EQM Midstream Partners, LP
Annual Report 2012

Plain-text annual report

Morningstar® Document Research℠ FORM 10-KEQT Midstream Partners, LP - EQMFiled: February 21, 2013 (period: December 31, 2012)Annual report with a comprehensive overview of the companyThe information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The userassumes all risks for any damages or losses arising from any use of this information, except to the extent such damages or losses cannot belimited or excluded by applicable law. Past financial performance is no guarantee of future results. UNITED STATESSECURITIES AND EXCHANGE COMMISSIONWashington, D.C. 20549 FORM 10-K [X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)OF THE SECURITIES EXCHANGE ACT OF 1934 FOR THE FISCAL YEAR ENDED DECEMBER 31, 2012 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 1-35574 EQT Midstream Partners, LP(Exact name of registrant as specified in its charter) DELAWARE(State or other jurisdiction of incorporation or organization)37-1661577(IRS Employer Identification No.) 625 Liberty AvenuePittsburgh, Pennsylvania(Address of principal executive offices)15222(Zip Code) Registrant’s telephone number, including area code: (412) 553-5700 Securities registered pursuant to Section 12(b) of the Act: Title of each class Name of each exchange on which registeredCommon Units Representing Limited Partner InterestsNew 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 o No  Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes o No  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 of1934 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 filingrequirements for the past 90 days. Yes  No o Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Website, if any, every Interactive Data Filerequired to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorterperiod that the registrant was required to submit and post such files). Yes  No o Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§ 229.405 of this chapter) 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 thisForm 10-K or any amendment to this Form 10-K.  Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company.See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):Large accelerated filer oAccelerated filer oNon-accelerated filer Smaller reporting company o Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes o No  The aggregate market value of the Common Units held by non-affiliates of the registrant as of June 30, 2012: $343.9 million At January 31, 2013, there were 17,339,718 Common Units, 17,339,718 Subordinated Units and 707,744 General Partner Units outstanding. DOCUMENTS INCORPORATED BY REFERENCE None Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. TABLE OF CONTENTS Glossary of Commonly Used Terms, Abbreviations and Measurements3Cautionary Statement5 PART I Item 1Business6Item 1ARisk Factors20Item 1BUnresolved Staff Comments47Item 2Properties47Item 3Legal Proceedings47Item 4Mine Safety and Health Administration Data48 PART II Item 5Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities49Item 6Selected Financial Data51Item 7Management’s Discussion and Analysis of Financial Condition and Results of Operations51Item 7AQuantitative and Qualitative Disclosures About Market Risk66Item 8Financial Statements and Supplementary Data67Item 9Changes in and Disagreements with Accountants on Accounting and Financial Disclosure93Item 9AControls and Procedures93Item 9BOther Information93 PART III Item 10Directors, Executive Officers and Corporate Governance94Item 11Executive Compensation97Item 12Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters106Item 13Certain Relationships and Related Transactions and Director Independence111Item 14Principal Accounting Fees and Services120 PART IV Item 15Exhibits, Financial Statement Schedules121Index to Financial Statements Covered by Report of Independent Registered Public Accounting Firm121Index to Exhibits122Signatures125 2Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Glossary of Commonly Used Terms, Abbreviations and Measurements adjusted EBITDA - a supplemental non-GAAP financial measure defined by the Company as net income plus net interest expense, income tax expense,depreciation and amortization expense, non-cash long-term compensation expense and other non-cash adjustments less other income and the Sunrise Pipelinelease payment. AFUDC – Allowance for Funds Used During Construction - carrying costs for the construction of certain long-term assets are capitalized and amortized overthe related assets’ estimated useful lives. The capitalized amount for construction of regulated assets includes interest cost and a designated cost of equity forfinancing the construction of these regulated assets. Appalachian Basin – the area of the United States comprised of those portions of West Virginia, Pennsylvania, Ohio, Maryland, Kentucky and Virginiathat lie in the Appalachian Mountains. British thermal unit – a measure of the amount of energy required to raise the temperature of one pound of water one degree Fahrenheit. distributable cash flow – a supplemental non-GAAP financial measure defined by the Company as adjusted EBITDA less net cash paid for interestexpense, maintenance capital expenditures and income taxes. end-user markets - the ultimate users and consumers of transported energy products. firm contracts – contracts for transportation services that obligate customers to pay a fixed monthly charge to reserve an agreed upon amount of pipelinecapacity regardless of the actual pipeline capacity used by a customer during each month. gas – all references to “gas” in this report refer to natural gas. horizontal drilling – drilling that ultimately is horizontal or near horizontal to increase the length of the well bore penetrating the target formation. HP - horsepower. local distribution company or LDC - LDCs are companies involved in the delivery of natural gas to consumers within a specific geographic area. LNG - natural gas that has been cooled to minus 161 degrees Celsius for transportation, typically by ship. The cooling process reduces the volume of naturalgas by 600 times. NGA - Natural Gas Act of 1938. NGPA – Natural Gas Policy Act of 1978. omnibus agreement - the agreement entered into among the Company, its general partner and EQT Corporation (EQT) in connection with the Company’sinitial public offering, pursuant to which EQT agreed to provide the Company with certain general and administrative services and a license to use the name“EQT” and related marks in connection with the Company’s business. The omnibus agreement also provides for certain indemnification and reimbursementobligations between the Company and EQT. park and loan services - those services pursuant to which customers receive the right to store natural gas in (park), or borrow gas from (loan), theCompany’s facilities on a seasonal basis. PSIA – Pipeline Safety Improvement Act of 2002. play - a proven geological formation that contains commercial amounts of hydrocarbons. receipt point - the point where production is received by or into a gathering system or transportation pipeline. 3Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Glossary of Commonly Used Terms, Abbreviations and Measurements reservoir - a porous and permeable underground formation containing an individual and separate natural accumulation of producible hydrocarbons (crude oiland/or natural gas) which is confined by impermeable rock or water barriers and is characterized by a single natural pressure system. throughput - the volume of natural gas transported or passing through a pipeline, plant, terminal or other facility during a particular period. wellhead - the equipment at the surface of a well used to control the well’s pressure and the point at which the hydrocarbons and water exit the ground. working gas – the volume of natural gas in the storage reservoir that can be extracted during the normal operation of the storage facility. Abbreviations ASC - Accounting Standards CodificationCBM – Coalbed MethaneDOT – U.S. Department of TransportationFASB – Financial Accounting Standards BoardFERC – Federal Energy Regulatory CommissionGAAP – Generally Accepted Accounting PrinciplesIRS – Internal Revenue ServiceLDC – Local Distribution CompanyNYMEX – New York Mercantile ExchangeNYSE – New York Stock ExchangePA PUC – Pennsylvania Public Utility CommissionPHMSA – Pipeline and Hazardous Materials Safety AdministrationSEC – Securities and Exchange CommissionWV PSC – West Virginia Public Service Commission MeasurementsBbl = barrelBtu = one British thermal unitBBtu = billion British thermal unitsBcf = billion cubic feetDth = million British thermal unitsMcf = thousand cubic feetMgal = thousand gallonsMBbl = thousand barrelsMMBtu = million British thermal unitsMMcf = million cubic feetTBtu = trillion British thermal unitsTcf = one trillion cubic feet 4Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Cautionary Statements Disclosures in this Annual Report on Form 10-K contain certain forward-looking statements within the meaning of Section 21E of the SecuritiesExchange Act of 1934, as amended, and Section 27A of the Securities Act of 1933, as amended. Statements that do not relate strictly to historical or currentfacts are forward-looking and usually identified by the use of words such as “anticipate,” “estimate,” “could,” “would,” “will,” “may,” “forecasts,”“approximate,” “expect,” “project,” “intend,” “plan,” “believe” and other words of similar meaning in connection with any discussion of future operating orfinancial matters. Without limiting the generality of the foregoing, forward-looking statements contained in this Annual Report on Form 10-K include thematters discussed in the sections captioned “Strategy” in Item 1, “Business” and “Outlook” in Item 7, “Management’s Discussion and Analysis of FinancialCondition and Results of Operations,” and the expectations of plans, strategies, objectives, and growth and anticipated financial and operational performanceof the Company and its subsidiaries, including guidance regarding transmission and storage and gathering revenue and volume growth; revenue projections;infrastructure programs (including the timing, cost, capacity and sources of funding with respect to such programs); natural gas production growth in theCompany’s operating areas for EQT Corporation and third parties; asset acquisitions, including the Company’s ability to complete any asset purchases fromEQT Corporation; the consummation of the Equitable Gas Company, LLC transaction, including the commercial arrangements to be entered into by theCompany in connection therewith; projected adjusted EBITDA and distributable cash flow; the amount and timing of distributions including expectedincreases; the effect of the Sunrise Pipeline lease on distributable cash flow; future projected Sunrise Pipeline lease payments; projected operating and capitalexpenditures including the amount of capital expenditures reimbursable by EQT; liquidity and financing requirements, including sources and availability; theeffects of government regulation and tax position. The forward-looking statements included in this Annual Report on Form 10-K are subject to risks anduncertainties that could cause actual results to differ materially from projected results. Accordingly, investors should not place undue reliance on forward-looking statements as a prediction of actual results. The Company has based these forward-looking statements on current expectations and assumptions aboutfuture events. While the Company considers these expectations and assumptions to be reasonable, they are inherently subject to significant business,economic, competitive, regulatory and other risks and uncertainties, most of which are difficult to predict and many of which are beyond the Company’scontrol. With respect to the proposed Equitable Gas Company, LLC transaction, these risks and uncertainties include, among others, the ability of EQTCorporation to obtain regulatory approvals for the transaction on the proposed terms and schedule and that the conditions to closing may not be satisfied. Therisks and uncertainties that may affect the operations, performance and results of the Company’s business and forward-looking statements include, but arenot limited to, those set forth under Item 1A, “Risk Factors” and elsewhere in this Annual Report on Form 10-K. Any forward-looking statement speaks only as of the date on which such statement is made and the Company does not intend to correct or updateany forward-looking statement, whether as a result of new information, future events or otherwise. In reviewing any agreements incorporated by reference in or filed with this Annual Report on Form 10-K, please remember that such agreements areincluded to provide information regarding the terms of such agreements and are not intended to provide any other factual or disclosure information about theCompany. The agreements may contain representations and warranties by the Company, which should not in all instances be treated as categorical statementsof fact, but rather as a way of allocating the risk to one of the parties of such agreements should those statements prove to be inaccurate. The representationsand warranties were made only as of the date of the relevant agreement or such other date or dates as may be specified in such agreement and are subject tomore recent developments. Accordingly, these representations and warranties alone may not describe the actual state of affairs of the Company or its affiliatesas of the date they were made or at any other time. 5Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. PART I Item 1. Business EQT Midstream Partners, LP (the Partnership, EQT Midstream Partners or the Company), which closed its initial public offering (IPO) tobecome publicly traded on July 2, 2012, is a growth-oriented Delaware limited partnership formed in January 2012. Equitrans, L.P. (Equitrans) is aPennsylvania limited partnership and the predecessor for accounting purposes (the Predecessor) of EQT Midstream Partners (the Successor). References in this Form 10-K to the “Company,” when used for periods prior to the IPO, refer to Equitrans. References in this Form 10-K to the“Company,” when used for periods beginning at or following the IPO, refer collectively to the Partnership and its consolidated subsidiaries.Immediately prior to the closing of the IPO, EQT Corporation contributed all of the partnership interests in Equitrans to the Partnership. Therefore,the historical financial statements contained in this Form 10-K reflect the assets, liabilities and operations of Equitrans (excluding the results ofoperations of Big Sandy Pipeline, a FERC-regulated transmission pipeline sold by Equitrans to an unrelated party in July 2011) for periods endingbefore July 2, 2012 and EQT Midstream Partners for periods beginning at or following July 2, 2012. References in this Form 10-K to ‘‘EQT’’ refercollectively to EQT Corporation and its consolidated subsidiaries. Overview EQT Midstream Partners is a growth-oriented limited partnership formed by EQT Corporation (NYSE: EQT) to own, operate, acquire and developmidstream assets in the Appalachian Basin. The Company provides substantially all of its natural gas transmission, storage and gathering services undercontracts with fixed reservation and/or usage fees, with a significant portion of its revenues being generated under long-term firm contracts. The Company’soperations are primarily focused in southwestern Pennsylvania and northern West Virginia, a strategic location in the rapidly growing natural gas shale playknown as the Marcellus Shale. This same region is also the core operating area of EQT, the general partner and majority equity owner of the Company. TheCompany provides midstream services to EQT and multiple third parties across 22 counties in Pennsylvania and West Virginia through its two primaryassets: the Equitrans Transmission and Storage System, which serves as a header system transmission pipeline, and the Equitrans Gathering System, whichdelivers natural gas from wells and other receipt points to transmission pipelines. The Company believes that its strategically located assets, combined with itsworking relationship with EQT, position it as a leading Appalachian Basin midstream energy company serving the Marcellus Shale region. EQT is the Company’s largest customer and is one of the largest natural gas producers in the Appalachian Basin. For the year ended December 31,2012, EQT reported 6.0 Tcfe of proved reserves and total production sales volumes of 258.5 Bcfe, representing a 33% increase compared to the year endedDecember 31, 2011. Approximately 58% of EQT’s total production in 2012 was from Marcellus wells, and overall Marcellus volumes increased 85%compared to the year ended December 31, 2011. During the year ended December 31, 2012, approximately 81% of the Company’s total natural gastransmission and gathering volumes were comprised of natural gas produced by EQT and other affiliated volumes. In order to facilitate production growth inits areas of operation, EQT invested approximately $2.0 billion in midstream infrastructure from January 1, 2007 through December 31, 2012 and currentlyowns a substantial and growing portfolio of midstream assets, many of which have multiple interconnects into the Company’s system. The Company believesits economic relationship with EQT incentivizes EQT to provide the Company with access to additional production growth in and around its existing assetsand with acquisitions and organic growth opportunities, although EQT is under no obligation to do so. Initial Public Offering On July 2, 2012, immediately prior to the closing of the IPO, EQT contributed all of the partnership interests in Equitrans to the Partnership. TheCompany issued 14,375,000 common units in the IPO, which included the full exercise of the underwriters’ over-allotment option, and represented 40.6% ofthe Company’s outstanding equity. EQT retained a 59.4% equity interest in the Company, including 2,964,718 common units, 17,339,718 subordinatedunits, and a 2% general partner interest. 6Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Transmission and Storage System The Company’s transmission and storage system includes an approximately 700 mile FERC-regulated interstate pipeline that connects to fiveinterstate pipelines and multiple distribution companies. The transmission system is supported by 14 associated natural gas storage reservoirs withapproximately 400 MMcf per day of peak withdrawal capability and 32 Bcf of working gas capacity and 21 compressor units. As of December 31, 2012, thetransmission assets had total throughput capacity of approximately 1.4 TBtu per day. Revenues associated with the Company’s transmission and storagesystem represented approximately 88% and 85% of total revenues for the year ended December 31, 2012 and 2011, respectively. As of December 31, 2012, theweighted average remaining contract life based on total revenues for firm transmission and storage contracts was approximately 9.4 years. The Company’s transmission and storage system was initially constructed to receive natural gas from interstate pipelines and local conventionalnatural gas producers for delivery to LDCs and industrial end-users located in West Virginia and western Pennsylvania, including the city of Pittsburgh.Prompted by the rapid development of the Marcellus Shale in 2007 and the resulting excess supply of natural gas in the region, the Company shifted the focusof its transmission and storage system and reengineered its pipeline to act as a header system receiving natural gas produced in the Marcellus play. In turn, thesystem was poised to deliver this Marcellus gas into interstate pipelines that serve customers throughout the Mid-Atlantic and Northeastern United States, aswell as to continue delivering to LDCs and end-users directly connected to the system. In 2010, the Company initiated an expansion of its transmission and storage system, which is now complete, in order to increase its ability to receivegas produced in the Marcellus Shale for delivery to high demand, end-user markets through existing interconnects with several interstate transmissionpipelines. The expansion of the Company’s transmission and storage system involved increasing the maximum allowable operating pressure of six miles ofpipeline, installing emission controls and increasing horsepower on two engines at the Pratt Compressor Station, installing a delivery point interconnect withTexas Eastern and installing two receipt points with an affiliated Marcellus gathering system located in Greene County, Pennsylvania. The Equitrans2010 Marcellus expansion project increased off-system capacity by over 200 BBtu per day at a cost of approximately $16 million. The Company has an acreage dedication from EQT pursuant to which the Company has the right to elect to transport on its transmission andstorage system all natural gas produced from wells drilled by EQT under an area covering approximately 60,000 acres in Allegheny, Washington and GreeneCounties in Pennsylvania and Wetzel, Marion, Taylor, Tyler, Doddridge, Harrison and Lewis Counties in West Virginia. EQT has a significant natural gasdrilling program in these areas and is expanding its retained midstream infrastructure, which connects to the Company’s transmission and storage system, tomeet expected production growth. On June 18, 2012, the Company transferred ownership of the Sunrise Pipeline, which was under construction at the time and placed into service inthe third quarter of 2012, to EQT. Concurrent with this transfer, the Company entered into a capital lease with EQT for the Sunrise Pipeline. Under the lease,the Company operates the pipeline as part of its transmission and storage system under the rates, terms and conditions of its FERC-approved tariff. TheSunrise Pipeline provides access to liquids-rich Marcellus Shale acreage and consists of 41.5 miles of 24-inch diameter pipeline that parallels andinterconnects with the segment of the Company’s transmission and storage system from Wetzel County, West Virginia to Greene County, Pennsylvania. TheSunrise Pipeline provides 314 BBtu per day of additional firm capacity to the system at an estimated construction cost of approximately $225 million. The Company generally provides transmission and storage services in two manners: firm service and interruptible service. A significant portion ofthe Company’s transportation and storage services are provided through firm service agreements. The Company generally does not take title to the natural gastransported or stored for its customers. Approximately 1.0 TBtu per day of the Company’s transmission capacity and 19.9 TBtu of its storage capacity, respectively, were subscribedunder firm transmission and storage contracts with a weighted average remaining contract life based on contracted revenues of approximately 9.7 years fortransmission contracts and 3.0 years for storage contracts as of December 31, 2012. 7Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Transmission and Storage System Firm transmission contracts obligate the Company’s customers to pay a fixed monthly charge to reserve an agreed upon amount of pipeline capacityregardless of the actual pipeline capacity used by a customer during each month, which is referred to as a monthly reservation charge. In addition to monthlyreservation charges, the Company also collects usage charges when a firm transmission customer uses the capacity it has reserved under these firmtransmission contracts. These charges are assessed on the actual volume of natural gas transported on the transmission system. Firm transmission customersare charged an interruptible over firm usage charge when the level of natural gas received for delivery from a firm transmission customer exceeds its reservedcapacity. Firm storage contracts obligate customers to pay a fixed monthly charge for the firm right to inject, withdraw and store a specified volume of naturalgas regardless of the amount of storage capacity actually utilized by the customer. Firm storage customers are also assessed usage charges on the actualquantities of natural gas injected into or withdrawn from storage. Firm service storage customers are charged an interruptible over firm usage charge when thelevel of gas withdrawn exceeds the customer’s maximum daily withdrawal limit. The Company’s transmission and storage system also derives a small portion of its revenues through interruptible service contracts under which itscustomers pay fees based on their actual utilization of assets for transmission and storage services. Customers who have executed interruptible contracts arenot assured capacity or service on the applicable pipeline and storage facilities. To the extent that physical capacity that is contracted for firm service is notbeing fully utilized or there is excess capacity that has not been contracted for service, the system can allocate such capacity to interruptible services. TheCompany also provides natural gas “park and loan” services to assist customers in managing short-term gas surpluses or deficits. Under these park and loanservice agreements, customers are charged a usage fee based on the quantities of natural gas stored in (park), or borrowed from (loan), the Company’sfacilities. 8Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. As of December 31, 2012, approximately 54% of the Company’s contracted transmission firm capacity was subscribed at the maximum recourserate allowed under the Company’s tariff. The remaining 46% of contracted transmission firm capacity was subscribed by customers under negotiated rateagreements at rates generally above the maximum recourse rate under the tariff, some of which is under contracts pending execution with respect to bindingprecedent agreements and the remaining contracts have been filed with and accepted by the FERC. Gathering System The Company’s gathering system consists of approximately 2,000 miles of FERC-regulated low-pressure gathering lines that have multiple deliveryinterconnects with transmission and storage systems. Revenues associated with the Company’s gathering system, all of which were generated underinterruptible gathering service contracts, represented approximately 12% and 15% of total revenues for the year ended December 31, 2012 and 2011,respectively. The primary term of a typical gathering agreement is one year with month-to-month roll over provisions terminable upon at least 30 days notice. Therates for gathering service are based on the maximum posted tariff rate and assessed on actual receipts into the gathering system. The Company also retains afixed percentage of wellhead natural gas receipts to recover natural gas used to run its compressor stations and lost and unaccounted for gas experienced on itsgathering system. Gathering System 9Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. The following table provides information regarding the transmission, storage and gathering assets as of December 31, 2012: SystemApproximateNumber ofMilesApproximateNumber ofReceipt PointsApproximateCompression(Horsepower)ApproximateAverage DailyThroughput (BBtu/d)Transmission and Storage7007026,000606Gathering2,0002,50022,00078 The following table provides a revenue breakdown of the Company’s contracts by business segment for the year ended December 31, 2012: Revenue Composition %Firm ContractsCapacityReservationInterruptibleContractsChargesUsage ChargesUsage ChargesTotalTransmission and Storage62%20%6%88%Gathering——12%12% Strategy The Company’s principal business objective is to increase the quarterly cash distributions that it pays to unitholders over time while ensuring theongoing stability of its business. The Company expects to achieve this objective through the following business strategies: · Pursuing accretive acquisitions from EQT. The Company intends to seek opportunities to expand its existing natural gas transmission,storage and gathering operations primarily through accretive acquisitions from EQT. While the Company will review acquisition opportunitiesfrom third parties as they become available, it expects that the majority of its most significant opportunities will be sourced from EQT’s existingportfolio of midstream assets or from expansion projects or acquisitions that EQT undertakes in the future as it builds additional midstreamassets to support its production growth. · Capitalizing on economically attractive organic growth opportunities. EQT’s acreage dedication to the Company’s assets and EQT’seconomic relationship with the Company provides a platform for organic growth. The Company expects to achieve this growth by meetingEQT’s midstream needs, which the Company expects to increase as a result of EQT’s anticipated drilling activity in the Company’s areas ofoperation. In addition, the Company intends to use EQT’s knowledge of, and expertise in, the Marcellus Shale in order to target and efficientlyexecute economically attractive organic growth projects, although EQT is under no obligation to share such knowledge and expertise with theCompany. The Company will evaluate organic expansion and greenfield construction opportunities in existing and new markets that it believeswill increase the volume of transmission, storage and gathering capacity subscribed on its system. The Company is executing on 2013expansion projects that it believes will increase the capacity of the transmission and storage system by approximately 450 BBtu per day at a totalcost of approximately $28 million. These expansion projects are expected to be placed into service by year-end 2013. Additional 2013 expansioncapital expenditures of approximately $10 million primarily relate to projects which will be completed in 2014. · Attracting additional third-party volumes. The Company actively markets its midstream services to, and pursues strategic relationshipswith, third-party producers in order to attract additional volumes and/or expansion opportunities. The Company believes that its connectivity tointerstate pipelines, which is a key feature of a header system transmission pipeline, as well as its position as an early developer of midstreaminfrastructure within certain areas of the Marcellus Shale, will allow the Company to capture additional third-party volumes in the future. TheCompany anticipates that organic growth projects that it pursues, or any assets it acquires from EQT, will be constructed in a manner that 10Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. leverages economies of scale to allow for incremental third party volumes in excess of capacity amounts needed by EQT. · Focusing on stable, fixed-fee business. The Company intends to pursue opportunities to provide fixed-fee transmission, storage and gatheringservices to EQT and third parties. The Company will focus on obtaining additional long-term firm commitments from customers, which mayinclude reservation-based charges, volume commitments and acreage dedications. · Increasing access to existing and new delivery markets. The Company is actively working to increase delivery interconnects with interstatepipelines, neighboring LDCs, large industrial facilities and electric generation plants in order to increase access to existing and new markets fornatural gas consumption. The Company’s transmission and storage system has the flexibility to accommodate significant additional throughputto service new end-user markets and it believes that the Company’s access to numerous supply sources, including Marcellus Shale production,five interstate pipelines and its on-system storage facilities, which can be used to balance volatile load swings, make the Company an attractiveoption for these end-user delivery markets. The Company’s Relationship with EQT One of the Company’s principal attributes is its relationship with EQT. Headquartered in Pittsburgh, Pennsylvania, in the heart of the AppalachianBasin, EQT is an integrated energy company, with an emphasis on natural gas production, gathering, transmission, distribution and marketing. EQTconducts its business through three business segments: EQT Production, EQT Midstream and Distribution. EQT Production is one of the largest natural gasproducers in the Appalachian Basin with 6.0 Tcfe of proved reserves across 3.5 million gross acres as of December 31, 2012. EQT Midstream providestransmission, storage and gathering services for EQT’s produced gas, as well as to third parties in the Appalachian Basin. EQT also has a regulated naturalgas distribution subsidiary, Equitable Gas Company, LLC (Equitable Gas Company), which distributes and sells natural gas to residential, commercial andindustrial customers in southwestern Pennsylvania, West Virginia and eastern Kentucky. EQT owns a 2.0% general partner interest in the Company, all of the Company’s incentive distribution rights and a 57.4% limited partner interest inthe Company. Because of its ownership of the incentive distribution rights, EQT is positioned to directly benefit from committing additional natural gasvolumes to the Company’s systems and from facilitating accretive acquisitions and organic growth opportunities. However, EQT is under no obligation tomake acquisition opportunities available to the Company, is not restricted from competing with the Company and may acquire, construct or dispose ofmidstream assets without any obligation to offer the Company the opportunity to purchase or construct these assets. The Company believes that its relationship with EQT is advantageous for the following reasons: · EQT is a leader among exploration and production companies in the Appalachian Basin. EQT had approximately 3.5 million gross acresas of December 31, 2012, of which approximately 540,000 gross acres were located in the Marcellus Shale. A substantial portion of EQT’sdrilling efforts in 2011 and 2012 were focused on drilling horizontal wells in the Marcellus Shale formations of southwestern Pennsylvania andnorthern West Virginia. For the year ended December 31, 2012, EQT reported total sales volumes of 258.5 Bcfe, representing a 33% increasecompared to the year ended December 31, 2011. Approximately 58% of EQT’s total production in 2012 was from wells in the Marcellus Shale.EQT Marcellus sales volumes were 85% higher for the year ended December 31, 2012 as compared to the year ended December 31, 2011. · EQT has a substantial and growing portfolio of midstream assets. The Company expects to have the opportunity to purchase additionalmidstream assets from EQT in the future, although EQT is under no obligation to make the opportunities available to the Company. EQT’sretained midstream assets include: – Sunrise Pipeline. On June 18, 2012, the Company transferred ownership of the Sunrise Pipeline, which was under construction atthe time and placed into service in the third quarter of 2012, to EQT. The Sunrise Pipeline provides access to liquids-rich MarcellusShale acreage and consists of 41.5 miles of 24-inch diameter pipeline that parallels and interconnects with the segment of theCompany’s transmission and storage system from Wetzel County, West 11Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Virginia to Greene County, Pennsylvania. In addition, the Sunrise Pipeline project included connecting to a new delivery point withTexas Eastern in Greene County and constructing the Jefferson compressor station. The Sunrise Pipeline project provides 314 BBtuper day of additional firm capacity to the system at an estimated cost