary so long as no "Default" or "Event of Default", as defined under the indenture governing the Notes, has occurred as a result thereof;

• the requirements for defeasance or discharge of the indentures governing the Notes having been satisfied; or

• the release, other than the discharge through payments by a Guarantor Subsidiary, from its guarantee under the Credit Agreement or other indebtedness that resulted in the obligation of the Guarantor Subsidiary under the indenture governing the Notes

The following supplemental condensed combining and consolidating financial information reflects the Issuer’s separate accounts, the combined accounts of the Guarantor Subsidiaries, the combined accounts of the Non-Guarantor Subsidiaries, the combining and consolidating adjustments and eliminations and the Issuer’s consolidated accounts for the dates and periods indicated. For purposes of the following condensed combining and consolidating information, the Issuer’s investments in its subsidiaries and the Guarantor and Non-Guarantor Subsidiaries’ investments in its subsidiaries are accounted for under the equity method of accounting.

SunCoke Energy, Inc.

Condensed Consolidating Statement of Income

Years Ended December 31, 2018

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Revenues
Sales and other operating revenue	$	—		$	216.0		$	1,239.5		$	(4.6	)	$	1,450.9
Equity in earnings of subsidiaries	34.3			25.2			—			(59.5		)	—
Total revenues, net of equity in earnings of subsidiaries	34.3			241.2			1,239.5			(64.1		)	1,450.9
Costs and operating expenses
Cost of products sold and operating expenses	—			165.7			963.4			(4.6		)	1,124.5
Selling, general and administrative expenses	6.5			11.8			47.8			—			66.1
Depreciation and amortization expenses	—			8.8			132.8			—			141.6
Total costs and operating expenses	6.5			186.3			1,144.0			(4.6		)	1,332.2
Operating income	27.8			54.9			95.5			(59.5		)	118.7
Interest (income) expense, net - affiliate	—			(6.0		)	6.0			—			—
Interest expense (income), net	3.1			(1.6		)	59.9			—			61.4
Total interest expense (income), net	3.1			(7.6		)	65.9			—			61.4
Loss on extinguishment of debt	0.3			—			—			—			0.3
Income before income tax (benefit) expense	24.4			62.5			29.6			(59.5		)	57.0
Income tax (benefit) expense	(1.8		)	12.1			(5.7		)	—			4.6
Loss from equity method investment	—			—			5.4			—			5.4
Net income	26.2			50.4			29.9			(59.5		)	47.0
Less: Net income attributable to noncontrolling interests	—			—			20.8			—			20.8
Net income attributable to SunCoke Energy, Inc.	$	26.2		$	50.4		$	9.1		$	(59.5	)	$	26.2
Comprehensive income	$	34.3		$	50.6		$	37.8		$	(67.6	)	$	55.1
Less: Comprehensive income attributable to noncontrolling interests	—			—			20.8			—			20.8
Comprehensive income attributable to SunCoke Energy, Inc.	$	34.3		$	50.6		$	17.0		$	(67.6	)	$	34.3

SunCoke Energy, Inc.

Condensed Consolidating Statement of Income

Years Ended December 31, 2017

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Revenues
Sales and other operating revenue	$	—		$	209.6		$	1,126.3		$	(4.4	)	$	1,331.5
Equity in earnings (loss) of subsidiaries	109.9			(54.5		)	—			(55.4		)	—
Total revenues, net of equity in earnings (loss) of subsidiaries	109.9			155.1			1,126.3			(59.8		)	1,331.5
Costs and operating expenses
Cost of products sold and operating expenses	—			156.6			867.9			(4.4		)	1,020.1
Selling, general and administrative expenses	8.7			22.7			47.6			—			79.0
Depreciation and amortization expenses	—			7.5			120.7			—			128.2
Total costs and operating expenses	8.7			186.8			1,036.2			(4.4		)	1,227.3
Operating income (loss)	101.2			(31.7		)	90.1			(55.4		)	104.2
Interest (income) expense, net - affiliate	—			(7.5		)	7.5			—			—
Interest expense, net	4.9			0.1			56.9			—			61.9
Total interest expense (income), net	4.9			(7.4		)	64.4			—			61.9
Gain on extinguishment of debt	0.4			—			20.0			—			20.4
Income (loss) before income tax (benefit) expense	95.9			(24.3		)	5.7			(55.4		)	21.9
Income tax (benefit) expense	(26.5		)	(150.2		)	95.1			—			(81.6		)
Net income (loss)	122.4			125.9			(89.4		)	(55.4		)	103.5
Less: Net loss attributable to noncontrolling interests	—			—			(18.9		)	—			(18.9		)
Net income (loss) attributable to SunCoke Energy, Inc.	$	122.4		$	125.9		$	(70.5	)	$	(55.4	)	$	122.4
Comprehensive income (loss)	$	121.3		$	125.3		$	(91.0	)	$	(53.2	)	$	102.4
Less: Comprehensive loss attributable to noncontrolling interests	—			—			(18.9		)	—			(18.9		)
Comprehensive income (loss) attributable to SunCoke Energy, Inc.	$	121.3		$	125.3		$	(72.1	)	$	(53.2	)	$	121.3

SunCoke Energy, Inc.

Condensed Consolidating Statement of Income

Years Ended December 31, 2016

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Revenues
Sales and other operating revenue	$	—		$	176.7		$	1,050.5		$	(3.9	)	$	1,223.3
Equity in earnings of subsidiaries	19.7			51.3			—			(71.0		)	—
Total revenues, net of equity in earnings of subsidiaries	19.7			228.0			1,050.5			(74.9		)	1,223.3
Costs and operating expenses
Cost of products sold and operating expenses	—			130.7			779.1			(3.9		)	905.9
Selling, general and administrative expenses	12.9			25.6			52.1			—			90.6
Depreciation and amortization expenses	—			9.2			105.0			—			114.2
Loss on divestiture of business and impairments	—			—			14.7			—			14.7
Total costs and operating expenses	12.9			165.5			950.9			(3.9		)	1,125.4
Operating income	6.8			62.5			99.6			(71.0		)	97.9
Interest (income) expense, net - affiliate	—			(7.6		)	7.6			—			—
Interest expense, net	6.0			0.3			48.5			—			54.8
Total interest expense (income), net	6.0			(7.3		)	56.1			—			54.8
Gain on extinguishment of debt, net	—			—			(25.0		)	—			(25.0		)
Income before income tax (benefit) expense and loss (gain) from equity method investment	0.8			69.8			68.5			(71.0		)	68.1
Income tax (benefit) expense	(13.6		)	38.7			(16.5		)	—			8.6
Net income	14.4			31.1			85.0			(71.0		)	59.5
Less: Net income attributable to noncontrolling interests	—			—			45.1			—			45.1
Net income attributable to SunCoke Energy, Inc.	$	14.4		$	31.1		$	39.9		$	(71.0	)	$	14.4
Comprehensive income	$	15.2		$	30.8		$	86.1		$	(71.8	)	$	60.3
Less: Comprehensive income attributable to noncontrolling interests	—			—			45.1			—			45.1
Comprehensive income attributable to SunCoke Energy, Inc.	$	15.2		$	30.8		$	41.0		$	(71.8	)	$	15.2

SunCoke Energy, Inc.

Condensed Consolidating Balance Sheet

December 31, 2018

(Dollars in millions, except per share amounts)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Assets
Cash and cash equivalents	$	—		$	123.2		$	22.5		$	—		$	145.7
Receivables	—			13.3			62.1			—			75.4
Inventories	—			10.6			99.8			—			110.4
Income tax receivable	—			—			96.1			(95.4		)	0.7
Other current assets	—			1.8			1.0			—			2.8
Advances to affiliates	—			281.1			—			(281.1		)	—
Total current assets	—			430.0			281.5			(376.5		)	335.0
Notes receivable from affiliate	—			—			200.0			(200.0		)	—
Properties, plants and equipment, net	—			54.3			1,416.8			—			1,471.1
Goodwill	—			3.4			73.5			—			76.9
Other intangibles assets, net	—			1.1			155.7			—			156.8
Deferred income taxes	7.0			—			—			(7.0		)	—
Deferred charges and other assets	—			5.1			0.4			—			5.5
Total assets	$	7.0		$	493.9		$	2,127.9		$	(583.5	)	$	2,045.3
Liabilities and Equity
Advances from affiliate	$	167.3		$	—		$	113.8		$	(281.1	)	$	—
Accounts payable	—			14.7			100.3			—			115.0
Accrued liabilities	1.8			13.7			30.1			—			45.6
Deferred revenue	—			—			3.0			—			3.0
Current portion of long-term debt and financing obligation	1.1			—			2.8			—			3.9
Interest payable	0.4			—			3.2			—			3.6
Income taxes payable	1.9			93.5			—			(95.4		)	—
Total current liabilities	172.5			121.9			253.2			(376.5		)	171.1
Long term-debt and financing obligation	41.2			—			793.3			—			834.5
Payable to affiliate	—			200.0			—			(200.0		)	—
Accrual for black lung benefits	—			10.9			34.0			—			44.9
Retirement benefit liabilities	—			12.2			13.0			—			25.2
Deferred income taxes	—			194.9			66.8			(7.0		)	254.7
Asset retirement obligations	—			—			14.6			—			14.6
Other deferred credits and liabilities	3.5			6.6			7.5			—			17.6
Total liabilities	217.2			546.5			1,182.4			(583.5		)	1,362.6
Equity
Preferred stock, $0.01 par value. Authorized 50,000,000 shares; no issued and outstanding shares at December 31, 2018	—			—			—			—			—
Common stock, $0.01 par value. Authorized 300,000,000 shares; issued 72,223,750 shares at December 31, 2018	0.7			—			—			—			0.7
Treasury stock, 7,477,657 shares at December 31, 2018	(140.7		)	—			—						(140.7		)
Additional paid-in capital	488.9			61.0			612.8			(673.9		)	488.8
Accumulated other comprehensive loss	(13.1		)	(2.0		)	(11.1		)	13.1			(13.1		)
Retained earnings	127.5			526.1			124.2			(650.4		)	127.4
Equity investment eliminations	(673.5		)	(637.7		)	—			1,311.2			—
Total SunCoke Energy, Inc. stockholders’ equity	(210.2		)	(52.6		)	725.9			—			463.1
Noncontrolling interests	—			—			219.6			—			219.6
Total equity	(210.2		)	(52.6		)	945.5			—			682.7
Total liabilities and equity	$	7.0		$	493.9		$	2,127.9		$	(583.5	)	$	2,045.3

SunCoke Energy, Inc.

Condensed Consolidating Balance Sheet

December 31, 2017

(Dollars in millions, except per share amounts)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Assets
Cash and cash equivalents	$	—		$	103.6		$	16.6		$	—		$	120.2
Receivables	—			17.1			51.4			—			68.5
Inventories	—			9.1			101.9			—			111.0
Income taxes receivable	—			—			88.1			(83.3		)	4.8
Other current assets	—			4.6			2.1			—			6.7
Advances to affiliate	—			245.8			—			(245.8		)	—
Total current assets	—			380.2			260.1			(329.1		)	311.2
Notes receivable from affiliate	—			89.0			300.0			(389.0		)	—
Properties, plants and equipment, net	—			59.8			1,441.5			—			1,501.3
Goodwill	—			3.4			73.5			—			76.9
Other intangible assets, net	—			1.7			166.2			—			167.9
Deferred income taxes	7.1			—			—			(7.1		)	—
Deferred charges and other assets	—			2.3			0.5			—			2.8
Total assets	$	7.1		$	536.4		$	2,241.8		$	(725.2	)	$	2,060.1
Liabilities and Equity
Advances from affiliate	$	162.2		$	—		$	83.6		$	(245.8	)	$	—
Accounts payable	—			16.4			99.1			—			115.5
Accrued liabilities	1.5			19.7			32.0			—			53.2
Deferred Revenue	—			—			1.7			—			1.7
Current portion of long-term debt and financing obligation	—			—			2.6			—			2.6
Interest payable	1.4			—			4.0			—			5.4
Income taxes payable	1.9			81.4			—			(83.3		)	—
Total current liabilities	167.0			117.5			223.0			(329.1		)	178.4
Long-term debt and financing obligation	42.7			—			818.4			—			861.1
Payable to affiliate	—			300.0			89.0			(389.0		)	—
Accrual for black lung benefits	—			11.8			33.1			—			44.9
Retirement benefit liabilities	—			13.7			14.5			—			28.2
Deferred income taxes	—			193.8			71.1			(7.1		)	257.8
Asset retirement obligations	—			—			14.0			—			14.0
Other deferred credits and liabilities	3.7			6.4			6.0			—			16.1
Total liabilities	213.4			643.2			1,269.1			(725.2		)	1,400.5
Equity
Preferred stock, $0.01 par value. Authorized 50,000,000 shares; no issued and outstanding shares at December 31, 2017	—			—			—			—			—
Common stock, $0.01 par value. Authorized 300,000,000 shares; issued 71,707,304 shares at December 31, 2017	0.7			—			—			—			0.7
Treasury stock, 7,477,657 shares at December 31, 2017	(140.7		)	—			—			—			(140.7		)
Additional paid-in capital	486.2			141.0			641.9			(782.9		)	486.2
Accumulated other comprehensive loss	(21.2		)	(2.2		)	(19.0		)	21.2			(21.2		)
Retained earnings	101.2			475.6			116.4			(592.0		)	101.2
Equity investment eliminations	(632.5		)	(721.2		)	—			1,353.7			—
Total SunCoke Energy, Inc. stockholders’ equity	(206.3		)	(106.8		)	739.3			—			426.2
Noncontrolling interests	—			—			233.4			—			233.4
Total equity	(206.3		)	(106.8		)	972.7			—			659.6
Total liabilities and equity	$	7.1		$	536.4		$	2,241.8		$	(725.2	)	$	2,060.1

SunCoke Energy, Inc.

Condensed Consolidating Statement of Cash Flows

Years Ended December 31, 2018

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Cash Flows from Operating Activities:
Net income (loss)	$	26.2		$	50.4		$	29.9		$	(59.5	)	$	47.0
Adjustments to reconcile net income to net cash (used in) provided by operating activities:
Loss from equity method investment	—			—			5.4			—			5.4
Depreciation and amortization expense	—			8.8			132.8			—			141.6
Deferred income tax (benefit) expense	(0.2		)	1.2			(4.4		)	—			(3.4		)
Gain on curtailment and payments in excess of expense for postretirement plan benefits	—			(1.0		)	(1.4		)	—			(2.4		)
Share-based compensation expense	3.1			—			—			—			3.1
Equity in loss of subsidiaries	(34.3		)	(25.2		)	—			59.5			—
Loss on extinguishment of debt	0.3			—			—			—			0.3
Changes in working capital pertaining to operating activities:
Receivables	—			3.8			(10.7		)	—			(6.9		)
Inventories	—			(1.5		)	2.1			—			0.6
Accounts payable	—			(1.6		)	0.9			—			(0.7		)
Accrued liabilities	0.4			(5.9		)	(1.8		)	—			(7.3		)
Deferred revenue	—			—			1.3			—			1.3
Interest payable	(1.0		)	—			(0.8		)	—			(1.8		)
Income taxes	0.3			12.2			(8.0		)	—			4.5
Other	0.3			(0.9		)	5.1			—			4.5
Net cash (used in) provided by operating activities	(4.9		)	40.3			150.4			—			185.8
Cash Flows from Investing Activities:
Capital expenditures	—			(2.8		)	(97.5		)	—			(100.3		)
Sale of equity method investment	—			—			4.0			—			4.0
Other investing activities	—			—			0.5			—			0.5
Net cash used in investing activities	—			(2.8		)	(93.0		)	—			(95.8		)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt	45.0			—			—			—			45.0
Repayment of long-term debt	(45.7		)	—			—			—			(45.7		)
Debt issuance costs	(0.5		)	—			—			—			(0.5		)
Proceeds from revolving facility	—			—			179.5			—			179.5
Repayment of revolving facility	—			—			(204.5		)	—			(204.5		)
Repayment of financing obligation	—			—			(2.6		)	—			(2.6		)
Cash distributions to noncontrolling interests	—			—			(31.9		)	—			(31.9		)
Acquisition of additional interest in the Partnership	—			(4.2		)	—			—			(4.2		)
Other financing activities	0.7			—			(0.3		)	—			0.4
Net increase (decrease) in advances from affiliates	5.4			(13.7		)	8.3			—			—
Net cash provided by (used in) financing activities	4.9			(17.9		)	(51.5		)	—			(64.5		)
Net increase in cash, cash equivalents and restricted cash	—			19.6			5.9			—			25.5
Cash, cash equivalents and restricted cash at beginning of year	—			103.6			16.6			—			120.2
Cash, cash equivalents and restricted cash at end of year	$	—		$	123.2		$	22.5		$	—		$	145.7

SunCoke Energy, Inc.

Condensed Consolidating Statement of Cash Flows

Years Ended December 31, 2017

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Cash Flows from Operating Activities:
Net income (loss)	$	122.4		$	125.9		$	(89.4	)	$	(55.4	)	$	103.5
Adjustments to reconcile net income (loss) to net cash (used in) provided by operating activities:
Depreciation and amortization expense	—			7.5			120.7			—			128.2
Deferred income tax (benefit) expense	(22.8		)	(170.1		)	105.7			—			(87.2		)
Gain on curtailment and payments in excess of expense for postretirement plan benefits	—			(1.0		)	(0.8		)	—			(1.8		)
Share-based compensation expense	4.7			—			0.1			—			4.8
Equity in (loss) earnings of subsidiaries	(109.9		)	54.5			—			55.4			—
Loss on extinguishment of debt	0.4			—			20.0			—			20.4
Changes in working capital pertaining to operating activities (net of the effects of divestiture):
Receivables	—			(4.9		)	(2.9		)	—			(7.8		)
Inventories	—			(0.1		)	(18.4		)	—			(18.5		)
Accounts payable	—			3.0			8.7			—			11.7
Accrued liabilities	(0.2		)	(1.3		)	4.1			—			2.6
Deferred revenue	—			—			(0.8		)	—			(0.8		)
Interest payable	(0.1		)	—			(10.7		)	—			(10.8		)
Income taxes	(2.7		)	16.3			(13.8		)	—			(0.2		)
Other	1.3			—			3.1			—			4.4
Net cash (used in) provided by operating activities	(6.9		)	29.8			125.6			—			148.5
Cash Flows from Investing Activities:
Capital expenditures	—			(4.1		)	(71.5		)	—			(75.6		)
Return of Brazilian investment	—			—			20.5			—			20.5
Net cash used in investing activities	—			(4.1		)	(51.0		)	—			(55.1		)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt	—			—			693.7			—			693.7
Repayment of long-term debt	—			—			(644.9		)	—			(644.9		)
Debt issuance costs	(1.6		)	—			(15.8		)	—			(17.4		)
Proceeds from revolving facility	—			—			350.0			—			350.0
Repayment of revolving facility	—			—			(392.0		)	—			(392.0		)
Repayment of financing obligation	—			—			(2.5		)	—			(2.5		)
Cash distributions to noncontrolling interests	—			—			(47.0		)	—			(47.0		)
Acquisition of additional interest in the Partnership	—			(48.7		)	—			—			(48.7		)
Other financing activities	1.1			—			—			—			1.1
Net increase (decrease) in advances from affiliates	7.4			66.9			(74.3		)	—			—
Net cash provided by (used in) financing activities	6.9			18.2			(132.8		)	—			(107.7		)
Net increase (decrease) in cash, cash equivalents and restricted cash	—			43.9			(58.2		)	—			(14.3		)
Cash, cash equivalents and restricted cash at beginning of year	—			59.7			74.8			—			134.5
Cash, cash equivalents and restricted cash at end of year	$	—		$	103.6		$	16.6		$	—		$	120.2

SunCoke Energy, Inc.

Condensed Consolidating Statement of Cash Flows

December 31, 2016

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Cash Flows from Operating Activities:
Net income	$	14.4		$	31.1		$	85.0		$	(71.0	)	$	59.5
Adjustments to reconcile net income to net cash (used in) provided by operating activities:
Depreciation and amortization expense	—			9.2			105.0			—			114.2
Deferred income tax (benefit) expense	(16.6		)	8.7			11.0			—			3.1
Gain on curtailment and payments in excess of expense for postretirement plan benefits	—			(1.5		)	(1.1		)	—			(2.6		)
Share-based compensation expense	6.5			—			—			—			6.5
Equity in loss of subsidiaries	(19.7		)	(51.3		)	—			71.0			—
Gain on extinguishment of debt	—			—			(25.0		)	—			(25.0		)
Loss on divestiture of business and impairments	—			—			14.7			—			14.7
Changes in working capital pertaining to operating activities (net of acquisitions):
Receivables	—			(4.3		)	8.0			—			3.7
Inventories	—			(3.7		)	33.1			—			29.4
Accounts payable	—			4.6			(5.4		)	—			(0.8		)
Accrued liabilities	1.5			4.8			0.5			—			6.8
Deferred revenue	—			—			0.4			—			0.4
Interest payable	0.1			—			(2.8		)	—			(2.7		)
Income taxes	(6.9		)	28.2			(14.3		)	—			7.0
Other	2.5			8.9			(6.5		)	—			4.9
Net cash (used in) provided by operating activities	(18.2		)	34.7			202.6			—			219.1
Cash Flows from Investing Activities:
Capital expenditures	—			(5.7		)	(58.0		)	—			(63.7		)
Return of Brazilian investment	—			—			20.5			—			20.5
Divestiture of coal business	—			—			(12.8		)	—			(12.8		)
Other investing activities	—			—			2.1			—			2.1
Net cash used in investing activities	—			(5.7		)	(48.2		)	—			(53.9		)
Cash Flows from Financing Activities:
Repayment of long-term debt	—			—			(66.1		)	—			(66.1		)
Debt issuance costs	—			—			(0.2		)	—			(0.2		)
Proceeds from revolving facility	—			—			28.0			—			28.0
Repayment of revolving facility	(60.4		)	—			(38.0		)	—			(98.4		)
Proceeds from financing obligation	—			—			16.2			—			16.2
Repayment of financing obligation	—			—			(1.0		)	—			(1.0		)
Cash distributions to noncontrolling interests	—			—			(49.4		)	—			(49.4		)
Other financing activities	(0.3		)	(1.1		)	—			—			(1.4		)
Net increase (decrease) in advances from affiliates	78.9			(38.8		)	(40.1		)	—			—
Net cash provided by (used in) financing activities	18.2			(39.9		)	(150.6		)	—			(172.3		)
Net (decrease) increase in cash, cash equivalents and restricted cash	—			(10.9		)	3.8			—			(7.1		)
Cash, cash equivalents and restricted cash at beginning of year	—			70.6			71.0			—			141.6
Cash, cash equivalents and restricted cash at end of year	$	—		$	59.7		$	74.8		$	—		$	134.5

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Summary of Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2018

Accounting Policies [Abstract]

Use of Estimates

Use of Estimates

The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and accompanying notes. Actual amounts could differ from these estimates.

Reclassifications

Reclassifications

Certain amounts in the prior period consolidated financial statements have been reclassified to conform to the current year presentation.

