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, 2017 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	¨	Accelerated filer	ý
Non-accelerated filer	¨  (Do not check if a smaller reporting company)	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, 2017 closing price of $10.90 on the New York Stock Exchange) held by non-affiliates was approximately $694,796,596.

The number of shares of common stock outstanding as of February 9, 2018 was 64,542,973.

Portions of the SunCoke Energy, Inc. 2018 definitive Proxy Statement, which will be filed with the Securities and Exchange Commission within 120 days after December 31, 2017, 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	30
Item 2.	Properties	31
Item 3.	Legal Proceedings	31
Item 4.	Mine Safety Disclosures	32
PART II
Item 5.	Market for Registrant’s Common Equity, Related Stockholders Matters and Issuer Purchases of Equity Securities	32
Item 6.	Selected Financial Data	35
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	36
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	111
Item 9A.	Controls and Procedures	111
Item 9B.	Other Information	111
PART III
Item 10.	Directors, Executive Officers and Corporate Governance	112
Item 11.	Executive Compensation	112
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	112
Item 13.	Certain Relationships and Related Transactions, and Director Independence	112
Item 14.	Principal Accounting Fees and Services	114
PART IV
Item 15.	Exhibits, Financial Statement Schedules	115

PART I

Item 1. Business

Overview

SunCoke Energy, Inc. (“SunCoke Energy,” “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 approximately 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, 2017, 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 59.9 percent limited partner interest in the Partnership. The remaining 38.1 percent interest in the Partnership was held by public unitholders.

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.”

Business Segments

We report our business results through three segments:

• Domestic Coke consists of our Jewell Coke Company, L.P. ("Jewell"), Indiana Harbor Coke Company ("Indiana Harbor"), Haverhill Coke Company LLC ("Haverhill"), Gateway Energy and Coke Company, LLC ("Granite City") and Middletown Coke Company, LLC ("Middletown") cokemaking and heat recovery operations located in Vansant, Virginia; East Chicago, Indiana; Franklin Furnace, Ohio; Granite City, Illinois; and Middletown, Ohio, respectively.

• Brazil Coke consists of our operations in Vitória, Brazil, where we operate a cokemaking facility, ArcelorMittal Brasil S.A. ("ArcelorMittal Brazil”), for a Brazilian subsidiary of ArcelorMittal S.A.;

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

For additional information regarding our business segments, see “Part II. Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” and Note 18 to our consolidated financial statements.

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
					1,150	5,940
Equity Method Investment:
VISA SunCoke(2)	Odisha, India	Various	2007	NA	88	440	Steam for power generation
Total					1,238	6,380

(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.

(2) We hold a 49 percent investment in a cokemaking joint venture with VISA Steel Limited in India ("VISA SunCoke"), which was fully impaired in 2015, and consequently, beginning in the fourth quarter of 2015, we no longer include our share of VISA SunCoke in our financial results. Cokemaking capacity represents 100 percent of VISA SunCoke.

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 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.

2

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 seven 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 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 three of our coke sales agreements are fixed subject to an annual adjustment based on an inflation index. Under our other three 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. Beginning in 2015, the operating and maintenance cost recovery mechanism in our Indiana Harbor coke sales agreement shifted from an annually negotiated budget amount with a cap to a fixed recovery per ton. 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. In 2018, the operating cost component of our contract at Indiana Harbor reverts to an annually negotiated budget, which is expected to have a favorable impact on our future results. 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 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 Plant iron production capacity. AK Steel must give at least two years prior notice of its intention to terminate the agreement. The Company finds that neither of the criteria have been met. No other coke sales contract 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, they have benefited from improved steel pricing, favorable trade rulings, and solid end market demand in 2017. Despite recent trade actions, imported steel continues to be an issue across the industry as finished steel imports remain elevated at approximately 27 percent of U.S. steel consumption. Despite the improving macro environment, AK Steel has kept its Ashland Kentucky Works facility idled and U.S. Steel has kept portions of its Granite City Works facility idled, both since 2015.

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 segment consists of CMT, KRT, Lake Terminal and DRT. CMT 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 due to its new ship loader, placed in service during the fourth quarter of 2016. 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 recently secured additional merchant business including aggregates (crushed stone) and petroleum coke. Additionally, we secured barge unloading capabilities to efficiently unload coal, petroleum coke and other materials from barges at CMT’s dock. The addition of barge unloading capabilities complements CMT's existing rail and truck offerings and provides the terminal with the ability to transload and mix a significantly broader variety of materials. 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 two operations in West Virginia. Lake Terminal is located in East Chicago, Indiana and provides coal handling and mixing services to SunCoke's Indiana Harbor cokemaking operations. DRT was formed in 2016 to accommodate our Jewell cokemaking facility 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. For CMT, cash received from customers for take-or-pay billings based on pro-rata volume commitments under take-or-pay contracts that is in excess of cash earned for services provided is recorded as deferred revenue. Deferred revenue on take-or-pay contracts is recognized into income at the earlier of when service is provided or annually based on the terms of the contract. Our 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. Services provided to our domestic cokemaking facilities are provided under contracts with terms equivalent to those of an 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.

In 2017, global thermal coal prices continued to rise to nearly $100 per ton from previous lows during early 2016, resulting in improved export economics for our CMT customers. On a spot basis, average API2 and API5 index prices in 2017 have improved 40 percent and 36 percent, respectively, as compared to 2016. In 2017, metallurgical market conditions and volumes were generally favorable, but thermal market demand was low due to weak natural gas prices and suppressed, weather-related electricity demand.

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.

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 5.6 million tons of metallurgical coal in 2017. 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 2018, 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 point of delivery 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 held by us. 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 of $5.1 million.

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. In 2017, our Domestic Coke segment accounted for approximately 25 percent of coke market capacity in the U.S. 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 industrial materials. CMT is the only bulk material terminal in the lower U.S. with direct rail access on the Canadian National Railway. In 2017, CMT accounted for approximately 52 percent of U.S. thermal coal exports from the U.S. Gulf Coast and approximately 18 percent of total U.S. thermal coal exports. In late 2016, CMT commissioned a new 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, 2017, we have approximately 909 employees in the U.S. Approximately 39 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 2018, at which time the collective bargaining process will resume. We do not anticipate any work stoppages during the extended period of the agreement. In 2017, we reached a new three-year agreement for our Granite City location, which will expire on August 31, 2020.

As of December 31, 2017, we have approximately 270 employees at the cokemaking facility in Vitória, Brazil, all of whom are represented by a union under a labor agreement. In 2017, we reached a new one-year labor agreement at our Vitoria, Brazil facility which will expire on October 31, 2018. We will negotiate the renewal of this agreement in 2018 and do not anticipate any work stoppages.

6

Safety

We are committed to maintaining a safe work environment and ensuring strict environmental compliance across all of our operations as the health and safety of our employees and the communities in which we operate are critical to our success. We believe that we employ best practices and conduct continual training programs to ensure that all of our employees are focused on safety. Furthermore, we employ a structured safety and environmental process that provides a robust framework for managing and monitoring safety and environmental performance.

We have consistently operated within the top quartilefor the U.S. Occupational Safety and Health Administration’s 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 U.S. Environmental Protection Agency ("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.

• Air Quality. Our cokemaking facilities employ Maximum Available Control Technology (“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 Best Available Control Technology (“BACT”). In a non-attainment area, the facility must install air pollution control equipment or employ procedures that meet Lowest Achievable Emission Rate (“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 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

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challenges to these designations are possible. If redesignated, we may be required 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 November 2015, the EPA revised the existing NAAQS for ground level ozone to make the standard more stringent. In November 2017, EPA designated the area where the Haverhill and Jewell facilities are located as attainment/unclassifiable. In December 2017, various related litigants filed a lawsuit against the EPA claiming the agency failed to designate those areas that are not in compliance with the standard for ground-based ozone. EPA subsequently announced its intent to designate various areas of the country as nonattainment, including where the Indiana Harbor, Granite City, and Middletown facilities are located, but invited the states to submit updated air quality data to potentially change that designation. In January 2018, EPA announced its intent to designate all remaining areas of the country by April 30, 2018, but there remains a possibility of further legal action that could affect this date. These designations, whenever issued, 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 also 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 process 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

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authorities have considerable discretion in the timing of the permit issuance and the public has the right to 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, 2017, we have posted $10.4 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, 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 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. Currently there is little information as to what may constitute BACT for GHG in most industries. We may also be subject to the EPA’s “Tailoring Rule,” where 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. Depending on whether the Clean Power Plan is ultimately upheld or if another rule is promulgated in the future, it could increase the demand for natural gas-generated electricity.

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.

• 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 the Occupational Safety and Health Administration (OSHA) of the United States Department of Labor and equivalent state agencies under various standards designed to promote worker safety. As noted above, we have consistently operated within the top quartile 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, 2017, we had 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, 2017 was $50.3 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, 2017.

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 Partnership’s ability 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 and 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").

Executive Officers of the Registrant

Our executive officers and their ages as of February 15, 2018, were as follows:

Name	Age	Position
Michael G. Rippey	60	President and Chief Executive Officer
Fay West	48	Senior Vice President and Chief Financial Officer
Katherine T. Gates	41	Senior Vice President, General Counsel and Chief Compliance Officer
P. Michael Hardesty	55	Senior Vice President, Commercial Operations, Business Development, Terminals and International Coke
Allison S. Lausas	38	Vice President, Finance and Controller
Gary P. Yeaw	60	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 $1.1 billion steel service center headquartered in Ohio, where he is a member of the Nominating Committee, the Compensation Committee, and 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 a member of its Audit 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 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

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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 October 2014. Ms. Lausas joined SunCoke Energy, Inc. in 2011 and most recently held the role of Assistant Controller. 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 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, or pulverized coal, and the use of these coke substitutes may increase in the future, particularly in light of current low natural gas prices. 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 have a material and adverse effect on our results of operations and therefore our ability to distribute cash to unitholders.

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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, 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 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.”

The final impacts of the Tax Cuts and Jobs Act could be materially different from our current estimates.

The Tax Cuts and Jobs Act (“Tax Legislation”) was signed into law on December 22, 2017. The new law made numerous changes to U.S. federal corporate tax law and is expected to reduce our effective tax rate for fiscal year 2018 and future periods. Effective January 1, 2018, the Tax Legislation lowers the U.S. corporate tax rate from 35 percent to 21 percent and prompts various other changes to U.S. federal corporate tax law, including the establishment of a territorial-style system for taxing foreign-source income of domestic multinational corporations. The tax benefit recorded in 2017 involves significant judgment and assumptions as to the impact of the Tax Legislation. Our estimated impact of the new law is based on management's current knowledge and assumptions. Recognized impacts could be materially different from current estimates based on our actual results in fiscal year 2018 and our further analysis of the new law. Because we are in the process of quantifying the impact of the Tax Legislation, we expect to record any adjustments in the next year in accordance with the guidance provided in the SEC Staff Accounting Bulletin No. 118. These adjustments could be material. The full impact of the Tax Legislation on our business, operations, and financial statements cannot be predicted at this time and we make no assurances in this regard. See Note 5 to the consolidated financial statements.

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,

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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 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 per share. 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.

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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 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.

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.

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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, 2017. Under the Partnership’s revolving credit agreement, the lenders could declare the loans and other amounts (including letter of credit obligations), totaling $131.9 million at December 31, 2017, to be immediately due and payable.

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

Over the next five years, we have approximately $187.3 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;

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• 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.

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.

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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 facility are subject to early termination under certain circumstances and any such termination could have a material adverse effect on our consolidated cash flows, financial position and 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 by AK Steel under certain circumstances, and any such termination could have a material adverse effect on our business. The Haverhill coke sales agreement with AK Steel expires on December 31, 2021, with two automatic, successive five-year renewal periods, which are subject to termination if notice is given at least one-year prior to 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 iron production operations at its steel plant works in Ashland, Kentucky (the Ashland 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 Plant’s iron production capacity.

If AK Steel were to terminate the Haverhill AK Steel Contracts, we may be unable to enter into similar long-term contracts with replacement customers for all or any portion of the coke previously purchased by AK Steel. Similarly, we may be forced to sell some or all of the previously contracted coke in the spot market, which could be at prices lower than we have currently contracted for and could subject us to significant price volatility. If AK Steel elects to terminate the Haverhill AK Steel Contracts, our cash flows, financial position and results of operations could be materially and adversely affected.

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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.

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.

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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 more than half 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 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.

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,

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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.

CMT is impacted by seaborne export market dynamics.  Fluctuations in the benchmark price for coal delivery into northwest Europe, as referenced in the API2 index price, influence our customers' decisions to place tons into the export market and thus impact transloading volumes through our terminal facility. 

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.

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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 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 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 required 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, 2017, our liabilities for coal workers’ black lung benefits totaled approximately$50.3 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.”

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.

Our Board of Directors has suspended the Company's dividend. 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.

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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;

• 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 59.9 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

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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 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

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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 “Management’s Discussion and Analysis-Final Regulations”. 

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 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 Partnership’s ability to continue to qualify as a publicly traded partnership.

Item 1B. Unresolved Staff Comments

None.

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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.

• 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 lease small parcels of land, mineral rights and coal mining rights for approximately 35 thousand acres of land in Buchanan and Russell Counties, Virginia. These leases convey mining rights to us in exchange for payment of certain 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, 2017.

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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.

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 have been trading under the stock trading symbol “SXC” on the New York Stock Exchange since July 21, 2011. The table below provides quarterly price ranges of our common stock for the two most recent fiscal years, based on the high and low prices from intraday trades.

	2017				2016
	High		Low		High		Low
First quarter	$	11.88	$	8.04	$	6.63	$	2.05
Second quarter	$	11.47	$	7.66	$	8.19	$	5.14
Third quarter	$	11.25	$	8.20	$	8.20	$	5.52
Fourth quarter	$	12.57	$	9.01	$	13.14	$	7.23

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Performance Graph

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, 2012 to December 31, 2017.

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 9, 2018, we had a total of 72,020,630 issued shares and 64,542,973 outstanding shares of our common stock and had 11,732 holders of record of our common stock.

Dividends

In 2015, our Board of Directors suspended the Company's dividend. Any future dividends will be determined by the Company's Board of Directors on a quarterly basis and will depend on business conditions, our financial condition, earnings, liquidity and capital requirements, covenants in our debt agreements and other factors.

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 2017. At December 31, 2017 there was $39.4 million available under the authorized share repurchase program.

Partnership Common Unit Purchase Program

In April 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 $50.0 million. In July 2017, the Company's Board of Directors authorized the Company to purchase an incremental $50.0 millionof Partnership common units in the open market. During 2017, the Company purchased 2,853,032 of outstanding Partnership common units in the open market for total cash payments of $48.7 million, which increased our limited partner interest in the Partnership from53.9 percent to 59.9 percent at December 31, 2017.

Subsequent to December 31, 2017, the Company purchased an additional 132,188 of outstanding Partnership common units in the open market for total cash payments of $2.3 million, leaving a remaining common unit purchase program balance of $49.0 million as of February 15, 2018.

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. At December 31, 2017, there was $37.2 million available under the authorized unit repurchase program. There were no unit repurchases during 2017.

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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,
	2017(1)		2016(1)		2015(1)			2014			2013
	(Dollars in millions, except per share amounts)
Operating Results:
Total revenues	$	1,331.5	$	1,223.3	$	1,362.7		$	1,503.8		$	1,647.7
Operating income (loss)(2)	$	102.9	$	96.6	$	79.8		$	(62.4	)	$	111.3
Net income (loss)(2)(3)(4)	$	103.5	59.5		$	10.3		$	(101.8	)	$	50.1
Net income (loss) attributable to SunCoke Energy, Inc.(4)(5)	$	122.4	$	14.4	$	(22.0	)	$	(126.1	)	$	25.0
Earnings (loss) attributable to SunCoke Energy, Inc. per common share
Basic	$	1.90	$	0.22	$	(0.34	)	$	(1.83	)	$	0.36
Diluted	$	1.88	$	0.22	$	(0.34	)	$	(1.83	)	$	0.36
Dividends paid per share	$	—	$	—	$	0.4335		$	0.0585		$	—
Other Information:
Total assets	$	2,060.1	$	2,120.9	$	2,255.5		$	1,959.7		$	2,213.3
Long-term debt	$	861.1	$	849.2	$	997.7		$	633.5		$	630.1

(1) The results of CMT have been included in the consolidated financial statements since it was acquired on August 12, 2015. CMT added combined assets of $394.6 million, $411.7 million and $426.1 million at December 31, 2017, 2016 and 2015, respectively. CMT contributed revenues of $71.1 million, $62.7 million and $28.6 million, as well as operating income of $42.3 million, $46.5 million and $18.4 million during 2017, 2016 and 2015, respectively.

(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) 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.

(5) On January 13, 2015 and on August 12, 2015 the Partnership acquired ownership interests in the Company's Granite City cokemaking facility of 75 percent and 23 percent, respectively. Additionally, on January 24, 2013, in conjunction with the Partnership's initial public offering, and on May 9, 2014, the Partnership acquired ownership interests in each of the Company's Haverhill and Middletown cokemaking facilities of 65 percent and 33 percent, respectively.

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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 18 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.

2017 Overview

Our consolidated results of operations in 2017 were as follows:

	Year Ended December 31,
	2017
	(Dollars in millions)
Net income attributable to SunCoke Energy, Inc.	$	122.4
Net cash provided by operating activities	$	148.5
Adjusted EBITDA	$	234.7

During 2017, the Company successfully delivered against the majority of our key objectives:

• Achieved financial objectives. We delivered Adjusted EBITDA of $234.7 million, at the top end of our guidance range of $220 million to $235 million, and generated $148.5 million of operating cash flow, above our post-refinancing guidance of between $128 million and $143 million and in line with our original guidance. Domestic Coke contributed Adjusted EBITDA per ton of approximately $49, at the high-end of our guidance range of $46 to $49 per ton, on 3.9 million tons. Logistics delivered Adjusted EBITDA of $70.8 million, within our guidance range of $67 million to $72 million, reflecting the highest annual volumes in CMT’s history.

• Refinanced our overall capital structure and deployed cash toward attractive investment opportunities. We refinanced our senior note obligations at both the Company and the Partnership and extended revolver maturities by more than 4 years to nearly 7 years remaining. Our current capital structure now provides us with significant flexibility to execute our growth, operating and capital allocation priorities going forward. We also purchased 2.9 million Partnership common units for $48.7 million, increasing our limited interest from 53.9 percent to 59.9 percent. Assuming distributions per unit from the Partnership remain consistent, the Company expects to save $7 million annually on total distributions paid to public unitholders.

• Expanded Logistics customer and product mix. We secured new volumes at CMT, expanding into aggregates (crushed stone) and petroleum coke, which contributed $1.5 million of Adjusted EBITDA. We also secured barge unloading capabilities at CMT, which provide the terminal with the ability to transload and mix a significantly broader variety of materials.

• Completed 58 oven rebuilds at Indiana Harbor. We have now rebuilt a total of 144 total ovens at our Indiana Harbor facility, more than half of the entire facility, and remain encouraged by the performance in charge weights and coking times on the rebuilt ovens. As a result of lost production from planned ovens out of service and operating and maintenance expense on the oven rebuilds, we expected Adjusted EBITDA losses at Indiana Harbor of approximately $13 million in 2017. However, in the fourth quarter of 2017, planned oven rebuilds were out of service longer than anticipated. Additionally, we experienced faster than anticipated degradation of certain non-

36

rebuilt ovens. Both of these factors drove lower production than anticipated, which resulted in additional losses of $5.5 million beyond our Adjusted EBITDA guidance.

Our Focus and Outlook for 2018

During 2018, our primary focus will be to:

• Accomplish our 2018 financial objectives. We expect to deliver Adjusted EBITDA of between $240 million and $255 million and operating cash flow of between $150 million and $165 million. Significant improvement at Indiana Harbor and solid ongoing operations across the remaining Domestic Coke fleet are expected to drive Adjusted EBITDA per ton of approximately $50 to $52 on approximately 3.9 million tons of coke. Logistics is expected to continue to grow and to deliver Adjusted EBITDA of approximately $71 million to $76 million.

• Deliver operational excellence and optimize our asset base. We will continue to work with new and existing customers to fully utilize our existing cokemaking and logistics capacity. We plan to leverage CMT's capabilities to diversify its customer base and product mix to secure new business, which we expect will contribute to our plan of securing an additional $5 million to $10 million of Adjusted EBITDA in the next two years. We also remain committed to maintaining a safe work environment and expect to substantially complete the Granite City gas sharing environmental remediation project.

• Complete 67 oven rebuilds at Indiana Harbor.  We expect our Indiana Harbor cokemaking operation to deliver near break-even results on 870 thousand to 900 thousand tons of coke sales. The 2018 rebuilds are expected to cost approximately $30 million to $35 million, including capital expenditures of approximately $25 million to $30 million. Longer-term, we anticipate increased production from the rebuilt ovens and improved operating and maintenance spending as the oven rebuild campaign comes to an end.

Items Impacting Comparability

• Debt Activities. During 2017, the Partnership refinanced its debt obligations and the Company extended the maturity of its Revolving Facility and reduced its borrowing capacity to $100.0 million. As a result of the debt refinancing, 2017 included a loss on extinguishment of debt on the Consolidated Statement of Operations of $20.4 million. See further discussion of these activities in Note 12 to our consolidated financial statements and discussion in "Liquidity and Capital Resources."

During 2016 and 2015, the Partnership de-levered its balance sheet by repurchasing $89.5 million and $47.5 million face value 2020 Partnership Notes, resulting in gains on debt extinguishment of $25.0 million and $12.1 million on the Consolidated Statement of Operations during 2016 and 2015, respectively. Additionally, during 2015, we contributed 98 percent interest in Granite City to the Partnership. In connection with the related financing, the Partnership incurred losses on extinguishment of debt of $11.4 million in 2015.

As a result of the above debt activities, weighted average debt balances during 2017, 2016 and 2015 were $885.4 million, $920.2 million and $819.6 million, respectively, and interest expense, net was $60.6 million, $53.5 million and $56.2 million, respectively. The increase in interest expense, net in 2017 as compared to 2016 was driven by higher interest rates as a result of the Partnership's debt refinancing activities as well as lower capitalized interest, partially offset by lower average debt balances. The decrease in interest expense, net in 2016 as compared to 2015 was the result of favorable interest rates on new debt as compared to rates on debt repurchased, partially offset by interest on higher average debt balances.

• Tax Rulings.

◦ Tax Legislation. On December 22, 2017, the Tax Cuts and Jobs Act (“Tax Legislation”) was enacted. The Tax Legislation significantly revises 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. 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

37

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

• Terminated the Potential New Cokemaking Facility Project. We continue to have regular discussions with our customers regarding their respective long-term coke requirements. However, our ability to construct a new cokemaking facility, or enter into new commercial arrangements with our coke customers, is subject to our customers' decisions with respect to their own cokemaking assets, their outlook for their coke requirements and general domestic steel industry and market conditions. Our ongoing focus is to renew our existing customers' contracts in the upcoming years.

In 2014, we finalized the required permitting and engineering plan for a potential new cokemaking facility to be constructed in Kentucky. However, in June 2017, due to our focus on renewing our existing customer contracts and the lack of any long-term customer commitment for a majority of the facility's capacity, we decided to terminate the project. As a result, during 2017, the Company wrote-off previously capitalized engineering cost and land deposits of $5.3 million. During 2016, the Company wrote-off expiring land deposits related to the project of $1.9 million. These costs were included in selling, general and administrative expenses on the Consolidated Statements of Operations.

• Convent Marine Terminal Acquisition. Comparability between periods was impacted by the acquisition of CMT on August 12, 2015. CMT results in periods presented were as follows:

	Years Ended December 31,
	2017		2016		2015
	(Dollars in millions)
Total revenues	$	71.1	$	62.7	$	28.6
Cost of products sold and operating expenses(1)	11.9		1.3		4.7
Depreciation and amortization expense	16.8		14.8		5.4
Adjusted EBITDA	57.4		50.5		20.6

(1) Includes $1.7 million and $10.1 million of favorable fair value adjustments to our contingent consideration liability in 2017 and 2016, respectively.

• Redemption of 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") 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. With the redemption of the Brazil Investment, the Company no longer receives the $9.5 millionannual preferred dividend. Additionally, in 2016, SunCoke added certain new patents to its existing intellectual property licensing agreement for which SunCoke now earns an incremental $5.1 million in annual licensing fees through 2023. 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. Overall, these transactions resulted in a redemption of the investment and a reduction of $4.4 million to total revenues and Adjusted EBITDA in 2016 and each subsequent year through the end of the contract.

• Loss on Divestiture of Business and Impairments. 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. Cost savings due to the absence of the coal mining operations

38

improved Adjusted EBITDA results by $8.4 million in 2016 as compared to 2015 and an additional $2.5 million in 2017 as compared to 2016.

• Pension Plan Termination. Effective May 30, 2014, Dominion Coal Corporation ("Dominion Coal"), a wholly-owned subsidiary of the Company, terminated its defined benefit plan, which was previously offered generally to all full-time employees of Dominion Coal. In June 2015, the plan settled its obligations by purchasing annuities using plan assets, which triggered settlement accounting and resulted in a non-cash loss of $12.6 million recorded in cost of products sold and operating expenses on the Consolidated Statements of Operations.

• India Equity Method Investment. As a result of market conditions, we recorded impairment charges of $19.4 million related to our equity method investment in VISA SunCoke during 2015, included in loss from equity method investment on the Consolidated Statements of Operations. The 2015 impairment brought our investment in VISA SunCoke to zero, and consequently, we no longer include our share of VISA SunCoke in our financial results. See Note 17 to our consolidated financial statements.

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Consolidated Results of Operations

The following section includes analysis of consolidated results of operations for the years ended December 31, 2017, 2016 and 2015. See "Analysis of Segment Results" later in this section for further details of these results.

	Years Ended December 31,									Increase (Decrease)
	2017			2016			2015			2017 vs. 2016			2016 vs. 2015
	(Dollars in millions)
Revenues
Sales and other operating revenue	$	1,331.5		$	1,223.3		$	1,362.7		$	108.2		$	(139.4	)
Costs and operating expenses
Cost of products sold and operating expenses	1,020.8			906.5			1,098.4			114.3			(191.9		)
Selling, general and administrative expenses	79.6			91.3			75.4			(11.7		)	15.9
Depreciation and amortization expense	128.2			114.2			109.1			14.0			5.1
Loss on divestiture of business and impairments(1)	—			14.7			—			(14.7		)	14.7
Total costs and operating expenses	1,228.6			1,126.7			1,282.9			101.9			(156.2		)
Operating income	102.9			96.6			79.8			6.3			16.8
Interest expense, net(1)	60.6			53.5			56.2			7.1			(2.7		)
Loss (gain) on extinguishment of debt, net(1)	20.4			(25.0		)	0.5			45.4			(25.5		)
Income before income tax (benefit) expense and loss from equity method investment	21.9			68.1			23.1			(46.2		)	45.0
Income tax (benefit) expense	(81.6		)	8.6			(8.8		)	(90.2		)	17.4
Loss from equity method investment(1)	—			—			21.6			—			(21.6		)
Net income	103.5			59.5			10.3			44.0			49.2
Less: Net (loss) income attributable to noncontrolling interests	(18.9		)	45.1			32.3			(64.0		)	12.8
Net income (loss) attributable to SunCoke Energy, Inc.	$	122.4		$	14.4		$	(22.0	)	$	108.0		$	36.4

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

Sales and Other Operating Revenue. The increase in sales and other operating revenue in 2017 as compared to the prior year was primarily due to the pass-through of higher coal prices in our Domestic Coke segment as well as higher sales volumes in our Logistics segment partially offset by lower sales volumes in our Domestic Coke segment. The decrease in sales and other operating revenues in 2016 as compared to 2015 primarily reflects the pass-through of lower coal prices in our Domestic Coke segment as well as lower sales volumes in both our Domestic Coke and Logistics segments, excluding the contributions of CMT. These decreases in 2016 were partly offset by a full year of contributions from CMT, increasing sales and other operating revenue $34.1 million as compared to 2015.

Cost of Products Sold and Operating Expenses. The increase in cost of products sold and operating expense in 2017 was primarily due to higher coal costs associated with higher coal prices in our Domestic Coke segment as compared to 2016. The decrease in cost of products sold and operating expense in 2016 was primarily due to the result of reduced coal costs in our Domestic Coke segment as compared to 2015. Additionally, black lung charges of $9.8 million in 2015 were recorded in costs of products sold and operating expenses. Beginning in 2016, with our exit from the coal mining business, black lung charges were recorded in selling, general and administrative expenses, which resulted in a favorable impact to cost of products sold and operating expenses in 2016 compared to 2015. Adjustments to our contingent consideration liability decreased cost of products sold and operating expenses by $1.7 million and $10.1 million in 2017 and 2016, respectively. See Note 17 to our consolidated financial statements.

Selling, General and Administrative Expenses. The decrease in selling, general and administrative expense in 2017 was driven by lower employee-related and other 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 in 2017 as compared to 2016. These benefits were partially offset by the year-over-year impact of the expiration of land deposits and the write-off of costs associated with the termination of our project for a potential new cokemaking facility previously discussed in "Items Impacting Comparability." The increase in selling, general and administrative expense in 2016 as compared to 2015 was primarily driven by $8.1 million of black lung charges in 2016, as black lung charges were included in cost of products sold

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and operating expenses prior to 2016, as discussed above. The remaining increase was driven by unfavorable fair value adjustments in deferred compensation as a result of changes in certain performance metrics and changes in the Company’s share price and Partnership's unit price as well as the absence of a $4.0 million postretirement benefit plan curtailment gain recognized in 2015.

Depreciation and Amortization Expense. The increase in depreciation and amortization expense during 2017 was impacted by depreciation expense on the new ship loader at CMT and certain environmental remediation assets at our Haverhill cokemaking facility, both placed in service during the fourth quarter of 2016. The increase in depreciation and amortization expense in 2016 was driven by a full year of depreciation of CMT assets of $14.8 million in 2016 compared to depreciation expense of $5.4 million in 2015, as CMT was acquired in August 2015. CMT depreciation was mostly offset by lower depreciation of our coal mining assets, which decreased as a result of the disposal of our assets in April 2016.  Depreciation and amortization expense in each year was also impacted by revisions to the remaining useful lives of certain assets, primarily related to certain assets in our Domestic Coke segment and the closure of our former coal preparation plant, which resulted in additional depreciation of $22.4 million, $13.7 million and $15.1 million, or $0.35, $0.17 and $0.21 per common share from operations, during 2017, 2016 and 2015, respectively.

Income Taxes. Income tax benefit was $81.6 million and $8.8 million in 2017 and 2015, respectively, while 2016 had income tax expense of $8.6 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 benefit related to the Tax Legislation, both previously discussed in "Items Impacting Comparability." Additionally, the income tax benefit recorded in 2015 related to the insolvency of a subsidiary. See 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
	2017			2016			2015
Net (loss) income attributable to the Partnership's common public unitholders'(1)(2)	$	(13.5	)	$	46.1		$	34.1
Net loss attributable to third-party interest in our Indiana Harbor cokemaking facility(3)	(5.4		)	(1.0		)	(1.8		)
Net (loss) income attributable to noncontrolling interest	$	(18.9	)	$	45.1		$	32.3

(1) The decrease during the year ended December 31, 2017 as compared to 2016 was primarily due to the impacts of the IRS Final Regulations, which resulted in the Partnership becoming taxable at the end of the 10-year transition period, as well as the Partnership's loss on extinguishment of debt in 2017 and the absence of the Partnership's gain on extinguishment of debt in 2016. These impacts were partially offset by the Tax Legislation in 2017, which lowered corporate income tax rates. See "Items Impacting Comparability" for further discussion.

(2) The increase during the year ended December 31, 2016 as compared to 2015 was primarily due to the Partnership's gain on extinguishment of debt due to its de-levering activities previously described in "Items Impacting Comparability."

(3) The decrease during the year ended December 31, 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 Coke Company, L.P. ("Jewell"), Indiana Harbor Coke Company ("Indiana Harbor"), Haverhill Coke Company LLC ("Haverhill"), Gateway Energy and Coke Company, LLC ("Granite City") and Middletown Coke Company, LLC ("Middletown") cokemaking and heat recovery operations located in Vansant, Virginia; East Chicago, Indiana; Franklin Furnace, Ohio; Granite City, Illinois; and Middletown, Ohio, respectively.

• Brazil Coke consists of our operations in Vitória, Brazil, where we operate a cokemaking facility, ArcelorMittal Brasil S.A. ("ArcelorMittal Brazil”), for a Brazilian subsidiary of ArcelorMittal S.A.;

• Logistics consists of Convent Marine Terminal ("CMT"), Kanawha River Terminals, LLC ("KRT"), SunCoke Lake Terminal, LLC ("Lake Terminal"), and Dismal River Terminal, LLC ("DRT") providing handling and/or

41

mixing services in Convent, Louisiana; Ceredo and Belle, West Virginia; East Chicago, Indiana; and 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, which was historically presented as a reportable segment. Prior year periods have been recasted to reflect current presentation.

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 18 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, 2017, 2016 and 2015:

	Years Ended December 31,									Increase (Decrease)
	2017			2016			2015			2017 vs. 2016			2016 vs. 2015
	(Dollars in millions, except per ton amounts)
Sales and other operating revenue:
Domestic Coke	$	1,195.0		$	1,097.6		$	1,244.1		$	97.4		$	(146.5	)
Brazil Coke	43.4			39.5			43.4			3.9			(3.9		)
Logistics	93.1			84.7			60.8			8.4			23.9
Logistics intersegment sales	23.8			23.2			20.4			0.6			2.8
Corporate and Other(1)	—			1.5			14.4			(1.5		)	(12.9		)
Corporate and Other intersegment sales(1)	—			22.0			101.0			(22.0		)	(79.0		)
Elimination of intersegment sales	(23.8		)	(45.2		)	(121.4		)	21.4			76.2
Total sales and other operating revenue	$	1,331.5		$	1,223.3		$	1,362.7		$	108.2		$	(139.4	)
Adjusted EBITDA(2):
Domestic Coke	$	188.9		$	193.9		$	210.1		$	(5.0	)	$	(16.2	)
Brazil Coke	18.2			16.2			22.4			2.0			(6.2		)
Logistics	70.8			63.9			38.0			6.9			25.9
Corporate and Other, including legacy costs, net(3)	(43.2		)	(57.0		)	(85.1		)	13.8			28.1
Adjusted EBITDA	$	234.7		$	217.0		$	185.4		$	17.7		$	31.6
Coke Operating Data:
Domestic Coke capacity utilization (%)	91			93			97			(2		)	(4		)
Domestic Coke production volumes (thousands of tons)	3,861			3,954			4,122			(93		)	(168		)
Domestic Coke sales volumes (thousands of tons)	3,851			3,956			4,115			(105		)	(159		)
Domestic Coke Adjusted EBITDA per ton(4)	$	49.05		$	49.01		$	51.06		$	0.04		$	(2.05	)
Brazilian Coke production—operated facility (thousands of tons)	1,761			1,741			1,760			20			(19		)
Logistics Operating Data:
Tons handled (thousands of tons)(5)	21,616			18,569			18,864			3,047			(295		)
CMT take-or-pay shortfall tons (thousands of tons)(6)	2,918			6,076			1,291			(3,158		)	4,785

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

(2) See Note 18 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, 2017, 2016 and 2015.

(3) Corporate and Other includes the activity from our legacy coal mining business, which incurred Adjusted EBITDA losses of $10.5 million, $15.0 million, and $40.9 million for the years ended December 31, 2017, 2016 and 2015, 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
	2017 vs. 2016			2016 vs. 2015			2017 vs. 2016			2016 vs. 2015
	(Dollars in millions)
Beginning	$	1,097.6		$	1,244.1		$	193.9		$	210.1
Volumes(1)	(23.8		)	(35.9		)	(2.5		)	(7.5		)
Coal cost recovery and yields(2)	118.8			(103.6		)	7.1			(8.8		)
Operating and maintenance costs(3)	1.0			2.3			(15.6		)	14.0
Transportation costs shifted from Coal Mining segment(4)	—			—			—			(5.5		)
Haverhill turbine failure(5)	0.9			(0.9		)	3.5			(3.5		)
Energy and other	0.5			(8.4		)	2.5			(4.9		)
Ending	$	1,195.0		$	1,097.6		$	188.9		$	193.9

(1) In both 2016 and 2017, volumes were negatively impacted by 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 were increasing in 2017 and decreasing in 2016. Additionally, our oven rebuilds at Indiana Harbor, which began in late 2015, negatively impacted coal-to-coke yields in 2016 as compared to 2015. As the oven rebuilds have continued in 2017, the impact on coal-to-coke yield gains in 2017 was comparable to 2016.

(3) 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. Operating and maintenance savings in 2016 as compared to 2015 was primarily a result of a cost rationalization initiative completed in 2016 at Indiana Harbor.

(4) In 2016, the divestiture of the coal mining business and the transition to a 100 percent purchased third-party coal model resulted in a shift of coal transportation costs from our former Coal Mining segment to our Jewell cokemaking facility of approximately $5.5 million. This shift of costs had no impact on consolidated Adjusted EBITDA.

(5) In October 2016, the Partnership sustained a turbine failure at its Haverhill II facility, the impact of which was partially mitigated by insurance recoveries. The Haverhill II turbine was fully restored in January 2017.

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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
	2017 vs. 2016		2016 vs. 2015			2017 vs. 2016		2016 vs. 2015
	(Dollars in millions)
Beginning	$	107.9	$	81.2		$	63.9	$	38.0
Acquisition of CMT(1)	—		34.1			—		29.9
Creation of DRT(2)	—		3.9			—		0.7
Transloading volumes(3)	3.1		(10.5		)	2.4		(5.6		)
Price/margin impact of mix in transloading services(4)	3.0		(1.4		)	3.0		—
Operating and maintenance costs and other	2.9		0.6			1.5		0.9
Ending	$	116.9	$	107.9		$	70.8	$	63.9

(1) Comparability between 2016 and 2015 was impacted by the acquisition of CMT on August 12, 2015. Both 2016 and 2017 reflect a full year of CMT results.

(2) Comparability between 2016 and 2015 was impacted by the formation of DRT in early 2016. Both 2016 and 2017 reflect a full year of DRT results.

(3) CMT achieved record volumes in 2017, which included $1.0 million of new merchant business. Transloading volumes decreased at KRT and Lake Terminal in both 2016 and 2017, driven by challenging market conditions in both the thermal and metallurgical coal markets.

(4) The contractual price escalation for transloading services provided to certain customers at CMT in 2017 primarily drove the increase in both revenue and Adjusted EBITDA in 2017 as compared to 2016.

Brazil Coke

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 reimbursement of 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.

2016 compared to 2015

Sales and other operating revenue decreased$3.9 million, or 9.0 percent, to $39.5 million in 2016 compared to $43.4 million in 2015. The decrease in sales and other operating revenue was primarily driven by the absence of our $9.5 million preferred annual dividend, no longer received with the redemption of our Brazil Investment in 2016, net of the $5.1 million additional licensing fees. Higher reimbursement of operating and maintenance costs favorably impacted sales and other operating revenue $2.0 million compared to 2015. The remaining decrease was primarily related to unfavorable translation adjustments.

Adjusted EBITDA decreased$6.2 million, or 27.7 percent, to $16.2 million in 2016 compared to $22.4 million in 2015. The decrease in Adjusted EBITDA was primarily driven by the absence of our $9.5 million preferred annual dividend, as described above, net of the $5.1 million additional licensing fees. The remaining decrease was primarily related to unfavorable translation adjustments.

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Corporate and Other

2017 compared to 2016

Corporate and Other Adjusted EBITDA results, which include costs related to our legacy coal mining business, 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 includes 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 current year 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 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.

2016 compared to 2015

Corporate and Other revenues, inclusive of intersegment sales, were $23.5 million and $115.4 million for 2016 and 2015, respectively, and represented revenues from our legacy coal mining business, which was disposed of in April 2016.

Corporate and Other Adjusted EBITDA results, which include activity from our legacy coal mining business, improved $28.1 million, or 33.0 percent, to losses of $57.0 million in 2016 as compared to losses of $85.1 million in 2015. The improvement includes a $25.9 million year-over-year benefit associated with the absence of our legacy coal mining business, which was disposed of in April 2016. The Company also incurred lower severance costs of $3.8 million in 2016 as well as additional employee-related savings of $1.3 million in 2016 compared to 2015. The absence of $2.6 million of transaction costs incurred in 2015 related to the acquisition of CMT and the Granite City dropdowns further improved results in 2016 as compared to the prior year period. These improvements were partially offset by increases in expenses of $5.5 million substantially driven by mark-to-market adjustments in deferred compensation caused by changes in certain performance metrics and changes in the Company's share price and the Partnership's unit price.

Liquidity and Capital Resources

Our primary liquidity needs are to finance the fund of working capital, fund investments, service our debt, maintain cash reserves and replacement of 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. We may be required to access the capital markets for funding related to the maturities of our long-term borrowings beginning in 2022. As of December 31, 2017, together with the Partnership, we had $120.2 million of cash and cash equivalents and $226.6 millionof borrowing availability under our credit facilities.

Debt Refinancing

During 2017, the Partnership refinanced its debt obligations and received $693.7 million of proceeds, net of a net discount of $6.3 million, from the issuance of $700.0 million of 7.5 percent 2025 Partnership Notes. The Partnership also increased the Partnership Revolver's capacity to $285.0 millionand extended its maturity date to May 2022. Additionally, the Company extended the Revolving Facility's maturity date to May 2022 and reduced its capacity to $100.0 million. In connection with the refinancing and revolver amendments, the Company and the Partnership incurred debt issuance costs of $17.6 million.

The Partnership used the proceeds described above to purchase and redeem all of its 2020 Partnership Notes, including principal of $463.0 million and a premium of $18.7 million, repay the $50.0 millionoutstanding on the Partnership Term Loan, repay the $112.6 million outstanding on the Partnership's Promissory Noteand reduce the Partnership Revolver outstanding balance by $42.0 million.

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. The Company funded the redemption with a term loan in the aggregate principal amount of $45.0 million maturing on May 24, 2022 under the Company’s existing Amended and Restated Credit Agreement.

As a result of the debt refinancing activities and the timing of these activities, consolidated interest expense, net is expected to increase by approximately $3 million in 2018 compared to 2017.

See further discussion of these debt activities in Note 12 to our consolidated financial statements.

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Covenants

As of December 31, 2017, 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.

Credit Rating

In May 2017, Moody's Investor Services ("Moody's") upgraded the Company's corporate family rating to B1 from B2, in connection with the refinancing of the Partnership's capital structure. The rating upgrade reflects the improved steel market fundamentals and the strengthened financial position of our customers as well as de-leveraging undertaken by the Company and Partnership in the past 24 months.

Distributions

On January 22, 2018, the Partnership's Board of Directors declared a quarterly cash distribution of $0.5940 per unit. This distribution will be paid on March 1, 2018 to unitholders of record on February 15, 2018.

Partnership Common Unit Purchase Program

In April 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 $50.0 million. In July 2017, the Company's Board of Directors authorized the Company to purchase an incremental $50.0 millionof Partnership common units in the open market. During 2017, the Company purchased 2,853,032 of outstanding Partnership common units in the open market for total cash payments of $48.7 million, which increased our limited partner interest in the Partnership from53.9 percent to 59.9 percent at December 31, 2017.

Subsequent to December 31, 2017, the Company purchased an additional 132,188 of outstanding Partnership common units in the open market for total cash payments of $2.3 million, leaving a remaining common unit purchase program balance of $49.0 million as of February 15, 2018.

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, 2017, 2016 and 2015:

	Years Ended December 31,
	2017			2016			2015
	(Dollars in millions)
Net cash provided by operating activities	$	148.5		$	219.1		$	141.1
Net cash used in investing activities	(54.6		)	(36.2		)	(285.2		)
Net cash (used in) provided by financing activities	(107.7		)	(172.3		)	128.5
Net (decrease) increase in cash and cash equivalents	$	(13.8	)	$	10.6		$	(15.6	)

Cash Provided by Operating Activities

Net cash provided by operating activities decreased by $70.6 million in 2017 as compared to 2016. The decrease was primarily driven by the unfavorable year-over-year change in primary working capital, which is comprised of accounts receivable, inventories and accounts payable, 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 of $10.6 million during 2017 as compared to 2016 due primarily to changes in the timing of interest payments 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.

Net cash provided by operating activities increased by $78.0 million in 2016 as compared to 2015 partially due to the full year benefit of CMT's cash provided by operating activities, a net increase of $35.0 million. Larger decreases to coal inventory levels and coal prices in 2016 as compared to 2015 as well as timing of payments for coal purchases in 2015 provided additional operating cash flow of approximately $23 million in 2016. Lower operating costs due to the divestiture of

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the coal mining business during 2016 also contributed to the increase in operating cash flow as compared to 2015. Additionally, 2015 was adversely impacted by coal severance payments of $11.5 million.

Cash Used in Investing Activities

Net cash used in investing activities increased $18.4 million to $54.6 million in 2017 as compared to 2016. The increase is primarily due to higher capital spending on the Indiana Harbor oven rebuild initiative and the environmental remediation project at Granite City during 2017 as compared to 2016. This increase was partially offset by the $12.8 million payment related to the divestiture of the coal mining business in 2016.

Net cash used in investing activities decreased $249.0 million to $36.2 million in 2016 as compared to 2015. The decrease is primarily due to the absence of the investing cash outflow of $191.7 million from the acquisition of CMT in 2015. In 2016, the Partnership amended an agreement with The Cline Group, which unrestricted $6.0 million of previously restricted cash and relieved the Partnership of any obligation to repay these amounts to The Cline Group. The Company also received $20.5 million in cash at the closing of the redemption of its Brazil Investment during 2016. These cash inflows were more than offset by the divestiture of the coal mining business in 2016, where the Company paid $12.8 million to Revelation, as well as capital expenditures, excluding the CMT capital expansion costs, which was funded from restricted cash. The decrease in capital expenditures in 2016 compared to 2015 related to lower spending on the environmental remediation project at Haverhill during 2016.

Cash (Used in) Provided by Financing Activities

Net cash used in financing activities was $107.7 million in 2017, and was primarily related to the Company's acquisition of outstanding Partnership common units for a total payment of $48.7 million and the Partnership's distribution payment 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. See Note 12 to our consolidated financial statements for further discussion of debt activities.

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.

Net cash provided by financing activities was $128.5 million in 2015, and was primarily in connection with the Granite City Dropdown and the acquisition of CMT. The proceeds from the issuance of the related debt, net of repayments were $249.4 million. These net cash inflows were partially offset by return of investments to shareholders and unitholders, including dividends and distributions of $71.3 million and equity repurchases of $48.5 million.

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.

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

	Years Ended December 31,
	2017		2016		2015
	(Dollars in millions)
Ongoing capital(1)	$	54.7	$	39.8	$	45.9
Environmental remediation project(2)	19.4		7.8		20.9
Expansion capital:(3)
CMT ship loader(4)	1.1		13.5		4.6
Other capital expansion	0.4		2.6		4.4
Total expansion capital	1.5		16.1		9.0
Total capital expenditures	$	75.6	$	63.7	$	75.8

(1) Includes $29.7 million, $14.0 million and $12.1 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, 2017, 2016 and 2015, respectively.

(2) Includes $1.1 million, $2.7 million and $2.9 million of interest capitalized in connection with the environmental gas sharing projects for the years ended December 31, 2017, 2016 and 2015, respectively.

(3) Excludes the acquisition of CMT.

(4) 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 and $0.8 million for the years ended December 31, 2016 and 2015, respectively.

In 2018, we expect our capital expenditures to be approximately $95 million, which is comprised of the following:

• Total ongoing capital expenditures of approximately $59 million, of which approximately $25 million will be spent at the Partnership and approximately $25 million to $30 million will be spent on the Indiana Harbor oven rebuild project.

• Total capital expenditures on environmental remediation projects of approximately $35 million, all of which will be spent at the Partnership, including the cash payments for certain work performed in 2017; and

• Total expansion capital of approximately $1 million in our Logistics segment.

We anticipate spending approximately $145 million on our environmental remediation projects to comply with the expected terms of the consent decree at our Haverhill and Granite City cokemaking operations. We have spent approximately $111 million, including $7 million spent by the Company prior to the formation of the Partnership, related to these projects since 2012. The remaining capital is expected to be spent through the first quarter of 2019. A portion of the proceeds from the Partnership's initial public offering and the dropdowns of ownership interest in Haverhill, Middletown and Granite City are to be used to fund $119 million of these environmental remediation projects. Pursuant to the omnibus agreement, the Company will reimburse the Partnership approximately $20 million for the estimated additional spending beyond what has previously been funded.

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Contractual Obligations

The following table summarizes our significant contractual obligations as of December 31, 2017:

			Payment Due Dates
	Total		2018		2019-2020		2021-2022		Thereafter
	(Dollars in millions)
Total borrowings:(1)
Principal	$	887.3	$	2.6	$	54.7	$	130.0	$	700.0
Interest	422.2		61.9		118.7		112.5		129.1
Operating leases(2)	9.3		3.1		3.8		1.3		1.1
Purchase obligations:
Coal(3)(4)	584.4		527.6		56.8		—		—
Transportation and coal handling(5)	216.8		38.6		61.9		49.2		67.1
Other(6)	11.1		2.5		3.8		3.0		1.8
Total	$	2,131.1	$	636.3	$	299.7	$	296.0	$	899.1

(1) At December 31, 2017, debt consists of $700.0 million of 2025 Partnership Notes, $44.6 million of 2019 Company Notes, $12.7 million of Partnership Financing Obligation and $130.0 million of Partnership Revolver. Projected interest costs on variable rate instruments were calculated using market rates at December 31, 2017.

(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 were not executed at December 31, 2017. We estimate these contracts to be approximately $94 million of additional purchase obligations in 2018 and expect these to be finalized in the first quarter of 2018.

(4) Our Jewell cokemaking facility has a five-year coal procurement contract with minimum volume requirements that set pricing annually. Projected purchase obligations were calculated using 2018 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. We had outstanding surety bonds with third parties of approximately $24 million as of December 31, 2017 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 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

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 a goodwill carrying value of $73.5 million as of December 31, 2017. 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 25 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.

To the extent changes in factors or circumstances occur that impact our future cash flow projections, such as a loss of either Murray or Foresight as customers, significant reductions in volume or pricing beyond our existing contract term or lower incremental merchant business, future assessments of goodwill and intangible assets may result in material impairment charges.

Finite-Lived Intangible and Long-Lived Assets

Intangible assets are primarily comprised of customer contracts, customer relationships, and permits. 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.

Finite-lived intangible and 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 finite-lived intangible and 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 finite-lived and long-lived assets may not be readily

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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.

Cash flows at our Indiana Harbor facility were negative during 2017, driven by the oven rebuild project implemented to address coke oven degradation. Based on these results, we performed an impairment test in 2017 and concluded that our projected undiscounted cash flows associated with the facility were approximately 45 percent, or substantially in excess, of the carrying value of our long-lived assets at Indiana Harbor. However, we continue to closely monitor our performance at Indiana Harbor, and if our coke oven rebuild project does not stabilize production or if the project costs are significantly higher than expected, our current conclusion as to recoverability of assets at that location could change.

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.

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

	December 31,
	2017			2016
Discount rate (percent)(1)	3.3		%	3.7		%
Active claims	351			349
Estimated black lung liability (dollars in millions)(2)	$	50.3		$	50.2

(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 0.25 percent decrease in the discount rate would have increased coal workers' black lung expense by $1.2 million in 2017.

(2) The current portion of the black lung liability was $5.4 million and $4.8 million at December 31, 2017 and 2016, 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,
	2017		2016		2015
	(dollars in millions)
Payments	$	7.4	$	7.8	$	3.8
Expense	$	7.5	$	8.1	$	9.8

Recent Accounting Standards

See Note 2 to our consolidated financial statements.

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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 18 in our consolidated financial statements for both the definition of Adjusted EBITDA and reconciliations from GAAP to the non-GAAP measurement for 2017, 2016 and 2015.

Below is a reconciliation of 2018 Adjusted EBITDA guidance from its closest GAAP measures:

	2018
	Low			High
Net Cash Provided by Operating activities	$	150		$	165
Subtract:
Depreciation and amortization expense	137			129
Changes in working capital and other	(22		)	(14		)
Net Income	$	35		$	50
Add:
Depreciation and amortization expense	137			129
Interest expense, net	63			63
Income tax expense	5			13
Adjusted EBITDA	$	240		$	255
Subtract: Adjusted EBITDA attributable to noncontrolling interest(1)	80			84
Adjusted EBITDA attributable to SXC	$	160		$	171

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

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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 do 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 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.

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, 2017 and 2016, the daily average outstanding balance on borrowings with variable interest rates was $184.3 million and $262.1 million, respectively. Assuming a 50 basis point change in LIBOR, interest expense would have been impacted by $0.9 million and $1.2 million in 2017 and 2016, respectively. At December 31, 2017, we had outstanding borrowings with variable interest rates of $130.0 million under the Partnership Revolver.

At December 31, 2017 and 2016, we had cash and cash equivalents of $120.2 million and $134.0 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 $0.6 million for both the years ended December 31, 2017 and 2016.

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 2017 and 2016 would have been approximately $0.5 million.

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Item 8. Financial Statements and Supplementary Data

INDEX TO FINANCIAL STATEMENTS

	Page
Report of Independent Registered Public Accounting Firm	59
Consolidated Statements of Operations for the Years Ended December 31, 2017, 2016 and 2015	61
Consolidated Statements of Comprehensive Income (Loss) for the Years Ended December 31, 2017, 2016 and 2015	62
Consolidated Balance Sheets at December 31, 2017 and 2016	63
Consolidated Statements of Cash Flows for the Years Ended December  31, 2017, 2016 and 2015	64
Consolidated Statements of Equity for the Years Ended December 31, 2017, 2016, and 2015	65
Notes to Consolidated Financial Statements	68
1. General and Basis of Presentation	68
2. Summary of Significant Accounting Policies	69
3. Acquisitions and Dropdown Transactions	72
4. Customer Concentrations	75
5. Income Taxes	76
6. Inventories	79
7. Properties, Plants, and Equipment, Net	79
8. Goodwill and Other Intangible Assets	79
9. Asset Retirement Obligations	81
10. Retirement Benefit Plans	81
11. Accrued Liabilities	85
12. Debt and Financing Obligation	85
13. Commitments and Contingent Liabilities	88
14. Accumulated Other Comprehensive Loss	90
15. Share-Based Compensation	91
16. Earnings Per Share	95
17. Fair Value Measurements	96
18. Business Segment Information	97
19. Selected Quarterly Data (unaudited)	101
20. Supplemental Condensed Combining and Consolidating Financial Information	102

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, 2017 and 2016, the related consolidated statements of operations, comprehensive income (loss), equity, and cash flows for each of the years in the three-year period ended December 31, 2017, 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, 2017, 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, 2017 and 2016, and the results of its operations and its cash flows for each of the years in the three-year period ended December 31, 2017, 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, 2017, 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, 2018

60

SunCoke Energy, Inc.