of approximately $225 million. Furthermore, the Jeffersoncompressor station can be expanded to provide in aggregate over 470 BBtu per day of additional firm capacity. Management of EQThas indicated to the Company that EQT currently anticipates that this system will be fully developed over the next several yearsthrough the addition of relatively low-cost compression, including the expansion of the Jefferson compressor station. Initially, theCompany is operating the Sunrise Pipeline under a lease agreement with EQT by which the Company markets the capacity, enters intoall agreements for transportation service with customers and operates the Sunrise Pipeline according to the terms of its tariff. TheCompany makes lease payments to EQT based on revenues collected and the actual cost to operate the Sunrise Pipeline. As a result,the Sunrise Pipeline lease is not expected to have a net positive or negative impact on distributable cash flow. Upon termination of thelease agreement, the Company will be required to purchase the Sunrise Pipeline at a price to be negotiated between the parties. EQT hasthe ability to terminate the lease agreement early in its sole discretion. – Other retained midstream assets. EQT’s retained midstream asset base also includes approximately 8,300 miles of gatheringpipelines with throughput of approximately 838 BBtu of natural gas per day for the year ended December 31, 2012. These retainedassets include approximately 100 miles of high-pressure gathering lines serving both liquids-rich and dry areas in the Marcellus Shalelocated in Greene, Washington, Armstrong and Tioga counties in Pennsylvania and Doddridge and Taylor counties in West Virginia. – Development of additional midstream assets. As EQT expands its exploration and production operations in the Appalachian Basin,primarily in the Marcellus and Utica Shales, into areas that are currently underserved by midstream infrastructure, the Companyexpects it will develop, either independently or in partnership with EQT, additional midstream assets to ensure takeaway capacity forEQT’s expected production growth. While the Company’s relationship with EQT may provide significant benefits, it may also become a source of potential conflicts. For example, EQTis not restricted from competing with the Company. In addition, all of the executive officers and a majority of the directors of the Company’s general partneralso serve as officers and/or directors of EQT, and these officers and directors face conflicts of interest, which include the allocation of their time between theCompany and EQT. For a description of the Company’s relationships with EQT, please read Item 13, “Certain Relationships and Related Transactions, andDirector Independence.” Markets and Customers For the years ended December 31, 2012, 2011 and 2010, EQT accounted for approximately 78%, 79% and 81%, respectively, of the Company’stotal revenues. No other customers accounted for more than 10% of revenues in 2012, 2011 or 2010. Transmission and Storage Customers The Company provides natural gas transmission services for EQT and third parties, predominantly consisting of LDCs, marketers, producers andcommercial and industrial users that the Company believes to be creditworthy. The Company’s transmission system serves not only adjacent markets inPennsylvania and West Virginia but also provides its customers access to high-demand end-user markets in the Mid-Atlantic and Northeastern United Statesthrough 1,377 BBtu per day of delivery interconnect capacity with major interstate pipelines. The Company provides storage services to a broad mix ofcustomers, including marketers and LDCs. The Company’s primary transportation and storage customer is EQT. For the years ended December 31, 2012, 2011 and 2010, EQT and itsaffiliates accounted for approximately 81%, 83% and 86%, respectively, of transmission revenues and 68%, 77% and 82%, respectively, of storage revenues.Other than EQT, no customer accounted for more than 10% of total transmission and storage revenue for the years ended December 31, 2012, 12Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. 2011 or 2010. The Company’s other principal transmission customers include XTO Energy Inc., a wholly-owned subsidiary of ExxonMobil Corporation,and PDC Mountaineer, LLC. Gathering Customers The Company’s gathering system currently has approximately 2,500 receipt points with a number of natural gas producers. EQT representedapproximately 63% of the 78 BBtu per day of natural gas supplied to the gathering system in 2012, approximately 46% of the 78 BBtu per day of natural gassupplied to the gathering system in 2011, and approximately 45% of the 83 BBtu per day of natural gas supplied to the gathering system in 2010. TheCompany has gathering agreements conforming to its tariff with marketers and distribution companies that purchase natural gas from receipt points on thesystem for delivery to the interstate pipeline market, including EQT Energy, Equitable Gas Company and Dominion Field Services. Dominion Field Services generally provides any necessary processing for the gas gathered by the Company’s gathering system. In connection withthe Company’s sale of certain processing plants to Dominion Field Services in 2000, it entered into an agreement with a primary term through December 31,2014 pursuant to which Dominion Field Services is obligated to process any wet gas the Company delivers to certain processing facilities up to the individualoperating capacity of each plant. During the years ended December 31, 2012, 2011 and 2010, 77%, 76% and 75%, respectively, of the natural gas suppliedto the Company’s gathering system was processed by Dominion Field Services. The Company’s gathering customers are responsible for the costs associatedwith treating and processing natural gas in order to meet pipeline specifications, and are required to have processing agreements in place with Dominion FieldServices or another processor as a prerequisite to receiving transportation service on its gathering system. Competition Competition for natural gas transmission and storage volumes is primarily based on rates, customer commitment levels, timing, performance,commercial terms, reliability, services levels, location, reputation and fuel efficiencies. The Company’s principal competitors in its natural gas transmissionand storage market include companies that own major natural gas pipelines. In addition, the Company competes with companies who are building highpressure gathering facilities that are not subject to FERC jurisdiction to move volumes to interstate pipelines. EQT also owns and in the future may constructnatural gas transmission pipelines and high-pressure gathering facilities. Major pipeline natural gas transmission companies who compete with the Companyalso have existing storage facilities connected to their transmission systems that compete with certain of the Company’s storage facilities. Pending and futureconstruction projects, if and when brought on-line, may also compete with the Company’s natural gas transmission and storage services and many of itscompetitors have capital and other resources far greater than the Company. These projects may include FERC-certificated expansions and greenfieldconstruction projects. Key competitors for new low-pressure gathering systems include independent gas gatherers and integrated energy companies. Many of theCompany’s competitors have capital resources and control supplies of natural gas greater than it. The Company’s major competitors for natural gas suppliesand markets in its operating regions include Dominion Transmission, local distribution companies and small producers constructing their own gatheringsystems. Regulatory Environment FERC Regulation The Company’s interstate natural gas transportation and storage operations are regulated by FERC under the NGA, the NGPA and the Energy PolicyAct of 2005. The Company’s system operates under a tariff approved by FERC that establishes rates, cost recovery mechanisms and the terms andconditions of service to its customers. Generally, FERC’s authority extends to: · rates and charges for natural gas transmission, storage and gathering services;· certification and construction of new interstate transportation and storage facilities; 13Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. · extension or abandonment of interstate transportation and storage services and facilities;· maintenance of accounts and records;· relationships between pipelines and certain affiliates;· terms and conditions of services and service contracts with customers;· depreciation and amortization policies;· acquisition and disposition of interstate transportation and storage facilities; and· initiation and discontinuation of interstate transportation and storage services. The Company holds certificates of public convenience and necessity for its transmission and storage system issued by FERC pursuant to Section 7of the NGA covering rates, facilities, activities and services. These certificates require the Company to provide open-access services on its interstate pipelineand storage facilities on a non-discriminatory basis to all customers who qualify under the FERC gas tariff. In addition, under Section 8 of the NGA, FERChas the power to prescribe the accounting treatment of certain items for regulatory purposes. Thus, the books and records of the Company’s interstate pipelineand storage facilities may be periodically audited by FERC. FERC regulates the rates and charges for transportation and storage in interstate commerce. Under the NGA, rates charged by interstate pipelinesmust be just and reasonable. FERC’s cost-of-service regulations generally limit the maximum recourse rates for transportation and storage services to the costof providing service plus a reasonable rate of return. In each rate case, FERC must approve service costs, the allocation of costs, the allowed rate of return oncapital investment, rate design and other rate factors. A negative determination on any of these rate factors could adversely affect the Company’s business,financial condition, results of operations, liquidity and ability to make distributions. The maximum recourse rate that the Company may charge for its services is established through FERC’s ratemaking process. Generally, themaximum filed recourse rates for interstate pipelines are based on the cost of providing that service including recovery of and a return on the pipeline’s actualprudent historical cost of investment. Key determinants in the ratemaking process include the depreciated capital costs of the facilities, the costs of providingservice, the allowed rate of return and volume throughput and contractual capacity commitment assumptions. The maximum applicable recourse rates andterms and conditions for service are set forth in the pipeline’s FERC approved tariff. Rate design and the allocation of costs also can impact a pipeline’sprofitability. While the ratemaking process establishes the maximum rate that can be charged, interstate pipelines such as the Company’s transmission andstorage system are permitted to discount their firm and interruptible rates without further FERC authorization down to the variable cost of performing service,provided they do not “unduly discriminate.” In addition, pipelines are allowed to negotiate different rates with their customers, as described below. Pursuant to the NGA, changes to rates or terms and conditions of service can be proposed by a pipeline company under Section 4, or the existinginterstate transportation and storage rates or terms and conditions of service may be challenged by a complaint filed by interested persons including customers,state agencies or the FERC under Section 5. Rate increases proposed by a pipeline may be allowed to become effective subject to refund, while rates or termsand conditions of service which are the subject of a complaint under Section 5 are subject to prospective change by FERC. Rate increases proposed by aregulated interstate pipeline may be challenged and such increases may ultimately be rejected by FERC. Any successful challenge against rates charged for theCompany’s transportation and storage services could have a material adverse effect on its business, financial condition, results of operations, liquidity andability to make distributions. The Company’s interstate pipeline may also use “negotiated rates” which, in theory, could involve rates above or below the recourse rate or rates thatare subject to a different rate structure, provided that the affected customers are willing to agree to such rates and that the FERC has approved the negotiatedrate agreement. A prerequisite for allowing the negotiated rates is that negotiated rate customers must have had the option to take service under the pipeline’smaximum recourse rates. As of December 31, 2012, approximately 46% of the system’s contracted firm transportation capacity was committed under such“negotiated rate” contracts. Each negotiated rate transaction is designed to fix the negotiated rate for the term of the firm transportation agreement and the fixedrate is generally not subject to adjustment for increased or decreased costs occurring during the contract term. FERC regulations also extend to the terms and conditions set forth in agreements for transportation and storage services executed between interstatepipelines and their customers. These service agreements are required to conform, in all material respects, with the form of service agreements set forth in thepipeline’s FERC-approved 14Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. tariff. In the event that the FERC finds that an agreement, in whole or part, is materially non-conforming, it could reject the agreement, require the Company toseek modification of the agreement or require the Company to modify its tariff so that the non-conforming provisions are generally available to all customers. FERC Regulation of Gathering Rates and Terms of Service While the FERC does not generally regulate the rates and terms of service over facilities determined to be performing a natural gas gathering function,it has traditionally regulated rates charged by interstate pipelines for gathering services performed on the pipeline’s own gathering facilities when those gatheringservices are performed in connection with jurisdictional interstate transportation. The Company maintains rates and terms of service in its tariff for unbundledgathering services performed on its gathering facilities in connection with the transportation service. Just as with rates and terms of service for transmissionand storage services, the Company’s rates and terms of services for its gathering system may be challenged by complaint and are subject to prospective changeby the FERC. Rate increases and changes to terms and conditions of service the Company proposes for its gathering service may be protested and suchincreases or changes may ultimately be rejected by the FERC. Pipeline Safety and Maintenance The Company’s interstate natural gas pipeline system is subject to regulation by the PHMSA office of the DOT. PHMSA has established safetyrequirements pertaining to the design, installation, testing, construction, operation and maintenance of gas pipeline facilities, including requirements thatpipeline operators develop a written qualification program for individuals performing covered tasks on pipeline facilities and implement pipeline integritymanagement programs. These integrity management plans require more frequent inspections and other preventative measures to ensure safe operation of oil andnatural gas transportation pipelines in “high consequence areas,” such as high population areas or facilities that are hard to evacuate and areas of dailyconcentrations of people. Notwithstanding the investigatory and preventative maintenance costs incurred in the Company’s performance of customary pipeline managementactivities, significant additional expenses may be incurred if anomalous pipeline conditions are discovered or more stringent pipeline safety requirements areimplemented. For example, on August 25, 2011, PHMSA published an advanced notice of proposed rulemaking in which the agency is seeking publiccomment on a number of changes to its natural gas transmission pipeline regulations contained in federal regulations including: (i) modifying the definition ofhigh consequence areas; (ii) strengthening integrity management requirements as they apply to existing regulated operators; (iii) strengthening or expandingvarious non-integrity pipeline management standards relating to such matters as valve spacing, automatic or remotely-controlled valves, corrosion protectionand gathering lines; and (iv) adding new regulations to govern the safety of underground natural gas storage facilities including underground storage cavernsand injection withdrawal well piping that are not currently regulated under the federal regulations. PHMSA has specifically indicated an intent in thisrulemaking to address the need for standards governing the safety of underground natural gas storage facilities. Public comments on these matters weresubmitted to PHMSA in December 2011, and a final rule from PHMSA is forthcoming. On January 3, 2012, President Obama signed into law the Pipeline Safety, Regulatory Certainty and Job Creation Act of 2011. The Act increases themaximum civil penalties for administrative enforcement actions, requires the DOT to study and report on the sufficiency of existing gathering line regulationsto ensure safety and the use of leak detection systems by hazardous liquid pipelines, requires pipeline operators to verify their records on maximum allowableoperating pressure and imposes new emergency response and incident notification requirements. States are largely preempted by federal law from regulating interstate pipeline safety but may assume responsibility for enforcement of federalinterstate pipeline safety regulations for certain intrastate facilities. For example, a Pennsylvania statute was enacted in 2012 authorizing the PA PUC to enforcefederal regulations applicable to intrastate gathering lines as well as non-FERC certificated transmission lines. In practice, states vary considerably in theirauthority and capacity to address pipeline safety. The Company does not anticipate any significant problems in complying with any state laws and regulationswhich are determined to be applicable to its operations. The Company’s natural gas pipelines have inspection and compliance programs designed to maintaincompliance with federal and state pipeline safety and pollution control requirements. 15Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. The Company believes that its operations are in substantial compliance with all existing federal, state and local pipeline safety laws and regulationsand that its compliance with such laws and regulations will not have a material adverse effect on its business, financial condition, results of operations,liquidity or ability to make distributions, but the Company can provide no assurance that the adoption of new laws and regulations such as those proposed byPHMSA will not result in significant added costs that could have such a material adverse effect in the future. Pipeline Safety Cost Tracker The Company’s Pipeline Safety Cost Tracker (PSCT) is a cost recovery mechanism for qualifying costs incurred by the Company under the PSIA.The qualifying costs recoverable through the PSCT include a rate of return, taxes and depreciation associated with capital investments and actual operatingand maintenance expenses incurred under the PSIA. The PSCT surcharge is a usage charge expressed in dollars per Dth and is assessed to firm andinterruptible transmission service customers. The Company is required to track all expenses and capital investments associated with the PSIA made on andafter September 1, 2005. The Company makes annual filings with the FERC to adjust the PSCT surcharge to reconcile actual historic qualifying costsincurred against PSCT revenues collected. On March 1, 2012, Equitrans made its annual filing with the FERC to recover costs it incurs to comply with the PSIA. The filing provided for therecovery of $10.4 million in qualifying pipeline safety costs. One customer and the Independent Oil and Gas Association filed protests which asserted, amongother things, that Equitrans had not included all the appropriate volumes in calculating the level of its surcharge. Equitrans responded to the protests and in anorder issued March 30, 2012 the FERC accepted the annual filing and suspended it, allowing the surcharge to become effective on April 1, 2012. Equitranssubmitted additional information to the FERC on April 19, 2012 with the expectation that the FERC would subsequently issue an order based on the materialEquitrans submitted. On January 14, 2013, following numerous discussions with its customers, Equitrans filed a Stipulation and Agreement of Settlement (ProposedSettlement) with the FERC. If approved by the FERC, the Proposed Settlement will resolve all issues arising out of Equitrans’ 2012 PSCT annual filing. TheProposed Settlement will eliminate the tracking of PSIA costs and replace the PSCT surcharge with a Pipeline Safety Cost (PSC) rate effective April 1, 2013.The new PSC rate will have both a reservation and a usage component. The reservation component of the PSC rate applicable to firm transportation servicewill be set at $0.8108 per Dth of the contract Maximum Daily Quantity (MDQ) applicable to service provided on the mainline system and the usagecomponent will be set at $0.1372 per Dth delivered to the customer. The PSC rate applicable to interruptible over firm service, no-notice firm transportationservice nominated on a point to point basis and interruptible service will be $0.1372 per Dth delivered to the customer. Additionally, under the ProposedSettlement, Equitrans will reduce its transmission retainage factor approved in Equitrans’ most recent rate case from 3.72% to 2.72% effective February 1,2013. Equitrans will no longer track its continued recovery of base storage gas, and the 7.1 base storage gas recovery limit established in that 2006 rate casesettlement will be eliminated. To the extent that Equitrans over-recovers its actual fuel and lost gas, the excess gas could be used to replenish the storage basegas. If approved, the Proposed Settlement PSC rate and transmission retainage factor will be in effect for a minimum of three years. Since the inception of the PSCT surcharge in September 2005 through December 31, 2012, the Company has invested approximately $62 millionand recognized approximately $37 million of revenues associated with the PSCT. During the year ended December 31, 2012, the Company recognizedapproximately $8 million of revenues associated with the PSCT. Environmental, Health and Safety Regulation The Company’s natural gas transportation, storage and gathering activities are subject to stringent and complex federal, state and local laws andregulations governing environmental protection, including air emissions, water quality, wastewater discharges and solid waste management. Such laws andregulations generally require the Company to obtain and comply with a wide variety of environmental registrations, licenses, permits and other approvals.Failure to comply with these laws and regulations may result in the assessment of administrative, civil and/or criminal penalties, the imposition of remedialrequirements and the issuance of orders enjoining future operations. 16Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. The Company believes that compliance with existing federal, state and local environmental laws and regulations will not have a material adverseeffect on its business, financial condition, results of operations, liquidity or ability to make distributions. Nevertheless, environmental regulatory programscontinue to evolve and future regulations may place more restrictions and limitations on activities that may affect the environment. As a result, there can be noassurance as to the amount or timing of future expenditures for environmental compliance or remediation, and actual future expenditures may be different fromthe amounts the Company currently anticipates. The Company has established procedures for ongoing evaluation of its operations to identify potential environmental exposures and to assurecompliance with regulatory policies and procedures. Ongoing expenditures for compliance with environmental laws and regulations, including investments inplant and facilities to meet environmental requirements, have not been material to the Company’s business, financial condition, results of operations, liquidityor ability to make distributions. Climate Change Legislative and regulatory measures to address climate change and greenhouse gas emissions are in various phases of discussion or implementation.Effective January 1, 2011, the EPA began regulating greenhouse gas emissions by subjecting new facilities and major modifications to existing facilities thatemit large amounts of greenhouse gases to the permitting requirements of the federal Clean Air Act. In addition, the U.S. Congress has been considering billsthat would establish a cap-and-trade program to reduce emissions of greenhouse gases. Legislation or regulation that restricts carbon emissions could increasethe Company’s cost of environmental compliance by requiring the Company to install new equipment to reduce emissions from larger facilities and/orpurchase emission allowances. Climate change and greenhouse gas legislation or regulation could also delay or otherwise negatively affect efforts to obtainpermits and other regulatory approvals with regard to existing and new facilities or impose additional monitoring and reporting requirements. Conversely,legislation or regulation that sets a price on or otherwise restricts carbon emissions could also benefit the Company by increasing demand for natural gasbecause the combustion of natural gas results in substantially fewer carbon emissions per Btu of heat generated than other fuels such as coal. The effect on theCompany of any new legislative or regulatory measures will depend on the particular provisions that are ultimately adopted. Seasonality Operating revenues are seasonal and, based on utility customer contracts, are currently expected to be higher in the first and fourth quarters of eachyear. Weather impacts natural gas demand for power generation and heating purposes. Peak demand for natural gas typically occurs during the winter monthsas a result of the heating load. Title to Properties and Rights-of-Way The Company’s real property falls into two categories: (i) parcels that it owns in fee and (ii) parcels in which its interest derives from leases,easements, rights-of-way, permits or licenses from landowners or governmental authorities, permitting the use of such land for the Company’s operations.Portions of the land on which the Company’s pipelines and facilities are located are owned by the Company in fee title, and it believes that it has satisfactorytitle to these lands. The remainder of the land on which the Company’s pipelines and facilities are located are held by the Company pursuant to surface leasesbetween the Company, as lessee, and the fee owner of the lands, as lessors. The Company has leased or owned much of these lands for many years withoutany material challenge known to the Company relating to the title to the land upon which the assets are located, and it is believed that the Company hassatisfactory leasehold estates or fee ownership to such lands. The Company believes that it has satisfactory title to all of its material leases, easements, rights-of-way, permits and licenses, and the Company has no knowledge of any material challenge to its title to such assets or their underlying fee title. However, there are certain lands within the Company’s storage pools as to which it does not currently have real property rights. The Company hasidentified the lands as to which it believes it must obtain such rights and is in the midst of a program to acquire such rights. Since the beginning of thisprogram in 2009 through December 31, 2012, the Company has successfully acquired such rights for approximately 14,679 acres out of a total 46,452acres, and the Company expects to acquire the remainder within the next four years. In accordance with the Company’s FERC license, the geologicalformations within which its permitted storage facilities are located cannot be used by 17Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. third parties in any way that would detrimentally affect its storage operations and the Company has the power of eminent domain with respect to theacquisition of necessary real property rights to use such storage facilities. The Company believes the cost to acquire such rights will be approximately$7 million over the next four years. Some of the leases, easements, rights-of-way, permits and licenses which were transferred to the Company at the closing of the IPO in July 2012require the consent of the grantor of such rights, which in certain instances is a governmental entity. The Company obtained, prior to the closing of the IPO,sufficient third-party consents, permits and authorizations for the transfer of the assets necessary to enable it to operate its business in all material respects. EQT, the Company or their affiliates may initially continue to hold record title to portions of certain assets until the Company makes the appropriatefilings in the jurisdictions in which such assets are located and obtains any consents and approvals that were not obtained prior to transfer. Such consents andapprovals would include those required by federal and state agencies or political subdivisions. In some cases, EQT may, where required consents orapprovals have not been obtained, temporarily hold record title to property as nominee for the Company’s benefit and in other cases may, on the basis ofexpense and difficulty associated with the conveyance of title, cause its affiliates to retain title as nominee for the Company’s benefit until a future date. TheCompany anticipates that there will be no material change in the tax treatment of its common units resulting from EQT holding the title to any part of suchassets subject to future conveyance or as the Company’s nominee. Insurance The Company generally shares insurance coverage with EQT, for which it will reimburse EQT pursuant to the terms of the omnibus agreement. TheCompany’s insurance program includes general liability insurance, auto liability insurance, workers’ compensation insurance and property insurance. TheCompany’s general partner maintains director and officer liability insurance under a separate policy from EQT’s corporate director and officer insurance. Inaddition, the Company has procured a separate general liability policy. All insurance coverage is in amounts which management believes are reasonable andappropriate. Facilities EQT leases its corporate offices in Pittsburgh, Pennsylvania. Pursuant to the omnibus agreement, the Company pays a proportionate share ofEQT’s costs to lease the building. Employees The Company does not have any employees. The Company is managed and operated by the directors and officers of its general partner. All of theCompany’s executive management personnel are employees of EQT or an affiliate of EQT and devote the portion of their time to the Company’s business andaffairs that is required to manage and conduct its operations. Under the terms of the omnibus agreement with EQT, the Company reimburses EQT for theprovision of various general and administrative services for its benefit, for direct expenses incurred by EQT on the Company’s behalf and for expensesallocated to the Company as a result of it being a public entity. Availability of Reports The Company makes certain filings with the SEC, including its annual report on Form 10-K, quarterly reports on Form 10-Q, current reports onForm 8-K and all amendments and exhibits to those reports, available free of charge through its website, http://www.eqtmidstreampartners.com, as soon asreasonably practicable after the date they are filed with, or furnished to, the SEC. The filings are also available at the SEC’s Public Reference Room at 100 FStreet, N.E., Washington, D.C. 20549 or by calling 1-800-SEC-0330. These filings are also available on the internet at http://www.sec.gov. The Company’spress releases and recent analyst presentations are also available on the Company’s website. Composition of Segment Operating Revenues Presented below are operating revenues by segment as a percentage of total operating revenues of the Company. 18Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. For the year ended December 31,201220112010Transmission and storage operating revenues88%85%81%Gathering operating revenues12%15%19% Financial Information about Segments See Note 2 to the Consolidated Financial Statements for financial information by business segment including, but not limited to, revenues fromexternal customers, operating income and total assets, which information is incorporated herein by reference. Jurisdiction and Year of Formation EQT Midstream Partners is a Delaware limited partnership formed in January 2012. Financial Information about Geographic Areas All of the Company’s assets and operations are located in the continental United States. 19Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Item 1A. Risk Factors Risks Relating to Our Business In addition to the other information contained in this Annual Report on Form 10-K, the following risk factors should be considered in evaluating ourbusiness and future prospects. Please note that additional risks not presently known to us or that are currently considered immaterial may also have anegative impact on our business and operations. If any of the events or circumstances described below actually occurs, our business, financial condition,results of operations, liquidity or ability to make distributions could suffer and the trading price of our common units could decline. We are dependent on EQT for a substantial majority of our revenues and future growth. Therefore, we are indirectly subject to the businessrisks of EQT. We have no control over EQT’s business decisions and operations, and EQT is under no obligation to adopt a business strategythat favors us. Historically, we have provided a substantial percentage of our natural gas transmission, storage and gathering services to EQT. During the yearended December 31, 2012, approximately 78% of our revenues were from EQT. We expect to derive a substantial majority of our revenues from EQT for theforeseeable future. Therefore, any event, whether in our area of operations or otherwise, that adversely affects EQT’s production, financial condition, leverage,results of operations or cash flows may adversely affect our ability to sustain or increase cash distributions to our unitholders. Accordingly, we are indirectlysubject to the business risks of EQT, including the following: · natural gas price volatility may have an adverse effect on its drilling operations, revenue, profitability, future rate of growth and liquidity;· infrastructure capacity constraints and interruptions;· risks associated with the operation of its wells, pipelines and facilities, including potential environmental liabilities;· the availability of capital on a satisfactory economic basis to fund its operations;· its ability to identify production opportunities based on market conditions;· uncertainties inherent in projecting future rates of production;· its ability to develop additional reserves that are economically recoverable, to optimize existing well production and sustain production;· adverse effects of governmental and environmental regulation and negative public perception regarding its operations; and· the loss of key personnel. Unless we are successful in attracting significant unaffiliated third-party customers, our ability to maintain or increase the capacity subscribed andvolumes transported under service arrangements on our transmission and storage system as well as the volumes gathered on our gathering system will bedependent on receiving consistent or increasing commitments from EQT. While EQT has dedicated acreage to, and entered into long-term firm transportationcontracts on, our systems, it may determine in the future that drilling in areas outside of our current areas of operations is strategically more attractive to it andit is under no contractual obligation to maintain its production dedicated to us. For example, EQT Energy, LLC, or EQT Energy, a wholly-owned marketingaffiliate of EQT, allowed a storage agreement with us for 3.6 Bcf of storage capacity and the associated firm transmission agreement to expire on March 31,2012. This decision was likely due to lower natural gas price spreads and increased supply of natural gas from the Marcellus Shale. A reduction in thecapacity subscribed or volumes transported, stored or gathered on our systems by EQT could have a material adverse effect on our business, financialcondition, results of operations and ability to make quarterly cash distributions to our unitholders. We may not have sufficient cash from operations following the establishment of cash reserves and payment of fees and expenses, including costreimbursements to EQT and its affiliates, to enable us to pay the minimum quarterly distribution to holders of our common and subordinatedunits. In order to pay the minimum quarterly distribution of $0.35 per unit, or $1.40 per unit on an annualized basis, we will require available cash ofapproximately $12.4 million per quarter, or $49.5 million per year, based on the number of common, subordinated and general partner units outstanding atDecember 31, 2012. We may not have 20Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. sufficient available cash each quarter to enable us to pay the minimum quarterly distribution. The amount of cash we can distribute on our units principallydepends upon the amount of cash we generate from our operations, which will fluctuate from quarter to quarter based on, among other things: · the rates we charge for our transmission, storage and gathering services;· the level of firm transmission and storage capacity sold and volumes of natural gas we transport, store and gather for our customers;· regional, domestic and foreign supply and perceptions of supply of natural gas; the level of demand and perceptions of demand in our end-usemarkets; and actual and anticipated future prices of natural gas and other commodities (and the volatility thereof), which may impact ourability to renew and replace firm transmission and storage agreements;· the effect of seasonal variations in temperature on the amount of natural gas that we transport, store and gather;· the level of competition from other midstream energy companies in our geographic markets;· the creditworthiness of our customers;· the level of our operating, maintenance and general and administrative costs;· regulatory action affecting the supply of, or demand for, natural gas, the rates we can charge on our assets, how we contract for services, ourexisting contracts, our operating costs or our operating flexibility; and· prevailing economic conditions. In addition, the actual amount of cash we will have available for distribution will depend on other factors, including: · the level and timing of capital expenditures we make;· the level of our operating and general and administrative expenses, including reimbursements to our general partner and its affiliates, includingEQT, for services provided to us;· the cost of acquisitions, if any;· our debt service requirements and other liabilities;· fluctuations in our working capital needs;· our ability to borrow funds and access capital markets;· restrictions on distributions contained in our debt agreements;· the amount of cash reserves established by our general partner; and· other business risks affecting our cash levels. Our natural gas transportation, storage and gathering services are subject to extensive regulation by federal, state and local regulatoryauthorities. Changes or additional regulatory measures adopted by such authorities could have a material adverse effect on our business,financial condition, results of operations, liquidity and ability to make distributions. Our interstate natural gas transportation and storage operations are regulated by the FERC under the NGA, the NGPA, and the Energy Policy Act of2005. Our gathering operations are also regulated by the FERC in connection with our interstate transportation operations. Our system operates under a tariffapproved by the FERC that establishes rates, cost recovery mechanisms and terms and conditions of service to our customers. Generally, the FERC’sauthority extends to: · rates and charges for our natural gas transmission, storage and gathering services;· certification and construction of new interstate transmission and storage facilities;· abandonment of interstate transmission and storage services and facilities;· maintenance of accounts and records;· relationships between pipelines and certain affiliates;· terms and conditions of services and service contracts with customers;· depreciation and amortization policies;· acquisition and disposition of interstate transmission and storage facilities; and· initiation and discontinuation of interstate transmission and storage services. Interstate pipelines may not charge rates or impose terms and conditions of service that, upon review by the FERC, are found to be unjust andunreasonable or unduly discriminatory. The maximum recourse rate that may be 21Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. charged by our interstate pipeline for its transmission and storage services is established through the FERC’s ratemaking process. The maximum applicablerecourse rate and terms and conditions for service are set forth in our FERC-approved tariff. Pursuant to the NGA, existing interstate transportation and storage rates and terms and conditions of service may be challenged by complaint and aresubject to prospective change by the FERC. Additionally, rate increases and changes to terms and conditions of service proposed by a regulated interstatepipeline may be protested and such increases or changes can be delayed and may ultimately be rejected by the FERC. We currently hold authority from theFERC to charge and collect (i) “recourse rates” (i.e., the maximum rates an interstate pipeline may charge for its services under its tariff) and (ii) “negotiatedrates” which generally involve rates above the “recourse rates,” provided that the affected customers are willing to agree to such rates and that the FERC hasapproved the negotiated rate agreement. As of December 31, 2012, approximately 46% of our system’s contracted firm transportation capacity was committedunder such “negotiated rate” contracts, rather than recourse rate or discount rate contracts. There can be no guarantee that we will be allowed to continue tooperate under such rate structures for the remainder of those assets’ operating lives. Any successful challenge against rates charged for our transportation andstorage services could have a material adverse effect on our business, financial condition, results of operations, liquidity and ability to make distributions. While the FERC does not generally regulate the rates and terms of service over facilities determined to be performing a natural gas gathering function,the FERC has traditionally regulated rates charged by interstate pipelines for gathering services performed on the pipeline’s own gathering facilities when thosegathering services are performed in connection with jurisdictional interstate transmission facilities. We maintain rates and terms of service in our tariff forunbundled gathering services performed on our gathering facilities, which are connected to our transmission and storage system. Just as with rates and termsof service for transportation and storage services, our rates and terms of services for our gathering may be challenged by complaint and are subject toprospective change by the FERC. Rate increases and changes to terms and conditions of service which we propose for our gathering service may be protestedand such increases or changes can be delayed and may ultimately be rejected by the FERC. The FERC’s jurisdiction extends to the certification and construction of interstate transportation and storage facilities, including, but not limited to,acquisitions, facility maintenance, expansions, and abandonment of facilities and services. While the FERC exercises jurisdiction over the rate and terms ofservice for our gathering operations, our gathering facilities are not subject to the FERC’s certification and construction authority. Prior to commencingconstruction of new or existing interstate transportation and storage facilities, an interstate pipeline must obtain a certificate authorizing the construction, or fileto amend its existing certificate, from the FERC. Typically, a significant expansion project requires review by a number of governmental agencies, includingstate and local agencies, whose cooperation is important in completing the regulatory process on schedule. Any refusal by an agency to issue authorizations orpermits for one or more of these projects may mean that we will not be able to pursue these projects or that they will be constructed in a manner or with capitalrequirements that we did not anticipate. Such refusal or modification could materially and negatively impact the additional revenues expected from theseprojects. FERC regulations also extend to the terms and conditions set forth in agreements for transportation and storage services executed between interstatepipelines and their customers. These service agreements are required to conform, in all material respects, with the form of service agreements set forth in thepipeline’s FERC-approved tariff. Non-conforming agreements must be filed with, and accepted by, the FERC. In the event that the FERC finds that anagreement, in whole or part, is materially non-conforming, it could reject the agreement or require us to seek modification, or alternatively require us to modifyour tariff so that the non-conforming provisions are generally available to all customers. Under current policy, the FERC permits interstate pipelines to include an income tax allowance in the cost-of-service used as the basis for calculatingtheir regulated rates. For pipelines owned by partnerships or limited liability companies taxed as partnerships for federal income tax purposes, the taxallowance will reflect the actual or potential income tax liability on the FERC-jurisdictional income attributable to all partnership or limited liability companyinterests if the ultimate owner of the interest has an actual or potential income tax liability on such income. This policy was upheld on May 29, 2007 by theCourt of Appeals for the District of Columbia Circuit. The FERC will determine, on a case-by-case basis, whether the owners of an interstate pipeline havesuch actual or potential 22Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. income tax liability. In a future rate case, we may be required to demonstrate the extent to which inclusion of an income tax allowance in the applicable cost-of-service is permitted under the current income tax allowance policy. In addition, the FERC’s income tax allowance policy is frequently the subject of challenge,and we cannot predict whether the FERC or a reviewing court will alter the existing policy. If the FERC’s policy were to change and if the FERC were todisallow a substantial portion of our pipeline’s income tax allowance, our regulated rates, and therefore our revenues and ability to make distributions, couldbe materially adversely affected. The FERC may not continue to pursue its approach of pro-competitive policies as it considers matters such as interstate pipeline rates and rules andpolicies that may affect rights of access to natural gas transportation capacity and transportation and storage facilities. Failure to comply with applicable provisions of the NGA, the NGPA, the Pipeline Safety Act of 1968 and certain other laws, as well as with theregulations, rules, orders, restrictions and conditions associated with these laws, could result in the imposition of administrative and criminal remedies andcivil penalties of up to $1,000,000 per day, per violation. In addition, future federal, state, or local legislation or regulations under which we will operate our natural gas transportation, storage and gatheringbusinesses may have a material adverse effect on our business, financial condition, results of operations, liquidity and ability to make distributions to ourunitholders. Any significant decrease in production of natural gas in our areas of operation could adversely affect our business and operating results andreduce our distributable cash flow. Our business is dependent on the continued availability of natural gas production and reserves in our areas of operation. Low prices for natural gasor regulatory limitations could adversely affect development of additional reserves and production that is accessible by our pipeline and storage assets.Production from existing wells and natural gas supply basins with access to our systems will naturally decline over time. The amount of natural gas reservesunderlying these wells may also be less than anticipated, and the rate at which production from these reserves declines may be greater than anticipated.Additionally, the competition for natural gas supplies to serve other markets could reduce the amount of natural gas supply for our customers or lower naturalgas prices could cause producers to determine in the future that drilling activities in areas outside of our current areas of operation are strategically moreattractive to them. For example, in 2012 in response to low natural gas prices, a number of large natural gas producers announced their intention to re-evaluateand/or reduce their drilling programs in certain areas, including the Appalachian Basin. A reduction in the natural gas volumes supplied by EQT or otherthird party producers could result in reduced throughput on our systems and adversely impact our ability to grow our operations and increase cashdistributions to our unitholders. Accordingly, to maintain or increase the contracted capacity or the volume of natural gas transported, stored and gathered onour systems and cash flows associated therewith, our customers must continually obtain adequate supplies of natural gas. The primary factors affecting our ability to obtain non-dedicated sources of natural gas include (i) the level of successful drilling activity near oursystems and (ii) our ability to compete for volumes from successful new wells. While EQT has dedicated production from certain of its leased properties tous, we have no control over the level of drilling activity in our areas of operation, the amount of reserves associated with wells connected to our gatheringsystem or the rate at which production from a well declines. In addition, we have no control over EQT or other producers or their drilling or productiondecisions, which are affected by, among other things, the availability and cost of capital, prevailing and projected energy prices, demand for hydrocarbons,levels of reserves, geological considerations, environmental or other governmental regulations, the availability of drilling permits, the availability of drillingrigs, and other production and development costs. Fluctuations in energy prices can also greatly affect the development of new natural gas reserves. In general terms, the prices of natural gas, oil andother hydrocarbon products fluctuate in response to changes in supply and demand, market uncertainty and a variety of additional factors that are beyond ourcontrol. These factors include worldwide economic conditions; weather conditions and seasonal trends; the levels of domestic production and consumerdemand; the availability of imported liquefied natural gas, or LNG; the ability to export LNG; the availability of transportation systems with adequatecapacity; the volatility and uncertainty of regional pricing differentials and premiums; the price and availability of alternative fuels; the effect of energyconservation measures; the nature and extent of governmental regulation and taxation; and the anticipated future prices of natural 23Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. gas, LNG and other commodities. Declines in natural gas prices could have a negative impact on exploration, development and production activity and, ifsustained, could lead to a material decrease in such activity. Sustained reductions in exploration or production activity in our areas of operation would lead toreduced utilization of our systems. Because of these factors, even if new natural gas reserves are known to exist in areas served by our assets, producers maychoose not to develop those reserves. Moreover, EQT may not develop the acreage it has dedicated to us. If reductions in drilling activity result in our inabilityto maintain levels of contracted capacity and throughput, it could reduce our