Revenue Recognition

Revenue Recognition

The Company sells coke as well as steam and electricity and also provides mixing and/or handling services of coal and other aggregates. The Company also receives fees for operating the cokemaking plant in Brazil and for the licensing of its proprietary technology for use at this facility as well as reimbursement of substantially all of its operating costs. See Note 18.

Substantially all of the coke produced by the Company is sold pursuant to long-term contracts with its customers. The Company evaluates each of its contracts to determine whether the arrangement contains a lease under the applicable accounting standards. If the specific facts and circumstances indicate that it is remote that parties other than the contracted customer will take more than a minor amount of the coke that will be produced by the property, plant and equipment during the term of the coke supply agreement, and the price that the customer is paying for the coke is neither contractually fixed per unit nor equal to the current market price per unit at the time of delivery, then the long-term contract is deemed to contain a lease. The lease component of the price of coke represents the rental payment for the use of the property, plant and equipment, and all such payments are accounted for as contingent rentals as they are only earned by the Company when the coke is delivered and title passes to the customer. The total amount of revenue recognized by the Company for these contingent rentals represents less than 10 percent of consolidated sales and other operating revenues for each of the years ended December 31, 2018, 2017 and 2016. Upon adoption of Accounting Standard Codification ("ASC") 842, "Leases", in 2019, these long-term contracts to sell coke will no longer be deemed to contain operating leases.

Cash Equivalents

Cash Equivalents

The Company considers all highly liquid investments with a remaining maturity of three months or less at the time of purchase to be cash equivalents. These cash equivalents consist principally of certificates of deposit.

Inventories

Inventories

Inventories are valued at the lower of cost or net realizable value. Cost is determined using the first-in, first-out method, except for the Company’s materials and supplies inventory, which are determined using the average-cost method. The Company utilizes the selling prices under its long-term coke supply contracts to record lower of cost or net realizable value inventory adjustments.

Properties, Plants and Equipment

Properties, Plants and Equipment

Plants and equipment are depreciated on a straight-line basis over their estimated useful lives. Coke and energy plant, machinery and equipment are generally depreciated over 25 to 30 years. Logistics plant and equipment are generally depreciated over 15 to 35 years. Depreciation and amortization is excluded from cost of products sold and operating expenses and is presented separately on the Consolidated Statements of Income. Gains and losses on the disposal or retirement of fixed assets are reflected in earnings when the assets are sold or retired. Amounts incurred that extend an asset’s useful life, increase its productivity or add production capacity are capitalized. The Company accounts for changes in useful lives, when appropriate, as a change in estimate, with prospective application only. The Company capitalized interest of $3.2 million, $1.1 million, and $5.0 million in 2018, 2017 and 2016, respectively. Direct costs, such as outside labor, materials, internal payroll and benefits costs incurred during capital projects are capitalized; indirect costs are not capitalized. Normal repairs and maintenance costs are expensed as incurred.

Impairment of Long-Lived Assets

Impairment of Long-Lived Assets

Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. A long-lived asset, or group of assets, is considered to be impaired when the undiscounted net cash flows expected to be generated by the asset are less than its carrying amount. Such estimated future cash flows are highly subjective and are based on numerous assumptions about future operations and market conditions. The impairment recognized is the amount by which the carrying amount exceeds the fair market value of the impaired asset, or group of assets. It is also difficult to precisely estimate fair market value because quoted market prices for our long-lived assets may not be readily available. Therefore, fair market value is generally based on the present values of estimated future cash flows using discount rates commensurate with the risks associated with the assets being reviewed for impairment.

Goodwill and Other Intangibles

Goodwill and Other Intangibles

Goodwill, which represents the excess of the purchase price over the fair value of net assets acquired, is tested for impairment as of October 1 of each year, or when events occur or circumstances change that would, more likely than not, reduce the fair value of a reporting unit to below its carrying value. The Company performs its annual goodwill impairment test by comparing the fair value of the reporting unit with its carrying amount. The Company would recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value. See Note 8.

Intangible assets are primarily comprised of permits, customer contracts and customer relationships. Intangible assets are amortized over their useful lives in a manner that reflects the pattern in which the economic benefit of the intangible asset is consumed. Intangible assets are assessed for impairment when a triggering event occurs.

Investment in Brazilian Cokemaking Operations

Investment in Brazilian Cokemaking Operations

On November 28, 2016, ArcelorMittal Brazil redeemed SunCoke’s indirectly held preferred and common equity interest in Sol Coqueria Tubarão S.A. ("Brazil Investment"), previously accounted for at cost, for consideration of $41.0 million. The Company received $20.5 million in cash at closing in 2016 and received the remaining $20.5 million in cash, plus interest of $0.2 million, in 2017. Starting in 2016, SunCoke receives $5.1 million in licensing fees per year, in addition to our per ton licensing fee, through 2023 related to the addition of certain patents to its existing intellectual property licensing agreement, which are currently in use by ArcelorMittal Brazil at the Brazil facility. The Company also extended the life of its patents with the Brazilian authorities through 2033, providing opportunity to extend the existing licensing agreement beyond 2023. Licensing fees are included in sales and other operating revenue on the Consolidated Statements of Income.

Income Taxes

Income Taxes

Deferred tax asset and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those differences are projected to be recovered or settled. See Note 5.

The Company recognizes uncertain tax positions in its financial statements when minimum recognition threshold and measurement attributes are met in accordance with current accounting guidance.

Black Lung Benefit Liabilities

Black Lung Benefit Liabilities

The Company has obligations related to coal workers’ pneumoconiosis, or black lung, benefits to certain of our former coal miners and their dependents. Such benefits are provided for under Title IV of the Federal Coal Mine and Safety Act of 1969 and subsequent amendments, as well as for black lung benefits provided in the states of Virginia, Kentucky and West Virginia pursuant to workers’ compensation legislation. The Patient Protection and Affordable Care Act (“PPACA”), which was implemented in 2010, amended previous legislation related to coal workers’ black lung obligations. PPACA provides for the automatic extension of awarded lifetime benefits to surviving spouses and changes the legal criteria used to assess and award claims. We act as a self-insurer for both state and federal black lung benefits and adjust our liability each year based upon actuarial calculations of our expected future payments for these benefits.

Postretirement Benefit Plan Liabilities

Postretirement Benefit Plan Liabilities

The postretirement benefit plans, which are frozen, are unfunded and the accumulated postretirement benefit obligation is fully recognized on the Consolidated Balance Sheets. Actuarial gains (losses) and prior service costs (benefits) which have not yet been recognized in net income are recognized as a credit (charge) to accumulated other comprehensive income (loss). The credit (charge) to accumulated other comprehensive income (loss), which is reflected net of related tax effects, is subsequently recognized in net income when amortized as a component of postretirement benefit plans expense included in interest expense, net on the Consolidated Statements of Income.

Asset Retirement Obligations

Asset Retirement Obligations

The fair value of a liability for an asset retirement obligation is recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. The associated asset retirement costs are capitalized as part of the carrying amount of the asset and depreciated over its remaining estimated useful life. The Company’s asset retirement obligations primarily relate to costs associated with restoring land to its original state.

Shipping and Handling Costs

Shipping and Handling Costs

Shipping and handling costs are included in cost of products sold and operating expenses on the Consolidated Statements of Income and are generally passed through to our customers. The Company has elected the practical expedient under ASC 606, "Revenue from Contracts with Customers", to account for shipping and handling activities as a promise to fulfill the transfer of coke.

Share-based Compensation

Share-Based Compensation

We measure the cost of employee services in exchange for equity instrument awards and cash awards based on the grant-date fair value of the award. The cash awards and performance metrics of equity awards are remeasured on a quarterly basis. The market metrics of equity awards are not remeasured. The total cost is recognized over the requisite service period. Award forfeitures are accounted for as they occur. The costs of equity awards and cash awards were recorded to additional paid-in capital and accrued liabilities, respectively, on the Consolidated Balance Sheets.

Fair Value Measurements

Fair Value Measurements

The Company determines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. As required, the Company utilizes valuation techniques that maximize the use of observable inputs (levels 1 and 2) and minimize the use of unobservable inputs (level 3) within the fair value hierarchy included in current accounting guidance. Assets and liabilities are classified within the fair value hierarchy based on the lowest level (least observable) input that is significant to the measurement in its entirety.

Currency Transactions

Currency Translation

The functional currency of the Company’s Brazilian operations is the Brazilian real. The Company’s Brazil operations translate its assets and liabilities into U.S. dollars at the current exchange rates in effect at the end of the fiscal period. The gains or losses that result from this process are shown as cumulative translation adjustments within accumulated other comprehensive loss in the Consolidated Balance Sheets. The revenue and expense accounts of foreign operations are translated into U.S. dollars at the average exchange rates during the period.

Recently Adopted Accounting Pronouncements and Recently Issued Pronouncements

Recently Adopted Accounting Pronouncements

In May 2014, Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2014-09, “Revenue from Contracts with Customers (Topic 606),” which supersedes the revenue recognition requirements in “Revenue Recognition (Topic 605),” and requires entities to recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The Company adopted this standard on January 1, 2018, using the modified retrospective method with no material impact on our revenue recognition model on an annual basis. See Note 18.

In November 2016, the FASB issued ASU 2016-18, “Statement of Cash Flows (Topic 230): Restricted cash.” The Company retrospectively adopted this ASU in the first quarter 2018 and modified the Company's cash flow presentation to include restricted cash with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. Historical restricted cash balances were related to cash withheld from the 2015 acquisition of CMT to fund the completion of certain expansion capital improvements, and the related immaterial impacts have been reclassified on the statement of cash flows for the years ended December 31, 2017 and 2016. The restricted cash balance was zero at both December 31, 2018 and December 31, 2017.

In March 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 Company adopted this ASU in the first quarter 2018 and retrospectively presented net periodic postretirement benefit cost in the income statement separately from the service cost component and outside a subtotal of income from operations. In conjunction with the adoption of this standard, expense of $1.3 million was reclassified from operating income and was recorded in interest expense, net on the Consolidated Statements of Income for both the years ended December 31, 2017 and 2016, respectively. See Note 10.

In February 2018, the FASB issued ASU 2018-02, “Income Statement-Reporting Comprehensive Income (Topic 220) - Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income.” The Company adopted this ASU in the first quarter 2018 and reclassified $1.1 million of deferred tax adjustments to accumulated other comprehensive income (loss) from retained earnings on the December 31, 2017 balance sheet for the tax effects resulting from the Tax Cuts and Jobs Act of 2017.

Recently Issued Pronouncements

In February 2016, the FASB issued ASU 2016-02, "Leases (Topic 842)." ASU 2016-02 requires leases to be recognized as assets and liabilities on the balance sheet for the rights and obligations created by all leases with terms of more than 12 months. Subsequently, the FASB has issued various ASUs to provide further clarification around certain aspects of ASC 842, "Leases".  This standard is effective for annual and interim periods in fiscal years beginning after December 15, 2018, with early adoption permitted. A multi-disciplined implementation team has gained an understanding of the accounting and disclosure provisions of the standard and analyzed the impacts to our business, including the development of new accounting processes to account for our leases and support the required disclosures. We have implemented a technology tool to assist with the accounting and reporting requirements of this standard. While we are still finalizing the impact of adopting this standard, we expect that upon adoption the right-of-use assets and lease liabilities, such as land, the lease of our corporate office space and certain equipment rentals, will increase the reported assets and liabilities on our Consolidated Balance Sheets by approximately $5 million to $10 million. The Company adopted this standard on January 1, 2019, by applying the modified retrospective transition approach and electing not to adjust prior comparative periods.

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Acquisition of Noncontrolling Interest (Tables)

12 Months Ended

Dec. 31, 2018

Noncontrolling Interest [Abstract]

Schedule of Changes in Ownership Interest

The following table summarizes the Company's purchases of outstanding Partnership common units in the open market:

	Years Ended December 31
	2018		2017
	(Dollars in millions)
Units purchased	231,171		2,853,032
Cash paid	$	4.2	$	48.7
Decrease in noncontrolling interest (1)	$	2.7	$	29.6
Decrease in additional paid in capital (2)	$	1.2	$	12.0

(1) Represents Partnership's net book value acquired by the Company.

(2) Represents consideration paid in excess of the net book value of the noncontrolling interest acquired net of deferred tax adjustments of $0.3 million and $7.1 million for the years ended December 31, 2018 and 2017, respectively.

The following table summarizes the effects of the changes in the Company's ownership interest in the Partnership on SunCoke's equity:

	Years Ended December 31,
	2018			2017
	(Dollars in millions)
Net income attributable to SunCoke Energy, Inc	$	26.2		$	122.4
Decrease in SunCoke Energy, Inc. equity for the purchase of additional interest in the Partnership	(1.2		)	(12.0		)
Changes from net income attributable to SunCoke Energy, Inc and transfers to noncontrolling interest	$	25.0		$	110.4

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Customer Concentrations (Tables)

12 Months Ended

Dec. 31, 2018

Risks and Uncertainties [Abstract]

Schedules of Concentration of Risk, by Risk Factor

The table below shows sales to Murray and Foresight:

	Years ended December 31,
	2018			2017			2016
	(Dollars in millions)
Sales and other operating revenue	$	62.5		$	57.8		$	53.5
Percent of Company sales and other operating revenue	4.3		%	4.3		%	4.4		%
Percent of Logistics segment sales and other operating revenue, including intersegment sales	49.3		%	49.4		%	49.6		%

The table below shows receivables due from Murray and Foresight:

	December 31,
	2018		2017
	(Dollars in millions)
Murray and Foresight	$	3.2	$	9.7

The table below shows receivables due from the Company's significant customers:

	December 31,
	2018		2017
	(Dollars in millions)
AM USA and ArcelorMittal Brazil	$	34.3	$	25.7
AK Steel	$	25.3	$	13.2
U.S. Steel	$	5.2	$	5.6

The table below shows sales to the Company's significant customers:

	Years ended December 31,
	2018				2017				2016
	Sales and other operating revenue		Percent of Company sales and other operating revenue		Sales and other operating revenue		Percent of Company sales and other operating revenue		Sales and other operating revenue		Percent of Company sales and other operating revenue
	(Dollars in millions)
AM USA and ArcelorMittal Brazil(1)	$	735.8	50.7	%	$	678.2	50.9	%	$	596.6	48.8	%
AK Steel(2)	$	377.9	26.0	%	$	331.3	24.9	%	$	350.0	28.6	%
U.S. Steel(3)	$	206.8	14.3	%	$	214.1	16.1	%	$	185.3	15.1	%

(1) Represents revenues included in our Domestic Coke and Brazil Coke segments.

(2) Represents revenues included in our Domestic Coke segment.

(3) Represents revenues included in our Domestic Coke and Logistics segments.

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Income Taxes (Tables)

12 Months Ended

Dec. 31, 2018

Income Tax Disclosure [Abstract]

Components of income before income tax expense

The components of income before income tax (benefit) expense and loss from equity method investment are as follows:

	Years Ended December 31,
	2018		2017		2016
	(Dollars in millions)
Domestic	$	39.3	$	4.3	$	52.5
Foreign	17.7		17.6		15.6
Total	$	57.0	$	21.9	$	68.1

Components of income tax expense

ncome tax expense (benefit) consisted of the following:

	Years Ended December 31,
	2018			2017			2016
	(Dollars in millions)
Current tax expense:
U.S. federal	$	1.4		$	1.7		$	2.7
State	2.1			(1.0		)	(2.2		)
Foreign	4.5			4.9			5.0
Total current tax expense	8.0			5.6			5.5
Deferred tax expense:
U.S. federal	(3.1		)	(99.7		)	(1.5		)
State	(0.3		)	12.5			4.6
Total deferred tax (benefit) expense	(3.4		)	(87.2		)	3.1
Total	$	4.6		$	(81.6	)	$	8.6

Reconciliation of income tax expense

The reconciliation of income tax expense at the U.S. statutory rate to income tax expense (benefit) is as follows:

	Years Ended December 31,
	2018					2017					2016
	(Dollars in millions)
Income tax expense at U.S. statutory rate	$	12.0		21.0	%	$	7.7		35.0	%	$	23.8		35.0	%
Increase (reduction) in income taxes resulting from:
Impact of Final Regulations(1)	(1.4		)	(2.5	)%	64.2			293.2	%	—			—	%
Impact of Tax Legislation(2)	(4.8		)	(8.4	)%	(154.7		)	(706.4	)%	—			—	%
Income attributable to noncontrolling interests in partnerships(3)	(3.9		)	(6.8	)%	(5.4		)	(24.7	)%	(15.6		)	(23.0	)%
State and other income taxes, net of federal income tax effects	1.6			2.8	%	2.0			9.1	%	1.1			1.7	%
Change in valuation allowance(4)	0.7			1.2	%	3.9			17.8	%	0.4			0.6	%
Other	0.4			0.7	%	0.7			3.2	%	(1.1		)	(1.6	)%
Income tax (benefit) expense at effective tax rate	$	4.6		8.0	%	$	(81.6	)	(372.8	)%	$	8.6		12.7	%

(1) In January 2017, the Internal Revenue Service ("IRS") announced its decision to exclude cokemaking as a qualifying income generating activity in its final regulations (the "Final Regulations") issued under section 7704(d)(1)(E) of the Internal Revenue Code relating to the qualifying income exception for publicly traded partnerships. Subsequent to the 10-year transition period, certain cokemaking entities in the Partnership will become taxable as corporations. As a result, the Partnership recorded deferred income tax expense of $148.6 million to set up its initial deferred income tax liability during 2017, primarily related to differences in the book and tax basis of fixed assets, which are expected to exist at the end of the 10-year transition period when the cokemaking operations become taxable.  However, the Company had previously recorded $84.4 million of the deferred income tax liability in its financial statements related to the Company's share of the deferred tax liability for the book and tax differences in its investment in the Partnership. As such, the Company's 2017 financial statements reflect the $64.2 million incremental impact from the Final Regulations solely attributable to the Partnership’s public unitholders, which was also recorded as an equal reduction to noncontrolling interest.

In 2018, the Partnership recorded a deferred tax benefit of $3.6 million related to its changes in projected deferred tax liability associated with projected book and tax differences at the end of the 10-year transition period due to current period additions and changes in estimated useful lives of certain assets. The Company's 2018 financial statements reflect a $1.4 million benefit, which is solely attributable to the Partnership’s public unitholders and was also recorded as an equal reduction to noncontrolling interest. 

As a result, the Final Regulations have no impact to net income attributable to the Company.

(2) On December 22, 2017, the Tax Legislation was enacted. The Tax Legislation significantly revised the U.S. corporate income tax structure, including lowering corporate income tax rates. In addition, the SEC staff released Staff Accounting Bulletin 118 on December 23, 2017, which provided for companies to record a provisional impact of the Tax Legislation during a measurement period, not to exceed one year, in situations where companies do not have the necessary information available, prepared, or analyzed in reasonable detail to complete the accounting under ASC 740, "Income Taxes", for certain income tax effects of the Tax Legislation for the reporting period which includes enactment. During 2017, SunCoke recorded a provisional net income tax benefit of $154.7 million, of which $125.0 million was attributable to the Company, for the impact of this Tax Legislation. These benefits were primarily due to the $169.0 million net benefit resulting from the remeasurement of U.S. deferred income tax liabilities and assets at the lower enacted corporate tax rates. During 2017, based on information available at the time, the Company recorded provisional income tax expense of $14.3 million for a valuation allowance against $19.0 million of foreign tax credit carryforwards that the Company believed would not be realized prior to their expiration as a result of the Tax Legislation. Based on an updated analysis of the foreign tax credit rules relating to the new Tax Legislation, the Company revised its estimate of the realizability of its foreign tax credits, resulting in a net $4.8 million benefit during the third quarter of 2018. There were no other significant changes to previous estimates and amounts recorded in 2017 relating to this Tax Legislation.

(3) Excludes the impact of the Final Regulations on qualifying income discussed above. No income tax expense is reflected in the Consolidated Statements of Income for income attributable to noncontrolling interests in partnership entities.

(4)

Tax effects of temporary differences that comprise the net deferred income tax liability

The tax effects of temporary differences that comprise the net deferred income tax liability from operations are as follows:

	December 31,
	2018			2017
	(Dollars in millions)
Deferred tax assets:
Retirement benefit liabilities	$	6.4		$	7.1
Black lung benefit liabilities	11.3			11.6
Share-based compensation	6.4			6.1
Federal tax credit carryforward(1)	21.5			23.2
Foreign tax credit carryforward(2)	15.9			19.0
Federal net operating loss	—			2.5
Section 163(j) interest limitation carryforward(3)	1.8			—
State tax credit carryforward, net of federal income tax effects(4)	2.4			4.0
State net operating loss carryforward, net of federal income tax effects(5)	13.5			13.9
Other liabilities not yet deductible	4.9			4.3
Total deferred tax assets	84.1			91.7
Less valuation allowance(6)	(20.7		)	(26.2		)
Deferred tax asset, net	63.4			65.5
Deferred tax liabilities:
Properties, plants and equipment	(111.5		)	(114.9		)
Investment in partnerships	(206.6		)	(208.4		)
Total deferred tax liabilities	(318.1		)	(323.3		)
Net deferred tax liability	$	(254.7	)	$	(257.8	)

(1) Federal tax credit carryforward expires in 2032 through 2034.

(2) Foreign tax credit carryforward expires in 2023 through 2028.

(3) The Tax Legislation generally limits the deductibility of business interest expense to 30 percent of adjusted taxable income. This limitation resulted in a deferred tax asset as it is eligible for deduction in future taxable years and has no expiration.

(4) State tax credit carryforward, net of federal income tax effects expires in 2019 through 2023.

(5) State net operating loss carryforward, net of federal income tax effects expires in 2023 through 2038.

(6) Primarily related to state tax credit and net operating loss carryforwards and the $9.9 million allowance against the foreign tax credit carryforward.

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Inventories (Tables)

12 Months Ended

Dec. 31, 2018

Inventory Disclosure [Abstract]

Components of inventories

These components of inventories were as follows:

	December 31,
	2018		2017
	(Dollars in millions)
Coal	$	59.9	$	61.4
Coke	8.6		12.3
Materials, supplies and other	41.9		37.3
Total inventories	$	110.4	$	111.0

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Properties, Plants and Equipment, Net (Tables)

12 Months Ended

Dec. 31, 2018

Property, Plant and Equipment [Abstract]

Components of net properties, plants and equipment

The components of net properties, plants and equipment were as follows:

	December  31,
	2018			2017
	(Dollars in millions)
Coke and energy plant, machinery and equipment(1)	$	1,876.3		$	1,812.0
Logistics plant, machinery and equipment	218.3			216.2
Land and land improvements	119.7			118.7
Construction-in-progress	72.7			51.9
Other	39.9			35.7
Gross investment, at cost	2,326.9			2,234.5
Less: accumulated depreciation(1)	(855.8		)	(733.2		)
Total properties, plants and equipment, net	$	1,471.1		$	1,501.3

(1) Includes assets, consisting mainly of coke and energy plant, machinery and equipment, with a gross investment totaling $1,416.2 million and $1,337.3 million and accumulated depreciation of $554.1 million and $475.8 million at December 31, 2018 and December 31, 2017, respectively, which are subject to long-term contracts to sell coke and are deemed to contain operating leases. Upon adoption of ASC 842, "Leases",in 2019, these contracts will no longer be deemed to contain operating leases.

