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Item 1.	Business

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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.;

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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.

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(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.

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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.

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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.

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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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•	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.

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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.

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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.

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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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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.

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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.

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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.

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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.

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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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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.

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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.

•	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.

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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.

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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.

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Item 1A.	Risk Factors

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•	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.

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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.

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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.

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•	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.

•	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.

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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

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

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•	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.

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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.

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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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Item 1B.	Unresolved Staff Comments

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Item 2.	Properties

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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.

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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.

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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.

Item 3.	Legal Proceedings

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Item 4.	Mine Safety Disclosures

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

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Item 6.	Selected Financial Data

(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

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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.

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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.

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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-

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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.

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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.

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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.

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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."

•	Tax Rulings.

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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.

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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

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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.

•	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:

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

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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 million annual 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.

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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

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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.

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

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(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."

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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

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(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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(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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(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.

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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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(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.

•	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.

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(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.

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

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•	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;

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•	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;

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•	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.

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Item 7A.	Quantitative and Qualitative Disclosures About Market Risk

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Item 8.	Financial Statements and Supplementary Data