revenue and impair our ability to make quarterly cash distributions to ourunitholders. The price of natural gas has been at historically low levels recently, with the five-year NYMEX natural gas futures price at $3.62 per MMbtu inApril 2012, compared to a high of $11.51 per MMbtu in July 2008. As of January 31, 2013, the near month NYMEX natural gas futures price was$3.23 per MMbtu. The lower prices of natural gas are due in part to high levels of natural gas in storage, increased production, especially from unconventionalsources, like shale plays, and the effects of the economic downturn starting in 2008. According to the U.S. Energy Information Administration, or EIA, theamount of natural gas produced in the continental United States increased 14.1% from 55.3 Bcf/d to 63.0 Bcf/d from 2008 to 2011. Furthermore, the amountof natural gas in storage in the United States increased to 3.5 Tcf as of December 31, 2012 compared to the five-year average of 3.2 Tcf, due to theunseasonably warm winter of 2011/2012 and to the decisions of many producers to store natural gas based on their expectation of higher prices in the future.In response to lower natural gas prices, the number of land-based natural gas drilling rigs in the continental United States has declined from approximately1,403 as of December 31, 2008 to approximately 370 as of December 31, 2012 according to Smith Bits (a unit of Schlumberger Limited). In addition, it may be more difficult to maintain or increase the current volumes on our gathering systems in unconventional resource plays such asthe Marcellus Shale, as the basins in those plays generally have higher initial production rates and steeper production decline curves than wells in moreconventional basins. Furthermore, our gathering assets were initially constructed as a low-pressure system designed for shallow, vertical wells and MarcellusShale production is increasingly from horizontal wells at higher pressure than our existing gathering assets were designed to handle. If natural gas pricesremain low, production in the area around our low-pressure gathering system may continue to decline. Accordingly, volumes on our gathering system wouldneed to be replaced at a faster rate to maintain or grow the current volumes than may be the case in other regions of production. Should we determine that theeconomics of our gathering assets do not justify the capital expenditures needed to grow or maintain volumes associated therewith, revenues associated withthese assets will decline over time. If new supplies of natural gas are not obtained to replace the natural decline in volumes from existing supply basins, or if natural gas supplies arediverted to serve other markets, the overall volume of natural gas transported and stored on our systems would decline, which could have a material adverseeffect on our business, financial condition, results of operations, liquidity and on our ability to make quarterly cash distributions to our unitholders. We may not be able to increase our third-party throughput and resulting revenue due to competition and other factors, which could limit ourability to grow and extend our dependence on EQT. Part of our growth strategy includes diversifying our customer base by identifying opportunities to offer services to third parties other than EQT. Forthe years ended December 31, 2012, 2011 and 2010, EQT accounted for approximately 81%, 83% and 86%, respectively, of our transmission revenues,68%, 77% and 82%, respectively, of our storage revenues, 64%, 64% and 64%, respectively, of our gathering revenues and 78%, 79% and 81%,respectively, of our total revenues. Our ability to increase our third-party throughput and resulting revenue is subject to numerous factors beyond our control,including competition from third parties and the extent to which we have available capacity when third-party shippers require it. To the extent that we lackavailable capacity on our systems for third-party volumes, we may not be able to compete effectively with third-party systems for additional natural gasproduction in our areas of operation. We have historically provided transmission, storage and gathering services to third parties on only a limited basis, and we may not be able to attractmaterial third-party service opportunities. Our efforts to attract new unaffiliated customers may be adversely affected by our relationship with EQT and ourdesire to provide services pursuant to fee-based contracts. Our potential customers may prefer to obtain services under other forms of contractual arrangementsunder which we would be required to assume direct commodity exposure, and potential 24Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. customers may desire to contract for gathering services that are not subject to FERC regulation. In addition, we will need to continue to improve our reputationamong our potential customer base for providing high quality service in order to continue to successfully attract unaffiliated third parties. We are exposed to the credit risk of our customers in the ordinary course of our business. We extend credit to our customers as a normal part of our business. As a result, we are exposed to the risk of loss resulting from the nonpaymentand/or nonperformance of our customers. While we have established credit policies, including assessing the creditworthiness of our customers as permitted byour FERC-approved natural gas tariff, and requiring appropriate terms or credit support from them based on the results of such assessments, we may nothave adequately assessed the creditworthiness of our existing or future customers. Furthermore, unanticipated future events could result in a deterioration of thecreditworthiness of our contracted customers, including EQT. Any resulting nonpayment and/or nonperformance by our customers could have a materialadverse effect on our business, financial condition, results of operations, liquidity and ability to make quarterly cash distributions to our unitholders. Increased competition from other companies that provide transmission, storage or gathering services, or from alternative fuel sources, could havea negative impact on the demand for our services, which could adversely affect our financial results. Our ability to renew or replace existing contracts at rates sufficient to maintain current revenues and cash flows could be adversely affected by theactivities of our competitors. Our systems compete primarily with other interstate and intrastate pipelines and storage facilities in the transportation and storageof natural gas. Some of our competitors have greater financial resources and may now, or in the future, have access to greater supplies of natural gas than wedo. Some of these competitors may expand or construct transportation and storage systems that would create additional competition for the services we provideto our customers. In addition, our customers may develop their own transmission, storage or gathering services instead of using ours. Moreover, EQT and itsaffiliates are not limited in their ability to compete with us. The policies of the FERC promoting competition in natural gas markets are having the effect of increasing the natural gas transportation and storageoptions for our traditional customer base. As a result, we could experience some “turnback” of firm capacity as existing agreements expire. If we are unable toremarket this capacity or can remarket it only at substantially discounted rates compared to previous contracts, we may have to bear the costs associated withthe turned back capacity. Increased competition could reduce the volumes of natural gas transported or stored by our systems or, in cases where we do nothave long-term fixed rate contracts, could force us to lower our transportation or storage rates. Further, natural gas as a fuel competes with other forms of energy available to end-users, including electricity, coal and liquid fuels. Increaseddemand for such forms of energy at the expense of natural gas could lead to a reduction in demand for natural gas storage and transportation services. All of these competitive pressures could make it more difficult for us to retain our existing customers and/or attract new customers as we seek toexpand our business, which could have a material adverse effect on our business, financial condition, results of operations, liquidity and ability to makequarterly cash distributions to our unitholders. In addition, competition could intensify the negative impact of factors that decrease demand for natural gas inthe markets served by our systems, such as adverse economic conditions, weather, higher fuel costs and taxes or other governmental or regulatory actions thatdirectly or indirectly increase the cost or limit the use of natural gas. If third-party pipelines and other facilities interconnected to our pipelines and facilities become unavailable to transport natural gas, ourrevenues and cash available to make distributions to our unitholders could be adversely affected. We depend upon third-party pipelines and other facilities that provide receipt and delivery options to and from our transmission and storage system.For example, our transmission and storage system interconnects with the following interstate pipelines: Texas Eastern, Dominion Transmission, ColumbiaGas Transmission, Tennessee Gas Pipeline Company and National Fuel Gas Supply Corporation, as well as multiple distribution companies. Similarly, ourgathering system has multiple delivery interconnects to the Dominion Transmission system. Additionally, 25Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. substantially all of the natural gas that is gathered by our gathering system that requires processing and treating is handled by Dominion Transmission. In theevent that our access to such facility was impaired or if we were unable to negotiate a processing and treating contract with another party on like terms, theamount of natural gas that our gathering system can gather and transport onto our transmission and storage system would be adversely affected, which couldreduce revenues from our gathering activities. Because we do not own these third party pipelines or facilities, their continuing operation is not within ourcontrol. If these or any other pipeline connections or facilities were to become unavailable for current or future volumes of natural gas due to repairs, damage tothe facility, lack of capacity or any other reason, our ability to operate efficiently and continue shipping natural gas to end markets could be restricted, therebyreducing our revenues. Any temporary or permanent interruption at any key pipeline interconnect or facility could have a material adverse effect on ourbusiness, financial condition, results of operations, liquidity and ability to make quarterly cash distributions to our unitholders. Certain of the services we provide on our transmission and storage system are subject to long-term, fixed-price “negotiated rate” contracts thatare not subject to adjustment, even if our cost to perform such services exceeds the revenues received from such contracts, and, as a result, ourcosts could exceed our revenues received under such contracts. It is possible that costs to perform services under “negotiated rate” contracts will exceed the negotiated rates. If this occurs, it could decrease the cashflow realized by our systems and, therefore, the cash we have available for distribution to our unitholders. Under FERC policy, a regulated service providerand a customer may mutually agree to sign a contract for service at a “negotiated rate,” which is generally above the FERC-regulated “recourse rate” for thatservice, and that contract must be filed with and accepted by the FERC. As of December 31, 2012, approximately 46% of our contracted transmission firmcapacity was subscribed under such “negotiated rate” contracts. These “negotiated rate” contracts are not generally subject to adjustment for increased costswhich could be caused by inflation or other factors relating to the specific facilities being used to perform the services. For example, on March 1, 2012,Equitrans made an annual filing with the FERC to recover costs it incurred to comply with the Pipeline Safety Improvement Act of 2002; however the amountof such recovery is subject to FERC approval. The 2012 filing has not yet been approved and is the subject of two protests, with respect to which Equitranshas filed the Proposed Settlement intended to resolve the issues raised by the protesting customers. To the extent the FERC does not approve the ProposedSettlement or ultimately agrees with the positions of the protesting customers, the level of the surcharge, and thus the amount of the anticipated cost recovery,could be significantly reduced. If the level of the surcharge is reduced, we will not generally be able to adjust these “negotiated rate” contracts to take intoaccount the increased costs we incur to comply with the Pipeline Safety Improvement Act of 2002. Any shortfall of revenue, representing the difference between“recourse rates” (if higher) and negotiated rates, under current FERC policy is generally not recoverable from other shippers. We may not be able to renew or replace expiring contracts at favorable rates or on a long-term basis. Our primary exposure to market risk occurs at the time our existing contracts expire and are subject to renegotiation and renewal. As of December 31,2012, the weighted average remaining contract life based on total revenues for our firm transmission and storage contracts was approximately 9.4 years. Theextension or replacement of existing contracts, including our contracts with EQT, depends on a number of factors beyond our control, including: · the level of existing and new competition to provide services to our markets;· the macroeconomic factors affecting natural gas economics for our current and potential customers;· the balance of supply and demand, on a short-term, seasonal and long-term basis, in our markets;· the extent to which the customers in our markets are willing to contract on a long-term basis; and· the effects of federal, state or local regulations on the contracting practices of our customers. Any failure to extend or replace a significant portion of our existing contracts, or extending or replacing them at unfavorable or lower rates, could havea material adverse effect on our business, financial condition, results of operations, liquidity and ability to make quarterly cash distributions to ourunitholders. If the tariff governing the services we provide is successfully challenged, we could be required to reduce our tariff rates, which would have amaterial adverse effect on our business, financial condition, results of operations, liquidity and ability to make quarterly cash distributions toour unitholders. 26Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Any of our shippers, the FERC, or other interested stakeholders, such as state regulatory agencies, may challenge the maximum recourse rates or theterms and conditions of service included in our tariff. We do not have an agreement in place that would prohibit EQT or its affiliates from challenging ourtariff. If any challenge were successful, among other things, the rates that we charge on our systems could be reduced. Successful challenges would have amaterial adverse effect on our business, financial condition, results of operations, liquidity and ability to make quarterly cash distributions to our unitholders. If we are unable to make acquisitions on economically acceptable terms from EQT or third parties, our future growth will be limited, and theacquisitions we do make may reduce, rather than increase, our cash generated from operations on a per unit basis. Our ability to grow depends, in part, on our ability to make acquisitions that increase our cash generated from operations on a per unit basis. Theacquisition component of our strategy is based, in large part, on our expectation of ongoing divestitures of midstream energy assets by industry participants,including EQT. We have no contractual arrangement with EQT that would require it to provide us with an opportunity to offer to purchase midstream assetsthat it may sell. Accordingly, while we believe EQT will be incentivized pursuant to its economic relationship with us to offer us opportunities to purchasemidstream assets, there can be no assurance that any such offer will be made. Furthermore, many factors could impair our access to future midstream assetsand the willingness of EQT to offer us acquisition opportunities, including a change in control of EQT or a transfer of the incentive distribution rights by ourgeneral partner to a third party. A material decrease in divestitures of midstream energy assets from EQT or otherwise would limit our opportunities for futureacquisitions and could have a material adverse effect on our business, financial condition, results of operations, liquidity and ability to make quarterly cashdistributions to our unitholders. If we are unable to make accretive acquisitions from EQT or third parties, whether because, among other reasons, (i) EQT elects not to sell orcontribute additional assets to us or to offer acquisition opportunities to us, (ii) we are unable to identify attractive third-party acquisition opportunities, (iii) weare unable to negotiate acceptable purchase contracts with EQT or third parties, (iv) we are unable to obtain financing for these acquisitions on economicallyacceptable terms, (v) we are outbid by competitors or (vi) we are unable to obtain necessary governmental or third-party consents, then our future growth andability to increase distributions will be limited. Furthermore, even if we do make acquisitions that we believe will be accretive, these