Consolidated Statements of Operations

	Years Ended December 31,
	2017			2016			2015
	(Dollars and shares in millions, except per share amounts)
Revenues
Sales and other operating revenue	$	1,331.5		$	1,223.3		$	1,362.7
Costs and operating expenses
Cost of products sold and operating expenses	1,020.8			906.5			1,098.4
Selling, general and administrative expenses	79.6			91.3			75.4
Depreciation and amortization expense	128.2			114.2			109.1
Loss on divestiture of business and impairments	—			14.7			—
Total costs and operating expenses	1,228.6			1,126.7			1,282.9
Operating income	102.9			96.6			79.8
Interest expense, net	60.6			53.5			56.2
Loss (gain) on extinguishment of debt, net	20.4			(25.0		)	0.5
Income before income tax (benefit) expense and loss from equity method investment	21.9			68.1			23.1
Income tax (benefit) expense	(81.6		)	8.6			(8.8		)
Loss from equity method investment	—			—			21.6
Net income	103.5			59.5			10.3
Less: Net (loss) income attributable to noncontrolling interests	(18.9		)	45.1			32.3
Net income (loss) attributable to SunCoke Energy, Inc.	$	122.4		$	14.4		$	(22.0	)
Earnings (loss) attributable to SunCoke Energy, Inc. per common share:
Basic	$	1.90		$	0.22		$	(0.34	)
Diluted	$	1.88		$	0.22		$	(0.34	)
Weighted average number of common shares outstanding:
Basic	64.3			64.2			65.0
Diluted	65.2			64.4			65.0

(See Accompanying Notes)

61

SunCoke Energy, Inc.

Consolidated Statements of Comprehensive Income (Loss)

	Years Ended December 31,
	2017			2016			2015
	(Dollars in millions)
Net income	$	103.5		$	59.5		$	10.3
Other comprehensive income (loss):
Reclassifications of actuarial loss amortization, prior service benefit, curtailment gain and settlement loss to earnings (net of related tax expense of zero, zero and $3.4 million, respectively)	0.2			—			5.2
Retirement benefit plans funded status adjustment (net of related tax benefit of $0.3 million, $0.1 million and $0.1 million, respectively)	(0.8		)	(0.2		)	(0.4		)
Currency translation adjustment	(0.5		)	1.0			(3.1		)
Comprehensive income	102.4			60.3			12.0
Less: Comprehensive (loss) income attributable to noncontrolling interests	(18.9		)	45.1			32.3
Comprehensive income (loss) attributable to SunCoke Energy, Inc.	$	121.3		$	15.2		$	(20.3	)

(See Accompanying Notes)

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SunCoke Energy, Inc.

Consolidated Balance Sheets

	December 31,
	2017			2016
	(Dollars in millions,  except par value amounts)
Assets
Cash and cash equivalents	$	120.2		$	134.0
Receivables	68.5			60.7
Receivable from redemption of Brazilian investment	—			20.5
Inventories	111.0			92.5
Income tax receivable	4.8			4.6
Other current assets	6.7			3.8
Total current assets	311.2			316.1
Properties, plants and equipment (net of accumulated depreciation of $733.2 million and $625.9 million at December 31, 2017 and 2016, respectively)	1,501.3			1,542.6
Goodwill	76.9			76.9
Other intangible assets, net	167.9			179.0
Deferred charges and other assets	2.8			6.3
Total assets	$	2,060.1		$	2,120.9
Liabilities and Equity
Accounts payable	$	115.5		$	98.6
Accrued liabilities	53.2			49.8
Deferred revenue	1.7			2.5
Current portion of long-term debt and financing obligation	2.6			4.9
Interest payable	5.4			16.2
Total current liabilities	178.4			172.0
Long-term debt and financing obligation	861.1			849.2
Accrual for black lung benefits	44.9			45.4
Retirement benefit liabilities	28.2			29.0
Deferred income taxes	257.8			352.5
Asset retirement obligations	14.0			13.9
Other deferred credits and liabilities	16.1			19.0
Total liabilities	1,400.5			1,481.0
Equity
Preferred stock, $0.01 par value. Authorized 50,000,000 shares; no issued shares at December 31, 2017 and 2016	—			—
Common stock, $0.01 par value. Authorized 300,000,000 shares; issued 72,006,905 shares and 71,707,304 shares at December 31, 2017 and 2016, respectively	0.7			0.7
Treasury stock, 7,477,657 shares at December 31, 2017 and 2016, respectively	(140.7		)	(140.7		)
Additional paid-in capital	486.2			492.1
Accumulated other comprehensive loss	(20.1		)	(19.0		)
Retained earnings (deficit)	100.1			(22.0		)
Total SunCoke Energy, Inc. stockholders' equity	426.2			311.1
Noncontrolling interests	233.4			328.8
Total equity	659.6			639.9
Total liabilities and equity	$	2,060.1		$	2,120.9

(See Accompanying Notes)

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SunCoke Energy, Inc.

Consolidated Statements of Cash Flows

	Years Ended December 31,
	2017			2016			2015
	(Dollars in millions)
Cash Flows from Operating Activities:
Net income	$	103.5		$	59.5		$	10.3
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	128.2			114.2			109.1
Deferred income tax (benefit) expense	(87.2		)	3.1			(5.6		)
Gain on curtailment and payments in excess of expense for postretirement plan benefits	(1.8		)	(2.6		)	(8.0		)
Settlement loss and payments in excess of expense for pension plan	—			—			13.1
Share-based compensation expense	4.8			6.5			7.2
Loss (gain) on extinguishment of debt, net	20.4			(25.0		)	0.5
Loss on divestiture of business and impairments	—			14.7			—
Loss from equity method investment	—			—			21.6
Changes in working capital pertaining to operating activities (net of the effects of divestiture and acquisition):
Receivables	(7.8		)	3.7			18.8
Inventories	(18.5		)	29.4			23.2
Accounts payable	11.7			(0.8		)	(17.9		)
Accrued liabilities	2.6			6.8			(24.3		)
Deferred revenue	(0.8		)	0.4			(4.4		)
Interest payable	(10.8		)	(2.7		)	(1.0		)
Income taxes	(0.2		)	7.0			(5.6		)
Other	4.4			4.9			4.1
Net cash provided by operating activities	148.5			219.1			141.1
Cash Flows from Investing Activities:
Capital expenditures	(75.6		)	(63.7		)	(75.8		)
Decrease (increase) in restricted cash	0.5			17.7			(17.7		)
Return of Brazilian investment	20.5			20.5			—
Divestiture of coal business	—			(12.8		)	—
Acquisition of businesses, net of cash received	—			—			(191.7		)
Other investing activities	—			2.1			—
Net cash used in investing activities	(54.6		)	(36.2		)	(285.2		)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt	693.7			—			260.8
Repayment of long-term debt	(644.9		)	(66.1		)	(248.1		)
Debt issuance costs	(17.4		)	(0.2		)	(5.7		)
Proceeds from revolving facility	350.0			28.0			292.4
Repayment of revolving facility	(392.0		)	(98.4		)	(50.0		)
Proceeds from financing obligation	—			16.2			—
Repayment of financing obligation	(2.5		)	(1.0		)	—
Cash distributions to noncontrolling interests	(47.0		)	(49.4		)	(43.3		)
Dividends paid	—			—			(28.0		)
Acquisition of additional interest in the Partnership	(48.7		)	—			—
Shares repurchased	—			—			(35.7		)
SunCoke Energy Partners, L.P. units repurchased	—			—			(12.8		)
Other financing activities	1.1			(1.4		)	(1.1		)
Net cash (used in) provided by financing activities	(107.7		)	(172.3		)	128.5
Net (decrease) increase in cash and cash equivalents	(13.8		)	10.6			(15.6		)
Cash and cash equivalents at beginning of year	134.0			123.4			139.0
Cash and cash equivalents at end of year	$	120.2		$	134.0		$	123.4
Supplemental Disclosure of Cash Flow Information
Interest paid	$	69.0		$	58.4		$	58.1
Income taxes paid, net of refunds of $1.0 million, $8.2 million and $1.5 million, respectively	$	5.8		$	(2.3	)	$	2.4

(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, 2014	71,251,529	$	0.7	4,977,115	$	(105.0	)	$	543.6		$	(21.5	)	$	13.9		$	431.7		$	273.7		$	705.4
Net (loss) income	—	—		—	—			—			—			(22.0		)	(22.0		)	32.3			10.3
Reclassifications of prior service cost and actuarial loss amortization to earnings (net of related tax expense of $3.4 million)	—	—		—	—			—			5.2			—			5.2			—			5.2
Retirement benefit plans funded status adjustment (net of related tax benefit of $0.1 million)	—	—		—	—			—			(0.4		)	—			(0.4		)	—			(0.4		)
Currency translation adjustment	—	—		—	—			—			(3.1		)	—			(3.1		)	—			(3.1		)
Adjustments from changes in ownership of SunCoke Energy Partners, L.P.	—	—		—	—			(8.0		)	—			—			(8.0		)	83.0			75.0
Deferred taxes related to basis difference in the Partnership	—	—		—	—			(55.6		)	—			—			(55.6		)	—			(55.6		)
Cash distributions to noncontrolling interests	—	—		—	—			—			—			—			—			(43.3		)	(43.3		)
Dividends	—	—		—	—			—			—			(28.3		)	(28.3		)	—			(28.3		)
Share-based compensation expense	—	—		—	—			7.2			—			—			7.2			—			7.2
Share issuances, net of shares withheld for taxes and other equity activities	237,919	—		—	—			(1.1		)	—			—			(1.1		)	—			(1.1		)
Shares repurchased	—	—		2,500,542	(35.7		)	—			—			—			(35.7		)	—			(35.7		)
Partnership unit repurchases	—	—		—	—			—			—			—			—			(12.8		)	(12.8		)
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

(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, 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)

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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, 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		)	—			—			—
At December 31, 2017	72,006,905	$	0.7	7,477,657	$	(140.7	)	$	486.2		$	(20.1	)	$	100.1		$	426.2		$	233.4		$	659.6

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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,” “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 approximately 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. We also hold a 49 percent investment in a cokemaking joint venture with VISA Steel Limited in India ("VISA SunCoke"), which was fully impaired in 2015, and consequently, beginning in the fourth quarter of 2015, we no longer include our share of VISA SunCoke in our financial results.

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.

We previously controlled coal mining operations in Virginia and West Virginia until April 2016 when the Company completed the disposal of its coal mining business to Revelation Energy, LLC ("Revelation"). 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, 2017, we owned the general partner of the Partnership, which consists of a 2.0 percent ownership interest and incentive distribution rights ("IDRs"), and a 59.9 percent limited partner interest in the Partnership. The remaining 38.1 percent interest in the Partnership was held by public unitholders.

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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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 Note 18.

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. Revenues related to the sale of products are recognized when title passes, generally when products are shipped or delivered in accordance with the terms of the respective sales agreements. Service revenues are recognized when services are provided as defined by customer contracts. Revenues are not recognized until sales prices are fixed or determinable and collectability is reasonably assured. Licensing fees, which include an annual fixed fee and a fee determined on a per ton basis, are recognized when earned in accordance with the contract terms.

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 combined sales and other operating revenues for each of the years ended December 31, 2017, 2016 and 2015.

The Partnership receives payment for shortfall obligations on certain Logistics take-or-pay contracts. The payments in excess of services performed are recorded in deferred revenue on the Consolidated Balance Sheets. Deferred revenue on take-or-pay contracts is generally billed quarterly and recognized as income at the earlier of when service is provided or annually based on the terms of the contract.

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 Operations. 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 capitalized interest of $1.1 million, $5.0 million and $3.7 million in 2017, 2016 and 2015, 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.

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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.

Cash flows at our Indiana Harbor facility were negative during 2017, driven by the oven rebuild project implemented to address coke oven degradation. Based on these results, we performed an impairment test in 2017 and concluded that our projected undiscounted cash flows associated with the facility were approximately 45 percent, or substantially in excess, of the carrying value of our long-lived assets at Indiana Harbor. However, we continue to closely monitor our performance at Indiana Harbor, and if our coke oven rebuild project does not stabilize production or if the project costs are significantly higher than expected, our current conclusion as to recoverability of assets at that location could change.

See Note 17 for discussion of impairments recorded during prior years.

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.

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.

There were no impairments of goodwill or other intangible assets during the periods presented. See Note 8 for further discussion on the Partnership's Logistics goodwill impairment test.

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. With the redemption of the Brazil Investment, the Company no longer receives the $9.5 million annual preferred dividend on its Brazil Investment from ArcelorMittal Brazil, included in sales and other operating revenue on the Consolidated Statement of Operations in 2015. 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 Statement of Operations.

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 for discussion of the impacts of the Tax Cuts and Jobs Act (“Tax Legislation”), which was enacted on December 22, 2017.

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. There were no uncertain tax positions at December 31, 2017, and 2016. See Note 5.

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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 selling, general and administrative expenses on the Consolidated Statement of Operations. 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 Operations and are generally passed through to our customers.

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.

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Currency Translation

The functional currency of the Company’s Brazilian operations and India joint venture are the Brazilian real and Indian rupee, respectively. The Company’s foreign operations translate their 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 and are included in our Consolidated Statements of Operations. The Company did not incur any material foreign currency transaction gains or losses during the periods presented.

Recently Issued Pronouncements

In May 2014, Financial Accounting Standards Board ("FASB") 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. Subsequently, the FASB has issued various ASUs to provide further clarification around certain aspects of ASC 606. This standard will be effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period, and early adoption was permitted on a limited basis. We have substantially completed our analysis of the new standard and do not expect a material change in our revenue recognition model on an annual basis. Deferred revenue at CMT may be recognized on a more accelerated basis during quarterly periods within the year based on facts and circumstances considered at each quarter under the new guidance. The Company will adopt this standard on January 1, 2018 using the modified retrospective method.

In February 2016, the FASB issued ASU 2016-02, "Leases (Topic 842)." ASU 2016-02 requires lessees to recognize assets and liabilities on the balance sheet for the rights and obligations created by all leases with terms of more than 12 months. It 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 is in the process of analyzing the impacts to our business, including the development of new accounting processes to account for our leases and support the required disclosures. While we are still evaluating the impact of adopting this standard, we expect that upon adoption the right-of-use assets and lease liabilities, such as various plant equipment rentals and the lease of our corporate office space, will increase the reported assets and liabilities on our Consolidated Balance Sheets. We are currently evaluating technology tools to assist with the accounting and reporting requirements of this standard. The Company expects to adopt this standard on January 1, 2019 and is currently evaluating our transition method options.

Labor Concentrations

As of December 31, 2017, we have approximately 909 employees in the U.S. Approximately 39 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 2018, at which time the collective bargaining process will resume. We do not anticipate any work stoppages during the extended period of the agreement. In 2017, we reached a new three-year agreement for our Granite City location, which will expire on August 31, 2020.

As of December 31, 2017, we have approximately 270 employees at the cokemaking facility in Vitória, Brazil, all of whom are represented by a union under a labor agreement. In 2017, we reached a new one-year labor agreement at our Vitoria, Brazil facility which will expire on October 31, 2018. We will negotiate the renewal of this agreement in 2018 and do not anticipate any work stoppages.

3. Acquisitions and Dropdown Transactions

Acquisition of Partnership Common Units

In April 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 $50.0 million. In July 2017, the Company's Board of Directors authorized the Company to purchase an incremental $50.0 millionof Partnership common units in the open market. During 2017, the Company purchased 2,853,032 of outstanding Partnership common units in the open market for total cash payments of $48.7 million, which increased our limited partner interest in the Partnership from53.9 percent to 59.9 percent at December 31, 2017. This resulted in a decrease in noncontrolling interest of$29.6 million

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during 2017 on the Consolidated Balance Sheets related to the Partnership's net book value acquired by the Company. The Company decreased its additional paid-in capital balance by $12.0 million on the Consolidated Balance Sheets for the consideration paid in excess of the net book value of the noncontrolling interest acquired, net of a deferred tax adjustment of $7.1 million during 2017.

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

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

Subsequent to December 31, 2017, the Company purchased an additional 132,188 of outstanding Partnership common units in the open market for total cash payments of $2.3 million, leaving a remaining common unit purchase program balance of $49.0 million as of February 15, 2018.

Convent Marine Terminal Acquisition

On August 12, 2015, the Partnership completed the acquisition of a 100 percent ownership interest in Raven Energy LLC, which owns Convent Marine Terminal ("CMT"), for a total transaction value of $403.1 million. The transaction value included $191.7 million in cash paid by the Partnership, 4.8 million common units issued with an aggregate value of $75.0 million to The Cline Group, $114.9 million of debt assumed and $21.5 million of cash withheld to fund capital expenditures.

The results of CMT have been included in the consolidated financial statements since the date of acquisition and are reported in the Logistics segment. CMT contributed revenues of $71.1 million, $62.7 million and $28.6 million, as well as operating income of $42.3 million, $46.5 million and $18.4 million during 2017, 2016 and 2015, respectively.

 The following combined and consolidated results of operations were prepared using historical financial information of CMT and assumes that the acquisition of CMT occurred on January 1, 2015:

	Years Ended December 31,
	2017		2016		2015
	(Audited)				(Unaudited pro forma)
	(Dollars in millions)
Total revenues	$	1,331.5	$	1,223.3	$	1,395.4
Net income	$	103.5	$	59.5	$	9.7
Net income (loss) attributable to SunCoke Energy, Inc.	$	122.4	$	14.4	$	(22.3	)
Earnings (loss) attributable to SunCoke Energy, Inc. per common share:
Basic	$	1.90	$	0.22	$	(0.34	)
Diluted	$	1.88	$	0.22	$	(0.34	)

The unaudited pro forma combined results of operations reflect historical results adjusted for interest expense, depreciation adjustments based on the fair value of acquired property, plant and equipment, amortization of acquired identifiable intangible assets, and income tax expense. The pro forma combined results do not include acquisition costs or new contracts. The unaudited pro forma combined and consolidated financial statements are presented for informational purposes only and do not necessarily reflect future results given the timing of new customer contracts, revenue recognition related to take-or-pay shortfalls, and other effects of integration, nor do they purport to be indicative of the results of operations that actually would have resulted had the acquisition of CMT occurred on January 1, 2015 or future results.

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Granite City Dropdowns

On January 13, 2015, the Company contributed a 75 percent interest in its Granite City cokemaking facility to the Partnership for a total transaction value of $244.4 million (the "Granite City Dropdown"). The transaction value included $148.3 million of debt and other liabilities assumed by the Partnership, $50.1 million of Partnership common units issued, $1.0 million of general partner interest issued to the Partnership's general partner and $45.0 million of cash withheld to pre-fund our obligation to the Partnership for the anticipated costs of an environmental remediation project at Granite City. Subsequent to the Granite City Dropdown, we continued to own the general partner of the Partnership, which owns a 2 percent general partners interest and IDRs, and a 56.1 percent limited partner interest in the Partnership. The remaining 41.9 percent limited partner interest in the Partnership was held by public unitholders and was reflected as a noncontrolling interest in the consolidated financial statements.

On August 12, 2015, the Company contributed an additional 23 percent interest in Granite City to the Partnership for a total transaction value of $65.2 million (the "Granite City Supplemental Dropdown"). The transaction value included $46.9 million of debt and other liabilities assumed by the Partnership, $17.9 million of Partnership common units issued and $0.4 million of general partner interest issued to the Partnership's general partner. Subsequent to the Granite City Supplemental Dropdown and the units issued in connection with the acquisition of CMT, we continue to own the general partner of the Partnership, which owns a 2 percent general partner interest and IDRs, and owned a 53.4 percent limited partner interest in the Partnership. The remaining 44.6 percent limited partner interest in the Partnership was held by public unitholders and was reflected as a noncontrolling interest in the consolidated financial statements.

We accounted for the Granite City Dropdown and Granite City Supplemental Dropdown as equity transactions, which resulted in an increase in noncontrolling interest and a decrease in SunCoke Energy's equity of $6.5 million and $1.5 million, respectively, representing the Partnership's common public unitholders' share of the book value of ownership interest received of $114.7 million, net of their share of the transaction value of $106.7 million.

The table below summarizes the effects of the changes in the Company’s ownership interest in Granite City on SunCoke’s equity:

	Year Ended December 31, 2015
	(Dollars in millions)
Net loss attributable to SunCoke Energy, Inc.	$	(22.0	)
Decrease in SunCoke Energy, Inc. equity for the contribution of 75 percent interest in Granite City	(6.5		)
Decrease in SunCoke Energy, Inc. for the contribution of an additional 23 percent interest in Granite City	(1.5		)
Change from net loss attributable to SunCoke Energy, Inc. and dropdown transactions	$	(30.0	)

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4. Customer Concentrations

In 2017, 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 a Brazilian subsidiary of ArcelorMittal S.A., where we operate a cokemaking facility, ArcelorMittal Brasil S.A. ("ArcelorMittal Brazil”).

The table below shows sales to the Company's significant customers for the years ended December 31, 2017, 2016 and 2015:

	Years ended December 31,
	2017				2016				2015
	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)	$	678.2	50.9	%	$	596.6	48.8	%	$	671.8	49.3	%
AK Steel(2)	$	331.3	24.9	%	$	350.0	28.6	%	$	395.4	29.0	%
U.S. Steel(3)	$	214.1	16.1	%	$	185.3	15.1	%	$	212.7	15.6	%

(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.

Since 2015, AK Steel has kept its Ashland Kentucky Works facility idled and U.S. Steel has kept portions of its Granite City Works facility idled. These temporary idlings do not change any obligations that AK Steel and/or U.S. Steel have under their long-term, take-or-pay contracts with us.

The Company generally does not require any collateral with respect to its receivables. At both December 31, 2017 and 2016, 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 three significant customers as of December 31, 2017 and 2016:

	December 31,
	2017		2016
	(Dollars in millions)
AM USA and ArcelorMittal Brazil(1)	$	25.7	$	47.7
AK Steel	$	13.2	$	10.7
U.S. Steel	$	5.6	$	5.7

(1) The 2016 receivables due include the $20.5 million receivable recorded as redemption of Brazil investment on the Consolidated Balance Sheets and was collected in 2017.

Our Logistics segment provides coal handling and storage services to Murray American Coal, Inc. ("Murray") and Foresight Energy LLC ("Foresight"), who are the two primary customers in the Logistics segment and related parties of The Cline Group, a beneficial owner of the Partnership. Sales to Foresight and Murray accounted for $57.8 million, or 4.3 percent, and $53.5 million, or 4.4 percent and $22.0 million, or 1.6 percent of the Company's sales and other operating revenue and were recorded in the Logistics segment for the years ended December 31, 2017, 2016 and 2015, respectively, representing 49.4 percent, 49.6 percent and 27.1 percent of Logistics revenue, including intersegment sales, in 2017, 2016 and 2015, respectively. Receivables from Murray and Foresight were $9.7 million and $8.0 million and were recorded in receivables on the Consolidated Balance Sheets at December 31, 2017 and 2016, respectively.

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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,
	2017		2016		2015
	(Dollars in millions)
Domestic	$	4.3	$	52.5	$	8.6
Foreign	17.6		15.6		14.5
Total	$	21.9	$	68.1	$	23.1

The components of income tax (benefit) expense are as follows:

	Years Ended December 31,
	2017			2016			2015
	(Dollars in millions)
Income taxes currently payable (receivable):
U.S. federal	$	1.7		$	2.7		$	(3.1	)
State	(1.0		)	(2.2		)	(3.3		)
Foreign	4.9			5.0			3.2
Total taxes currently payable (receivable)	5.6			5.5			(3.2		)
Deferred tax (benefit) expense:
U.S. federal	(99.7		)	(1.5		)	(12.7		)
State	12.5			4.6			7.1
Total deferred tax (benefit) expense	(87.2		)	3.1			(5.6		)
Total	$	(81.6	)	$	8.6		$	(8.8	)

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

	Years Ended December 31,
	2017					2016					2015
	(Dollars in millions)
Income tax expense at 35 percent U.S. statutory rate	$	7.7		35.0	%	$	23.8		35.0	%	$	8.0		35.0	%
Increase (reduction) in income taxes resulting from:
Impact of Final Regulations(1)	64.2			293.2	%	—			—	%	—			—	%
Impact of Tax Legislation(2)	(154.7		)	(706.4	)%	—			—	%	—			—	%
Income attributable to noncontrolling interests in partnerships(3)	(5.4		)	(24.7	)%	(15.6		)	(23.0	)%	(11.2		)	(48.3	)%
State and other income taxes, net of federal income tax effects	2.0			9.1	%	1.1			1.7	%	1.8			7.7	%
Change in valuation allowance(4)(5)	3.9			17.8	%	0.4			0.6	%	(8.8		)	(38.0	)%
Investment in subsidiary(5)	—			—	%	—			—	%	1.0			4.4	%
Other	0.7			3.2	%	(1.1		)	(1.6	)%	0.4			1.2	%
Income tax (benefit) expense at effective tax rate	$	(81.6	)	(372.8	)%	$	8.6		12.7	%	$	(8.8	)	(38.0	)%

(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

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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. 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 revises 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 provides 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 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 impact resulting from the remeasurement of U.S. deferred income tax liabilities and assets at the lower enacted corporate tax rates. Based on information currently available, the Company has recorded a provisional income tax expense of $14.3 million for a valuation allowance against $19.0 million of foreign tax credit carryforwards that the Company believes will not be realized prior to their expiration as a result of the Tax Legislation. The final impact of the Tax Legislation may differ from the estimate recorded this period, possibly materially, due to changes in interpretations and assumptions the Company has made, guidance that may be issued and actions the Company may take as a result of the Tax Legislation.

(3) Excludes the 2017 impact of the Final Regulations on qualifying income discussed above. No income tax expense is reflected in the Consolidated Statements of Operations 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.

(5) On December 22, 2014, SunCoke executed a definitive agreement to sell 100 percent of its interest in the entities that made up the Harold Keene Coal Companies. This required SunCoke to record a deferred tax asset of $11.9 million related to the outside basis difference on the Harold Keene investment. This deferred tax asset was offset by a $9.8 million valuation allowance. SunCoke canceled the definitive agreement during the third quarter of 2015. Due to the cancellation of the agreement, the deferred tax asset and the valuation allowance recorded during 2014 were reversed during 2015. The reversal of the deferred tax asset during 2015 was largely offset by a related current income tax deduction due to the determination of insolvency of the subsidiary, resulting in the net income tax benefit of $1.0 million in the investment in subsidiary line. The actual sale of the coal business, which was completed in the second quarter of 2016, had no material impact on the effective tax rate.

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

	December 31,
	2017			2016
	(Dollars in millions)
Deferred tax assets:
Retirement benefit liabilities	$	7.1		$	12.2
Black lung benefit liabilities	11.6			18.9
Share-based compensation	6.1			8.6
Federal tax credit carryforward(1)	23.2			23.2
Foreign tax credit carryforward(2)	19.0			14.0
Federal net operating loss	2.5			17.2
State tax credit carryforward, net of federal income tax effects(3)	4.0			5.5
State net operating loss carryforward, net of federal income tax effects(4)	13.9			8.4
Other liabilities not yet deductible	4.3			7.8
Total deferred tax assets	91.7			115.8
Less valuation allowance(5)	(26.2		)	(5.9		)
Deferred tax asset, net	65.5			109.9
Deferred tax liabilities:
Properties, plants and equipment(6)	(114.9		)	(0.3		)
Investment in partnerships(6)	(208.4		)	(462.1		)
Total deferred tax liabilities	(323.3		)	(462.4		)
Net deferred tax liability	$	(257.8	)	$	(352.5	)

(1) Federal tax credit carryforward expires in 2032 through 2033.

(2) Foreign tax credit carryforward expires in 2022 through 2027.

(3) State tax credit carryforward, net of federal income tax effects expires in 2017 through 2022.

(4) State net operating loss carryforward, net of federal income tax effects expires in 2017 through 2035.

(5) Primarily related to state tax credit carryforward and the $14.3 million allowance against the foreign tax credit carryforward as a result of the Tax Legislation in 2017.

(6) As a result of the Final Regulations discussed above, deferred tax liabilities associated with properties, plants and equipment increased and investment in partnerships decreased.

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, 2014 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, 2017 and 2016, and there were no interest or penalties recognized during the years ended December 31, 2017, 2016 and 2015. 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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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,
	2017		2016
	(Dollars in millions)
Coal	$	61.4	$	49.4
Coke	12.3		7.7
Materials, supplies and other	37.3		35.4
Total inventories	$	111.0	$	92.5

7. Properties, Plants, and Equipment, Net

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

	December  31,
	2017			2016
	(Dollars in millions)
Coke and energy plant, machinery and equipment(1)	$	1,812.0		$	1,767.1
Logistics plant, machinery and equipment	216.2			214.4
Land and land improvements	118.7			118.7
Construction-in-progress	51.9			33.4
Other	35.7			34.9
Gross investment, at cost	2,234.5			2,168.5
Less: Accumulated depreciation(2)	(733.2		)	(625.9		)
Total properties, plants and equipment, net	$	1,501.3		$	1,542.6

(1) Includes assets, consisting mainly of coke and energy plant, machinery and equipment, with a gross investment totaling $1,337.3 million and $1,281.5 million and accumulated depreciation of $475.8 million and $410.4 million at December 31, 2017 and December 31, 2016, respectively, which are subject to long-term contracts to sell coke and are deemed to contain operating leases.

8. Goodwill and Other Intangible Assets

Goodwill allocated to SunCoke's reportable segments as of December 31, 2017 and 2016 and changes in the carrying amount of goodwill during the fiscal year ended December 31, 2016 are shown below. There were no changes in the carrying amount of goodwill during the fiscal year ended December 31, 2017:

	Domestic Coke		Logistics		Total
	(Dollars in millions)
Net balance at December 31, 2015	$	3.4	$	67.7	$	71.1
Adjustments(1)	—		5.8		5.8
Net balance at December 31, 2016 and 2017	$	3.4	$	73.5	$	76.9

(1) During 2016, the Partnership recorded an adjustment to correct an error in the acquisition date fair value of the contingent consideration liability, which increased the contingent consideration liability and goodwill balance by $6.4 million. See Note 17. Additionally, a working capital adjustment to the acquisition date fair value of the acquired net assets decreased the amount of the purchase price allocated to goodwill by $0.6 million.

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The Company performed its annual goodwill impairment test as of October 1, 2017, 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 25 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. To the extent changes in factors or circumstances occur that impact our future cash flow projections, such as a loss of either Murray or Foresight as customers, significant reductions in volume or pricing beyond our existing contract term or lower incremental merchant business, future assessments of goodwill and intangible assets may result in material impairment charges.

The following table summarizes the components of gross and net intangible asset balances as of December 31, 2017 and December 31, 2016:

		December 31, 2017						December 31, 2016
	Weighted - Average Remaining Amortization Years	Gross Carrying Amount		Accumulated Amortization		Net		Gross Carrying Amount		Accumulated Amortization		Net
		(Dollars in millions)
Customer contracts	5	$	31.7	$	13.8	$	17.9	$	31.7	$	9.9	$	21.8
Customer relationships	14	28.7		5.7		23.0		28.7		3.8		24.9
Permits	25	139.0		12.2		126.8		139.0		7.1		131.9
Trade name	1	1.2		1.0		0.2		1.2		0.8		0.4
Total		$	200.6	$	32.7	$	167.9	$	200.6	$	21.6	$	179.0

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 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 3.4 years.

Total amortization expense for intangible assets subject to amortization was $11.1 million, $11.2 million and $5.1 million for the years ended December 31, 2017, 2016 and 2015, respectively. Based on the carrying value of finite-lived intangible assets as of December 31, 2017, we estimate amortization expense for each of the next five years as follows:

	(Dollars in millions)
2018	$	11.0
2019	10.9
2020	10.7
2021	10.3
2022	10.3
Thereafter	114.7
Total	$	167.9

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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, 2015	$	22.2
Liabilities settled	(0.7		)
Accretion expense(1)	1.1
Disposal of coal mining liabilities(2)	(9.4		)
Revisions in estimated cash flows	0.7
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

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

(2) In 2016, the Company completed the disposal of its coal mining business to Revelation who assumed a substantial portion of our mining reclamation obligations.

10. Retirement Benefits Plans

Defined Benefit Pension Plan and Postretirement Health Care and Life Insurance Plans

The Company had a noncontributory defined benefit pension plan (“defined benefit plan”), which provided retirement benefits for certain of its employees. Effective January 1, 2011, pension benefits under the Company’s defined benefit plan were frozen for all participants in this plan. Effective May 30, 2014, Dominion Coal Corporation, a wholly-owned subsidiary of the Company, terminated its defined benefit plan, a plan that was previously offered generally to all full-time employees of Dominion Coal Corporation. Subsequently, the Company obtained IRS approval for the plan termination and executed an agreement with a high-quality insurance company to annuitize the pension plan using plan assets. As a result of the termination of the Dominion Coal defined benefit plan, each participant became fully vested in his or her benefits thereunder without regard to age and years of service.

As a result of the pension termination, unrecognized losses, which previously were recorded in accumulated other comprehensive loss on the Consolidated Balance Sheets, were recognized as expense. The net settlement loss of $12.6 million was recorded in cost of products sold and operating expenses on the Consolidated Statements of Operations during 2015. At December 31, 2017 and 2016, there are no remaining benefit obligations or plan assets related to the defined benefit pension plan.

The Company also 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. Employer costs for all those still eligible for such benefits were capped. The termination of coal mining employees triggered a curtailment gain of $4.1 million in 2015, respectively, which represented accelerated amortization of prior service credits previously recorded in accumulated other comprehensive income.

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Defined benefit plan expense consisted of the following components:

	Years Ended December 31,
	2017		2016		2015
	(Dollars in millions)
Interest cost on benefit obligations	$	—	$	—	$	0.7
Expected return on plan assets	—		—		(0.7		)
Settlement loss	—		—		12.6
Amortization of:
Actuarial losses	—		—		0.5
Total expense	$	—	$	—	$	13.1

Postretirement benefit plans expense (benefit) consisted of the following components:

	Years Ended December 31,
	2017			2016			2015
	(Dollars in millions)
Interest cost on benefit obligations	$	1.1		$	1.3		$	1.3
Amortization of:
Actuarial losses	0.9			0.7			0.8
Prior service benefit	(0.7		)	(0.7		)	(1.2		)
Curtailment gain	—			—			(4.1		)
Total expense (benefit)	$	1.3		$	1.3		$	(3.2	)

Amortization of actuarial losses and prior service benefit for 2018 is estimated to be $0.6 million and $0.7 million, respectively, for the postretirement benefit plans.

Postretirement benefit plans expense (benefit) 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 (benefit):

	Postretirement Benefit Plans
	2017		2016		2015
Discount Rate	3.65	%	3.80	%	3.45	%

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The following amounts were recognized as components of other comprehensive income (loss) before related tax impacts for the years ended December 31, 2017, 2016 and 2015:

	Years Ended December 31,
	Defined Benefit Plan						Postretirement Benefit Plans
	2017		2016		2015		2017			2016			2015
	(Dollars in millions)
Reclassifications to earnings of:
Actuarial loss amortization	$	—	$	—	$	0.5	$	0.9		$	0.7		$	0.8
Prior service benefit amortization	—		—		—		(0.7		)	(0.7		)	(1.2		)
Curtailment gain	—		—		—		—			—			(4.1		)
Settlement loss	—		—		12.6		—			—			—
Retirement benefit plan funded status    adjustments:
Actuarial gains (losses)	—		—		0.9		(1.1		)	(1.8		)	(1.4		)
Prior service (cost) benefit(1)	—		—		—		—			1.5			—
	$	—	$	—	$	14.0	$	(0.9	)	$	(0.3	)	$	(5.9	)

(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 will provide a subsidy to these participants of $3,600 per participant per 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 during 2017 and 2016:

	Postretirement Benefit Plans
	2017			2016
	(Dollars in millions)
Benefit obligation at beginning of year	$	32.3		$	34.8
Interest cost	1.1			1.3
Actuarial losses	1.1			1.8
Plan amendments(1)	—			(1.5		)
Benefits paid	(3.2		)	(4.1		)
Benefit obligation at end of year(2)	$	31.3		$	32.3

(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 will provide a subsidy to these participants of $3,600 per participant per year. The plan change resulted in a decrease in the benefit obligation of $1.5 million during 2016.

(2) Represents retirement benefit liabilities, including current portion, on the Consolidated Balance Sheets. The current portion of retirement liabilities, which totaled $3.1 million and $3.3 million at December 31, 2017 and 2016, 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 (loss) at December 31, 2017 and 2016:

	Postretirement Benefit Plans
	2017			2016
	(Dollars in millions)
Cumulative amounts not yet recognized in net income:
Actuarial losses	$	11.8		$	11.6
Prior service benefits	(3.4		)	(4.1		)
Accumulated other comprehensive loss (before related tax benefit)	$	8.4		$	7.5

The expected benefit payments through 2026 for the postretirement benefit plan are as follows:

	Postretirement Benefit Plans
	(Dollars in millions)
Year ending December 31:
2018	$	3.1
2019	3.0
2020	2.9
2021	2.8
2022	2.6
2023 through 2026	10.1

The measurement date for the Company’s postretirement benefit plans is December 31. The following discount rates were used to determine the benefit obligation at December 31, 2017 and 2016, respectively (in percentages):

	Postretirement Benefit Plans
	2017		2016
Discount rate	3.35	%	3.65	%

The health care cost trend assumption used at December 31, 2017, to compute the accumulated postretirement benefit obligation for the postretirement benefit plans was 6.50 percent (6.50 percent at December 31, 2016), which is assumed to decline gradually to 5.00 percent in 2025 and to remain at that level thereafter. A one-percentage point change each year in assumed health care cost trend rates would have an impact of less than $0.1 million on the total of service and interest cost components of postretirement benefits expense and the accumulated postretirement benefit obligation as of December 31, 2017 and 2016.

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 $6.4 million, $5.6 million and $6.5 million for the years ended December 31, 2017, 2016 and 2015, respectively.

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11. Accrued Liabilities

Accrued liabilities consist of following:

	December 31,
	2017		2016
	(Dollars in millions)
Accrued benefits	$	21.3	$	21.4
Current portion of postretirement benefit obligation	3.1		3.3
Other taxes payable	10.5		10.4
Current portion of black lung liability	5.4		4.8
Accrued legal	5.6		4.4
Other	7.3		5.5
Total accrued liabilities	$	53.2	$	49.8

12. Debt and Financing Obligation

Total debt consisted of the following:

	December 31,
	2017			2016
	(Dollars in millions)
7.500 percent senior notes, due 2025 ("2025 Partnership Notes")	$	700.0		$	—
7.375 percent senior notes, due 2020 (''2020 Partnership Notes'')	—			463.0
7.625 percent senior notes, due 2019 ("2019 Notes")	44.6			44.6
Partnership's term loan, due 2019 ("Partnership Term Loan")	—			50.0
SunCoke's revolving credit facility, due 2022 ("Revolving Facility")	—			—
Partnership's revolving credit facility, due 2022 and 2019, respectively ("Partnership Revolver")	130.0			172.0
Partnership's promissory note payable, due 2021 ("Promissory Note")	—			113.2
5.82 percent financing obligation, due 2021 ("Partnership Financing Obligation")	12.7			15.2
Total borrowings	$	887.3		$	858.0
(Discount) premium	(5.9		)	7.5
Debt issuance costs	(17.7		)	(11.4		)
Total debt and financing obligation	$	863.7		$	854.1
Less: current portion of long-term debt and financing obligation	2.6			4.9
Total long-term debt and financing obligation	$	861.1		$	849.2

Issuance of 2025 Partnership Notes

The Partnership issued $630.0 million aggregate principal amount of senior notes in May 2017 and an additional $70.0 million aggregate principal amount of senior notes in December 2017 with an interest rate of 7.5 percent due in May 2025. The Partnership received proceeds of $693.7 million, net of a net discount of $6.3 million during 2017. The Partnership incurred debt issuance costs related to this transaction of $12.9 million. The 2025 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 2025 Partnership Notes is payable semi-annually in cash in arrears on June 15 and December 15 of each year, which commenced on December 15, 2017.

The Partnership may redeem some or all of the 2025 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 2025 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 2025 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.

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The Partnership is obligated to offer to purchase all or a portion of the 2025 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 2025 Partnership Notes contains 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.

Purchase, Redemption and Repayment of Partnership Debt

During 2017, the Partnership used the proceeds from the issuance of the 2025 Partnership Notes to purchase and redeem all of its 2020 Partnership Notes, including principal of $463.0 million and a premium of $18.7 million, repay the $50.0 million outstanding on the Partnership Term Loan, repay the $112.6 million outstanding on the Partnership's Promissory Note and reduce the Partnership Revolver outstanding balance by $42.0 million. As a result of the debt extinguishment, the Partnership recorded a loss on extinguishment of debt on the Consolidated Statement of Operations of $19.2 million, which included the premium paid and a write-off of unamortized debt issuance costs of $7.1 million partly offset by a write-off of unamortized premiums of $6.6 million.

Partnership Financing Obligation

In 2016, the Partnership entered into a sale-leaseback arrangement of certain coke and logistics equipment. The leaseback agreement has an initial lease period of 60 months, with an effective interest rate of 5.82 percent 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.

Redemption of 2019 Notes

The 2019 Notes are the Company’s senior unsecured obligations and are guaranteed on a senior unsecured basis by each of the Company’s existing and future subsidiaries that guarantees the Company’s credit facilities. The Company may redeem some or all of their notes at specified redemption prices. If the Company sells certain of its assets or experiences specific kinds of changes in control, subject to certain exceptions, the Company must offer to purchase their 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. The Company funded the redemption with a term loan in the aggregate principal amount of $45.0 million maturing on May 24, 2022 under the Company’s existing Amended and Restated Credit Agreement. 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.

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.

In February 2017, the Company extended the maturity of its Revolving Facility to December 2018 and reduced its capacity by $25.0 million to $125.0 million, resulting in additional debt issuance costs of $0.6 million. Additionally, the Company recorded a loss on extinguishment of debt on the Consolidated Statement of Operations of $0.1 million, representing a write-off of unamortized debt issuance costs, during 2017.

In May 2017, the Company amended and restated its Revolving Facility, which extended its maturity date from December 2018 to May 2022 and reduced its capacity to $100.0 million, resulting in debt issuance costs of $1.1 million. Additionally, the Company recorded a loss on extinguishment of debt on the Consolidated Statement of Operations of $0.3 million, representing a write-off of unamortized debt issuance costs, during 2017. As of December 31, 2017, the Revolving Facility had letters of credit outstanding of $26.5 million and no outstanding balance, leaving $73.5 million available. Commitment fees are based on the unused portion of the Revolving Facility at a rate of 0.4 percent.

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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 and 2.3 percent during 2016 and 2015, respectively. There were no borrowings during 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.

In May 2017, the Partnership amended and restated the Partnership Revolver, which increased the Partnership's capacity from $250.0 million to $285.0 million and extended the maturity from May 2019 to May 2022. In connection with the amendments to the Partnership Revolver, the Partnership incurred debt issuance costs of $3.0 million and recorded a loss on extinguishment of debt on the Consolidated Statement of Operations of $0.8 million, representing a write-off of unamortized debt issuance costs, during 2017.

As of December 31, 2017, the Partnership had $1.9 million of letters of credit outstanding and an outstanding balance of $130.0 million, leaving $153.1 million available. Commitment fees are based on the unused portion of the Partnership Revolver at a rate of 0.4 percent.

The Partnership Revolver borrowings bear interest at a variable rate of LIBOR plus 250 basis points or 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 3.8 percent, 3.3 percent and 2.9 percent during 2017, 2016 and 2015, 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, 2017, 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.

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Maturities

As of December 31, 2017, the combined aggregate amount of maturities for long-term borrowings for each of the next five years is as follows:

	(Dollars in Millions)(1)
2018	$	2.6
2019(2)	47.4
2020	7.3
2021	—
2022	130.0
2023-Thereafter	700.0
Total	$	887.3

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

(2) As previously disclosed, the 2019 Notes were repaid in January 2018 with the proceeds of a new term loan due in May 2022.

13. Commitments and Contingent Liabilities

Lease obligations

The Company, as lessee, has noncancelable operating leases for land, office space, equipment and railcars. Total rental expense was $7.3 million, $8.7 million and $8.5 million in 2017, 2016 and 2015, respectively. 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:
2018	$	3.1
2019	2.4
2020	1.4
2021	0.9
2022	0.3
2023-Thereafter	1.1
Total	$	9.2

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 in existence prior to the Granite City Dropdown at the Partnership's Granite City facility.  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 U.S. Environmental Protection Agency ("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. An amendment was lodged in federal court in February 2018 and is

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undergoing review. The amendment 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.

We anticipate spending approximately $145 million related to these projects, of which we have spent approximately $111 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 quarter of 2019. A portion of the proceeds from the Partnership's initial public offering and subsequent dropdowns are expected to be used to fund $119 million of these environmental remediation projects. Pursuant to the omnibus agreement, the Company will reimburse the Partnership approximately $20 million for the estimated additional spending beyond what has previously been funded.

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. have met regularly since those discussions commenced, and continued to meet regularly in 2017 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 of the NOVs/FOVs. A Consent Decree among the parties was lodged in federal court in January 2018 and is undergoing review. The settlement includes a $2.5 million civil penalty payment, which is included in accrued liabilities on the Consolidated Balance Sheets as of December 31, 2017. 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

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 estimated black lung liabilities:

	December 31,
	2017			2016
Discount rate (percent)(1)	3.3		%	3.7		%
Active claims	351			349
Estimated black lung liability (dollars in millions)(2)	$	50.3		$	50.2

(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 0.25 percent decrease in the discount rate would have increased coal workers' black lung expense by $1.2 million in 2017.

(2) The current portion of the black lung liability was $5.4 million and $4.8 million at December 31, 2017 and 2016, 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,
	2017		2016		2015
	(dollars in millions)
Payments	$	7.4	$	7.8	$	3.8
Expense	$	7.5	$	8.1	$	9.8

14. Accumulated Other Comprehensive Loss

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

	Benefit Plans			Currency Translation Adjustments			Total
	(Dollars in millions)
At December 31, 2015	$	(4.6	)	$	(15.2	)	$	(19.8	)
Other comprehensive loss before reclassifications	—			1.0			1.0
Retirement benefit plans funded status adjustment	(0.2		)	—			(0.2		)
Net current period other comprehensive loss	(0.2		)	1.0			0.8
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		)
At December 31, 2017	$	(5.4	)	$	(14.7	)	$	(20.1	)

(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 retained earnings to accumulated other comprehensive loss.

The tax benefit associated with the Company's benefit plans as of December 31, 2017 and 2016 was $3 million and $2.7 million, respectively.

The Company's accumulated other comprehensive loss balance includes $9.0 million from currency translation adjustments of the investment in VISA SunCoke, which remains until the cumulative investment balance is no longer negative or the investment is disposed. The balance would be reclassified to earnings if the investment is disposed of by the Company.

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

	December 31,
	2017			2016			2015
	(Dollars in millions)
Amortization of benefit plans to net income:
Actuarial loss	$	(0.9	)	$	(0.7	)	$	(1.3	)
Prior service benefit	0.7			0.7			1.2
Curtailment gain	—			—			4.1
Settlement loss	—			—			(12.6		)
Total before taxes	(0.2		)	—			(8.6		)
Income tax cost (benefit)	—			—			3.4
Total, net of tax	$	(0.2	)	$	—		$	(5.2	)

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 6,000,000 shares 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. 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, 2017, 2016 and 2015, 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:
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
2015 grant	593,976	$	16.33	$	4.87
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

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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, 2017, 2016 and 2015 was based on using the following weighted-average assumptions:

	Years Ended December 31,
	2017		2016		2015
Risk free interest rate	2.11	%	1.25	%	1.66	%
Expected term	6 years		5 years		5 years
Volatility	53	%	52	%	36	%
Dividend yield	—	%	—	%	1.64	%

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, 2017 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, 2016	2,923,668		$	15.69	6.3	$	2.2
Granted	237,791		$	10.14
Exercised	(10,252	)	$	9.66
Forfeited	(5,092	)	$	20.70
Outstanding at December 31, 2017	3,146,115		$	15.31	5.6	$	2.8
Exercisable at December 31, 2017	2,530,129		$	16.64	4.8	$	0.7
Expected to vest at December 31, 2017	615,986		$	9.87	8.4	$	2.1

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 2017 and 2015 was $0.3 million and $0.1 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, 2017 and 2015:

	Shares	Weighted Average Grant-Date Fair Value		Grant Date Fair Value
				(Dollars in millions)
2017 grants	22,628	$	9.85	$	0.2
2015 grants	297,514	$	14.51	$	4.3

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

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The following table summarizes information with respect to RSUs outstanding as of December 31, 2017 and RSU activity during the fiscal year then ended:

	Number of RSUs		Weighted Average Grant- Date Fair Value
Nonvested at December 31, 2016	224,940		$	16.18
Granted	22,628		$	9.85
Vested	(135,522	)	$	17.22
Forfeited	(5,649	)	$	11.47
Nonvested at December 31, 2017	106,397		$	13.53

Total grant date fair value of RSUs vested was $2.3 million, $3.7 million and $4.6 million during 2017, 2016 and 2015, 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 year ended December 31, 2017:

	Shares	Fair Value per Share		Grant Date Fair Value
				(Dollars in millions)
2017 grant	385,758	$	11.61	$	4.5

The 2017 PSU grant was 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 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. In February 2017, the Company granted 237,610 PSUs that will vest on December 31, 2019. In December 2017, the Company granted 148,148 PSUs that will vest on December 31, 2020.

The Company granted the following PSUs during the years ended December 31, 2016 and 2015:

	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
2015 grant	67,135	$	16.90	67,136	$	18.27	$	2.4

(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.

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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 2016 and 2015 grants will vest on December 31, 2018 and December 31, 2017, respectively.

The following table summarizes information with respect to unearned PSUs outstanding as of December 31, 2017 and PSU activity during the fiscal year then ended:

	Number of PSUs		Weighted Average Grant- Date Fair Value
Nonvested at December 31, 2016	666,713		$	10.51
Granted	385,758		$	11.61
Vested	(11,071	)	$	22.30
Forfeited	(258,619	)	$	13.72
Nonvested at December 31, 2017	782,781		$	10.06

Liability Classified Awards

Restricted Stock Units Settled in Cash

During the years ended December 31, 2017 and 2016, the Company issued 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, 2017 and 2016 was $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, 2017 was adjusted based on the closing price of our common stock on December 31, 2017 of $11.99 per share. The liability at December 31, 2017 was $1.2 million, of which $0.9 million was included in accrued liabilities and $0.3 million was included in other deferred credits and liabilities on the Consolidated Balance Sheets.

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 $0.7 million and $0.9 million during the years ended December 31, 2017 and 2016, respectively, that vests on December 31, 2019 and 2018, respectively. The 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, 2017 was adjusted based on the Company's current performance related to the above awards. The cash incentive award liability at December 31, 2017 was not material.

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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,
	2017		2016		2015		2017		2016		2015		December 31, 2017
	Compensation Expense(1)						Net of tax						Unrecognized Compensation Cost		Recognition Period
	(Dollars in millions)												(Dollars in millions)		(Years)
Equity Awards:
Stock Options	$	1.3	$	2.1	$	2.5	$	0.8	$	1.3	$	1.6	$	0.7	2.0
RSUs	1.1		2.6		4.2		0.7		1.7		2.7		$	0.3	1.2
PSUs	1.9		1.4		0.5		1.2		0.9		0.3		$	2.4	2.8
Total equity awards	$	4.3	$	6.1	$	7.2	$	2.7	$	3.9	$	4.6
Liability Awards:
Cash RSUs	$	1.0	$	0.7	$	—	$	0.6	$	0.5	$	—	$	1.3	1.7
Cash incentive award	0.2		0.1		—		0.1		0.1		—		$	0.4	1.9
Total liability awards	$	1.2	$	0.8	$	—	$	0.7	$	0.6	$	—

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

The Company issued $0.5 million and $0.4 million of share-based compensation to the Company's Board of Directors during the years ended December 31, 2017 and 2016, respectively. The share-based compensation issued to the Company's Board of Directors was not material during the year ended December 31, 2015.

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,
	2017	2016	2015
	(Shares in millions)
Weighted-average number of common shares outstanding-basic	64.3	64.2	65.0
Add: effect of dilutive share-based compensation awards	0.9	0.2	—
Weighted-average number of shares-diluted	65.2	64.4	65.0

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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,
	2017	2016	2015
	(Shares in millions)
Stock options	2.9	3.0	2.9
Restricted stock units	—	0.2	0.5
Performance stock units	0.1	0.2	—
Total	3.0	3.4	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

Certain assets and liabilities are measured at fair value on a recurring basis. The Company’s cash equivalents, which amounted to $5.5 million and $4.4 million at December 31, 2017 and 2016, 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 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 at December 31, 2017 and December 31, 2016 was $2.5 million and $4.2 million, respectively, and was included in other deferred credits and liabilities on the Consolidated Balance Sheets.

During 2017, as a result of adverse mining conditions faced by one of our thermal coal customers, the Partnership lowered CMT's throughput volume projection for this customer, which reduced the Partnership's contingent consideration liability balance by $1.7 million. The decrease in fair value was recorded as a reduction to costs of products sold and operating expenses on the Consolidated Statements of Operations during 2017. Throughput volumes at CMT in 2017 were consistent with projections and higher than 2016 levels, but still significantly below levels that would trigger payment of the contingent consideration.

During March 2016, as part of developing commercial activities subsequent to the acquisition, 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. The increase in the volume threshold reduced the fair value of the contingent consideration liability by $3.7 million, which was recorded as a reduction to cost of products sold and operating expense on the Consolidated Statement of Operations.

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During the second half of 2016, the Partnership lowered CMT’s throughput volume projections in future periods for certain customers due to declining coal prices which were expected to reduce export volume through CMT. These updated volume projections resulted in a net decrease to the contingent consideration liability, decreasing cost of products sold and operating expenses on the Consolidated Statements of Operations by $6.4 million during the year ended December 31, 2016. During 2016, the Partnership also recorded an adjustment to correct an error in the acquisition date fair value of the contingent consideration liability, which increased the contingent consideration liability and goodwill balance by $6.4 million.

Non-Financial Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis

Certain assets and liabilities are measured at fair value on a nonrecurring basis; that is, the assets and liabilities are not measured at fair value on an ongoing basis, but are subject to fair value adjustments in certain circumstances (e.g., when there is evidence of impairment).

India Equity Method Investment Valuation

As a result of sustained depressed market conditions, the Company recorded other-than-temporary impairment charges of the joint venture investment in the Company's India reportable segment of $19.4 million in 2015. These charges were recorded in loss from equity method investment on the Consolidated Statement of Operations and resulted in an investment balance of zero. Consequently, beginning in the fourth quarter of 2015, we no longer include the results of our share of VISA SunCoke in our consolidated financial statements. In accordance with GAAP, our share of future earnings of the joint venture will only be included in our results once the cumulative investment balance is no longer negative. The Company has no plans to make further capital contributions to this investment.

The estimated discounted cash flows in 2015 utilized inputs considered to be Level 3 in the fair value hierarchy. Key assumptions in the 2015 discounted cash flow analysis included a 13.5 percent discount rate and estimated cash flows, which considered the timing and extent of future improvements in the Indian market, an important component of which is gross margin recovery. The continuing deterioration of market conditions resulted in forecasted gross loss of $8 per ton to a forecasted gross margin gain of $13 per ton upon market recovery. A $5 per ton change in the gross margin assumption in 2016 would have impacted the valuation of our investment by approximately $8 million. To the extent possible, the Company considered available market information and other third-party data and compared the inputs to relevant historical information during the 2015 valuations.

Certain Financial Assets and Liabilities not Measured at Fair Value

At December 31, 2017 and 2016, the fair value of the Company’s long-term debt was estimated to be $919.7 million and $854.4 million, respectively, compared to a carrying amount of $887.3 million and $858.0 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. 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 located in Vansant, Virginia; East Chicago, Indiana; Franklin Furnace, Ohio; Granite City, Illinois; and Middletown, Ohio, respectively. Each of these facilities produces coke, and all facilities except Jewell and Indiana Harbor recover waste heat, which is converted to steam or electricity through a similar production process. Steam is provided to customers pursuant to steam supply and purchase agreements. Electricity is sold into the regional power market or to AK Steel Holding Corporation ("AK Steel") pursuant to energy sales agreements. Coke sales at each of the Company's five domestic cokemaking facilities are made pursuant to long-term, take-or-pay agreements with ArcelorMittal S.A., AK Steel, and U.S. Steel. Each of the coke sales agreements contains pass-through provisions for costs incurred in the cokemaking process, including coal procurement costs (subject to meeting contractual coal-to-coke yields), operating and maintenance expense, costs related to the transportation of coke to the customers, taxes (other than income taxes) and costs associated with changes in regulation, in addition to containing a fixed fee.