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Goodwill and Other Intangible Assets (Tables)

12 Months Ended

Dec. 31, 2018

Goodwill and Intangible Assets Disclosure [Abstract]

Schedule of Goodwill

	December 31, 2018 and 2017
	(Dollars in millions)
Domestic Coke	$	3.4
Logistics	73.5
Total	$	76.9

Schedule of Finite-Lived Intangible Assets

The following table summarizes the components of gross and net intangible asset balances:

		December 31, 2018						December 31, 2017
	Weighted - Average Remaining Amortization Years	Gross Carrying Amount		Accumulated Amortization		Net		Gross Carrying Amount		Accumulated Amortization		Net
		(Dollars in millions)
Customer contracts	4	$	31.7	$	17.7	$	14.0	$	31.7	$	13.8	$	17.9
Customer relationships	13	28.7		7.5		21.2		28.7		5.7		23.0
Permits	24	139.0		17.4		121.6		139.0		12.2		126.8
Trade name	—	1.2		1.2		—		1.2		1.0		0.2
Total		$	200.6	$	43.8	$	156.8	$	200.6	$	32.7	$	167.9

Schedule of Finite-Lived Intangible Assets, Future Amortization Expense

Based on the carrying value of finite-lived intangible assets as of December 31, 2018, we estimate amortization expense for each of the next five years as follows:

	(Dollars in millions)
2019	$	10.9
2020	10.7
2021	10.3
2022	10.3
2023	7.0
Thereafter	107.6
Total	$	156.8

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Asset Retirement Obligations (Tables)

12 Months Ended

Dec. 31, 2018

Asset Retirement Obligation [Abstract]

Reconciliation of changes in the asset retirement obligation

The following table provides a reconciliation of changes in the asset retirement obligation from operations during each period:

	(Dollars in millions)
Balance at December 31, 2016	$	13.9
Liabilities settled	(0.7		)
Accretion expense(1)	1.0
Revisions in estimated cash flows	(0.2		)
Balance at December 31, 2017	$	14.0
Liabilities settled	(0.4		)
Accretion expense(1)	0.9
Revisions in estimated cash flows	$	0.1
Balance at December 31, 2018	$	14.6

(1) Included in cost of products sold and operating expenses on the Consolidated Statements of Income.

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Retirement Benefits Plans (Tables)

12 Months Ended

Dec. 31, 2018

Retirement Benefits [Abstract]

Postretirement benefit plans (benefit) expense

Postretirement benefit plans expense consisted of the following components:

	Years Ended December 31,
	2018			2017			2016
	(Dollars in millions)
Interest cost on benefit obligations	$	1.0		$	1.1		$	1.3
Amortization of:
Actuarial losses	0.6			0.9			0.7
Prior service benefit	(0.7		)	(0.7		)	(0.7		)
Total expense	$	0.9		$	1.3		$	1.3

Discount rates used to determine benefit obligations for the plans

The following discount rates were used to determine the benefit obligation:

	December 31,
	2018		2017
Discount rate	4.00	%	3.35	%

The following assumptions were used to determine postretirement benefit plans expense:

	December 31,
	2018		2017		2016
Discount Rate	3.35	%	3.65	%	3.80	%

Recognized components of other comprehensive income (loss)

The following amounts were recognized as components of other comprehensive income (loss) before related tax impacts:

		Years Ended December 31,
		2018			2017			2016
	(Dollars in millions)
Reclassifications to earnings of:
Actuarial loss amortization		$	0.6		$	0.9		$	0.7
Prior service benefit amortization		(0.7		)	(0.7		)	(0.7		)
Retirement benefit plan funded status    adjustments:
Actuarial gains (losses)		0.8			(1.1		)	(1.8		)
Prior service benefit(1)		—			—			1.5
		$	0.7		$	(0.9	)	$	(0.3	)

(1) Effective January 1, 2017, a plan change occurred resulting in Medicare-eligible disabled participants transitioning from a Company-sponsored group medical plan to a federal health care exchange plan. The Company provides a subsidy to these participants each year. The plan change resulted in a decrease in the benefit obligation of $1.5 million during 2016.

Components of changes in benefit obligations and fair value of plan assets

The following table sets forth the components of the changes in benefit obligations:

	Years Ended December 31,
	2018			2017
	(Dollars in millions)
Benefit obligation at beginning of year	$	31.3		$	32.3
Interest cost	1.0			1.1
Actuarial (gain)/loss	(0.8		)	1.1
Benefits paid	(3.3		)	(3.2		)
Benefit obligation at end of year(1)	$	28.2		$	31.3

(1) Represents retirement benefit liabilities, including current portion, on the Consolidated Balance Sheets. The current portion of retirement liabilities, which totaled $3.0 million and $3.1 million at December 31, 2018 and 2017, respectively, is classified in accrued liabilities on the Consolidated Balance Sheets.

Cumulative amounts not recognized

The following table sets forth the cumulative amounts not yet recognized in net income:

	Years Ended December 31,
	2018			2017
	(Dollars in millions)
Cumulative amounts not yet recognized in net income:
Actuarial losses	$	10.4		$	11.8
Prior service benefits	(2.6		)	(3.4		)
Accumulated other comprehensive loss (before related tax benefit)	$	7.8		$	8.4

Expected benefit payments

The expected benefit payments through 2028 for the postretirement benefit plan are as follows:

Year ending December 31:	(Dollars in millions)
2019	$	3.0
2020	2.9
2021	2.8
2022	2.6
2023	2.4
2024 through 2028	9.5

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Accrued Liabilities (Tables)

12 Months Ended

Dec. 31, 2018

Balance Sheet Related Disclosures [Abstract]

Accrued liabilities

Accrued liabilities consist of following:

	December 31,
	2018		2017
	(Dollars in millions)
Accrued benefits	$	21.2	$	21.3
Current portion of postretirement benefit obligation	3.0		3.1
Other taxes payable	9.1		10.5
Current portion of black lung liability	4.5		5.4
Accrued legal	4.2		5.6
Other	3.6		7.3
Total accrued liabilities	$	45.6	$	53.2

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Debt and Financing Obligation (Tables)

12 Months Ended

Dec. 31, 2018

Debt Disclosure [Abstract]

Schedule of Long-term Debt Instruments

Total debt and financing obligation consisted of the following:

	December 31,
	2018			2017
	(Dollars in millions)
7.500 percent senior notes, due 2025 ("Partnership Notes")	$	700.0		$	700.0
7.625 percent senior notes, due 2019 ("2019 Notes")	—			44.6
Term loan, due 2022 ("Term Loan")	43.9			—
SunCoke's revolving credit facility, due 2022 ("Revolving Facility")	—			—
Partnership's revolving credit facility, due 2022 ("Partnership Revolver")	105.0			130.0
5.82 percent financing obligation, due 2021 ("Partnership Financing Obligation")	10.1			12.7
Total borrowings	$	859.0		$	887.3
Original issue discount	(5.4		)	(5.9		)
Debt issuance costs	(15.2		)	(17.7		)
Total debt and financing obligation	$	838.4		$	863.7
Less: current portion of long-term debt and financing obligation	3.9			2.6
Total long-term debt and financing obligation	$	834.5		$	861.1

Schedule of Maturities of Long-term Debt

As of December 31, 2018, the combined aggregate amount of maturities for long-term borrowings for each of the next five years is as follows:

	(Dollars in millions)
2019	$	3.9
2020(1)	10.7
2021	3.4
2022	141.0
2023	—
2024-Thereafter	700.0
Total	$	859.0

(1) Assumes the Partnership Financing Obligation early buyout option is exercised in 2020.

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Commitments And Contingent Liabilities (Tables)

12 Months Ended

Dec. 31, 2018

Commitments and Contingencies Disclosure [Abstract]

Aggregate amount of future minimum annual rentals applicable to noncancelable operating leases and related subleases

The aggregate amount of future minimum annual rental payments applicable to noncancelable operating leases is as follows:

	Minimum Rental Payments
	(Dollars in millions)
Year ending December 31:
2019	$	2.0
2020	1.1
2021	1.0
2022	0.5
2023	0.1
2024-Thereafter	0.7
Total	$	5.4

Schedule of black lung benefit liabilities

The following table summarizes discount rates utilized, active claims, and the total black lung liabilities:

	December 31,
	2018			2017
Discount rate(1)	4.0		%	3.3		%
Active claims	345			351
Black lung liability (dollars in millions)(2)	$	49.4		$	50.3

(1) The discount rate is determined based on a portfolio of high-quality corporate bonds with maturities that are consistent with the estimated duration of our black lung obligations. A decrease of 25 basis points in the discount rate would have increased black lung expense by $1.1 million in 2018.

(2) The current portion of the black lung liability was $4.5 million and $5.4 million at December 31, 2018 and 2017, respectively, and was included in accrued liabilities on the Consolidated Balance Sheets.

The following table summarizes annual black lung payments and expense:

	Years Ended December 31,
	2018		2017		2016
	(Dollars in millions)
Payments	$	6.3	$	7.4	$	7.8
Expense	$	5.4	$	7.5	$	8.1

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Accumulated Other Comprehensive Loss (Tables)

12 Months Ended

Dec. 31, 2018

Equity [Abstract]

Components of accumulated other comprehensive (loss) income

The following tables set forth the changes in the balance of accumulated other comprehensive loss, net of tax, by component:

	Benefit Plans			Currency Translation Adjustments			Total
	(Dollars in millions)
At December 31, 2016	$	(4.8	)	$	(14.2	)	$	(19.0	)
Other comprehensive loss before reclassifications	—			(0.5		)	(0.5		)
Amounts reclassified from accumulated other comprehensive loss	0.2			—			0.2
Retirement benefit plans funded status adjustment	(0.8		)	—			(0.8		)
Net current period other comprehensive loss	(0.6		)	(0.5		)	(1.1		)
Cumulative effect from adoption of ASU 2018-02(1)	(1.1		)	—			(1.1		)
At December 31, 2017	$	(6.5	)	$	(14.7	)	$	(21.2	)
Other comprehensive loss before reclassifications	—			(1.4		)	(1.4		)
Amounts reclassified from accumulated other comprehensive loss	(0.1		)	—			(0.1		)
Retirement benefit plans funded status adjustment	0.6			—			0.6
Recognition of accumulated currency translation loss upon sale of equity method investment(2)	—			9.0			9.0
Net current period other comprehensive loss	0.5			7.6			8.1
At December 31, 2018	$	(6.0	)	$	(7.1	)	$	(13.1	)

(1) As a result of the Tax Legislation, the Company revalued its deferred tax asset for our postretirement benefit plan for the impact of lower income tax rates, the impact of which was reclassified from accumulated other comprehensive loss to retained earnings.

(2) These accumulated currency translation losses were recognized into income as a result of the sale of our equity method investment in VISA SunCoke.

The tax benefit associated with the Company's benefit plans as of December 31, 2018 and 2017 was $1.8 million and $1.9 million, respectively.

Impact of net income of reclassification adjustments

The increase (decrease) on net income due to reclassification adjustments from accumulated other comprehensive income were as follows⁽¹⁾:

	December 31,
	2018			2017			2016
	(Dollars in millions)
Recognition of accumulated currency translation loss upon sale of equity method investment	$	(9.0	)	$	—		$	—
Amortization of benefit plans to net income:(2)
Actuarial loss	$	(0.6	)	$	(0.9	)	$	(0.7	)
Prior service benefit	0.7			0.7			0.7
Total, net of tax(3)	(8.9		)	(0.2		)	—

(1) Amounts in parentheses indicate debits to net income.

(2) These accumulated other comprehensive (income) loss components are included in the computation of postretirement benefit plan expense (benefit) and included in interest expense, net on the Consolidated Statements of Income. See Note 10.

(3) The related tax cost (benefit) was zero for all years presented.

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Share-Based Compensation (Tables)

12 Months Ended

Dec. 31, 2018

Share-based Compensation [Abstract]

Summary of information with respect to common stock option awards and performance share units

The following table summarizes information with respect to common stock option awards outstanding as of December 31, 2018 and stock option activity during the fiscal year then ended:

	Number of Options		Weighted Average Exercise Price		Weighted Average Remaining Contractual Term (years)	Aggregate Intrinsic Value (millions)
Outstanding at December 31, 2017	3,146,115		$	15.31	5.6	$	2.8
Granted	78,447		$	10.49
Exercised	(127,107	)	$	6.49
Forfeited	(211,667	)	$	17.07
Outstanding at December 31, 2018	2,885,788		$	15.46	4.8	$	2.1
Exercisable at December 31, 2018	2,546,059		$	16.38	4.1	$	0.4
Expected to vest at December 31, 2018	339,729		$	8.59	8.2	$	0.9

The Company grants performance share units ("PSUs"), which represent the right to receive shares of the Company's common stock, contingent upon the attainment of Company performance and market goals and continued employment.

The Company granted the following PSUs during the years ended December 31, 2018 and 2017:

	Shares	Fair Value per Share		Grant Date Fair Value
				(Dollars in millions)
2018 grant(1)	96,389	$	11.36	$	1.1
2017 grant(2)	385,758	$	11.61	$	4.5

(1) The service period for the 2018 PSUs ends on December 31, 2020 and the awards will vest during the first quarter of 2021.

(2) The Company granted 237,610 PSUs in February 2017, for which the service period will end on December 31, 2019, and 148,148 PSUs in December 2017, for which the service period will end on December 31, 2020. These awards will vest during the first quarter of 2020 and 2021, respectively.

The Company granted the following stock options during the years ended December 31, 2018, 2017 and 2016, with an exercise price equal to the closing price of our common stock on the date of grant:

		Weighted Average Per Share
	No. of Shares	Exercise Price		Weighted Average Grant Date Fair Value
Traditional stock options:
2018 grant	78,447	$	10.49	$	5.38
2017 grant	157,196	$	10.29	$	5.32
2016 March grant	90,925	$	6.03	$	2.78
2016 February grant	95,001	$	3.80	$	1.71
Performance based options:
2017 grant	80,595	$	9.85	$	5.17
2016 March grant	90,925	$	6.03	$	2.42
2016 February grant	58,448	$	3.80	$	1.06

Weighted-average assumptions

The weighted-average fair value of employee stock options granted during the years ended December 31, 2018, 2017 and 2016 was based on using the following weighted-average assumptions:

	Years Ended December 31,
	2018		2017		2016
Risk free interest rate	3	%	2	%	1	%
Expected term	6 years		6 years		5 years
Volatility	52	%	53	%	52	%
Dividend yield	—	%	—	%	—	%

Summary of information with respect to RSUs

The following table summarizes information with respect to RSUs outstanding as of December 31, 2018 and RSU activity during the fiscal year then ended:

	Number of RSUs		Weighted Average Grant- Date Fair Value
Nonvested at December 31, 2017	106,397		$	13.53
Granted	32,128		$	10.49
Vested	(87,131	)	$	14.27
Forfeited	(4,181	)	$	8.37
Nonvested at December 31, 2018	47,213		$	10.29

The Company granted the following restricted stock units ("RSUs") during the years ended December 31, 2018 and 2017:

	Shares	Weighted Average Grant-Date Fair Value		Grant Date Fair Value
				(Dollars in millions)
2018 grants	32,128	10.49		$	0.3
2017 grants	22,628	$	9.85	$	0.2

Summary of information with respect to PSUs

The Company granted the following PSUs during the year ended December 31, 2016:

	ROIC Portion(1)			TSR Portion(2)			Total
	Shares	Fair Value per Share		Shares	Fair Value per Share		Grant Date Fair Value
							(Dollars in millions)
2016 March grant(3)	67,167	$	10.51	201,500	$	6.35	$	2.0
2016 February grant	105,210	$	5.66	105,210	$	5.81	$	1.2

(1) The number of PSUs that ultimately vest will be determined by the Company's three-year average pre-tax return on capital for the Company's coke and logistics businesses. Additionally, only applicable to the 2016 grants, if at any time during the vesting period the closing price of the Company's common stock equals or exceeds $9.00 per share for any 15 trading days, which was met during 2016, the pre-tax return on capital portion of the award, as adjusted, will be multiplied by two.

(2) The number of PSUs that ultimately vest will be determined by the Company's three-year total shareholder return ("TSR") as compared to the TSR of the companies making up the S&P 600.

(3) The final vesting value of the TSR portion of this award cannot exceed $4.9 million.

The following table summarizes information with respect to unearned PSUs outstanding as of December 31, 2018 and PSU activity during the fiscal year then ended:

	Number of PSUs		Weighted Average Grant- Date Fair Value
Nonvested at December 31, 2017	782,781		$	10.06
Granted	96,389		$	11.36
Vested	(1,710	)	$	16.90
Forfeited	(125,085	)	$	17.59
Nonvested at December 31, 2018	752,375		$	8.86

Schedule of unrecognized compensation cost

Below is a summary of the compensation expense, unrecognized compensation costs, the period for which the unrecognized compensation cost is expected to be recognized over and the estimated forfeiture rate for each award:

	Years ended December 31,
	2018		2017		2016		2018		2017		2016		December 31, 2018
	Compensation Expense(1)						Net of tax						Unrecognized Compensation Cost		Recognition Period
	(Dollars in millions)												(Dollars in millions)		(Years)
Equity Awards:
Stock Options	$	0.5	$	1.3	$	2.1	$	0.4	$	0.8	$	1.3	$	0.5	1.6
RSUs	0.4		1.1		2.6		0.3		0.7		1.7		$	0.3	1.7
PSUs	1.9		1.9		1.4		1.7		1.2		0.9		$	2.6	1.9
Total equity awards	$	2.8	$	4.3	$	6.1	$	2.4	$	2.7	$	3.9
Liability Awards:
Cash RSUs	$	0.8	$	1.0	$	0.7	$	0.6	$	0.6	$	0.5	$	0.7	1.4
Cash incentive award	0.9		0.2		0.1		0.7		0.1		0.1		$	0.9	1.8
Total liability awards	$	1.7	$	1.2	$	0.8	$	1.3	$	0.7	$	0.6

(1) Compensation expense is recognized by the Company in selling, general and administrative expenses on the Consolidated Statements of Income.

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Earnings Per Share (Tables)

12 Months Ended

Dec. 31, 2018

Earnings Per Share [Abstract]

Reconciliation of the weighted-average number of common shares used to compute basic earnings per share ("EPS") to those used to compute diluted EPS

The following table sets forth the reconciliation of the weighted-average number of common shares used to compute basic earnings per share to those used to compute diluted EPS:

	Years Ended December 31,
	2018	2017	2016
	(Shares in millions)
Weighted-average number of common shares outstanding-basic	64.7	64.3	64.2
Add: effect of dilutive share-based compensation awards	0.8	0.9	0.2
Weighted-average number of shares-diluted	65.5	65.2	64.4

Schedule of antidilutive securities excluded from computation of earnings per share

The following table shows stock options, restricted stock units, and performance stock units that are excluded from the computation of diluted earnings per share as the shares would have been anti-dilutive:

	Years Ended December 31,
	2018	2017	2016
	(Shares in millions)
Stock options	2.7	2.9	3.0
Restricted stock units	—	—	0.2
Performance stock units	0.1	0.1	0.2
Total	2.8	3.0	3.4

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Revenue from Contracts with Customers (Tables)

12 Months Ended

Dec. 31, 2018

Revenue from Contract with Customer [Abstract]

Changed in Deferred Revenue

The following table provides changes in the Company's deferred revenue:

	2018			2017
	(Dollars in millions)
Beginning balance at December 31, 2017 and 2016, respectively	$	1.7		$	2.5
Reclassification of the beginning contract liabilities to revenue, as a result of performance obligation satisfied	(1.4		)	(2.1		)
Billings in excess of services performed, not recognized as revenue	2.7			1.3
Ending balance at December 31, 2018 and 2017, respectively	$	3.0		$	1.7

Disaggregation of Revenue

The following table provides disaggregated sales and other operating revenue by product or service, excluding intersegment revenues:

	Years Ended December 31,
	2018		2017		2016
	(Dollars in millions)
Sales and other operating revenue:
Cokemaking	$	1,250.5	$	1,140.8	$	1,038.2
Energy	49.7		53.2		54.3
Logistics	101.0		89.7		82.9
Operating and licensing fees	40.4		43.4		39.5
Other	9.3		4.4		8.4
Sales and other operating revenue	$	1,450.9	$	1,331.5	$	1,223.3

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Business Segment Information (Tables)

12 Months Ended

Dec. 31, 2018

Segment Reporting [Abstract]

Business segment information

The following table includes Adjusted EBITDA, which is the measure of segment profit or loss and liquidity reported to the chief operating decision maker for purposes of allocating resources to the segments and assessing their performance:

	Years Ended December 31,
	2018			2017			2016
	(Dollars in millions)
Sales and other operating revenue:
Domestic Coke	$	1,308.3		$	1,195.0		$	1,097.6
Brazil Coke	40.4			43.4			39.5
Logistics	102.2			93.1			84.7
Logistics intersegment sales	24.5			23.8			23.2
Corporate and Other(1)	—			—			1.5
Corporate and Other intersegment sales(1)	—			—			22.0
Elimination of intersegment sales	(24.5		)	(23.8		)	(45.2		)
Total sales and other operating revenue	$	1,450.9		$	1,331.5		$	1,223.3
Adjusted EBITDA
Domestic Coke	$	207.9		$	188.9		$	193.9
Brazil Coke	18.4			18.2			16.2
Logistics	72.6			70.8			63.9
Corporate and Other(2)	(35.7		)	(43.2		)	(57.0		)
Total Adjusted EBITDA	$	263.2		$	234.7		$	217.0
Depreciation and amortization expense:
Domestic Coke(3)	$	114.4		$	102.6		$	84.0
Brazil Coke	0.7			0.7			0.7
Logistics	25.1			24.4			24.8
Corporate and Other	1.4			0.5			4.7
Total depreciation and amortization expense	$	141.6		$	128.2		$	114.2
Capital expenditures:
Domestic Coke	$	95.1		$	68.8		$	44.6
Logistics	5.2			4.4			17.4
Corporate and Other	—			2.4			1.7
Total capital expenditures	$	100.3		$	75.6		$	63.7

(1) Corporate and Other revenues are related to our legacy coal mining business, which was disposed in April 2016.

(2) Corporate and Other includes the activity from our legacy coal mining business, which incurred Adjusted EBITDA losses of $9.8 million, $10.5 million, and $15.0 million for the years ended December 31, 2018, 2017 and 2016, respectively.

(3) We revised the estimated useful lives of certain assets in our Domestic Coke segment, primarily as a result of plans to replace major components of certain heat recovery steam generators with upgraded materials and design, resulting in additional depreciation of $9.2 million, or $0.14 per common share, during the year ended December 31, 2018.