acquisitions maynevertheless result in a decrease in the cash generated from operations on a per unit basis. Any acquisition involves potential risks, including, among other things: · mistaken assumptions about volumes, revenue and costs, including synergies and potential growth;· an inability to secure adequate customer commitments to use the acquired systems or facilities;· an inability to integrate successfully the assets or businesses we acquire;· the assumption of unknown liabilities for which we are not indemnified or for which our indemnity is inadequate;· the diversion of management’s and employees’ attention from other business concerns; and· unforeseen difficulties operating in new geographic areas or business lines. If any acquisition eventually proves not to be accretive to our distributable cash flow per unit, it could have a material adverse effect on our business,financial condition, results of operations, liquidity and ability to make quarterly cash distributions to our unitholders. Expanding our business by constructing new midstream assets subjects us to risks. Organic and greenfield growth projects are a significant component of our growth strategy. The development and construction of pipelines and storagefacilities involves numerous regulatory, environmental, political and legal uncertainties beyond our control and may require the expenditure of significantamounts of capital. These types of projects may not be completed on schedule, at the budgeted cost or at all. Moreover, our revenues may not increaseimmediately upon the expenditure of funds on a particular project. For instance, if we build a new midstream asset, the construction will occur over anextended period of time, and we will not receive material increases in revenues until the project is placed into service. Moreover, we may construct facilities tocapture anticipated future growth in production and/or demand in a region in which such growth does not 27Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. materialize. As a result, new facilities may not be able to attract enough throughput to achieve our expected investment return, which could adversely affect ourbusiness, financial condition, results of operations, liquidity and ability to make distributions. Certain of our internal growth projects may require regulatory approval from federal and state authorities prior to construction, including anyextensions from or additions to our transmission and storage system. The approval process for storage and transportation projects located in the Northeast hasbecome increasingly challenging, due in part to state and local concerns related to unregulated exploration and production and gathering activities in newproduction areas, including the Marcellus Shale play. Such authorization may not be granted or, if granted, such authorization may include burdensome orexpensive conditions. If we are unable to obtain needed capital or financing on satisfactory terms to fund expansions of our asset base, our ability to make quarterlycash distributions may be diminished or our financial leverage could increase. We do not have any commitment with any of our affiliates toprovide any direct or indirect financial assistance to us. In order to expand our asset base, we will need to make expansion capital expenditures. If we do not make sufficient or effective expansion capitalexpenditures, we will be unable to expand our business operations and may be unable to maintain or raise the level of our quarterly cash distributions. We willbe required to use cash from our operations or incur borrowings or sell additional common units or other limited partner interests in order to fund ourexpansion capital expenditures. Using cash from operations will reduce distributable cash flow to our common unitholders. Our ability to obtain bankfinancing or to access the capital markets for future equity or debt offerings may be limited by our financial condition at the time of any such financing oroffering as well as the covenants in our debt agreements, general economic conditions and contingencies and uncertainties that are beyond our control. Even ifwe are successful in obtaining funds for expansion capital expenditures through equity or debt financings, the terms thereof could limit our ability to paydistributions to our common unitholders. In addition, incurring additional debt may significantly increase our interest expense and financial leverage, andissuing additional limited partner interests may result in significant common unitholder dilution and increase the aggregate amount of cash required tomaintain the then-current distribution rate, which could materially decrease our ability to pay distributions at the then-current distribution rate. We do not have any commitment with our general partner or other affiliates, including EQT, to provide any direct or indirect financial assistance tous. We are subject to numerous hazards and operational risks. Our business operations are subject to all of the inherent hazards and risks normally incidental to the gathering, compressing, transportation andstorage of natural gas. These operating risks include, but are not limited to: · damage to pipelines, facilities, equipment and surrounding properties caused by hurricanes, earthquakes, tornadoes, floods, fires and othernatural disasters and acts of terrorism;· inadvertent damage from construction, vehicles, farm and utility equipment;· uncontrolled releases of natural gas and other hydrocarbons;· leaks, migrations or losses of natural gas as a result of the malfunction of equipment or facilities and, with respect to storage assets, as a resultof undefined boundaries, geologic anomalies, natural pressure migration and wellbore migration;· ruptures, fires and explosions; and· other hazards that could also result in personal injury and loss of life, pollution and suspension of operations. These risks could result in loss of human life, personal injuries, significant damage to property, environmental pollution, impairment of ouroperations and substantial losses to us. The location of certain segments of our systems in or near populated areas, including residential areas, commercialbusiness centers and industrial sites, could increase the damages resulting from these risks. In spite of any precautions taken, an event such as thosedescribed above could cause considerable harm to people or property and could have a material adverse effect on our business, financial condition, results ofoperations, liquidity and ability to make distributions. Accidents or other 28Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. operating risks could further result in loss of service available to our customers. Such circumstances, including those arising from maintenance and repairactivities, could result in service interruptions on segments of our systems. Potential customer impacts arising from service interruptions on segments of oursystems could include limitations on our ability to satisfy customer requirements, obligations to provide reservation charge credits to customers in times ofconstrained capacity, and solicitation of our existing customers by others for potential new projects that would compete directly with our existing services.Such circumstances could adversely impact our ability to meet contractual obligations and retain customers, with a resulting negative impact on our business,financial condition, results of operations, liquidity and on our ability to make distributions to you. We do not insure against all potential losses and could be seriously harmed by unexpected liabilities. We are not fully insured against all risks inherent to our businesses, including environmental accidents that might occur. In addition, we do notmaintain business interruption insurance in the type and amount necessary to cover all possible risks of loss. The occurrence of any operating risks not fullycovered by insurance could have a material adverse effect on our business, financial condition, results of operations, liquidity and on our ability to makedistributions to you. EQT currently maintains excess liability insurance that covers EQT’s and its affiliates’, including our, legal and contractual liabilities arising out ofbodily injury, personal injury or property damage, including resulting loss of use, to third parties. This excess liability insurance includes coverage forsudden and accidental pollution liability but excludes: release of pollutants subsequent to their disposal; release of substances arising from the combustion offuels that result in acidic deposition; and testing, monitoring, clean-up, containment, treatment or removal of pollutants from property owned, occupied by,rented to, used by or in the care, custody or control of EQT and its affiliates. EQT also maintains coverage for itself and its affiliates, including us, for physical damage to assets and resulting business interruption, includingdamage caused by terrorist acts committed by a U.S. person or interest. All of EQT’s insurance is subject to deductibles. If a significant accident or event occurs for which we are not fully insured, it could adversely affectour operations and financial condition. We may not be able to maintain or obtain insurance of the type and amount we desire at reasonable rates, and we mayelect to self insure a portion of our asset portfolio. The insurance coverage we do obtain may contain large deductibles or fail to cover certain hazards or coverall potential losses. In addition, we share insurance coverage with EQT, for which we will reimburse EQT pursuant to the terms of the omnibus agreement. Tothe extent EQT experiences covered losses under the insurance policies, the limit of our coverage for potential losses may be decreased. We are subject to stringent environmental laws and regulations that may expose us to significant costs and liabilities. Our natural gas gathering, transportation and storage operations are subject to stringent and complex federal, state and local environmental laws andregulations that govern the discharge of materials into the environment or otherwise relate to environmental protection. Examples of these laws include: · the federal Clean Air Act and analogous state laws that impose obligations related to air emissions;· the federal Comprehensive Environmental Response, Compensation and Liability Act, known as CERCLA or the Superfund law, andanalogous state laws that regulate the cleanup of hazardous substances that may be or have been released at properties currently or previouslyowned or operated by us or at locations to which our wastes are or have been transported for disposal;· the federal Water Pollution Control Act, or the Clean Water Act, and analogous state laws that regulate discharges from our facilities into stateand federal waters, including wetlands;· the federal Oil Pollution Act, or OPA, and analogous state laws that establish strict liability for releases of oil into waters of the United States;· the federal Resource Conservation and Recovery Act, or RCRA, and analogous state laws that impose requirements for the storage, treatmentand disposal of solid and hazardous waste from our facilities;· the Endangered Species Act, or ESA; and· the Toxic Substances Control Act, or TSCA, and analogous state laws that impose requirements on the use, storage and disposal of variouschemicals and chemical substances at our facilities. 29Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. These laws and regulations may impose numerous obligations that are applicable to our operations, including the acquisition of permits to conductregulated activities, the incurrence of capital or operating expenditures to limit or prevent releases of materials from our pipelines and facilities, and theimposition of substantial liabilities and remedial obligations for pollution resulting from our operations. Numerous governmental authorities, such as the U.S.Environmental Protection Agency, or the EPA, and analogous state agencies, have the power to enforce compliance with these laws and regulations and thepermits issued under them, oftentimes requiring difficult and costly corrective actions. Failure to comply with these laws, regulations and permits may resultin the assessment of administrative, civil and criminal penalties, the imposition of remedial obligations and the issuance of injunctions limiting or preventingsome or all of our operations. In addition, we may experience a delay in obtaining or be unable to obtain required permits or regulatory authorizations, whichmay cause us to lose potential and current customers, interrupt our operations and limit our growth and revenue. In addition, future changes in environmentalor other laws may result in additional compliance expenditures that have not been pre-funded and which could adversely affect our business, financialcondition, results of operations, liquidity and our ability to make cash distributions to our unitholders. For example, on April 7, 2012, the EPA issued finalrules that establish new air emission controls for oil and natural gas production, processing, transmission and storage operations. Specifically, EPA’srule package includes standards to address emissions of sulfur dioxide and volatile organic compounds, or VOC, and a separate set of emission standards toaddress hazardous air pollutants frequently associated with oil and natural gas production and processing activities. The rules establish new or more stringentrequirements regarding emissions from compressors, dehydrators, storage tanks and other production equipment in addition to leak detection requirements fornatural gas processing plants. These rules may require modifications to certain of our operations, which could include the installation of new equipment tocontrol emissions. Compliance with such rules could result in significant costs, including increased capital expenditures and operating costs, and couldadversely affect our business. There is a risk that we may incur costs and liabilities in connection with our operations due to historical industry operations and waste disposalpractices, our handling of wastes and potential emissions and discharges related to our operations. Private parties, including the owners of the propertiesthrough which our transmission and storage system or our gathering system pass and facilities where our wastes are taken for reclamation or disposal, mayhave the right to pursue legal actions to require remediation of contamination or enforce compliance with environmental requirements as well as to seekdamages for personal injury or property damage. For example, an accidental release from one of our pipelines could subject us to substantial liabilities arisingfrom environmental cleanup and restoration costs, claims made by neighboring landowners and other third parties for personal injury and property damageand fines or penalties for related violations of environmental laws or regulations. Pursuant to the terms of the omnibus agreement, EQT will indemnify us forcertain potential environmental and toxic tort claims, losses and expenses associated with the operation of the assets retained by us and occurring before theclosing date of the IPO. However, the maximum liability of EQT for these indemnification obligations will not exceed $15 million, which may not besufficient to fully compensate us for such claims, losses and expenses. In addition, changes in environmental laws occur frequently, and any such changesthat result in more stringent and costly waste handling, storage, transport, disposal or remediation requirements could have a material adverse effect on ourbusiness, financial condition, results of operations, liquidity or ability to make distributions. We may not be able to recover all or any of these costs frominsurance. Climate change legislation, regulatory initiatives and litigation could result in increased operating costs and reduced demand for the natural gasservices we provide. In December 2009, the EPA published its findings that emissions of greenhouse gases, or GHGs, present a danger to public health and theenvironment because emissions of such gases are, according to the EPA, contributing to warming of the Earth’s atmosphere and other climatic conditions.Based on these findings, the EPA adopted two sets of regulations that restrict emissions of GHGs under existing provisions of the federal Clean Air Act,including one that requires a reduction in emissions of GHGs from motor vehicles and another that regulates GHG emissions from certain large stationarysources under the Clean Air Act Prevention of Significant Deterioration and Title V permitting programs. The stationary source rule “tailors” these permittingprograms to apply to certain stationary sources of GHG emissions in a multi-step process, with the largest sources first subject to permitting. In addition, theEPA expanded its existing GHG emissions reporting rule to include onshore oil and natural gas processing, transmission, storage, and distribution activities,beginning in 2012 for emissions occurring in 2011. Congress has also from time to time considered legislation to reduce emissions of GHGs. The adoption ofany legislation or 30Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. regulations that restrict emissions of GHGs from our equipment and operations could require us to incur significant added costs to reduce emissions of GHGsor could adversely affect demand for the natural gas we transport, store and gather. Significant portions of our pipeline systems have been in service for several decades. There could be unknown events or conditions or increasedmaintenance or repair expenses and downtime associated with our pipelines that could have a material adverse effect