The Brazil Coke segment operates a cokemaking facility located in Vitória, Brazil for a project company. The Brazil Coke segment earns income from the Brazilian facility through licensing and operating fees payable to us under long-term contracts with the local project company that will run through at least 2023.

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Logistics operations are comprised of CMT, located in Louisiana, KRT, located in West Virginia, SunCoke Lake Terminal, located in Indiana, and DRT, located in Virginia adjacent to our Jewell cokemaking facility. Our logistics operations have a collective capacity to mix and transload approximately 40 million tons of coal and other aggregates annually and provide handling and/or mixing services to its customers, which include the Partnership's cokemaking facilities and other SunCoke cokemaking facilities. 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, which was historically presented as a separate reportable segment. Prior year periods have been recasted to reflect current presentation.

Segment assets, net of tax are those assets utilized within a specific segment and exclude deferred taxes and current tax receivables.

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,
	2017			2016			2015
	(Dollars in millions)
Sales and other operating revenue:
Domestic Coke	$	1,195.0		$	1,097.6		$	1,244.1
Brazil Coke	43.4			39.5			43.4
Logistics	93.1			84.7			60.8
Logistics intersegment sales	23.8			23.2			20.4
Corporate and Other(1)	—			1.5			14.4
Corporate and Other intersegment sales(1)	—			22.0			101.0
Elimination of intersegment sales	(23.8		)	(45.2		)	(121.4		)
Total sales and other operating revenue	$	1,331.5		$	1,223.3		$	1,362.7
Adjusted EBITDA
Domestic Coke	$	188.9		$	193.9		$	210.1
Brazil Coke	18.2			16.2			22.4
Logistics	70.8			63.9			38.0
Corporate and Other(2)	(43.2		)	(57.0		)	(85.1		)
Total Adjusted EBITDA	$	234.7		$	217.0		$	185.4
Depreciation and amortization expense:
Domestic Coke	$	102.6		$	84.0		$	81.6
Brazil Coke	0.7			0.7			0.6
Logistics	24.4			24.8			14.0
Corporate and Other	0.5			4.7			12.9
Total depreciation and amortization expense	$	128.2		$	114.2		$	109.1
Capital expenditures:
Domestic Coke	$	68.8		$	44.6		$	67.6
Logistics	4.4			17.4			6.0
Corporate and Other	2.4			1.7			2.2
Total capital expenditures	$	75.6		$	63.7		$	75.8

(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 $10.5 million, $15.0 million, and $40.9 million for the years ended December 31, 2017, 2016 and 2015, respectively.

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

	Years Ended December 31,
	2017		2016
	(Dollars in millions)
Segment assets
Domestic Coke	$	1,439.7	$	1,495.0
Brazil Coke	10.9		32.6
Logistics	491.9		515.6
Corporate and Other	112.8		73.1
Segment assets, excluding tax assets and assets held for sale	2,055.3		2,116.3
Tax assets	4.8		4.6
Total assets	$	2,060.1	$	2,120.9

The following table sets forth the Company’s total sales and other operating revenue by product or service:

	Years Ended December 31,
	2017		2016		2015
	(Dollars in millions)
Sales and other operating revenue:
Cokemaking	$	1,140.8	$	1,038.2	$	1,182.0
Energy	53.2		54.3		61.5
Logistics	89.7		82.9		58.8
Operating and licensing fees	43.4		39.5		34.0
Other	4.4		8.4		26.4
Sales and other operating revenue	$	1,331.5	$	1,223.3	$	1,362.7

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 interest, taxes, depreciation and amortization and impairments attributable to our equity method investment. 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;

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• 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,
	2017			2016			2015
	(Dollars in millions)
Net cash provided by operating activities	$	148.5		$	219.1		$	141.1
Subtract:
Depreciation and amortization expense	128.2			114.2			109.1
Deferred income tax (benefit) expense	(87.2		)	3.1			(5.6		)
Loss (gain) on extinguishment of debt	20.4			(25.0		)	0.5
Loss on divestiture of business	—			14.7			—
Changes in working capital and other	(16.4		)	52.6			26.8
Net income	$	103.5		$	59.5		$	10.3
Add:
Depreciation and amortization expense	128.2			114.2			109.1
Interest expense, net	60.6			53.5			56.2
Loss (gain) on extinguishment of debt	20.4			(25.0		)	0.5
Income tax (benefit) expense	(81.6		)	8.6			(8.8		)
Contingent consideration adjustments(1)	(1.7		)	(10.1		)	—
Expiration of land deposits and write-off of costs related to potential new cokemaking facility(2)	5.3			1.9			—
Non-cash reversal of acquired contractual obligation(3)	—			(0.7		)	(3.3		)
Loss on divestiture of business	—			14.7			—
Coal rationalization costs(4)	—			0.4			0.6
Adjustment to unconsolidated affiliate earnings(5)	—			—			20.8
Adjusted EBITDA(6)	$	234.7		$	217.0		$	185.4
Subtract: Adjusted EBITDA attributable to noncontrolling interest(7)	86.4			86.6			81.2
Adjusted EBITDA attributable to SunCoke Energy, Inc.	$	148.3		$	130.4		$	104.2

(1) As a result of changes in the fair value of the contingent consideration liability, the Partnership recognized benefits of $1.7 million and $10.1 million during 2017 and 2016, respectively. See Note 17.

(2) In 2014, we finalized the required permitting and engineering plan for a potential new cokemaking facility to be constructed in Kentucky. However, in June 2017, due to our focus on renewing our existing customer contracts and the lack of any long-term customer commitment for a majority of the facility's capacity, we decided to terminate the project. As a result, during 2017, the Company wrote-off previously capitalized engineering and land deposit costs of $5.3 million. During 2016, the Company wrote-off expiring land deposits related to the project of $1.9 million.

(3) In association with the acquisition of CMT, we assumed certain performance obligations under existing contracts and recorded liabilities related to such obligations. In 2015 and 2016, the final acquired contractual performance obligations expired without the customer requiring performance. Therefore, the Partnership reversed the liabilities as we no longer have any obligations under the contracts.

(4) 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.

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(5) Reflects share of interest, taxes, depreciation and amortization related to VISA SunCoke, including impairments of our investment in VISA SunCoke of $19.4 million, which resulted in an investment balance of zero. Beginning in the fourth quarter of 2015, we no longer include the results of our share of VISA SunCoke in our consolidated financial statements.

(6) In accordance with the SEC’s May 2016 update of its guidance on the appropriate use of non-GAAP financial measures, Adjusted EBITDA does not include Logistics deferred revenue until it is recognized as GAAP revenue.

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

19. Selected Quarterly Data (unaudited)

	2017										2016
	First Quarter(1)			Second Quarter(2)			Third Quarter		Fourth Quarter(3)(4)		First Quarter			Second Quarter			Third Quarter		Fourth Quarter(4)
	(Dollars in millions)
Sales and other operating revenue	$	309.7		$	323.2		$	339.0	$	359.6	$	311.1		$	292.7		$	293.9	$	325.6
Gross profit(5)	$	42.0		$	32.7		$	51.2	$	56.6	$	42.4		$	39.7		$	50.7	$	69.8
Net (loss) income	$	(57.7	)	$	(31.5	)	$	18.8	$	173.9	$	12.6		$	1.0		$	14.4	$	31.5
Less: Net (loss) income attributable to noncontrolling interests	$	(58.7	)	$	(7.3	)	$	7.2	$	39.9	$	16.7		$	5.6		$	8.3	$	14.5
Net income (loss) attributable to SunCoke Energy, Inc.	$	1.0		$	(24.2	)	$	11.6	$	134.0	$	(4.1	)	$	(4.6	)	$	6.1	$	17.0
Earnings (loss) attributable to SunCoke Energy, Inc. per common share:
Basic(6)	$	0.02		$	(0.38	)	$	0.18	$	2.08	$	(0.06	)	$	(0.07	)	$	0.10	$	0.26
Diluted(6)	$	0.02		$	(0.38	)	$	0.18	$	2.05	$	(0.06	)	$	(0.07	)	$	0.10	$	0.26

(1) 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.

(2) During the second quarter of 2017, the Partnership incurred $20.2 million of losses in connection with debt refinancing. See Note 12.

(3) 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.

(4) The Partnership recognized deferred revenue from Logistics take-or-pay billings for minimum volume shortfalls of $16.4 million and $31.5 million into revenue in the fourth quarters of 2017 and 2016 respectively.

(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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20. 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 and $44.6 million of 2019 Notes (“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 footnote, SunCoke Energy, Inc. 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 2025 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, 2017, less than 25 percent of net assets were restricted. 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 2019 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 2019 Notes, has occurred as a result thereof;

• the designation of a Guarantor Subsidiary as an "unrestricted subsidiary" in accordance with the indenture governing the 2019 Notes

• the requirements for defeasance or discharge of the indentures governing the 2019 Notes having been satisfied;

• 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 2019 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.

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SunCoke Energy, Inc.

Condensed Consolidating Statement of Operations

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 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	—			157.3			867.9			(4.4		)	1,020.8
Selling, general and administrative expenses	8.7			22.6			48.3			—			79.6
Depreciation and amortization expenses	—			7.5			120.7			—			128.2
Total costs and operating expenses	8.7			187.4			1,036.9			(4.4		)	1,228.6
Operating income (loss)	101.2			(32.3		)	89.4			(55.4		)	102.9
Interest (income) expense, net - affiliate	—			(7.5		)	7.5			—			—
Interest expense (income), net	4.9			(0.5		)	56.2			—			60.6
Total interest expense (income), net	4.9			(8.0		)	63.7			—			60.6
Loss on extinguishment of debt	0.4			—			20.0			—			20.4
Income 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

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SunCoke Energy, Inc.

Condensed Consolidating Statement of Operations

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 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	—			131.3			779.1			(3.9		)	906.5
Selling, general and administrative expenses	12.9			25.5			52.9			—			91.3
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			166.0			951.7			(3.9		)	1,126.7
Operating income	6.8			62.0			98.8			(71.0		)	96.6
Interest (income) expense, net - affiliate	—			(7.6		)	7.6			—			—
Interest expense (income), net	6.0			(0.2		)	47.7			—			53.5
Total interest expense (income), net	6.0			(7.8		)	55.3			—			53.5
Gain on extinguishment of debt	—			—			(25.0		)	—			(25.0		)
Income before income tax (benefit) expense	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 Statement of Operations

Years Ended December 31, 2015

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Revenues
Sales and other operating revenue	$	—		$	197.2		$	1,165.5		$	—		$	1,362.7
Equity in (loss) earnings of subsidiaries	(8.4		)	34.4			—			(26.0		)	—
Total revenues, net of equity in (loss) earnings of subsidiaries	(8.4		)	231.6			1,165.5			(26.0		)	1,362.7
Costs and operating expenses
Cost of products sold and operating expenses	—			150.2			948.2			—			1,098.4
Selling, general and administrative expenses	9.5			30.7			35.2			—			75.4
Depreciation and amortization expenses	—			10.4			98.7			—			109.1
Total costs and operating expenses	9.5			191.3			1,082.1			—			1,282.9
Operating (loss) income	(17.9		)	40.3			83.4			(26.0		)	79.8
Interest (income) expense, net - affiliate	—			(7.3		)	7.3			—			—
Interest expense (income), net	8.3			(0.6		)	48.5			—			56.2
Total interest expense (income), net	8.3			(7.9		)	55.8			—			56.2
Loss (gain) on extinguishment of debt, net	1.2			—			(0.7		)	—			0.5
(Loss) income before income tax (benefit) expense and loss from equity method investment	(27.4		)	48.2			28.3			(26.0		)	23.1
Income tax (benefit) expense	(5.4		)	29.6			(33.0		)	—			(8.8		)
Loss from equity method investment	—			—			21.6			—			21.6
Net (loss) income	(22.0		)	18.6			39.7			(26.0		)	10.3
Less: Net income attributable to noncontrolling interests	—			—			32.3			—			32.3
Net (loss) income attributable to SunCoke Energy, Inc.	$	(22.0	)	$	18.6		$	7.4		$	(26.0	)	$	(22.0	)
Comprehensive (loss) income	$	(20.3	)	$	18.4		$	41.6		$	(27.7	)	$	12.0
Less: Comprehensive income attributable to noncontrolling interests	—			—			32.3			—			32.3
Comprehensive (loss) income attributable to SunCoke Energy, Inc.	$	(20.3	)	$	18.4		$	9.3		$	(27.7	)	$	(20.3	)

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 tax receivable	—			—			88.1			(83.3		)	4.8
Other current assets	—			4.6			2.1			—			6.7
Advances to affiliates	—			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 intangibles 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
Investment in subsidiaries	632.5			721.2			—			(1,353.7		)	—
Total assets	$	639.6		$	1,257.6		$	2,241.8		$	(2,078.9	)	$	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 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 72,006,905 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	(20.1		)	(2.2		)	(17.9		)	20.1			(20.1		)
Retained earnings	100.1			475.6			115.3			(590.9		)	100.1
Total SunCoke Energy, Inc. stockholders’ equity	426.2			614.4			739.3			(1,353.7		)	426.2
Noncontrolling interests	—			—			233.4			—			233.4
Total equity	426.2			614.4			972.7			(1,353.7		)	659.6
Total liabilities and equity	$	639.6		$	1,257.6		$	2,241.8		$	(2,078.9	)	$	2,060.1

106

SunCoke Energy, Inc.

Condensed Consolidating Balance Sheet

December 31, 2016

(Dollars in millions, except per share amounts)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Assets
Cash and cash equivalents	$	—		$	59.7		$	74.3		$	—		$	134.0
Receivables	—			12.2			48.5			—			60.7
Receivable from redemption of investment in Brazil	—			—			20.5			—			20.5
Inventories	—			9.0			83.5			—			92.5
Income taxes receivable	17.8			—			74.3			(87.5		)	4.6
Other current assets	0.2			1.8			1.8			—			3.8
Advances to affiliate	—			282.2			—			(282.2		)	—
Total current assets	18.0			364.9			302.9			(369.7		)	316.1
Notes receivable from affiliate	—			89.0			300.0			(389.0		)	—
Properties, plants and equipment, net	—			62.8			1,479.8			—			1,542.6
Goodwill	—			3.4			73.5			—			76.9
Other intangible assets, net	—			2.3			176.7			—			179.0
Deferred charges and other assets	—			5.1			1.2			—			6.3
Investment in subsidiaries	542.7			688.2			—			(1,230.9		)	—
Total assets	$	560.7		$	1,215.7		$	2,334.1		$	(1,989.6	)	$	2,120.9
Liabilities and Equity
Advances from affiliate	$	184.2		$	—		$	98.0		$	(282.2	)	$	—
Accounts payable	—			13.6			85.0			—			98.6
Accrued liabilities	1.7			20.5			27.6			—			49.8
Deferred Revenue	—			—			2.5			—			2.5
Current portion of long-term debt and financing obligation	—			—			4.9			—			4.9
Interest payable	1.5			—			14.7			—			16.2
Income taxes payable	—			87.5			—			(87.5		)	—
Total current liabilities	187.4			121.6			232.7			(369.7		)	172.0
Long-term debt and financing obligation	43.5			—			805.7			—			849.2
Payable to affiliate	—			300.0			89.0			(389.0		)	—
Accrual for black lung benefits	—			12.3			33.1			—			45.4
Retirement benefit liabilities	—			14.1			14.9			—			29.0
Deferred income taxes	15.9			371.0			(34.4		)	—			352.5
Asset retirement obligations	—			—			13.9			—			13.9
Other deferred credits and liabilities	2.8			6.4			9.8			—			19.0
Total liabilities	249.6			825.4			1,164.7			(758.7		)	1,481.0
Equity
Preferred stock, $0.01 par value. Authorized 50,000,000 shares; no issued and outstanding shares at December 31, 2016	—			—			—			—			—
Common stock, $0.01 par value. Authorized 300,000,000 shares; issued 71,707,304 shares at December 31, 2016	0.7			—			—			—			0.7
Treasury stock, 7,477,657 shares at December 31, 2016	(140.7		)	—			—			—			(140.7		)
Additional paid-in capital	492.1			42.1			672.2			(714.3		)	492.1
Accumulated other comprehensive loss	(19.0		)	(1.6		)	(17.4		)	19.0			(19.0		)
Retained (deficit) earnings	(22.0		)	349.8			185.8			(535.6		)	(22.0		)
Total SunCoke Energy, Inc. stockholders’ equity	311.1			390.3			840.6			(1,230.9		)	311.1
Noncontrolling interests	—			—			328.8			—			328.8
Total equity	311.1			390.3			1,169.4			(1,230.9		)	639.9
Total liabilities and equity	$	560.7		$	1,215.7		$	2,334.1		$	(1,989.6	)	$	2,120.9

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 expense (benefit)	(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 (earnings) loss 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:
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		)
Decrease in restricted cash	—			—			0.5			—			0.5
Return of Brazilian investment	—			—			20.5			—			20.5
Net cash used in investing activities	—			(4.1		)	(50.5		)	—			(54.6		)
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 affiliate	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 and cash equivalents	—			43.9			(57.7		)	—			(13.8		)
Cash and cash equivalents at beginning of year	—			59.7			74.3			—			134.0
Cash and cash equivalents at end of year	$	—		$	103.6		$	16.6		$	—		$	120.2

108

SunCoke Energy, Inc.

Condensed Consolidating Statement of Cash Flows

Years Ended 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 earnings 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 the effects of divestiture):
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		)
Decrease in restricted cash	—			—			17.7			—			17.7
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		)	(30.5		)	—			(36.2		)
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 affiliate	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 and cash equivalents	—			(10.9		)	21.5			—			10.6
Cash and cash equivalents at beginning of year	—			70.6			52.8			—			123.4
Cash and cash equivalents at end of year	$	—		$	59.7		$	74.3		$	—		$	134.0

109

SunCoke Energy, Inc.

Condensed Consolidating Statement of Cash Flows

December 31, 2015

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Cash Flows from Operating Activities:
Net (loss) income	$	(22.0	)	$	18.6		$	39.7		$	(26.0	)	$	10.3
Adjustments to reconcile net income to net cash (used in) provided by continuing operating activities:
Depreciation and amortization expense	—			10.4			98.7			—			109.1
Deferred income tax (benefit) expense	(20.7		)	14.9			0.2			—			(5.6		)
Gain on curtailment and payments in excess of expense for postretirement plan benefits	—			(1.6		)	(6.4		)	—			(8.0		)
Settlement loss and payments in excess of expense for pension plan	—			—			13.1			—			13.1
Share-based compensation expense	7.2			—			—			—			7.2
Equity in loss (earnings) of subsidiaries	8.4			(34.4		)	—			26.0			—
Loss from equity method investment	—			—			21.6			—			21.6
Loss (gain) on extinguishment of debt, net	1.2			—			(0.7		)	—			0.5
Changes in working capital pertaining to operating activities (net of acquisitions):
Receivables	0.1			9.4			9.3			—			18.8
Inventories	—			(1.3		)	24.5			—			23.2
Accounts payable	—			(3.2		)	(14.7		)	—			(17.9		)
Accrued liabilities	(0.2		)	(2.3		)	(21.8		)	—			(24.3		)
Deferred revenue	—			—			(4.4		)	—			(4.4		)
Interest payable	(6.1		)	—			5.1			—			(1.0		)
Income taxes	17.1			23.2			(45.9		)	—			(5.6		)
Other	(0.9		)	1.5			3.5			—			4.1
Net cash (used in) provided by operating activities	(15.9		)	35.2			121.8			—			141.1
Cash Flows from Investing Activities:
Capital expenditures	—			(11.8		)	(64.0		)	—			(75.8		)
Acquisition of business, net of cash acquired	—			—			(191.7		)	—			(191.7		)
Increase in restricted cash	—			—			(17.7		)	—			(17.7		)
Net cash used in investing activities	—			(11.8		)	(273.4		)	—			(285.2		)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt	—			—			260.8			—			260.8
Repayment of long-term debt	(16.8		)	—			(231.3		)	—			(248.1		)
Debt issuance costs	(0.4		)	—			(5.3		)	—			(5.7		)
Proceeds from revolving facility	60.4			—			232.0			—			292.4
Repayment of revolving facility	—			—			(50.0		)	—			(50.0		)
Cash distributions to noncontrolling interests	—			—			(43.3		)	—			(43.3		)
Dividends paid	(28.0		)	—			—			—			(28.0		)
Shares repurchased	(35.7		)	—			—			—			(35.7		)
SunCoke Energy Partners, L.P. units repurchased	—			—			(12.8		)	—			(12.8		)
Other financing activities	(1.1		)	—			—			—			(1.1		)
Net increase (decrease) in advances from affiliate	37.5			(55.1		)	17.6			—			—
Net cash provided by (used in) financing activities	15.9			(55.1		)	167.7			—			128.5
Net (decrease) increase in cash and cash equivalents	—			(31.7		)	16.1			—			(15.6		)
Cash and cash equivalents at beginning of year	—			102.3			36.7			—			139.0
Cash and cash equivalents at end of year	$	—		$	70.6		$	52.8		$	—		$	123.4

110

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, 2017, 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, 2017.

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

There was no change in our internal control over financial reporting that occurred during the year ended December 31, 2017 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

Item 9B. Other Information

None.

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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 2017 Annual Meeting of Stockholders to be held on May 3, 2018 (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

Arrangements Between SunCoke Energy and the Partnership

In the first half of 2016, SunCoke took certain actions to support the Partnership's strategy to de-lever its balance sheet and maintain a solid liquidity position. During the first quarter of 2016, SunCoke provided a "reimbursement holiday" on the $7.0 million of corporate costs allocated to the Partnership and also returned its $1.4 million IDR cash distribution to the Partnership ("IDR giveback"), resulting in capital contributions of $8.4 million. During the second quarter of 2016, SunCoke provided the Partnership with deferred payment terms until April 2017 on the reimbursement of the $6.9 million of allocated corporate costs to the Partnership and the $1.4 million IDR cash distribution, resulting in an outstanding payable to SunCoke of $8.3 million included in payable to affiliate, net on the Consolidated Balance Sheets as of December 31, 2016. During 2017, the Partnership paid the amounts due to SunCoke.

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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 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.

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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.

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.”

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.”    

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.”

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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
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)
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)

115

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 (filed herewith)
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 (filed herewith)
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 (filed herewith)
10.9*	SunCoke Energy, Inc. Executive Involuntary Severance Plan, amended and restated effective as of November 7, 2017 (filed herewith)
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)

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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)
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)

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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)
12.1*	Consolidated Ratio of Earnings to Fixed Charges (filed herewith)
21.1*	Subsidiaries of the Registrant (filed herewith)
23.1*	Consent of KPMG LLP (filed herewith)
24.1*	Powers of Attorney (filed herewith)
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)

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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.

119

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, 2018.

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, 2018.

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/ Andrew D. Africk*	Director
Andrew D. Africk
/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, 2018
Fay West

120

EX-10.5.5

Exhibit 10.5.5

PERFORMANCE SHARE UNIT AGREEMENT

under the

SUNCOKE ENERGY, INC. LONG-TERM PERFORMANCE ENHANCEMENT PLAN

This Performance Share Unit Agreement (the “Agreement”), is entered into as of _______________ (the “Agreement Date”), by and between SunCoke Energy, Inc. (“SunCoke”) and , an employee of SunCoke or one of its Affiliates (the “Participant”).

WITNESSETH:

WHEREAS, the SunCoke Energy, Inc. Long-Term Performance Enhancement Plan (the “Plan”) is administered by the Compensation Committee (the “Committee”), and the Committee has determined to grant to the Participant, pursuant to the terms and conditions of the Plan, an award (the “Award”) of Performance Share Units (“PSUs”), representing rights to receive shares of Common Stock, which Award is subject to a risk of forfeiture by the Participant, with the payout of such PSUs being conditioned upon the attainment of performance goals established by the Committee for the applicable performance period and the Participant’s continued employment with SunCoke or one of its Affiliates through the Determination Date (as defined herein); and

WHEREAS, the Participant has determined to accept such Award.

NOW, THEREFORE, in consideration of these premises and the mutual promises of each of the Parties herein contained, and for other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, SunCoke and the Participant, each intending to be legally bound hereby, agree as follows:

ARTICLE I

AWARD OF PERFORMANCE SHARE UNITS

1.1    Identifying Provisions. For purposes of this Agreement, the following terms shall have the following respective meanings:

(a)    Participant: ________________

(b)    Grant Date: ________________

(c)    Target Number of Total PSUs: ________________, in the aggregate, divided as follows:

(i) A target number of ________________PSUs (Adj. EBITDA), the eventual payout of which is dependent upon the level of attainment of certain targets for three-year cumulative adjusted earnings before interest, taxes, depreciation and amortization (“Adj. EBITDA”), and further adjusted for three-year total shareholder return (“TSR”), relative to the NASDAQ U.S. Benchmark Iron & Steel Total Return Index, as more particularly described on “Exhibit A,” attached hereto.

(ii) A target number of ________________PSUs (ROIC), the eventual payout of which is dependent upon the level of attainment of certain targets for three-year average pre-tax return on invested capital, including coke, logistics and unallocated corporate cost, but excluding discontinued operations and legacy costs [e.g., Black Lung, pensions and other post-employment benefits] (“ROIC”), and further adjusted for TSR, relative to the

NASDAQ U.S. Benchmark Iron & Steel Total Return Index, as more particularly described on “Exhibit A,” attached hereto.

(d) Performance Period: Three-year period beginning on January 1, 2018 and ending on December 31, 2020.

The term “PSUs” used herein shall mean and refer to the PSUs (Adj. EBITDA) and PSUs (ROIC) collectively. Any initially capitalized terms and phrases used in this Agreement but not otherwise defined herein, shall have the respective meanings ascribed to them in the Plan.

1.2    Award of PSUs. Subject to the terms and conditions of the Plan and this Agreement, the Participant is hereby granted the target number of total PSUs set forth in Section 1.1.

1.3    Dividend Equivalents. The Participant shall be entitled to receive payment from SunCoke in an amount equal to each cash dividend (“Dividend Equivalent”) payable subsequent to the Grant Date, just as though such Participant, on the record date for payment of such dividend, had been the holder of record of shares of Common Stock equal to the target number of PSUs. SunCoke shall establish a bookkeeping methodology to account for the Dividend Equivalents to be credited to the Participant. The Dividend Equivalents will not bear interest.

1.4    Adjustment, Vesting and Payment of PSUs and Dividend Equivalents.

(a)    Adjustment.

(1)    The target number of total PSUs subject to each PSU Award shall be adjusted by the Committee after the end of the Performance Period, based on the level of achievement of the performance goal(s) established with respect to the Performance Period as set forth in the attached Exhibit A. The date that the Committee determines the level of performance goal achievement applicable to the Award is the “Determination Date”.

(2)    Dividend Equivalents will be subject to the same adjustment, determined by multiplying the amount of Dividend Equivalents as of the Determination Date by the percentage adjustment made to the PSUs.

(b)    Vesting. Except as set forth in Section 1.5(b), (c) and (d) below, a Participant shall become vested in this PSU Award and related Dividend Equivalents on the Determination Date, if the Participant remains in continuous employment with SunCoke or one of its Affiliates until the Determination Date. PSUs and Dividend Equivalents that do not vest shall be forfeited.

(c)    Payment. Except as set forth in Section 1.5(b) and (c) below, actual payment for vested PSUs and vested Dividend Equivalents shall be made to the Participant within one month after the Determination Date.

(1)    Payment for vested PSUs. Payment for vested PSUs shall be made in shares of Common Stock. The number of shares of Common Stock paid to the Participant shall be equal to the aggregate total number of PSUs that vest on the Determination Date.

(2)    Payment of Related Dividend Equivalents. Payment for the vested Dividend Equivalents will be made in cash.

1.5    Termination of Employment.

(a)    Termination of Employment - In General. Upon termination of the Participant’s employment with SunCoke and its Affiliates prior to the Determination Date for any reason other than a Qualifying Termination or due to death or permanent disability, the Participant shall forfeit 100% of such Participant’s PSUs, together with the related Dividend Equivalents, and the Participant shall not be entitled to receive any Common Stock or any payment of any Dividend Equivalents with respect to the forfeited PSUs.

(b)    Qualifying Termination of Employment. In the event of the Participant’s Qualifying Termination prior to the Determination Date, the Participant’s outstanding PSUs and Dividend Equivalents shall vest immediately as follows:

(i)    For the PSUs (Adj. EBITDA): at the higher of (A) the target level, or (B) the actual performance level attained for Adj. EBITDA; and

(ii)    For the PSUs (ROIC): at the higher of (A) the target level, or (B) the actual performance level attained for ROIC,

in each case, calculated as of the fiscal quarter ending on, or immediately prior to, the date of the Change in Control, and adjusted for TSR (calculated as of the date of the Change in Control), relative to the NASDAQ U.S. Benchmark Iron & Steel Total Return Index, as more particularly described on “Exhibit A,” attached hereto. Each of such vested PSUs (Adj. EBITDA) and PSUs (ROIC) shall be paid in the form described in Section 1.4(c) above within one month following such Qualifying Termination.

(c)    Termination of Employment Due to Death or Permanent Disability. In the event of the Participant’s termination of employment due to death or permanent disability prior to the Determination Date, the Participant’s outstanding PSUs and Dividend Equivalents shall vest immediately at the target level and be paid in the form described in Section 1.4(c) above within one month following such termination of employment.

(d)    Termination Due to Retirement. In the event of the Participant’s termination of employment with SunCoke and its Affiliates prior to the Determination Date due to Retirement, the Participant’s PSUs and Dividend Equivalents shall remain outstanding and shall be adjusted at the end of the performance period as described in Section 1.4. The Participant shall vest in a pro rata portion of the adjusted PSUs determined by multiplying the number of PSUs by a fraction, the numerator of which is the number of full months that have elapsed from the beginning of the performance period to the employment termination date and the denominator of which is the number of full months in the performance period. The Participant also shall vest in the adjusted pro rata portion of the related Dividend Equivalents. The Participant’s PSUs and Dividend Equivalents that vest shall be paid in the form described in Section 1.4(c) above within one month following the Determination Date.

For purposes of this Section 1.5,

(i)    a Participant’s termination of employment shall not be deemed to be a “Retirement” unless: (x) such termination is other than for Just Cause; (y) the Participant has attained at least 55 years of age; and (z) the Participant’s age, when added to such Participant’s years of credited service with the SunCoke and/or its Affiliates, equals at least 65 years; and

(ii)    a Participant shall have a “permanent disability” if such Participant is found to be disabled, under the terms of SunCoke’s long-term disability policy in effect at the time of the Participant’s termination, due to such condition or if the Committee in its discretion makes such determination.

ARTICLE II

GENERAL PROVISIONS

2.1    Effect of Plan; Construction. The entire text of the Plan is expressly incorporated herein by this reference and so forms a part of this Agreement. In the event of any inconsistency or discrepancy between the provisions of the PSU Award covered by this Agreement and the terms and conditions of the Plan under which such PSUs are granted, the provisions in the Plan shall govern and prevail. The PSUs, the related Dividend Equivalents and this Agreement are each subject in all respects to, and SunCoke

and the Participant each hereby agree to be bound by, all of the terms and conditions of the Plan, as the same may have been amended from time to time in accordance with its terms.

2.2    Tax Withholding. All distributions under this Agreement are subject to withholding of all applicable taxes.

(a)    Payment in Cash. Cash payments in respect of any vested PSU or Dividend Equivalent shall be made net of any applicable federal, state, or local withholding taxes.

(b)    Payment in Stock. Immediately prior to the payment of any shares of Common Stock to Participant in respect of vested PSUs, the Participant shall remit an amount sufficient to satisfy any Federal, state and/or local withholding tax due on the receipt of such Common Stock. At the election of the Participant, and subject to such rules as may be established by the Committee, such withholding obligations may be satisfied through the surrender of shares of Common Stock (otherwise payable to Participant in respect of such vested PSUs) having a value, as of the date that such vested PSUs first became payable, sufficient to satisfy the applicable tax obligation.

2.3    Administration. Pursuant to the Plan, the Committee is vested with conclusive authority to interpret and construe the Plan, to adopt rules and regulations for carrying out the Plan, and to make determinations with respect to all matters relating to this Agreement, the Plan and Awards made pursuant thereto. The authority to manage and control the operation and administration of this Agreement shall be likewise vested in the Committee, and the Committee shall have all powers with respect to this Agreement as it has with respect to the Plan. Any interpretation of this Agreement by the Committee, and any decision made by the Committee with respect to this Agreement, shall be final and binding.

2.4    Amendment. This Agreement may be amended in accordance with the terms of the Plan.

2.5    Captions. The captions at the beginning of each of the numbered Sections and Articles herein are for reference purposes only and will have no legal force or effect. Such captions will not be considered a part of this Agreement for purposes of interpreting, construing or applying this Agreement and will not define, limit, extend, explain or describe the scope or extent of this Agreement or any of its terms and conditions.

2.6    Governing Law. The validity, construction, interpretation and effect of this instrument shall be governed exclusively by and determined in accordance with the law of the State of Delaware (without giving effect to the conflicts of law principles thereof), except to the extent preempted by federal law, which shall govern.

2.7    Notices. All notices, requests and demands to or upon the respective parties hereto to be effective shall be in writing, by facsimile, by overnight courier or by registered or certified mail, postage prepaid and return receipt requested. Notices to SunCoke shall be deemed to have been duly given or made upon actual receipt by SunCoke. Such communications shall be addressed and directed to the parties listed below (except where this Agreement expressly provides that it be directed to another) as follows, or to such other address or recipient for a party as may be hereafter notified by such party hereunder:

(a)    If to SunCoke:        SunCoke Energy, Inc.

Compensation Committee of the Board of Directors

1011 Warrenville Road

Lisle, IL 60532

Attention: Corporate Secretary

(b) If to the Participant:    To the address for Participant as it appears on SunCoke’s records.

2.8    Severability. If any provision hereof is found by a court of competent jurisdiction to be prohibited or unenforceable, it shall, as to such jurisdiction, be ineffective only to the extent of such prohibition or unenforceability, and such prohibition or unenforceability shall not invalidate the balance of such provision to the extent it is not prohibited or unenforceable, nor invalidate the other provisions hereof.

2.9    Entire Agreement. This Agreement constitutes the entire understanding and supersedes any and all other agreements, oral or written, between the parties hereto, in respect of the subject matter of this Agreement and embodies the entire understanding of the parties with respect to the subject matter hereof.

2.10    Forfeiture. The shares of Common Stock or cash payments received in connection with the Award granted pursuant to this Agreement constitute incentive compensation. The Participant agrees that any shares of Common Stock or cash payments received with respect to the Award will be subject to any clawback/forfeiture provisions applicable to SunCoke that are required by any law in the future, including, without limitation, the Dodd-Frank Wall Street Reform and Consumer Protection Act and/or any applicable regulations.

* * *

This Award is conditioned upon the acceptance by the Participant of the terms and conditions of the Award as set forth in this Agreement. To accept this Agreement, a Participant must access E*Trade Financial Services’ website.

SUNCOKE ENERGY, INC.

Long Term Performance Enhancement Plan

Performance Share Unit Agreement

Exhibit A

Calculation of TSR Modifier*

*In the event that SunCoke's TSR performance is negative, the overall payout of the award shall be capped at 100%.

Three-year TSR calculation:TSR = [P_f - Pi+ D]/[P_i], where:

TSR = Three-year total shareholder return on SXC common stock, expressed as a percent.

P_f = average closing price for SXC common stock for the ten-day trading period immediately preceding December 31, 2020.

D = reinvested dividends during the period from January 1, 2018 through December 31, 2020.

P_i = average closing price for SXC common stock for the ten-day trading period immediately preceding January 1, 2018.

EX-10.6.1

EXHIBIT 10.6.1

AWARD AGREEMENTunder theSUNCOKE ENERGY, INC. LONG-TERM CASH INCENTIVE PLAN

This Award Agreement (the “Agreement”), is entered into as of ____________, by and between SunCoke Energy, Inc. (“SunCoke”) and XX, an employee of SunCoke or one of its Affiliates (the “Participant”).

WITNESSETH:

WHEREAS, the SunCoke Energy, Inc. Long-Term Cash Incentive Plan (the “LTIP”) is administered by the Compensation Committee (the “Committee”), and the Committee has determined to grant to the Participant, pursuant to the terms and conditions of the LTIP, an award (the “Award”), representing the opportunity to receive a cash payment following the end of a Performance Period, with the payout of such Award being conditioned upon the attainment of one or more Performance Goals established by the Committee for the applicable Performance Period and the Participant’s continued employment with SunCoke or one of its Affiliates.

NOW, THEREFORE, in consideration of these premises and the mutual promises of each of the Parties herein contained, and for other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, SunCoke and the Participant, each intending to be legally bound hereby, agree as follows:

ARTICLE IAWARD

1.1    Acceptance of Award. The Award is conditioned upon its acceptance by the Participant in the space provided therefore at the end of this Agreement and the return of an executed copy of this Agreement to the Senior Vice President Human Resources, no later than ___________.

1.2    Identifying Provisions. For purposes of this Agreement, the following terms shall have the following respective meanings:

(a)    Participant: ____________

(b)    Grant Date: ____________

(c) Target Award:$_____________________, in the aggregate, divided as follows:

(i) A target value of $________, for the LTI Cash (Adj. EBITDA) portion of the total award. The eventual payout of this portion of the award is dependent upon the level of attainment of certain targets for three-year cumulative adjusted earnings before interest, taxes, depreciation and amortization (“Adj.EBITDA”), and further adjusted for three-year total shareholder return (“TSR”), relative to the NASDAQ U.S. Benchmark Iron & Steel Total Return Index, as more particularly described on “Exhibit A,” attached hereto.

Page 1 of 6

(ii) A target value of $__________, for the LTI Cash (ROIC) portion of the total award. The eventual payout of this portion of the award is dependent upon the level of attainment of certain targets for three-year average pre-tax return on invested capital, including coke, logistics and unallocated corporate cost, but excluding discontinued operations and legacy costs [e.g., Black Lung, pensions and other post-employment benefits] (“ROIC”), and further adjusted for TSR, relative to the NASDAQ U.S. Benchmark Iron & Steel Total Return Index, as more particularly described on “Exhibit A,” attached hereto.

(d) Performance Period: Three-year period ending on _____________.

The term “Award” used herein shall mean and refer to the LTI Cash (Adj. EBITDA) portion of the total award and the LTI Cash (ROIC) portion of the total award, collectively. Any initially capitalized terms and phrases used in this Agreement but not otherwise defined herein, shall have the respective meanings ascribed to them in the Plan.

1.3    Grant of Award. Subject to the terms and conditions of the LTIP and this Agreement, the Participant is hereby granted the target Award set forth in Section 1.2.

1.4    Adjustment, Vesting and Payment of Award.

(a)    Adjustment. The target value of each of: (i) the LTI Cash (Adj. EBITDA) portion; and (ii) the LTI Cash (ROIC) portion of the total Award shall be adjusted by the Committee after the end of the Performance Period, based on the level of achievement of the respective performance goal(s) established with for the Performance Period, as set forth in the attached Exhibit A. The date that the Committee determines the level of performance goal achievement applicable to the Award is the “Determination Date”.

(b)    Vesting. Except as set forth in Section 1.5(a), (b) and (c) below, a Participant shall become vested in his Award (as adjusted pursuant to (a) above) if he remains in continuous employment with SunCoke or one of its Affiliates until the Determination Date. An Award that does not vest shall be forfeited.

(c)    Payment. Except as set forth in Section 1.5(a) and (c) below, actual payment for Award shall be made to the Participant within one month after the Determination Date.

1.5    Termination of Employment.

(a)    Termination of Employment - In General. Upon termination of the Participant’s employment with SunCoke and its Affiliates prior to the Determination Date for any reason other than a Qualifying Termination or Just Cause or due to death or permanent disability, the Award shall remain outstanding and shall be adjusted at the end of the Performance Period as described in Section 1.4(a). The Participant shall vest in a pro rata portion of the adjusted Award, determined by multiplying the adjusted Award by a fraction, the numerator of which is the number of full months elapsed from the beginning of the Performance Period to the employment termination date, and the denominator of which is the number of full months in the Performance Period. The vested portion of the Award will be paid in cash within one month following the Determination Date, and the unvested portion will be forfeited.

(b)    Qualifying Termination of Employment. In the event of the Participant’s Qualifying Termination prior to the Determination Date, the Participant’s outstanding Award shall vest immediately as follows:

Page 2 of 6

(i)    For the LTI Cash (Adj. EBITDA) portion: at the higher of (A) the target level, or (B) the actual performance level attained for cumulative Adj. EBITDA; and

(ii)    For the LTI Cash (ROIC) portion: at the higher of (A) the target level, or (B) the actual performance level attained for pre-tax ROIC,

in each case, calculated as of the fiscal quarter ending on, or immediately prior to, the date of the Change in Control, and adjusted for TSR (calculated as of the date of the Change in Control) relative to the NASDAQ U.S. Benchmark Iron & Steel Total Return Index, as more particularly described on “Exhibit A,” attached hereto. Each of such vested LTI Cash (Adj. EBITDA) portion and vested LTI Cash (ROIC) portion shall be paid in cash within one month following such Qualifying Termination.

(c)    Termination of Employment Due to Death or Permanent Disability. In the event of the Participant’s termination of employment due to death or permanent disability prior to the Determination Date, the Participant’s outstanding Award shall not be adjusted pursuant to Section 1.4(a) above, but shall vest immediately at the target level and be paid in cash within one month following such termination of employment. For purposes of this Section 1.5(c), a Participant shall have a “permanent disability” if he is found to be disabled, under the terms of SunCoke’s long-term disability policy in effect at the time of the Participant’s termination, due to such condition or if the Committee in its discretion makes such determination.

(d)    In the event the Participant’s employment is terminated prior to the Determination Date by SunCoke or an Affiliate for Just Cause, the Participant’s Award shall be forfeited.

ARTICLE IIGENERAL PROVISIONS

2.1    Effect of Plan; Construction. The entire text of the LTIP is expressly incorporated herein by this reference and so forms a part of this Agreement. In the event of any inconsistency or discrepancy between the provisions of the Award covered by this Agreement and the terms and conditions of the LTIP under which such Award is granted, the provisions in the LTIP shall govern and prevail. The Award and this Agreement are each subject in all respects to, and SunCoke and the Participant each hereby agree to be bound by, all of the terms and conditions of the LTIP, as the same may have been amended from time to time in accordance with its terms.

2.2    Tax Withholding. The payment of an Award under this Agreement shall be net of any applicable federal, state, or local withholding taxes.

2.3    Administration. Pursuant to the LTIP, the Committee is vested with conclusive authority to interpret and construe the LTIP, to adopt rules and regulations for carrying out the LTIP, and to make determinations with respect to all matters relating to this Agreement, the LTIP and Awards made pursuant thereto. The authority to manage and control the operation and administration of this Agreement shall be likewise vested in the Committee, and the Committee shall have all powers with respect to this Agreement as it has with respect to the LTIP. Any interpretation of this Agreement by the Committee, and any decision made by the Committee with respect to this Agreement, shall be final and binding.

2.4    Amendment. This Agreement may be amended in accordance with the terms of the LTIP.

Page 3 of 6

2.5    Captions. The captions at the beginning of each of the numbered Sections and Articles herein are for reference purposes only and will have no legal force or effect. Such captions will not be considered a part of this Agreement for purposes of interpreting, construing or applying this Agreement and will not define, limit, extend, explain or describe the scope or extent of this Agreement or any of its terms and conditions.

2.6    Governing Law. The validity, construction, interpretation and effect of this instrument shall be governed exclusively by and determined in accordance with the law of the State of Delaware (without giving effect to the conflicts of law principles thereof), except to the extent preempted by federal law, which shall govern.

2.7    Notices. All notices, requests and demands to or upon the respective parties hereto to be effective shall be in writing, by facsimile, by overnight courier or by registered or certified mail, postage prepaid and return receipt requested. Notices to SunCoke shall be deemed to have been duly given or made upon actual receipt by SunCoke. Such communications shall be addressed and directed to the parties listed below (except where this Agreement expressly provides that it be directed to another) as follows, or to such other address or recipient for a party as may be hereafter notified by such party hereunder:

(a)    If to SunCoke:        SunCoke Energy, Inc.

Compensation Committee of the Board of Directors

1011 Warrenville Road

Lisle, IL 60532

Attention: Corporate Secretary

(b) If to the Participant:    To the address for the Participant as it appears on SunCoke’s records.

2.8    Severability. If any provision hereof is found by a court of competent jurisdiction to be prohibited or unenforceable, it shall, as to such jurisdiction, be ineffective only to the extent of such prohibition or unenforceability, and such prohibition or unenforceability shall not invalidate the balance of such provision to the extent it is not prohibited or unenforceable, nor invalidate the other provisions hereof.

2.9    Entire Agreement. This Agreement constitutes the entire understanding and supersedes any and all other agreements, oral or written, between the parties hereto, in respect of the subject matter of this Agreement and embodies the entire understanding of the parties with respect to the subject matter hereof.

2.10    Forfeiture. The cash payment received in connection with the Award granted pursuant to this Agreement constitutes incentive compensation. The Participant agrees that any cash payment received with respect to the Award will be subject to any clawback/forfeiture provisions applicable to SunCoke that are required by any law in the future, including, without limitation, the Dodd-Frank Wall Street Reform and Consumer Protection Act and/or any applicable regulations.

* * *

Page 4 of 6

IN WITNESS WHEREOF, this Agreement is delivered by the Company as of the _____ day of ________.

	SunCoke Energy, Inc. By: Its:
AGREED AND ACCEPTED: Participant Signature Print Name Date

Page 5 of 6

EXHIBIT A

SUNCOKE ENERGY, INC.

Long Term Cash Incentive Plan

2018 Award Agreement

Calculation of TSR Modifier*

Three-year TSR calculation:TSR = [P_f - Pi+ D]/[P_i], where:

TSR = Three-year total shareholder return on SXC common stock, expressed as a percent.

P_f = average closing price for SXC common stock for the ten-day trading period immediately preceding December 31, 2020.

D = reinvested dividends during the period from January 1, 2018 through December 31, 2020.

P_i = average closing price for SXC common stock for the ten-day trading period immediately preceding January 1, 2018.

Page 6 of 6

EX-10.8

EXHIBIT 10.8

SUNCOKE ENERGY, INC.

SPECIAL EXECUTIVE SEVERANCE PLAN

(Effective as of November 7, 2017)

SunCoke Energy, Inc.

Special Executive Severance Plan

ARTICLE I

DEFINITIONS

1.1. “Annual Compensation” shall mean a Participant’s annual base salary as in effect immediately prior to the Change in Control, or, if greater, immediately prior to the Employment Termination Date, plus the greater of (x) the Participant’s annual guideline (target) bonus as in effect immediately before the Change in Control or, if higher, the Employment Termination Date, or (y) the average annual bonus awarded to the Participant with respect to the three years ending before the Change in Control or, if higher, with respect to the three years ending before the Employment Termination Date.

1.2. “Affiliate” shall mean any entity that directly, or indirectly through one or more intermediaries,

controls, is controlled by, or is under common control with SunCoke Energy, Inc.

1.3. “Benefit” or “Benefits” shall mean any or all of the benefits that a Participant is entitled to receive pursuant to Article IV of the Plan.

1.4. “Benefit Extension Period” shall mean, for each Participant, two years.

1.5. “Board of Directors” shall mean the Board of Directors of SunCoke Energy, Inc.

1.6. “Business Combination” shall have the meaning provided herein at Section 1.7(c).

1.7. “Change in Control” shall mean the occurrence of any of the following events:

(a) The acquisition by any individual, entity or group (within the meaning of Section 13(d)(3) or 14(d)(2) of the Exchange Act) (a “Person”) of beneficial ownership (within the meaning of Rule 13d-3 promulgated under the Exchange Act) of twenty percent (20%) or more of either: (i) the then-outstanding shares of common stock of SunCoke Energy, Inc. (the “Outstanding Company Common Stock”) or (ii) the combined voting power of the then-outstanding voting securities of SunCoke Energy, Inc. entitled to vote generally in the election of directors (the “Outstanding Company Voting Securities”); provided, however, that, for purposes of this Section 1.7(a), the following acquisitions shall not constitute a Change in Control:

(A) any acquisition directly from SunCoke Energy, Inc.,

(B) any acquisition by SunCoke Energy, Inc.,

(C) any acquisition by any employee benefit plan (or related trust) sponsored or maintained by SunCoke Energy, Inc. or any company controlled by, controlling or under common control with SunCoke Energy, Inc., or

(D) any acquisition by any entity pursuant to a transaction that complies with Sections 1.7(c)(1), (c)(2) and (c)(3) of this definition;

(b) Individuals who, as of the date that the plan becomes effective, constitute the Board of Directors (the “Incumbent Board”) cease for any reason to constitute at least a majority of the Board of Directors; provided, however, that any individual becoming a director subsequent to the date hereof whose election, or nomination for election by the shareholders of SunCoke Energy, Inc., was approved by a vote of at least a majority of the directors then comprising the Incumbent Board shall be considered as though such individual were a member of the Incumbent Board, but excluding, for this purpose, any such individual whose initial assumption of office occurs as a result of an actual or threatened election contest with respect to the election or removal of directors or other actual or threatened solicitation of proxies or consents by or on behalf of a Person other than the Board of Directors;

(c) Consummation of a reorganization, merger, statutory share exchange or consolidation or similar corporate transaction involving SunCoke Energy, Inc. or any of its subsidiaries, a sale or other disposition of all or substantially all of the assets of SunCoke Energy, Inc., or the acquisition of assets or stock of another entity by SunCoke Energy, Inc. or any of its subsidiaries (each, a “Business Combination”), in each case unless, following such Business Combination,

(i) all or substantially all of the individuals and entities that were the beneficial owners of the Outstanding Company Common Stock and the Outstanding Company Voting Securities immediately prior to such Business Combination beneficially own, directly or indirectly, more than fifty percent (50%) of the then-outstanding shares of common stock and the combined voting power of the then-outstanding voting securities entitled to vote generally in the election of directors, as the case may be, of the corporation resulting from such Business Combination (including, without limitation, a corporation that, as a result of such transaction, owns SunCoke Energy, Inc. or all or substantially all of the assets of SunCoke Energy, Inc., either directly or through one or more subsidiaries) in substantially the same proportions as their ownership immediately prior to such Business Combination of the Outstanding Company Common Stock and the Outstanding Company Voting Securities, as the case may be,

(ii) no Person (excluding any corporation resulting from such Business Combination or any employee benefit plan (or related trust) of SunCoke Energy, Inc. or such corporation resulting from such Business Combination or any of their respective subsidiaries) beneficially owns, directly or indirectly, twenty percent (20%) or more of, respectively, the then-outstanding shares of common stock of the corporation resulting from such Business Combination or the combined voting power of the then-outstanding voting securities of such corporation, except to the extent that such ownership existed prior to the Business Combination, and

(iii) at least a majority of the members of the board of directors of the corporation resulting from such Business Combination were members of the Incumbent Board at the time of the execution of the initial agreement or of the action of the Board of Directors providing for such Business Combination; or

(d) Approval by the shareholders of SunCoke Energy, Inc. of a complete liquidation or dissolution of SunCoke Energy, Inc;

provided, however, that in no event shall the IPO or the subsequent distribution of shares of common stock, par value $0.01, of SunCoke Energy, Inc., from Sunoco, Inc. to the shareholders of Sunoco, Inc. constitute a Change in Control as defined above.

1.8. “Chief Executive Officer” shall mean the individual serving as the Chief Executive Officer of SunCoke Energy, Inc. as of the date of reference.

1.9. “Code” shall mean the Internal Revenue Code of 1986, as amended.

1.10. “Committee” shall mean the administrative committee designated pursuant to Article VI of the Plan to administer the Plan in accordance with its terms.

1.11. “Company” shall mean SunCoke Energy, Inc., and any Affiliate.

1.12. “Company Service” shall mean, for purposes of determining Benefits available to any Participant in this Plan, the total aggregate recorded length of such Participant’s service with SunCoke Energy, Inc. or any Affiliate (while it is an Affiliate). Company Service shall commence with the Participant’s initial date of employment with the Company, and shall end with such Participant’s death, retirement, or termination for any reason. Company Service also shall include:

(a) all periods of approved leave of absence (civil, family, medical, military, or Olympic); provided, however, that the Participant returns to work within the prescribed time following the leave;

(b) any break in service of thirty (30) days or less; and

(c) any service credited under applicable Company policies with respect to the length of a Participant’s employment by any non-affiliated entity that subsequently becomes an Affiliate or part of the operations of the Company.

1.13. “Disability” shall mean any illness, injury or incapacity of such duration and type as to render a Participant eligible to receive long-term disability benefits under the applicable broad-based long-term disability program of the Company.

1.14. “Compensation Committee” shall mean the compensation committee of the Board of Directors.

1.15. “Employment Termination Date” shall mean the date on which a Participant separates from service as defined in Section 409A of the Internal Revenue Code of 1986, as amended (the “Code”) and the regulations issued thereunder.

1.16. “ERISA” shall mean the Employee Retirement Income Security Act of 1974, as amended.

1.17. “Exchange Act” shall mean the Securities Exchange Act of 1934, as amended.

1.18. “Incumbent Board” shall have the meaning provided herein at Section 1.7(b).

1.19. “IPO” shall mean the initial public offering of the SunCoke Energy, Inc.

1.20. “Involuntary Plan” shall mean the SunCoke Energy, Inc. Executive Involuntary Severance Plan.

1.21. “Just Cause” shall mean:

(a) the willful and continued failure of the Participant to perform substantially the Participant’s duties with the Company (other than any such failure resulting from incapacity due to physical or mental illness or following notice of employment termination by the Participant pursuant to Section 1.28(b)), after a written demand for substantial performance is delivered to the Participant by the Board of Directors or the Chief Executive Officer that specifically identifies the manner in which the Board of Directors or the Chief Executive Officer believes that the Participant has not substantially performed the Participant’s duties, or

(b) the willful engaging by the Participant in illegal conduct or gross misconduct that is materially and demonstrably injurious to the Company.

For purposes of this Section 1.22, no act, or failure to act, on the part of the Participant shall be considered “willful” unless it is done, or omitted to be done, by the Participant in bad faith or without reasonable belief that the Participant’s action or omission was in the best interests of the Company. Any act, or failure to act, based upon authority given pursuant to a resolution duly adopted by the Board or upon the instructions of the Chief Executive Officer or a senior officer of the Company or based upon the advice of counsel for the Company shall be conclusively presumed to be done, or omitted to be done, by the Participant in good faith and in the best interests of the Company.

1.22. “Outstanding Company Common Stock” shall have the meaning provided herein at Section 1.7(a).

1.23. “Outstanding Company Voting Stock” shall have the meaning provided herein at Section 1.7(a).

1.24. “Participant” shall mean any individual officer or executive designated by the Chief Executive Officer of the Company on or before the occurrence of any Change in Control; provided, however, that such individual is employed by the Company on or before such Change in Control. For purposes of Section 4.6 of this Plan, each former officer or executive designated by the Chief Executive Officer also shall be a Participant.

1.25. “Person” shall have the meaning provided herein at Section 1.7(a).

1.26. “Plan” shall mean the SunCoke Energy, Inc. Special Executive Severance Plan, as set forth herein, and as the same may from time to time be amended.