The following table sets forth the Company’s segment assets:

	December 31,
	2018		2017
	(Dollars in millions)
Segment assets
Domestic Coke	$	1,446.5	$	1,439.7
Brazil Coke	15.1		10.9
Logistics	463.0		491.9
Corporate and Other	120.0		112.8
Segment assets, excluding income tax receivable	2,044.6		2,055.3
Tax assets	0.7		4.8
Total assets	$	2,045.3	$	2,060.1

Reconciliation of Adjusted EBITDA (unaudited) to net income

elow are reconciliations of Adjusted EBITDA to net income and Adjusted EBITDA to net cash provided by operating activities, which are its most directly comparable financial measures calculated and presented in accordance with GAAP:

	Years Ended December 31,
	2018			2017			2016
	(Dollars in millions)
Net cash provided by operating activities	$	185.8		$	148.5		$	219.1
Subtract:
Depreciation and amortization expense	141.6			128.2			114.2
Deferred income tax (benefit) expense	(3.4		)	(87.2		)	3.1
Loss (gain) on extinguishment of debt	0.3			20.4			(25.0		)
Loss on divestiture of business	—			—			14.7
Loss from equity method investment	5.4			—			—
Changes in working capital and other	(5.1		)	(16.4		)	52.6
Net income	$	47.0		$	103.5		$	59.5
Add:
Depreciation and amortization expense	141.6			128.2			114.2
Interest expense, net(1)	61.4			60.6			53.5
Loss (gain) on extinguishment of debt	0.3			20.4			(25.0		)
Income tax expense (benefit)	4.6			(81.6		)	8.6
Contingent consideration adjustments(2)	2.5			(1.7		)	(10.1		)
Transaction costs(3)	0.4			—			—
Expiration of land deposits and write-off of costs related to potential new cokemaking facility(4)	—			5.3			1.9
Non-cash reversal of acquired contractual obligation(5)	—			—			(0.7		)
Loss on divestiture of business	—			—			14.7
Coal rationalization costs(6)	—			—			0.4
Loss from equity method investment	5.4			—			—
Adjusted EBITDA	$	263.2		$	234.7		$	217.0
Subtract: Adjusted EBITDA attributable to noncontrolling interest(7)	82.0			86.4			86.6
Adjusted EBITDA attributable to SunCoke Energy, Inc.	$	181.2		$	148.3		$	130.4

(1) In conjunction with the adoption of ASU 2017-07, the non-service type expense associated with the postretirement benefit plans was excluded from operating income and recorded in interest expense, net on the Consolidated Statements of Income during the periods presented. Amounts in prior periods were immaterial, and therefore, were not reclassified in the reconciliation of Adjusted EBITDA to net income and net cash provided by operating activities.

(2) Adjustments to the fair value of the contingent consideration in 2018, 2017 and 2016 were primarily the result of modifications to the volume forecast. See Note 17.

(3) Represents costs incurred in connection with the Simplification Transaction.

(4) In 2014, we finalized the required permitting and engineering plan for a potential new cokemaking facility, however, the project was terminated. As a result, during 2017 and 2016, the Company wrote-off previously capitalized engineering costs and land deposits for a potential new cokemaking facility of $5.3 million and $1.9 million, respectively. These costs were included in selling, general and administrative expenses on the Consolidated Statements of Income.

(5) In association with the acquisition of CMT, we assumed certain performance obligations under existing contracts and recorded liabilities related to such obligations. In 2016, the Partnership reversed the liability as we no longer had any obligations under the contracts.

(6) Prior to the divestiture of our coal mining business, the Company incurred coal rationalization costs including employee severance, contract termination costs and other costs to idle mines during the execution of our coal rationalization plan.

(7) Reflects noncontrolling interests in Indiana Harbor and the portion of the Partnership owned by public unitholders.

XML

Selected Quarterly Data (unaudited) (Tables)

12 Months Ended

Dec. 31, 2018

Quarterly Financial Information Disclosure [Abstract]

Schedule of quarterly financial information

	2018								2017
	First Quarter		Second Quarter		Third Quarter		Fourth Quarter(1)		First Quarter(2)			Second Quarter(3)			Third Quarter		Fourth Quarter(1)(4)
	(Dollars in millions)
Sales and other operating revenue	$	350.5	$	367.0	$	364.5	$	368.9	$	309.7		$	323.2		$	339.0	$	359.6
Gross profit(5)	$	47.0	$	52.3	$	45.8	$	39.7	$	42.2		$	32.9		$	51.3	$	56.8
Net income (loss)	$	13.0	$	11.4	$	17.1	$	5.5	$	(57.7	)	$	(31.5	)	$	18.8	$	173.9
Less: Net income (loss) attributable to noncontrolling interests	$	4.3	$	7.2	$	5.6	$	3.7	$	(58.7	)	$	(7.3	)	$	7.2	$	39.9
Net income (loss) attributable to SunCoke Energy, Inc.	$	8.7	$	4.2	$	11.5	$	1.8	$	1.0		$	(24.2	)	$	11.6	$	134.0
Earnings (loss) attributable to SunCoke Energy, Inc. per common share:
Basic(6)	$	0.13	$	0.06	$	0.18	$	0.03	$	0.02		$	(0.38	)	$	0.18	$	2.08
Diluted(6)	$	0.13	$	0.06	$	0.18	$	0.03	$	0.02		$	(0.38	)	$	0.18	$	2.05

(1) The Partnership recognized deferred revenue from Logistics take-or-pay billings for minimum volume shortfalls of $16.4 million into revenue in the fourth quarter of 2017. As a result of the increase in tons handled throughout 2018, there were no shortfalls to be recognized during the fourth quarter.

(2) The first quarter of 2017 reflects the net impact to the Company’s deferred tax expense of $64.2 million related to the IRS Final Regulations on qualifying income all of which was attributable to unitholders of the Partnership. See Note 5.

(3) During the second quarter of 2017, the Partnership incurred $20.2 million of losses in connection with debt refinancing.

(4) During the fourth quarter of 2017, the Company recorded $154.7 million of tax benefits as a result of the new Tax Legislation, $125.0 million of which was attributable to the Company. See Note 5.

(5) Gross profit equals sales and other operating revenue less cost of products sold and operating expenses and depreciation and amortization.

(6) Basic and diluted earnings per share are computed independently for each of the quarters presented. Therefore, the sum of quarterly basic and diluted per share information may not equal annual basic and diluted earnings per share.

XML

Supplemental Condensed Combining and Consolidating Financial Information (Tables)

12 Months Ended

Dec. 31, 2018

Condensed Financial Information Disclosure [Abstract]

Condensed Consolidating Statement of Income

SunCoke Energy, Inc.

Condensed Consolidating Statement of Income

Years Ended December 31, 2018

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Revenues
Sales and other operating revenue	$	—		$	216.0		$	1,239.5		$	(4.6	)	$	1,450.9
Equity in earnings of subsidiaries	34.3			25.2			—			(59.5		)	—
Total revenues, net of equity in earnings of subsidiaries	34.3			241.2			1,239.5			(64.1		)	1,450.9
Costs and operating expenses
Cost of products sold and operating expenses	—			165.7			963.4			(4.6		)	1,124.5
Selling, general and administrative expenses	6.5			11.8			47.8			—			66.1
Depreciation and amortization expenses	—			8.8			132.8			—			141.6
Total costs and operating expenses	6.5			186.3			1,144.0			(4.6		)	1,332.2
Operating income	27.8			54.9			95.5			(59.5		)	118.7
Interest (income) expense, net - affiliate	—			(6.0		)	6.0			—			—
Interest expense (income), net	3.1			(1.6		)	59.9			—			61.4
Total interest expense (income), net	3.1			(7.6		)	65.9			—			61.4
Loss on extinguishment of debt	0.3			—			—			—			0.3
Income before income tax (benefit) expense	24.4			62.5			29.6			(59.5		)	57.0
Income tax (benefit) expense	(1.8		)	12.1			(5.7		)	—			4.6
Loss from equity method investment	—			—			5.4			—			5.4
Net income	26.2			50.4			29.9			(59.5		)	47.0
Less: Net income attributable to noncontrolling interests	—			—			20.8			—			20.8
Net income attributable to SunCoke Energy, Inc.	$	26.2		$	50.4		$	9.1		$	(59.5	)	$	26.2
Comprehensive income	$	34.3		$	50.6		$	37.8		$	(67.6	)	$	55.1
Less: Comprehensive income attributable to noncontrolling interests	—			—			20.8			—			20.8
Comprehensive income attributable to SunCoke Energy, Inc.	$	34.3		$	50.6		$	17.0		$	(67.6	)	$	34.3

SunCoke Energy, Inc.

Condensed Consolidating Statement of Income

Years Ended December 31, 2017

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Revenues
Sales and other operating revenue	$	—		$	209.6		$	1,126.3		$	(4.4	)	$	1,331.5
Equity in earnings (loss) of subsidiaries	109.9			(54.5		)	—			(55.4		)	—
Total revenues, net of equity in earnings (loss) of subsidiaries	109.9			155.1			1,126.3			(59.8		)	1,331.5
Costs and operating expenses
Cost of products sold and operating expenses	—			156.6			867.9			(4.4		)	1,020.1
Selling, general and administrative expenses	8.7			22.7			47.6			—			79.0
Depreciation and amortization expenses	—			7.5			120.7			—			128.2
Total costs and operating expenses	8.7			186.8			1,036.2			(4.4		)	1,227.3
Operating income (loss)	101.2			(31.7		)	90.1			(55.4		)	104.2
Interest (income) expense, net - affiliate	—			(7.5		)	7.5			—			—
Interest expense, net	4.9			0.1			56.9			—			61.9
Total interest expense (income), net	4.9			(7.4		)	64.4			—			61.9
Gain on extinguishment of debt	0.4			—			20.0			—			20.4
Income (loss) before income tax (benefit) expense	95.9			(24.3		)	5.7			(55.4		)	21.9
Income tax (benefit) expense	(26.5		)	(150.2		)	95.1			—			(81.6		)
Net income (loss)	122.4			125.9			(89.4		)	(55.4		)	103.5
Less: Net loss attributable to noncontrolling interests	—			—			(18.9		)	—			(18.9		)
Net income (loss) attributable to SunCoke Energy, Inc.	$	122.4		$	125.9		$	(70.5	)	$	(55.4	)	$	122.4
Comprehensive income (loss)	$	121.3		$	125.3		$	(91.0	)	$	(53.2	)	$	102.4
Less: Comprehensive loss attributable to noncontrolling interests	—			—			(18.9		)	—			(18.9		)
Comprehensive income (loss) attributable to SunCoke Energy, Inc.	$	121.3		$	125.3		$	(72.1	)	$	(53.2	)	$	121.3

SunCoke Energy, Inc.

Condensed Consolidating Statement of Income

Years Ended December 31, 2016

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Revenues
Sales and other operating revenue	$	—		$	176.7		$	1,050.5		$	(3.9	)	$	1,223.3
Equity in earnings of subsidiaries	19.7			51.3			—			(71.0		)	—
Total revenues, net of equity in earnings of subsidiaries	19.7			228.0			1,050.5			(74.9		)	1,223.3
Costs and operating expenses
Cost of products sold and operating expenses	—			130.7			779.1			(3.9		)	905.9
Selling, general and administrative expenses	12.9			25.6			52.1			—			90.6
Depreciation and amortization expenses	—			9.2			105.0			—			114.2
Loss on divestiture of business and impairments	—			—			14.7			—			14.7
Total costs and operating expenses	12.9			165.5			950.9			(3.9		)	1,125.4
Operating income	6.8			62.5			99.6			(71.0		)	97.9
Interest (income) expense, net - affiliate	—			(7.6		)	7.6			—			—
Interest expense, net	6.0			0.3			48.5			—			54.8
Total interest expense (income), net	6.0			(7.3		)	56.1			—			54.8
Gain on extinguishment of debt, net	—			—			(25.0		)	—			(25.0		)
Income before income tax (benefit) expense and loss (gain) from equity method investment	0.8			69.8			68.5			(71.0		)	68.1
Income tax (benefit) expense	(13.6		)	38.7			(16.5		)	—			8.6
Net income	14.4			31.1			85.0			(71.0		)	59.5
Less: Net income attributable to noncontrolling interests	—			—			45.1			—			45.1
Net income attributable to SunCoke Energy, Inc.	$	14.4		$	31.1		$	39.9		$	(71.0	)	$	14.4
Comprehensive income	$	15.2		$	30.8		$	86.1		$	(71.8	)	$	60.3
Less: Comprehensive income attributable to noncontrolling interests	—			—			45.1			—			45.1
Comprehensive income attributable to SunCoke Energy, Inc.	$	15.2		$	30.8		$	41.0		$	(71.8	)	$	15.2

Condensed Consolidating Balance Sheet

SunCoke Energy, Inc.

Condensed Consolidating Balance Sheet

December 31, 2018

(Dollars in millions, except per share amounts)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Assets
Cash and cash equivalents	$	—		$	123.2		$	22.5		$	—		$	145.7
Receivables	—			13.3			62.1			—			75.4
Inventories	—			10.6			99.8			—			110.4
Income tax receivable	—			—			96.1			(95.4		)	0.7
Other current assets	—			1.8			1.0			—			2.8
Advances to affiliates	—			281.1			—			(281.1		)	—
Total current assets	—			430.0			281.5			(376.5		)	335.0
Notes receivable from affiliate	—			—			200.0			(200.0		)	—
Properties, plants and equipment, net	—			54.3			1,416.8			—			1,471.1
Goodwill	—			3.4			73.5			—			76.9
Other intangibles assets, net	—			1.1			155.7			—			156.8
Deferred income taxes	7.0			—			—			(7.0		)	—
Deferred charges and other assets	—			5.1			0.4			—			5.5
Total assets	$	7.0		$	493.9		$	2,127.9		$	(583.5	)	$	2,045.3
Liabilities and Equity
Advances from affiliate	$	167.3		$	—		$	113.8		$	(281.1	)	$	—
Accounts payable	—			14.7			100.3			—			115.0
Accrued liabilities	1.8			13.7			30.1			—			45.6
Deferred revenue	—			—			3.0			—			3.0
Current portion of long-term debt and financing obligation	1.1			—			2.8			—			3.9
Interest payable	0.4			—			3.2			—			3.6
Income taxes payable	1.9			93.5			—			(95.4		)	—
Total current liabilities	172.5			121.9			253.2			(376.5		)	171.1
Long term-debt and financing obligation	41.2			—			793.3			—			834.5
Payable to affiliate	—			200.0			—			(200.0		)	—
Accrual for black lung benefits	—			10.9			34.0			—			44.9
Retirement benefit liabilities	—			12.2			13.0			—			25.2
Deferred income taxes	—			194.9			66.8			(7.0		)	254.7
Asset retirement obligations	—			—			14.6			—			14.6
Other deferred credits and liabilities	3.5			6.6			7.5			—			17.6
Total liabilities	217.2			546.5			1,182.4			(583.5		)	1,362.6
Equity
Preferred stock, $0.01 par value. Authorized 50,000,000 shares; no issued and outstanding shares at December 31, 2018	—			—			—			—			—
Common stock, $0.01 par value. Authorized 300,000,000 shares; issued 72,223,750 shares at December 31, 2018	0.7			—			—			—			0.7
Treasury stock, 7,477,657 shares at December 31, 2018	(140.7		)	—			—						(140.7		)
Additional paid-in capital	488.9			61.0			612.8			(673.9		)	488.8
Accumulated other comprehensive loss	(13.1		)	(2.0		)	(11.1		)	13.1			(13.1		)
Retained earnings	127.5			526.1			124.2			(650.4		)	127.4
Equity investment eliminations	(673.5		)	(637.7		)	—			1,311.2			—
Total SunCoke Energy, Inc. stockholders’ equity	(210.2		)	(52.6		)	725.9			—			463.1
Noncontrolling interests	—			—			219.6			—			219.6
Total equity	(210.2		)	(52.6		)	945.5			—			682.7
Total liabilities and equity	$	7.0		$	493.9		$	2,127.9		$	(583.5	)	$	2,045.3

SunCoke Energy, Inc.

Condensed Consolidating Balance Sheet

December 31, 2017

(Dollars in millions, except per share amounts)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Assets
Cash and cash equivalents	$	—		$	103.6		$	16.6		$	—		$	120.2
Receivables	—			17.1			51.4			—			68.5
Inventories	—			9.1			101.9			—			111.0
Income taxes receivable	—			—			88.1			(83.3		)	4.8
Other current assets	—			4.6			2.1			—			6.7
Advances to affiliate	—			245.8			—			(245.8		)	—
Total current assets	—			380.2			260.1			(329.1		)	311.2
Notes receivable from affiliate	—			89.0			300.0			(389.0		)	—
Properties, plants and equipment, net	—			59.8			1,441.5			—			1,501.3
Goodwill	—			3.4			73.5			—			76.9
Other intangible assets, net	—			1.7			166.2			—			167.9
Deferred income taxes	7.1			—			—			(7.1		)	—
Deferred charges and other assets	—			2.3			0.5			—			2.8
Total assets	$	7.1		$	536.4		$	2,241.8		$	(725.2	)	$	2,060.1
Liabilities and Equity
Advances from affiliate	$	162.2		$	—		$	83.6		$	(245.8	)	$	—
Accounts payable	—			16.4			99.1			—			115.5
Accrued liabilities	1.5			19.7			32.0			—			53.2
Deferred Revenue	—			—			1.7			—			1.7
Current portion of long-term debt and financing obligation	—			—			2.6			—			2.6
Interest payable	1.4			—			4.0			—			5.4
Income taxes payable	1.9			81.4			—			(83.3		)	—
Total current liabilities	167.0			117.5			223.0			(329.1		)	178.4
Long-term debt and financing obligation	42.7			—			818.4			—			861.1
Payable to affiliate	—			300.0			89.0			(389.0		)	—
Accrual for black lung benefits	—			11.8			33.1			—			44.9
Retirement benefit liabilities	—			13.7			14.5			—			28.2
Deferred income taxes	—			193.8			71.1			(7.1		)	257.8
Asset retirement obligations	—			—			14.0			—			14.0
Other deferred credits and liabilities	3.7			6.4			6.0			—			16.1
Total liabilities	213.4			643.2			1,269.1			(725.2		)	1,400.5
Equity
Preferred stock, $0.01 par value. Authorized 50,000,000 shares; no issued and outstanding shares at December 31, 2017	—			—			—			—			—
Common stock, $0.01 par value. Authorized 300,000,000 shares; issued 71,707,304 shares at December 31, 2017	0.7			—			—			—			0.7
Treasury stock, 7,477,657 shares at December 31, 2017	(140.7		)	—			—			—			(140.7		)
Additional paid-in capital	486.2			141.0			641.9			(782.9		)	486.2
Accumulated other comprehensive loss	(21.2		)	(2.2		)	(19.0		)	21.2			(21.2		)
Retained earnings	101.2			475.6			116.4			(592.0		)	101.2
Equity investment eliminations	(632.5		)	(721.2		)	—			1,353.7			—
Total SunCoke Energy, Inc. stockholders’ equity	(206.3		)	(106.8		)	739.3			—			426.2
Noncontrolling interests	—			—			233.4			—			233.4
Total equity	(206.3		)	(106.8		)	972.7			—			659.6
Total liabilities and equity	$	7.1		$	536.4		$	2,241.8		$	(725.2	)	$	2,060.1

Condensed Combining and Consolidating Statement of Cash Flows

SunCoke Energy, Inc.

Condensed Consolidating Statement of Cash Flows

Years Ended December 31, 2018

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Cash Flows from Operating Activities:
Net income (loss)	$	26.2		$	50.4		$	29.9		$	(59.5	)	$	47.0
Adjustments to reconcile net income to net cash (used in) provided by operating activities:
Loss from equity method investment	—			—			5.4			—			5.4
Depreciation and amortization expense	—			8.8			132.8			—			141.6
Deferred income tax (benefit) expense	(0.2		)	1.2			(4.4		)	—			(3.4		)
Gain on curtailment and payments in excess of expense for postretirement plan benefits	—			(1.0		)	(1.4		)	—			(2.4		)
Share-based compensation expense	3.1			—			—			—			3.1
Equity in loss of subsidiaries	(34.3		)	(25.2		)	—			59.5			—
Loss on extinguishment of debt	0.3			—			—			—			0.3
Changes in working capital pertaining to operating activities:
Receivables	—			3.8			(10.7		)	—			(6.9		)
Inventories	—			(1.5		)	2.1			—			0.6
Accounts payable	—			(1.6		)	0.9			—			(0.7		)
Accrued liabilities	0.4			(5.9		)	(1.8		)	—			(7.3		)
Deferred revenue	—			—			1.3			—			1.3
Interest payable	(1.0		)	—			(0.8		)	—			(1.8		)
Income taxes	0.3			12.2			(8.0		)	—			4.5
Other	0.3			(0.9		)	5.1			—			4.5
Net cash (used in) provided by operating activities	(4.9		)	40.3			150.4			—			185.8
Cash Flows from Investing Activities:
Capital expenditures	—			(2.8		)	(97.5		)	—			(100.3		)
Sale of equity method investment	—			—			4.0			—			4.0
Other investing activities	—			—			0.5			—			0.5
Net cash used in investing activities	—			(2.8		)	(93.0		)	—			(95.8		)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt	45.0			—			—			—			45.0
Repayment of long-term debt	(45.7		)	—			—			—			(45.7		)
Debt issuance costs	(0.5		)	—			—			—			(0.5		)
Proceeds from revolving facility	—			—			179.5			—			179.5
Repayment of revolving facility	—			—			(204.5		)	—			(204.5		)
Repayment of financing obligation	—			—			(2.6		)	—			(2.6		)
Cash distributions to noncontrolling interests	—			—			(31.9		)	—			(31.9		)
Acquisition of additional interest in the Partnership	—			(4.2		)	—			—			(4.2		)
Other financing activities	0.7			—			(0.3		)	—			0.4
Net increase (decrease) in advances from affiliates	5.4			(13.7		)	8.3			—			—
Net cash provided by (used in) financing activities	4.9			(17.9		)	(51.5		)	—			(64.5		)
Net increase in cash, cash equivalents and restricted cash	—			19.6			5.9			—			25.5
Cash, cash equivalents and restricted cash at beginning of year	—			103.6			16.6			—			120.2
Cash, cash equivalents and restricted cash at end of year	$	—		$	123.2		$	22.5		$	—		$	145.7

SunCoke Energy, Inc.