1.27. “Qualifying Termination” of the employment of a Participant shall mean any of the following:

(a) a termination of employment by the Company within two (2) years after a Change in Control, other than for Just Cause, death or Disability;

(b) a termination of employment by the Participant within two (2) years after a Change in Control for one or more of the following reasons:

(i) the assignment to such Participant of any duties inconsistent in a way significantly adverse to such Participant, with such Participant’s positions, duties, responsibilities and status with the Company immediately prior to the Change in Control, or a significant reduction in the duties or responsibilities held by the Participant immediately prior to the Change in Control, or a significant change in the Participant’s reporting responsibilities, title or offices as in effect immediately prior to the Change in Control that is adverse to the Participant, in each case except in connection with such Participant’s termination of employment by the Company for Just Cause; or

(ii) a material reduction in the Participant’s (A) annual base salary or (B) total annual compensation opportunity, from such base salary or total annual compensation opportunity in effect immediately prior to the Change in Control; or

(iii) the Company requires the Participant to be based anywhere other than the Participant’s present work location or a location within thirty-five (35) miles from the present location; or the Company requires the Participant to travel on Company business to an extent substantially more burdensome than such Participant’s travel obligations during the period of twelve (12) consecutive months immediately preceding the Change in Control; or

(iv) the Company fails to obtain a satisfactory agreement from any successor to assume and perform this Plan, as contemplated by Section 10.11 hereof, or

(v) any other action or inaction that constitutes a material breach by the Company of this Plan with respect to such Participant,

(each of clauses (i) through (v), a “Good Reason Event”); provided, however, that in the case of any such termination of employment by the Participant under this subparagraph (b), such termination shall not be deemed to be a Qualifying Termination unless (x) Participant has notified the Company in writing describing the occurrence of one or more Good Reason Events within sixty (60) days of such occurrence, (y) the Company fails to cure such Good Reason Event within thirty (30) days after its receipt of such written notice and (z) the termination of employment occurs within one hundred twenty (120) days after the occurrence of the applicable Good Reason Event.

1.28. “SunCoke Energy, Inc.” shall mean SunCoke Energy, Inc., a Delaware corporation, and any successor thereto by merger, consolidation, liquidation or purchase of assets or stock or similar transaction.

ARTICLE II

BACKGROUND, PURPOSE AND TERM OF PLAN

2.1. Background. SunCoke Energy, Inc. maintains this Plan for the purpose of providing severance allowances to Participants whose employment is terminated in connection with or following a Change in Control. The Plan shall be effective as of July 27, 2011 (the “Effective Date”).

2.2. Purpose of the Plan. The Plan, as set forth herein, has been adopted by the Board of Directors, or a committee thereof, delegated such responsibility, acting in its sole discretion, in recognition that the possibility of a major transaction or a Change in Control exists and that such possibility, and the uncertainty and questions which it may raise among management, may result in the departure or distraction of key management personnel to the detriment of the Company. The Board of Directors has determined that appropriate steps should be taken to reinforce and encourage the continued attention and dedication of Participants, as key members of Company’s management, to their assigned duties without distraction.

2.3. Term of the Plan. The Plan will continue until such time as the Board of Directors, or a committee thereof, delegated such responsibility, acting in its sole discretion, elects to modify, supersede or terminate it; provided, however, that no such action taken after a Change in Control, or before, but in connection with, a Change in Control, may terminate or reduce the benefits or prospective benefits of any individual who is a Participant on the date of the action without the express written consent of the Participant.

ARTICLE III

PARTICIPATION AND ELIGIBILITY FOR BENEFITS

3.1. General Requirements. Participants shall be designated in accordance with Section 1.25. Except with respect to the benefits and payments under Section 4.6, in order to receive a Benefit under this Plan, a Participant’s employment must have been terminated as a result of a Qualifying Termination.

3.2. Qualifying Termination. The Committee shall determine whether any termination of a Participant is a Qualifying Termination. The Participant shall follow the procedures described in Article IX for presenting his or her claim for Benefits under this Plan.

ARTICLE IV

BENEFITS

4.1. Amount of Immediate Cash Benefit; Qualifying Termination. In the event of a termination of employment that would qualify the Participant for Benefits that is a Qualifying Termination, the cash amount to be paid to a Participant eligible to receive Benefits under Section 3.1 hereof shall be paid as provided in Section 5.1 hereof and shall equal the sum of the following:

(a) An amount equal to the Participant’s earned vacation (as determined under the Company’s applicable vacation policy as in effect at the time of the Change in Control) through his or her Employment Termination Date;

(b) for each Participant, Annual Compensation multiplied by two (2);

(c) In addition to the annual compensation benefit described in Section 4.1(b) hereof, a Participant in this Plan, who is also an “Eligible Employee” for purposes of the SunCoke Energy, Inc. Annual Incentive Plan, will be entitled to payment of the following amounts:

(i) Prior Year Bonus. Such Participant whose Employment Termination Date occurs prior to April 1 of a calendar year will be entitled to the annual cash bonus payable pursuant to the SunCoke Energy, Inc. Annual Incentive Plan for the prior year, but only to the extent not yet paid.

(ii) Pro-rated Current Year Bonus. Such Participant whose Employment Termination Date occurs between April 1 and December 31 of a calendar year will be entitled to a one-time portion of the current year target annual cash bonus for which the Participant is eligible pursuant to the SunCoke Energy, Inc. Annual Incentive Plan, pro-rated and adjusted for actual Company performance for the calendar year in which the Employment Termination Date occurs, in accordance with the terms and provisions of the SunCoke Energy, Inc. Annual Incentive Plan, based on such Participant’s salary or wages earned through the Employment Termination Date. Subject to Section 5.1 hereof, to the extent applicable, such prorated bonus will be paid on the customary payout date under the SunCoke Energy, Inc. Annual Incentive Plan.

4.2. Executive Severance Benefits. In the event that Benefits are paid under Section 4.1, the Participant shall continue to be entitled, through the end of his/her Benefit Extension Period, to those employee benefits, based upon the amount of coverage or benefits provided at the Change in Control, listed below:

(a) Death benefits in an amount equal to one (1) times the Participant’s annual base salary at the Employment Termination Date (provided, however, that any supplemental coverages elected under the SunCoke Energy, Inc. Death Benefits Plan (or any similar plan of any of the following: a subsidiary or affiliate which has adopted this Plan; a corporation succeeding to the business of SunCoke Energy, Inc.; and/or any subsidiary or affiliate, by merger, consolidation or liquidation or purchase of assets or stock or similar transaction) will be discontinued under the terms of such plan or plans); and

(b) Medical plan benefits (including dental coverage), with COBRA continuation eligibility beginning as of the end of the Benefit Extension Period.

In each case, when contributions are required of all Executive Resource Employees at the time of the Participant’s Employment Termination Date, or thereafter, if required of all other active Executive Resource Employees, the Participant shall continue to be responsible for making the required contributions during the Benefit Extension Period in order to be eligible for the coverage. The difference between the cost for such medical plan benefits under Code Section 4980B and the amount of the necessary contributions that a Participant is required to pay for such coverage as provided above will be paid by the Company and considered

imputed income to such Participant. Each Participant is responsible for the payment of income tax due as a result of such imputed income. Each Participant also shall be entitled to reasonable outplacement services during the Benefit Extension Period, at no cost to the Participant (but only to the extent such services are provided no later than the end of the second calendar year following the year of the Participant’s Employment Termination Date and are paid for directly by the Company no later than the end of the third calendar year following the year of the Participant’s Employment Termination Date), from an experienced third-party vendor selected by the Committee and consistent with vendors used in connection with the SunCoke Energy, Inc. Involuntary Termination Plan immediately before the Change in Control.

4.3. Retirement and Savings Plans. This Plan shall not govern and shall in no way affect the Participant’s interest in, or entitlement to benefits under, any of the Company’s “qualified” or supplemental retirement plans, and payments received under any such plans shall not affect a Participant’s right to any Benefit hereunder.

4.4. Relationship to Involuntary Plan. If a Participant becomes entitled to receive severance benefits under this Plan, the Participant shall not be entitled to any benefits under the Involuntary Plan.

4.5. Effect on Other Benefits. There shall not be drawn from the continued provision by the Company of any of the aforementioned Benefits any implication of continued employment or of continued right to accrual of retirement benefits under the Company’s qualified or supplemental retirement plans, nor shall a terminated employee, except as otherwise provided under the terms of the Plan, accrue vacation days, paid holidays, paid sick days or other similar benefits normally associated with employment for any part of the Benefit Extension Period during which benefits are payable under this Plan. A Participant shall have no duty to mitigate with respect to Benefits under this Plan by seeking or accepting alternative employment. Further, the amount of any payment or benefit provided for in this Plan shall not be reduced by any compensation earned by the Participant as the result of employment by another employer, by retirement benefits, by offset against any amount claimed to be owed by the Participant to the Company, or otherwise.

4.6. Legal Fees and Expenses. The Company also shall pay to the Participant (or the Participant’s representative) all legal fees and expenses incurred by or with respect to the Participant during his lifetime or within ten (ten) years after his death:

(a) in disputing in good faith any issue relating a Qualifying Termination entitling the Participant to Benefits under this Plan (including any good faith dispute regarding whether or not a Qualifying Termination has occurred); or

(b) in seeking in good faith to obtain or enforce any benefit or right provided by this Plan (or the payment of any Benefits through any trust established to fund Benefits under this Plan).

Such payments shall be made as such fees and expenses are incurred by the Participant (or the Participant’s representative), but in no event later than five (5) business days after delivery of the Participant’s (or Participant’s representative’s) written requests for payment accompanied with such evidence of fees and expenses incurred as the Company reasonably may require. Notwithstanding the foregoing sentence, all such payments shall be made on or before the close of the calendar year following the calendar year in which the expense was incurred. The amount of expenses eligible for reimbursement under this provision in one calendar year may not affect the amount of expenses eligible for reimbursement under this provision in any other calendar year. The Participant (or Participant’s representative) shall reimburse the Company for such fees and expenses at such time as a court of competent jurisdiction, or another independent third party having similar authority, determines that the Participant’s claim was frivolously brought without reasonable expectation of success on the merits thereof.

4. 7. Excise Tax Reduction. If in connection with the Change in Control (i) a Participant would be or is subject to an excise tax under Section 4999 of the Internal Revenue Code (an “Excise Tax”) with respect to the Benefits, or any other cash, benefits or other property received, or any acceleration of vesting of any benefit or award (the “Change in Control Benefits”), and (ii) the total net after-tax amount of the Participant's Change in Control Benefits (after taking into account federal, state and local income and employment taxes and the Excise Tax) is less than the pre-tax Change in Control Benefits reduced to the largest amount that would not trigger the imposition of such Excise Tax, then the Participant's Benefits shall be so reduced so that no Excise Tax is imposed.

Within 15 days after the Participant's termination of employment, a nationally recognized accounting firm selected by the Company shall make a determination as to whether any Excise Tax would be reported with respect to the Change in Control Benefits and, if so, the amount of the Excise Tax, the total net after-tax amount of the Change in Control Benefits (after taking into account federal, state and local income and employment taxes and the Excise Tax) and the amount of reduction to the Change in Control Benefits necessary to avoid such Excise Tax. The Participant shall determine the particular Change in Control Benefits to be reduced, and the Company shall provide the Participant with such information as is necessary to make such determination. The Company shall be responsible for all fees and expenses connected with the determinations by the accounting firm pursuant to this Section 4. 7. The Participant agrees to notify the Company in the event of any audit or other proceeding by the IRS or any taxing authority in which the IRS or other taxing authority asserts that any Excise Tax should be assessed against the Participant and to cooperate with the Company in contesting any such proposed assessment with respect to such Excise Tax.

ARTICLE V

METHOD AND DURATION OF BENEFIT PAYMENTS

5.1. Method of Payment. Subject to the last sentence of Section 5.1, the cash Benefits to which a Participant is entitled, as determined pursuant to Article IV hereof, shall be paid in a lump sum. Payment shall be made by mailing to the last address provided by the Participant to the Company. In general, subject to the last sentence of this Section 5.1, payment shall be made within fifteen (15) days after the Participant’s Employment Termination Date but in no event later than thirty (30) days thereafter; provided, however, that payment of any Benefits under any provision of the Plan that are deferred compensation for purposes of Code Section 409A to any Participant who is a specified employee determined in accordance with Code Section 409A (a “Specified Employee”) shall be paid in a lump sum on the later of the date such payments are due or the date that is six months after the Participant’s Employee Termination Date. In the event the Company should fail to pay when due the amounts described in Article IV (determined without regard to the payment delay to Specified Employees required by Code Section 409A), the Participant shall also be entitled to receive from the Company an amount representing interest on any unpaid or untimely amounts from the due date (determined without regard to the payment delay to Specified Employees required by Code Section 409A) to the date of payment at a rate equal to the prime rate of Citibank, N.A. as in effect from time to time after such due date. Notwithstanding anything to the contrary contained in this Plan, if (x) a Participant also participates in the Involuntary Plan and (y) the Change in Control does not constitute a “change in the ownership of the corporation,” a “change in effective control of the corporation” or a “change in the ownership of a substantial portion of the assets of the corporation” within the meaning of Section 409A(a)(2)(A)(v) of the Code, then payment of the cash Benefits provided under Section 4.1(b) of the Plan shall be made in equal monthly installments in accordance with Section 5.1 of the Involuntary Plan and during a number of months equal to the number of months that would apply to such Participant based on Section 1.5(b) of the Involuntary Plan.

5.2. Payments to Beneficiary(ies). Each Participant shall designate a beneficiary(ies) to receive any Benefits due hereunder in the event of the Participant’s death prior to the receipt of all such Benefits. Such beneficiary designation shall be made in the manner, and at the time, prescribed by the Company in its sole discretion. In the absence of an effective beneficiary designation hereunder, the Participant’s estate shall be deemed to be his or her designated beneficiary.

ARTICLE VI

ADMINISTRATION

6.1. Appointment of the Committee. The Committee shall consist of three (3) or more persons appointed by the Compensation Committee. Committee members may be, but need not be, employees of SunCoke Energy, Inc. Following a Change in Control, the individuals most recently so appointed to serve as members of the Committee before the Change in Control, or successors whom they approve, shall continue to serve as the Committee.

6.2. Tenure of the Committee. Before a Change in Control, Committee members shall serve at the pleasure of the Compensation Committee and may be discharged, with or without cause, by the Compensation Committee. Committee members may resign at any time on ten (10) days’ written notice.

6.3. Authority and Duties. It shall be the duty of the Committee, on the basis of information supplied to it by the Company, to determine the eligibility of each Participant for Benefits under the Plan, to determine the amount of Benefit to which each such Participant may be entitled, and to determine the manner and time of payment of the Benefit consistent with the provisions hereof. In addition, the exercise of discretion by the Committee need not be uniformly applied to similarly situated Participants. The Company shall make such payments as are certified to it by the Committee to be due to Participants. The Committee shall have the full power and authority to construe, interpret and administer the Plan, to correct deficiencies therein, and to supply omissions. Except as provided in Section 9.2, all decisions, actions and interpretations of the Committee shall be final, binding and conclusive upon the parties.

6.4. Action by the Committee. A majority of the members of the Committee shall constitute a quorum for the transaction of business at a meeting of the Committee. Any action of the Committee may be taken upon the affirmative vote of a majority of the members of the Committee at a meeting, or at the direction of the chairperson, without a meeting by mail, telegraph, telephone or electronic communication device; provided that all of the members of the Committee are informed of their right to vote on the matter before the Committee and of the outcome of the vote thereon.

6.5. Officers of the Committee. The Compensation Committee shall designate one of the members of the Committee to serve as chairperson thereof. The Compensation Committee shall also designate a person to serve as Secretary of the Committee, which person may be, but need not be, a member of the Committee.

6.6. Compensation of the Committee. Members of the Committee shall receive no compensation for their services as such. However, all reasonable expenses of the Committee shall be paid or reimbursed by the Company upon proper documentation. The Company shall indemnify members of the Committee against personal liability for actions taken in good faith in the discharge of their respective duties as members of the Committee and shall provide coverage to them under the Company’s Liability Insurance program(s).

6.7. Records, Reporting and Disclosure. The Committee shall keep all individual and group records relating to Participants and former Participants and all other records necessary for the proper operation of the Plan. Such records shall be made available to the Company and to each Participant for examination during business hours except that a Participant shall examine only such records as pertain exclusively to the

examining Participant and to the Plan. The Committee shall prepare and shall file as required by law or regulation, all reports, forms, documents and other items required by ERISA, the Internal Revenue Code, and every other relevant statute, each as amended, and all regulations thereunder (except that the Company, as payor of the Benefits, shall prepare and distribute to the proper recipients all forms relating to withholding of income or wage taxes, Social Security taxes, and other amounts which may be similarly reportable).

6.8. Actions of the Chief Executive Officer. Whenever a determination is required of the Chief Executive Officer under the Plan, such determination shall be made solely at the discretion of the Chief Executive Officer. In addition, the exercise of discretion by the Chief Executive Officer need not be uniformly applied to similarly situated Participants and shall be final and binding on each Participant or beneficiary(ies) to whom the determination is directed.

6.9. Bonding. The Committee shall arrange any bonding that may be required by law, but no amount in excess of the amount required by law (if any) shall be required by the Plan.

ARTICLE VII

AMENDMENT AND TERMINATION

7.1. Amendment, Suspension and Termination. The Company, acting through the Board of Directors, retains the right, at any time and from time to time, to amend, suspend or terminate the Plan in whole or in part, for any reason, and without either the consent of or the prior notification to any Participant. Notwithstanding the foregoing, no such action that is taken after a Change in Control or before, but in connection with, a Change in Control, may terminate or reduce the benefits or prospective benefits of any Participant on the date of such action without the express written consent of the Participant. No amendment, suspension or termination shall give the Company the right to recover any amount paid to a Participant prior to the date of such action or to cause the cessation and discontinuance of payments of Benefits to any person or persons under the Plan already receiving Benefits. The Board of Directors shall have the right to delegate its authority and powers hereunder, or any portion thereof, to any committee of the Board of Directors, and shall have the right to rescind any such delegation in whole or in part.

ARTICLE VIII

DUTIES OF THE COMPANY

8.1. Records. The Company shall supply to the Committee all records and information necessary to the performance of the Committee’s duties.

8.2. Payment. The Company shall make payments from its general assets to Participants and shall provide the Benefits described in Article IV hereof in accordance with the terms of the Plan, as directed by the Committee.

ARTICLE IX

CLAIMS PROCEDURES

9.1. Application for Benefits. Benefits shall be paid by the Company following an event that qualifies the Participant for Benefits. In the event a Participant believes himself/herself eligible for Benefits under this Plan and Benefit payments have not been initiated by the Company, the Participant may apply for such Benefits by requesting payment of Benefits in writing from the Committee.

9.2. Appeals of Denied Claims for Benefits. In the event that any claim for Benefits is denied in whole or in part, the Participant (or beneficiary, if applicable) whose claim has been so denied shall be notified of such denial in writing by the Committee, within thirty (30) days following submission by the Participant (or beneficiary, if applicable) of such claim to the Committee. The notice advising of the denial shall specify the reason or reasons for denial, make specific reference to pertinent Plan provisions, describe any additional material or information necessary for the claimant to perfect the claim (explaining why such material or information is needed), and shall advise the Participant of the procedure for the appeal of such denial. All appeals shall be made by the following procedure:

(a) The Participant whose claim has been denied shall file with the Committee a notice of desire to appeal the denial. Such notice shall be filed within sixty (60) days of notification by the Committee of the claim denial, shall be made in writing, and shall set forth all of the facts upon which the appeal is based. Appeals not timely filed shall be barred.

(b) The Committee shall, within thirty (30) days of receipt of the Participant’s notice of appeal, establish a hearing date on which the Participant may make an oral presentation to the Committee in support of his/her appeal. The Participant shall be given not less than ten (10) days’ notice of the date set for the hearing.

(c) The Committee shall consider the merits of the claimant’s written and oral presentations, the merits of any facts or evidence in support of the denial of benefits, and such other facts and circumstances as the Committee shall deem relevant. If the claimant elects not to make an oral presentation, such election shall not be deemed adverse to his/her interest, and the Committee shall proceed as set forth below as though an oral presentation of the contents of the claimant’s written presentation had been made.

(d) The Committee shall render a determination upon the appealed claim, within sixty (60) days of the hearing date, which determination shall be accompanied by a written statement as to the reasons therefor.

ARTICLE X

MISCELLANEOUS

10.1. Nonalienation of Benefits. None of the payments, benefits or rights of any Participant shall be subject to any claim of any creditor, and, in particular, to the fullest extent permitted by law, all such payments, benefits and rights shall be free from attachment, garnishment, trustee’s process, or any other legal or equitable process available to any creditor of such Participant. No Participant shall have the right to alienate, anticipate, commute, pledge, encumber or assign any of the benefits or payments which he/she may expect to receive, contingently or otherwise, under this Plan.

10.2. No Contract of Employment. Neither the establishment of the Plan, nor any modification thereof, nor the creation of any fund, trust or account, nor the payment of any benefits shall be construed as giving any Participant, or any person whosoever, the right to be retained in the service of the Company, and all Participants shall remain subject to discharge to the same extent as if the Plan had never been adopted.

10.3. Severability of Provisions. If any provision of this Plan shall be held invalid or unenforceable, such invalidity or unenforceability shall not affect any other provisions hereof, and this Plan shall be construed and enforced as if such provisions had not been included.

10.4. Successors, Heirs, Assigns, and Personal Representatives. This Plan shall be binding upon the heirs, executors, administrators, successors and assigns of the parties, including each Participant, present and future.

10.5. Headings and Captions. The headings and captions herein are provided for reference and convenience only, shall not be considered part of the Plan, and shall not be employed in the construction of the Plan.

10.6. Gender and Number. Except where otherwise clearly indicated by context, the masculine and the neuter shall include the feminine and the neuter, the singular shall include the plural, and vice-versa.

10.7. Unfunded Plan. The Plan shall not be funded. A Participant’s right to receive payment of Benefits hereunder shall be no greater than the right of any unsecured creditor of the Company. The Company may, but shall not be required to, set aside or earmark an amount necessary to provide the Benefits specified herein (including the establishment of trusts). In any event, no Participant shall have any right to, or interest in, any assets of the Company which may be applied by the Company to the payment of Benefits except as may be provided pursuant to the terms of any trust established by the Company to provide Benefits.

10.8. Payments to Incompetent Persons,Etc. Any Benefit payable to or for the benefit of a minor, an incompetent person or other person incapable of receipting therefor shall be deemed paid when paid to such person’s guardian or to the party providing or reasonably appearing to provide for the care of such person, and such payment shall fully discharge the Company, the Committee and all other parties with respect thereto.

10.9. Lost Payees. A Benefit shall be deemed forfeited if the Committee is unable to locate a Participant to whom a Benefit is due. Such Benefit shall be reinstated if application is made by the Participant for the forfeited Benefit while this Plan is in operation.

10.10. Controlling Law. This Plan shall be construed and enforced according to the laws of the State of Delaware to the extent not preempted by federal law.

10.11. Successor Employer. The Company shall require any successor or assignee, whether direct or indirect, by purchase, merger, consolidation or otherwise, to all or substantially all the business or assets of the Company, expressly and unconditionally to assume and agree to perform the Company’s obligations under this Plan, in the same manner and to the same extent that the Company would be required to perform if no such succession or assignment had taken place. In such event, the term “Company” shall mean the Company and any successor or assignee to the business or assets which by reason hereof becomes bound by the terms and provisions of this Plan.

10.12. Code Section 409A. This Plan is intended to comply with the requirements of Code Section 409A or an exemption or exclusion therefrom and, with respect to amounts that are subject to Code Section 409A, shall in all respects be administered in accordance with Code Section 409A. Each payment under this Plan shall be treated as a separate payment for purposes of Code Section 409A. In no event may a Participant, directly or indirectly, designate the calendar year of any payment to be made under this Agreement. Notwithstanding anything to the contrary in this Plan, all reimbursements and in-kind benefits provided under this Plan shall be made or provided in accordance with the requirements of Section 409A of the Code, including, where applicable, the requirement that:

(a) any reimbursement is for expenses incurred during the Participant’s lifetime (or during a shorter period of time specified in this Plan);

(b) the amount of expenses eligible for reimbursement, or in-kind benefits provided, during a calendar year may not affect the expenses eligible for reimbursement, or in-kind benefits to be provided, in any other calendar year, except, if such benefits consist of the reimbursement of expenses referred to in Section 105(b) of the Code, a maximum, if provided under the terms of the plan providing such medical benefit, may be imposed on the amount of such reimbursements over some or all of the period in which such benefit is to be provided to the Participant as described in Treasury Regulation Section 1.409A-3(i)(iv)(B);

(c) the reimbursement of an eligible expense will be made no later than the last day of the calendar year following the year in which the expense is incurred, provided that the Participant shall have submitted an invoice for such fees and expenses at least ten (10) days before the end of the calendar year next following the calendar year in which such fees and expenses were incurred; and

(d) the right to reimbursement or in-kind benefits is not subject to liquidation or exchange for another benefit.

EX-10.9

EXHIBIT 10.9

SUNCOKE ENERGY, INC.

EXECUTIVE INVOLUNTARY SEVERANCE PLAN

(Amended and Restated as of November 7, 2017)

SunCoke Energy, Inc.

Executive Involuntary Severance Plan

ARTICLE I

DEFINITIONS

1.1. “Benefit” or “Benefits” shall mean any or all of the benefits that a Participant is entitled to receive pursuant to Article IV of the Plan.

1.2. “Board of Directors” shall mean the Board of Directors of SunCoke Energy, Inc. or any successor thereto.

1.3. “Change in Control Benefits” shall have the meaning assigned to such term in Section 4.7 hereof.

1.4. “Chief Executive Officer” shall mean the individual serving as the Chief Executive Officer of SunCoke Energy, Inc. as of the Effective Date.

1.5. “Committee” shall mean the administrative committee designated pursuant to Article VI of the Plan to administer the Plan in accordance with its terms.

1.6. “Company” shall mean SunCoke Energy, Inc., a Delaware corporation. The term “Company” shall include any successor to SunCoke Energy, Inc., any subsidiary or affiliate which has adopted the Plan, or a corporation succeeding to the business of SunCoke Energy, Inc., or any subsidiary or affiliate, by merger, consolidation or liquidation or purchase of assets or stock or similar transaction.

1.7. “Company Service” shall mean, for purposes of determining Benefits available to any Participant in this Plan, the total aggregate recorded length of such Participant’s service with: SunCoke Energy, Inc.; any subsidiary or affiliate of SunCoke Energy, Inc. (whether by merger, consolidation or liquidation or purchase of assets or stock or similar transaction) which has adopted the Plan; and/or any corporation succeeding to the business of SunCoke Energy, Inc.

Company Service shall commence with the Participant’s initial date of employment with the Company, and shall end with such Participant’s death, retirement, or termination for any reason. Company Service also shall include:

(a) all periods of approved leave of absence (civil, family, medical, military, or Olympic); provided, however, that the Participant returns to work within the prescribed time following the leave;

(b) any break in service of thirty (30) days or less; and

(c) any service credited under applicable Company policies with respect to the length of a Participant’s employment by any non-affiliated entity that is subsequently acquired by, and becomes a part of, the Company’s operations.

1.8. “Compensation Committee” shall mean the Compensation Committee of the Board of Directors.

1.9. “Disability” shall mean any illness, injury or incapacity of such duration and type as to render a Participant eligible to receive long-term disability benefits under the applicable broad-based long-term disability program of the Company.

1.10 “Effective Date” shall have the meaning assigned to such term in Section 2.1 hereof.

1.11. “Employment Termination Date” shall mean the date on which a Participant separates from service as defined in Section 409A of the Internal Revenue Code of 1986, as amended (the “Code”) and the regulations issued thereunder.

1.12. “ERISA” shall mean the Employee Retirement Income Security Act of 1974, as amended.

1.13. “Excise Tax” shall have the meaning assigned to such term in Section 4.7 hereof.

1.14 “Just Cause” shall mean, as determined by the Committee:

(a) the willful and continued failure of the Participant to perform substantially the Participant’s duties with the Company (other than any such failure resulting from incapacity due to physical or mental illness), after a written demand for substantial performance is delivered to the Participant by the Board of Directors or the Chief Executive Officer that specifically identifies the manner in which the Board of Directors or the Chief Executive Officer believes that the Participant has not substantially performed the Participant’s duties,

(b) indictment of the Participant for a felony in connection with the Participant’s employment duties or responsibilities to the Company that is not quashed within six (6) months;

(c) conviction of Participant of a felony;

(d) willful conduct by the Participant in connection with the Participant’s employment duties or responsibilities to the Company that is gross misconduct (including, but not limited to, dishonest or fraudulent acts) and places the Company at risk of material injury; or

(e) the Participant’s failure to comply with a policy of the Company that places the Company at risk of material injury.

For purposes of this Section 1.11, no act, or failure to act, on the part of the Participant shall be considered “willful” unless it is done, or omitted to be done, by the Participant in bad faith or without reasonable belief that the Participant’s action or omission was in the best interests of the Company. In addition, for purposes of this Section 1.11, “injury” shall include, but not be limited to, financial injury and injury to the reputation of the Company. Any act, or failure to act, based upon authority given pursuant to a resolution duly adopted by the Board or upon the instructions of the Chief Executive Officer or a senior officer of the Company or based upon the advice of counsel for the Company shall be conclusively presumed to be done, or omitted to be done, by the Participant in good faith and in the best interests of the Company.

1.15. “Participant” shall mean any executive so designated by the Chief Executive Officer; provided, however, that any such executive who has an employment contract with the Company that provides severance benefits shall not be eligible to participate in the Plan while such contract is in effect except to the extent specifically provided in the contract.

1.16. “Plan” shall mean the SunCoke Energy, Inc. Executive Involuntary Severance Plan, as set forth herein, and as the same may from time to time be amended.

1.17. “Plan Year” shall mean each fiscal year of the Company during which this Plan is in effect.

1.18. “Salary Continuation Period” shall mean:

(a) six (6) weeks, in the case of a Participant who either has not executed the release described in Section 3.3 hereof, or who has revoked such a previously executed release; or

(b) in the case of a Participant who has executed and not revoked the release described in Section 3.3 hereof:

(i) seventy-eight (78) weeks for the Company’s Chief Executive Officer and each Senior Vice President of the Company; and

(iii) fifty-two (52) weeks for each other Participant.

1.19. “Special Executive Severance Plan” shall mean the SunCoke Energy, Inc. Special Executive Severance Plan

1.20. “Weekly Compensation” shall mean the sum of each of the following items divided by 52:

(a) a Participant’s annual base salary; and

(b) the applicable guideline (target) annual bonus amount in effect on his or her Employment Termination Date.

ARTICLE II

BACKGROUND, PURPOSE AND TERM OF PLAN

2.1. Background. The Company maintains this Plan for the purpose of providing severance allowances to all Participants, whose employment is terminated for reasons other than fault of their own. The Plan shall be effective as of July 27, 2011 (the “Effective Date”).

2.2. Purpose of the Plan. In recognition of their past service to the Company, this Plan is intended to alleviate, in part or in full, financial hardships which may be experienced by certain of those employees of the Company whose employment is terminated. In essence, benefits under the Plan are intended to be additional compensation for past services. The amount or kind of benefit to be provided is to be based on the position of the Participant and the Participant’s compensation at his or her Employment Termination Date.

2.3. Term of the Plan. The Plan will continue until such time as the Board of Directors, or a committee thereof, delegated such responsibility, acting in its sole discretion, elects to modify, supersede or terminate it in accordance with the further provisions hereof.

ARTICLE III

PARTICIPATION AND ELIGIBILITY FOR BENEFITS

3.1. General Eligibility Requirement. In order to receive a Benefit under this Plan, a Participant’s employment must have been terminated by the Company other than for Just Cause, death or Disability; provided, however, that any Participant who is receiving benefits under the Special Executive Severance Plan shall not also be eligible to receive any Benefit under this Plan.

3.2. Employment by Successor. Notwithstanding anything herein to the contrary, no Benefits shall be due hereunder in connection with the sale or other disposition by the Company of the capital stock or assets of any business unit, division, subsidiary, or other affiliate, if the Participant receives an offer of employment from the purchaser or other acquiror at a combined annual salary and guideline bonus at least

equal to the annual salary and guideline bonus for his or her position with the Company immediately prior to such sale or other disposition.

3.3. Release. Unless the Participant executes a full waiver and release of claims in a form satisfactory to the Company, and notwithstanding anything herein to the contrary as provided in Section 5.2, the Benefits provided hereunder in connection with a termination of employment shall be provided only for the Salary Continuation Period set forth in Section 1.18(a) of this Plan.

ARTICLE IV

BENEFIT

4.1. Amount of Immediate Cash Benefit. The immediate cash amount to be paid to a Participant eligible to receive Benefits under Section 3.1 hereof shall be paid in a lump sum and shall equal the Participant’s earned vacation (as determined under the Company’s applicable vacation policy as in effect on the Employment Termination Date) through the end of his or her Employment Termination Date.

4.2. Ongoing Benefits.

(a) Salary Continuation. A Participant who is eligible to receive Benefits under Section 3.1 shall continue to be entitled, through the end of his/her Salary Continuation Period to his/her Weekly Compensation as in effect on the Employment Termination Date.

(b) Bonus Available Under SunCoke Energy, Inc. Annual Incentive Plan: In addition to the salary continuation benefit described in Section 4.2(a) hereof, a Participant in this Plan, who is also an “Eligible Employee” for purposes of the SunCoke Energy, Inc. Annual Incentive Plan, will be entitled to payment of the following amounts:

(i) Prior Year Bonus. Such Participant whose Employment Termination Date occurs prior to April 1 of a calendar year will be entitled to the annual cash bonus payable pursuant to the SunCoke Energy, Inc. Annual Incentive Plan for the prior year, but only to the extent not yet paid.

(ii) Pro-rated Current Year Bonus. Such Participant whose Employment Termination Date occurs between April 1 and December 31 of a calendar year will be entitled to a one-time portion of the current year target annual cash bonus for which the Participant is eligible pursuant to the SunCoke Energy, Inc. Annual Incentive Plan, pro-rated and adjusted for actual Company performance for the calendar year in which the Employment Termination Date occurs, in accordance with the terms and provisions of the SunCoke Energy, Inc. Annual Incentive Plan, based on such Participant’s salary or wages earned through the Employment Termination Date. Subject to Section 5.1(b) hereof, to the extent applicable, such prorated bonus will be paid on the customary payout date under the SunCoke Energy, Inc. Annual Incentive Plan.

4.3. Executive Benefits. A Participant who is eligible to receive Benefits under Section 3.1 shall continue to be entitled, through the end of his/her Salary Continuation Period to those employee benefits listed below:

(a) death benefits in an amount equal to one (1) times the Participant’s annual base salary at the Employment Termination Date (provided, however, that any supplemental coverages elected under the SunCoke Energy, Inc. Death Benefits Plan (or any similar plan of any of the following: a subsidiary or affiliate which has adopted this Plan; a corporation succeeding to the business of SunCoke Energy, Inc.; and/or any subsidiary or affiliate, by

merger, consolidation or liquidation or any purchase of assets or stock or similar transaction) will be discontinued under the terms of such plan or plans); and

(b) medical plan benefits (excluding dental coverage), including COBRA continuation coverage beginning as of the start of the Salary Continuation Period and running concurrently therewith.

In each case, when contributions are required of all other active Participants at the time of the Participant’s Employment Termination Date, or thereafter, if required of other Participants, the Participant shall continue to be responsible for making the required contributions during the Salary Continuation Period in order to be eligible for the coverage. The difference between the cost for such medical plan benefits under Code Section 4980B and the amount of the necessary contributions that a Participant is required to pay for such coverage as provided above will be paid by the Company and considered imputed income to such Participant. Each Participant is responsible for the payment of income tax due as a result of such imputed income. The Participant also shall be entitled to reasonable outplacement services as deemed appropriate by the Committee (but only to the extent such services are provided no later than the end of the second calendar year following the year of the Participant’s Employment Termination Date and are paid for directly by the Company no later than the end of the third calendar year following the year of the Participant’s Employment Termination Date).

4.4. Retirement Plans. This Plan shall not govern and shall in no way affect the Participant’s interest in, or entitlement to benefits under, any of the Company’s qualified or supplemental retirement plans and any payments received under any such plan shall not affect a Participant’s right to any Benefit hereunder.

4.5. Minimum Benefit. Notwithstanding the provisions of Sections 4.2 and 4.3 hereof, the Benefits available under this Plan shall not be less than those determined in accordance with the provisions of the SunCoke Energy, Inc. Involuntary Termination Plan. If the Participant determines that the benefits under the SunCoke Energy, Inc. Involuntary Termination Plan are more valuable to the Participant than the comparable Benefits set forth in this Plan, then the provisions used to calculate the Benefits available to the Participant under this Plan shall not apply, and the Benefits available to the Participant under this Plan shall be calculated using only the applicable provisions of the SunCoke Energy, Inc. Involuntary Termination Plan. In all events, the timing of payment of benefits shall be determined in accordance with the terms of this Plan.

4.6. Effect on Other Benefits. There shall not be drawn from the continued provision by the Company of any of the aforementioned Benefits any implication of continued employment or of continued right to accrual of retirement benefits under the Company’s qualified or supplemental retirement plans, nor shall a Participant accrue vacation days, paid holidays, paid sick days or other similar benefits normally associated with employment for any part of the Salary Continuation Period during which benefits are payable under this Plan.

4.7. Excise Tax Reduction. If in connection with the Change in Control of the Company (as defined in the Special Executive Severance Plan) (i) a Participant would be or is subject to an excise tax under Section 4999 of the Internal Revenue Code (an "Excise Tax") with respect to the Benefits, or any other cash, benefits or other property received, or any acceleration of vesting of any benefit or award (the "Change in Control Benefits"), and (ii) the total net after-tax amount of the Participant's Change in Control Benefits (after taking into account federal, state and local income and employment taxes and the Excise Tax) is less than the pre-tax Change in Control Benefits reduced to the largest amount that would not trigger the imposition of such Excise Tax, then the Participant's Benefits shall be so reduced so that no Excise Tax is imposed. Within 15 days after the Participant's termination of employment, a nationally recognized accounting firm selected by the Company shall make a determination as to whether any Excise Tax would be reported with respect to the Change in Control Benefits and, if so, the amount of the Excise Tax, the total net after-tax amount of the

Change in Control Benefits (after taking into account federal, state and local income and employment taxes and the Excise Tax) and the amount of reduction to the Change in Control Benefits necessary to avoid such Excise Tax. The Participant shall determine the particular Change in Control Benefits to be reduced, and the Company shall provide the Participant with such information as is necessary to make such determination. The Company shall be responsible for all fees and expenses connected with the determinations by the accounting firm pursuant to this Section 4.7. The Participant agrees to notify the Company in the event of any audit or other proceeding by the IRS or any taxing authority in which the IRS or other taxing authority asserts that any Excise Tax should be assessed against the Participant and to cooperate with the Company in contesting any such proposed assessment with respect to such Excise Tax.

ARTICLE V

METHOD AND DURATION OF BENEFIT PAYMENTS

5.1. Method of Payment.

(a) The cash Benefits to which a Participant is entitled, as determined pursuant to Article IV hereof, shall be paid monthly except as otherwise provided in this Article V, and the Salary Continuation Period shall begin the first day of the month following the month in which the Employment Termination Date occurs. If a Participant becomes entitled to cash Benefits determined in accordance with Section 1.18(b), the number of equal monthly payments for such Participant shall be determined by dividing the applicable Salary Continuation Period by four and rounding up to the nearest whole number. Pursuant to Treasury Regulation Section 1.409A-2(b)(2)(iii), for purposes of Treasury Regulation 1.409A-1(b)(4) and all other provisions of the regulations promulgated under Code Section 409A, the Participant’s right to the series of monthly payments hereunder at all times shall be treated as a right to a series of separate payments. Payment shall be made by mailing to the last address provided by the Participant to the Company, or by direct deposit into a bank account designated by the Participant in writing to the Company.

(b) Payment of any cash Benefits (that are deferred compensation for purposes of Code Section 409A) to any Participant who is a specified employee under Section 409A of the Code shall be made as follows. Cash Benefits that are scheduled to be paid for the period which begins on such Participant’s Employment Termination Date and ends on the date six months from such Participant’s Employment Termination Date, shall not be paid as scheduled, but shall be accumulated and paid in a lump sum on the date six months after the Participant’s Employment Termination Date. Simple interest will be paid on cash Benefits delayed hereunder from the date such payments would have been made to the Participant but for this subsection (b), to the date of actual payment, at the interest rate equal to the prime rate of Citibank, N.A. as in effect from time to time after such due date.

5.2. Conditions to Entitlement to Benefit. In order to be eligible to receive full Benefits hereunder (other than Benefits pursuant to Section 1.18(a) or Section 4.1), a Participant shall make himself/herself available to the Company and cooperate in any reasonable manner (so as not to unreasonably interfere with subsequent employment) in providing assistance to the Company after his or her Employment Termination Date in conducting any matters which are pending at such time, and, as provided in Section 3.3, shall execute a release and discharge of the Company from any and all claims, demands or causes of action other than as to amounts or benefits due to the Participant under any plan, program or contract provided by, or entered into with, the Company. Such release and discharge shall be in such form as is prescribed by the Committee and shall be executed and delivered no later than the fiftieth (50th) day following the Participant’s Employment Termination Date. In the event that a Participant does not so execute and deliver such release, or in the event that the Participant revokes such release, the Company shall cease payment of any Benefits (other than

Benefits pursuant to Section 1.18(a) or Section 4.1) and the Participant shall repay any Benefits (other than Benefits pursuant to Section 1.18(a) or Section 4.1) previously provided to him or her. In addition, no Benefits due hereunder shall be paid to a Participant who is required by Company guidelines to execute an agreement governing the assignment of patents or the disclosure of confidential information unless an executed copy of such agreement is on file with the Company.

5.3. Payments to Beneficiary(ies). Each Participant shall designate a beneficiary(ies) to receive any Benefits due hereunder in the event of the Participant’s death prior to the receipt of all such Benefits. Such beneficiary designation shall be made in the manner, and at the time, prescribed by the Committee in its sole discretion. In the absence of an effective beneficiary designation hereunder, the Participant’s estate shall be deemed to be his or her designated beneficiary.

ARTICLE VI

ADMINISTRATION

6.1. Appointment of the Committee. The Committee shall consist of three (3) or more persons appointed by the Compensation Committee. Committee members may be, but need not be, employees of the Company.

6.2. Tenure of the Committee. Committee members shall serve at the pleasure of the Compensation Committee and may be discharged, with or without Cause, by the Compensation Committee. Committee members may resign at any time on ten (10) days’ written notice.

6.3. Authority and Duties. It shall be the duty of the Committee to determine the eligibility of each Participant for Benefits under the Plan, to determine the amount of Benefit to which each such Participant may be entitled, and to determine the manner and time of payment of the Benefit consistent with the provisions hereof. The Company shall make such payments as are certified to it by the Committee to be due to Participants. The Committee shall have the full power and authority to construe, interpret and administer the Plan, to correct deficiencies therein, to supply omissions and to make factual determinations. All decisions, actions and interpretations of the Committee shall be final, binding and conclusive upon the parties.

6.4. Action by the Committee. A majority of the members of the Committee shall constitute a quorum for the transaction of business at a meeting of the Committee. Any action of the Committee may be taken upon the affirmative vote of a majority of the members of the Committee at a meeting, or at the direction of the Chairperson, without a meeting by mail, telegraph, telephone or electronic communication device; provided that all of the members of the Committee are informed of their right to vote on the matter before the Committee and of the outcome of the vote thereon.

6.5. Officers of the Committee. The Compensation Committee shall designate one of the members of the Committee to serve as Chairperson thereof. The Compensation Committee shall also designate a person to serve as Secretary of the Committee, which person may be, but need not be, a member of the Committee.

6.6. Compensation of the Committee. Members of the Committee shall receive no compensation for their services as such. However, all reasonable expenses of the Committee shall be paid or reimbursed by the Company upon proper documentation. The Company shall indemnify members of the Committee against personal liability for actions taken in good faith in the discharge of their respective duties as members of the Committee and shall provide coverage to them under the Company’s liability insurance program(s).

6.7. Records, Reporting and Disclosure. The Committee shall keep all individual and group records relating to Participants and former Participants and all other records necessary for the proper operation of

the Plan. Such records shall be made available to the Company and to each Participant for examination during business hours except that a Participant shall examine only such records as pertain exclusively to the examining Participant and to the Plan. The Committee shall prepare and shall file as required by law or regulation all reports, forms, documents and other items required by ERISA, the Internal Revenue Code, and every other relevant statute, each as amended, and all regulations thereunder (except that the Company, as payor of the Benefits, shall prepare and distribute to the proper recipients all forms relating to withholding of income or wage taxes, Social Security taxes, and other amounts which may be similarly reportable).

6.8. Actions of the Chief Executive Officer or the Board of Directors. Whenever a determination is required of the Chief Executive Officer or the Board of Directors under the Plan, such determination shall be made solely at the discretion of the Chief Executive Officer or the Board of Directors, as applicable.

6.9. Bonding. The Committee shall arrange any bonding that may be required by law, but no amount in excess of the amount required by law (if any) shall be required by the Plan.

ARTICLE VII

AMENDMENT AND TERMINATION

7.1. Amendment, Suspension and Termination. The Company, acting by or pursuant to a resolution of the Board of Directors, or a committee thereof delegated such responsibility, retains the right, at any time and from time to time, to amend, suspend or terminate the Plan in whole or in part, for any reason, and without either the consent of or the prior notification to any Participant. No such amendment shall give the Company the right to recover any amount paid to a Participant prior to the date of such amendment or to cause the cessation and discontinuance of payments of Benefits to any person or persons under the Plan already receiving Benefits.

ARTICLE VIII

DUTIES OF THE COMPANY

8.1. Records. The Company shall supply to the Committee all records and information necessary to the performance of the Committee’s duties.

8.2. Payment. The Company shall make payments from its general assets to Participants, and shall provide the Benefits described in Article IV hereof in accordance with the terms of this Plan, as directed by the Committee.

ARTICLE IX

CLAIMS PROCEDURES

9.1. Application for Benefits. Benefits shall be paid by the Company following a termination of employment that qualifies the Participant for Benefits. In the event a Participant believes himself/herself eligible for Benefits under this Plan and Benefit payments have not been initiated by the Company, the Participant may apply for such Benefits by requesting payment of Benefits in writing from the Company.

9.2. Appeals of Denied Claims for Benefits. In the event that any claim for benefits is denied in whole or in part, the Participant (or beneficiary, if applicable) whose claim has been so denied shall be notified of such denial in writing by the Committee, within ninety (90) days following submission by the Participant (or beneficiary, if applicable) of such claim to the Committee (unless the Committee determines that special circumstances require an extension of time for processing the claim, in which case (i) the Committee shall

notify in writing the Participant of the extension, the reasons therefor and the expected determination date and (ii) such extension shall not exceed the amount permitted by applicable law or regulation). The notice advising of the denial shall specify the reason or reasons for denial, make specific reference to pertinent Plan provisions, describe any additional material or information necessary for the claimant to perfect the claim (explaining why such material or information is needed), and shall advise the Participant of the procedure for the appeal of such denial. All appeals shall be made by the following procedure:

(a) The Participant whose claim has been denied shall file with the Committee a notice of desire to appeal the denial. Such notice shall be filed within sixty (60) days of notification by the Committee of the claim denial, shall be made in writing, and shall set forth all of the facts upon which the appeal is based. Appeals not timely filed shall be barred.

(b) The Committee shall consider the merits of the claimant’s written presentation, the merits of any facts or evidence in support of the denial of benefits, and such other facts and circumstances as the Committee shall deem relevant.

(c) The Committee shall render a determination upon the appealed claim, within sixty (60) days of the Committee’s receipt of the Participant’s notice of appeal (unless the Committee determines that special circumstances require an extension of time for processing the claim, in which case (i) the Committee shall notify in writing the Participant of the extension, the reasons therefor and the expected determination date and (ii) such extension shall not exceed the amount permitted by applicable law or regulation), which determination shall be accompanied by a written statement as to the reasons therefor. The determination so rendered shall be binding upon all parties and shall not be overturned unless such determination was an abuse of discretion and/or violated the highest applicable legal standard.

ARTICLE X

MISCELLANEOUS

10.1. Non-alienation of Benefits. None of the payments, benefits or rights of any Participant shall be subject to any claim of any creditor, and, in particular, to the fullest extent permitted by law, all such payments, benefits and rights shall be free from attachment, garnishment, trustee’s process, or any other legal or equitable process available to any creditor of such Participant. No Participant shall have the right to alienate, anticipate, commute, pledge, encumber or assign any of the benefits or payments which he/she may expect to receive, contingently or otherwise, under this Plan.

10.2. No Contract of Employment. Neither the establishment of the Plan, nor any modification thereof, nor the creation of any fund, trust or account, nor the payment of any Benefits shall be construed as giving any Participant, or any person whosoever, the right to be retained in the service of the Company, and all Participants shall remain subject to discharge to the same extent as if the Plan had never been adopted.

10.3. Severability of Provisions. If any provision of this Plan shall be held invalid or unenforceable, such invalidity or unenforceability shall not affect any other provisions hereof, and this Plan shall be construed and enforced as if such provisions had not been included.

10.4. Successors, Heirs, Assigns, and Personal Representatives. This Plan shall be binding upon the heirs, executors, administrators, successors and assigns of the parties, including each Participant, present and future. Unless the Chief Executive Officer directs otherwise, the Company shall require any successor or successors (whether direct or indirect, by purchase, merger, consolidation or otherwise) to all or substantially all of the business and/or assets of the Company, or a division thereof, to acknowledge expressly that this Agreement is binding upon and enforceable against the Company in accordance with the terms hereof, and

to become jointly and severally obligated with the Company to perform this Agreement in the same manner and to the same extent that the Company would be required to perform if no such succession or successions had taken place.

10.5. Headings and Captions. The headings and captions herein are provided for reference and convenience only, shall not be considered part of the Plan, and shall not be employed in the construction of the Plan.

10.6. Gender and Number. Except where otherwise clearly indicated by context, the masculine and the neuter shall include the feminine and the neuter, the singular shall include the plural, and vice-versa.

10.7. Unfunded Plan. The Plan shall not be funded. The Company may, but shall not be required to, set aside or earmark an amount necessary to provide the Benefits specified herein (including the establishment of trusts). In any event, no Participant shall have any right to, or interest in, any assets of the Company which may be applied by the Company to the payment of Benefits.

10.8. Payments to Incompetent Persons,Etc. Any Benefit payable to or for the benefit of a minor, an incompetent person or other person incapable of receipting therefor shall be deemed paid when paid to such person’s guardian or to the party providing or reasonably appearing to provide for the care of such person, and such payment shall fully discharge the Company, the Committee and all other parties with respect thereto.

10.9. Lost Payees. A Benefit shall be deemed forfeited if the Committee is unable to locate a Participant to whom a Benefit is due. Such Benefit shall be reinstated if application is made by the Participant for the forfeited Benefit while this Plan is in operation.

10.10. Controlling Law. This Plan shall be construed and enforced according to the laws of the State of Delaware to the extent not preempted by Federal law.

10.11. Code Section 409A. This Plan is intended to comply with the requirements of Code Section 409A or an exemption or exclusion therefrom and, with respect to amounts that are subject to Code Section 409A, shall in all respects be administered in accordance with Code Section 409A. Each payment under this Plan shall be treated as a separate payment for purposes of Code Section 409A. In no event may a Participant, directly or indirectly, designate the calendar year of any payment to be made under this Agreement. Notwithstanding anything to the contrary in this Plan, all reimbursements and in-kind benefits provided under this Plan shall be made or provided in accordance with the requirements of Section 409A of the Code, including, where applicable, the requirement that:

(a) any reimbursement is for expenses incurred during the Participant’s lifetime (or during a shorter period of time specified in this Plan);

(b) the amount of expenses eligible for reimbursement, or in-kind benefits provided, during a calendar year may not affect the expenses eligible for reimbursement, or in-kind benefits to be provided, in any other calendar year, except, if such benefits consist of the reimbursement of expenses referred to in Section 105(b) of the Code, a maximum, if provided under the terms of the plan providing such medical benefit, may be imposed on the amount of such reimbursements over some or all of the period in which such benefit is to be provided to the Participant as described in Treasury Regulation Section 1.409A-3(i)(iv)(B);

(c) the reimbursement of an eligible expense will be made no later than the last day of the calendar year following the year in which the expense is incurred, provided that the Participant shall

have submitted an invoice for such fees and expenses at least ten (10) days before the end of the calendar year next following the calendar year in which such fees and expenses were incurred; and

(d) the right to reimbursement or in-kind benefits is not subject to liquidation or exchange for another benefit.

EX-12.1

Exhibit 12.1

CONSOLIDATED RATIO OF EARNINGS TO FIXED CHARGES
Computation of Ratios of Earnings to Fixed Charges
Exhibit 12.1
	Year ended December 31,
	2017		2016			2015		2014			2013
	(Dollars in millions, except ratios)
Earnings:
Income before income taxes	$	21.9	$	68.1		$	23.1	$	(125.6	)	$	84.2
Fixed charges	65.2		61.7			63.5		69.2			55.8
Amortization of capitalized interest	1.9		1.4			1.1		1.0			0.9
Less:
Capitalized interest	(1.1)		(5.0		)	(3.7)		(3.2)			(1.0)
Noncontrolling interest in pre-tax loss (income) loss of subsidiaries that have not incurred fixed charges	18.9		(45.1)			(32.3)		(24.3)			(25.1)
Adjusted earnings	$	106.8	$	81.1		$	51.7	$	(82.9	)	$	114.8
Fixed Charges:
Interest cost - affiliate	$	—	$	—		$	—	$	—		$	—
Interest cost	62.4		58.8			60.7		66.6			53.7
Interest portion of rent expense*	2.8		2.9			2.8		2.6			2.1
Total fixed charges	$	65.2	$	61.7		$	63.5	$	69.2		$	55.8
Ratios of earnings to fixed charges	1.6		1.3			†		**			2.1
*Represents one-third of the total operating lease rental expense, which is that portion deemed to be interest.
**Earnings for the year ended December 31, 2014 were inadequate to cover fixed charges by $152.1 million.
†Earnings for the year ended December 31, 2015 were inadequate to cover fixed charges by $11.8 million.

EX-21.1

Exhibit 21.1

SunCoke Energy, Inc.

Subsidiaries of the Registrant

Company Name: Registration

The Claymont Investment Company LLC        DE

SunCoke Technology and Development LLC        DE

—Sun Coke East Servicios de Coquelificaçäo Ltda. (1%)    Brazil

Sun Coke International, Inc.        DE

—Sun Coke East Servicios de Coquelificaçäo Ltda. (99%)    Brazil

—Sun Coke Europe Holding B.V.            Netherlands

——SunCoke India Private Limited (99%)        India

——VISA SunCoke Limited (49%)            India

—SunCoke India Private Limited (1%)        India

Sun Coal & Coke LLC        IN

—Indiana Harbor Coke Corporation        DE

——Indiana Harbor Coke Company L.P. (84.2%)        DE

—Indiana Harbor Coke Company        DE

____Indiana Harbor Coke Company L.P. (1%)        DE

—Gateway Energy & Coke Company, LLC (2%)        DE

—Haverhill Coke Company LLC (2%)        DE

—Middletown Coke Company, LLC (2%)        DE

—SunCoke Energy South Shore, LLC        DE

—Elk River Minerals Corporation        VA

—Jewell Coke Acquisition Company        DE

____Jewell Coke Company, L.P. (2%)        DE

—SunCoke Domestic Finance Corp.        DE

—SunCoke Energy Partners GP LLC        DE

——SunCoke Energy Partners, L.P. (2%)        DE

—SunCoke Energy Partners, L.P. (59.9%)        DE

——SunCoke Energy Partners Finance Corp.        DE

——Haverhill Coke Company LLC (98%)        DE

——FF Farms Holdings LLC             DE

______Haverhill Cogeneration Company LLC        DE

——Middletown Coke Company, LLC (98%)        DE

———Middletown Cogeneration Company LLC        DE

——Gateway Energy & Coke Company, LLC (98%)    DE

________Gateway Cogeneration Company LLC        DE

____SunCoke Logistics LLC        DE

Exhibit 21.1

________SunCoke Lake Terminal LLC        DE

________Kanawha River Terminals LLC        DE

__________Marigold Dock, Inc.        DE

__________Ceredo Liquid Terminal LLC        DE

________Raven Energy LLC        DE

__________Jacobs Materials Handling LLC        DE

Jewell Resources Corporation        VA

—Jewell Coke Company, L.P. (98%)        VA

—Jewell Smokeless Coal Corporation        VA

—Jewell Coal & Coke Company, Inc.            VA

—Dismal River Terminal, LLC        DE

—Oakwood Red Ash Coal Corporation        VA

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, 333-179804 and 333-176403) 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, 2018, with respect to the consolidated balance sheets of SunCoke Energy, Inc. as of December 31, 2017 and 2016, and the related consolidated statements of operations, comprehensive income (loss), equity, and cash flows for each of the years in the three-year period ended December 31, 2017, and the related notes (collectively, the “consolidated financial statements”), and the effectiveness of internal control over financial reporting as of December 31, 2017, which reports appear in the December 31, 2017 annual report on Form 10‑K of SunCoke Energy, Inc.

/s/ KPMG LLP

Chicago, Illinois

February 15, 2018

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, 2017 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 2018.

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, 2017 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 2018.

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, 2017 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 2018.

Signature:	/s/ Katherine T. Gates
Name:	Katherine T. Gates
Title:	Senior Vice President, General Counsel, and Chief Compliance 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, 2017 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 2018.

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, 2017 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 2018.

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, 2017 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 2018.

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, 2017 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 2018.

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, 2017 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 2018.

Signature:	/s/ Andrew D. Africk
Name:	Andrew D. Africk
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, 2017 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 2018.

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, 2017 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 2018.

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, 2017 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 2018.

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, 2017 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, 2018

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, 2017 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, 2018

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, 2017, 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, 2017 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, 2017 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, 2018

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, 2017, 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, 2017 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, 2017 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, 2018

EX-95.1

Exhibit 95.1

SunCoke Energy, Inc.

Mine Safety Disclosures for the Period Ended December 31, 2017

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 believe that we employ industry best practices and conduct routine training programs, and we also focus additional effort and resources each day and each shift to help ensure that our employees are focused on safety. Furthermore, we employ a structured safety and environmental process that provides a robust framework for managing, monitoring and improving safety and environmental performance.

We have consistently operated our metallurgical coke operations within or near 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	$	464	0	no	no	n/a	n/a	n/a
4406716/Central Shop	0	0	0	0	0	$	0	0	no	no	n/a	n/a	n/a
4407058/Heavy Equipment	0	0	0	0	0	$	—	0	no	no	n/a	n/a	n/a
Total	0	0	0	0	0	$	464	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. In the fourth quarter of fiscal year 2017, MSHA informed us that as of April 10, 2017, the MSHA ID# 4406716 associated with our Central Shop has been transitioned to the status of “Abandoned and Sealed”. Therefore, as of such date, MHSA no longer exercises jurisdiction over the Central Shop.

(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 quarter ended December 31, 2017 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, 2017.

(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, 2017. 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, 2017.

(11) The legal proceedings which remain pending before the FMSHRC as of December 31, 2017 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 (#)
4406499/Dominion 7	n/a	n/a	0	0	0	0
4406718/Dominion 26	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, 2017. The number of “initiated legal actions” reported here may not have remained pending as of December 31, 2017.

(13) This number reflects legal proceedings before the FMSHRC that were resolved during the year ended December 31, 2017.

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Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2017	Feb. 09, 2018	Jun. 30, 2017
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	Accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2017
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Common Stock, Shares Outstanding		64,542,973
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 694,796,596

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Consolidated Statements of Operations - USD ($) shares in Millions, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Revenues
Sales and other operating revenue									$ 1,331.5	$ 1,223.3	$ 1,362.7
Costs and operating expenses
Cost of products sold and operating expenses									1,020.8	906.5	1,098.4
Selling, general and administrative expenses									79.6	91.3	75.4
Depreciation and amortization expense									128.2	114.2	109.1
Loss on divestiture of business and impairments									0.0	14.7	0.0
Total costs and operating expenses									1,228.6	1,126.7	1,282.9
Operating income									102.9	96.6	79.8
Interest expense, net									60.6	53.5	56.2
Loss (gain) on extinguishment of debt, net			$ 20.2						20.4	(25.0)	0.5
Income before income tax (benefit) expense and loss from equity method investment									21.9	68.1	23.1
Income tax (benefit) expense									(81.6)	8.6	(8.8)
Loss from equity method investment									0.0	0.0	21.6
Net income	$ 173.9	$ 18.8	(31.5)	$ (57.7)	$ 31.5	$ 14.4	$ 1.0	$ 12.6	103.5	59.5	10.3
Less: Net (loss) income attributable to noncontrolling interests	39.9	7.2	(7.3)	(58.7)	14.5	8.3	5.6	16.7	(18.9)	45.1	32.3
Net income (loss) attributable to SunCoke Energy, Inc.	$ 134.0	$ 11.6	$ (24.2)	$ 1.0	$ 17.0	$ 6.1	$ (4.6)	$ (4.1)	$ 122.4	$ 14.4	$ (22.0)
Earnings (loss) attributable to SunCoke Energy, Inc. per common share:
Basic (in dollars per share)	$ 2.08	$ 0.18	$ (0.38)	$ 0.02	$ 0.26	$ 0.10	$ (0.07)	$ (0.06)	$ 1.90	$ 0.22	$ (0.34)
Diluted (in dollars per share)	$ 2.05	$ 0.18	$ (0.38)	$ 0.02	$ 0.26	$ 0.10	$ (0.07)	$ (0.06)	$ 1.88	$ 0.22	$ (0.34)
Weighted average number of common shares outstanding:
Basic (in shares)									64.3	64.2	65.0
Diluted (in shares)									65.2	64.4	65.0

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Consolidated Statements of Comprehensive Income (Loss) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Statement of Comprehensive Income [Abstract]
Net income	$ 173.9	$ 18.8	$ (31.5)	$ (57.7)	$ 31.5	$ 14.4	$ 1.0	$ 12.6	$ 103.5	$ 59.5	$ 10.3
Other comprehensive income (loss):
Reclassifications of actuarial loss amortization, prior service benefit, curtailment gain and settlement loss to earnings (net of related tax expense of zero, zero and $3.4 million, respectively)									0.2	0.0	5.2
Retirement benefit plans funded status adjustment (net of related tax benefit of $0.3 million, $0.1 million and $0.1 million, respectively)									(0.8)	(0.2)	(0.4)
Currency translation adjustment									(0.5)	1.0	(3.1)
Comprehensive income									102.4	60.3	12.0
Less: Comprehensive (loss) income attributable to noncontrolling interests									(18.9)	45.1	32.3
Comprehensive income (loss) attributable to SunCoke Energy, Inc.									$ 121.3	$ 15.2	$ (20.3)

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Consolidated Statements of Comprehensive Income (Loss) (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
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	$ (3.4)
Retirement expense (benefit) plans funded status adjustment, tax	$ (0.3)	$ (0.1)	$ (0.1)

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Consolidated Balance Sheets - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Assets
Cash and cash equivalents	$ 120.2	$ 134.0
Receivables	68.5	60.7
Receivable from redemption of Brazilian investment	0.0	20.5
Inventories	111.0	92.5
Income tax receivable	4.8	4.6
Other current assets	6.7	3.8
Total current assets	311.2	316.1
Properties, plants and equipment (net of accumulated depreciation of $733.2 million and $625.9 million at December 31, 2017 and 2016, respectively)	1,501.3	1,542.6
Goodwill	76.9	76.9
Other intangible assets, net	167.9	179.0
Deferred charges and other assets	2.8	6.3
Total assets	2,060.1	2,120.9
Liabilities and Equity
Accounts payable	115.5	98.6
Accrued liabilities	53.2	49.8
Deferred revenue	1.7	2.5
Current portion of long-term debt and financing obligation	2.6	4.9
Interest payable	5.4	16.2
Total current liabilities	178.4	172.0
Long-term debt and financing obligation	861.1	849.2
Accrual for black lung benefits	44.9	45.4
Retirement benefit liabilities	28.2	29.0
Deferred income taxes	257.8	352.5
Asset retirement obligations	14.0	13.9
Other deferred credits and liabilities	16.1	19.0
Total liabilities	1,400.5	1,481.0
Equity
Preferred stock, $0.01 par value. Authorized 50,000,000 shares; no issued shares at December 31, 2017 and 2016	0.0	0.0
Common stock, $0.01 par value. Authorized 300,000,000 shares; issued 72,006,905 shares and 71,707,304 shares at December 31, 2017 and 2016, respectively	0.7	0.7
Treasury stock, 7,477,657 shares at December 31, 2017 and 2016, respectively	(140.7)	(140.7)
Additional paid-in capital	486.2	492.1
Accumulated other comprehensive loss	(20.1)	(19.0)
Retained earnings (deficit)	100.1	(22.0)
Total SunCoke Energy, Inc. stockholders' equity	426.2	311.1
Noncontrolling interests	233.4	328.8
Total equity	659.6	639.9
Total liabilities and equity	$ 2,060.1	$ 2,120.9

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Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Statement of Financial Position [Abstract]
Accumulated depreciation	$ 733.2	$ 625.9
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)	72,006,905	71,707,304
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, 2017	Dec. 31, 2016	Dec. 31, 2015
Cash Flows from Operating Activities:
Net income	$ 103.5	$ 59.5	$ 10.3
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	128.2	114.2	109.1
Deferred income tax (benefit) expense	(87.2)	3.1	(5.6)
Gain on curtailment and payments in excess of expense for postretirement plan benefits	(1.8)	(2.6)	(8.0)
Settlement loss and payments in excess of expense for pension plan	0.0	0.0	13.1
Share-based compensation expense	4.8	6.5	7.2
Loss (gain) on extinguishment of debt, net	20.4	(25.0)	0.5
Loss on divestiture of business and impairments	0.0	14.7	0.0
Loss from equity method investment	0.0	0.0	21.6
Changes in working capital pertaining to operating activities (net of the effects of divestiture and acquisition):
Receivables	(7.8)	3.7	18.8
Inventories	(18.5)	29.4	23.2
Accounts payable	11.7	(0.8)	(17.9)
Accrued liabilities	2.6	6.8	(24.3)
Deferred revenue	(0.8)	0.4	(4.4)
Interest payable	(10.8)	(2.7)	(1.0)
Income taxes	(0.2)	7.0	(5.6)
Other	4.4	4.9	4.1
Net cash provided by operating activities	148.5	219.1	141.1
Cash Flows from Investing Activities:
Capital expenditures	(75.6)	(63.7)	(75.8)
Decrease (increase) in restricted cash	0.5	17.7	(17.7)
Return of Brazilian investment	20.5	20.5	0.0
Divestiture of coal business	0.0	(12.8)	0.0
Acquisition of businesses, net of cash received	0.0	0.0	(191.7)
Other investing activities	0.0	2.1	0.0
Net cash used in investing activities	(54.6)	(36.2)	(285.2)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt	693.7	0.0	260.8
Repayment of long-term debt	(644.9)	(66.1)	(248.1)
Debt issuance costs	(17.4)	(0.2)	(5.7)
Proceeds from revolving facility	350.0	28.0	292.4
Repayment of revolving facility	(392.0)	(98.4)	(50.0)
Proceeds from financing obligation	0.0	16.2	0.0
Repayment of financing obligation	(2.5)	(1.0)	0.0
Cash distributions to noncontrolling interests	(47.0)	(49.4)	(43.3)
Dividends paid	0.0	0.0	(28.0)
Acquisition of additional interest in the Partnership	(48.7)	0.0	0.0
Shares repurchased	0.0	0.0	(35.7)
SunCoke Energy Partners, L.P. units repurchased	0.0	0.0	(12.8)
Other financing activities	1.1	(1.4)	(1.1)
Net cash (used in) provided by financing activities	(107.7)	(172.3)	128.5
Net (decrease) increase in cash and cash equivalents	(13.8)	10.6	(15.6)
Cash and cash equivalents at beginning of year	134.0	123.4	139.0
Cash and cash equivalents at end of year	120.2	134.0	123.4
Supplemental Disclosure of Cash Flow Information
Interest paid	69.0	58.4	58.1
Income taxes paid, net of refunds of $1.0 million, $8.2 million and $1.5 million, respectively	$ 5.8	$ (2.3)	$ 2.4

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Consolidated Statements of Cash Flows (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Statement of Cash Flows [Abstract]
Tax refunds	$ 1.0	$ 8.2	$ 1.5

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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, 2014	$ 705.4	$ 0.7	$ (105.0)	$ 543.6	$ (21.5)	$ 13.9	$ 431.7	$ 273.7
Beginning balance, shares at Dec. 31, 2014		71,251,529	4,977,115
Stockholders' Equity
Net income	10.3					(22.0)	(22.0)	32.3
Reclassifications of prior service cost and actuarial loss amortization to earnings (net of related tax expense of $3.4 million)	5.2				5.2		5.2
Retirement benefit plans funded status adjustment (net of related tax benefit of $0.3 million, $0.1 million and $0.1 million, respectively)	(0.4)				(0.4)		(0.4)
Currency translation adjustment	(3.1)				(3.1)		(3.1)
Adjustments from changes in ownership of SunCoke Energy Partners, L.P.	75.0			(8.0)			(8.0)	83.0
Deferred taxes related to basis difference in the Partnership	(55.6)			(55.6)			(55.6)
Cash distributions to noncontrolling interests	(43.3)							(43.3)
Dividends	(28.3)					(28.3)	(28.3)
Share-based compensation expense	7.2			7.2			7.2
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		237,919
Shares repurchased	(35.7)		$ (35.7)				(35.7)
Shares repurchased, shares			2,500,542
Acquisition of additional interest in the Partnership:
Partnership unit repurchases and cash paid	(12.8)							(12.8)
Ending balance, shares at Dec. 31, 2015		71,489,448	7,477,657
Ending balance at Dec. 31, 2015	622.8	$ 0.7	$ (140.7)	486.1	(19.8)	(36.4)	289.9	332.9
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 $0.3 million, $0.1 million and $0.1 million, respectively)	(0.2)				(0.2)		(0.2)
Currency translation adjustment	1.0				1.0		1.0
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	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
Acquisition of additional interest in the Partnership:
Cumulative effect from adoption of ASU 2016-09	0.0			0.3		(0.3)
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 $0.3 million, $0.1 million and $0.1 million, respectively)	(0.8)				(0.8)		(0.8)
Currency translation adjustment	(0.5)				(0.5)		(0.5)
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
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	72,006,905	7,477,657
Ending balance at Dec. 31, 2017	$ 659.6	$ 0.7	$ (140.7)	$ 486.2	$ (20.1)	$ 100.1	$ 426.2	$ 233.4

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Consolidated Statements of Equity (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Statement of Stockholders' Equity [Abstract]
Net of related tax benefit, reclassifications of prior service benefit and actuarial loss amortization to earnings	$ 0.0	$ 0.0	$ 3.4
Retirement expense (benefit) plans funded status adjustment, tax	$ (0.3)	$ (0.1)	$ (0.1)

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General and Basis of Presentation

12 Months Ended

Dec. 31, 2017

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,” “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 approximately 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. We also hold a 49 percent investment in a cokemaking joint venture with VISA Steel Limited in India ("VISA SunCoke"), which was fully impaired in 2015, and consequently, beginning in the fourth quarter of 2015, we no longer include our share of VISA SunCoke in our financial results.

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.

We previously controlled coal mining operations in Virginia and West Virginia until April 2016 when the Company completed the disposal of its coal mining business to Revelation Energy, LLC ("Revelation"). 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, 2017, we owned the general partner of the Partnership, which consists of a 2.0 percent ownership interest and incentive distribution rights ("IDRs"), and a 59.9 percent limited partner interest in the Partnership. The remaining 38.1 percent interest in the Partnership was held by public unitholders.

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, 2017

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 Note 18.

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. Revenues related to the sale of products are recognized when title passes, generally when products are shipped or delivered in accordance with the terms of the respective sales agreements. Service revenues are recognized when services are provided as defined by customer contracts. Revenues are not recognized until sales prices are fixed or determinable and collectability is reasonably assured. Licensing fees, which include an annual fixed fee and a fee determined on a per ton basis, are recognized when earned in accordance with the contract terms.

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 combined sales and other operating revenues for each of the years ended December 31, 2017, 2016 and 2015.

The Partnership receives payment for shortfall obligations on certain Logistics take-or-pay contracts. The payments in excess of services performed are recorded in deferred revenue on the Consolidated Balance Sheets. Deferred revenue on take-or-pay contracts is generally billed quarterly and recognized as income at the earlier of when service is provided or annually based on the terms of the contract.

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 Operations. 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 capitalized interest of $1.1 million, $5.0 million and $3.7 million in 2017, 2016 and 2015, 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.

Cash flows at our Indiana Harbor facility were negative during 2017, driven by the oven rebuild project implemented to address coke oven degradation. Based on these results, we performed an impairment test in 2017 and concluded that our projected undiscounted cash flows associated with the facility were approximately 45 percent, or substantially in excess, of the carrying value of our long-lived assets at Indiana Harbor. However, we continue to closely monitor our performance at Indiana Harbor, and if our coke oven rebuild project does not stabilize production or if the project costs are significantly higher than expected, our current conclusion as to recoverability of assets at that location could change.

See Note 17 for discussion of impairments recorded during prior years.

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.

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.

There were no impairments of goodwill or other intangible assets during the periods presented. See Note 8 for further discussion on the Partnership's Logistics goodwill impairment test.

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. With the redemption of the Brazil Investment, the Company no longer receives the $9.5 million annual preferred dividend on its Brazil Investment from ArcelorMittal Brazil, included in sales and other operating revenue on the Consolidated Statement of Operations in 2015. 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 Statement of Operations.

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 for discussion of the impacts of the Tax Cuts and Jobs Act (“Tax Legislation”), which was enacted on December 22, 2017.

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. There were no uncertain tax positions at December 31, 2017, and 2016. 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 selling, general and administrative expenses on the Consolidated Statement of Operations. 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 Operations and are generally passed through to our customers.

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 and India joint venture are the Brazilian real and Indian rupee, respectively. The Company’s foreign operations translate their 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 and are included in our Consolidated Statements of Operations. The Company did not incur any material foreign currency transaction gains or losses during the periods presented.

Recently Issued Pronouncements

In May 2014, Financial Accounting Standards Board ("FASB") 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. Subsequently, the FASB has issued various ASUs to provide further clarification around certain aspects of ASC 606. This standard will be effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period, and early adoption was permitted on a limited basis. We have substantially completed our analysis of the new standard and do not expect a material change in our revenue recognition model on an annual basis. Deferred revenue at CMT may be recognized on a more accelerated basis during quarterly periods within the year based on facts and circumstances considered at each quarter under the new guidance. The Company will adopt this standard on January 1, 2018 using the modified retrospective method.

In February 2016, the FASB issued ASU 2016-02, "Leases (Topic 842)." ASU 2016-02 requires lessees to recognize assets and liabilities on the balance sheet for the rights and obligations created by all leases with terms of more than 12 months. It 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 is in the process of analyzing the impacts to our business, including the development of new accounting processes to account for our leases and support the required disclosures. While we are still evaluating the impact of adopting this standard, we expect that upon adoption the right-of-use assets and lease liabilities, such as various plant equipment rentals and the lease of our corporate office space, will increase the reported assets and liabilities on our Consolidated Balance Sheets. We are currently evaluating technology tools to assist with the accounting and reporting requirements of this standard. The Company expects to adopt this standard on January 1, 2019 and is currently evaluating our transition method options.

Labor Concentrations

As of December 31, 2017, we have approximately 909 employees in the U.S. Approximately 39 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 2018, at which time the collective bargaining process will resume. We do not anticipate any work stoppages during the extended period of the agreement. In 2017, we reached a new three-year agreement for our Granite City location, which will expire on August 31, 2020.

As of December 31, 2017, we have approximately 270 employees at the cokemaking facility in Vitória, Brazil, all of whom are represented by a union under a labor agreement. In 2017, we reached a new one-year labor agreement at our Vitoria, Brazil facility which will expire on October 31, 2018. We will negotiate the renewal of this agreement in 2018 and do not anticipate any work stoppages.

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Acquisitions and Dropdown Transactions

12 Months Ended

Dec. 31, 2017

Business Combinations [Abstract]

Acquisitions and Dropdown Transactions

3. Acquisitions and Dropdown Transactions

Acquisition of Partnership Common Units

In April 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 $50.0 million. In July 2017, the Company's Board of Directors authorized the Company to purchase an incremental $50.0 millionof Partnership common units in the open market. During 2017, the Company purchased 2,853,032 of outstanding Partnership common units in the open market for total cash payments of $48.7 million, which increased our limited partner interest in the Partnership from53.9 percent to 59.9 percent at December 31, 2017. This resulted in a decrease in noncontrolling interest of$29.6 million during 2017 on the Consolidated Balance Sheets related to the Partnership's net book value acquired by the Company. The Company decreased its additional paid-in capital balance by $12.0 million on the Consolidated Balance Sheets for the consideration paid in excess of the net book value of the noncontrolling interest acquired, net of a deferred tax adjustment of $7.1 million during 2017.

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

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

Subsequent to December 31, 2017, the Company purchased an additional 132,188 of outstanding Partnership common units in the open market for total cash payments of $2.3 million, leaving a remaining common unit purchase program balance of $49.0 million as of February 15, 2018.

Convent Marine Terminal Acquisition

On August 12, 2015, the Partnership completed the acquisition of a 100 percent ownership interest in Raven Energy LLC, which owns Convent Marine Terminal ("CMT"), for a total transaction value of $403.1 million. The transaction value included $191.7 million in cash paid by the Partnership, 4.8 million common units issued with an aggregate value of $75.0 million to The Cline Group, $114.9 million of debt assumed and $21.5 million of cash withheld to fund capital expenditures.

The results of CMT have been included in the consolidated financial statements since the date of acquisition and are reported in the Logistics segment. CMT contributed revenues of $71.1 million, $62.7 million and $28.6 million, as well as operating income of $42.3 million, $46.5 million and $18.4 million during 2017, 2016 and 2015, respectively.

 The following combined and consolidated results of operations were prepared using historical financial information of CMT and assumes that the acquisition of CMT occurred on January 1, 2015:

	Years Ended December 31,
	2017		2016		2015
	(Audited)				(Unaudited pro forma)
	(Dollars in millions)
Total revenues	$	1,331.5	$	1,223.3	$	1,395.4
Net income	$	103.5	$	59.5	$	9.7
Net income (loss) attributable to SunCoke Energy, Inc.	$	122.4	$	14.4	$	(22.3	)
Earnings (loss) attributable to SunCoke Energy, Inc. per common share:
Basic	$	1.90	$	0.22	$	(0.34	)
Diluted	$	1.88	$	0.22	$	(0.34	)

The unaudited pro forma combined results of operations reflect historical results adjusted for interest expense, depreciation adjustments based on the fair value of acquired property, plant and equipment, amortization of acquired identifiable intangible assets, and income tax expense. The pro forma combined results do not include acquisition costs or new contracts. The unaudited pro forma combined and consolidated financial statements are presented for informational purposes only and do not necessarily reflect future results given the timing of new customer contracts, revenue recognition related to take-or-pay shortfalls, and other effects of integration, nor do they purport to be indicative of the results of operations that actually would have resulted had the acquisition of CMT occurred on January 1, 2015 or future results.

Granite City Dropdowns

On January 13, 2015, the Company contributed a 75 percent interest in its Granite City cokemaking facility to the Partnership for a total transaction value of $244.4 million (the "Granite City Dropdown"). The transaction value included $148.3 million of debt and other liabilities assumed by the Partnership, $50.1 million of Partnership common units issued, $1.0 million of general partner interest issued to the Partnership's general partner and $45.0 million of cash withheld to pre-fund our obligation to the Partnership for the anticipated costs of an environmental remediation project at Granite City. Subsequent to the Granite City Dropdown, we continued to own the general partner of the Partnership, which owns a 2 percent general partners interest and IDRs, and a 56.1 percent limited partner interest in the Partnership. The remaining 41.9 percent limited partner interest in the Partnership was held by public unitholders and was reflected as a noncontrolling interest in the consolidated financial statements.

On August 12, 2015, the Company contributed an additional 23 percent interest in Granite City to the Partnership for a total transaction value of $65.2 million (the "Granite City Supplemental Dropdown"). The transaction value included $46.9 million of debt and other liabilities assumed by the Partnership, $17.9 million of Partnership common units issued and $0.4 million of general partner interest issued to the Partnership's general partner. Subsequent to the Granite City Supplemental Dropdown and the units issued in connection with the acquisition of CMT, we continue to own the general partner of the Partnership, which owns a 2 percent general partner interest and IDRs, and owned a 53.4 percent limited partner interest in the Partnership. The remaining 44.6 percent limited partner interest in the Partnership was held by public unitholders and was reflected as a noncontrolling interest in the consolidated financial statements.

We accounted for the Granite City Dropdown and Granite City Supplemental Dropdown as equity transactions, which resulted in an increase in noncontrolling interest and a decrease in SunCoke Energy's equity of $6.5 million and $1.5 million, respectively, representing the Partnership's common public unitholders' share of the book value of ownership interest received of $114.7 million, net of their share of the transaction value of $106.7 million.

The table below summarizes the effects of the changes in the Company’s ownership interest in Granite City on SunCoke’s equity:

	Year Ended December 31, 2015
	(Dollars in millions)
Net loss attributable to SunCoke Energy, Inc.	$	(22.0	)
Decrease in SunCoke Energy, Inc. equity for the contribution of 75 percent interest in Granite City	(6.5		)
Decrease in SunCoke Energy, Inc. for the contribution of an additional 23 percent interest in Granite City	(1.5		)
Change from net loss attributable to SunCoke Energy, Inc. and dropdown transactions	$	(30.0	)

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Customer Concentrations

12 Months Ended

Dec. 31, 2017

Risks and Uncertainties [Abstract]

Customer Concentrations

4. Customer Concentrations

In 2017, 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 a Brazilian subsidiary of ArcelorMittal S.A., where we operate a cokemaking facility, ArcelorMittal Brasil S.A. ("ArcelorMittal Brazil”).

The table below shows sales to the Company's significant customers for the years ended December 31, 2017, 2016 and 2015:

	Years ended December 31,
	2017				2016				2015
	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)	$	678.2	50.9	%	$	596.6	48.8	%	$	671.8	49.3	%
AK Steel(2)	$	331.3	24.9	%	$	350.0	28.6	%	$	395.4	29.0	%
U.S. Steel(3)	$	214.1	16.1	%	$	185.3	15.1	%	$	212.7	15.6	%

(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.

Since 2015, AK Steel has kept its Ashland Kentucky Works facility idled and U.S. Steel has kept portions of its Granite City Works facility idled. These temporary idlings do not change any obligations that AK Steel and/or U.S. Steel have under their long-term, take-or-pay contracts with us.

The Company generally does not require any collateral with respect to its receivables. At both December 31, 2017 and 2016, 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 three significant customers as of December 31, 2017 and 2016:

	December 31,
	2017		2016
	(Dollars in millions)
AM USA and ArcelorMittal Brazil(1)	$	25.7	$	47.7
AK Steel	$	13.2	$	10.7
U.S. Steel	$	5.6	$	5.7

(1) The 2016 receivables due include the $20.5 million receivable recorded as redemption of Brazil investment on the Consolidated Balance Sheets and was collected in 2017.

Our Logistics segment provides coal handling and storage services to Murray American Coal, Inc. ("Murray") and Foresight Energy LLC ("Foresight"), who are the two primary customers in the Logistics segment and related parties of The Cline Group, a beneficial owner of the Partnership. Sales to Foresight and Murray accounted for $57.8 million, or 4.3 percent, and $53.5 million, or 4.4 percent and $22.0 million, or 1.6 percent of the Company's sales and other operating revenue and were recorded in the Logistics segment for the years ended December 31, 2017, 2016 and 2015, respectively, representing 49.4 percent, 49.6 percent and 27.1 percent of Logistics revenue, including intersegment sales, in 2017, 2016 and 2015, respectively. Receivables from Murray and Foresight were $9.7 million and $8.0 million and were recorded in receivables on the Consolidated Balance Sheets at December 31, 2017 and 2016, respectively.

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Income Taxes

12 Months Ended

Dec. 31, 2017

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,
	2017		2016		2015
	(Dollars in millions)
Domestic	$	4.3	$	52.5	$	8.6
Foreign	17.6		15.6		14.5
Total	$	21.9	$	68.1	$	23.1

The components of income tax (benefit) expense are as follows:

	Years Ended December 31,
	2017			2016			2015
	(Dollars in millions)
Income taxes currently payable (receivable):
U.S. federal	$	1.7		$	2.7		$	(3.1	)
State	(1.0		)	(2.2		)	(3.3		)
Foreign	4.9			5.0			3.2
Total taxes currently payable (receivable)	5.6			5.5			(3.2		)
Deferred tax (benefit) expense:
U.S. federal	(99.7		)	(1.5		)	(12.7		)
State	12.5			4.6			7.1
Total deferred tax (benefit) expense	(87.2		)	3.1			(5.6		)
Total	$	(81.6	)	$	8.6		$	(8.8	)

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

	Years Ended December 31,
	2017					2016					2015
	(Dollars in millions)
Income tax expense at 35 percent U.S. statutory rate	$	7.7		35.0	%	$	23.8		35.0	%	$	8.0		35.0	%
Increase (reduction) in income taxes resulting from:
Impact of Final Regulations(1)	64.2			293.2	%	—			—	%	—			—	%
Impact of Tax Legislation(2)	(154.7		)	(706.4	)%	—			—	%	—			—	%
Income attributable to noncontrolling interests in partnerships(3)	(5.4		)	(24.7	)%	(15.6		)	(23.0	)%	(11.2		)	(48.3	)%
State and other income taxes, net of federal income tax effects	2.0			9.1	%	1.1			1.7	%	1.8			7.7	%
Change in valuation allowance(4)(5)	3.9			17.8	%	0.4			0.6	%	(8.8		)	(38.0	)%
Investment in subsidiary(5)	—			—	%	—			—	%	1.0			4.4	%
Other	0.7			3.2	%	(1.1		)	(1.6	)%	0.4			1.2	%
Income tax (benefit) expense at effective tax rate	$	(81.6	)	(372.8	)%	$	8.6		12.7	%	$	(8.8	)	(38.0	)%

(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. 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 revises 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 provides 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 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 impact resulting from the remeasurement of U.S. deferred income tax liabilities and assets at the lower enacted corporate tax rates. Based on information currently available, the Company has recorded a provisional income tax expense of $14.3 million for a valuation allowance against $19.0 million of foreign tax credit carryforwards that the Company believes will not be realized prior to their expiration as a result of the Tax Legislation. The final impact of the Tax Legislation may differ from the estimate recorded this period, possibly materially, due to changes in interpretations and assumptions the Company has made, guidance that may be issued and actions the Company may take as a result of the Tax Legislation.

(3) Excludes the 2017 impact of the Final Regulations on qualifying income discussed above. No income tax expense is reflected in the Consolidated Statements of Operations 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.

(5) On December 22, 2014, SunCoke executed a definitive agreement to sell 100 percent of its interest in the entities that made up the Harold Keene Coal Companies. This required SunCoke to record a deferred tax asset of $11.9 million related to the outside basis difference on the Harold Keene investment. This deferred tax asset was offset by a $9.8 million valuation allowance. SunCoke canceled the definitive agreement during the third quarter of 2015. Due to the cancellation of the agreement, the deferred tax asset and the valuation allowance recorded during 2014 were reversed during 2015. The reversal of the deferred tax asset during 2015 was largely offset by a related current income tax deduction due to the determination of insolvency of the subsidiary, resulting in the net income tax benefit of $1.0 million in the investment in subsidiary line. The actual sale of the coal business, which was completed in the second quarter of 2016, had no material impact on the effective tax rate.

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

	December 31,
	2017			2016
	(Dollars in millions)
Deferred tax assets:
Retirement benefit liabilities	$	7.1		$	12.2
Black lung benefit liabilities	11.6			18.9
Share-based compensation	6.1			8.6
Federal tax credit carryforward(1)	23.2			23.2
Foreign tax credit carryforward(2)	19.0			14.0
Federal net operating loss	2.5			17.2
State tax credit carryforward, net of federal income tax effects(3)	4.0			5.5
State net operating loss carryforward, net of federal income tax effects(4)	13.9			8.4
Other liabilities not yet deductible	4.3			7.8
Total deferred tax assets	91.7			115.8
Less valuation allowance(5)	(26.2		)	(5.9		)
Deferred tax asset, net	65.5			109.9
Deferred tax liabilities:
Properties, plants and equipment(6)	(114.9		)	(0.3		)
Investment in partnerships(6)	(208.4		)	(462.1		)
Total deferred tax liabilities	(323.3		)	(462.4		)
Net deferred tax liability	$	(257.8	)	$	(352.5	)

(1) Federal tax credit carryforward expires in 2032 through 2033.

(2) Foreign tax credit carryforward expires in 2022 through 2027.

(3) State tax credit carryforward, net of federal income tax effects expires in 2017 through 2022.

(4) State net operating loss carryforward, net of federal income tax effects expires in 2017 through 2035.

(5) Primarily related to state tax credit carryforward and the $14.3 million allowance against the foreign tax credit carryforward as a result of the Tax Legislation in 2017.

(6) As a result of the Final Regulations discussed above, deferred tax liabilities associated with properties, plants and equipment increased and investment in partnerships decreased.

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, 2014 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, 2017 and 2016, and there were no interest or penalties recognized during the years ended December 31, 2017, 2016 and 2015. 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, 2017

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,
	2017		2016
	(Dollars in millions)
Coal	$	61.4	$	49.4
Coke	12.3		7.7
Materials, supplies and other	37.3		35.4
Total inventories	$	111.0	$	92.5

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Properties, Plants, and Equipment, Net

12 Months Ended

Dec. 31, 2017

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,
	2017			2016
	(Dollars in millions)
Coke and energy plant, machinery and equipment(1)	$	1,812.0		$	1,767.1
Logistics plant, machinery and equipment	216.2			214.4
Land and land improvements	118.7			118.7
Construction-in-progress	51.9			33.4
Other	35.7			34.9
Gross investment, at cost	2,234.5			2,168.5
Less: Accumulated depreciation(2)	(733.2		)	(625.9		)
Total properties, plants and equipment, net	$	1,501.3		$	1,542.6

(1) Includes assets, consisting mainly of coke and energy plant, machinery and equipment, with a gross investment totaling $1,337.3 million and $1,281.5 million and accumulated depreciation of $475.8 million and $410.4 million at December 31, 2017 and December 31, 2016, respectively, which are subject to long-term contracts to sell coke and are deemed to contain operating leases.

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Goodwill and Other Intangible Assets

12 Months Ended

Dec. 31, 2017

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill and Other Intangible Assets

8. Goodwill and Other Intangible Assets

Goodwill allocated to SunCoke's reportable segments as of December 31, 2017 and 2016 and changes in the carrying amount of goodwill during the fiscal year ended December 31, 2016 are shown below. There were no changes in the carrying amount of goodwill during the fiscal year ended December 31, 2017:

	Domestic Coke		Logistics		Total
	(Dollars in millions)
Net balance at December 31, 2015	$	3.4	$	67.7	$	71.1
Adjustments(1)	—		5.8		5.8
Net balance at December 31, 2016 and 2017	$	3.4	$	73.5	$	76.9

(1) During 2016, the Partnership recorded an adjustment to correct an error in the acquisition date fair value of the contingent consideration liability, which increased the contingent consideration liability and goodwill balance by $6.4 million. See Note 17. Additionally, a working capital adjustment to the acquisition date fair value of the acquired net assets decreased the amount of the purchase price allocated to goodwill by $0.6 million.

The Company performed its annual goodwill impairment test as of October 1, 2017, 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 25 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. To the extent changes in factors or circumstances occur that impact our future cash flow projections, such as a loss of either Murray or Foresight as customers, significant reductions in volume or pricing beyond our existing contract term or lower incremental merchant business, future assessments of goodwill and intangible assets may result in material impairment charges.

The following table summarizes the components of gross and net intangible asset balances as of December 31, 2017 and December 31, 2016:

		December 31, 2017						December 31, 2016
	Weighted - Average Remaining Amortization Years	Gross Carrying Amount		Accumulated Amortization		Net		Gross Carrying Amount		Accumulated Amortization		Net
		(Dollars in millions)
Customer contracts	5	$	31.7	$	13.8	$	17.9	$	31.7	$	9.9	$	21.8
Customer relationships	14	28.7		5.7		23.0		28.7		3.8		24.9
Permits	25	139.0		12.2		126.8		139.0		7.1		131.9
Trade name	1	1.2		1.0		0.2		1.2		0.8		0.4
Total		$	200.6	$	32.7	$	167.9	$	200.6	$	21.6	$	179.0

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 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 3.4 years.

Total amortization expense for intangible assets subject to amortization was $11.1 million, $11.2 million and $5.1 million for the years ended December 31, 2017, 2016 and 2015, respectively. Based on the carrying value of finite-lived intangible assets as of December 31, 2017, we estimate amortization expense for each of the next five years as follows:

	(Dollars in millions)
2018	$	11.0
2019	10.9
2020	10.7
2021	10.3
2022	10.3
Thereafter	114.7
Total	$	167.9

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Asset Retirement Obligations

12 Months Ended

Dec. 31, 2017

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, 2015	$	22.2
Liabilities settled	(0.7		)
Accretion expense(1)	1.1
Disposal of coal mining liabilities(2)	(9.4		)
Revisions in estimated cash flows	0.7
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

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

(2) In 2016, the Company completed the disposal of its coal mining business to Revelation who assumed a substantial portion of our mining reclamation obligations.

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Retirement Benefits Plans

12 Months Ended

Dec. 31, 2017

Retirement Benefits [Abstract]

Retirement Benefits Plans

10. Retirement Benefits Plans

Defined Benefit Pension Plan and Postretirement Health Care and Life Insurance Plans

The Company had a noncontributory defined benefit pension plan (“defined benefit plan”), which provided retirement benefits for certain of its employees. Effective January 1, 2011, pension benefits under the Company’s defined benefit plan were frozen for all participants in this plan. Effective May 30, 2014, Dominion Coal Corporation, a wholly-owned subsidiary of the Company, terminated its defined benefit plan, a plan that was previously offered generally to all full-time employees of Dominion Coal Corporation. Subsequently, the Company obtained IRS approval for the plan termination and executed an agreement with a high-quality insurance company to annuitize the pension plan using plan assets. As a result of the termination of the Dominion Coal defined benefit plan, each participant became fully vested in his or her benefits thereunder without regard to age and years of service.

As a result of the pension termination, unrecognized losses, which previously were recorded in accumulated other comprehensive loss on the Consolidated Balance Sheets, were recognized as expense. The net settlement loss of $12.6 million was recorded in cost of products sold and operating expenses on the Consolidated Statements of Operations during 2015. At December 31, 2017 and 2016, there are no remaining benefit obligations or plan assets related to the defined benefit pension plan.

The Company also 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. Employer costs for all those still eligible for such benefits were capped. The termination of coal mining employees triggered a curtailment gain of $4.1 million in 2015, respectively, which represented accelerated amortization of prior service credits previously recorded in accumulated other comprehensive income.

Defined benefit plan expense consisted of the following components:

	Years Ended December 31,
	2017		2016		2015
	(Dollars in millions)
Interest cost on benefit obligations	$	—	$	—	$	0.7
Expected return on plan assets	—		—		(0.7		)
Settlement loss	—		—		12.6
Amortization of:
Actuarial losses	—		—		0.5
Total expense	$	—	$	—	$	13.1

Postretirement benefit plans expense (benefit) consisted of the following components:

	Years Ended December 31,
	2017			2016			2015
	(Dollars in millions)
Interest cost on benefit obligations	$	1.1		$	1.3		$	1.3
Amortization of:
Actuarial losses	0.9			0.7			0.8
Prior service benefit	(0.7		)	(0.7		)	(1.2		)
Curtailment gain	—			—			(4.1		)
Total expense (benefit)	$	1.3		$	1.3		$	(3.2	)

Amortization of actuarial losses and prior service benefit for 2018 is estimated to be $0.6 million and $0.7 million, respectively, for the postretirement benefit plans.

Postretirement benefit plans expense (benefit) 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 (benefit):

	Postretirement Benefit Plans
	2017		2016		2015
Discount Rate	3.65	%	3.80	%	3.45	%

The following amounts were recognized as components of other comprehensive income (loss) before related tax impacts for the years ended December 31, 2017, 2016 and 2015:

	Years Ended December 31,
	Defined Benefit Plan						Postretirement Benefit Plans
	2017		2016		2015		2017			2016			2015
	(Dollars in millions)
Reclassifications to earnings of:
Actuarial loss amortization	$	—	$	—	$	0.5	$	0.9		$	0.7		$	0.8
Prior service benefit amortization	—		—		—		(0.7		)	(0.7		)	(1.2		)
Curtailment gain	—		—		—		—			—			(4.1		)
Settlement loss	—		—		12.6		—			—			—
Retirement benefit plan funded status    adjustments:
Actuarial gains (losses)	—		—		0.9		(1.1		)	(1.8		)	(1.4		)
Prior service (cost) benefit(1)	—		—		—		—			1.5			—
	$	—	$	—	$	14.0	$	(0.9	)	$	(0.3	)	$	(5.9	)

(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 will provide a subsidy to these participants of $3,600 per participant per 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 during 2017 and 2016:

	Postretirement Benefit Plans
	2017			2016
	(Dollars in millions)
Benefit obligation at beginning of year	$	32.3		$	34.8
Interest cost	1.1			1.3
Actuarial losses	1.1			1.8
Plan amendments(1)	—			(1.5		)
Benefits paid	(3.2		)	(4.1		)
Benefit obligation at end of year(2)	$	31.3		$	32.3

(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 will provide a subsidy to these participants of $3,600 per participant per year. The plan change resulted in a decrease in the benefit obligation of $1.5 million during 2016.

(2) Represents retirement benefit liabilities, including current portion, on the Consolidated Balance Sheets. The current portion of retirement liabilities, which totaled $3.1 million and $3.3 million at December 31, 2017 and 2016, 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 (loss) at December 31, 2017 and 2016:

	Postretirement Benefit Plans
	2017			2016
	(Dollars in millions)
Cumulative amounts not yet recognized in net income:
Actuarial losses	$	11.8		$	11.6
Prior service benefits	(3.4		)	(4.1		)
Accumulated other comprehensive loss (before related tax benefit)	$	8.4		$	7.5

The expected benefit payments through 2026 for the postretirement benefit plan are as follows:

	Postretirement Benefit Plans
	(Dollars in millions)
Year ending December 31:
2018	$	3.1
2019	3.0
2020	2.9
2021	2.8
2022	2.6
2023 through 2026	10.1

The measurement date for the Company’s postretirement benefit plans is December 31. The following discount rates were used to determine the benefit obligation at December 31, 2017 and 2016, respectively (in percentages):

	Postretirement Benefit Plans
	2017		2016
Discount rate	3.35	%	3.65	%

The health care cost trend assumption used at December 31, 2017, to compute the accumulated postretirement benefit obligation for the postretirement benefit plans was 6.50 percent (6.50 percent at December 31, 2016), which is assumed to decline gradually to 5.00 percent in 2025 and to remain at that level thereafter. A one-percentage point change each year in assumed health care cost trend rates would have an impact of less than $0.1 million on the total of service and interest cost components of postretirement benefits expense and the accumulated postretirement benefit obligation as of December 31, 2017 and 2016.

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 $6.4 million, $5.6 million and $6.5 million for the years ended December 31, 2017, 2016 and 2015, respectively.

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Accrued Liabilities

12 Months Ended

Dec. 31, 2017

Balance Sheet Related Disclosures [Abstract]

Accrued Liabilities

11. Accrued Liabilities

Accrued liabilities consist of following:

	December 31,
	2017		2016
	(Dollars in millions)
Accrued benefits	$	21.3	$	21.4
Current portion of postretirement benefit obligation	3.1		3.3
Other taxes payable	10.5		10.4
Current portion of black lung liability	5.4		4.8
Accrued legal	5.6		4.4
Other	7.3		5.5
Total accrued liabilities	$	53.2	$	49.8

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Debt and Financing Obligation

12 Months Ended

Dec. 31, 2017

Debt Disclosure [Abstract]

Debt and Financing Obligation

12. Debt and Financing Obligation

Total debt consisted of the following:

	December 31,
	2017			2016
	(Dollars in millions)
7.500 percent senior notes, due 2025 ("2025 Partnership Notes")	$	700.0		$	—
7.375 percent senior notes, due 2020 (''2020 Partnership Notes'')	—			463.0
7.625 percent senior notes, due 2019 ("2019 Notes")	44.6			44.6
Partnership's term loan, due 2019 ("Partnership Term Loan")	—			50.0
SunCoke's revolving credit facility, due 2022 ("Revolving Facility")	—			—
Partnership's revolving credit facility, due 2022 and 2019, respectively ("Partnership Revolver")	130.0			172.0
Partnership's promissory note payable, due 2021 ("Promissory Note")	—			113.2
5.82 percent financing obligation, due 2021 ("Partnership Financing Obligation")	12.7			15.2
Total borrowings	$	887.3		$	858.0
(Discount) premium	(5.9		)	7.5
Debt issuance costs	(17.7		)	(11.4		)
Total debt and financing obligation	$	863.7		$	854.1
Less: current portion of long-term debt and financing obligation	2.6			4.9
Total long-term debt and financing obligation	$	861.1		$	849.2

Issuance of 2025 Partnership Notes

The Partnership issued $630.0 million aggregate principal amount of senior notes in May 2017 and an additional $70.0 million aggregate principal amount of senior notes in December 2017 with an interest rate of 7.5 percent due in May 2025. The Partnership received proceeds of $693.7 million, net of a net discount of $6.3 million during 2017. The Partnership incurred debt issuance costs related to this transaction of $12.9 million. The 2025 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 2025 Partnership Notes is payable semi-annually in cash in arrears on June 15 and December 15 of each year, which commenced on December 15, 2017.

The Partnership may redeem some or all of the 2025 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 2025 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 2025 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 2025 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 2025 Partnership Notes contains 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.

Purchase, Redemption and Repayment of Partnership Debt

During 2017, the Partnership used the proceeds from the issuance of the 2025 Partnership Notes to purchase and redeem all of its 2020 Partnership Notes, including principal of $463.0 million and a premium of $18.7 million, repay the $50.0 million outstanding on the Partnership Term Loan, repay the $112.6 million outstanding on the Partnership's Promissory Note and reduce the Partnership Revolver outstanding balance by $42.0 million. As a result of the debt extinguishment, the Partnership recorded a loss on extinguishment of debt on the Consolidated Statement of Operations of $19.2 million, which included the premium paid and a write-off of unamortized debt issuance costs of $7.1 million partly offset by a write-off of unamortized premiums of $6.6 million.

Partnership Financing Obligation

In 2016, the Partnership entered into a sale-leaseback arrangement of certain coke and logistics equipment. The leaseback agreement has an initial lease period of 60 months, with an effective interest rate of 5.82 percent 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.

Redemption of 2019 Notes

The 2019 Notes are the Company’s senior unsecured obligations and are guaranteed on a senior unsecured basis by each of the Company’s existing and future subsidiaries that guarantees the Company’s credit facilities. The Company may redeem some or all of their notes at specified redemption prices. If the Company sells certain of its assets or experiences specific kinds of changes in control, subject to certain exceptions, the Company must offer to purchase their 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. The Company funded the redemption with a term loan in the aggregate principal amount of $45.0 million maturing on May 24, 2022 under the Company’s existing Amended and Restated Credit Agreement. 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.

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.

In February 2017, the Company extended the maturity of its Revolving Facility to December 2018 and reduced its capacity by $25.0 million to $125.0 million, resulting in additional debt issuance costs of $0.6 million. Additionally, the Company recorded a loss on extinguishment of debt on the Consolidated Statement of Operations of $0.1 million, representing a write-off of unamortized debt issuance costs, during 2017.

In May 2017, the Company amended and restated its Revolving Facility, which extended its maturity date from December 2018 to May 2022 and reduced its capacity to $100.0 million, resulting in debt issuance costs of $1.1 million. Additionally, the Company recorded a loss on extinguishment of debt on the Consolidated Statement of Operations of $0.3 million, representing a write-off of unamortized debt issuance costs, during 2017. As of December 31, 2017, the Revolving Facility had letters of credit outstanding of $26.5 million and no outstanding balance, leaving $73.5 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 and 2.3 percent during 2016 and 2015, respectively. There were no borrowings during 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.

In May 2017, the Partnership amended and restated the Partnership Revolver, which increased the Partnership's capacity from $250.0 million to $285.0 million and extended the maturity from May 2019 to May 2022. In connection with the amendments to the Partnership Revolver, the Partnership incurred debt issuance costs of $3.0 million and recorded a loss on extinguishment of debt on the Consolidated Statement of Operations of $0.8 million, representing a write-off of unamortized debt issuance costs, during 2017.

As of December 31, 2017, the Partnership had $1.9 million of letters of credit outstanding and an outstanding balance of $130.0 million, leaving $153.1 million available. Commitment fees are based on the unused portion of the Partnership Revolver at a rate of 0.4 percent.

The Partnership Revolver borrowings bear interest at a variable rate of LIBOR plus 250 basis points or 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 3.8 percent, 3.3 percent and 2.9 percent during 2017, 2016 and 2015, 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, 2017, 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, 2017, the combined aggregate amount of maturities for long-term borrowings for each of the next five years is as follows:

	(Dollars in Millions)(1)
2018	$	2.6
2019(2)	47.4
2020	7.3
2021	—
2022	130.0
2023-Thereafter	700.0
Total	$	887.3

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

(2) As previously disclosed, the 2019 Notes were repaid in January 2018 with the proceeds of a new term loan due in May 2022.

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Commitments and Contingent Liabilities

12 Months Ended

Dec. 31, 2017

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. Total rental expense was $7.3 million, $8.7 million and $8.5 million in 2017, 2016 and 2015, respectively. 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:
2018	$	3.1
2019	2.4
2020	1.4
2021	0.9
2022	0.3
2023-Thereafter	1.1
Total	$	9.2

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 in existence prior to the Granite City Dropdown at the Partnership's Granite City facility.  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 U.S. Environmental Protection Agency ("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. An amendment was lodged in federal court in February 2018 and is undergoing review. The amendment 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.

We anticipate spending approximately $145 million related to these projects, of which we have spent approximately $111 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 quarter of 2019. A portion of the proceeds from the Partnership's initial public offering and subsequent dropdowns are expected to be used to fund $119 million of these environmental remediation projects. Pursuant to the omnibus agreement, the Company will reimburse the Partnership approximately $20 million for the estimated additional spending beyond what has previously been funded.

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. have met regularly since those discussions commenced, and continued to meet regularly in 2017 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 of the NOVs/FOVs. A Consent Decree among the parties was lodged in federal court in January 2018 and is undergoing review. The settlement includes a $2.5 million civil penalty payment, which is included in accrued liabilities on the Consolidated Balance Sheets as of December 31, 2017. 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

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.

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

	December 31,
	2017			2016
Discount rate (percent)(1)	3.3		%	3.7		%
Active claims	351			349
Estimated black lung liability (dollars in millions)(2)	$	50.3		$	50.2

(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 0.25 percent decrease in the discount rate would have increased coal workers' black lung expense by $1.2 million in 2017.

(2) The current portion of the black lung liability was $5.4 million and $4.8 million at December 31, 2017 and 2016, 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,
	2017		2016		2015
	(dollars in millions)
Payments	$	7.4	$	7.8	$	3.8
Expense	$	7.5	$	8.1	$	9.8

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Accumulated Other Comprehensive Loss

12 Months Ended

Dec. 31, 2017

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 income (loss), net of tax, by component:

	Benefit Plans			Currency Translation Adjustments			Total
	(Dollars in millions)
At December 31, 2015	$	(4.6	)	$	(15.2	)	$	(19.8	)
Other comprehensive loss before reclassifications	—			1.0			1.0
Retirement benefit plans funded status adjustment	(0.2		)	—			(0.2		)
Net current period other comprehensive loss	(0.2		)	1.0			0.8
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		)
At December 31, 2017	$	(5.4	)	$	(14.7	)	$	(20.1	)

(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 retained earnings to accumulated other comprehensive loss.

The tax benefit associated with the Company's benefit plans as of December 31, 2017 and 2016 was $3 million and $2.7 million, respectively.

The Company's accumulated other comprehensive loss balance includes $9.0 million from currency translation adjustments of the investment in VISA SunCoke, which remains until the cumulative investment balance is no longer negative or the investment is disposed. The balance would be reclassified to earnings if the investment is disposed of by the Company.

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

	December 31,
	2017			2016			2015
	(Dollars in millions)
Amortization of benefit plans to net income:
Actuarial loss	$	(0.9	)	$	(0.7	)	$	(1.3	)
Prior service benefit	0.7			0.7			1.2
Curtailment gain	—			—			4.1
Settlement loss	—			—			(12.6		)
Total before taxes	(0.2		)	—			(8.6		)
Income tax cost (benefit)	—			—			3.4
Total, net of tax	$	(0.2	)	$	—		$	(5.2	)

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Share-Based Compensation

12 Months Ended

Dec. 31, 2017

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 6,000,000 shares 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. 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, 2017, 2016 and 2015, 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:
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
2015 grant	593,976	$	16.33	$	4.87
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, 2017, 2016 and 2015 was based on using the following weighted-average assumptions:

	Years Ended December 31,
	2017		2016		2015
Risk free interest rate	2.11	%	1.25	%	1.66	%
Expected term	6 years		5 years		5 years
Volatility	53	%	52	%	36	%
Dividend yield	—	%	—	%	1.64	%

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, 2017 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, 2016	2,923,668		$	15.69	6.3	$	2.2
Granted	237,791		$	10.14
Exercised	(10,252	)	$	9.66
Forfeited	(5,092	)	$	20.70
Outstanding at December 31, 2017	3,146,115		$	15.31	5.6	$	2.8
Exercisable at December 31, 2017	2,530,129		$	16.64	4.8	$	0.7
Expected to vest at December 31, 2017	615,986		$	9.87	8.4	$	2.1

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 2017 and 2015 was $0.3 million and $0.1 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, 2017 and 2015:

	Shares	Weighted Average Grant-Date Fair Value		Grant Date Fair Value
				(Dollars in millions)
2017 grants	22,628	$	9.85	$	0.2
2015 grants	297,514	$	14.51	$	4.3

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, 2017 and RSU activity during the fiscal year then ended:

	Number of RSUs		Weighted Average Grant- Date Fair Value
Nonvested at December 31, 2016	224,940		$	16.18
Granted	22,628		$	9.85
Vested	(135,522	)	$	17.22
Forfeited	(5,649	)	$	11.47
Nonvested at December 31, 2017	106,397		$	13.53

Total grant date fair value of RSUs vested was $2.3 million, $3.7 million and $4.6 million during 2017, 2016 and 2015, 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 year ended December 31, 2017:

	Shares	Fair Value per Share		Grant Date Fair Value
				(Dollars in millions)
2017 grant	385,758	$	11.61	$	4.5

The 2017 PSU grant was 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 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. In February 2017, the Company granted 237,610 PSUs that will vest on December 31, 2019. In December 2017, the Company granted 148,148 PSUs that will vest on December 31, 2020.