Condensed Consolidating Statement of Cash Flows

Years Ended December 31, 2017

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Cash Flows from Operating Activities:
Net income (loss)	$	122.4		$	125.9		$	(89.4	)	$	(55.4	)	$	103.5
Adjustments to reconcile net income (loss) to net cash (used in) provided by operating activities:
Depreciation and amortization expense	—			7.5			120.7			—			128.2
Deferred income tax (benefit) expense	(22.8		)	(170.1		)	105.7			—			(87.2		)
Gain on curtailment and payments in excess of expense for postretirement plan benefits	—			(1.0		)	(0.8		)	—			(1.8		)
Share-based compensation expense	4.7			—			0.1			—			4.8
Equity in (loss) earnings of subsidiaries	(109.9		)	54.5			—			55.4			—
Loss on extinguishment of debt	0.4			—			20.0			—			20.4
Changes in working capital pertaining to operating activities (net of the effects of divestiture):
Receivables	—			(4.9		)	(2.9		)	—			(7.8		)
Inventories	—			(0.1		)	(18.4		)	—			(18.5		)
Accounts payable	—			3.0			8.7			—			11.7
Accrued liabilities	(0.2		)	(1.3		)	4.1			—			2.6
Deferred revenue	—			—			(0.8		)	—			(0.8		)
Interest payable	(0.1		)	—			(10.7		)	—			(10.8		)
Income taxes	(2.7		)	16.3			(13.8		)	—			(0.2		)
Other	1.3			—			3.1			—			4.4
Net cash (used in) provided by operating activities	(6.9		)	29.8			125.6			—			148.5
Cash Flows from Investing Activities:
Capital expenditures	—			(4.1		)	(71.5		)	—			(75.6		)
Return of Brazilian investment	—			—			20.5			—			20.5
Net cash used in investing activities	—			(4.1		)	(51.0		)	—			(55.1		)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt	—			—			693.7			—			693.7
Repayment of long-term debt	—			—			(644.9		)	—			(644.9		)
Debt issuance costs	(1.6		)	—			(15.8		)	—			(17.4		)
Proceeds from revolving facility	—			—			350.0			—			350.0
Repayment of revolving facility	—			—			(392.0		)	—			(392.0		)
Repayment of financing obligation	—			—			(2.5		)	—			(2.5		)
Cash distributions to noncontrolling interests	—			—			(47.0		)	—			(47.0		)
Acquisition of additional interest in the Partnership	—			(48.7		)	—			—			(48.7		)
Other financing activities	1.1			—			—			—			1.1
Net increase (decrease) in advances from affiliates	7.4			66.9			(74.3		)	—			—
Net cash provided by (used in) financing activities	6.9			18.2			(132.8		)	—			(107.7		)
Net increase (decrease) in cash, cash equivalents and restricted cash	—			43.9			(58.2		)	—			(14.3		)
Cash, cash equivalents and restricted cash at beginning of year	—			59.7			74.8			—			134.5
Cash, cash equivalents and restricted cash at end of year	$	—		$	103.6		$	16.6		$	—		$	120.2

SunCoke Energy, Inc.

Condensed Consolidating Statement of Cash Flows

December 31, 2016

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Cash Flows from Operating Activities:
Net income	$	14.4		$	31.1		$	85.0		$	(71.0	)	$	59.5
Adjustments to reconcile net income to net cash (used in) provided by operating activities:
Depreciation and amortization expense	—			9.2			105.0			—			114.2
Deferred income tax (benefit) expense	(16.6		)	8.7			11.0			—			3.1
Gain on curtailment and payments in excess of expense for postretirement plan benefits	—			(1.5		)	(1.1		)	—			(2.6		)
Share-based compensation expense	6.5			—			—			—			6.5
Equity in loss of subsidiaries	(19.7		)	(51.3		)	—			71.0			—
Gain on extinguishment of debt	—			—			(25.0		)	—			(25.0		)
Loss on divestiture of business and impairments	—			—			14.7			—			14.7
Changes in working capital pertaining to operating activities (net of acquisitions):
Receivables	—			(4.3		)	8.0			—			3.7
Inventories	—			(3.7		)	33.1			—			29.4
Accounts payable	—			4.6			(5.4		)	—			(0.8		)
Accrued liabilities	1.5			4.8			0.5			—			6.8
Deferred revenue	—			—			0.4			—			0.4
Interest payable	0.1			—			(2.8		)	—			(2.7		)
Income taxes	(6.9		)	28.2			(14.3		)	—			7.0
Other	2.5			8.9			(6.5		)	—			4.9
Net cash (used in) provided by operating activities	(18.2		)	34.7			202.6			—			219.1
Cash Flows from Investing Activities:
Capital expenditures	—			(5.7		)	(58.0		)	—			(63.7		)
Return of Brazilian investment	—			—			20.5			—			20.5
Divestiture of coal business	—			—			(12.8		)	—			(12.8		)
Other investing activities	—			—			2.1			—			2.1
Net cash used in investing activities	—			(5.7		)	(48.2		)	—			(53.9		)
Cash Flows from Financing Activities:
Repayment of long-term debt	—			—			(66.1		)	—			(66.1		)
Debt issuance costs	—			—			(0.2		)	—			(0.2		)
Proceeds from revolving facility	—			—			28.0			—			28.0
Repayment of revolving facility	(60.4		)	—			(38.0		)	—			(98.4		)
Proceeds from financing obligation	—			—			16.2			—			16.2
Repayment of financing obligation	—			—			(1.0		)	—			(1.0		)
Cash distributions to noncontrolling interests	—			—			(49.4		)	—			(49.4		)
Other financing activities	(0.3		)	(1.1		)	—			—			(1.4		)
Net increase (decrease) in advances from affiliates	78.9			(38.8		)	(40.1		)	—			—
Net cash provided by (used in) financing activities	18.2			(39.9		)	(150.6		)	—			(172.3		)
Net (decrease) increase in cash, cash equivalents and restricted cash	—			(10.9		)	3.8			—			(7.1		)
Cash, cash equivalents and restricted cash at beginning of year	—			70.6			71.0			—			141.6
Cash, cash equivalents and restricted cash at end of year	$	—		$	59.7		$	74.8		$	—		$	134.5

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General and Basis of Presentation (Details) $ in Millions		1 Months Ended	5 Months Ended	12 Months Ended
	Jun. 27, 2018 USD ($)	Apr. 30, 2016 USD ($)	Dec. 31, 2017	Dec. 31, 2018 USD ($) Cokemaking_facility T	Dec. 31, 2017 USD ($)	Dec. 31, 2016 USD ($)	Feb. 05, 2019
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Coke production experience, more than				55 years
Period that Suncoke constructed the only greenfield cokemaking facilities in the US				30 years
Sale of equity method investment				$ 4.0	$ 0.0	$ 0.0
Recognition of accumulated currency translation loss upon sale of equity method investment				9.0	0.0	0.0
Transaction costs				0.4	0.0	0.0
Loss from equity method investment				5.4	0.0	0.0
Divestiture of coal business				$ 0.0	$ 0.0	12.8
SunCoke Energy Partners, L.P. | Subsequent Event
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Common Stock, Conversion Per Share							1.40
Indiana Harbor
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Ownership percentage (as a percent)				14.80%
SunCoke Energy Partners, L.P.
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Ownership interest of general partnership (as a percent)				2.00%
Interest in partnership (as a percent)			60.40%
VISA SunCoke Limited
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Ownership percentage (as a percent)	49.00%
Public Unitholders
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Ownership percentage held by public unitholders				37.60%
VISA SunCoke Limited
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Sale of equity method investment	$ 4.0
Recognition of accumulated currency translation loss upon sale of equity method investment	$ 9.0
Transaction costs				$ 0.4
Loss from equity method investment				$ 5.4
Disposal Group, Held-for-sale, Not Discontinued Operations | Remaining Coal Mining Assets, Mineral Leases, Real Estate, and a Substantial Portion of Mining Reclamation Obligations | Coal Mining
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Divestiture of coal business		$ 12.8
Gain (Loss) on Divestiture of Business | Disposal Group, Held-for-sale, Not Discontinued Operations | Remaining Coal Mining Assets, Mineral Leases, Real Estate, and a Substantial Portion of Mining Reclamation Obligations | Coal Mining
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Gain (loss) on divestiture						$ (14.7)
United States
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Number of facilities | Cokemaking_facility				5
Cokemaking capacity (in tons) | T				4,200,000
Brazil
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Number of facilities | Cokemaking_facility				1
Cokemaking capacity (in tons) | T				1,700,000
Convent, Louisiana, East Chicago, Indiana, West Virginia
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Coal handling capacity (in tons), more than | T				40,000,000
Coal storage capacity (in tons) | T				3,000,000

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Summary of Significant Accounting Policies (Details) $ in Millions	12 Months Ended
	Dec. 31, 2018 USD ($) Employee	Dec. 31, 2017 USD ($)	Dec. 31, 2016 USD ($)	Nov. 28, 2016 USD ($)
Revenue Recognition
Contingent rentals as a percent of combined sales, less than	10.00%	10.00%	10.00%
Property, Plant and Equipment
Interest costs capitalized	$ 3.2	$ 1.1	$ 5.0
Investment in Brazilian Cokemaking Operations
Cash at closing	0.0	20.5	20.5
Incremental licensing fee per year	$ 5.1
Labor Concentrations
Number of employees | Employee	895
Percentage of domestic employees	3.00%
Vitoria, Brazil
Labor Concentrations
Number of employees | Employee	285
Cokemaking Operations
Labor Concentrations
Percentage of domestic employees	40.00%
ArcelorMittal Brazil
Investment in Brazilian Cokemaking Operations
Cash at closing		20.5	$ 20.5
Investment interest		$ 0.2
ArcelorMittal Brazil | Brazil Investment
Investment in Brazilian Cokemaking Operations
Consideration transferred				$ 41.0
Coke and energy plant, machinery and equipment | Minimum
Property, Plant and Equipment
Useful life	25 years
Coke and energy plant, machinery and equipment | Maximum
Property, Plant and Equipment
Useful life	30 years
Logistics plant, machinery and equipment | Minimum
Property, Plant and Equipment
Useful life	15 years
Logistics plant, machinery and equipment | Maximum
Property, Plant and Equipment
Useful life	35 years

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Summary of Significant Accounting Policies - Accounting Pronouncements (Details) - USD ($)	3 Months Ended	12 Months Ended
	Mar. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jan. 01, 2019	Dec. 31, 2018
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Assets		$ 2,060,100,000			$ 2,045,300,000
Liabilities		1,400,500,000			1,362,600,000
ASU 2016-18
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Restricted cash		0			$ 0
ASU 2017-07
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Expense		1,300,000	$ 1,300,000
ASU 2018-02
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Deferred tax adjustments	$ 1,100,000	$ 1,100,000
AS 2016-02 | Minimum | Subsequent Event
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Assets				$ 5,000,000
Liabilities				5,000,000
AS 2016-02 | Maximum | Subsequent Event
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Assets				10,000,000
Liabilities				$ 10,000,000

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Acquisition of Noncontrolling Interest (Details) - USD ($)	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Subsidiary, Sale of Stock [Line Items]
Cash paid									$ 4,200,000	$ 48,700,000	$ 0
Decrease in noncontrolling interest									4,200,000	48,700,000
Decrease in additional paid-in capital									1,200,000	12,000,000
Deferred tax adjustment									300,000	7,100,000
Change in Ownership Interest
Net income attributable to SunCoke Energy, Inc	$ 1,800,000	$ 11,500,000	$ 4,200,000	$ 8,700,000	$ 134,000,000	$ 11,600,000	$ (24,200,000)	$ 1,000,000	26,200,000	122,400,000	$ 14,400,000
Decrease in SunCoke Energy, Inc. equity for the purchase of additional interest in the Partnership									(1,200,000)	(12,000,000)
Changes from net income attributable to SunCoke Energy, Inc and transfers to noncontrolling interest									25,000,000	110,400,000
Public Unit Purchase Program
Subsidiary, Sale of Stock [Line Items]
Authorized purchase amount					$ 100,000,000					$ 100,000,000
Remaining balance	$ 47,100,000								$ 47,100,000
Units purchased (in shares)									231,171	2,853,032
Cash paid									$ 4,200,000	$ 48,700,000
Decrease in noncontrolling interest									2,700,000	29,600,000
Decrease in additional paid-in capital									1,200,000	12,000,000
Deferred tax adjustment									300,000	7,100,000
Change in Ownership Interest
Decrease in SunCoke Energy, Inc. equity for the purchase of additional interest in the Partnership									$ (1,200,000)	$ (12,000,000)

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Customer Concentrations (Narrative) (Details) - Customer Concentration Risk T in Millions	12 Months Ended
	Dec. 31, 2018 Customer T
Concentration Risk [Line Items]
Quantity of coke sold to three primary customers (in tons) | T	4
Number of primary customers in U.S	3
Accounts Receivable
Concentration Risk [Line Items]
Number of primary customers in U.S	3

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Customer Concentrations (Sales and Receivables to Significant Customers) (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Concentration Risk [Line Items]
Sales and other operating revenue	$ 368.9	$ 364.5	$ 367.0	$ 350.5	$ 359.6	$ 339.0	$ 323.2	$ 309.7	$ 1,450.9	$ 1,331.5	$ 1,223.3
AM USA and ArcelorMittal Brazil | Sales Revenue, Net | Customer Concentration Risk
Concentration Risk [Line Items]
Sales and other operating revenue									$ 735.8	$ 678.2	$ 596.6
Percent of Company sales and other operating revenue									50.70%	50.90%	48.80%
AM USA and ArcelorMittal Brazil | Accounts Receivable | Customer Concentration Risk
Concentration Risk [Line Items]
Accounts receivable due	34.3				25.7				$ 34.3	$ 25.7
AK Steel | Sales Revenue, Net | Customer Concentration Risk
Concentration Risk [Line Items]
Sales and other operating revenue									$ 377.9	$ 331.3	$ 350.0
Percent of Company sales and other operating revenue									26.00%	24.90%	28.60%
AK Steel | Accounts Receivable | Customer Concentration Risk
Concentration Risk [Line Items]
Accounts receivable due	25.3				13.2				$ 25.3	$ 13.2
U.S. Steel | Sales Revenue, Net | Customer Concentration Risk
Concentration Risk [Line Items]
Sales and other operating revenue									$ 206.8	$ 214.1	$ 185.3
Percent of Company sales and other operating revenue									14.30%	16.10%	15.10%
U.S. Steel | Accounts Receivable | Customer Concentration Risk
Concentration Risk [Line Items]
Accounts receivable due	5.2				5.6				$ 5.2	$ 5.6
Foresight and Murray | Sales Revenue, Net | Customer Concentration Risk
Concentration Risk [Line Items]
Sales and other operating revenue									$ 62.5	$ 57.8	$ 53.5
Percent of Company sales and other operating revenue									4.30%	4.30%	4.40%
Foresight and Murray | Accounts Receivable | Customer Concentration Risk
Concentration Risk [Line Items]
Accounts receivable due	3.2				$ 9.7				$ 3.2	$ 9.7
Foresight and Murray | Accounts Receivable | Customer Concentration Risk | Logistics
Concentration Risk [Line Items]
Accounts receivable due	$ 0.0								$ 0.0

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Income Taxes (Components of Income From Operations) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
The components of income before income tax expense
Domestic	$ 39.3	$ 4.3	$ 52.5
Foreign	17.7	17.6	15.6
Total	$ 57.0	$ 21.9	$ 68.1

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Income Taxes (Components of Income Tax Expense) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Current tax expense:
U.S. federal	$ 1.4	$ 1.7	$ 2.7
State	2.1	(1.0)	(2.2)
Foreign	4.5	4.9	5.0
Total current tax expense	8.0	5.6	5.5
Deferred tax expense:
U.S. federal	(3.1)	(99.7)	(1.5)
State	(0.3)	12.5	4.6
Total deferred tax (benefit) expense	(3.4)	(87.2)	3.1
Income tax expense	$ 4.6	$ (81.6)	$ 8.6

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Income Taxes (Reconciliation of Income Tax Expense to US Statutory Rate) (Details) - USD ($)	3 Months Ended			12 Months Ended
	Sep. 30, 2018	Dec. 31, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Reconciliation of income tax expense
Income tax expense at U.S. statutory rate				$ 12,000,000	$ 7,700,000	$ 23,800,000
Impact of Final Regulations				(1,400,000)	64,200,000	0
Provisional net income tax benefit		$ 154,700,000		4,800,000	154,700,000	0
Income attributable to noncontrolling interests in partnerships				(3,900,000)	(5,400,000)	(15,600,000)
State and other income taxes, net of federal income tax effects				1,600,000	2,000,000	1,100,000
Change in valuation allowance				700,000	3,900,000	400,000
Other				400,000	700,000	(1,100,000)
Income tax expense (benefit)				$ 4,600,000	$ (81,600,000)	$ 8,600,000
Reconciliation of income tax expense (as a percent)
Income tax expense at U.S. statutory rate				21.00%	35.00%	35.00%
Impact of Final Regulations				(2.50%)	293.20%	0.00%
Impact of Tax Legislation				(8.40%)	(706.40%)	0.00%
Income attributable to noncontrolling interests in partnerships				(6.80%)	(24.70%)	(23.00%)
State and other income taxes, net of federal income tax effects				2.80%	9.10%	1.70%
Change in valuation allowance				1.20%	17.80%	0.60%
Other				0.70%	3.20%	(1.60%)
Total effective income tax expense				8.00%	(372.80%)	12.70%
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Deferred income tax (benefit) expense				$ (3,400,000)	$ (87,200,000)	$ 3,100,000
Net deferred tax liability		257,800,000		254,700,000	257,800,000
Provisional net income tax benefit		154,700,000		4,800,000	154,700,000	$ 0
Remeasurement of deferred income tax liabilities and assets					169,000,000
Provisional income tax expense (benefit)				9,900,000	14,300,000
Valuation allowance					19,000,000
Benefit from foreign tax credits	$ (4,800,000)
Income tax expense attributable to noncontrolling interests				0
Suncoke Inc
Reconciliation of income tax expense
Provisional net income tax benefit		125,000,000			125,000,000
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Provisional net income tax benefit		125,000,000			125,000,000
IRS
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Deferred income tax (benefit) expense				3,600,000	148,600,000
Net deferred tax liability		$ 84,400,000			84,400,000
Deferred tax expense			$ 64,200,000	$ 1,400,000	$ 64,200,000

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Income Taxes (Components of Net Deferred Tax Liability) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Deferred tax assets:
Retirement benefit liabilities	$ 6.4	$ 7.1
Black lung benefit liabilities	11.3	11.6
Share-based compensation	6.4	6.1
Federal tax credit carryforward	21.5	23.2
Foreign tax credit carryforward	15.9	19.0
Federal net operating loss	0.0	2.5
Section 163(j) interest limitation carryforward	1.8	0.0
State tax credit carryforward, net of federal income tax effects	2.4	4.0
State net operating loss carryforward, net of federal income tax effects	13.5	13.9
Other liabilities not yet deductible	4.9	4.3
Total deferred tax assets	84.1	91.7
Less valuation allowance	(20.7)	(26.2)
Deferred tax asset, net	63.4	65.5
Deferred tax liabilities:
Properties, plants and equipment	(111.5)	(114.9)
Investment in partnerships	(206.6)	(208.4)
Total deferred tax liabilities	(318.1)	(323.3)
Net deferred tax liability	(254.7)	(257.8)
Provisional income tax expense (benefit)	$ 9.9	$ 14.3

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Income Taxes (Narrative) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Tax Disclosure [Abstract]
State and foreign income tax returns subject to examination period (in years)	3 years
State and foreign income tax returns subject to examination period maximum (in years)	5 years
Period amended federal returns remain subject to examination	1 year
Uncertain tax positions	$ 0	$ 0
Interest and penalties	$ 0	$ 0	$ 0

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Inventories (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Components of inventories
Coal	$ 59.9	$ 61.4
Coke	8.6	12.3
Materials, supplies and other	41.9	37.3
Total inventories	$ 110.4	$ 111.0

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Properties, Plants, and Equipment, Net (Components) (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Property, Plant and Equipment [Line Items]
Gross investment, at cost	$ 2,326.9	$ 2,234.5
Less: Accumulated depreciation	(855.8)	(733.2)
Total properties, plants and equipment, net	1,471.1	1,501.3
Coke and energy plant, machinery and equipment
Property, Plant and Equipment [Line Items]
Gross investment, at cost	1,876.3	1,812.0
Less: Accumulated depreciation	(554.1)	(475.8)
Logistics plant, machinery and equipment
Property, Plant and Equipment [Line Items]
Gross investment, at cost	218.3	216.2
Land and land improvements
Property, Plant and Equipment [Line Items]
Gross investment, at cost	119.7	118.7
Construction-in-progress
Property, Plant and Equipment [Line Items]
Gross investment, at cost	72.7	51.9
Other
Property, Plant and Equipment [Line Items]
Gross investment, at cost	$ 39.9	$ 35.7

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Properties, Plants, and Equipment, Net (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Property, Plant and Equipment [Line Items]
Accumulated depreciation	$ 855.8	$ 733.2
Coke and energy plant, machinery and equipment
Property, Plant and Equipment [Line Items]
Coke and energy plant, machinery and equipment	1,416.2	1,337.3
Accumulated depreciation	$ 554.1	$ 475.8

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Goodwill and Other Intangible Assets - Goodwill (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Goodwill [Line Items]
Goodwill	$ 76.9	$ 76.9
Domestic Coke
Goodwill [Line Items]
Goodwill	3.4	3.4
Logistics
Goodwill [Line Items]
Goodwill	$ 73.5	$ 73.5

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Goodwill and Other Intangible Assets - Narrative (Details) $ in Millions		12 Months Ended
	Oct. 01, 2016	Dec. 31, 2018 USD ($)	Dec. 31, 2017 USD ($)	Dec. 31, 2016 USD ($)	Oct. 01, 2017
Goodwill [Line Items]
Total amortization expense		$ 11.1	$ 11.1	$ 11.2
Permits
Goodwill [Line Items]
Useful life		24 years
Permits | Convent Marine Terminal
Goodwill [Line Items]
Useful life		27 years
Remaining renewal term		2 years 4 months 24 days
Logistics
Goodwill [Line Items]
Fair value of reporting unit in excess of carrying value, percent					30.00%
Change in discount rate that would not impact goodwill impairment test	1.00%
Logistics | Discount Rate
Goodwill [Line Items]
Discount rate on discounted cash flow analysis					0.14

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Goodwill and Other Intangible Assets - Gross and Net Intangible Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	$ 200.6	$ 200.6
Accumulated Amortization	43.8	32.7
Total	$ 156.8	167.9
Customer contracts
Finite-Lived Intangible Assets [Line Items]
Weighted - Average Remaining Amortization (in years)	4 years
Gross Carrying Amount	$ 31.7	31.7
Accumulated Amortization	17.7	13.8
Total	$ 14.0	17.9
Customer relationships
Finite-Lived Intangible Assets [Line Items]
Weighted - Average Remaining Amortization (in years)	13 years
Gross Carrying Amount	$ 28.7	28.7
Accumulated Amortization	7.5	5.7
Total	$ 21.2	23.0
Permits
Finite-Lived Intangible Assets [Line Items]
Weighted - Average Remaining Amortization (in years)	24 years
Gross Carrying Amount	$ 139.0	139.0
Accumulated Amortization	17.4	12.2
Total	121.6	126.8
Trade name
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	1.2	1.2
Accumulated Amortization	1.2	1.0
Total	$ 0.0	$ 0.2

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Goodwill and Other Intangible Assets - Schedule of Future Amortization Expense (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]
2019	$ 10.9
2020	10.7
2021	10.3
2022	10.3
2023	7.0
Thereafter	107.6
Total	$ 156.8	$ 167.9

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Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Reconciliation of changes in the asset retirement obligation
Beginning Balance	$ 14.0	$ 13.9
Liabilities settled	(0.4)	(0.7)
Accretion expense	0.9	1.0
Revisions in estimated cash flows	0.1	(0.2)
Ending Balance	$ 14.6	$ 14.0