The Company granted the following PSUs during the years ended December 31, 2016 and 2015:

	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
2015 grant	67,135	$	16.90	67,136	$	18.27	$	2.4

(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 2016 and 2015 grants will vest on December 31, 2018 and December 31, 2017, respectively.

The following table summarizes information with respect to unearned PSUs outstanding as of December 31, 2017 and PSU activity during the fiscal year then ended:

	Number of PSUs		Weighted Average Grant- Date Fair Value
Nonvested at December 31, 2016	666,713		$	10.51
Granted	385,758		$	11.61
Vested	(11,071	)	$	22.30
Forfeited	(258,619	)	$	13.72
Nonvested at December 31, 2017	782,781		$	10.06

Liability Classified Awards

Restricted Stock Units Settled in Cash

During the years ended December 31, 2017 and 2016, the Company issued 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, 2017 and 2016 was $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, 2017 was adjusted based on the closing price of our common stock on December 31, 2017 of $11.99 per share. The liability at December 31, 2017 was $1.2 million, of which $0.9 million was included in accrued liabilities and $0.3 million was included in other deferred credits and liabilities on the Consolidated Balance Sheets.

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 $0.7 million and $0.9 million during the years ended December 31, 2017 and 2016, respectively, that vests on December 31, 2019 and 2018, respectively. The 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, 2017 was adjusted based on the Company's current performance related to the above awards. The cash incentive award liability at December 31, 2017 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,
	2017		2016		2015		2017		2016		2015		December 31, 2017
	Compensation Expense(1)						Net of tax						Unrecognized Compensation Cost		Recognition Period
	(Dollars in millions)												(Dollars in millions)		(Years)
Equity Awards:
Stock Options	$	1.3	$	2.1	$	2.5	$	0.8	$	1.3	$	1.6	$	0.7	2.0
RSUs	1.1		2.6		4.2		0.7		1.7		2.7		$	0.3	1.2
PSUs	1.9		1.4		0.5		1.2		0.9		0.3		$	2.4	2.8
Total equity awards	$	4.3	$	6.1	$	7.2	$	2.7	$	3.9	$	4.6
Liability Awards:
Cash RSUs	$	1.0	$	0.7	$	—	$	0.6	$	0.5	$	—	$	1.3	1.7
Cash incentive award	0.2		0.1		—		0.1		0.1		—		$	0.4	1.9
Total liability awards	$	1.2	$	0.8	$	—	$	0.7	$	0.6	$	—

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

The Company issued $0.5 million and $0.4 million of share-based compensation to the Company's Board of Directors during the years ended December 31, 2017 and 2016, respectively. The share-based compensation issued to the Company's Board of Directors was not material during the year ended December 31, 2015.

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Earnings Per Share

12 Months Ended

Dec. 31, 2017

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,
	2017	2016	2015
	(Shares in millions)
Weighted-average number of common shares outstanding-basic	64.3	64.2	65.0
Add: effect of dilutive share-based compensation awards	0.9	0.2	—
Weighted-average number of shares-diluted	65.2	64.4	65.0

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,
	2017	2016	2015
	(Shares in millions)
Stock options	2.9	3.0	2.9
Restricted stock units	—	0.2	0.5
Performance stock units	0.1	0.2	—
Total	3.0	3.4	3.4

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Fair Value Measurements

12 Months Ended

Dec. 31, 2017

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

Certain assets and liabilities are measured at fair value on a recurring basis. The Company’s cash equivalents, which amounted to $5.5 million and $4.4 million at December 31, 2017 and 2016, 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 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 at December 31, 2017 and December 31, 2016 was $2.5 million and $4.2 million, respectively, and was included in other deferred credits and liabilities on the Consolidated Balance Sheets.

During 2017, as a result of adverse mining conditions faced by one of our thermal coal customers, the Partnership lowered CMT's throughput volume projection for this customer, which reduced the Partnership's contingent consideration liability balance by $1.7 million. The decrease in fair value was recorded as a reduction to costs of products sold and operating expenses on the Consolidated Statements of Operations during 2017. Throughput volumes at CMT in 2017 were consistent with projections and higher than 2016 levels, but still significantly below levels that would trigger payment of the contingent consideration.

During March 2016, as part of developing commercial activities subsequent to the acquisition, 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. The increase in the volume threshold reduced the fair value of the contingent consideration liability by $3.7 million, which was recorded as a reduction to cost of products sold and operating expense on the Consolidated Statement of Operations. During the second half of 2016, the Partnership lowered CMT’s throughput volume projections in future periods for certain customers due to declining coal prices which were expected to reduce export volume through CMT. These updated volume projections resulted in a net decrease to the contingent consideration liability, decreasing cost of products sold and operating expenses on the Consolidated Statements of Operations by $6.4 million during the year ended December 31, 2016. During 2016, the Partnership also recorded an adjustment to correct an error in the acquisition date fair value of the contingent consideration liability, which increased the contingent consideration liability and goodwill balance by $6.4 million.

Non-Financial Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis

Certain assets and liabilities are measured at fair value on a nonrecurring basis; that is, the assets and liabilities are not measured at fair value on an ongoing basis, but are subject to fair value adjustments in certain circumstances (e.g., when there is evidence of impairment).

India Equity Method Investment Valuation

As a result of sustained depressed market conditions, the Company recorded other-than-temporary impairment charges of the joint venture investment in the Company's India reportable segment of $19.4 million in 2015. These charges were recorded in loss from equity method investment on the Consolidated Statement of Operations and resulted in an investment balance of zero. Consequently, beginning in the fourth quarter of 2015, we no longer include the results of our share of VISA SunCoke in our consolidated financial statements. In accordance with GAAP, our share of future earnings of the joint venture will only be included in our results once the cumulative investment balance is no longer negative. The Company has no plans to make further capital contributions to this investment.

The estimated discounted cash flows in 2015 utilized inputs considered to be Level 3 in the fair value hierarchy. Key assumptions in the 2015 discounted cash flow analysis included a 13.5 percent discount rate and estimated cash flows, which considered the timing and extent of future improvements in the Indian market, an important component of which is gross margin recovery. The continuing deterioration of market conditions resulted in forecasted gross loss of $8 per ton to a forecasted gross margin gain of $13 per ton upon market recovery. A $5 per ton change in the gross margin assumption in 2016 would have impacted the valuation of our investment by approximately $8 million. To the extent possible, the Company considered available market information and other third-party data and compared the inputs to relevant historical information during the 2015 valuations.

Certain Financial Assets and Liabilities not Measured at Fair Value

At December 31, 2017 and 2016, the fair value of the Company’s long-term debt was estimated to be $919.7 million and $854.4 million, respectively, compared to a carrying amount of $887.3 million and $858.0 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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Business Segment Information

12 Months Ended

Dec. 31, 2017

Segment Reporting [Abstract]

Business Segment Information

18. 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 located in Vansant, Virginia; East Chicago, Indiana; Franklin Furnace, Ohio; Granite City, Illinois; and Middletown, Ohio, respectively. Each of these facilities produces coke, and all facilities except Jewell and Indiana Harbor recover waste heat, which is converted to steam or electricity through a similar production process. Steam is provided to customers pursuant to steam supply and purchase agreements. Electricity is sold into the regional power market or to AK Steel Holding Corporation ("AK Steel") pursuant to energy sales agreements. Coke sales at each of the Company's five domestic cokemaking facilities are made pursuant to long-term, take-or-pay agreements with ArcelorMittal S.A., AK Steel, and U.S. Steel. Each of the coke sales agreements contains pass-through provisions for costs incurred in the cokemaking process, including coal procurement costs (subject to meeting contractual coal-to-coke yields), operating and maintenance expense, costs related to the transportation of coke to the customers, taxes (other than income taxes) and costs associated with changes in regulation, in addition to containing a fixed fee.

The Brazil Coke segment operates a cokemaking facility located in Vitória, Brazil for a project company. The Brazil Coke segment earns income from the Brazilian facility through licensing and operating fees payable to us under long-term contracts with the local project company that will run through at least 2023.

Logistics operations are comprised of CMT, located in Louisiana, KRT, located in West Virginia, SunCoke Lake Terminal, located in Indiana, and DRT, located in Virginia adjacent to our Jewell cokemaking facility. Our logistics operations have a collective capacity to mix and transload approximately 40 million tons of coal and other aggregates annually and provide handling and/or mixing services to its customers, which include the Partnership's cokemaking facilities and other SunCoke cokemaking facilities. 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, which was historically presented as a separate reportable segment. Prior year periods have been recasted to reflect current presentation.

Segment assets, net of tax are those assets utilized within a specific segment and exclude deferred taxes and current tax receivables.

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,
	2017			2016			2015
	(Dollars in millions)
Sales and other operating revenue:
Domestic Coke	$	1,195.0		$	1,097.6		$	1,244.1
Brazil Coke	43.4			39.5			43.4
Logistics	93.1			84.7			60.8
Logistics intersegment sales	23.8			23.2			20.4
Corporate and Other(1)	—			1.5			14.4
Corporate and Other intersegment sales(1)	—			22.0			101.0
Elimination of intersegment sales	(23.8		)	(45.2		)	(121.4		)
Total sales and other operating revenue	$	1,331.5		$	1,223.3		$	1,362.7
Adjusted EBITDA
Domestic Coke	$	188.9		$	193.9		$	210.1
Brazil Coke	18.2			16.2			22.4
Logistics	70.8			63.9			38.0
Corporate and Other(2)	(43.2		)	(57.0		)	(85.1		)
Total Adjusted EBITDA	$	234.7		$	217.0		$	185.4
Depreciation and amortization expense:
Domestic Coke	$	102.6		$	84.0		$	81.6
Brazil Coke	0.7			0.7			0.6
Logistics	24.4			24.8			14.0
Corporate and Other	0.5			4.7			12.9
Total depreciation and amortization expense	$	128.2		$	114.2		$	109.1
Capital expenditures:
Domestic Coke	$	68.8		$	44.6		$	67.6
Logistics	4.4			17.4			6.0
Corporate and Other	2.4			1.7			2.2
Total capital expenditures	$	75.6		$	63.7		$	75.8

(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 $10.5 million, $15.0 million, and $40.9 million for the years ended December 31, 2017, 2016 and 2015, respectively.

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

	Years Ended December 31,
	2017		2016
	(Dollars in millions)
Segment assets
Domestic Coke	$	1,439.7	$	1,495.0
Brazil Coke	10.9		32.6
Logistics	491.9		515.6
Corporate and Other	112.8		73.1
Segment assets, excluding tax assets and assets held for sale	2,055.3		2,116.3
Tax assets	4.8		4.6
Total assets	$	2,060.1	$	2,120.9

The following table sets forth the Company’s total sales and other operating revenue by product or service:

	Years Ended December 31,
	2017		2016		2015
	(Dollars in millions)
Sales and other operating revenue:
Cokemaking	$	1,140.8	$	1,038.2	$	1,182.0
Energy	53.2		54.3		61.5
Logistics	89.7		82.9		58.8
Operating and licensing fees	43.4		39.5		34.0
Other	4.4		8.4		26.4
Sales and other operating revenue	$	1,331.5	$	1,223.3	$	1,362.7

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 interest, taxes, depreciation and amortization and impairments attributable to our equity method investment. 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,
	2017			2016			2015
	(Dollars in millions)
Net cash provided by operating activities	$	148.5		$	219.1		$	141.1
Subtract:
Depreciation and amortization expense	128.2			114.2			109.1
Deferred income tax (benefit) expense	(87.2		)	3.1			(5.6		)
Loss (gain) on extinguishment of debt	20.4			(25.0		)	0.5
Loss on divestiture of business	—			14.7			—
Changes in working capital and other	(16.4		)	52.6			26.8
Net income	$	103.5		$	59.5		$	10.3
Add:
Depreciation and amortization expense	128.2			114.2			109.1
Interest expense, net	60.6			53.5			56.2
Loss (gain) on extinguishment of debt	20.4			(25.0		)	0.5
Income tax (benefit) expense	(81.6		)	8.6			(8.8		)
Contingent consideration adjustments(1)	(1.7		)	(10.1		)	—
Expiration of land deposits and write-off of costs related to potential new cokemaking facility(2)	5.3			1.9			—
Non-cash reversal of acquired contractual obligation(3)	—			(0.7		)	(3.3		)
Loss on divestiture of business	—			14.7			—
Coal rationalization costs(4)	—			0.4			0.6
Adjustment to unconsolidated affiliate earnings(5)	—			—			20.8
Adjusted EBITDA(6)	$	234.7		$	217.0		$	185.4
Subtract: Adjusted EBITDA attributable to noncontrolling interest(7)	86.4			86.6			81.2
Adjusted EBITDA attributable to SunCoke Energy, Inc.	$	148.3		$	130.4		$	104.2

(1) As a result of changes in the fair value of the contingent consideration liability, the Partnership recognized benefits of $1.7 million and $10.1 million during 2017 and 2016, respectively. See Note 17.

(2) In 2014, we finalized the required permitting and engineering plan for a potential new cokemaking facility to be constructed in Kentucky. However, in June 2017, due to our focus on renewing our existing customer contracts and the lack of any long-term customer commitment for a majority of the facility's capacity, we decided to terminate the project. As a result, during 2017, the Company wrote-off previously capitalized engineering and land deposit costs of $5.3 million. During 2016, the Company wrote-off expiring land deposits related to the project of $1.9 million.

(3) In association with the acquisition of CMT, we assumed certain performance obligations under existing contracts and recorded liabilities related to such obligations. In 2015 and 2016, the final acquired contractual performance obligations expired without the customer requiring performance. Therefore, the Partnership reversed the liabilities as we no longer have any obligations under the contracts.

(4) 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.

(5) Reflects share of interest, taxes, depreciation and amortization related to VISA SunCoke, including impairments of our investment in VISA SunCoke of $19.4 million, which resulted in an investment balance of zero. Beginning in the fourth quarter of 2015, we no longer include the results of our share of VISA SunCoke in our consolidated financial statements.

(6) In accordance with the SEC’s May 2016 update of its guidance on the appropriate use of non-GAAP financial measures, Adjusted EBITDA does not include Logistics deferred revenue until it is recognized as GAAP revenue.

(7) Reflects noncontrolling interest 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, 2017

Quarterly Financial Information Disclosure [Abstract]

Selected Quarterly Data (unaudited)

19. Selected Quarterly Data (unaudited)

	2017										2016
	First Quarter(1)			Second Quarter(2)			Third Quarter		Fourth Quarter(3)(4)		First Quarter			Second Quarter			Third Quarter		Fourth Quarter(4)
	(Dollars in millions)
Sales and other operating revenue	$	309.7		$	323.2		$	339.0	$	359.6	$	311.1		$	292.7		$	293.9	$	325.6
Gross profit(5)	$	42.0		$	32.7		$	51.2	$	56.6	$	42.4		$	39.7		$	50.7	$	69.8
Net (loss) income	$	(57.7	)	$	(31.5	)	$	18.8	$	173.9	$	12.6		$	1.0		$	14.4	$	31.5
Less: Net (loss) income attributable to noncontrolling interests	$	(58.7	)	$	(7.3	)	$	7.2	$	39.9	$	16.7		$	5.6		$	8.3	$	14.5
Net income (loss) attributable to SunCoke Energy, Inc.	$	1.0		$	(24.2	)	$	11.6	$	134.0	$	(4.1	)	$	(4.6	)	$	6.1	$	17.0
Earnings (loss) attributable to SunCoke Energy, Inc. per common share:
Basic(6)	$	0.02		$	(0.38	)	$	0.18	$	2.08	$	(0.06	)	$	(0.07	)	$	0.10	$	0.26
Diluted(6)	$	0.02		$	(0.38	)	$	0.18	$	2.05	$	(0.06	)	$	(0.07	)	$	0.10	$	0.26

(1) 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.

(2) During the second quarter of 2017, the Partnership incurred $20.2 million of losses in connection with debt refinancing. See Note 12.

(3) 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.

(4) The Partnership recognized deferred revenue from Logistics take-or-pay billings for minimum volume shortfalls of $16.4 million and $31.5 million into revenue in the fourth quarters of 2017 and 2016 respectively.

(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, 2017

Condensed Financial Information of Parent Company Only Disclosure [Abstract]

Supplemental Condensed Combining and Consolidating Financial Information

20. 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 and $44.6 million of 2019 Notes (“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 footnote, SunCoke Energy, Inc. 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 2025 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, 2017, less than 25 percent of net assets were restricted. 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 2019 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 2019 Notes, has occurred as a result thereof;

• the designation of a Guarantor Subsidiary as an "unrestricted subsidiary" in accordance with the indenture governing the 2019 Notes

• the requirements for defeasance or discharge of the indentures governing the 2019 Notes having been satisfied;

• 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 2019 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 Operations

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 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	—			157.3			867.9			(4.4		)	1,020.8
Selling, general and administrative expenses	8.7			22.6			48.3			—			79.6
Depreciation and amortization expenses	—			7.5			120.7			—			128.2
Total costs and operating expenses	8.7			187.4			1,036.9			(4.4		)	1,228.6
Operating income (loss)	101.2			(32.3		)	89.4			(55.4		)	102.9
Interest (income) expense, net - affiliate	—			(7.5		)	7.5			—			—
Interest expense (income), net	4.9			(0.5		)	56.2			—			60.6
Total interest expense (income), net	4.9			(8.0		)	63.7			—			60.6
Loss on extinguishment of debt	0.4			—			20.0			—			20.4
Income 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 Operations

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 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	—			131.3			779.1			(3.9		)	906.5
Selling, general and administrative expenses	12.9			25.5			52.9			—			91.3
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			166.0			951.7			(3.9		)	1,126.7
Operating income	6.8			62.0			98.8			(71.0		)	96.6
Interest (income) expense, net - affiliate	—			(7.6		)	7.6			—			—
Interest expense (income), net	6.0			(0.2		)	47.7			—			53.5
Total interest expense (income), net	6.0			(7.8		)	55.3			—			53.5
Gain on extinguishment of debt	—			—			(25.0		)	—			(25.0		)
Income before income tax (benefit) expense	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 Statement of Operations

Years Ended December 31, 2015

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Revenues
Sales and other operating revenue	$	—		$	197.2		$	1,165.5		$	—		$	1,362.7
Equity in (loss) earnings of subsidiaries	(8.4		)	34.4			—			(26.0		)	—
Total revenues, net of equity in (loss) earnings of subsidiaries	(8.4		)	231.6			1,165.5			(26.0		)	1,362.7
Costs and operating expenses
Cost of products sold and operating expenses	—			150.2			948.2			—			1,098.4
Selling, general and administrative expenses	9.5			30.7			35.2			—			75.4
Depreciation and amortization expenses	—			10.4			98.7			—			109.1
Total costs and operating expenses	9.5			191.3			1,082.1			—			1,282.9
Operating (loss) income	(17.9		)	40.3			83.4			(26.0		)	79.8
Interest (income) expense, net - affiliate	—			(7.3		)	7.3			—			—
Interest expense (income), net	8.3			(0.6		)	48.5			—			56.2
Total interest expense (income), net	8.3			(7.9		)	55.8			—			56.2
Loss (gain) on extinguishment of debt, net	1.2			—			(0.7		)	—			0.5
(Loss) income before income tax (benefit) expense and loss from equity method investment	(27.4		)	48.2			28.3			(26.0		)	23.1
Income tax (benefit) expense	(5.4		)	29.6			(33.0		)	—			(8.8		)
Loss from equity method investment	—			—			21.6			—			21.6
Net (loss) income	(22.0		)	18.6			39.7			(26.0		)	10.3
Less: Net income attributable to noncontrolling interests	—			—			32.3			—			32.3
Net (loss) income attributable to SunCoke Energy, Inc.	$	(22.0	)	$	18.6		$	7.4		$	(26.0	)	$	(22.0	)
Comprehensive (loss) income	$	(20.3	)	$	18.4		$	41.6		$	(27.7	)	$	12.0
Less: Comprehensive income attributable to noncontrolling interests	—			—			32.3			—			32.3
Comprehensive (loss) income attributable to SunCoke Energy, Inc.	$	(20.3	)	$	18.4		$	9.3		$	(27.7	)	$	(20.3	)

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 tax receivable	—			—			88.1			(83.3		)	4.8
Other current assets	—			4.6			2.1			—			6.7
Advances to affiliates	—			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 intangibles 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
Investment in subsidiaries	632.5			721.2			—			(1,353.7		)	—
Total assets	$	639.6		$	1,257.6		$	2,241.8		$	(2,078.9	)	$	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 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 72,006,905 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	(20.1		)	(2.2		)	(17.9		)	20.1			(20.1		)
Retained earnings	100.1			475.6			115.3			(590.9		)	100.1
Total SunCoke Energy, Inc. stockholders’ equity	426.2			614.4			739.3			(1,353.7		)	426.2
Noncontrolling interests	—			—			233.4			—			233.4
Total equity	426.2			614.4			972.7			(1,353.7		)	659.6
Total liabilities and equity	$	639.6		$	1,257.6		$	2,241.8		$	(2,078.9	)	$	2,060.1

SunCoke Energy, Inc.

Condensed Consolidating Balance Sheet

December 31, 2016

(Dollars in millions, except per share amounts)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Assets
Cash and cash equivalents	$	—		$	59.7		$	74.3		$	—		$	134.0
Receivables	—			12.2			48.5			—			60.7
Receivable from redemption of investment in Brazil	—			—			20.5			—			20.5
Inventories	—			9.0			83.5			—			92.5
Income taxes receivable	17.8			—			74.3			(87.5		)	4.6
Other current assets	0.2			1.8			1.8			—			3.8
Advances to affiliate	—			282.2			—			(282.2		)	—
Total current assets	18.0			364.9			302.9			(369.7		)	316.1
Notes receivable from affiliate	—			89.0			300.0			(389.0		)	—
Properties, plants and equipment, net	—			62.8			1,479.8			—			1,542.6
Goodwill	—			3.4			73.5			—			76.9
Other intangible assets, net	—			2.3			176.7			—			179.0
Deferred charges and other assets	—			5.1			1.2			—			6.3
Investment in subsidiaries	542.7			688.2			—			(1,230.9		)	—
Total assets	$	560.7		$	1,215.7		$	2,334.1		$	(1,989.6	)	$	2,120.9
Liabilities and Equity
Advances from affiliate	$	184.2		$	—		$	98.0		$	(282.2	)	$	—
Accounts payable	—			13.6			85.0			—			98.6
Accrued liabilities	1.7			20.5			27.6			—			49.8
Deferred Revenue	—			—			2.5			—			2.5
Current portion of long-term debt and financing obligation	—			—			4.9			—			4.9
Interest payable	1.5			—			14.7			—			16.2
Income taxes payable	—			87.5			—			(87.5		)	—
Total current liabilities	187.4			121.6			232.7			(369.7		)	172.0
Long-term debt and financing obligation	43.5			—			805.7			—			849.2
Payable to affiliate	—			300.0			89.0			(389.0		)	—
Accrual for black lung benefits	—			12.3			33.1			—			45.4
Retirement benefit liabilities	—			14.1			14.9			—			29.0
Deferred income taxes	15.9			371.0			(34.4		)	—			352.5
Asset retirement obligations	—			—			13.9			—			13.9
Other deferred credits and liabilities	2.8			6.4			9.8			—			19.0
Total liabilities	249.6			825.4			1,164.7			(758.7		)	1,481.0
Equity
Preferred stock, $0.01 par value. Authorized 50,000,000 shares; no issued and outstanding shares at December 31, 2016	—			—			—			—			—
Common stock, $0.01 par value. Authorized 300,000,000 shares; issued 71,707,304 shares at December 31, 2016	0.7			—			—			—			0.7
Treasury stock, 7,477,657 shares at December 31, 2016	(140.7		)	—			—			—			(140.7		)
Additional paid-in capital	492.1			42.1			672.2			(714.3		)	492.1
Accumulated other comprehensive loss	(19.0		)	(1.6		)	(17.4		)	19.0			(19.0		)
Retained (deficit) earnings	(22.0		)	349.8			185.8			(535.6		)	(22.0		)
Total SunCoke Energy, Inc. stockholders’ equity	311.1			390.3			840.6			(1,230.9		)	311.1
Noncontrolling interests	—			—			328.8			—			328.8
Total equity	311.1			390.3			1,169.4			(1,230.9		)	639.9
Total liabilities and equity	$	560.7		$	1,215.7		$	2,334.1		$	(1,989.6	)	$	2,120.9

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 expense (benefit)	(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 (earnings) loss 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:
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		)
Decrease in restricted cash	—			—			0.5			—			0.5
Return of Brazilian investment	—			—			20.5			—			20.5
Net cash used in investing activities	—			(4.1		)	(50.5		)	—			(54.6		)
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 affiliate	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 and cash equivalents	—			43.9			(57.7		)	—			(13.8		)
Cash and cash equivalents at beginning of year	—			59.7			74.3			—			134.0
Cash and cash equivalents at end of year	$	—		$	103.6		$	16.6		$	—		$	120.2

SunCoke Energy, Inc.

Condensed Consolidating Statement of Cash Flows

Years Ended 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 earnings 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 the effects of divestiture):
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		)
Decrease in restricted cash	—			—			17.7			—			17.7
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		)	(30.5		)	—			(36.2		)
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 affiliate	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 and cash equivalents	—			(10.9		)	21.5			—			10.6
Cash and cash equivalents at beginning of year	—			70.6			52.8			—			123.4
Cash and cash equivalents at end of year	$	—		$	59.7		$	74.3		$	—		$	134.0

SunCoke Energy, Inc.

Condensed Consolidating Statement of Cash Flows

December 31, 2015

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Cash Flows from Operating Activities:
Net (loss) income	$	(22.0	)	$	18.6		$	39.7		$	(26.0	)	$	10.3
Adjustments to reconcile net income to net cash (used in) provided by continuing operating activities:
Depreciation and amortization expense	—			10.4			98.7			—			109.1
Deferred income tax (benefit) expense	(20.7		)	14.9			0.2			—			(5.6		)
Gain on curtailment and payments in excess of expense for postretirement plan benefits	—			(1.6		)	(6.4		)	—			(8.0		)
Settlement loss and payments in excess of expense for pension plan	—			—			13.1			—			13.1
Share-based compensation expense	7.2			—			—			—			7.2
Equity in loss (earnings) of subsidiaries	8.4			(34.4		)	—			26.0			—
Loss from equity method investment	—			—			21.6			—			21.6
Loss (gain) on extinguishment of debt, net	1.2			—			(0.7		)	—			0.5
Changes in working capital pertaining to operating activities (net of acquisitions):
Receivables	0.1			9.4			9.3			—			18.8
Inventories	—			(1.3		)	24.5			—			23.2
Accounts payable	—			(3.2		)	(14.7		)	—			(17.9		)
Accrued liabilities	(0.2		)	(2.3		)	(21.8		)	—			(24.3		)
Deferred revenue	—			—			(4.4		)	—			(4.4		)
Interest payable	(6.1		)	—			5.1			—			(1.0		)
Income taxes	17.1			23.2			(45.9		)	—			(5.6		)
Other	(0.9		)	1.5			3.5			—			4.1
Net cash (used in) provided by operating activities	(15.9		)	35.2			121.8			—			141.1
Cash Flows from Investing Activities:
Capital expenditures	—			(11.8		)	(64.0		)	—			(75.8		)
Acquisition of business, net of cash acquired	—			—			(191.7		)	—			(191.7		)
Increase in restricted cash	—			—			(17.7		)	—			(17.7		)
Net cash used in investing activities	—			(11.8		)	(273.4		)	—			(285.2		)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt	—			—			260.8			—			260.8
Repayment of long-term debt	(16.8		)	—			(231.3		)	—			(248.1		)
Debt issuance costs	(0.4		)	—			(5.3		)	—			(5.7		)
Proceeds from revolving facility	60.4			—			232.0			—			292.4
Repayment of revolving facility	—			—			(50.0		)	—			(50.0		)
Cash distributions to noncontrolling interests	—			—			(43.3		)	—			(43.3		)
Dividends paid	(28.0		)	—			—			—			(28.0		)
Shares repurchased	(35.7		)	—			—			—			(35.7		)
SunCoke Energy Partners, L.P. units repurchased	—			—			(12.8		)	—			(12.8		)
Other financing activities	(1.1		)	—			—			—			(1.1		)
Net increase (decrease) in advances from affiliate	37.5			(55.1		)	17.6			—			—
Net cash provided by (used in) financing activities	15.9			(55.1		)	167.7			—			128.5
Net (decrease) increase in cash and cash equivalents	—			(31.7		)	16.1			—			(15.6		)
Cash and cash equivalents at beginning of year	—			102.3			36.7			—			139.0
Cash and cash equivalents at end of year	$	—		$	70.6		$	52.8		$	—		$	123.4

XML

Summary of Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2017

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. Revenues related to the sale of products are recognized when title passes, generally when products are shipped or delivered in accordance with the terms of the respective sales agreements. Service revenues are recognized when services are provided as defined by customer contracts. Revenues are not recognized until sales prices are fixed or determinable and collectability is reasonably assured. Licensing fees, which include an annual fixed fee and a fee determined on a per ton basis, are recognized when earned in accordance with the contract terms.

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 combined sales and other operating revenues for each of the years ended December 31, 2017, 2016 and 2015.

The Partnership receives payment for shortfall obligations on certain Logistics take-or-pay contracts. The payments in excess of services performed are recorded in deferred revenue on the Consolidated Balance Sheets. Deferred revenue on take-or-pay contracts is generally billed quarterly and recognized as income at the earlier of when service is provided or annually based on the terms of the contract.

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 Operations. 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 capitalized interest of $1.1 million, $5.0 million and $3.7 million in 2017, 2016 and 2015, 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.

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. With the redemption of the Brazil Investment, the Company no longer receives the $9.5 million annual preferred dividend on its Brazil Investment from ArcelorMittal Brazil, included in sales and other operating revenue on the Consolidated Statement of Operations in 2015. 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 Statement of Operations.

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 for discussion of the impacts of the Tax Cuts and Jobs Act (“Tax Legislation”), which was enacted on December 22, 2017.

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 selling, general and administrative expenses on the Consolidated Statement of Operations.

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 Operations and are generally passed through to our customers.

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 and India joint venture are the Brazilian real and Indian rupee, respectively. The Company’s foreign operations translate their 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 and are included in our Consolidated Statements of Operations.

Recently Issued Pronouncements

Recently Issued Pronouncements

In May 2014, Financial Accounting Standards Board ("FASB") 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. Subsequently, the FASB has issued various ASUs to provide further clarification around certain aspects of ASC 606. This standard will be effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period, and early adoption was permitted on a limited basis. We have substantially completed our analysis of the new standard and do not expect a material change in our revenue recognition model on an annual basis. Deferred revenue at CMT may be recognized on a more accelerated basis during quarterly periods within the year based on facts and circumstances considered at each quarter under the new guidance. The Company will adopt this standard on January 1, 2018 using the modified retrospective method.

In February 2016, the FASB issued ASU 2016-02, "Leases (Topic 842)." ASU 2016-02 requires lessees to recognize assets and liabilities on the balance sheet for the rights and obligations created by all leases with terms of more than 12 months. It 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 is in the process of analyzing the impacts to our business, including the development of new accounting processes to account for our leases and support the required disclosures. While we are still evaluating the impact of adopting this standard, we expect that upon adoption the right-of-use assets and lease liabilities, such as various plant equipment rentals and the lease of our corporate office space, will increase the reported assets and liabilities on our Consolidated Balance Sheets. We are currently evaluating technology tools to assist with the accounting and reporting requirements of this standard. The Company expects to adopt this standard on January 1, 2019 and is currently evaluating our transition method options.

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Acquisitions and Dropdown Transactions (Tables)

12 Months Ended

Dec. 31, 2017

Business Combinations [Abstract]

Changes in Company's Ownership Interest in Les than Wholly Owned Subsidiary

The table below summarizes the effects of the changes in the Company’s ownership interest in Granite City on SunCoke’s equity:

	Year Ended December 31, 2015
	(Dollars in millions)
Net loss attributable to SunCoke Energy, Inc.	$	(22.0	)
Decrease in SunCoke Energy, Inc. equity for the contribution of 75 percent interest in Granite City	(6.5		)
Decrease in SunCoke Energy, Inc. for the contribution of an additional 23 percent interest in Granite City	(1.5		)
Change from net loss attributable to SunCoke Energy, Inc. and dropdown transactions	$	(30.0	)

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

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

Business Acquisition, Pro Forma Information

The following combined and consolidated results of operations were prepared using historical financial information of CMT and assumes that the acquisition of CMT occurred on January 1, 2015:

	Years Ended December 31,
	2017		2016		2015
	(Audited)				(Unaudited pro forma)
	(Dollars in millions)
Total revenues	$	1,331.5	$	1,223.3	$	1,395.4
Net income	$	103.5	$	59.5	$	9.7
Net income (loss) attributable to SunCoke Energy, Inc.	$	122.4	$	14.4	$	(22.3	)
Earnings (loss) attributable to SunCoke Energy, Inc. per common share:
Basic	$	1.90	$	0.22	$	(0.34	)
Diluted	$	1.88	$	0.22	$	(0.34	)

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Customer Concentrations (Tables)

12 Months Ended

Dec. 31, 2017

Risks and Uncertainties [Abstract]

Schedules of Concentration of Risk, by Risk Factor

The table below shows receivables due from the Company's three significant customers as of December 31, 2017 and 2016:

	December 31,
	2017		2016
	(Dollars in millions)
AM USA and ArcelorMittal Brazil(1)	$	25.7	$	47.7
AK Steel	$	13.2	$	10.7
U.S. Steel	$	5.6	$	5.7

(1) The 2016 receivables due include the $20.5 million receivable recorded as redemption of Brazil investment on the Consolidated Balance Sheets and was collected in 2017.

The table below shows sales to the Company's significant customers for the years ended December 31, 2017, 2016 and 2015:

	Years ended December 31,
	2017				2016				2015
	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)	$	678.2	50.9	%	$	596.6	48.8	%	$	671.8	49.3	%
AK Steel(2)	$	331.3	24.9	%	$	350.0	28.6	%	$	395.4	29.0	%
U.S. Steel(3)	$	214.1	16.1	%	$	185.3	15.1	%	$	212.7	15.6	%

(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, 2017

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,
	2017		2016		2015
	(Dollars in millions)
Domestic	$	4.3	$	52.5	$	8.6
Foreign	17.6		15.6		14.5
Total	$	21.9	$	68.1	$	23.1

Components of income tax expense

The components of income tax (benefit) expense are as follows:

	Years Ended December 31,
	2017			2016			2015
	(Dollars in millions)
Income taxes currently payable (receivable):
U.S. federal	$	1.7		$	2.7		$	(3.1	)
State	(1.0		)	(2.2		)	(3.3		)
Foreign	4.9			5.0			3.2
Total taxes currently payable (receivable)	5.6			5.5			(3.2		)
Deferred tax (benefit) expense:
U.S. federal	(99.7		)	(1.5		)	(12.7		)
State	12.5			4.6			7.1
Total deferred tax (benefit) expense	(87.2		)	3.1			(5.6		)
Total	$	(81.6	)	$	8.6		$	(8.8	)

Reconciliation of income tax expense

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

	Years Ended December 31,
	2017					2016					2015
	(Dollars in millions)
Income tax expense at 35 percent U.S. statutory rate	$	7.7		35.0	%	$	23.8		35.0	%	$	8.0		35.0	%
Increase (reduction) in income taxes resulting from:
Impact of Final Regulations(1)	64.2			293.2	%	—			—	%	—			—	%
Impact of Tax Legislation(2)	(154.7		)	(706.4	)%	—			—	%	—			—	%
Income attributable to noncontrolling interests in partnerships(3)	(5.4		)	(24.7	)%	(15.6		)	(23.0	)%	(11.2		)	(48.3	)%
State and other income taxes, net of federal income tax effects	2.0			9.1	%	1.1			1.7	%	1.8			7.7	%
Change in valuation allowance(4)(5)	3.9			17.8	%	0.4			0.6	%	(8.8		)	(38.0	)%
Investment in subsidiary(5)	—			—	%	—			—	%	1.0			4.4	%
Other	0.7			3.2	%	(1.1		)	(1.6	)%	0.4			1.2	%
Income tax (benefit) expense at effective tax rate	$	(81.6	)	(372.8	)%	$	8.6		12.7	%	$	(8.8	)	(38.0	)%

(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. 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 revises 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 provides 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 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 impact resulting from the remeasurement of U.S. deferred income tax liabilities and assets at the lower enacted corporate tax rates. Based on information currently available, the Company has recorded a provisional income tax expense of $14.3 million for a valuation allowance against $19.0 million of foreign tax credit carryforwards that the Company believes will not be realized prior to their expiration as a result of the Tax Legislation. The final impact of the Tax Legislation may differ from the estimate recorded this period, possibly materially, due to changes in interpretations and assumptions the Company has made, guidance that may be issued and actions the Company may take as a result of the Tax Legislation.

(3) Excludes the 2017 impact of the Final Regulations on qualifying income discussed above. No income tax expense is reflected in the Consolidated Statements of Operations 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.

(5) On December 22, 2014, SunCoke executed a definitive agreement to sell 100 percent of its interest in the entities that made up the Harold Keene Coal Companies. This required SunCoke to record a deferred tax asset of $11.9 million related to the outside basis difference on the Harold Keene investment. This deferred tax asset was offset by a $9.8 million valuation allowance. SunCoke canceled the definitive agreement during the third quarter of 2015. Due to the cancellation of the agreement, the deferred tax asset and the valuation allowance recorded during 2014 were reversed during 2015. The reversal of the deferred tax asset during 2015 was largely offset by a related current income tax deduction due to the determination of insolvency of the subsidiary, resulting in the net income tax benefit of $1.0 million in the investment in subsidiary line. The actual sale of the coal business, which was completed in the second quarter of 2016, had no material impact on the effective tax rate.

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,
	2017			2016
	(Dollars in millions)
Deferred tax assets:
Retirement benefit liabilities	$	7.1		$	12.2
Black lung benefit liabilities	11.6			18.9
Share-based compensation	6.1			8.6
Federal tax credit carryforward(1)	23.2			23.2
Foreign tax credit carryforward(2)	19.0			14.0
Federal net operating loss	2.5			17.2
State tax credit carryforward, net of federal income tax effects(3)	4.0			5.5
State net operating loss carryforward, net of federal income tax effects(4)	13.9			8.4
Other liabilities not yet deductible	4.3			7.8
Total deferred tax assets	91.7			115.8
Less valuation allowance(5)	(26.2		)	(5.9		)
Deferred tax asset, net	65.5			109.9
Deferred tax liabilities:
Properties, plants and equipment(6)	(114.9		)	(0.3		)
Investment in partnerships(6)	(208.4		)	(462.1		)
Total deferred tax liabilities	(323.3		)	(462.4		)
Net deferred tax liability	$	(257.8	)	$	(352.5	)

(1) Federal tax credit carryforward expires in 2032 through 2033.

(2) Foreign tax credit carryforward expires in 2022 through 2027.

(3) State tax credit carryforward, net of federal income tax effects expires in 2017 through 2022.

(4) State net operating loss carryforward, net of federal income tax effects expires in 2017 through 2035.

(5) Primarily related to state tax credit carryforward and the $14.3 million allowance against the foreign tax credit carryforward as a result of the Tax Legislation in 2017.

(6) As a result of the Final Regulations discussed above, deferred tax liabilities associated with properties, plants and equipment increased and investment in partnerships decreased.

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Inventories (Tables)

12 Months Ended

Dec. 31, 2017

Inventory Disclosure [Abstract]

Components of inventories

These components of inventories were as follows:

	December 31,
	2017		2016
	(Dollars in millions)
Coal	$	61.4	$	49.4
Coke	12.3		7.7
Materials, supplies and other	37.3		35.4
Total inventories	$	111.0	$	92.5

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Properties, Plants and Equipment, Net (Tables)

12 Months Ended

Dec. 31, 2017

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,
	2017			2016
	(Dollars in millions)
Coke and energy plant, machinery and equipment(1)	$	1,812.0		$	1,767.1
Logistics plant, machinery and equipment	216.2			214.4
Land and land improvements	118.7			118.7
Construction-in-progress	51.9			33.4
Other	35.7			34.9
Gross investment, at cost	2,234.5			2,168.5
Less: Accumulated depreciation(2)	(733.2		)	(625.9		)
Total properties, plants and equipment, net	$	1,501.3		$	1,542.6

(1) Includes assets, consisting mainly of coke and energy plant, machinery and equipment, with a gross investment totaling $1,337.3 million and $1,281.5 million and accumulated depreciation of $475.8 million and $410.4 million at December 31, 2017 and December 31, 2016, respectively, which are subject to long-term contracts to sell coke and are deemed to contain operating leases.

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Goodwill and Other Intangible Assets (Tables)

12 Months Ended

Dec. 31, 2017

Goodwill and Intangible Assets Disclosure [Abstract]

Schedule of Goodwill

Goodwill allocated to SunCoke's reportable segments as of December 31, 2017 and 2016 and changes in the carrying amount of goodwill during the fiscal year ended December 31, 2016 are shown below. There were no changes in the carrying amount of goodwill during the fiscal year ended December 31, 2017:

	Domestic Coke		Logistics		Total
	(Dollars in millions)
Net balance at December 31, 2015	$	3.4	$	67.7	$	71.1
Adjustments(1)	—		5.8		5.8
Net balance at December 31, 2016 and 2017	$	3.4	$	73.5	$	76.9

(1) During 2016, the Partnership recorded an adjustment to correct an error in the acquisition date fair value of the contingent consideration liability, which increased the contingent consideration liability and goodwill balance by $6.4 million. See Note 17. Additionally, a working capital adjustment to the acquisition date fair value of the acquired net assets decreased the amount of the purchase price allocated to goodwill by $0.6 million.

Schedule of Finite-Lived Intangible Assets

The following table summarizes the components of gross and net intangible asset balances as of December 31, 2017 and December 31, 2016:

		December 31, 2017						December 31, 2016
	Weighted - Average Remaining Amortization Years	Gross Carrying Amount		Accumulated Amortization		Net		Gross Carrying Amount		Accumulated Amortization		Net
		(Dollars in millions)
Customer contracts	5	$	31.7	$	13.8	$	17.9	$	31.7	$	9.9	$	21.8
Customer relationships	14	28.7		5.7		23.0		28.7		3.8		24.9
Permits	25	139.0		12.2		126.8		139.0		7.1		131.9
Trade name	1	1.2		1.0		0.2		1.2		0.8		0.4
Total		$	200.6	$	32.7	$	167.9	$	200.6	$	21.6	$	179.0

Schedule of Finite-Lived Intangible Assets, Future Amortization Expense

Based on the carrying value of finite-lived intangible assets as of December 31, 2017, we estimate amortization expense for each of the next five years as follows:

	(Dollars in millions)
2018	$	11.0
2019	10.9
2020	10.7
2021	10.3
2022	10.3
Thereafter	114.7
Total	$	167.9

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Asset Retirement Obligations (Tables)

12 Months Ended

Dec. 31, 2017

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, 2015	$	22.2
Liabilities settled	(0.7		)
Accretion expense(1)	1.1
Disposal of coal mining liabilities(2)	(9.4		)
Revisions in estimated cash flows	0.7
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

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

(2) In 2016, the Company completed the disposal of its coal mining business to Revelation who assumed a substantial portion of our mining reclamation obligations.

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Retirement Benefits Plans (Tables)

12 Months Ended

Dec. 31, 2017

Retirement Benefits [Abstract]

Defined benefit plan expense (benefit)

Defined benefit plan expense consisted of the following components:

	Years Ended December 31,
	2017		2016		2015
	(Dollars in millions)
Interest cost on benefit obligations	$	—	$	—	$	0.7
Expected return on plan assets	—		—		(0.7		)
Settlement loss	—		—		12.6
Amortization of:
Actuarial losses	—		—		0.5
Total expense	$	—	$	—	$	13.1

Postretirement benefit plans (benefit) expense

Postretirement benefit plans expense (benefit) consisted of the following components:

	Years Ended December 31,
	2017			2016			2015
	(Dollars in millions)
Interest cost on benefit obligations	$	1.1		$	1.3		$	1.3
Amortization of:
Actuarial losses	0.9			0.7			0.8
Prior service benefit	(0.7		)	(0.7		)	(1.2		)
Curtailment gain	—			—			(4.1		)
Total expense (benefit)	$	1.3		$	1.3		$	(3.2	)

Discount rates used to determine benefit obligations for the plans

The following assumptions were used to determine postretirement benefit plans expense (benefit):

	Postretirement Benefit Plans
	2017		2016		2015
Discount Rate	3.65	%	3.80	%	3.45	%

The following discount rates were used to determine the benefit obligation at December 31, 2017 and 2016, respectively (in percentages):

	Postretirement Benefit Plans
	2017		2016
Discount rate	3.35	%	3.65	%

Recognized components of other comprehensive income (loss)

The following amounts were recognized as components of other comprehensive income (loss) before related tax impacts for the years ended December 31, 2017, 2016 and 2015:

	Years Ended December 31,
	Defined Benefit Plan						Postretirement Benefit Plans
	2017		2016		2015		2017			2016			2015
	(Dollars in millions)
Reclassifications to earnings of:
Actuarial loss amortization	$	—	$	—	$	0.5	$	0.9		$	0.7		$	0.8
Prior service benefit amortization	—		—		—		(0.7		)	(0.7		)	(1.2		)
Curtailment gain	—		—		—		—			—			(4.1		)
Settlement loss	—		—		12.6		—			—			—
Retirement benefit plan funded status    adjustments:
Actuarial gains (losses)	—		—		0.9		(1.1		)	(1.8		)	(1.4		)
Prior service (cost) benefit(1)	—		—		—		—			1.5			—
	$	—	$	—	$	14.0	$	(0.9	)	$	(0.3	)	$	(5.9	)

(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 will provide a subsidy to these participants of $3,600 per participant per 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 during 2017 and 2016:

	Postretirement Benefit Plans
	2017			2016
	(Dollars in millions)
Benefit obligation at beginning of year	$	32.3		$	34.8
Interest cost	1.1			1.3
Actuarial losses	1.1			1.8
Plan amendments(1)	—			(1.5		)
Benefits paid	(3.2		)	(4.1		)
Benefit obligation at end of year(2)	$	31.3		$	32.3

(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 will provide a subsidy to these participants of $3,600 per participant per year. The plan change resulted in a decrease in the benefit obligation of $1.5 million during 2016.

(2) Represents retirement benefit liabilities, including current portion, on the Consolidated Balance Sheets. The current portion of retirement liabilities, which totaled $3.1 million and $3.3 million at December 31, 2017 and 2016, 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 (loss) at December 31, 2017 and 2016:

	Postretirement Benefit Plans
	2017			2016
	(Dollars in millions)
Cumulative amounts not yet recognized in net income:
Actuarial losses	$	11.8		$	11.6
Prior service benefits	(3.4		)	(4.1		)
Accumulated other comprehensive loss (before related tax benefit)	$	8.4		$	7.5

Expected benefit payments

The expected benefit payments through 2026 for the postretirement benefit plan are as follows:

	Postretirement Benefit Plans
	(Dollars in millions)
Year ending December 31:
2018	$	3.1
2019	3.0
2020	2.9
2021	2.8
2022	2.6
2023 through 2026	10.1

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Accrued Liabilities (Tables)

12 Months Ended

Dec. 31, 2017

Balance Sheet Related Disclosures [Abstract]

Accrued liabilities

Accrued liabilities consist of following:

	December 31,
	2017		2016
	(Dollars in millions)
Accrued benefits	$	21.3	$	21.4
Current portion of postretirement benefit obligation	3.1		3.3
Other taxes payable	10.5		10.4
Current portion of black lung liability	5.4		4.8
Accrued legal	5.6		4.4
Other	7.3		5.5
Total accrued liabilities	$	53.2	$	49.8

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Debt and Financing Obligation (Tables)

12 Months Ended

Dec. 31, 2017

Debt Disclosure [Abstract]

Schedule of Long-term Debt Instruments

Total debt consisted of the following:

	December 31,
	2017			2016
	(Dollars in millions)
7.500 percent senior notes, due 2025 ("2025 Partnership Notes")	$	700.0		$	—
7.375 percent senior notes, due 2020 (''2020 Partnership Notes'')	—			463.0
7.625 percent senior notes, due 2019 ("2019 Notes")	44.6			44.6
Partnership's term loan, due 2019 ("Partnership Term Loan")	—			50.0
SunCoke's revolving credit facility, due 2022 ("Revolving Facility")	—			—
Partnership's revolving credit facility, due 2022 and 2019, respectively ("Partnership Revolver")	130.0			172.0
Partnership's promissory note payable, due 2021 ("Promissory Note")	—			113.2
5.82 percent financing obligation, due 2021 ("Partnership Financing Obligation")	12.7			15.2
Total borrowings	$	887.3		$	858.0
(Discount) premium	(5.9		)	7.5
Debt issuance costs	(17.7		)	(11.4		)
Total debt and financing obligation	$	863.7		$	854.1
Less: current portion of long-term debt and financing obligation	2.6			4.9
Total long-term debt and financing obligation	$	861.1		$	849.2

Schedule of Maturities of Long-term Debt

As of December 31, 2017, the combined aggregate amount of maturities for long-term borrowings for each of the next five years is as follows:

	(Dollars in Millions)(1)
2018	$	2.6
2019(2)	47.4
2020	7.3
2021	—
2022	130.0
2023-Thereafter	700.0
Total	$	887.3

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

(2) As previously disclosed, the 2019 Notes were repaid in January 2018 with the proceeds of a new term loan due in May 2022.

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Commitments And Contingent Liabilities (Tables)

12 Months Ended

Dec. 31, 2017

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:
2018	$	3.1
2019	2.4
2020	1.4
2021	0.9
2022	0.3
2023-Thereafter	1.1
Total	$	9.2

Schedule of black lung benefit liabilities

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

	December 31,
	2017			2016
Discount rate (percent)(1)	3.3		%	3.7		%
Active claims	351			349
Estimated black lung liability (dollars in millions)(2)	$	50.3		$	50.2

(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 0.25 percent decrease in the discount rate would have increased coal workers' black lung expense by $1.2 million in 2017.

(2) The current portion of the black lung liability was $5.4 million and $4.8 million at December 31, 2017 and 2016, 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,
	2017		2016		2015
	(dollars in millions)
Payments	$	7.4	$	7.8	$	3.8
Expense	$	7.5	$	8.1	$	9.8

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Accumulated Other Comprehensive Loss (Tables)

12 Months Ended

Dec. 31, 2017

Equity [Abstract]

Components of accumulated other comprehensive (loss) income

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

	Benefit Plans			Currency Translation Adjustments			Total
	(Dollars in millions)
At December 31, 2015	$	(4.6	)	$	(15.2	)	$	(19.8	)
Other comprehensive loss before reclassifications	—			1.0			1.0
Retirement benefit plans funded status adjustment	(0.2		)	—			(0.2		)
Net current period other comprehensive loss	(0.2		)	1.0			0.8
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		)
At December 31, 2017	$	(5.4	)	$	(14.7	)	$	(20.1	)

Impact of net income of reclassification adjustments

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

	December 31,
	2017			2016			2015
	(Dollars in millions)
Amortization of benefit plans to net income:
Actuarial loss	$	(0.9	)	$	(0.7	)	$	(1.3	)
Prior service benefit	0.7			0.7			1.2
Curtailment gain	—			—			4.1
Settlement loss	—			—			(12.6		)
Total before taxes	(0.2		)	—			(8.6		)
Income tax cost (benefit)	—			—			3.4
Total, net of tax	$	(0.2	)	$	—		$	(5.2	)

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Share-Based Compensation (Tables)

12 Months Ended

Dec. 31, 2017

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, 2017 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, 2016	2,923,668		$	15.69	6.3	$	2.2
Granted	237,791		$	10.14
Exercised	(10,252	)	$	9.66
Forfeited	(5,092	)	$	20.70
Outstanding at December 31, 2017	3,146,115		$	15.31	5.6	$	2.8
Exercisable at December 31, 2017	2,530,129		$	16.64	4.8	$	0.7
Expected to vest at December 31, 2017	615,986		$	9.87	8.4	$	2.1

The Company granted the following stock options during the years ended December 31, 2017, 2016 and 2015, 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:
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
2015 grant	593,976	$	16.33	$	4.87
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 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 year ended December 31, 2017:

	Shares	Fair Value per Share		Grant Date Fair Value
				(Dollars in millions)
2017 grant	385,758	$	11.61	$	4.5

Weighted-average assumptions

The weighted-average fair value of employee stock options granted during the years ended December 31, 2017, 2016 and 2015 was based on using the following weighted-average assumptions:

	Years Ended December 31,
	2017		2016		2015
Risk free interest rate	2.11	%	1.25	%	1.66	%
Expected term	6 years		5 years		5 years
Volatility	53	%	52	%	36	%
Dividend yield	—	%	—	%	1.64	%

Summary of information with respect to RSUs

The Company granted the following restricted stock units ("RSUs") during the years ended December 31, 2017 and 2015:

	Shares	Weighted Average Grant-Date Fair Value		Grant Date Fair Value
				(Dollars in millions)
2017 grants	22,628	$	9.85	$	0.2
2015 grants	297,514	$	14.51	$	4.3

The following table summarizes information with respect to RSUs outstanding as of December 31, 2017 and RSU activity during the fiscal year then ended:

	Number of RSUs		Weighted Average Grant- Date Fair Value
Nonvested at December 31, 2016	224,940		$	16.18
Granted	22,628		$	9.85
Vested	(135,522	)	$	17.22
Forfeited	(5,649	)	$	11.47
Nonvested at December 31, 2017	106,397		$	13.53

Summary of information with respect to PSUs

The Company granted the following PSUs during the years ended December 31, 2016 and 2015:

	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
2015 grant	67,135	$	16.90	67,136	$	18.27	$	2.4

(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, 2017 and PSU activity during the fiscal year then ended:

	Number of PSUs		Weighted Average Grant- Date Fair Value
Nonvested at December 31, 2016	666,713		$	10.51
Granted	385,758		$	11.61
Vested	(11,071	)	$	22.30
Forfeited	(258,619	)	$	13.72
Nonvested at December 31, 2017	782,781		$	10.06

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,
	2017		2016		2015		2017		2016		2015		December 31, 2017
	Compensation Expense(1)						Net of tax						Unrecognized Compensation Cost		Recognition Period
	(Dollars in millions)												(Dollars in millions)		(Years)
Equity Awards:
Stock Options	$	1.3	$	2.1	$	2.5	$	0.8	$	1.3	$	1.6	$	0.7	2.0
RSUs	1.1		2.6		4.2		0.7		1.7		2.7		$	0.3	1.2
PSUs	1.9		1.4		0.5		1.2		0.9		0.3		$	2.4	2.8
Total equity awards	$	4.3	$	6.1	$	7.2	$	2.7	$	3.9	$	4.6
Liability Awards:
Cash RSUs	$	1.0	$	0.7	$	—	$	0.6	$	0.5	$	—	$	1.3	1.7
Cash incentive award	0.2		0.1		—		0.1		0.1		—		$	0.4	1.9
Total liability awards	$	1.2	$	0.8	$	—	$	0.7	$	0.6	$	—

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

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Earnings Per Share (Tables)

12 Months Ended

Dec. 31, 2017

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,
	2017	2016	2015
	(Shares in millions)
Weighted-average number of common shares outstanding-basic	64.3	64.2	65.0
Add: effect of dilutive share-based compensation awards	0.9	0.2	—
Weighted-average number of shares-diluted	65.2	64.4	65.0

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,
	2017	2016	2015
	(Shares in millions)
Stock options	2.9	3.0	2.9
Restricted stock units	—	0.2	0.5
Performance stock units	0.1	0.2	—
Total	3.0	3.4	3.4

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Business Segment Information (Tables)

12 Months Ended

Dec. 31, 2017

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,
	2017			2016			2015
	(Dollars in millions)
Sales and other operating revenue:
Domestic Coke	$	1,195.0		$	1,097.6		$	1,244.1
Brazil Coke	43.4			39.5			43.4
Logistics	93.1			84.7			60.8
Logistics intersegment sales	23.8			23.2			20.4
Corporate and Other(1)	—			1.5			14.4
Corporate and Other intersegment sales(1)	—			22.0			101.0
Elimination of intersegment sales	(23.8		)	(45.2		)	(121.4		)
Total sales and other operating revenue	$	1,331.5		$	1,223.3		$	1,362.7
Adjusted EBITDA
Domestic Coke	$	188.9		$	193.9		$	210.1
Brazil Coke	18.2			16.2			22.4
Logistics	70.8			63.9			38.0
Corporate and Other(2)	(43.2		)	(57.0		)	(85.1		)
Total Adjusted EBITDA	$	234.7		$	217.0		$	185.4
Depreciation and amortization expense:
Domestic Coke	$	102.6		$	84.0		$	81.6
Brazil Coke	0.7			0.7			0.6
Logistics	24.4			24.8			14.0
Corporate and Other	0.5			4.7			12.9
Total depreciation and amortization expense	$	128.2		$	114.2		$	109.1
Capital expenditures:
Domestic Coke	$	68.8		$	44.6		$	67.6
Logistics	4.4			17.4			6.0
Corporate and Other	2.4			1.7			2.2
Total capital expenditures	$	75.6		$	63.7		$	75.8

(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 $10.5 million, $15.0 million, and $40.9 million for the years ended December 31, 2017, 2016 and 2015, respectively.