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Retirement Benefits Plans (Narrative) (Details) - USD ($) $ in Millions		12 Months Ended
	Jan. 01, 2011	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Defined Benefit Plan Disclosure [Line Items]
Company's pretax income and the aggregate compensation levels of participating employees		$ 6.5	$ 6.4	$ 5.6
Postretirement benefit plans
Defined Benefit Plan Disclosure [Line Items]
Years of service, less than	10 years
Health care cost trend assumption increased health care cost trend rates (as a percent)		6.50%	6.50%
Health care cost trend assumption increased health care cost trend rates (as a percent)		5.00%

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Retirement Benefits Plans (Postretirement Benefit Plans (Benefit) Expense Components) (Details) - Postretirement benefit plans - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Defined Benefit Plan Disclosure [Line Items]
Interest cost on benefit obligations	$ 1.0	$ 1.1	$ 1.3
Amortization of:
Actuarial losses	0.6	0.9	0.7
Prior service benefit	(0.7)	(0.7)	(0.7)
Total expense	$ 0.9	$ 1.3	$ 1.3

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Retirement Benefits Plans (Assumptions Used to Determine Defined Benefit Plan and Postretirement Benefit Plans Expense (Benefit) (Details)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Postretirement benefit plans
Defined Benefit Plan Disclosure [Line Items]
Discount Rate (as a percent)	3.35%	3.65%	3.80%

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Retirement Benefits Plans (Amounts Recognized as Components of Other Comprehensive (Loss) Income) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Retirement benefit plan funded status adjustments:
Actuarial gains (losses)	$ 0.1	$ (0.2)	$ 0.0
Total	(0.6)	0.8	0.2
Postretirement benefit plans
Reclassifications to earnings of:
Actuarial loss amortization	0.6	0.9	0.7
Prior service benefit amortization	(0.7)	(0.7)	(0.7)
Retirement benefit plan funded status adjustments:
Actuarial gains (losses)	0.8	(1.1)	(1.8)
Prior service (cost) benefit	0.0	0.0	1.5
Total	$ 0.7	$ (0.9)	$ (0.3)

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Retirement Benefits Plans (Components of the Changes in Benefit Obligations and Fair Value of Plan Assets) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Change in Benefit Obligation
Current portion of retirement liabilities classified in accrued liabilities	$ 3.0	$ 3.1
Postretirement benefit plans
Change in Benefit Obligation
Benefit obligations at beginning of year	31.3	32.3
Interest cost	1.0	1.1	$ 1.3
Actuarial (gain)/loss	(0.8)	1.1
Benefits paid	(3.3)	(3.2)
Benefit obligations at end of year	28.2	31.3	32.3
Prior service (cost) benefit	$ 0.0	$ 0.0	$ 1.5

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Retirement Benefits Plans (Cumulative Amounts Not Yet Recognized in Net Income) (Details) - Postretirement benefit plans - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Cumulative amounts not yet recognized in net income:
Actuarial losses	$ 10.4	$ 11.8
Prior service benefits	(2.6)	(3.4)
Accumulated other comprehensive loss (before related tax benefit)	$ 7.8	$ 8.4

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Retirement Benefits Plans (Expected Benefit Payments) (Details) - Postretirement benefit plans $ in Millions	Dec. 31, 2018 USD ($)
Regulatory Liabilities [Line Items]
2019	$ 3.0
2020	2.9
2021	2.8
2022	2.6
2023	2.4
2024 through 2028	$ 9.5

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Retirement Benefits Plans (Discount Rate) (Details)	Dec. 31, 2018	Dec. 31, 2017
Postretirement benefit plans
Defined Benefit Plan Disclosure [Line Items]
Discount rate (as a percent)	4.00%	3.35%

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Accrued Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Balance Sheet Related Disclosures [Abstract]
Accrued benefits	$ 21.2	$ 21.3
Current portion of postretirement benefit obligation	3.0	3.1
Other taxes payable	9.1	10.5
Current portion of black lung liability	4.5	5.4
Accrued legal	4.2	5.6
Other	3.6	7.3
Total accrued liabilities	$ 45.6	$ 53.2

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Debt and Financing Obligation (Schedule of Debt) (Details) - USD ($)	Dec. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Total borrowings	$ 859,000,000	$ 887,300,000
Original issue discount	(5,400,000)	(5,900,000)
Debt issuance costs	(15,200,000)	(17,700,000)
Total debt and financing obligation	838,400,000	863,700,000
Current portion of long-term debt and financing obligation	3,900,000	2,600,000
Long-term debt and financing obligation	834,500,000	861,100,000
7.500 percent senior notes, due 2025 (Partnership Notes) | Senior notes
Debt Instrument [Line Items]
Total borrowings	$ 700,000,000	700,000,000
Interest rate on senior notes (as a percent)	7.50%
7.625 percent senior notes, due 2019 (2019 Notes) | Senior notes
Debt Instrument [Line Items]
Total borrowings	$ 0	44,600,000
Interest rate on senior notes (as a percent)	7.625%
Term loan, due 2022 (Term Loan) | Line of Credit
Debt Instrument [Line Items]
Total borrowings	$ 43,900,000	0
SunCoke's revolving credit facility, due 2022 (Revolving Facility) | Line of Credit | Revolving credit facility
Debt Instrument [Line Items]
Total borrowings	0	0
Partnership's revolving credit facility, due 2022 (Partnership Revolver) | Line of Credit | Revolving credit facility
Debt Instrument [Line Items]
Total borrowings	105,000,000	130,000,000
5.82 percent financing obligation, due 2021 (Partnership Financing Obligation) | Financing Obligation
Debt Instrument [Line Items]
Total borrowings	$ 10,100,000	$ 12,700,000
Interest rate on senior notes (as a percent)	5.82%

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Debt and Financing Obligation (Redemption of 2019 Notes) (Details)	Jan. 11, 2018 USD ($)
Senior notes | 7.625 percent senior notes, due 2019 (2019 Notes)
Debt Instrument [Line Items]
Debt redemption	$ 46,100,000
Accrued interest	1,500,000
Amortization of debt issuance costs	300,000
Line of Credit | Term loan, due 2022 (Term Loan)
Debt Instrument [Line Items]
Principal amount of term loan	45,000,000.0
Line of credit debt issuance costs, gross	$ 300,000

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Debt and Financing Obligation (Partnership Notes) (Details) - SunCoke Energy Partners, L.P. - Senior notes - 7.500 percent senior notes, due 2025 (Partnership Notes)	12 Months Ended
	Dec. 31, 2018
Debt Instrument [Line Items]
Change of control percent	101.00%
Before June 15, 2020
Debt Instrument [Line Items]
Redemption percentage	35.00%
Percentage of principal amount	107.50%
Anytime prior to June 15, 2020
Debt Instrument [Line Items]
Percentage of principal amount	100.00%

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Debt and Financing Obligation (Partnership Financing Obligation) (Details) - Integral Equipment and Mobile Equipment - SunCoke Energy Partners, L.P. - Domestic Coke and Coal Logistics	12 Months Ended
	Dec. 31, 2018
Sale Leaseback Transaction [Line Items]
Initial lease period	60 months
Buyout option period	48 months
Percent of original lease equipment cost	34.50%

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Debt and Financing Obligation (Revolving Facility) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Outstanding balance	$ 859,000,000	$ 887,300,000
Revolving credit facility | Line of Credit | SunCoke's revolving credit facility, due 2022 (Revolving Facility)
Debt Instrument [Line Items]
Capacity	100,000,000.0
Letters of credit outstanding under revolving facility	23,900,000
Outstanding balance	0	$ 0
Remaining borrowing capacity	$ 76,100,000
Unused capacity commitment fee	0.40%
Basis spread on variable rate	1.75%
The weighted-average interest rate for borrowings outstanding under credit agreement (as a percent)			2.80%

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Debt and Financing Obligation (Partnership Revolver) (Details) - USD ($)		12 Months Ended
	Nov. 03, 2015	Dec. 31, 2017	Dec. 31, 2018	May 31, 2017	Dec. 31, 2016
Line of Credit Facility [Line Items]
Outstanding balance		$ 887,300,000	$ 859,000,000
Partnership's revolving credit facility, due 2022 (Partnership Revolver) | Line of Credit | Revolving credit facility
Line of Credit Facility [Line Items]
Outstanding balance		130,000,000	105,000,000
SunCoke Energy Partners, L.P. | Partnership's revolving credit facility, due 2022 (Partnership Revolver) | Line of Credit | LIBOR
Line of Credit Facility [Line Items]
Basis spread on variable rate	2.50%
SunCoke Energy Partners, L.P. | Partnership's revolving credit facility, due 2022 (Partnership Revolver) | Line of Credit | Base Rate
Line of Credit Facility [Line Items]
Basis spread on variable rate	1.50%
SunCoke Energy Partners, L.P. | Partnership's revolving credit facility, due 2022 (Partnership Revolver) | Line of Credit | Revolving credit facility
Line of Credit Facility [Line Items]
Principal amount of term loan			$ 200,000,000	$ 285,000,000
Letters of credit outstanding under revolving facility		1,900,000
Outstanding balance		105,000,000
Remaining letters of credit agreement amount		$ 178,100,000
Unused capacity commitment fee		0.40%
The weighted-average interest rate for borrowings outstanding under credit agreement (as a percent)		3.80%	4.80%		3.30%

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Debt and Financing Obligation (Covenants) (Details)	Jun. 30, 2020	Dec. 31, 2018 USD ($)
Credit Agreement and Partner Revolver
Line of Credit Facility [Line Items]
Maximum consolidated leverage ratio		3.25
Minimum consolidated interest coverage ratio		2.75
Credit Agreement and Partner Revolver | SunCoke Energy Partners, L.P.
Line of Credit Facility [Line Items]
Cross default covenant threshold		$ 35,000,000
Line of Credit | Revolving credit facility | Partnership's revolving credit facility, due 2022 (Partnership Revolver) | SunCoke Energy Partners, L.P.
Line of Credit Facility [Line Items]
Maximum consolidated leverage ratio		4.5
Minimum consolidated interest coverage ratio		2.5
Line of Credit | Revolving credit facility | Partnership's revolving credit facility, due 2022 (Partnership Revolver) | SunCoke Energy Partners, L.P. | Forecast
Line of Credit Facility [Line Items]
Maximum consolidated leverage ratio	4.0

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Debt and Financing Obligation (Schedule of Long-Term Debt Maturity) (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Debt Disclosure [Abstract]
2019	$ 3.9
2020	10.7
2021	3.4
2022	141.0
2023	0.0
2024-Thereafter	700.0
Total debt	$ 859.0	$ 887.3

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Commitments and Contingent Liabilities (Lease Obligations) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Aggregate amount of future minimum annual rentals applicable to noncancelable operating leases and related subleases
2019	$ 2.0
2020	1.1
2021	1.0
2022	0.5
2023	0.1
2024-Thereafter	0.7
Total	5.4
Rental expense, net of sublease income	$ 9.8	$ 7.3	$ 8.7

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Commitments and Contingent Liabilities (Legal Matters) (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended	12 Months Ended
	Dec. 31, 2018	Jun. 30, 2019	Dec. 31, 2018	Dec. 31, 2014	Dec. 31, 2016
EPA | Accrued Liabilities
Loss Contingencies [Line Items]
Environmental remediation expense	$ 2.5
Haverhill and Granite City
Loss Contingencies [Line Items]
Estimate possible loss					$ 2.2
Expected spending on environmental liability	150.0		$ 150.0
Cost of capital projects			138.0	$ 7.0
Funds retained fro environmental remediation project	$ 119.0		$ 20.0
Haverhill and Granite City | Forecast
Loss Contingencies [Line Items]
Funds retained fro environmental remediation project		$ 5.0

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Commitments and Contingent Liabilities (Black Lung Benefit Liabilities) (Details) - Black Lung Benefit $ in Millions	12 Months Ended
	Dec. 31, 2018 USD ($) claim	Dec. 31, 2017 USD ($) claim	Dec. 31, 2016 USD ($)
Defined Benefit Plan Disclosure [Line Items]
Discount rate (as a percent)	4.00%	3.30%
Active claims | claim	345	351
Estimated liability	$ 49.4	$ 50.3
Increase in black lung expense	1.1
Current portion of black lung liability	4.5	5.4
Payments	6.3	7.4	$ 7.8
Expense	$ 5.4	$ 7.5	$ 8.1

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Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Components of accumulated other comprehensive (loss) income (net of related income taxes)
Beginning balance	$ 659.6	$ 659.6	$ 639.9	$ 622.8
Other comprehensive loss before reclassifications		(1.4)	(0.5)
Amounts reclassified from accumulated other comprehensive loss		(0.1)	0.2
Retirement benefit plans funded status adjustment		0.6	(0.8)	(0.2)
Recognition of accumulated currency translation loss upon sale of equity method investment		9.0	0.0	0.0
Net current period other comprehensive loss		8.1	(1.1)
Ending balance		682.7	659.6	639.9
ASU 2018-02
Components of accumulated other comprehensive (loss) income (net of related income taxes)
Cumulative effect from adoption of ASU 2018-02	(1.1)		(1.1)
Benefit Plans
Components of accumulated other comprehensive (loss) income (net of related income taxes)
Beginning balance	(6.5)	(6.5)	(4.8)
Other comprehensive loss before reclassifications		0.0	0.0
Amounts reclassified from accumulated other comprehensive loss		(0.1)	0.2
Retirement benefit plans funded status adjustment		0.6	(0.8)
Recognition of accumulated currency translation loss upon sale of equity method investment		0.0
Net current period other comprehensive loss		0.5	(0.6)
Ending balance		(6.0)	(6.5)	(4.8)
Tax benefit associated with benefit plans		1.8	1.9
Benefit Plans | ASU 2018-02
Components of accumulated other comprehensive (loss) income (net of related income taxes)
Cumulative effect from adoption of ASU 2018-02			(1.1)
Currency Translation Adjustments
Components of accumulated other comprehensive (loss) income (net of related income taxes)
Beginning balance	(14.7)	(14.7)	(14.2)
Other comprehensive loss before reclassifications		(1.4)	(0.5)
Amounts reclassified from accumulated other comprehensive loss		0.0	0.0
Retirement benefit plans funded status adjustment		0.0	0.0
Recognition of accumulated currency translation loss upon sale of equity method investment		9.0
Net current period other comprehensive loss		7.6	(0.5)
Ending balance		(7.1)	(14.7)	(14.2)
Currency Translation Adjustments | ASU 2018-02
Components of accumulated other comprehensive (loss) income (net of related income taxes)
Cumulative effect from adoption of ASU 2018-02			0.0
Accumulated Other Comprehensive Loss
Components of accumulated other comprehensive (loss) income (net of related income taxes)
Beginning balance	$ (21.2)	(21.2)	(19.0)	(19.8)
Retirement benefit plans funded status adjustment		0.6	(0.8)	(0.2)
Recognition of accumulated currency translation loss upon sale of equity method investment		9.0
Ending balance		$ (13.1)	$ (21.2)	$ (19.0)

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Accumulated Other Comprehensive Loss Reclassification Adjustments From AOCI (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Accumulated Other Comprehensive Income (Loss) [Line Items]
Recognition of accumulated currency translation loss upon sale of equity method investment	$ (9,000,000)	$ 0	$ 0
Income tax cost (benefit)	0	0	0
Benefit Plans
Accumulated Other Comprehensive Income (Loss) [Line Items]
Recognition of accumulated currency translation loss upon sale of equity method investment	0
Total, net of tax	(8,900,000)	(200,000)	0
Actuarial loss
Accumulated Other Comprehensive Income (Loss) [Line Items]
Amortization of benefit plans to net income	(600,000)	(900,000)	(700,000)
Prior service benefit
Accumulated Other Comprehensive Income (Loss) [Line Items]
Amortization of benefit plans to net income	$ 700,000	$ 700,000	$ 700,000

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Share-Based Compensation (Equity Classified Awards Narrative) (Details)	1 Months Ended		12 Months Ended
	Dec. 31, 2017 shares	Feb. 28, 2017 shares	Dec. 31, 2018 USD ($) Installment $ / shares shares	Dec. 31, 2017 USD ($) $ / shares shares	Dec. 31, 2016 USD ($) $ / shares shares	Feb. 14, 2018 shares	Jul. 13, 2011 shares
Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total intrinsic value of stock options exercised | $			$ 800,000	$ 300,000	$ 0
Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of annual installment in which stock option exercisable | Installment			3
Period from grant date for annual installment (in years)			1 year
Shares granted (shares)			32,128	22,628	0
Total fair value of non-option award units vested | $			$ 1,200,000	$ 2,300,000	$ 3,700,000
Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted (shares)	148,148	237,610	96,389	385,758
Performance Share Units | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage adjustment of award determined by pre-tax return on capital (as a percent)			0.00%
Performance Share Units | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage adjustment of award determined by pre-tax return on capital (as a percent)			200.00%
SunCoke LTPEP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common stock issuable (in shares)						6,000,000	1,600,000
Common stock issuable pursuant to new awards (in shares)						1,500,000	7,500,000
SunCoke LTPEP | Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of annual installment in which stock option exercisable | Installment			3
Period from grant date for annual installment (in years)			1 year
Expiration period			10 years
SunCoke LTPEP | Performance Based Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Closing common stock price (USD per share) | $ / shares				$ 14.78	$ 9.50
Number of trading days					15 days
Measurement period					3 years
SunCoke LTPEP | Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Measurement period			3 years
SunCoke LTPEP | Performance Share Units | Pre-tax return of capital for Coke and Coal Logistics businesses
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Closing common stock price (USD per share) | $ / shares			$ 9.00
Number of trading days			15 days
Measurement period			3 years
Percent of award allocation			50.00%
SunCoke LTPEP | Performance Share Units | Pre-tax return of capital for coke business
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Measurement period			3 years
SunCoke LTPEP | Performance Share Units | Minimum | Pre-tax return of capital for coke business
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Payout percentage			50.00%
Percentage adjustment of award determined by pre-tax return on capital (as a percent)			0.00%
SunCoke LTPEP | Performance Share Units | Maximum | Pre-tax return of capital for coke business
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Payout percentage			150.00%
Percentage adjustment of award determined by pre-tax return on capital (as a percent)			250.00%

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Share-Based Compensation (Stock Option and Performance Share Units Grants) (Details) - $ / shares	1 Months Ended		12 Months Ended
	Mar. 31, 2016	Feb. 29, 2016	Dec. 31, 2018	Dec. 31, 2017
Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average exercise price (in USD per share)			$ 10.49
SunCoke LTPEP | Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares granted (shares)	90,925	95,001	78,447	157,196
Weighted average exercise price (in USD per share)	$ 6.03	$ 3.80	$ 10.49	$ 10.29
Weighted-average fair value stock option (in dollars per share)	$ 2.78	$ 1.71	$ 5.38	$ 5.32
SunCoke LTPEP | Performance Based Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares granted (shares)	90,925	58,448		80,595
Weighted average exercise price (in USD per share)	$ 6.03	$ 3.80		$ 9.85
Weighted-average fair value stock option (in dollars per share)	$ 2.42	$ 1.06		$ 5.17

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Share-Based Compensation (Assumptions Used to Calculate Value of Stock Options) (Details) - Stock Options	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Risk free interest rate	3.00%	2.00%	1.00%
Expected term	6 years	6 years	5 years
Volatility	52.00%	53.00%	52.00%
Dividend yield	0.00%	0.00%	0.00%

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Share-Based Compensation (Summary of Stock Option Activity) (Details) - Stock Options - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Number of Options (in shares)
Outstanding at the beginning of period (shares)	3,146,115
Granted (shares)	78,447
Exercised (shares)	(127,107)
Forfeited (shares)	(211,667)
Outstanding at end of period (shares)	2,885,788	3,146,115
Exercisable at end of period (shares)	2,546,059
Expected to vest at end of period (shares)	339,729
Weighted Average Exercise Price (in dollars per share)
Outstanding at beginning of period (in USD per share)	$ 15.31
Granted (in USD per share)	10.49
Exercised (in USD per share)	6.49
Forfeited (in USD per share)	17.07
Outstanding at end of period (in USD per share)	15.46	$ 15.31
Exercisable at end of period (in USD per share)	16.38
Expected to vest at end of period (in USD per share)	$ 8.59
Weighted Average Remaining Contractual Term (years)
Weighted average remaining contractual term (in years)	4 years 9 months 18 days	5 years 7 months 6 days
Exercisable at end of period	4 years 1 month 6 days
Expected to vest at end of period	8 years 2 months 12 days
Aggregate Intrinsic Value (millions)
Aggregate intrinsic value	$ 2.1	$ 2.8
Exercisable at end of period	0.4
Expected to vest at end of period	$ 0.9

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Share-Based Compensation (Restricted Stock Units and Performance Share Units Granted) (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended				12 Months Ended
	Dec. 31, 2017	Feb. 28, 2017	Mar. 31, 2016	Feb. 29, 2016	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted (shares)					32,128	22,628	0
Weighted Average Grant-Date Fair Value (in USD per share)					$ 10.49	$ 9.85
Grant Date Fair Value					$ 0.3	$ 0.2
Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted (shares)	148,148	237,610			96,389	385,758
Weighted Average Grant-Date Fair Value (in USD per share)					$ 11.36	$ 11.61
Grant Date Fair Value					$ 1.1	$ 4.5
Performance Share Units | SunCoke LTPEP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date Fair Value			$ 2.0	$ 1.2
Performance Share Units | SunCoke LTPEP | ROIC Portion
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares granted (shares)			67,167	105,210
Weighted-average fair value stock option (in dollars per share)			$ 10.51	$ 5.66
Performance Share Units | SunCoke LTPEP | TSR Portion
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares granted (shares)			201,500	105,210
Weighted-average fair value stock option (in dollars per share)			$ 6.35	$ 5.81
Maximum award value					$ 4.9

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Share-Based Compensation (Summary of RSUs and PSUs Outstanding) (Details) - $ / shares	1 Months Ended		12 Months Ended
	Dec. 31, 2017	Feb. 28, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Restricted Stock Units (RSUs)
Number of Units
Outstanding at beginning of period (shares)			106,397
Granted (shares)			32,128	22,628	0
Vested (shares)			(87,131)
Forfeited (shares)			(4,181)
Outstanding at end of period (shares)	106,397		47,213	106,397
Weighted Average Grant- Date Fair Value (in dollars per share)
Outstanding at beginning of period (in USD per share)			$ 13.53
Granted (in USD per share)			10.49	$ 9.85
Vested (in USD per share)			14.27
Forfeited (in USD per share)			8.37
Outstanding at end of period (in USD per share)	$ 13.53		$ 10.29	$ 13.53
Performance Share Units
Number of Units
Outstanding at beginning of period (shares)			782,781
Granted (shares)	148,148	237,610	96,389	385,758
Vested (shares)			(1,710)
Forfeited (shares)			(125,085)
Outstanding at end of period (shares)	782,781		752,375	782,781
Weighted Average Grant- Date Fair Value (in dollars per share)
Outstanding at beginning of period (in USD per share)			$ 10.06
Granted (in USD per share)			11.36	$ 11.61
Vested (in USD per share)			16.90
Forfeited (in USD per share)			17.59
Outstanding at end of period (in USD per share)	$ 10.06		$ 8.86	$ 10.06