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

	Years Ended December 31,
	2017		2016
	(Dollars in millions)
Segment assets
Domestic Coke	$	1,439.7	$	1,495.0
Brazil Coke	10.9		32.6
Logistics	491.9		515.6
Corporate and Other	112.8		73.1
Segment assets, excluding tax assets and assets held for sale	2,055.3		2,116.3
Tax assets	4.8		4.6
Total assets	$	2,060.1	$	2,120.9

The following table sets forth the Company’s total sales and other operating revenue by product or service:

	Years Ended December 31,
	2017		2016		2015
	(Dollars in millions)
Sales and other operating revenue:
Cokemaking	$	1,140.8	$	1,038.2	$	1,182.0
Energy	53.2		54.3		61.5
Logistics	89.7		82.9		58.8
Operating and licensing fees	43.4		39.5		34.0
Other	4.4		8.4		26.4
Sales and other operating revenue	$	1,331.5	$	1,223.3	$	1,362.7

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,
	2017			2016			2015
	(Dollars in millions)
Net cash provided by operating activities	$	148.5		$	219.1		$	141.1
Subtract:
Depreciation and amortization expense	128.2			114.2			109.1
Deferred income tax (benefit) expense	(87.2		)	3.1			(5.6		)
Loss (gain) on extinguishment of debt	20.4			(25.0		)	0.5
Loss on divestiture of business	—			14.7			—
Changes in working capital and other	(16.4		)	52.6			26.8
Net income	$	103.5		$	59.5		$	10.3
Add:
Depreciation and amortization expense	128.2			114.2			109.1
Interest expense, net	60.6			53.5			56.2
Loss (gain) on extinguishment of debt	20.4			(25.0		)	0.5
Income tax (benefit) expense	(81.6		)	8.6			(8.8		)
Contingent consideration adjustments(1)	(1.7		)	(10.1		)	—
Expiration of land deposits and write-off of costs related to potential new cokemaking facility(2)	5.3			1.9			—
Non-cash reversal of acquired contractual obligation(3)	—			(0.7		)	(3.3		)
Loss on divestiture of business	—			14.7			—
Coal rationalization costs(4)	—			0.4			0.6
Adjustment to unconsolidated affiliate earnings(5)	—			—			20.8
Adjusted EBITDA(6)	$	234.7		$	217.0		$	185.4
Subtract: Adjusted EBITDA attributable to noncontrolling interest(7)	86.4			86.6			81.2
Adjusted EBITDA attributable to SunCoke Energy, Inc.	$	148.3		$	130.4		$	104.2

(1) As a result of changes in the fair value of the contingent consideration liability, the Partnership recognized benefits of $1.7 million and $10.1 million during 2017 and 2016, respectively. See Note 17.

(2) In 2014, we finalized the required permitting and engineering plan for a potential new cokemaking facility to be constructed in Kentucky. However, in June 2017, due to our focus on renewing our existing customer contracts and the lack of any long-term customer commitment for a majority of the facility's capacity, we decided to terminate the project. As a result, during 2017, the Company wrote-off previously capitalized engineering and land deposit costs of $5.3 million. During 2016, the Company wrote-off expiring land deposits related to the project of $1.9 million.

(3) In association with the acquisition of CMT, we assumed certain performance obligations under existing contracts and recorded liabilities related to such obligations. In 2015 and 2016, the final acquired contractual performance obligations expired without the customer requiring performance. Therefore, the Partnership reversed the liabilities as we no longer have any obligations under the contracts.

(4) 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.

(5) Reflects share of interest, taxes, depreciation and amortization related to VISA SunCoke, including impairments of our investment in VISA SunCoke of $19.4 million, which resulted in an investment balance of zero. Beginning in the fourth quarter of 2015, we no longer include the results of our share of VISA SunCoke in our consolidated financial statements.

(6) In accordance with the SEC’s May 2016 update of its guidance on the appropriate use of non-GAAP financial measures, Adjusted EBITDA does not include Logistics deferred revenue until it is recognized as GAAP revenue.

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

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Selected Quarterly Data (unaudited) (Tables)

12 Months Ended

Dec. 31, 2017

Quarterly Financial Information Disclosure [Abstract]

Schedule of quarterly financial information

	2017										2016
	First Quarter(1)			Second Quarter(2)			Third Quarter		Fourth Quarter(3)(4)		First Quarter			Second Quarter			Third Quarter		Fourth Quarter(4)
	(Dollars in millions)
Sales and other operating revenue	$	309.7		$	323.2		$	339.0	$	359.6	$	311.1		$	292.7		$	293.9	$	325.6
Gross profit(5)	$	42.0		$	32.7		$	51.2	$	56.6	$	42.4		$	39.7		$	50.7	$	69.8
Net (loss) income	$	(57.7	)	$	(31.5	)	$	18.8	$	173.9	$	12.6		$	1.0		$	14.4	$	31.5
Less: Net (loss) income attributable to noncontrolling interests	$	(58.7	)	$	(7.3	)	$	7.2	$	39.9	$	16.7		$	5.6		$	8.3	$	14.5
Net income (loss) attributable to SunCoke Energy, Inc.	$	1.0		$	(24.2	)	$	11.6	$	134.0	$	(4.1	)	$	(4.6	)	$	6.1	$	17.0
Earnings (loss) attributable to SunCoke Energy, Inc. per common share:
Basic(6)	$	0.02		$	(0.38	)	$	0.18	$	2.08	$	(0.06	)	$	(0.07	)	$	0.10	$	0.26
Diluted(6)	$	0.02		$	(0.38	)	$	0.18	$	2.05	$	(0.06	)	$	(0.07	)	$	0.10	$	0.26

(1) 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.

(2) During the second quarter of 2017, the Partnership incurred $20.2 million of losses in connection with debt refinancing. See Note 12.

(3) 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.

(4) The Partnership recognized deferred revenue from Logistics take-or-pay billings for minimum volume shortfalls of $16.4 million and $31.5 million into revenue in the fourth quarters of 2017 and 2016 respectively.

(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 (Tables)

12 Months Ended

Dec. 31, 2017

Condensed Financial Information of Parent Company Only Disclosure [Abstract]

Condensed Consolidating Statement of Income

SunCoke Energy, Inc.

Condensed Consolidating Statement of Operations

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 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	—			157.3			867.9			(4.4		)	1,020.8
Selling, general and administrative expenses	8.7			22.6			48.3			—			79.6
Depreciation and amortization expenses	—			7.5			120.7			—			128.2
Total costs and operating expenses	8.7			187.4			1,036.9			(4.4		)	1,228.6
Operating income (loss)	101.2			(32.3		)	89.4			(55.4		)	102.9
Interest (income) expense, net - affiliate	—			(7.5		)	7.5			—			—
Interest expense (income), net	4.9			(0.5		)	56.2			—			60.6
Total interest expense (income), net	4.9			(8.0		)	63.7			—			60.6
Loss on extinguishment of debt	0.4			—			20.0			—			20.4
Income 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 Operations

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 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	—			131.3			779.1			(3.9		)	906.5
Selling, general and administrative expenses	12.9			25.5			52.9			—			91.3
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			166.0			951.7			(3.9		)	1,126.7
Operating income	6.8			62.0			98.8			(71.0		)	96.6
Interest (income) expense, net - affiliate	—			(7.6		)	7.6			—			—
Interest expense (income), net	6.0			(0.2		)	47.7			—			53.5
Total interest expense (income), net	6.0			(7.8		)	55.3			—			53.5
Gain on extinguishment of debt	—			—			(25.0		)	—			(25.0		)
Income before income tax (benefit) expense	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 Statement of Operations

Years Ended December 31, 2015

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Revenues
Sales and other operating revenue	$	—		$	197.2		$	1,165.5		$	—		$	1,362.7
Equity in (loss) earnings of subsidiaries	(8.4		)	34.4			—			(26.0		)	—
Total revenues, net of equity in (loss) earnings of subsidiaries	(8.4		)	231.6			1,165.5			(26.0		)	1,362.7
Costs and operating expenses
Cost of products sold and operating expenses	—			150.2			948.2			—			1,098.4
Selling, general and administrative expenses	9.5			30.7			35.2			—			75.4
Depreciation and amortization expenses	—			10.4			98.7			—			109.1
Total costs and operating expenses	9.5			191.3			1,082.1			—			1,282.9
Operating (loss) income	(17.9		)	40.3			83.4			(26.0		)	79.8
Interest (income) expense, net - affiliate	—			(7.3		)	7.3			—			—
Interest expense (income), net	8.3			(0.6		)	48.5			—			56.2
Total interest expense (income), net	8.3			(7.9		)	55.8			—			56.2
Loss (gain) on extinguishment of debt, net	1.2			—			(0.7		)	—			0.5
(Loss) income before income tax (benefit) expense and loss from equity method investment	(27.4		)	48.2			28.3			(26.0		)	23.1
Income tax (benefit) expense	(5.4		)	29.6			(33.0		)	—			(8.8		)
Loss from equity method investment	—			—			21.6			—			21.6
Net (loss) income	(22.0		)	18.6			39.7			(26.0		)	10.3
Less: Net income attributable to noncontrolling interests	—			—			32.3			—			32.3
Net (loss) income attributable to SunCoke Energy, Inc.	$	(22.0	)	$	18.6		$	7.4		$	(26.0	)	$	(22.0	)
Comprehensive (loss) income	$	(20.3	)	$	18.4		$	41.6		$	(27.7	)	$	12.0
Less: Comprehensive income attributable to noncontrolling interests	—			—			32.3			—			32.3
Comprehensive (loss) income attributable to SunCoke Energy, Inc.	$	(20.3	)	$	18.4		$	9.3		$	(27.7	)	$	(20.3	)

Condensed Consolidating Balance Sheet

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 tax receivable	—			—			88.1			(83.3		)	4.8
Other current assets	—			4.6			2.1			—			6.7
Advances to affiliates	—			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 intangibles 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
Investment in subsidiaries	632.5			721.2			—			(1,353.7		)	—
Total assets	$	639.6		$	1,257.6		$	2,241.8		$	(2,078.9	)	$	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 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 72,006,905 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	(20.1		)	(2.2		)	(17.9		)	20.1			(20.1		)
Retained earnings	100.1			475.6			115.3			(590.9		)	100.1
Total SunCoke Energy, Inc. stockholders’ equity	426.2			614.4			739.3			(1,353.7		)	426.2
Noncontrolling interests	—			—			233.4			—			233.4
Total equity	426.2			614.4			972.7			(1,353.7		)	659.6
Total liabilities and equity	$	639.6		$	1,257.6		$	2,241.8		$	(2,078.9	)	$	2,060.1

SunCoke Energy, Inc.

Condensed Consolidating Balance Sheet

December 31, 2016

(Dollars in millions, except per share amounts)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Assets
Cash and cash equivalents	$	—		$	59.7		$	74.3		$	—		$	134.0
Receivables	—			12.2			48.5			—			60.7
Receivable from redemption of investment in Brazil	—			—			20.5			—			20.5
Inventories	—			9.0			83.5			—			92.5
Income taxes receivable	17.8			—			74.3			(87.5		)	4.6
Other current assets	0.2			1.8			1.8			—			3.8
Advances to affiliate	—			282.2			—			(282.2		)	—
Total current assets	18.0			364.9			302.9			(369.7		)	316.1
Notes receivable from affiliate	—			89.0			300.0			(389.0		)	—
Properties, plants and equipment, net	—			62.8			1,479.8			—			1,542.6
Goodwill	—			3.4			73.5			—			76.9
Other intangible assets, net	—			2.3			176.7			—			179.0
Deferred charges and other assets	—			5.1			1.2			—			6.3
Investment in subsidiaries	542.7			688.2			—			(1,230.9		)	—
Total assets	$	560.7		$	1,215.7		$	2,334.1		$	(1,989.6	)	$	2,120.9
Liabilities and Equity
Advances from affiliate	$	184.2		$	—		$	98.0		$	(282.2	)	$	—
Accounts payable	—			13.6			85.0			—			98.6
Accrued liabilities	1.7			20.5			27.6			—			49.8
Deferred Revenue	—			—			2.5			—			2.5
Current portion of long-term debt and financing obligation	—			—			4.9			—			4.9
Interest payable	1.5			—			14.7			—			16.2
Income taxes payable	—			87.5			—			(87.5		)	—
Total current liabilities	187.4			121.6			232.7			(369.7		)	172.0
Long-term debt and financing obligation	43.5			—			805.7			—			849.2
Payable to affiliate	—			300.0			89.0			(389.0		)	—
Accrual for black lung benefits	—			12.3			33.1			—			45.4
Retirement benefit liabilities	—			14.1			14.9			—			29.0
Deferred income taxes	15.9			371.0			(34.4		)	—			352.5
Asset retirement obligations	—			—			13.9			—			13.9
Other deferred credits and liabilities	2.8			6.4			9.8			—			19.0
Total liabilities	249.6			825.4			1,164.7			(758.7		)	1,481.0
Equity
Preferred stock, $0.01 par value. Authorized 50,000,000 shares; no issued and outstanding shares at December 31, 2016	—			—			—			—			—
Common stock, $0.01 par value. Authorized 300,000,000 shares; issued 71,707,304 shares at December 31, 2016	0.7			—			—			—			0.7
Treasury stock, 7,477,657 shares at December 31, 2016	(140.7		)	—			—			—			(140.7		)
Additional paid-in capital	492.1			42.1			672.2			(714.3		)	492.1
Accumulated other comprehensive loss	(19.0		)	(1.6		)	(17.4		)	19.0			(19.0		)
Retained (deficit) earnings	(22.0		)	349.8			185.8			(535.6		)	(22.0		)
Total SunCoke Energy, Inc. stockholders’ equity	311.1			390.3			840.6			(1,230.9		)	311.1
Noncontrolling interests	—			—			328.8			—			328.8
Total equity	311.1			390.3			1,169.4			(1,230.9		)	639.9
Total liabilities and equity	$	560.7		$	1,215.7		$	2,334.1		$	(1,989.6	)	$	2,120.9

Condensed Combining and Consolidating Statement of Cash Flows

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 expense (benefit)	(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 (earnings) loss 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:
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		)
Decrease in restricted cash	—			—			0.5			—			0.5
Return of Brazilian investment	—			—			20.5			—			20.5
Net cash used in investing activities	—			(4.1		)	(50.5		)	—			(54.6		)
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 affiliate	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 and cash equivalents	—			43.9			(57.7		)	—			(13.8		)
Cash and cash equivalents at beginning of year	—			59.7			74.3			—			134.0
Cash and cash equivalents at end of year	$	—		$	103.6		$	16.6		$	—		$	120.2

SunCoke Energy, Inc.

Condensed Consolidating Statement of Cash Flows

Years Ended 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 earnings 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 the effects of divestiture):
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		)
Decrease in restricted cash	—			—			17.7			—			17.7
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		)	(30.5		)	—			(36.2		)
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 affiliate	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 and cash equivalents	—			(10.9		)	21.5			—			10.6
Cash and cash equivalents at beginning of year	—			70.6			52.8			—			123.4
Cash and cash equivalents at end of year	$	—		$	59.7		$	74.3		$	—		$	134.0

SunCoke Energy, Inc.

Condensed Consolidating Statement of Cash Flows

December 31, 2015

(Dollars in millions)

	Issuer			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Combining and Consolidating Adjustments			Total
Cash Flows from Operating Activities:
Net (loss) income	$	(22.0	)	$	18.6		$	39.7		$	(26.0	)	$	10.3
Adjustments to reconcile net income to net cash (used in) provided by continuing operating activities:
Depreciation and amortization expense	—			10.4			98.7			—			109.1
Deferred income tax (benefit) expense	(20.7		)	14.9			0.2			—			(5.6		)
Gain on curtailment and payments in excess of expense for postretirement plan benefits	—			(1.6		)	(6.4		)	—			(8.0		)
Settlement loss and payments in excess of expense for pension plan	—			—			13.1			—			13.1
Share-based compensation expense	7.2			—			—			—			7.2
Equity in loss (earnings) of subsidiaries	8.4			(34.4		)	—			26.0			—
Loss from equity method investment	—			—			21.6			—			21.6
Loss (gain) on extinguishment of debt, net	1.2			—			(0.7		)	—			0.5
Changes in working capital pertaining to operating activities (net of acquisitions):
Receivables	0.1			9.4			9.3			—			18.8
Inventories	—			(1.3		)	24.5			—			23.2
Accounts payable	—			(3.2		)	(14.7		)	—			(17.9		)
Accrued liabilities	(0.2		)	(2.3		)	(21.8		)	—			(24.3		)
Deferred revenue	—			—			(4.4		)	—			(4.4		)
Interest payable	(6.1		)	—			5.1			—			(1.0		)
Income taxes	17.1			23.2			(45.9		)	—			(5.6		)
Other	(0.9		)	1.5			3.5			—			4.1
Net cash (used in) provided by operating activities	(15.9		)	35.2			121.8			—			141.1
Cash Flows from Investing Activities:
Capital expenditures	—			(11.8		)	(64.0		)	—			(75.8		)
Acquisition of business, net of cash acquired	—			—			(191.7		)	—			(191.7		)
Increase in restricted cash	—			—			(17.7		)	—			(17.7		)
Net cash used in investing activities	—			(11.8		)	(273.4		)	—			(285.2		)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt	—			—			260.8			—			260.8
Repayment of long-term debt	(16.8		)	—			(231.3		)	—			(248.1		)
Debt issuance costs	(0.4		)	—			(5.3		)	—			(5.7		)
Proceeds from revolving facility	60.4			—			232.0			—			292.4
Repayment of revolving facility	—			—			(50.0		)	—			(50.0		)
Cash distributions to noncontrolling interests	—			—			(43.3		)	—			(43.3		)
Dividends paid	(28.0		)	—			—			—			(28.0		)
Shares repurchased	(35.7		)	—			—			—			(35.7		)
SunCoke Energy Partners, L.P. units repurchased	—			—			(12.8		)	—			(12.8		)
Other financing activities	(1.1		)	—			—			—			(1.1		)
Net increase (decrease) in advances from affiliate	37.5			(55.1		)	17.6			—			—
Net cash provided by (used in) financing activities	15.9			(55.1		)	167.7			—			128.5
Net (decrease) increase in cash and cash equivalents	—			(31.7		)	16.1			—			(15.6		)
Cash and cash equivalents at beginning of year	—			102.3			36.7			—			139.0
Cash and cash equivalents at end of year	$	—		$	70.6		$	52.8		$	—		$	123.4

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General and Basis of Presentation (Details) $ in Millions			1 Months Ended		5 Months Ended	12 Months Ended
	Aug. 12, 2015	Jan. 13, 2015	Jul. 31, 2017	Apr. 30, 2016 USD ($)	Dec. 31, 2017	Dec. 31, 2017 USD ($) Cokemaking_facility T	Dec. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Coke production experience, more than						55 years
Number of facilities | Cokemaking_facility						5
Period that Suncoke constructed the only greenfield cokemaking facilities in the US						30 years
Divestiture of coal business | $						$ 0.0	$ 12.8	$ 0.0
Ownership percentage held by public unitholders	44.60%	41.90%
Indiana Harbor
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Ownership percentage (as a percent)					14.80%	14.80%
Suncoke Inc
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)			53.90%		59.90%
Public Unitholders
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Ownership percentage held by public unitholders						38.10%
VISA SunCoke Limited
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Ownership percentage (as a percent)					49.00%	49.00%
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)						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)						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						40,000,000
Coal storage capacity						3,000,000
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)

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Summary of Significant Accounting Policies (Details)	12 Months Ended
	Dec. 31, 2017 USD ($) Employee	Dec. 31, 2016 USD ($)	Dec. 31, 2015 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	$ 1,100,000	$ 5,000,000	$ 3,700,000
Impairment of Long-Lived Assets
Goodwill and intangible asset impairment	0	0	0
Investment in Brazilian Cokemaking Operations
Cash at closing	20,500,000	20,500,000	$ 0
Incremental licensing fee per year	5,100,000
Income Taxes
Uncertain tax positions	$ 0	0
Labor Concentrations
Number of employees | Employee	909
Percentage of domestic employees	3.00%
Vitoria, Brazil
Labor Concentrations
Number of employees | Employee	270
Term of labor agreement	1 year
Cokemaking Operations
Labor Concentrations
Percentage of domestic employees	39.00%
ArcelorMittal Brazil
Investment in Brazilian Cokemaking Operations
Cash at closing	$ (20,500,000)	$ 20,500,000
Investment interest	200,000
Preferred dividend	$ 9,500,000
ArcelorMittal Brazil | Brazil Investment
Investment in Brazilian Cokemaking Operations
Consideration transferred				$ 41,000,000
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
Indiana Harbor
Impairment of Long-Lived Assets
Percent in excess of carrying value	45.00%

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Acquisitions and Dropdown Transactions (Acquisition of Partnership Common Units) (Details) - USD ($)	1 Months Ended	2 Months Ended	3 Months Ended								5 Months Ended	12 Months Ended
	Jul. 31, 2017	Feb. 15, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Apr. 17, 2017
Subsidiary, Sale of Stock [Line Items]
Total cost for purchase of public units												$ 48,700,000	$ 0	$ 0
Noncontrolling interests decrease												48,700,000		12,800,000
Decrease in additional paid-in capital												(12,000,000)
Deferred tax adjustment												7,100,000
Change in Ownership Interest
Net income (loss) attributable to SunCoke Energy, Inc.			$ 134,000,000	$ 11,600,000	$ (24,200,000)	$ 1,000,000	$ 17,000,000	$ 6,100,000	$ (4,600,000)	$ (4,100,000)		122,400,000	$ 14,400,000	$ (22,000,000)
Decrease in SunCoke Energy, Inc. equity for the purchase of additional interest in the Partnership												(12,000,000)
Changes from net income attributable to SunCoke Energy, Inc and transfers to noncontrolling interest												$ 110,400,000
Suncoke Inc
Subsidiary, Sale of Stock [Line Items]
Interest in partnership (as a percent)	53.90%										59.90%
Public Unit Purchase Program
Subsidiary, Sale of Stock [Line Items]
Authorized purchase amount															$ 50,000,000.0
Incremental authorized amount	$ 50,000,000
Number of shares purchased (in shares)												2,853,032
Total cost for purchase of public units												$ 48,700,000
Noncontrolling interests decrease												$ (29,600,000)
Public Unit Purchase Program | Subsequent Event
Subsidiary, Sale of Stock [Line Items]
Number of shares purchased (in shares)		132,188
Total cost for purchase of public units		$ 2,300,000
Change in Ownership Interest
Remaining balance		$ 49,000,000

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Acquisitions and Dropdown Transactions (Convent Marine Terminal Acquisition Narrative) (Details) - SunCoke Energy Partners, L.P. - Convent Marine Terminal - USD ($) shares in Millions, $ in Millions		12 Months Ended
	Aug. 12, 2015	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Business Acquisition [Line Items]
Interest acquired (as a percent)	100.00%
Total consideration	$ 403.1
Consideration transferred, cash payment	191.7
Debt assumed	114.9
Cash withheld to fund capital expenditures	$ 21.5
Revenue from acquisition to period end		$ 71.1	$ 62.7	$ 28.6
Operating income from acquisition to period end		$ 42.3	$ 46.5	$ 18.4
Common units
Business Acquisition [Line Items]
Stock issued, shares	4.8
Stock issued as consideration	$ 75.0

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Acquisitions and Dropdown Transactions (Convent Marine Terminal Acquisition Pro Forma Information) (Details) - Convent Marine Terminal - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
SunCoke Energy Partners, L.P.
Business Acquisition [Line Items]
Total revenues	$ 1,331.5	$ 1,223.3	$ 1,395.4
Net income	103.5	59.5	9.7
Suncoke Energy Inc
Business Acquisition [Line Items]
Net income	$ 122.4	$ 14.4	$ (22.3)
Earnings (loss) attributable to SunCoke Energy, Inc. per common share: basic (in USD per share)	$ 1.90	$ 0.22	$ (0.34)
Earnings (loss) attributable to SunCoke Energy, Inc. per common share, diluted (in USD per share)	$ 1.88	$ 0.22	$ (0.34)

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Acquisitions and Dropdown Transactions (Granite City Dropdowns Narrative) (Details) - USD ($) $ in Millions			12 Months Ended
	Aug. 12, 2015	Jan. 13, 2015	Dec. 31, 2017	Dec. 31, 2015
Business Acquisition [Line Items]
Interest in partnership (as a percent)	53.40%	56.10%
Ownership percentage held by public unitholders	44.60%	41.90%
Granite City
Business Acquisition [Line Items]
Ownership interest of general partnership (as a percent)	2.00%	2.00%
Decrease in SunCoke Energy, Inc. equity for the contribution of 75 percent interest in Granite City				$ 6.5
Gateway Energy and Coal Company, LLC
Business Acquisition [Line Items]
Interest acquired (as a percent)	23.00%
SunCoke Energy Partners, L.P. | Granite City
Business Acquisition [Line Items]
Interest acquired (as a percent)		75.00%
Fair value of total consideration transferred		$ 244.4
Consideration withheld to pre-fund anticipated environmental remediation costs		45.0
Decrease in SunCoke Energy, Inc. equity for the contribution of 75 percent interest in Granite City		6.5
SunCoke Energy Partners, L.P. | Gateway Energy and Coal Company, LLC
Business Acquisition [Line Items]
Fair value of total consideration transferred	$ 65.2
Debt assumed	46.9	148.3
Decrease in SunCoke Energy, Inc. equity for the contribution of 75 percent interest in Granite City	1.5
Common units | SunCoke Energy Partners, L.P.
Business Acquisition [Line Items]
Stock issued, value	17.9
Common units | SunCoke Energy Partners, L.P. | Granite City
Business Acquisition [Line Items]
Value assigned to equity	106.7	50.1
Public | Common Units - Public | SunCoke Energy Partners, L.P.
Business Acquisition [Line Items]
Increase from subsidiary equity issuance			$ 114.7
General Partner | SunCoke Energy Partners, L.P. | Granite City
Business Acquisition [Line Items]
Value assigned to equity		$ 1.0
Stock issued, value	$ 0.4

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Acquisitions and Dropdown Transactions (Granite City Dropdowns Effects of Changes in Company's Ownership) (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Business Acquisition [Line Items]
Net income attributable to SunCoke Energy, Inc.	$ 134.0	$ 11.6	$ (24.2)	$ 1.0	$ 17.0	$ 6.1	$ (4.6)	$ (4.1)	$ 122.4	$ 14.4	$ (22.0)
Granite City
Business Acquisition [Line Items]
Net income attributable to SunCoke Energy, Inc.											(22.0)
Decrease in SunCoke Energy, Inc. equity for the contribution of 75 percent interest in Granite City											(6.5)
Decrease in SunCoke Energy, Inc. for the contribution of an additional 23 percent interest in Granite City											(1.5)
Change from net loss attributable to SunCoke Energy, Inc. and dropdown transactions											$ (30.0)

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Customer Concentrations (Narrative) (Details) T in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2017 USD ($) Customer T	Dec. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)
Concentration Risk [Line Items]
Sales and other operating revenue	$ 1,331.5	$ 1,223.3	$ 1,362.7
Coal Logistics | The Cline Group | Sales Revenue, Net
Concentration Risk [Line Items]
Percent of Company sales and other operating revenue	49.40%	49.60%	27.10%
Coal Logistics | The Cline Group | Affiliated Entity
Concentration Risk [Line Items]
Sales and other operating revenue	$ 57.8	$ 53.5	$ 22.0
Accounts receivable	$ 9.7	$ 8.0
Coal Logistics | The Cline Group | Affiliated Entity | Sales Revenue, Net
Concentration Risk [Line Items]
Percent of Company sales and other operating revenue	4.30%	4.40%	1.60%
ArcelorMittal Brazil
Concentration Risk [Line Items]
Preferred dividend	$ 9.5
Customer Concentration Risk
Concentration Risk [Line Items]
Quantity of coke sold to three primary customers (in tons) | T	4
Number of primary customers in U.S | Customer	3
Customer Concentration Risk | Accounts Receivable
Concentration Risk [Line Items]
Number of primary customers in U.S | Customer	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, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Concentration Risk [Line Items]
Sales and other operating revenue	$ 359.6	$ 339.0	$ 323.2	$ 309.7	$ 325.6	$ 293.9	$ 292.7	$ 311.1	$ 1,331.5	$ 1,223.3	$ 1,362.7
Receivable from redemption of Brazilian investment	0.0				20.5				0.0	20.5
ArcelorMittal Brazil
Concentration Risk [Line Items]
Preferred dividend									9.5
ArcelorMittal Brazil | Accounts Receivable | Customer Concentration Risk
Concentration Risk [Line Items]
Receivable from redemption of Brazilian investment					20.5					20.5
ArcelorMittal | Sales Revenue, Net | Customer Concentration Risk
Concentration Risk [Line Items]
Sales and other operating revenue									$ 678.2	$ 596.6	$ 671.8
Percent of Company sales and other operating revenue									50.90%	48.80%	49.30%
ArcelorMittal | Accounts Receivable | Customer Concentration Risk
Concentration Risk [Line Items]
Accounts receivable due	25.7				47.7				$ 25.7	$ 47.7
AK Steel | Sales Revenue, Net | Customer Concentration Risk
Concentration Risk [Line Items]
Sales and other operating revenue									$ 331.3	$ 350.0	$ 395.4
Percent of Company sales and other operating revenue									24.90%	28.60%	29.00%
AK Steel | Accounts Receivable | Customer Concentration Risk
Concentration Risk [Line Items]
Accounts receivable due	13.2				10.7				$ 13.2	$ 10.7
U.S. Steel | Sales Revenue, Net | Customer Concentration Risk
Concentration Risk [Line Items]
Sales and other operating revenue									$ 214.1	$ 185.3	$ 212.7
Percent of Company sales and other operating revenue									16.10%	15.10%	15.60%
U.S. Steel | Accounts Receivable | Customer Concentration Risk
Concentration Risk [Line Items]
Accounts receivable due	$ 5.6				$ 5.7				$ 5.6	$ 5.7

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Income Taxes (Components of Income From Operations) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
The components of income before income tax expense
Domestic	$ 4.3	$ 52.5	$ 8.6
Foreign	17.6	15.6	14.5
Total	$ 21.9	$ 68.1	$ 23.1

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Income Taxes (Components of Income Tax Expense) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income taxes currently payable (receivable):
U.S. federal	$ 1.7	$ 2.7	$ (3.1)
State	(1.0)	(2.2)	(3.3)
Foreign	4.9	5.0	3.2
Total taxes currently payable (receivable)	5.6	5.5	(3.2)
Deferred tax (benefit) expense:
U.S. federal	(99.7)	(1.5)	(12.7)
State	12.5	4.6	7.1
Total deferred tax (benefit) expense	(87.2)	3.1	(5.6)
Income tax expense	$ (81.6)	$ 8.6	$ (8.8)

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Income Taxes (Reconciliation of Income Tax Expense to US Statutory Rate) (Details) - USD ($)		3 Months Ended		12 Months Ended
	Dec. 22, 2014	Dec. 31, 2017	Mar. 31, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Reconciliation of income tax expense
Income tax expense at 35 percent U.S. statutory rate				$ 7,700,000	$ 23,800,000	$ 8,000,000
Impact of Final Regulations				64,200,000	0	0
Impact of Tax Legislation		$ (154,700,000)		(154,700,000)	0	0
Income attributable to noncontrolling interests in partnerships				(5,400,000)	(15,600,000)	(11,200,000)
State and other income taxes, net of federal income tax effects				2,000,000	1,100,000	1,800,000
Change in valuation allowance				3,900,000	400,000	(8,800,000)
Investment in subsidiary				0	0	1,000,000
Other				700,000	(1,100,000)	400,000
Income tax expense				$ (81,600,000)	$ 8,600,000	$ (8,800,000)
Reconciliation of income tax expense (as a percent)
Income tax expense at 35 percent U.S. statutory rate				35.00%	35.00%	35.00%
Impact of Final Regulations				293.20%	0.00%	0.00%
Impact of Tax Legislation				(706.40%)	0.00%	0.00%
Income attributable to noncontrolling interests in partnerships				(24.70%)	(23.00%)	(48.30%)
State and other income taxes, net of federal income tax effects				9.10%	1.70%	7.70%
Change in valuation allowance				17.80%	0.60%	(38.00%)
Investment in subsidiary				(0.00%)	(0.00%)	4.40%
Other				3.20%	(1.60%)	1.20%
Total effective income tax expense				(372.80%)	12.70%	(38.00%)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Deferred income tax (benefit) expense				$ (87,200,000)	$ 3,100,000	$ (5,600,000)
Net deferred tax liability		(257,800,000)		(257,800,000)	(352,500,000)
Provisional net income tax benefit		154,700,000		154,700,000	0	0
Remeasurement of deferred income tax liabilities and assets				169,000,000
Provisional income tax expense (benefit)				14,300,000
Valuation allowance				19,000,000
Income tax expense attributable to noncontrolling interests				0
Investment in subsidiary				0	0	(1,000,000)
Valuation allowance		26,200,000		26,200,000	5,900,000
Income tax (benefit) expense				(81,600,000)	$ 8,600,000	(8,800,000)
IRS
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Deferred income tax (benefit) expense				148,600,000
Net deferred tax liability		(84,400,000)		(84,400,000)
Deferred tax expense			$ 64,200,000	64,200,000
Harold Keene Coal Co
Reconciliation of income tax expense
Investment in subsidiary				(11,900,000)
Income tax expense						(1,000,000)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Interest in Harold Keene Coal Companies sold	100.00%
Investment in subsidiary				11,900,000
Valuation allowance						9,800,000
Income tax (benefit) expense						$ (1,000,000)
Suncoke Inc
Reconciliation of income tax expense
Impact of Tax Legislation		(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

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Income Taxes (Components of Net Deferred Tax Liability) (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Deferred tax assets:
Retirement benefit liabilities	$ 7.1	$ 12.2
Black lung benefit liabilities	11.6	18.9
Share-based compensation	6.1	8.6
Federal tax credit carryforward	23.2	23.2
Foreign tax credit carryforward	19.0	14.0
Federal net operating loss	2.5	17.2
State tax credit carryforward, net of federal income tax effects	4.0	5.5
State net operating loss carryforward, net of federal income tax effects	13.9	8.4
Other liabilities not yet deductible	4.3	7.8
Total deferred tax assets	91.7	115.8
Less valuation allowance	(26.2)	(5.9)
Deferred tax asset, net	65.5	109.9
Deferred tax liabilities:
Properties, plants and equipment	(114.9)	(0.3)
Investment in partnerships	(208.4)	(462.1)
Total deferred tax liabilities	(323.3)	(462.4)
Net deferred tax liability	$ (257.8)	$ (352.5)

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Income Taxes (Narrative) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
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, 2017	Dec. 31, 2016
Components of inventories
Coal	$ 61.4	$ 49.4
Coke	12.3	7.7
Materials, supplies and other	37.3	35.4
Total inventories	$ 111.0	$ 92.5

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Properties, Plants, and Equipment, Net (Components) (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Property, Plant and Equipment [Line Items]
Gross investment, at cost	$ 2,234.5	$ 2,168.5
Less: Accumulated depreciation	(733.2)	(625.9)
Total properties, plants and equipment, net	1,501.3	1,542.6
Coke and energy plant, machinery and equipment
Property, Plant and Equipment [Line Items]
Gross investment, at cost	1,812.0	1,767.1
Less: Accumulated depreciation	(475.8)	(410.4)
Logistics plant, machinery and equipment
Property, Plant and Equipment [Line Items]
Gross investment, at cost	216.2	214.4
Land and land improvements
Property, Plant and Equipment [Line Items]
Gross investment, at cost	118.7	118.7
Construction-in-progress
Property, Plant and Equipment [Line Items]
Gross investment, at cost	51.9	33.4
Other
Property, Plant and Equipment [Line Items]
Gross investment, at cost	$ 35.7	$ 34.9

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Properties, Plants, and Equipment, Net (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Property, Plant and Equipment [Line Items]
Accumulated depreciation	$ 733.2	$ 625.9
Coke and energy plant, machinery and equipment
Property, Plant and Equipment [Line Items]
Coke and energy plant, machinery and equipment	1,337.3	1,281.5
Accumulated depreciation	$ 475.8	$ 410.4

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Goodwill and Other Intangible Assets - Goodwill (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2017
Goodwill
Goodwill, beginning of period	$ 71,100,000
Goodwill, adjustments	5,800,000
Goodwill, end of period	76,900,000
Contingent consideration adjustment	(600,000)
Goodwill	71,100,000	$ 76,900,000
Convent Marine Terminal
Goodwill
Contingent consideration adjustment	6,400,000
Domestic Coke
Goodwill
Goodwill, beginning of period	3,400,000
Goodwill, adjustments	0.0
Goodwill, end of period	3,400,000
Goodwill	3,400,000	3,400,000
Coal Logistics
Goodwill
Goodwill, beginning of period	67,700,000
Goodwill, adjustments	5,800,000
Goodwill, end of period	73,500,000
Goodwill	$ 67,700,000	$ 73,500,000

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Goodwill and Other Intangible Assets - Narrative (Details) - USD ($) $ in Millions		12 Months Ended
	Oct. 01, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Oct. 01, 2017
Goodwill [Line Items]
Total amortization expense		$ 11.1	$ 11.2	$ 5.1
Permits
Goodwill [Line Items]
Useful life		25 years
Permits | Convent Marine Terminal
Goodwill [Line Items]
Useful life		27 years
Remaining renewal term		3 years 4 months 24 days
Coal Logistics
Goodwill [Line Items]
Fair value of reporting unit in excess of carrying value, percent					25.00%
Change in discount rate that would not impact goodwill impairment test	1.00%
Goodwill | Coal Logistics
Goodwill [Line Items]
Discount rate on discounted cash flow analysis	14.00%

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Goodwill and Other Intangible Assets - Gross and Net Intangible Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	$ 200.6	$ 200.6
Accumulated Amortization	32.7	21.6
Total	$ 167.9	179.0
Customer contracts
Finite-Lived Intangible Assets [Line Items]
Weighted - Average Remaining Amortization (in years)	5 years
Gross Carrying Amount	$ 31.7	31.7
Accumulated Amortization	13.8	9.9
Total	$ 17.9	21.8
Customer relationships
Finite-Lived Intangible Assets [Line Items]
Weighted - Average Remaining Amortization (in years)	14 years
Gross Carrying Amount	$ 28.7	28.7
Accumulated Amortization	5.7	3.8
Total	$ 23.0	24.9
Permits
Finite-Lived Intangible Assets [Line Items]
Weighted - Average Remaining Amortization (in years)	25 years
Gross Carrying Amount	$ 139.0	139.0
Accumulated Amortization	12.2	7.1
Total	$ 126.8	131.9
Trade name
Finite-Lived Intangible Assets [Line Items]
Weighted - Average Remaining Amortization (in years)	1 year
Gross Carrying Amount	$ 1.2	1.2
Accumulated Amortization	1.0	0.8
Total	$ 0.2	$ 0.4

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Goodwill and Other Intangible Assets - Schedule of Future Amortization Expense (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]
2018	$ 11.0
2019	10.9
2020	10.7
2021	10.3
2022	10.3
Thereafter	114.7
Total	$ 167.9	$ 179.0

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Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Reconciliation of changes in the asset retirement obligation
Beginning Balance	$ 13.9	$ 22.2
Liabilities settled	(0.7)	(0.7)
Accretion expense	1.0	1.1
Disposal of coal mining liabilities		(9.4)
Revisions in estimated cash flows	(0.2)	0.7
Ending Balance	$ 14.0	$ 13.9

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Retirement Benefits Plans (Narrative) (Details) - USD ($)		12 Months Ended
	Jan. 01, 2011	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Company's pretax income and the aggregate compensation levels of participating employees		$ 6,400,000	$ 5,600,000	$ 6,500,000
Defined Benefit Plan
Defined Benefit Plan Disclosure [Line Items]
Settlement loss		0	0	12,600,000
Benefit obligations		0	0
Postretirement Benefit Plans
Defined Benefit Plan Disclosure [Line Items]
Benefit obligations		31,300,000	32,300,000	34,800,000
Years of service, less than	10 years
Curtailment gain		0	$ 0	$ 4,100,000
Amortization of net gains (losses)		600,000
Prior service benefit amortization		$ 700,000
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%
Effect of one percentage point increase on service and interest cost components, less than		$ 100,000	$ 100,000
Effect of one percentage point decrease on service and interest cost components, less than		100,000	100,000
Effect of one percentage point increase on accumulated postretirement benefit obligation, less than		100,000	100,000
Effect of one percentage point decrease on accumulated postretirement benefit obligation, less than		$ 100,000	$ 100,000

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Retirement Benefits Plans (Defined Benefit Plan Expense (Benefit) Components) (Details) - Defined Benefit Plan - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Interest cost on benefit obligations	$ 0.0	$ 0.0	$ 0.7
Expected return on plan assets	0.0	0.0	(0.7)
Settlement loss	0.0	0.0	12.6
Amortization of:
Actuarial losses	0.0	0.0	0.5
Total expense (benefit)	$ 0.0	$ 0.0	$ 13.1

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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, 2017	Dec. 31, 2016	Dec. 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Interest cost on benefit obligations	$ 1.1	$ 1.3	$ 1.3
Amortization of:
Actuarial losses	0.9	0.7	0.8
Prior service benefit	(0.7)	(0.7)	(1.2)
Curtailment gain	0.0	0.0	(4.1)
Total expense (benefit)	$ 1.3	$ 1.3	$ (3.2)

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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, 2017	Dec. 31, 2016	Dec. 31, 2015
Postretirement Benefit Plans
Defined Benefit Plan Disclosure [Line Items]
Discount Rate (as a percent)	3.65%	3.80%	3.45%

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Retirement Benefits Plans (Amounts Recognized as Components of Other Comprehensive (Loss) Income) (Details) - USD ($)		12 Months Ended
	Jan. 01, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Retirement benefit plan funded status adjustments:
Actuarial gains (losses)		$ (200,000)	$ 0	$ (5,200,000)
Total		800,000	200,000	400,000
Defined Benefit Plan
Reclassifications to earnings of:
Actuarial loss amortization		0	0	500,000
Prior service benefit amortization		0	0	0
Curtailment gain		0	0	0
Settlement loss		0	0	12,600,000
Retirement benefit plan funded status adjustments:
Actuarial gains (losses)		0	0	900,000
Prior service (cost) benefit		0	0	0
Total		0	0	14,000,000
Postretirement Benefit Plans
Reclassifications to earnings of:
Actuarial loss amortization		900,000	700,000	800,000
Prior service benefit amortization		(700,000)	(700,000)	(1,200,000)
Curtailment gain		0	0	(4,100,000)
Settlement loss		0	0	0
Retirement benefit plan funded status adjustments:
Actuarial gains (losses)		(1,100,000)	(1,800,000)	(1,400,000)
Prior service (cost) benefit		0	1,500,000	0
Total		$ (900,000)	$ (300,000)	$ (5,900,000)
Subsidy to participants per year	$ 3,600

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Retirement Benefits Plans (Components of the Changes in Benefit Obligations and Fair Value of Plan Assets) (Details) - USD ($)		12 Months Ended
	Jan. 01, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Change in Benefit Obligation
Current portion of retirement liabilities classified in accrued liabilities		$ 3,100,000	$ 3,300,000
Postretirement Benefit Plans
Change in Benefit Obligation
Benefit obligations at beginning of year	$ 32,300,000	32,300,000	34,800,000
Interest cost		1,100,000	1,300,000	$ 1,300,000
Actuarial losses		1,100,000	1,800,000
Plan amendments		0	(1,500,000)
Benefits paid		(3,200,000)	(4,100,000)
Benefit obligations at end of year		31,300,000	32,300,000	34,800,000
Subsidy to participants per year	$ 3,600
Prior service (cost) benefit		$ 0	$ 1,500,000	$ 0

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Retirement Benefits Plans (Cumulative Amounts Not Yet Recognized in Net Income) (Details) - Postretirement Benefit Plans - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Cumulative amounts not yet recognized in net income:
Actuarial losses	$ 11.8	$ 11.6
Prior service benefits	(3.4)	(4.1)
Accumulated other comprehensive loss (before related tax benefit)	$ 8.4	$ 7.5

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Retirement Benefits Plans (Expected Benefit Payments) (Details) - Postretirement Benefit Plans $ in Millions	Dec. 31, 2017 USD ($)
Regulatory Liabilities [Line Items]
2018	$ 3.1
2019	3.0
2020	2.9
2021	2.8
2022	2.6
2023 through 2026	$ 10.1

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Retirement Benefits Plans (Discount Rate) (Details)	Dec. 31, 2017	Dec. 31, 2016
Postretirement Benefit Plans
Defined Benefit Plan Disclosure [Line Items]
Discount rate (as a percent)	3.35%	3.65%

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Accrued Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Balance Sheet Related Disclosures [Abstract]
Accrued benefits	$ 21.3	$ 21.4
Current portion of postretirement benefit obligation	3.1	3.3
Other taxes payable	10.5	10.4
Current portion of black lung liability	5.4	4.8
Accrued legal	5.6	4.4
Other	7.3	5.5
Total accrued liabilities	$ 53.2	$ 49.8

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Debt and Financing Obligation (Schedule of Debt) (Details) - USD ($)	Dec. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Total borrowings	$ 887,300,000	$ 858,000,000
(Discount) premium	(5,900,000)	7,500,000
Debt issuance costs	(17,700,000)	(11,400,000)
Total debt and financing obligation	863,700,000	854,100,000
Current portion of long-term debt and financing obligation	2,600,000	4,900,000
Long-term debt and financing obligation	861,100,000	849,200,000
7.500 percent senior notes, due 2025 (2025 Partnership Notes) | Senior notes
Debt Instrument [Line Items]
Total borrowings	$ 700,000,000	0
Interest rate on senior notes (as a percent)	7.50%
7.375 percent senior notes, due 2020 (''2020 Partnership Notes'') | Senior notes
Debt Instrument [Line Items]
Total borrowings	$ 0	463,000,000
Interest rate on senior notes (as a percent)	7.375%
7.625 percent senior notes, due 2019 (2019 Notes) | Senior notes
Debt Instrument [Line Items]
Total borrowings	$ 44,600,000	44,600,000
Interest rate on senior notes (as a percent)	7.625%
Partnership's term loan, due 2019 (Partnership Term Loan) | Line of Credit
Debt Instrument [Line Items]
Total borrowings	$ 0	50,000,000
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 and 2019, respectively (Partnership Revolver) | Line of Credit | Revolving credit facility
Debt Instrument [Line Items]
Total borrowings	130,000,000	172,000,000
Partnership's promissory note payable, due 2021 (Promissory Note) | Senior notes
Debt Instrument [Line Items]
Total borrowings	0	113,200,000
5.82 percent financing obligation, due 2021 (Partnership Financing Obligation) | Financing Obligation
Debt Instrument [Line Items]
Total borrowings	$ 12,700,000	$ 15,200,000
Interest rate on senior notes (as a percent)	5.82%

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Debt and Financing Obligation (Issuance of 2025 Partnership Senior Notes (Details) - Senior notes - 7.500 percent senior notes, due 2025 (2025 Partnership Notes) - USD ($)	1 Months Ended	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2017	May 31, 2017
Debt Instrument [Line Items]
Interest rate on senior notes (as a percent)	7.50%	7.50%
SunCoke Energy Partners, L.P.
Debt Instrument [Line Items]
Face amount of debt	$ 70,000,000	$ 70,000,000	$ 630,000,000
Interest rate on senior notes (as a percent)	7.50%	7.50%
Proceeds from issuance of senior debt	$ 693,700,000
Debt discount	6,300,000	$ 6,300,000
Debt issuance costs, net	$ 12,900,000	$ 12,900,000
Change of control percent		101.00%
SunCoke Energy Partners, L.P. | Before June 15, 2020
Debt Instrument [Line Items]
Redemption percentage		35.00%
Percentage of principal amount		107.50%
SunCoke Energy Partners, L.P. | Anytime prior to June 15, 2020
Debt Instrument [Line Items]
Percentage of principal amount		100.00%

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Debt and Financing Obligation (Purchase, Redemption and Repayment of Partnership Debt) (Details) - USD ($)	3 Months Ended	12 Months Ended
	Jun. 30, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Repayment of revolving credit facility		$ 392,000,000	$ 98,400,000	$ 50,000,000
Outstanding balance		887,300,000	858,000,000
Loss (gain) on extinguishment of debt, net	$ 20,200,000	20,400,000	(25,000,000)	$ 500,000
Senior notes | 7.375 percent senior notes, due 2020 (''2020 Partnership Notes'')
Debt Instrument [Line Items]
Outstanding balance		0	463,000,000
Senior notes | Partnership's promissory note payable, due 2021 (Promissory Note)
Debt Instrument [Line Items]
Outstanding balance		0	113,200,000
Line of Credit | Partnership's term loan, due 2019 (Partnership Term Loan)
Debt Instrument [Line Items]
Outstanding balance		0	50,000,000
Line of Credit | Partnership's revolving credit facility, due 2022 and 2019, respectively (Partnership Revolver) | Revolving credit facility
Debt Instrument [Line Items]
Outstanding balance		130,000,000	$ 172,000,000
SunCoke Energy Partners, L.P. | Senior notes | 7.375 percent senior notes, due 2020 (''2020 Partnership Notes'')
Debt Instrument [Line Items]
Face amount of debt		463,000,000
Redemption premium		18,700,000
Loss (gain) on extinguishment of debt, net		19,200,000
Debt issuance costs, gross		7,100,000
Unamortized premium		(6,600,000)
SunCoke Energy Partners, L.P. | Senior notes | Partnership's promissory note payable, due 2021 (Promissory Note)
Debt Instrument [Line Items]
Outstanding balance		112,600,000
SunCoke Energy Partners, L.P. | Senior notes | Partnership's revolving credit facility, due 2022 and 2019, respectively (Partnership Revolver)
Debt Instrument [Line Items]
Outstanding balance		42,000,000
SunCoke Energy Partners, L.P. | Line of Credit | Partnership's term loan, due 2019 (Partnership Term Loan)
Debt Instrument [Line Items]
Repayment of revolving credit facility		50,000,000
SunCoke Energy Partners, L.P. | Line of Credit | Partnership's revolving credit facility, due 2022 and 2019, respectively (Partnership Revolver) | Revolving credit facility
Debt Instrument [Line Items]
Outstanding balance		$ 130,000,000

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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, 2016
Sale Leaseback Transaction [Line Items]
Initial lease period	60 months
Interest rate	5.82%
Buyout option period	48 months
Percent of original lease equipment cost	34.50%

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Debt and Financing Obligation (Redemption of 2019 Notes) (Details) - Subsequent Event	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
Line of Credit | Term Loan Due 2022
Debt Instrument [Line Items]
Principal amount of term loan	$ 45,000,000.0

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Debt and Financing Obligation (Revolving Facility) (Details) - USD ($)	1 Months Ended	12 Months Ended
	Feb. 28, 2017	Dec. 31, 2017	May 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Outstanding balance		$ 887,300,000		$ 858,000,000
Revolving credit facility | Line of Credit | SunCoke's revolving credit facility, due 2018 (Revolving Facility)
Debt Instrument [Line Items]
Reduction of debt	$ 25,000,000
Maximum borrowing capacity	$ 125,000,000
Line of credit debt issuance costs, gross		600,000
Debt issuance costs, gross		100,000
Revolving credit facility | Line of Credit | SunCoke's revolving credit facility, due 2022 (Revolving Facility)
Debt Instrument [Line Items]
Maximum borrowing capacity			$ 100,000,000
Line of credit debt issuance costs, gross		1,100,000
Amortization of debt issuance costs		300,000
Letters of credit outstanding under revolving facility		26,500,000
Outstanding balance		0		$ 0
Remaining borrowing capacity		$ 73,500,000
Basis spread on variable rate		1.75%
Unused capacity commitment fee		0.40%
The weighted-average interest rate for borrowings outstanding under credit agreement (as a percent)				2.80%	2.30%

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Debt and Financing Obligation (Partnership Revolver) (Details) - USD ($)		12 Months Ended
	Nov. 03, 2015	Dec. 31, 2017	May 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Line of Credit Facility [Line Items]
Outstanding balance		$ 887,300,000		$ 858,000,000
Partnership's revolving credit facility, due 2022 and 2019, respectively (Partnership Revolver) | Line of Credit | Revolving credit facility
Line of Credit Facility [Line Items]
Outstanding balance		130,000,000		$ 172,000,000
SunCoke Energy Partners, L.P. | Partnership's revolving credit facility, due 2022 and 2019, respectively (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
Line of credit debt issuance costs, gross		3,000,000
Amortization of debt issuance costs		800,000
Letters of credit outstanding under revolving facility		1,900,000
Outstanding balance		130,000,000
Remaining letters of credit agreement amount		$ 153,100,000
SunCoke Energy Partners, L.P. | Partnership revolver, due 2019 | Line of Credit | LIBOR
Line of Credit Facility [Line Items]
Basis spread on variable rate	2.50%
SunCoke Energy Partners, L.P. | Partnership revolver, due 2019 | Line of Credit | Base Rate
Line of Credit Facility [Line Items]
Basis spread on variable rate	1.50%
SunCoke Energy Partners, L.P. | Partnership revolver, due 2019 | Line of Credit | Revolving credit facility
Line of Credit Facility [Line Items]
Principal amount of term loan			$ 250,000,000
Unused capacity commitment fee		0.40%
The weighted-average interest rate for borrowings outstanding under credit agreement (as a percent)		3.80%		3.30%	2.90%

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Debt and Financing Obligation (Covenants) (Details)	Jun. 30, 2020	Dec. 31, 2017 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 revolver, due 2019 | 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 revolver, due 2019 | 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, 2017	Dec. 31, 2016
Debt Disclosure [Abstract]
2018	$ 2.6
2019	47.4
2020	7.3
2021	0.0
2022	130.0
2023-Thereafter	700.0
Total debt	$ 887.3	$ 858.0