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Share-Based Compensation (Liability Classified Awards Narrative) (Details) $ / shares in Units, $ in Millions	1 Months Ended		12 Months Ended
	Dec. 31, 2017 shares	Feb. 28, 2017 shares	Dec. 31, 2018 USD ($) Installment $ / shares shares	Dec. 31, 2017 USD ($) $ / shares shares	Dec. 31, 2016 USD ($) $ / shares shares
Restricted Stock Units Settled in Cash
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted (shares) | shares			108,522	98,364	198,668
Number of annual installment in which stock option exercisable | Installment			3
Period from grant date for annual installment (in years)			1 year
Granted (in USD per share)			$ 10.71	$ 9.82	$ 3.82
Closing price (USD per share)			$ 8.55
Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted (shares) | shares	148,148	237,610	96,389	385,758
Granted (in USD per share)			$ 11.36	$ 11.61
Performance Share Units | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage adjustment of award determined by pre-tax return on capital (as a percent)			200.00%
Suncoke LTCIP | Cash Incentive Award
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant date fair value award | $			$ 1.0	$ 0.7	$ 0.9
Percent of award allocation			50.00%
Measurement period			3 years	3 years
Closing common stock price (USD per share)				$ 9.00
Number of trading days				15 days
Suncoke LTCIP | Cash Incentive Award | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage adjustment of award determined by pre-tax return on capital (as a percent)			25000.00%	200.00%
SunCoke LTPEP | Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Measurement period			3 years

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Share-Based Compensation (Compensation Expense and Unrecognized Compensation Costs) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Cost	$ 0.5
Recognition Period	1 year 7 months 6 days
Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Cost	$ 0.3
Recognition Period	1 year 8 months 12 days
Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Cost	$ 2.6
Recognition Period	1 year 10 months 24 days
Restricted Stock Units Settled in Cash
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Cost	$ 0.7
Recognition Period	1 year 4 months 24 days
Suncoke LTCIP | Cash Incentive Award
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Cost	$ 0.9
Recognition Period	1 year 9 months 18 days
Selling, General and Administrative Expenses | Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	$ 0.5	$ 1.3	$ 2.1
Net of tax	0.4	0.8	1.3
Selling, General and Administrative Expenses | Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	0.4	1.1	2.6
Net of tax	0.3	0.7	1.7
Selling, General and Administrative Expenses | Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	1.9	1.9	1.4
Net of tax	1.7	1.2	0.9
Selling, General and Administrative Expenses | Equity Classified Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	2.8	4.3	6.1
Net of tax	2.4	2.7	3.9
Selling, General and Administrative Expenses | Restricted Stock Units Settled in Cash
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	0.8	1.0	0.7
Net of tax	0.6	0.6	0.5
Selling, General and Administrative Expenses | Suncoke LTCIP | Cash Incentive Award
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	0.9	0.2	0.1
Net of tax	0.7	0.1	0.1
Selling, General and Administrative Expenses | Suncoke LTCIP | Liability Classified Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	1.7	1.2	0.8
Net of tax	$ 1.3	$ 0.7	$ 0.6

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Share-Based Compensation (Summary of Share-Based Compensation Expense Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Director
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost [Line Items]
Compensation expense	$ 0.3	$ 0.5	$ 0.4

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Earnings Per Share - Weighted Average Number of Shares (Details) - shares shares in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Earnings Per Share [Abstract]
Weighted-average number of common shares outstanding-basic	64.7	64.3	64.2
Add: effect of dilutive share-based compensation awards	0.8	0.9	0.2
Weighted-average number of shares-diluted	65.5	65.2	64.4

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Earnings Per Share - Antidilutive Shares Excluded From EPS Calculation (Details) - shares shares in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Potential dilutive effect excluded from the computation of diluted weighted-average shares outstanding (in shares)	2.8	3.0	3.4
Stock Options
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Potential dilutive effect excluded from the computation of diluted weighted-average shares outstanding (in shares)	2.7	2.9	3.0
Restricted Stock Units (RSUs)
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Potential dilutive effect excluded from the computation of diluted weighted-average shares outstanding (in shares)	0.0	0.0	0.2
Performance Share Units
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Potential dilutive effect excluded from the computation of diluted weighted-average shares outstanding (in shares)	0.1	0.1	0.2

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Fair Value Measurements (Financial Assets and Liabilities Measured at Fair Value on a Recurring Basis) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Mar. 31, 2016
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration liability	$ (2.5)	$ 1.7	$ 10.1
Cost of Products Sold and Operating Expenses
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration liability	2.5	1.7	$ 6.4
Level 1 | Cash Equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents measured at fair value	3.2	5.5
Fair Value, Inputs, Level 3 | SunCoke Energy Partners, L.P. | Convent Marine Terminal
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration	$ 5.0	$ 2.5		$ 3.7

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Fair Value Measurements (Certain Financial Assets and Liabilities not Measured at Fair Value) (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Fair Value Disclosures [Abstract]
Fair value of long-term debt	$ 822.8	$ 919.7
Outstanding balance	$ 859.0	$ 887.3

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Revenue from Contracts with Customers - Narrative (Details) T in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2018 USD ($) T
Cokemaking
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Percentage of facility capacity	90.00%
Expected term of agreement	6 years
Logistics
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Expected term of agreement	5 years
Capacity (in tons)	13
Performance obligation amount | $	$ 305
Logistics | Foresight and Murray
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Capacity (in tons)	15
Logistics | Foresight and Murray | CMT
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Capacity (in tons)	10

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Revenue from Contracts with Customers - Deferred Revenue (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Change in Contract with Customer, Liability [Roll Forward]
Beginning balance at December 31, 2017 and 2016, respectively	$ 1.7	$ 2.5
Reclassification of the beginning contract liabilities to revenue, as a result of performance obligation satisfied	(1.4)	(2.1)
Billings in excess of services performed, not recognized as revenue	2.7	1.3
Ending balance at December 31, 2018 and 2017, respectively	$ 3.0	$ 1.7

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Revenue from Contracts with Customers - Disaggregated Sales and Other Operating Revenue (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disaggregation of Revenue [Line Items]
Sales and other operating revenue	$ 368.9	$ 364.5	$ 367.0	$ 350.5	$ 359.6	$ 339.0	$ 323.2	$ 309.7	$ 1,450.9	$ 1,331.5	$ 1,223.3
Cokemaking
Disaggregation of Revenue [Line Items]
Sales and other operating revenue									1,250.5	1,140.8	1,038.2
Energy
Disaggregation of Revenue [Line Items]
Sales and other operating revenue									49.7	53.2	54.3
Logistics
Disaggregation of Revenue [Line Items]
Sales and other operating revenue									101.0	89.7	82.9
Operating and licensing fees
Disaggregation of Revenue [Line Items]
Sales and other operating revenue									40.4	43.4	39.5
Other
Disaggregation of Revenue [Line Items]
Sales and other operating revenue									$ 9.3	$ 4.4	$ 8.4

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Business Segment Information - Narrative (Details)	12 Months Ended
	Dec. 31, 2018 segment
Segment Reporting [Abstract]
Number of reportable segments	3

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Business Segment Information - Segment Profit or Loss (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Segment Reporting Information [Line Items]
Sales and other operating revenues	$ 368.9	$ 364.5	$ 367.0	$ 350.5	$ 359.6	$ 339.0	$ 323.2	$ 309.7	$ 1,450.9	$ 1,331.5	$ 1,223.3
Adjusted EBITDA									263.2	234.7	217.0
Depreciation and amortization expense									141.6	128.2	114.2
Capital expenditures									100.3	75.6	63.7
Domestic Coke | Service Life
Segment Reporting Information [Line Items]
Depreciation and amortization expense									$ 9.2
Additional depreciation per common share (USD per share)									$ 0.14
Corporate and Other
Segment Reporting Information [Line Items]
Sales and other operating revenues									$ 0.0	0.0	1.5
Adjusted EBITDA									(35.7)	(43.2)	(57.0)
Depreciation and amortization expense									1.4	0.5	4.7
Capital expenditures									0.0	2.4	1.7
Coal Mining
Segment Reporting Information [Line Items]
Adjusted EBITDA									(9.8)	(10.5)	(15.0)
Operating Segments | Domestic Coke
Segment Reporting Information [Line Items]
Sales and other operating revenues									1,308.3	1,195.0	1,097.6
Adjusted EBITDA									207.9	188.9	193.9
Depreciation and amortization expense									114.4	102.6	84.0
Capital expenditures									95.1	68.8	44.6
Operating Segments | Brazil Coke
Segment Reporting Information [Line Items]
Sales and other operating revenues									40.4	43.4	39.5
Adjusted EBITDA									18.4	18.2	16.2
Depreciation and amortization expense									0.7	0.7	0.7
Operating Segments | Logistics
Segment Reporting Information [Line Items]
Sales and other operating revenues									102.2	93.1	84.7
Adjusted EBITDA									72.6	70.8	63.9
Depreciation and amortization expense									25.1	24.4	24.8
Capital expenditures									5.2	4.4	17.4
Elimination of intersegment sales
Segment Reporting Information [Line Items]
Sales and other operating revenues									(24.5)	(23.8)	(45.2)
Elimination of intersegment sales | Logistics
Segment Reporting Information [Line Items]
Sales and other operating revenues									24.5	23.8	23.2
Corporate and Other intersegment sales
Segment Reporting Information [Line Items]
Sales and other operating revenues									$ 0.0	$ 0.0	$ 22.0

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Business Segment Information - Segment Assets (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Segment Reporting Information [Line Items]
Segment assets, excluding income tax receivable	$ 2,044.6	$ 2,055.3
Tax assets	0.7	4.8
Total assets	2,045.3	2,060.1
Operating Segments | Domestic Coke
Segment Reporting Information [Line Items]
Segment assets, excluding income tax receivable	1,446.5	1,439.7
Operating Segments | Brazil Coke
Segment Reporting Information [Line Items]
Segment assets, excluding income tax receivable	15.1	10.9
Operating Segments | Logistics
Segment Reporting Information [Line Items]
Segment assets, excluding income tax receivable	463.0	491.9
Corporate and Other
Segment Reporting Information [Line Items]
Segment assets, excluding income tax receivable	$ 120.0	$ 112.8

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Business Segment Information - Adjusted EBITDA (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Segment Reporting [Abstract]
Net cash provided by operating activities									$ 185.8	$ 148.5	$ 219.1
Subtract:
Depreciation and amortization expense									141.6	128.2	114.2
Deferred income tax expense									(3.4)	(87.2)	3.1
Loss (gain) on extinguishment of debt, net							$ 20.2		0.3	20.4	(25.0)
Loss on divestiture of business									0.0	0.0	14.7
Loss from equity method investment									5.4	0.0	0.0
Changes in working capital and other									(5.1)	(16.4)	52.6
Net income	$ 5.5	$ 17.1	$ 11.4	$ 13.0	$ 173.9	$ 18.8	(31.5)	$ (57.7)	47.0	103.5	59.5
Add:
Depreciation and amortization expense									141.6	128.2	114.2
Interest expense, net									61.4	60.6	53.5
Loss (gain) on extinguishment of debt, net							$ 20.2		0.3	20.4	(25.0)
Income tax expense (benefit)									4.6	(81.6)	8.6
Contingent consideration adjustments									2.5	(1.7)	(10.1)
Transaction costs									0.4	0.0	0.0
Expiration of land deposits and write-off of costs related to potential new cokemaking facility									0.0	5.3	1.9
Non-cash reversal of acquired contractual obligation									0.0	0.0	(0.7)
Coal rationalization costs									0.0	0.0	0.4
Adjustment to unconsolidated affiliate earnings									5.4	0.0	0.0
Adjusted EBITDA									263.2	234.7	217.0
Subtract: Adjusted EBITDA attributable to noncontrolling interest									82.0	86.4	86.6
Adjusted EBITDA attributable to SunCoke Energy, Inc.									$ 181.2	$ 148.3	$ 130.4

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Selected Quarterly Data (unaudited) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Selected Quarterly Financial Information
Sales and other operating revenue	$ 368.9	$ 364.5	$ 367.0	$ 350.5	$ 359.6	$ 339.0	$ 323.2	$ 309.7	$ 1,450.9	$ 1,331.5	$ 1,223.3
Gross profit	39.7	45.8	52.3	47.0	56.8	51.3	32.9	42.2
Net income	5.5	17.1	11.4	13.0	173.9	18.8	(31.5)	(57.7)	47.0	103.5	59.5
Less: Net income (loss) attributable to noncontrolling interests	3.7	5.6	7.2	4.3	39.9	7.2	(7.3)	(58.7)	20.8	(18.9)	45.1
Net income attributable to SunCoke Energy, Inc.	$ 1.8	$ 11.5	$ 4.2	$ 8.7	$ 134.0	$ 11.6	$ (24.2)	$ 1.0	$ 26.2	$ 122.4	$ 14.4
Earnings (loss) attributable to SunCoke Energy, Inc. per common share:
Basic (in dollars per share)	$ 0.03	$ 0.18	$ 0.06	$ 0.13	$ 2.08	$ 0.18	$ (0.38)	$ 0.02	$ 0.40	$ 1.90	$ 0.22
Diluted (in dollars per share)	$ 0.03	$ 0.18	$ 0.06	$ 0.13	$ 2.05	$ 0.18	$ (0.38)	$ 0.02	$ 0.40	$ 1.88	$ 0.22
Loss (gain) on extinguishment of debt, net							$ 20.2		$ 0.3	$ 20.4	$ (25.0)
Provisional net income tax benefit					$ 154.7				4.8	154.7	$ 0.0
IRS
Earnings (loss) attributable to SunCoke Energy, Inc. per common share:
Deferred tax expense								$ 64.2	$ 1.4	64.2
Suncoke Inc
Earnings (loss) attributable to SunCoke Energy, Inc. per common share:
Provisional net income tax benefit					125.0					125.0
SunCoke Energy Partners, L.P. | Logistics
Earnings (loss) attributable to SunCoke Energy, Inc. per common share:
Deferred revenue					$ 16.4					$ 16.4

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Supplemental Condensed Combining and Consolidating Financial Information -Narrative (Details)	Dec. 31, 2017
Condensed Financial Information Disclosure [Abstract]
Percentage of net assets	25.00%

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Supplemental Condensed Combining and Consolidating Financial Information - Condensed Consolidating Statement of Income (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Revenues
Sales and other operating revenue	$ 368.9	$ 364.5	$ 367.0	$ 350.5	$ 359.6	$ 339.0	$ 323.2	$ 309.7	$ 1,450.9	$ 1,331.5	$ 1,223.3
Equity in earnings of subsidiaries									0.0	0.0	0.0
Total revenues									1,450.9	1,331.5	1,223.3
Costs and operating expenses
Cost of products sold and operating expenses									1,124.5	1,020.1	905.9
Selling, general and administrative expenses									66.1	79.0	90.6
Depreciation and amortization expense									141.6	128.2	114.2
Loss on divestiture of business									0.0	0.0	14.7
Total costs and operating expenses									1,332.2	1,227.3	1,125.4
Operating income									118.7	104.2	97.9
Interest (income) expense, net - affiliate									0.0	0.0	0.0
Interest expense (income), net									61.4	61.9	54.8
Total interest expense (income), net									61.4	61.9	54.8
Loss (gain) on extinguishment of debt							20.2		0.3	20.4	(25.0)
Income before income tax expense (benefit) and loss from equity method investment									57.0	21.9	68.1
Income tax expense (benefit)									4.6	(81.6)	8.6
Loss from equity method investment									5.4	0.0	0.0
Net income	5.5	17.1	11.4	13.0	173.9	18.8	(31.5)	(57.7)	47.0	103.5	59.5
Less: Net income (loss) attributable to noncontrolling interests	3.7	5.6	7.2	4.3	39.9	7.2	(7.3)	(58.7)	20.8	(18.9)	45.1
Net income attributable to SunCoke Energy, Inc.	$ 1.8	$ 11.5	$ 4.2	$ 8.7	$ 134.0	$ 11.6	$ (24.2)	$ 1.0	26.2	122.4	14.4
Comprehensive income									55.1	102.4	60.3
Less: Comprehensive income (loss) attributable to noncontrolling interests									20.8	(18.9)	45.1
Comprehensive income attributable to SunCoke Energy, Inc.									34.3	121.3	15.2
Issuer
Costs and operating expenses
Loss on divestiture of business											0.0
Loss from equity method investment									0.0
Guarantor Subsidiaries
Costs and operating expenses
Loss on divestiture of business											0.0
Loss from equity method investment									0.0
Non- Guarantor Subsidiaries
Costs and operating expenses
Loss on divestiture of business											14.7
Loss from equity method investment									5.4
Reportable Legal Entities | Issuer
Revenues
Sales and other operating revenue									0.0	0.0	0.0
Equity in earnings of subsidiaries									34.3	109.9	19.7
Total revenues									34.3	109.9	19.7
Costs and operating expenses
Cost of products sold and operating expenses									0.0	0.0	0.0
Selling, general and administrative expenses									6.5	8.7	12.9
Depreciation and amortization expense									0.0	0.0	0.0
Loss on divestiture of business											0.0
Total costs and operating expenses									6.5	8.7	12.9
Operating income									27.8	101.2	6.8
Interest (income) expense, net - affiliate									0.0	0.0	0.0
Interest expense (income), net									3.1	4.9	6.0
Total interest expense (income), net									3.1	4.9	6.0
Loss (gain) on extinguishment of debt									0.3	0.4	0.0
Income before income tax expense (benefit) and loss from equity method investment									24.4	95.9	0.8
Income tax expense (benefit)									(1.8)	(26.5)	(13.6)
Loss from equity method investment									0.0
Net income									26.2	122.4	14.4
Less: Net income (loss) attributable to noncontrolling interests									0.0	0.0	0.0
Net income attributable to SunCoke Energy, Inc.									26.2	122.4	14.4
Comprehensive income									34.3	121.3	15.2
Less: Comprehensive income (loss) attributable to noncontrolling interests									0.0	0.0	0.0
Comprehensive income attributable to SunCoke Energy, Inc.									34.3	121.3	15.2
Reportable Legal Entities | Guarantor Subsidiaries
Revenues
Sales and other operating revenue									216.0	209.6	176.7
Equity in earnings of subsidiaries									25.2	(54.5)	51.3
Total revenues									241.2	155.1	228.0
Costs and operating expenses
Cost of products sold and operating expenses									165.7	156.6	130.7
Selling, general and administrative expenses									11.8	22.7	25.6
Depreciation and amortization expense									8.8	7.5	9.2
Loss on divestiture of business											0.0
Total costs and operating expenses									186.3	186.8	165.5
Operating income									54.9	(31.7)	62.5
Interest (income) expense, net - affiliate									(6.0)	(7.5)	(7.6)
Interest expense (income), net									(1.6)	0.1	0.3
Total interest expense (income), net									(7.6)	(7.4)	(7.3)
Loss (gain) on extinguishment of debt									0.0	0.0	0.0
Income before income tax expense (benefit) and loss from equity method investment									62.5	(24.3)	69.8
Income tax expense (benefit)									12.1	(150.2)	38.7
Loss from equity method investment									0.0
Net income									50.4	125.9	31.1
Less: Net income (loss) attributable to noncontrolling interests									0.0	0.0	0.0
Net income attributable to SunCoke Energy, Inc.									50.4	125.9	31.1
Comprehensive income									50.6	125.3	30.8
Less: Comprehensive income (loss) attributable to noncontrolling interests									0.0	0.0	0.0
Comprehensive income attributable to SunCoke Energy, Inc.									50.6	125.3	30.8
Reportable Legal Entities | Non- Guarantor Subsidiaries
Revenues
Sales and other operating revenue									1,239.5	1,126.3	1,050.5
Equity in earnings of subsidiaries									0.0	0.0	0.0
Total revenues									1,239.5	1,126.3	1,050.5
Costs and operating expenses
Cost of products sold and operating expenses									963.4	867.9	779.1
Selling, general and administrative expenses									47.8	47.6	52.1
Depreciation and amortization expense									132.8	120.7	105.0
Loss on divestiture of business											14.7
Total costs and operating expenses									1,144.0	1,036.2	950.9
Operating income									95.5	90.1	99.6
Interest (income) expense, net - affiliate									6.0	7.5	7.6
Interest expense (income), net									59.9	56.9	48.5
Total interest expense (income), net									65.9	64.4	56.1
Loss (gain) on extinguishment of debt									0.0	20.0	(25.0)
Income before income tax expense (benefit) and loss from equity method investment									29.6	5.7	68.5
Income tax expense (benefit)									(5.7)	95.1	(16.5)
Loss from equity method investment									5.4
Net income									29.9	(89.4)	85.0
Less: Net income (loss) attributable to noncontrolling interests									20.8	(18.9)	45.1
Net income attributable to SunCoke Energy, Inc.									9.1	(70.5)	39.9
Comprehensive income									37.8	(91.0)	86.1
Less: Comprehensive income (loss) attributable to noncontrolling interests									20.8	(18.9)	45.1
Comprehensive income attributable to SunCoke Energy, Inc.									17.0	(72.1)	41.0
Combining and Consolidating Adjustments
Revenues
Sales and other operating revenue									(4.6)	(4.4)	(3.9)
Equity in earnings of subsidiaries									(59.5)	(55.4)	(71.0)
Total revenues									(64.1)	(59.8)	(74.9)
Costs and operating expenses
Cost of products sold and operating expenses									(4.6)	(4.4)	(3.9)
Selling, general and administrative expenses									0.0	0.0	0.0
Depreciation and amortization expense									0.0	0.0	0.0
Loss on divestiture of business											0.0
Total costs and operating expenses									(4.6)	(4.4)	(3.9)
Operating income									(59.5)	(55.4)	(71.0)
Interest (income) expense, net - affiliate									0.0	0.0	0.0
Interest expense (income), net									0.0	0.0	0.0
Total interest expense (income), net									0.0	0.0	0.0
Loss (gain) on extinguishment of debt									0.0	0.0	0.0
Income before income tax expense (benefit) and loss from equity method investment									(59.5)	(55.4)	(71.0)
Income tax expense (benefit)									0.0	0.0	0.0
Loss from equity method investment									0.0
Net income									(59.5)	(55.4)	(71.0)
Less: Net income (loss) attributable to noncontrolling interests									0.0	0.0	0.0
Net income attributable to SunCoke Energy, Inc.									(59.5)	(55.4)	(71.0)
Comprehensive income									(67.6)	(53.2)	(71.8)
Less: Comprehensive income (loss) attributable to noncontrolling interests									0.0	0.0	0.0
Comprehensive income attributable to SunCoke Energy, Inc.									$ (67.6)	$ (53.2)	$ (71.8)

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Supplemental Condensed Combining and Consolidating Financial Information - Condensed Consolidating Balance Sheet (Details) - USD ($) $ / shares in Units, $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Assets
Cash and cash equivalents	$ 145.7	$ 120.2
Receivables	75.4	68.5
Inventories	110.4	111.0
Income tax receivable	0.7	4.8
Other current assets	2.8	6.7
Advances to affiliates	0.0	0.0
Total current assets	335.0	311.2
Notes receivable from affiliate	0.0	0.0
Properties, plants and equipment, net	1,471.1	1,501.3
Goodwill	76.9	76.9
Other intangible assets, net	156.8	167.9
Deferred income taxes	0.0	0.0
Deferred charges and other assets	5.5	2.8
Total assets	2,045.3	2,060.1
Liabilities and Equity
Advances from affiliate	0.0	0.0
Accounts payable	115.0	115.5
Accrued liabilities	45.6	53.2
Deferred revenue	3.0	1.7
Current portion of long-term debt and financing obligation	3.9	2.6
Interest payable	3.6	5.4
Income taxes payable	0.0	0.0
Total current liabilities	171.1	178.4
Long-term debt and financing obligation	834.5	861.1
Payable to affiliate	0.0	0.0
Accrual for black lung benefits	44.9	44.9
Retirement benefit liabilities	25.2	28.2
Deferred income taxes	254.7	257.8
Asset retirement obligations	14.6	14.0
Other deferred credits and liabilities	17.6	16.1
Total liabilities	1,362.6	1,400.5
Equity
Preferred stock	0.0	0.0
Common stock	0.7	0.7
Treasury stock	(140.7)	(140.7)
Additional paid-in capital	488.8	486.2
Accumulated other comprehensive income (loss)	(13.1)	(21.2)
Retained earnings (deficit)	127.4	101.2
Equity investment eliminations	0.0	0.0
Total SunCoke Energy, Inc. stockholders' equity	463.1	426.2
Noncontrolling interests	219.6	233.4
Total equity	682.7	659.6	$ 639.9	$ 622.8
Total liabilities and equity	$ 2,045.3	$ 2,060.1
Supplemental Condensed Consolidating Financial Information (Additional Textual) [Abstract]
Preferred stock, par value (in dollars per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000
Preferred stock, shares issued (in shares)	0	0
Preferred stock, shares outstanding	0	0
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	300,000,000	300,000,000
Common stock, shares, issued (in shares)	72,233,750	72,006,905
Treasury stock, shares (in shares)	7,477,657	7,477,657
Reportable Legal Entities | Issuer
Assets
Cash and cash equivalents	$ 0.0	$ 0.0
Receivables	0.0	0.0
Inventories	0.0	0.0
Income tax receivable	0.0	0.0
Other current assets	0.0	0.0
Advances to affiliates	0.0	0.0
Total current assets	0.0	0.0
Notes receivable from affiliate	0.0	0.0
Properties, plants and equipment, net	0.0	0.0
Goodwill	0.0	0.0
Other intangible assets, net	0.0	0.0
Deferred income taxes	7.0	7.1
Deferred charges and other assets	0.0	0.0
Total assets	7.0	7.1
Liabilities and Equity
Advances from affiliate	167.3	162.2
Accounts payable	0.0	0.0
Accrued liabilities	1.8	1.5
Deferred revenue	0.0	0.0
Current portion of long-term debt and financing obligation	1.1	0.0
Interest payable	0.4	1.4
Income taxes payable	1.9	1.9
Total current liabilities	172.5	167.0
Long-term debt and financing obligation	41.2	42.7
Payable to affiliate	0.0	0.0
Accrual for black lung benefits	0.0	0.0
Retirement benefit liabilities	0.0	0.0
Deferred income taxes	0.0	0.0
Asset retirement obligations	0.0	0.0
Other deferred credits and liabilities	3.5	3.7
Total liabilities	217.2	213.4
Equity
Preferred stock	0.0	0.0
Common stock	0.7	0.7
Treasury stock	(140.7)	(140.7)
Additional paid-in capital	488.9	486.2
Accumulated other comprehensive income (loss)	(13.1)	(21.2)
Retained earnings (deficit)	127.5	101.2
Equity investment eliminations	(673.5)	(632.5)
Total SunCoke Energy, Inc. stockholders' equity	(210.2)	(206.3)
Noncontrolling interests	0.0	0.0
Total equity	(210.2)	(206.3)
Total liabilities and equity	7.0	7.1
Reportable Legal Entities | Guarantor Subsidiaries
Assets
Cash and cash equivalents	123.2	103.6
Receivables	13.3	17.1
Inventories	10.6	9.1
Income tax receivable	0.0	0.0
Other current assets	1.8	4.6
Advances to affiliates	281.1	245.8
Total current assets	430.0	380.2
Notes receivable from affiliate	0.0	89.0
Properties, plants and equipment, net	54.3	59.8
Goodwill	3.4	3.4
Other intangible assets, net	1.1	1.7
Deferred income taxes	0.0	0.0
Deferred charges and other assets	5.1	2.3
Total assets	493.9	536.4
Liabilities and Equity
Advances from affiliate	0.0	0.0
Accounts payable	14.7	16.4
Accrued liabilities	13.7	19.7
Deferred revenue	0.0	0.0
Current portion of long-term debt and financing obligation	0.0	0.0
Interest payable	0.0	0.0
Income taxes payable	93.5	81.4
Total current liabilities	121.9	117.5
Long-term debt and financing obligation	0.0	0.0
Payable to affiliate	200.0	300.0
Accrual for black lung benefits	10.9	11.8
Retirement benefit liabilities	12.2	13.7
Deferred income taxes	194.9	193.8
Asset retirement obligations	0.0	0.0
Other deferred credits and liabilities	6.6	6.4
Total liabilities	546.5	643.2
Equity
Preferred stock	0.0	0.0
Common stock	0.0	0.0
Treasury stock	0.0	0.0
Additional paid-in capital	61.0	141.0
Accumulated other comprehensive income (loss)	(2.0)	(2.2)
Retained earnings (deficit)	526.1	475.6
Equity investment eliminations	(637.7)	(721.2)
Total SunCoke Energy, Inc. stockholders' equity	(52.6)	(106.8)
Noncontrolling interests	0.0	0.0
Total equity	(52.6)	(106.8)
Total liabilities and equity	493.9	536.4
Reportable Legal Entities | Non- Guarantor Subsidiaries
Assets
Cash and cash equivalents	22.5	16.6
Receivables	62.1	51.4
Inventories	99.8	101.9
Income tax receivable	96.1	88.1
Other current assets	1.0	2.1
Advances to affiliates	0.0	0.0
Total current assets	281.5	260.1
Notes receivable from affiliate	200.0	300.0
Properties, plants and equipment, net	1,416.8	1,441.5
Goodwill	73.5	73.5
Other intangible assets, net	155.7	166.2
Deferred income taxes	0.0	0.0
Deferred charges and other assets	0.4	0.5
Total assets	2,127.9	2,241.8
Liabilities and Equity
Advances from affiliate	113.8	83.6
Accounts payable	100.3	99.1
Accrued liabilities	30.1	32.0
Deferred revenue	3.0	1.7
Current portion of long-term debt and financing obligation	2.8	2.6
Interest payable	3.2	4.0
Income taxes payable	0.0	0.0
Total current liabilities	253.2	223.0
Long-term debt and financing obligation	793.3	818.4
Payable to affiliate	0.0	89.0
Accrual for black lung benefits	34.0	33.1
Retirement benefit liabilities	13.0	14.5
Deferred income taxes	66.8	71.1
Asset retirement obligations	14.6	14.0
Other deferred credits and liabilities	7.5	6.0
Total liabilities	1,182.4	1,269.1
Equity
Preferred stock	0.0	0.0
Common stock	0.0	0.0
Treasury stock	0.0	0.0
Additional paid-in capital	612.8	641.9
Accumulated other comprehensive income (loss)	(11.1)	(19.0)
Retained earnings (deficit)	124.2	116.4
Equity investment eliminations	0.0	0.0
Total SunCoke Energy, Inc. stockholders' equity	725.9	739.3
Noncontrolling interests	219.6	233.4
Total equity	945.5	972.7
Total liabilities and equity	2,127.9	2,241.8
Combining and Consolidating Adjustments
Assets
Cash and cash equivalents	0.0	0.0
Receivables	0.0	0.0
Inventories	0.0	0.0
Income tax receivable	(95.4)	(83.3)
Other current assets	0.0	0.0
Advances to affiliates	(281.1)	(245.8)
Total current assets	(376.5)	(329.1)
Notes receivable from affiliate	(200.0)	(389.0)
Properties, plants and equipment, net	0.0	0.0
Goodwill	0.0	0.0
Other intangible assets, net	0.0	0.0
Deferred income taxes	(7.0)	(7.1)
Deferred charges and other assets	0.0	0.0
Total assets	(583.5)	(725.2)
Liabilities and Equity
Advances from affiliate	(281.1)	(245.8)
Accounts payable	0.0	0.0
Accrued liabilities	0.0	0.0
Deferred revenue	0.0	0.0
Current portion of long-term debt and financing obligation	0.0	0.0
Interest payable	0.0	0.0
Income taxes payable	(95.4)	(83.3)
Total current liabilities	(376.5)	(329.1)
Long-term debt and financing obligation	0.0	0.0
Payable to affiliate	(200.0)	(389.0)
Accrual for black lung benefits	0.0	0.0
Retirement benefit liabilities	0.0	0.0
Deferred income taxes	(7.0)	(7.1)
Asset retirement obligations	0.0	0.0
Other deferred credits and liabilities	0.0	0.0
Total liabilities	(583.5)	(725.2)
Equity
Preferred stock	0.0	0.0
Common stock	0.0	0.0
Treasury stock		0.0
Additional paid-in capital	(673.9)	(782.9)
Accumulated other comprehensive income (loss)	13.1	21.2
Retained earnings (deficit)	(650.4)	(592.0)
Equity investment eliminations	1,311.2	1,353.7
Total SunCoke Energy, Inc. stockholders' equity	0.0	0.0
Noncontrolling interests	0.0	0.0
Total equity	0.0	0.0
Total liabilities and equity	$ (583.5)	$ (725.2)

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Supplemental Condensed Combining and Consolidating Financial Information - Condensed Consolidating Statement of Cash Flows (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Cash Flows from Operating Activities:
Net income	$ 5.5	$ 17.1	$ 11.4	$ 13.0	$ 173.9	$ 18.8	$ (31.5)	$ (57.7)	$ 47.0	$ 103.5	$ 59.5
Adjustments to reconcile net income to net cash (used in) provided by operating activities:
Loss from equity method investment									5.4	0.0	0.0
Depreciation and amortization expense									141.6	128.2	114.2
Deferred income tax (benefit) expense									(3.4)	(87.2)	3.1
Gain on curtailment and payments in excess of expense for postretirement plan benefits									(2.4)	(1.8)	(2.6)
Share-based compensation expense									3.1	4.8	6.5
Equity in loss of subsidiaries									0.0	0.0	0.0
Loss (gain) on extinguishment of debt							$ 20.2		0.3	20.4	(25.0)
Loss on divestiture of business									0.0	0.0	14.7
Changes in working capital pertaining to operating activities (net of the effects of divestiture):
Receivables									(6.9)	(7.8)	3.7
Inventories									0.6	(18.5)	29.4
Accounts payable									(0.7)	11.7	(0.8)
Accrued liabilities									(7.3)	2.6	6.8
Deferred revenue									1.3	(0.8)	0.4
Interest payable									(1.8)	(10.8)	(2.7)
Income taxes									4.5	(0.2)	7.0
Other									4.5	4.4	4.9
Net cash provided by operating activities									185.8	148.5	219.1
Cash Flows from Investing Activities:
Capital expenditures									(100.3)	(75.6)	(63.7)
Sale of equity method investment									(4.0)
Return of Brazilian investment									0.0	20.5	20.5
Divestiture of coal business									0.0	0.0	(12.8)
Other investing activities									0.5	0.0	2.1
Net cash used in investing activities									(95.8)	(55.1)	(53.9)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt									45.0	693.7	0.0
Repayment of long-term debt									(45.7)	(644.9)	(66.1)
Debt issuance costs									(0.5)	(17.4)	(0.2)
Proceeds from revolving facility									179.5	350.0	28.0
Repayment of revolving facility									(204.5)	(392.0)	(98.4)
Proceeds from financing obligation									0.0	0.0	16.2
Repayment of financing obligation									(2.6)	(2.5)	(1.0)
Cash distributions to noncontrolling interests									(31.9)	(47.0)	(49.4)
Acquisition of additional interest in the Partnership									(4.2)	(48.7)
Other financing activities									0.4	1.1	(1.4)
Net increase (decrease) in advances from affiliates									0.0	0.0	0.0
Net cash used in financing activities									(64.5)	(107.7)	(172.3)
Net increase (decrease) in cash, cash equivalents and restricted cash									25.5	(14.3)	(7.1)
Cash, cash equivalents and restricted cash at beginning of year				120.2				134.5	120.2	134.5	141.6
Cash, cash equivalents and restricted cash at end of year	145.7				120.2				145.7	120.2	134.5
Issuer
Adjustments to reconcile net income to net cash (used in) provided by operating activities:
Loss from equity method investment									0.0
Loss on divestiture of business											0.0
Guarantor Subsidiaries
Adjustments to reconcile net income to net cash (used in) provided by operating activities:
Loss from equity method investment									0.0
Loss on divestiture of business											0.0
Non- Guarantor Subsidiaries
Adjustments to reconcile net income to net cash (used in) provided by operating activities:
Loss from equity method investment									5.4
Loss on divestiture of business											14.7
Reportable Legal Entities | Issuer
Cash Flows from Operating Activities:
Net income									26.2	122.4	14.4
Adjustments to reconcile net income to net cash (used in) provided by operating activities:
Loss from equity method investment									0.0
Depreciation and amortization expense									0.0	0.0	0.0
Deferred income tax (benefit) expense									(0.2)	(22.8)	(16.6)
Gain on curtailment and payments in excess of expense for postretirement plan benefits									0.0	0.0	0.0
Share-based compensation expense									3.1	4.7	6.5
Equity in loss of subsidiaries									(34.3)	(109.9)	(19.7)
Loss (gain) on extinguishment of debt									0.3	0.4	0.0
Loss on divestiture of business											0.0
Changes in working capital pertaining to operating activities (net of the effects of divestiture):
Receivables									0.0	0.0	0.0
Inventories									0.0	0.0	0.0
Accounts payable									0.0	0.0	0.0
Accrued liabilities									0.4	(0.2)	1.5
Deferred revenue									0.0	0.0	0.0
Interest payable									(1.0)	(0.1)	0.1
Income taxes									0.3	(2.7)	(6.9)
Other									0.3	1.3	2.5
Net cash provided by operating activities									(4.9)	(6.9)	(18.2)
Cash Flows from Investing Activities:
Capital expenditures									0.0	0.0	0.0
Sale of equity method investment									0.0
Return of Brazilian investment										0.0	0.0
Divestiture of coal business											0.0
Other investing activities									0.0		0.0
Net cash used in investing activities									0.0	0.0	0.0
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt									45.0	0.0
Repayment of long-term debt									(45.7)	0.0	0.0
Debt issuance costs									(0.5)	(1.6)	0.0
Proceeds from revolving facility									0.0	0.0	0.0
Repayment of revolving facility									0.0	0.0	(60.4)
Proceeds from financing obligation											0.0
Repayment of financing obligation									0.0	0.0	0.0
Cash distributions to noncontrolling interests									0.0	0.0	0.0
Acquisition of additional interest in the Partnership									0.0	0.0
Other financing activities									0.7	1.1	(0.3)
Net increase (decrease) in advances from affiliates									5.4	7.4	78.9
Net cash used in financing activities									4.9	6.9	18.2
Net increase (decrease) in cash, cash equivalents and restricted cash									0.0	0.0	0.0
Cash, cash equivalents and restricted cash at beginning of year				0.0				0.0	0.0	0.0	0.0
Cash, cash equivalents and restricted cash at end of year	0.0				0.0				0.0	0.0	0.0
Reportable Legal Entities | Guarantor Subsidiaries
Cash Flows from Operating Activities:
Net income									50.4	125.9	31.1
Adjustments to reconcile net income to net cash (used in) provided by operating activities:
Loss from equity method investment									0.0
Depreciation and amortization expense									8.8	7.5	9.2
Deferred income tax (benefit) expense									1.2	(170.1)	8.7
Gain on curtailment and payments in excess of expense for postretirement plan benefits									(1.0)	(1.0)	(1.5)
Share-based compensation expense									0.0	0.0	0.0
Equity in loss of subsidiaries									(25.2)	54.5	(51.3)
Loss (gain) on extinguishment of debt									0.0	0.0	0.0
Loss on divestiture of business											0.0
Changes in working capital pertaining to operating activities (net of the effects of divestiture):
Receivables									3.8	(4.9)	(4.3)
Inventories									(1.5)	(0.1)	(3.7)
Accounts payable									(1.6)	3.0	4.6
Accrued liabilities									(5.9)	(1.3)	4.8
Deferred revenue									0.0	0.0	0.0
Interest payable									0.0	0.0	0.0
Income taxes									12.2	16.3	28.2
Other									(0.9)	0.0	8.9
Net cash provided by operating activities									40.3	29.8	34.7
Cash Flows from Investing Activities:
Capital expenditures									(2.8)	(4.1)	(5.7)
Sale of equity method investment									0.0
Return of Brazilian investment										0.0	0.0
Divestiture of coal business											0.0
Other investing activities									0.0		0.0
Net cash used in investing activities									(2.8)	(4.1)	(5.7)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt									0.0	0.0
Repayment of long-term debt									0.0	0.0	0.0
Debt issuance costs									0.0	0.0	0.0
Proceeds from revolving facility									0.0	0.0	0.0
Repayment of revolving facility									0.0	0.0	0.0
Proceeds from financing obligation											0.0
Repayment of financing obligation									0.0	0.0	0.0
Cash distributions to noncontrolling interests									0.0	0.0	0.0
Acquisition of additional interest in the Partnership									(4.2)	(48.7)
Other financing activities									0.0	0.0	(1.1)
Net increase (decrease) in advances from affiliates									(13.7)	66.9	(38.8)
Net cash used in financing activities									(17.9)	18.2	(39.9)
Net increase (decrease) in cash, cash equivalents and restricted cash									19.6	43.9	(10.9)
Cash, cash equivalents and restricted cash at beginning of year				103.6				59.7	103.6	59.7	70.6
Cash, cash equivalents and restricted cash at end of year	123.2				103.6				123.2	103.6	59.7
Reportable Legal Entities | Non- Guarantor Subsidiaries
Cash Flows from Operating Activities:
Net income									29.9	(89.4)	85.0
Adjustments to reconcile net income to net cash (used in) provided by operating activities:
Loss from equity method investment									5.4
Depreciation and amortization expense									132.8	120.7	105.0
Deferred income tax (benefit) expense									(4.4)	105.7	11.0
Gain on curtailment and payments in excess of expense for postretirement plan benefits									(1.4)	(0.8)	(1.1)
Share-based compensation expense									0.0	0.1	0.0
Equity in loss of subsidiaries									0.0	0.0	0.0
Loss (gain) on extinguishment of debt									0.0	20.0	(25.0)
Loss on divestiture of business											14.7
Changes in working capital pertaining to operating activities (net of the effects of divestiture):
Receivables									(10.7)	(2.9)	8.0
Inventories									2.1	(18.4)	33.1
Accounts payable									0.9	8.7	(5.4)
Accrued liabilities									(1.8)	4.1	0.5
Deferred revenue									1.3	(0.8)	0.4
Interest payable									(0.8)	(10.7)	(2.8)
Income taxes									(8.0)	(13.8)	(14.3)
Other									5.1	3.1	(6.5)
Net cash provided by operating activities									150.4	125.6	202.6
Cash Flows from Investing Activities:
Capital expenditures									(97.5)	(71.5)	(58.0)
Sale of equity method investment									(4.0)
Return of Brazilian investment										20.5	20.5
Divestiture of coal business											(12.8)
Other investing activities									0.5		2.1
Net cash used in investing activities									(93.0)	(51.0)	(48.2)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt									0.0	693.7
Repayment of long-term debt									0.0	(644.9)	(66.1)
Debt issuance costs									0.0	(15.8)	(0.2)
Proceeds from revolving facility									179.5	350.0	28.0
Repayment of revolving facility									(204.5)	(392.0)	(38.0)
Proceeds from financing obligation											16.2
Repayment of financing obligation									(2.6)	(2.5)	(1.0)
Cash distributions to noncontrolling interests									(31.9)	(47.0)	(49.4)
Acquisition of additional interest in the Partnership									0.0	0.0
Other financing activities									(0.3)	0.0	0.0
Net increase (decrease) in advances from affiliates									8.3	(74.3)	(40.1)
Net cash used in financing activities									(51.5)	(132.8)	(150.6)
Net increase (decrease) in cash, cash equivalents and restricted cash									5.9	(58.2)	3.8
Cash, cash equivalents and restricted cash at beginning of year				16.6				74.8	16.6	74.8	71.0
Cash, cash equivalents and restricted cash at end of year	22.5				16.6				22.5	16.6	74.8
Combining and Consolidating Adjustments
Cash Flows from Operating Activities:
Net income									(59.5)	(55.4)	(71.0)
Adjustments to reconcile net income to net cash (used in) provided by operating activities:
Loss from equity method investment									0.0
Depreciation and amortization expense									0.0	0.0	0.0
Deferred income tax (benefit) expense									0.0	0.0	0.0
Gain on curtailment and payments in excess of expense for postretirement plan benefits									0.0	0.0	0.0
Share-based compensation expense									0.0	0.0	0.0
Equity in loss of subsidiaries									59.5	55.4	71.0
Loss (gain) on extinguishment of debt									0.0	0.0	0.0
Loss on divestiture of business											0.0
Changes in working capital pertaining to operating activities (net of the effects of divestiture):
Receivables									0.0	0.0	0.0
Inventories									0.0	0.0	0.0
Accounts payable									0.0	0.0	0.0
Accrued liabilities									0.0	0.0	0.0
Deferred revenue									0.0	0.0	0.0
Interest payable									0.0	0.0	0.0
Income taxes									0.0	0.0	0.0
Other									0.0	0.0	0.0
Net cash provided by operating activities									0.0	0.0	0.0
Cash Flows from Investing Activities:
Capital expenditures									0.0	0.0	0.0
Sale of equity method investment									0.0
Return of Brazilian investment										0.0	0.0
Divestiture of coal business											0.0
Other investing activities									0.0		0.0
Net cash used in investing activities									0.0	0.0	0.0
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt									0.0	0.0
Repayment of long-term debt									0.0	0.0	0.0
Debt issuance costs									0.0	0.0	0.0
Proceeds from revolving facility									0.0	0.0	0.0
Repayment of revolving facility									0.0	0.0	0.0
Proceeds from financing obligation											0.0
Repayment of financing obligation									0.0	0.0	0.0
Cash distributions to noncontrolling interests									0.0	0.0	0.0
Acquisition of additional interest in the Partnership									0.0	0.0
Other financing activities									0.0	0.0	0.0
Net increase (decrease) in advances from affiliates									0.0	0.0	0.0
Net cash used in financing activities									0.0	0.0	0.0
Net increase (decrease) in cash, cash equivalents and restricted cash									0.0	0.0	0.0
Cash, cash equivalents and restricted cash at beginning of year				$ 0.0				$ 0.0	0.0	0.0	0.0
Cash, cash equivalents and restricted cash at end of year	$ 0.0				$ 0.0				$ 0.0	$ 0.0	$ 0.0