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Commitments and Contingent Liabilities (Lease Obligations) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Rental expense, net of sublease income	$ 7.3	$ 8.7	$ 8.5
Aggregate amount of future minimum annual rentals applicable to noncancelable operating leases and related subleases
2018	3.1
2019	2.4
2020	1.4
2021	0.9
2022	0.3
2023-Thereafter	1.1
Total	$ 9.2

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Commitments and Contingent Liabilities (Legal Matters) (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2019	Dec. 31, 2017	Dec. 31, 2014	Dec. 31, 2015
Haverhill and Granite City
Loss Contingencies [Line Items]
Estimate possible loss				$ 2.2
Expected spending on environmental liability		$ 145.0
Cost of capital projects		111.0	$ 7.0
Funds retained fro environmental remediation project		119.0
Haverhill and Granite City | Forecast
Loss Contingencies [Line Items]
Funds retained fro environmental remediation project	$ 20.0
EPA | Accrued Liabilities
Loss Contingencies [Line Items]
Litigation Settlement, Expense		$ 2.5

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Commitments and Contingent Liabilities (Black Lung Benefit Liabilities) (Details) - Black Lung Benefit $ in Millions	12 Months Ended
	Dec. 31, 2017 USD ($) claim	Dec. 31, 2016 USD ($) claim	Dec. 31, 2015 USD ($)
Defined Benefit Plan Disclosure [Line Items]
Discount rate (as a percent)	3.30%	3.70%
Active claims | claim	351	349
Estimated liability	$ 50.3	$ 50.2
Increase in black lung expense	1.2
Current portion of black lung liability	5.4	4.8
Payments	7.4	7.8	$ 3.8
Expense	$ 7.5	$ 8.1	$ 9.8

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Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Components of accumulated other comprehensive (loss) income (net of related income taxes)
Beginning balance	$ 639.9	$ 622.8	$ 705.4
Other comprehensive loss before reclassifications	(0.5)	1.0
Amounts reclassified from accumulated other comprehensive loss	0.2
Retirement benefit plans funded status adjustment	(0.8)	(0.2)	(0.4)
Net current period other comprehensive loss	(1.1)	0.8
Ending balance	659.6	639.9	622.8
Benefit Plans
Components of accumulated other comprehensive (loss) income (net of related income taxes)
Beginning balance	(4.8)	(4.6)
Other comprehensive loss before reclassifications	0.0	0.0
Amounts reclassified from accumulated other comprehensive loss	0.2	0.0	5.2
Retirement benefit plans funded status adjustment	(0.8)	(0.2)
Net current period other comprehensive loss	(0.6)	(0.2)
Ending balance	(5.4)	(4.8)	(4.6)
Tax benefit associated with benefit plans	3.0	2.7
Currency Translation Adjustments
Components of accumulated other comprehensive (loss) income (net of related income taxes)
Beginning balance	(14.2)	(15.2)
Other comprehensive loss before reclassifications	(0.5)	1.0
Amounts reclassified from accumulated other comprehensive loss	0.0
Retirement benefit plans funded status adjustment	0.0	0.0
Net current period other comprehensive loss	(0.5)	1.0
Ending balance	(14.7)	(14.2)	(15.2)
AOCI Attributable to Parent [Member]
Components of accumulated other comprehensive (loss) income (net of related income taxes)
Beginning balance	(19.0)	(19.8)	(21.5)
Retirement benefit plans funded status adjustment	(0.8)	(0.2)	(0.4)
Ending balance	(20.1)	$ (19.0)	$ (19.8)
VISA SunCoke Limited
Components of accumulated other comprehensive (loss) income (net of related income taxes)
Accumulated other comprehensive loss	$ (9.0)

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Accumulated Other Comprehensive Loss Reclassification Adjustments From AOCI (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total, net of tax	$ (0.2)
Benefit Plans
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total before taxes	(0.2)	$ 0.0	$ (8.6)
Income tax cost (benefit)	0.0	0.0	3.4
Total, net of tax	(0.2)	0.0	(5.2)
Actuarial loss
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total before taxes	(0.9)	(0.7)	(1.3)
Prior service benefit
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total before taxes	0.7	0.7	1.2
Curtailment gain
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total before taxes	0.0	0.0	4.1
Settlement loss
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total before taxes	$ 0.0	$ 0.0	$ (12.6)

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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, 2017 USD ($) Installment shares	Dec. 31, 2016 USD ($) shares	Dec. 31, 2015 USD ($) 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 | $			$ 300,000	$ 0	$ 100,000
Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted (shares)			22,628	0	297,514
Number of annual installment in which stock option exercisable | Installment			3
Period from grant date for annual installment (in years)			1 year
Total fair value of non-option award units vested | $			$ 2,300,000	$ 3,700,000	$ 4,600,000
Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted (shares)			385,758
Performance Share Units | December 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted (shares)		237,610
Performance Share Units | December 31, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted (shares)	148,148
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)						1,600,000
Common stock issuable pursuant to new awards (in shares)						6,000,000
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
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]
Percent of award allocation			50.00%
Measurement period			3 years
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 Ppercentage			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 Ppercentage			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 in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017 USD ($) Installment $ / shares shares
Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average exercise price (in USD per share)	$ 10.14
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]
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)	$ 9.00
Number of trading days	15 days
Measurement period	3 years
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
Maximum vesting value | $	$ 4.9
SunCoke LTPEP | 2017 grant | Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares granted (shares) | shares	157,196
Weighted average exercise price (in USD per share)	$ 10.29
Weighted-average fair value stock option (in dollars per share)	$ 5.32
SunCoke LTPEP | 2017 grant | Performance Based Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares granted (shares) | shares	80,595
Weighted average exercise price (in USD per share)	$ 9.85
Weighted-average fair value stock option (in dollars per share)	5.17
Closing common stock price (USD per share)	$ 14.78
SunCoke LTPEP | 2016 March grant | Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares granted (shares) | shares	90,925
Weighted average exercise price (in USD per share)	$ 6.03
Weighted-average fair value stock option (in dollars per share)	$ 2.78
SunCoke LTPEP | 2016 March grant | Performance Based Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares granted (shares) | shares	90,925
Weighted average exercise price (in USD per share)	$ 6.03
Weighted-average fair value stock option (in dollars per share)	2.42
Closing common stock price (USD per share)	$ 9.50
SunCoke LTPEP | 2016 March grant | Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date Fair Value | $	$ 2.0
SunCoke LTPEP | 2016 March grant | 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]
Number of shares granted (shares) | shares	67,167
Weighted-average fair value stock option (in dollars per share)	$ 10.51
SunCoke LTPEP | 2016 March grant | Performance Share Units | Pre-tax return of capital for coke business
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares granted (shares) | shares	201,500
Weighted-average fair value stock option (in dollars per share)	$ 6.35
SunCoke LTPEP | 2016 February grant | Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares granted (shares) | shares	95,001
Weighted average exercise price (in USD per share)	$ 3.80
Weighted-average fair value stock option (in dollars per share)	$ 1.71
SunCoke LTPEP | 2016 February grant | Performance Based Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares granted (shares) | shares	58,448
Weighted average exercise price (in USD per share)	$ 3.80
Weighted-average fair value stock option (in dollars per share)	$ 1.06
SunCoke LTPEP | 2016 February grant | Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date Fair Value | $	$ 1.2
SunCoke LTPEP | 2016 February grant | 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]
Number of shares granted (shares) | shares	105,210
Weighted-average fair value stock option (in dollars per share)	$ 5.66
SunCoke LTPEP | 2016 February grant | Performance Share Units | Pre-tax return of capital for coke business
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares granted (shares) | shares	105,210
Weighted-average fair value stock option (in dollars per share)	$ 5.81
SunCoke LTPEP | 2015 grant | Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares granted (shares) | shares	593,976
Weighted average exercise price (in USD per share)	$ 16.33
Weighted-average fair value stock option (in dollars per share)	$ 4.87
SunCoke LTPEP | 2015 grant | Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date Fair Value | $	$ 2.4
SunCoke LTPEP | 2015 grant | 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]
Number of shares granted (shares) | shares	67,135
Weighted-average fair value stock option (in dollars per share)	$ 16.90
SunCoke LTPEP | 2015 grant | Performance Share Units | Pre-tax return of capital for coke business
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares granted (shares) | shares	67,136
Weighted-average fair value stock option (in dollars per share)	$ 18.27

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Share-Based Compensation (Assumptions Used to Calculate Value of Stock Options) (Details) - Stock Options	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Risk free interest rate	2.11%	1.25%	1.66%
Expected term	6 years	5 years	5 years
Volatility	53.00%	52.00%	36.00%
Dividend yield	0.00%	0.00%	1.64%

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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, 2017	Dec. 31, 2016
Number of Options (in shares)
Outstanding at the beginning of period (shares)	2,923,668
Granted (shares)	237,791
Exercised (shares)	(10,252)
Forfeited (shares)	(5,092)
Outstanding at end of period (shares)	3,146,115	2,923,668
Exercisable at end of period (shares)	2,530,129
Expected to vest at end of period (shares)	615,986
Weighted Average Exercise Price (in dollars per share)
Outstanding at beginning of period (in USD per share)	$ 15.69
Granted (in USD per share)	10.14
Exercised (in USD per share)	9.66
Forfeited (in USD per share)	20.70
Outstanding at end of period (in USD per share)	15.31	$ 15.69
Exercisable at end of period (in USD per share)	16.64
Expected to vest at end of period (in USD per share)	$ 9.87
Weighted Average Remaining Contractual Term (years)
Weighted average remaining contractual term (in years)	5 years 7 months 6 days	6 years 3 months 18 days
Exercisable at end of period	4 years 9 months 18 days
Expected to vest at end of period	8 years 4 months 24 days
Aggregate Intrinsic Value (millions)
Aggregate intrinsic value	$ 2.8	$ 2.2
Exercisable at end of period	0.7
Expected to vest at end of period	$ 2.1

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Share-Based Compensation (Restricted Stock Units and Performance Share Units Granted) (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted (shares)	22,628	0	297,514
Weighted Average Grant-Date Fair Value (in USD per share)	$ 9.85		$ 14.51
Grant Date Fair Value	$ 0.2		$ 4.3
Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted (shares)	385,758
Weighted Average Grant-Date Fair Value (in USD per share)	$ 11.61
Grant Date Fair Value	$ 4.5

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Share-Based Compensation (Summary of RSUs and PSUs Outstanding) (Details) - $ / shares	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Restricted Stock Units (RSUs)
Number of Units
Outstanding at beginning of period (shares)	224,940
Granted (shares)	22,628	0	297,514
Vested (shares)	(135,522)
Forfeited (shares)	(5,649)
Outstanding at end of period (shares)	106,397	224,940
Weighted Average Grant- Date Fair Value (in dollars per share)
Outstanding at beginning of period (in USD per share)	$ 16.18
Granted (in USD per share)	9.85		$ 14.51
Vested (in USD per share)	17.22
Forfeited (in USD per share)	11.47
Outstanding at end of period (in USD per share)	$ 13.53	$ 16.18
Performance Share Units
Number of Units
Outstanding at beginning of period (shares)	666,713
Granted (shares)	385,758
Vested (shares)	(11,071)
Forfeited (shares)	(258,619)
Outstanding at end of period (shares)	782,781	666,713
Weighted Average Grant- Date Fair Value (in dollars per share)
Outstanding at beginning of period (in USD per share)	$ 10.51
Granted (in USD per share)	11.61
Vested (in USD per share)	22.30
Forfeited (in USD per share)	13.72
Outstanding at end of period (in USD per share)	$ 10.06	$ 10.51

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Share-Based Compensation (Liability Classified Awards Narrative) (Details) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017 USD ($) Installment $ / 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	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) | $ / shares	$ 9.82	$ 3.82
Closing price (USD per share) | $ / shares	$ 11.99
Liability | $	$ 1.2
Current liabilities | $	0.9
Noncurrent liabilities | $	$ 0.3
Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted (shares) | shares	385,758
Granted (in USD per share) | $ / shares	$ 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 | $	$ 0.7	$ 0.9
Percent of award allocation	50.00%
Measurement period	3 years	3 years
Closing common stock price (USD per share) | $ / shares		$ 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, 2017	Dec. 31, 2016	Dec. 31, 2015
Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Cost	$ 0.7
Recognition Period	2 years
Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Cost	$ 0.3
Recognition Period	1 year 2 months
Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Cost	$ 2.4
Recognition Period	2 years 9 months
Restricted Stock Units Settled in Cash
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Cost	$ 1.3
Recognition Period	1 year 8 months
Suncoke LTCIP | Cash Incentive Award
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Cost	$ 0.4
Recognition Period	1 year 11 months
Selling, General and Administrative Expenses | Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	$ 1.3	$ 2.1	$ 2.5
Net of tax	0.8	1.3	1.6
Selling, General and Administrative Expenses | Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	1.1	2.6	4.2
Net of tax	0.7	1.7	2.7
Selling, General and Administrative Expenses | Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	1.9	1.4	0.5
Net of tax	1.2	0.9	0.3
Selling, General and Administrative Expenses | Equity Classified Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	4.3	6.1	7.2
Net of tax	2.7	3.9	4.6
Selling, General and Administrative Expenses | Restricted Stock Units Settled in Cash
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	1.0	0.7	0.0
Net of tax	0.6	0.5	0.0
Selling, General and Administrative Expenses | Suncoke LTCIP | Cash Incentive Award
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	0.2	0.1	0.0
Net of tax	0.1	0.1	0.0
Selling, General and Administrative Expenses | Suncoke LTCIP | Liability Classified Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	1.2	0.8	0.0
Net of tax	$ 0.7	$ 0.6	$ 0.0

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Share-Based Compensation (Summary of Share-Based Compensation Expense Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Director
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost [Line Items]
Compensation expense	$ 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, 2017	Dec. 31, 2016	Dec. 31, 2015
Earnings Per Share [Abstract]
Weighted-average number of common shares outstanding-basic	64.3	64.2	65.0
Add: effect of dilutive share-based compensation awards	0.9	0.2	0.0
Weighted-average number of shares-diluted	65.2	64.4	65.0

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Earnings Per Share - Antidilutive Shares Excluded From EPS Calculation (Details) - shares shares in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
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)	3.0	3.4	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)	2.9	3.0	2.9
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	0.2	0.5
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	0.2	0.0

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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, 2017	Dec. 31, 2016	Dec. 31, 2015	Mar. 31, 2016
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration	$ 1.7	$ 10.1	$ 0.0
Contingent consideration adjustment		(0.6)
Cash Equivalents | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents measured at fair value	5.5	4.4
Convent Marine Terminal
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration adjustment		6.4
SunCoke Energy Partners, L.P. | Convent Marine Terminal
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration	2.5	4.2
Cost of Products Sold and Operating Expenses
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration	$ (1.7)	$ (6.4)
Other Noncurrent Liabilities | SunCoke Energy Partners, L.P. | Convent Marine Terminal | Fair Value, Inputs, Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration				$ 3.7

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Fair Value Measurements (Non-Financial Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis) (Details)	12 Months Ended
	Dec. 31, 2015 USD ($) $ / T
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity method investment | $	$ 0
VISA SunCoke Limited
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Loss on impairments | $	$ 19,400,000
Gross margin per ton on coke imports (in USD per ton) | $ / T	5
Change in investment valuation from $5 change in gross margin per ton (in USD per ton) | $	$ 8,000,000
VISA SunCoke Limited | Fair Value, Inputs, Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Discount rate on discounted cash flow analysis	13.50%
VISA SunCoke Limited | Fair Value, Inputs, Level 3 | Minimum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Gross margin per ton (in USD per ton) | $ / T	(8)
VISA SunCoke Limited | Fair Value, Inputs, Level 3 | Maximum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Gross margin per ton (in USD per ton) | $ / T	13

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Fair Value Measurements (Certain Financial Assets and Liabilities not Measured at Fair Value) (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Fair Value Disclosures [Abstract]
Fair value of long-term debt	$ 919.7	$ 854.4
Outstanding balance	$ 887.3	$ 858.0

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Business Segment Information - Narrative (Details)	12 Months Ended
	Dec. 31, 2017 Cokemaking_facility segment T
Revenues from External Customers and Long-Lived Assets [Line Items]
Number of reportable segments | segment	3
Number of facilities | Cokemaking_facility	5
Coal Logistics
Revenues from External Customers and Long-Lived Assets [Line Items]
Coal handling capacity (in tons) | T	40,000,000

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Business Segment Information - Segment Profit or Loss (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
Sales and other operating revenues	$ 1,331.5	$ 1,223.3	$ 1,362.7
Adjusted EBITDA	234.7	217.0	185.4
Depreciation and amortization expense	128.2	114.2	109.1
Capital expenditures	75.6	63.7	75.8
Corporate and Other
Segment Reporting Information [Line Items]
Sales and other operating revenues	0.0	1.5	14.4
Adjusted EBITDA	(43.2)	(57.0)	(85.1)
Depreciation and amortization expense	0.5	4.7	12.9
Capital expenditures	2.4	1.7	2.2
Coal Mining
Segment Reporting Information [Line Items]
Adjusted EBITDA	(10.5)	(15.0)	(40.9)
Operating Segments | Domestic Coke
Segment Reporting Information [Line Items]
Sales and other operating revenues	1,195.0	1,097.6	1,244.1
Adjusted EBITDA	188.9	193.9	210.1
Depreciation and amortization expense	102.6	84.0	81.6
Capital expenditures	68.8	44.6	67.6
Operating Segments | Brazil Coke
Segment Reporting Information [Line Items]
Sales and other operating revenues	43.4	39.5	43.4
Adjusted EBITDA	18.2	16.2	22.4
Depreciation and amortization expense	0.7	0.7	0.6
Operating Segments | Coal Logistics
Segment Reporting Information [Line Items]
Sales and other operating revenues	93.1	84.7	60.8
Adjusted EBITDA	70.8	63.9	38.0
Depreciation and amortization expense	24.4	24.8	14.0
Capital expenditures	4.4	17.4	6.0
Elimination of intersegment sales
Segment Reporting Information [Line Items]
Sales and other operating revenues	(23.8)	(45.2)	(121.4)
Elimination of intersegment sales | Coal Logistics
Segment Reporting Information [Line Items]
Sales and other operating revenues	23.8	23.2	20.4
Corporate and Other intersegment sales
Segment Reporting Information [Line Items]
Sales and other operating revenues	$ 0.0	$ 22.0	$ 101.0

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Business Segment Information - Segment Assets (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Segment Reporting Information [Line Items]
Segment assets, excluding tax assets	$ 2,055.3	$ 2,116.3
Tax assets	4.8	4.6
Total assets	2,060.1	2,120.9
Operating Segments | Domestic Coke
Segment Reporting Information [Line Items]
Segment assets, excluding tax assets	1,439.7	1,495.0
Operating Segments | Brazil Coke
Segment Reporting Information [Line Items]
Segment assets, excluding tax assets	10.9	32.6
Operating Segments | Coal Logistics
Segment Reporting Information [Line Items]
Segment assets, excluding tax assets	491.9	515.6
Corporate and Other
Segment Reporting Information [Line Items]
Segment assets, excluding tax assets	$ 112.8	$ 73.1

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Business Segment Information - Sales and Other Operating Revenue by Product or Service (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Sales and other operating revenue:
Sales and other operating revenue	$ 359.6	$ 339.0	$ 323.2	$ 309.7	$ 325.6	$ 293.9	$ 292.7	$ 311.1	$ 1,331.5	$ 1,223.3	$ 1,362.7
Cokemaking
Sales and other operating revenue:
Sales and other operating revenue									1,140.8	1,038.2	1,182.0
Energy
Sales and other operating revenue:
Sales and other operating revenue									53.2	54.3	61.5
Logistics
Sales and other operating revenue:
Sales and other operating revenue									89.7	82.9	58.8
Operating and licensing fees
Sales and other operating revenue:
Sales and other operating revenue									43.4	39.5	34.0
Other
Sales and other operating revenue:
Sales and other operating revenue									$ 4.4	$ 8.4	$ 26.4

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Business Segment Information - Adjusted EBITDA (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Segment Reporting [Abstract]
Net cash provided by operating activities									$ 148.5	$ 219.1	$ 141.1
Subtract:
Depreciation and amortization expense									128.2	114.2	109.1
Deferred income tax expense									(87.2)	3.1	(5.6)
Loss (gain) on extinguishment of debt, net			$ 20.2						20.4	(25.0)	0.5
Loss on divestiture of business and impairments									0.0	14.7	0.0
Changes in working capital and other									(16.4)	52.6	26.8
Net income	$ 173.9	$ 18.8	(31.5)	$ (57.7)	$ 31.5	$ 14.4	$ 1.0	$ 12.6	103.5	59.5	10.3
Add:
Depreciation and amortization expense									128.2	114.2	109.1
Interest expense, net									60.6	53.5	56.2
Loss (gain) on extinguishment of debt, net			$ 20.2						20.4	(25.0)	0.5
Income tax (benefit) expense									(81.6)	8.6	(8.8)
Contingent consideration adjustments									(1.7)	(10.1)	0.0
Expiration of land deposits and write-off of costs related to potential new cokemaking facility									5.3	1.9	0.0
Non-cash reversal of acquired contractual obligation									0.0	(0.7)	(3.3)
Coal rationalization costs									0.0	0.4	0.6
Adjustment to unconsolidated affiliate earnings									0.0	0.0	20.8
Adjusted EBITDA									234.7	217.0	185.4
Subtract: Adjusted EBITDA attributable to noncontrolling interest									86.4	86.6	81.2
Adjusted EBITDA attributable to SunCoke Energy, Inc.									$ 148.3	$ 130.4	$ 104.2

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Business Segment Information - Adjusted EBITDA (Footnote) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
Contingent consideration adjustments	$ (1,700,000)	$ (10,100,000)	$ 0
Expiration of land deposits and write-off of costs related to potential new cokemaking facility	5,300,000	1,900,000	0
Equity method investment			0
VISA SunCoke Limited
Segment Reporting Information [Line Items]
Loss on impairments			$ 19,400,000
Cost of Products Sold and Operating Expenses
Segment Reporting Information [Line Items]
Contingent consideration adjustments	1,700,000	6,400,000
Suncoke LP | Cost of Products Sold and Operating Expenses
Segment Reporting Information [Line Items]
Contingent consideration adjustments	$ 1,700,000	$ 10,100,000

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Selected Quarterly Data (unaudited) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Selected Quarterly Financial Information
Sales and other operating revenue	$ 359.6	$ 339.0	$ 323.2	$ 309.7	$ 325.6	$ 293.9	$ 292.7	$ 311.1	$ 1,331.5	$ 1,223.3	$ 1,362.7
Gross profit	56.6	51.2	32.7	42.0	69.8	50.7	39.7	42.4
Net income	173.9	18.8	(31.5)	(57.7)	31.5	14.4	1.0	12.6	103.5	59.5	10.3
Less: Net (loss) income attributable to noncontrolling interests	39.9	7.2	(7.3)	(58.7)	14.5	8.3	5.6	16.7	(18.9)	45.1	32.3
Net income attributable to SunCoke Energy, Inc.	$ 134.0	$ 11.6	$ (24.2)	$ 1.0	$ 17.0	$ 6.1	$ (4.6)	$ (4.1)	$ 122.4	$ 14.4	$ (22.0)
Earnings (loss) attributable to SunCoke Energy, Inc. per common share:
Basic (in dollars per share)	$ 2.08	$ 0.18	$ (0.38)	$ 0.02	$ 0.26	$ 0.10	$ (0.07)	$ (0.06)	$ 1.90	$ 0.22	$ (0.34)
Diluted (in dollars per share)	$ 2.05	$ 0.18	$ (0.38)	$ 0.02	$ 0.26	$ 0.10	$ (0.07)	$ (0.06)	$ 1.88	$ 0.22	$ (0.34)
Loss (gain) on extinguishment of debt, net			$ 20.2						$ 20.4	$ (25.0)	$ 0.5
Provisional net income tax benefit	$ 154.7								154.7	0.0	$ 0.0
IRS
Earnings (loss) attributable to SunCoke Energy, Inc. per common share:
Deferred tax expense				$ 64.2					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. | Coal Logistics
Earnings (loss) attributable to SunCoke Energy, Inc. per common share:
Deferred revenue	$ 16.4				$ 31.5				$ 16.4	$ 31.5

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Supplemental Condensed Combining and Consolidating Financial Information -Narrative (Details) $ in Millions	Dec. 31, 2017 USD ($)
Guarantor Subsidiaries
Guarantor Obligations [Line Items]
Guarantors obligations under the credit agreement	$ 44.6
SunCoke Energy Partners, L.P.
Guarantor Obligations [Line Items]
Partnership net assets restricted, less than	25.00%

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Supplemental Condensed Combining and Consolidating Financial Information - Condensed Consolidating Statement of Operations (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Revenues
Sales and other operating revenue	$ 359.6	$ 339.0	$ 323.2	$ 309.7	$ 325.6	$ 293.9	$ 292.7	$ 311.1	$ 1,331.5	$ 1,223.3	$ 1,362.7
Equity in earnings (loss) of subsidiaries									0.0	0.0	0.0
Total revenues									1,331.5	1,223.3	1,362.7
Costs and operating expenses
Cost of products sold and operating expenses									1,020.8	906.5	1,098.4
Selling, general and administrative expenses									79.6	91.3	75.4
Depreciation and amortization expense									128.2	114.2	109.1
Loss on divestiture of business and impairments									0.0	14.7	0.0
Total costs and operating expenses									1,228.6	1,126.7	1,282.9
Operating income (loss)									102.9	96.6	79.8
Interest (income) expense, net - affiliate									0.0	0.0	0.0
Interest expense (income), net									60.6	53.5	56.2
Total interest expense (income), net									60.6	53.5	56.2
Loss (gain) on extinguishment of debt, net			20.2						20.4	(25.0)	0.5
Income before income tax (benefit) expense and loss from equity method investment									21.9	68.1	23.1
Income tax (benefit) expense									(81.6)	8.6	(8.8)
Loss from equity method investment									0.0	0.0	21.6
Net income	173.9	18.8	(31.5)	(57.7)	31.5	14.4	1.0	12.6	103.5	59.5	10.3
Less: Net (loss) income attributable to noncontrolling interests	39.9	7.2	(7.3)	(58.7)	14.5	8.3	5.6	16.7	(18.9)	45.1	32.3
Net income (loss) attributable to SunCoke Energy, Inc.	$ 134.0	$ 11.6	$ (24.2)	$ 1.0	$ 17.0	$ 6.1	$ (4.6)	$ (4.1)	122.4	14.4	(22.0)
Comprehensive income (loss)									102.4	60.3	12.0
Less: Comprehensive (loss) income attributable to noncontrolling interests									(18.9)	45.1	32.3
Comprehensive income (loss) attributable to SunCoke Energy, Inc.									121.3	15.2	(20.3)
Issuer
Costs and operating expenses
Loss on divestiture of business and impairments										0.0
Guarantor Subsidiaries
Costs and operating expenses
Loss on divestiture of business and impairments										0.0
Non- Guarantor Subsidiaries
Costs and operating expenses
Loss on divestiture of business and impairments										14.7
Reportable Legal Entities | Issuer
Revenues
Sales and other operating revenue									0.0	0.0	0.0
Equity in earnings (loss) of subsidiaries									109.9	19.7	(8.4)
Total revenues									109.9	19.7	(8.4)
Costs and operating expenses
Cost of products sold and operating expenses									0.0	0.0	0.0
Selling, general and administrative expenses									8.7	12.9	9.5
Depreciation and amortization expense									0.0	0.0	0.0
Total costs and operating expenses									8.7	12.9	9.5
Operating income (loss)									101.2	6.8	(17.9)
Interest (income) expense, net - affiliate									0.0	0.0	0.0
Interest expense (income), net									4.9	6.0	8.3
Total interest expense (income), net									4.9	6.0	8.3
Loss (gain) on extinguishment of debt, net									0.4	0.0	1.2
Income before income tax (benefit) expense and loss from equity method investment									95.9	0.8	(27.4)
Income tax (benefit) expense									(26.5)	(13.6)	(5.4)
Loss from equity method investment											0.0
Net income									122.4	14.4	(22.0)
Less: Net (loss) income attributable to noncontrolling interests									0.0	0.0	0.0
Net income (loss) attributable to SunCoke Energy, Inc.									122.4	14.4	(22.0)
Comprehensive income (loss)									121.3	15.2	(20.3)
Less: Comprehensive (loss) income attributable to noncontrolling interests									0.0	0.0	0.0
Comprehensive income (loss) attributable to SunCoke Energy, Inc.									121.3	15.2	(20.3)
Reportable Legal Entities | Guarantor Subsidiaries
Revenues
Sales and other operating revenue									209.6	176.7	197.2
Equity in earnings (loss) of subsidiaries									(54.5)	51.3	34.4
Total revenues									155.1	228.0	231.6
Costs and operating expenses
Cost of products sold and operating expenses									157.3	131.3	150.2
Selling, general and administrative expenses									22.6	25.5	30.7
Depreciation and amortization expense									7.5	9.2	10.4
Total costs and operating expenses									187.4	166.0	191.3
Operating income (loss)									(32.3)	62.0	40.3
Interest (income) expense, net - affiliate									(7.5)	(7.6)	(7.3)
Interest expense (income), net									(0.5)	(0.2)	(0.6)
Total interest expense (income), net									(8.0)	(7.8)	(7.9)
Loss (gain) on extinguishment of debt, net									0.0	0.0	0.0
Income before income tax (benefit) expense and loss from equity method investment									(24.3)	69.8	48.2
Income tax (benefit) expense									(150.2)	38.7	29.6
Loss from equity method investment											0.0
Net income									125.9	31.1	18.6
Less: Net (loss) income attributable to noncontrolling interests									0.0	0.0	0.0
Net income (loss) attributable to SunCoke Energy, Inc.									125.9	31.1	18.6
Comprehensive income (loss)									125.3	30.8	18.4
Less: Comprehensive (loss) income attributable to noncontrolling interests									0.0	0.0	0.0
Comprehensive income (loss) attributable to SunCoke Energy, Inc.									125.3	30.8	18.4
Reportable Legal Entities | Non- Guarantor Subsidiaries
Revenues
Sales and other operating revenue									1,126.3	1,050.5	1,165.5
Equity in earnings (loss) of subsidiaries									0.0	0.0	0.0
Total revenues									1,126.3	1,050.5	1,165.5
Costs and operating expenses
Cost of products sold and operating expenses									867.9	779.1	948.2
Selling, general and administrative expenses									48.3	52.9	35.2
Depreciation and amortization expense									120.7	105.0	98.7
Total costs and operating expenses									1,036.9	951.7	1,082.1
Operating income (loss)									89.4	98.8	83.4
Interest (income) expense, net - affiliate									7.5	7.6	7.3
Interest expense (income), net									56.2	47.7	48.5
Total interest expense (income), net									63.7	55.3	55.8
Loss (gain) on extinguishment of debt, net									20.0	(25.0)	(0.7)
Income before income tax (benefit) expense and loss from equity method investment									5.7	68.5	28.3
Income tax (benefit) expense									95.1	(16.5)	(33.0)
Loss from equity method investment											21.6
Net income									(89.4)	85.0	39.7
Less: Net (loss) income attributable to noncontrolling interests									(18.9)	45.1	32.3
Net income (loss) attributable to SunCoke Energy, Inc.									(70.5)	39.9	7.4
Comprehensive income (loss)									(91.0)	86.1	41.6
Less: Comprehensive (loss) income attributable to noncontrolling interests									(18.9)	45.1	32.3
Comprehensive income (loss) attributable to SunCoke Energy, Inc.									(72.1)	41.0	9.3
Combining and Consolidating Adjustments
Revenues
Sales and other operating revenue									(4.4)	(3.9)	0.0
Equity in earnings (loss) of subsidiaries									(55.4)	(71.0)	(26.0)
Total revenues									(59.8)	(74.9)	(26.0)
Costs and operating expenses
Cost of products sold and operating expenses									(4.4)	(3.9)	0.0
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 and impairments										0.0
Total costs and operating expenses									(4.4)	(3.9)	0.0
Operating income (loss)									(55.4)	(71.0)	(26.0)
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, net									0.0	0.0	0.0
Income before income tax (benefit) expense and loss from equity method investment									(55.4)	(71.0)	(26.0)
Income tax (benefit) expense									0.0	0.0	0.0
Loss from equity method investment											0.0
Net income									(55.4)	(71.0)	(26.0)
Less: Net (loss) income attributable to noncontrolling interests									0.0	0.0	0.0
Net income (loss) attributable to SunCoke Energy, Inc.									(55.4)	(71.0)	(26.0)
Comprehensive income (loss)									(53.2)	(71.8)	(27.7)
Less: Comprehensive (loss) income attributable to noncontrolling interests									0.0	0.0	0.0
Comprehensive income (loss) attributable to SunCoke Energy, Inc.									$ (53.2)	$ (71.8)	$ (27.7)

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Supplemental Condensed Combining and Consolidating Financial Information - Condensed Consolidating Balance Sheet (Details) - USD ($) $ / shares in Units, $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Assets
Cash and cash equivalents	$ 120.2	$ 134.0	$ 123.4	$ 139.0
Receivables	68.5	60.7
Receivable from redemption of Brazilian investment	0.0	20.5
Inventories	111.0	92.5
Income tax receivable	4.8	4.6
Other current assets	6.7	3.8
Advances to affiliates	0.0	0.0
Total current assets	311.2	316.1
Notes receivable from affiliate	0.0	0.0
Properties, plants and equipment (net of accumulated depreciation of $733.2 million and $625.9 million at December 31, 2017 and 2016, respectively)	1,501.3	1,542.6
Goodwill	76.9	76.9
Other intangible assets, net	167.9	179.0
Deferred income taxes	0.0
Deferred charges and other assets	2.8	6.3
Investment in subsidiaries	0.0	0.0
Total assets	2,060.1	2,120.9
Liabilities and Equity
Advances from affiliate	0.0	0.0
Accounts payable	115.5	98.6
Accrued liabilities	53.2	49.8
Deferred revenue	1.7	2.5
Current portion of long-term debt and financing obligation	2.6	4.9
Interest payable	5.4	16.2
Income taxes payable	0.0	0.0
Total current liabilities	178.4	172.0
Long-term debt and financing obligation	861.1	849.2
Payable to affiliate	0.0	0.0
Accrual for black lung benefits	44.9	45.4
Retirement benefit liabilities	28.2	29.0
Deferred income taxes	257.8	352.5
Asset retirement obligations	14.0	13.9
Other deferred credits and liabilities	16.1	19.0
Total liabilities	1,400.5	1,481.0
Equity
Preferred stock	0.0	0.0
Common stock	0.7	0.7
Treasury stock	(140.7)	(140.7)
Additional paid-in capital	486.2	492.1
Accumulated other comprehensive income (loss)	(20.1)	(19.0)
Retained earnings (deficit)	100.1	(22.0)
Total SunCoke Energy, Inc. stockholders' equity	426.2	311.1
Noncontrolling interests	233.4	328.8
Total equity	659.6	639.9	622.8	705.4
Total liabilities and equity	$ 2,060.1	$ 2,120.9
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)	72,006,905	71,707,304
Treasury stock, shares (in shares)	7,477,657	7,477,657
Reportable Legal Entities | Issuer
Assets
Cash and cash equivalents	$ 0.0	$ 0.0	0.0	0.0
Receivables	0.0	0.0
Receivable from redemption of Brazilian investment		0.0
Inventories	0.0	0.0
Income tax receivable	0.0	17.8
Other current assets	0.0	0.2
Advances to affiliates	0.0	0.0
Total current assets	0.0	18.0
Notes receivable from affiliate	0.0	0.0
Properties, plants and equipment (net of accumulated depreciation of $733.2 million and $625.9 million at December 31, 2017 and 2016, respectively)	0.0	0.0
Goodwill	0.0	0.0
Other intangible assets, net	0.0	0.0
Deferred income taxes	7.1
Deferred charges and other assets	0.0	0.0
Investment in subsidiaries	632.5	542.7
Total assets	639.6	560.7
Liabilities and Equity
Advances from affiliate	162.2	184.2
Accounts payable	0.0	0.0
Accrued liabilities	1.5	1.7
Deferred revenue	0.0	0.0
Current portion of long-term debt and financing obligation	0.0	0.0
Interest payable	1.4	1.5
Income taxes payable	1.9	0.0
Total current liabilities	167.0	187.4
Long-term debt and financing obligation	42.7	43.5
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	15.9
Asset retirement obligations	0.0	0.0
Other deferred credits and liabilities	3.7	2.8
Total liabilities	213.4	249.6
Equity
Preferred stock	0.0	0.0
Common stock	0.7	0.7
Treasury stock	(140.7)	(140.7)
Additional paid-in capital	486.2	492.1
Accumulated other comprehensive income (loss)	(20.1)	(19.0)
Retained earnings (deficit)	100.1	(22.0)
Total SunCoke Energy, Inc. stockholders' equity	426.2	311.1
Noncontrolling interests	0.0	0.0
Total equity	426.2	311.1
Total liabilities and equity	639.6	560.7
Reportable Legal Entities | Guarantor Subsidiaries
Assets
Cash and cash equivalents	103.6	59.7	70.6	102.3
Receivables	17.1	12.2
Receivable from redemption of Brazilian investment		0.0
Inventories	9.1	9.0
Income tax receivable	0.0	0.0
Other current assets	4.6	1.8
Advances to affiliates	245.8	282.2
Total current assets	380.2	364.9
Notes receivable from affiliate	89.0	89.0
Properties, plants and equipment (net of accumulated depreciation of $733.2 million and $625.9 million at December 31, 2017 and 2016, respectively)	59.8	62.8
Goodwill	3.4	3.4
Other intangible assets, net	1.7	2.3
Deferred income taxes	0.0
Deferred charges and other assets	2.3	5.1
Investment in subsidiaries	721.2	688.2
Total assets	1,257.6	1,215.7
Liabilities and Equity
Advances from affiliate	0.0	0.0
Accounts payable	16.4	13.6
Accrued liabilities	19.7	20.5
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	81.4	87.5
Total current liabilities	117.5	121.6
Long-term debt and financing obligation	0.0	0.0
Payable to affiliate	300.0	300.0
Accrual for black lung benefits	11.8	12.3
Retirement benefit liabilities	13.7	14.1
Deferred income taxes	193.8	371.0
Asset retirement obligations	0.0	0.0
Other deferred credits and liabilities	6.4	6.4
Total liabilities	643.2	825.4
Equity
Preferred stock	0.0	0.0
Common stock	0.0	0.0
Treasury stock	0.0	0.0
Additional paid-in capital	141.0	42.1
Accumulated other comprehensive income (loss)	(2.2)	(1.6)
Retained earnings (deficit)	475.6	349.8
Total SunCoke Energy, Inc. stockholders' equity	614.4	390.3
Noncontrolling interests	0.0	0.0
Total equity	614.4	390.3
Total liabilities and equity	1,257.6	1,215.7
Reportable Legal Entities | Non- Guarantor Subsidiaries
Assets
Cash and cash equivalents	16.6	74.3	52.8	36.7
Receivables	51.4	48.5
Receivable from redemption of Brazilian investment		20.5
Inventories	101.9	83.5
Income tax receivable	88.1	74.3
Other current assets	2.1	1.8
Advances to affiliates	0.0	0.0
Total current assets	260.1	302.9
Notes receivable from affiliate	300.0	300.0
Properties, plants and equipment (net of accumulated depreciation of $733.2 million and $625.9 million at December 31, 2017 and 2016, respectively)	1,441.5	1,479.8
Goodwill	73.5	73.5
Other intangible assets, net	166.2	176.7
Deferred income taxes	0.0
Deferred charges and other assets	0.5	1.2
Investment in subsidiaries	0.0	0.0
Total assets	2,241.8	2,334.1
Liabilities and Equity
Advances from affiliate	83.6	98.0
Accounts payable	99.1	85.0
Accrued liabilities	32.0	27.6
Deferred revenue	1.7	2.5
Current portion of long-term debt and financing obligation	2.6	4.9
Interest payable	4.0	14.7
Income taxes payable	0.0	0.0
Total current liabilities	223.0	232.7
Long-term debt and financing obligation	818.4	805.7
Payable to affiliate	89.0	89.0
Accrual for black lung benefits	33.1	33.1
Retirement benefit liabilities	14.5	14.9
Deferred income taxes	71.1	(34.4)
Asset retirement obligations	14.0	13.9
Other deferred credits and liabilities	6.0	9.8
Total liabilities	1,269.1	1,164.7
Equity
Preferred stock	0.0	0.0
Common stock	0.0	0.0
Treasury stock	0.0	0.0
Additional paid-in capital	641.9	672.2
Accumulated other comprehensive income (loss)	(17.9)	(17.4)
Retained earnings (deficit)	115.3	185.8
Total SunCoke Energy, Inc. stockholders' equity	739.3	840.6
Noncontrolling interests	233.4	328.8
Total equity	972.7	1,169.4
Total liabilities and equity	2,241.8	2,334.1
Combining and Consolidating Adjustments
Assets
Cash and cash equivalents	0.0	0.0	$ 0.0	$ 0.0
Receivables	0.0	0.0
Receivable from redemption of Brazilian investment		0.0
Inventories	0.0	0.0
Income tax receivable	(83.3)	(87.5)
Other current assets	0.0	0.0
Advances to affiliates	(245.8)	(282.2)
Total current assets	(329.1)	(369.7)
Notes receivable from affiliate	(389.0)	(389.0)
Properties, plants and equipment (net of accumulated depreciation of $733.2 million and $625.9 million at December 31, 2017 and 2016, respectively)	0.0	0.0
Goodwill	0.0	0.0
Other intangible assets, net	0.0	0.0
Deferred income taxes	(7.1)
Deferred charges and other assets	0.0	0.0
Investment in subsidiaries	(1,353.7)	(1,230.9)
Total assets	(2,078.9)	(1,989.6)
Liabilities and Equity
Advances from affiliate	(245.8)	(282.2)
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	(83.3)	(87.5)
Total current liabilities	(329.1)	(369.7)
Long-term debt and financing obligation	0.0	0.0
Payable to affiliate	(389.0)	(389.0)
Accrual for black lung benefits	0.0	0.0
Retirement benefit liabilities	0.0	0.0
Deferred income taxes	(7.1)	0.0
Asset retirement obligations	0.0	0.0
Other deferred credits and liabilities	0.0	0.0
Total liabilities	(725.2)	(758.7)
Equity
Preferred stock	0.0	0.0
Common stock	0.0	0.0
Treasury stock		0.0
Additional paid-in capital	(782.9)	(714.3)
Accumulated other comprehensive income (loss)	20.1	19.0
Retained earnings (deficit)	(590.9)	(535.6)
Total SunCoke Energy, Inc. stockholders' equity	(1,353.7)	(1,230.9)
Noncontrolling interests	0.0	0.0
Total equity	(1,353.7)	(1,230.9)
Total liabilities and equity	$ (2,078.9)	$ (1,989.6)

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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, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Cash Flows from Operating Activities:
Net income	$ 173.9	$ 18.8	$ (31.5)	$ (57.7)	$ 31.5	$ 14.4	$ 1.0	$ 12.6	$ 103.5	$ 59.5	$ 10.3
Adjustments to reconcile net income (loss) to net cash (used in) provided by operating activities:
Depreciation and amortization expense									128.2	114.2	109.1
Deferred income tax (benefit) expense									(87.2)	3.1	(5.6)
Gain on curtailment and payments in excess of expense for postretirement plan benefits									(1.8)	(2.6)	(8.0)
Settlement loss and payments in excess of expense for pension plan									0.0	0.0	13.1
Share-based compensation expense									4.8	6.5	7.2
Equity in (earnings) loss of subsidiaries									0.0	0.0	0.0
Loss from equity method investment									0.0	0.0	21.6
Loss (gain) on extinguishment of debt, net			$ 20.2						20.4	(25.0)	0.5
Loss on divestiture of business and impairments										14.7
Changes in working capital pertaining to operating activities (net of the effects of divestiture and acquisition):
Receivables									(7.8)	3.7	18.8
Inventories									(18.5)	29.4	23.2
Accounts payable									11.7	(0.8)	(17.9)
Accrued liabilities									2.6	6.8	(24.3)
Deferred revenue									(0.8)	0.4	(4.4)
Interest payable									(10.8)	(2.7)	(1.0)
Income taxes									(0.2)	7.0	(5.6)
Other									4.4	4.9	4.1
Net cash provided by operating activities									148.5	219.1	141.1
Cash Flows from Investing Activities:
Capital expenditures									(75.6)	(63.7)	(75.8)
Acquisition of businesses, net of cash received									0.0	0.0	(191.7)
Decrease (increase) in restricted cash									0.5	17.7	(17.7)
Return of Brazilian investment									20.5	20.5	0.0
Divestiture of coal business									0.0	(12.8)	0.0
Other investing activities									0.0	2.1	0.0
Net cash used in investing activities									(54.6)	(36.2)	(285.2)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt									693.7	0.0	260.8
Repayment of long-term debt									(644.9)	(66.1)	(248.1)
Debt issuance costs									(17.4)	(0.2)	(5.7)
Proceeds from revolving facility									350.0	28.0	292.4
Repayment of revolving facility									(392.0)	(98.4)	(50.0)
Dividends paid									0.0	0.0	(28.0)
Proceeds from financing obligation									0.0	16.2	0.0
Repayment of financing obligation									(2.5)	(1.0)	0.0
Cash distributions to noncontrolling interests									(47.0)	(49.4)	(43.3)
Shares repurchased									0.0	0.0	(35.7)
SunCoke Energy Partners, L.P. units repurchased									0.0	0.0	(12.8)
Acquisition of additional interest in the Partnership									(48.7)
Other financing activities									1.1	(1.4)	(1.1)
Net increase (decrease) in advances from affiliate									0.0	0.0	0.0
Net cash (used in) provided by financing activities									(107.7)	(172.3)	128.5
Net (decrease) increase in cash and cash equivalents									(13.8)	10.6	(15.6)
Cash and cash equivalents at beginning of year				134.0				123.4	134.0	123.4	139.0
Cash and cash equivalents at end of year	120.2				134.0				120.2	134.0	123.4
Issuer
Cash Flows from Investing Activities:
Acquisition of businesses, net of cash received											0.0
Decrease (increase) in restricted cash											0.0
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt									0.0
Acquisition of additional interest in the Partnership									0.0
Guarantor Subsidiaries
Cash Flows from Investing Activities:
Acquisition of businesses, net of cash received											0.0
Decrease (increase) in restricted cash											0.0
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt									0.0
Acquisition of additional interest in the Partnership									(48.7)
Non- Guarantor Subsidiaries
Cash Flows from Investing Activities:
Acquisition of businesses, net of cash received											(191.7)
Decrease (increase) in restricted cash											(17.7)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt									693.7
Acquisition of additional interest in the Partnership									0.0
Reportable Legal Entities | Issuer
Cash Flows from Operating Activities:
Net income									122.4	14.4	(22.0)
Adjustments to reconcile net income (loss) to net cash (used in) provided by operating activities:
Depreciation and amortization expense									0.0	0.0	0.0
Deferred income tax (benefit) expense									(22.8)	(16.6)	(20.7)
Gain on curtailment and payments in excess of expense for postretirement plan benefits									0.0	0.0	0.0
Settlement loss and payments in excess of expense for pension plan											0.0
Share-based compensation expense									4.7	6.5	7.2
Equity in (earnings) loss of subsidiaries									(109.9)	(19.7)	8.4
Loss from equity method investment											0.0
Loss (gain) on extinguishment of debt, net									0.4	0.0	1.2
Loss on divestiture of business and impairments										0.0
Changes in working capital pertaining to operating activities (net of the effects of divestiture and acquisition):
Receivables									0.0	0.0	0.1
Inventories									0.0	0.0	0.0
Accounts payable									0.0	0.0	0.0
Accrued liabilities									(0.2)	1.5	(0.2)
Deferred revenue									0.0	0.0	0.0
Interest payable									(0.1)	0.1	(6.1)
Income taxes									(2.7)	(6.9)	17.1
Other									1.3	2.5	(0.9)
Net cash provided by operating activities									(6.9)	(18.2)	(15.9)
Cash Flows from Investing Activities:
Capital expenditures									0.0	0.0	0.0
Decrease (increase) in restricted cash									0.0	0.0
Return of Brazilian investment									0.0	0.0
Divestiture of coal business										0.0
Other investing activities										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
Repayment of long-term debt									0.0	0.0	(16.8)
Debt issuance costs									(1.6)	0.0	(0.4)
Proceeds from revolving facility									0.0	0.0	60.4
Repayment of revolving facility									0.0	(60.4)	0.0
Dividends paid											(28.0)
Proceeds from financing obligation										0.0
Repayment of financing obligation									0.0	0.0
Cash distributions to noncontrolling interests									0.0	0.0	0.0
Shares repurchased											(35.7)
SunCoke Energy Partners, L.P. units repurchased											0.0
Other financing activities									1.1	(0.3)	(1.1)
Net increase (decrease) in advances from affiliate									7.4	78.9	37.5
Net cash (used in) provided by financing activities									6.9	18.2	15.9
Net (decrease) increase in cash and cash equivalents									0.0	0.0	0.0
Cash and cash equivalents at beginning of year				0.0				0.0	0.0	0.0	0.0
Cash and cash equivalents 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									125.9	31.1	18.6
Adjustments to reconcile net income (loss) to net cash (used in) provided by operating activities:
Depreciation and amortization expense									7.5	9.2	10.4
Deferred income tax (benefit) expense									(170.1)	8.7	14.9
Gain on curtailment and payments in excess of expense for postretirement plan benefits									(1.0)	(1.5)	(1.6)
Settlement loss and payments in excess of expense for pension plan											0.0
Share-based compensation expense									0.0	0.0	0.0
Equity in (earnings) loss of subsidiaries									54.5	(51.3)	(34.4)
Loss from equity method investment											0.0
Loss (gain) on extinguishment of debt, net									0.0	0.0	0.0
Loss on divestiture of business and impairments										0.0
Changes in working capital pertaining to operating activities (net of the effects of divestiture and acquisition):
Receivables									(4.9)	(4.3)	9.4
Inventories									(0.1)	(3.7)	(1.3)
Accounts payable									3.0	4.6	(3.2)
Accrued liabilities									(1.3)	4.8	(2.3)
Deferred revenue									0.0	0.0	0.0
Interest payable									0.0	0.0	0.0
Income taxes									16.3	28.2	23.2
Other									0.0	8.9	1.5
Net cash provided by operating activities									29.8	34.7	35.2
Cash Flows from Investing Activities:
Capital expenditures									(4.1)	(5.7)	(11.8)
Decrease (increase) in restricted cash									0.0	0.0
Return of Brazilian investment									0.0	0.0
Divestiture of coal business										0.0
Other investing activities										0.0
Net cash used in investing activities									(4.1)	(5.7)	(11.8)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt											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
Dividends paid											0.0
Proceeds from financing obligation										0.0
Repayment of financing obligation									0.0	0.0
Cash distributions to noncontrolling interests									0.0	0.0	0.0
Shares repurchased											0.0
SunCoke Energy Partners, L.P. units repurchased											0.0
Other financing activities									0.0	(1.1)	0.0
Net increase (decrease) in advances from affiliate									66.9	(38.8)	(55.1)
Net cash (used in) provided by financing activities									18.2	(39.9)	(55.1)
Net (decrease) increase in cash and cash equivalents									43.9	(10.9)	(31.7)
Cash and cash equivalents at beginning of year				59.7				70.6	59.7	70.6	102.3
Cash and cash equivalents at end of year	103.6				59.7				103.6	59.7	70.6
Reportable Legal Entities | Non- Guarantor Subsidiaries
Cash Flows from Operating Activities:
Net income									(89.4)	85.0	39.7
Adjustments to reconcile net income (loss) to net cash (used in) provided by operating activities:
Depreciation and amortization expense									120.7	105.0	98.7
Deferred income tax (benefit) expense									105.7	11.0	0.2
Gain on curtailment and payments in excess of expense for postretirement plan benefits									(0.8)	(1.1)	(6.4)
Settlement loss and payments in excess of expense for pension plan											13.1
Share-based compensation expense									0.1	0.0	0.0
Equity in (earnings) loss of subsidiaries									0.0	0.0	0.0
Loss from equity method investment											21.6
Loss (gain) on extinguishment of debt, net									20.0	(25.0)	(0.7)
Loss on divestiture of business and impairments										14.7
Changes in working capital pertaining to operating activities (net of the effects of divestiture and acquisition):
Receivables									(2.9)	8.0	9.3
Inventories									(18.4)	33.1	24.5
Accounts payable									8.7	(5.4)	(14.7)
Accrued liabilities									4.1	0.5	(21.8)
Deferred revenue									(0.8)	0.4	(4.4)
Interest payable									(10.7)	(2.8)	5.1
Income taxes									(13.8)	(14.3)	(45.9)
Other									3.1	(6.5)	3.5
Net cash provided by operating activities									125.6	202.6	121.8
Cash Flows from Investing Activities:
Capital expenditures									(71.5)	(58.0)	(64.0)
Decrease (increase) in restricted cash									0.5	17.7
Return of Brazilian investment									20.5	20.5
Divestiture of coal business										(12.8)
Other investing activities										2.1
Net cash used in investing activities									(50.5)	(30.5)	(273.4)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt											260.8
Repayment of long-term debt									(644.9)	(66.1)	(231.3)
Debt issuance costs									(15.8)	(0.2)	(5.3)
Proceeds from revolving facility									350.0	28.0	232.0
Repayment of revolving facility									(392.0)	(38.0)	(50.0)
Dividends paid											0.0
Proceeds from financing obligation										16.2
Repayment of financing obligation									(2.5)	(1.0)
Cash distributions to noncontrolling interests									(47.0)	(49.4)	(43.3)
Shares repurchased											0.0
SunCoke Energy Partners, L.P. units repurchased											(12.8)
Other financing activities									0.0	0.0	0.0
Net increase (decrease) in advances from affiliate									(74.3)	(40.1)	17.6
Net cash (used in) provided by financing activities									(132.8)	(150.6)	167.7
Net (decrease) increase in cash and cash equivalents									(57.7)	21.5	16.1
Cash and cash equivalents at beginning of year				74.3				52.8	74.3	52.8	36.7
Cash and cash equivalents at end of year	16.6				74.3				16.6	74.3	52.8
Combining and Consolidating Adjustments
Cash Flows from Operating Activities:
Net income									(55.4)	(71.0)	(26.0)
Adjustments to reconcile net income (loss) to net cash (used in) provided by operating activities:
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
Settlement loss and payments in excess of expense for pension plan											0.0
Share-based compensation expense									0.0	0.0	0.0
Equity in (earnings) loss of subsidiaries									55.4	71.0	26.0
Loss from equity method investment											0.0
Loss (gain) on extinguishment of debt, net									0.0	0.0	0.0
Loss on divestiture of business and impairments										0.0
Changes in working capital pertaining to operating activities (net of the effects of divestiture and acquisition):
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
Acquisition of businesses, net of cash received											0.0
Decrease (increase) in restricted cash									0.0	0.0	0.0
Return of Brazilian investment									0.0	0.0
Divestiture of coal business										0.0
Other investing activities										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
Dividends paid											0.0
Proceeds from financing obligation										0.0
Repayment of financing obligation									0.0	0.0
Cash distributions to noncontrolling interests									0.0	0.0	0.0
Shares repurchased											0.0
SunCoke Energy Partners, L.P. units repurchased											0.0
Acquisition of additional interest in the Partnership									0.0
Other financing activities									0.0	0.0	0.0
Net increase (decrease) in advances from affiliate									0.0	0.0	0.0
Net cash (used in) provided by financing activities									0.0	0.0	0.0
Net (decrease) increase in cash and cash equivalents									0.0	0.0	0.0
Cash and cash equivalents at beginning of year				$ 0.0				$ 0.0	0.0	0.0	0.0
Cash and cash equivalents at end of year	$ 0.0				$ 0.0				$ 0.0	$ 0.0	$ 0.0