on our business, financialcondition, results of operations, liquidity and ability to make distributions. Significant portions of our transmission and storage system and our gathering system have been in service for several decades. The age andcondition of our systems could result in increased maintenance or repair expenditures, and any downtime associated with increased maintenance and repairactivities could materially reduce our revenue. Any significant increase in maintenance and repair expenditures or loss of revenue due to the age or condition ofour systems could adversely affect our business, financial condition, results of operations, liquidity and our ability to make cash distributions to ourunitholders. We may incur significant costs and liabilities as a result of pipeline integrity management program testing and related repairs. Pursuant to the Pipeline Safety Improvement Act of 2002, as reauthorized and amended by the Pipeline Inspection, Protection, Enforcement andSafety Act of 2006, the U.S. Department of Transportation, or DOT, has adopted regulations requiring pipeline operators to develop integrity managementprograms for transmission pipelines located where a leak or rupture could harm “high consequence areas,” including high population areas, unless theoperator effectively demonstrates by risk assessment that the pipeline could not affect the area. The regulations require operators, including us, to: · perform ongoing assessments of pipeline integrity;· identify and characterize applicable threats to pipeline segments that could impact a high consequence area;· maintain processes for data collection, integration and analysis;· repair and remediate pipelines as necessary; and· implement preventive and mitigating actions. Moreover, changes to pipeline safety laws and regulations that result in more stringent or costly safety standards could have a significant adverseeffect on us and similarly situated midstream operators. On January 3, 2012, President Obama signed the Pipeline Safety, Regulatory Certainty, and JobCreation Act of 2011, which act, among other things, directs the Secretary of Transportation to promulgate rules or standards relating to expanded integritymanagement requirements, automatic or remote-controlled valve use, excess flow valve use, leak detection system installation and testing to confirm thematerial strength of pipe operating above 30% of specified minimum yield strength in high consequence areas. These safety enhancement requirements andother provisions of this act could require us to install new or modified safety controls, pursue additional capital projects, or conduct maintenance programs onan accelerated basis, any or all of which tasks could result in our incurring increased operating costs that could be significant and have a material adverseeffect on our business, financial condition, results of operations, liquidity or ability to make distributions. In addition, many states have adopted regulations similar to existing DOT regulations for intrastate gathering and transmission lines. Although manyof our natural gas facilities fall within a class that is not subject to these requirements, we may incur significant costs and liabilities associated with repair,remediation, preventative or mitigation measures associated with our non-exempt pipelines, particularly our gathering pipelines. This estimate does not includethe costs, if any, for repair, remediation, preventative or mitigating actions that may be determined to be necessary as a result of the testing program, whichcould be substantial. Such costs and liabilities might relate to repair, remediation, preventative or mitigating actions that may be determined to be necessary asa result of the testing program, as well as lost cash flows resulting from shutting down our pipelines during the pendency of such repairs. Additionally, shouldwe fail to comply with DOT regulations, we could be subject to penalties and fines. We retained approximately $32 million of the net proceeds from the IPO inorder to pre-fund certain identified regulatory compliance capital expenditures, the majority of which are expected to be incurred over the two years followingthe IPO; however the actual cost of such expenditures may exceed $32 million. Furthermore, we are not 31Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. restricted from using this approximately $32 million for other purposes. In addition, we may be required to make additional maintenance capital expendituresin the future for similar regulatory compliance initiatives that are not reflected in our forecasted maintenance capital expenditures. The adoption of legislation relating to hydraulic fracturing and the enactment of severance taxes and impact fees on natural gas wells could causeour current and potential customers to reduce the number of wells they drill in the Marcellus Shale. If drilling reductions are significant, thereductions would have a material adverse effect on our business, financial condition, results of operations, liquidity and ability to makequarterly cash distributions to our unitholders. Our assets are primarily located in the Marcellus Shale fairway in southern Pennsylvania and northern West Virginia and a majority of theproduction that we receive from customers is produced from wells completed using hydraulic fracturing. Hydraulic fracturing is an important and commonlyused process in the completion of oil and gas wells, particularly in unconventional resource plays like the Marcellus Shale. The EPA is developing permittingguidance under the federal Safe Drinking Water Act for hydraulic fracturing activities that use diesel fuels in fracturing fluids. In addition, legislation has beenintroduced before Congress to provide for federal regulation of hydraulic fracturing and to require the disclosure of chemicals used by the oil and gas industryin the hydraulic fracturing process. Any such legislation may provide more opportunities for third parties opposed to hydraulic fracturing to initiate legalproceedings against our customers. In addition, a number of federal agencies, including the EPA and the U.S. Department of Energy, are analyzing, or havebeen requested to review, a variety of environmental issues associated with shale development, including hydraulic fracturing. On May 4, 2012, theDepartment of the Interior’s Bureau of Land Management, or BLM, issued a proposed rule to regulate hydraulic fracturing on public and Indian land. Therule would require companies to disclose the chemicals used in hydraulic fracturing operations to the BLM after fracturing operations have been completed,which would then become publicly available, and includes provisions addressing well-bore integrity and flowback water management plans. Currently, theproposed rule is on hold while the BLM reviews the thousands of public comments that it received on the proposal. However, some industry commentatorshave predicted that similar rules could follow that will impose a national minimum standard on hydraulic fracturing activities. These additional regulatoryburdens could make it more costly or uneconomical for our customers to develop wells, thereby limiting future oil and gas production and reducing futuredemand for our services. In addition, some states and municipalities have adopted, and other states and municipalities are considering adopting, regulationsthat could prohibit hydraulic fracturing in certain areas or impose more stringent disclosure and/or well construction requirements on hydraulic fracturingoperations. For example, Pennsylvania has adopted a variety of regulations since 2010 governing well drilling and hydraulic fracturing completion practices,including the adoption of upgraded well construction and casing standards, upgraded cement standards and new recordkeeping requirements. Additionally, in2012 Pennsylvania enacted legislation that authorizes counties to assess a local impact fee for unconventional gas wells, establishes additional regulatoryrequirements relating to horizontal drilling, and was intended to ensure uniformity between statewide environmental protection standards and municipalordinances (Act 13). The portion of Act 13 that deals with municipal uniformity was challenged and is currently before the Pennsylvania Supreme Courtawaiting a decision. Until a decision is rendered, municipal uniformity remains uncertain. Similarly, in 2011, West Virginia adopted legislation thatestablishes additional regulatory requirements relating to horizontal drilling and hydraulic fracturing. These initiatives could result in additional levels ofregulation and permitting of hydraulic fracturing operations, which could cause our customers to experience operational delays, increased operating andcompliance costs, restrictions or bans on drilling new wells, and additional regulatory burdens that could make it more difficult or commerciallyimpracticable for our customers to perform hydraulic fracturing, delaying the development of unconventional gas resources from shale formations which arenot commercial without the use of hydraulic fracturing and reducing the volume of natural gas transported through our pipelines. The results of our operations are affected by natural gas drilling activity which in turn could be affected by the state tax burdens placed on gasproduction and drilling and completion operations. West Virginia imposes severance tax on oil and gas production. Pennsylvania does not impose a severancetax. In 2012, Pennsylvania enacted legislation authorizing counties to impose an annual impact fee on unconventional gas wells (generally defined as wellsusing hydraulic fracturing or multilateral well bores) for the first 15 years of each well’s life. Total fees per well over the 15-year term range from $190,000 to$355,000, depending on gas prices and subject to consumer price indexing. As Pennsylvania counties assess impact fees, growth in drilling and production inPennsylvania could be reduced. If drilling reductions are significant, our operations could be adversely impacted. 32Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. We are exposed to costs associated with lost and unaccounted for volumes. A certain amount of natural gas is naturally lost in connection with its transportation across a pipeline system, and under our contractualarrangements with our customers we are entitled to retain a specified volume of natural gas in order to compensate us for such lost and unaccounted forvolumes as well as the natural gas used to run our compressor stations, which we refer to as fuel usage. The level of fuel usage and lost and unaccounted forvolumes on our transmission and storage system and our gathering system may exceed the natural gas volumes retained from our customers as compensationfor our fuel usage and lost and unaccounted for volumes pursuant to our contractual agreements and it will be necessary to purchase natural gas in the marketto make up for the difference, which exposes us to commodity price risk. For the years ended December 31, 2012, 2011 and 2010, our actual level of fuelusage and lost and unaccounted for volumes exceeded the amounts recovered from our gathering customers by approximately 1,800 Bbtu, 1,300 Bbtu and1,500 Bbtu, respectively, for which we recognized $4.0 million, $4.9 million and $5.7 million of purchased gas cost as a component of operating andmaintenance expense in 2012, 2011 and 2010, respectively. Future exposure to the volatility of natural gas prices as a result of gas imbalances could have amaterial adverse effect on our business, financial condition, results of operations, liquidity and ability to make quarterly cash distributions to our unitholders. Our exposure to direct commodity price risk may increase in the future. Although we intend to enter into fixed-fee contracts with new customers in the future, our efforts to obtain such contractual terms may not besuccessful. In addition, we may acquire or develop additional midstream assets in the future that do not provide services primarily based on capacityreservation charges or other fixed fee arrangements and therefore have a greater exposure to fluctuations in commodity price risk than our current operations.Future exposure to the volatility of natural gas prices as a result of our future contracts could have a material adverse effect on our business, financialcondition, results of operations, liquidity and ability to make quarterly cash distributions to our unitholders. We do not own all of the land on which our pipelines and facilities are located, which could disrupt our operations. We do not own all of the land on which our pipelines and facilities have been constructed, and we are therefore subject to the possibility of moreonerous terms and/or increased costs to retain necessary land use if we do not have valid rights-of-way, if such rights-of-way lapse or terminate or if ourfacilities are not properly located within the boundaries of such rights-of-way. Although many of these rights are perpetual in nature, we occasionally obtain therights to construct and operate our pipelines on land owned by third parties and governmental agencies for a specific period of time. If we were to beunsuccessful in renegotiating rights-of-way, we might have to relocate our facilities. A loss of rights-of-way or a relocation could have a material adverse effecton our business, financial condition, results of operations, liquidity and on our ability to make distributions to you. Any significant and prolonged change in or stabilization of natural gas prices could have a negative impact on our natural gas storage business. Historically, natural gas prices have been seasonal and volatile, which has enhanced demand for our storage services. The natural gas storagebusiness has benefited from significant price fluctuations resulting from seasonal price sensitivity, which impacts the level of demand for our services and therates we are able to charge for such services. On a system-wide basis, natural gas is typically injected into storage between April and October when natural gasprices are generally lower and withdrawn during the winter months of November through March when natural gas prices are typically higher. However, themarket for natural gas may not continue to experience volatility and seasonal price sensitivity in the future at the levels previously seen. If volatility andseasonality in the natural gas industry decrease, because of increased production capacity or otherwise, the demand for our storage services and the prices thatwe will be able to charge for those services may decline. In addition to volatility and seasonality, an extended period of high natural gas prices would increase the cost of acquiring base gas and likely placeupward pressure on the costs of associated storage expansion activities. For instance, the settlement approved by the FERC in our most recent rate caseincluded a provision allowing us to recover 7.1 Bcf of storage base gas through our transmission fuel retention percentage. If FERC approves Equitrans’Proposed Settlement of current protests associated with the PSC, the transmission fuel retention percentage will be 33Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. reduced from the current retention percentage of 3.72% to 2.72%. The Proposed Settlement also eliminates the tracking mechanism that relates to the recoveryof 7.1 Bcf of storage base gas. To the extent we need to replace storage base gas under the current terms of our most recent rate case, or the terms of theProposed Settlement, we may not be able to recover the cost of acquiring such base gas from our customers and will be subject to commodity price risk. Anextended period of low natural gas prices could adversely impact storage values for some period of time until market conditions adjust. These commodity priceimpacts could have a negative impact on our business, financial condition, results of operations, liquidity and ability to make distributions. Restrictions in our credit facility could adversely affect our business, financial condition, results of operations, liquidity and ability to makequarterly cash distributions to our unitholders. Concurrent with the closing of the IPO, we entered into a $350 million revolving credit facility. Our credit facility contains various covenants andrestrictive provisions that limit our ability to, among other things: · incur or guarantee additional debt;· make distributions on or redeem or repurchase units;· make certain investments and acquisitions;· incur certain liens or permit them to exist;· enter into certain types of transactions with affiliates;· merge or consolidate with another company; and· transfer, sell or otherwise dispose of assets. Our credit facility also contains covenants requiring us to maintain certain financial ratios. Our ability to meet those financial ratios and tests can beaffected by events beyond our control and we cannot assure our unitholders that we will meet those ratios and tests. In addition, our credit facility containsevents of default customary for transactions of this nature, including the occurrence of a change of control (which will occur if EQT fails to own a majority ofthe equity interests of our general partner, we fail to own 100% of Equitrans, L.P., or our general partner fails to be our general partner). The provisions of our credit facility may affect our ability to obtain future financing and pursue attractive business opportunities and our flexibilityin planning for, and reacting to, changes in business conditions. In addition, a failure to comply with the provisions of our credit facility could result in anevent of default, which could enable our lenders to, subject to the terms and conditions of the revolving credit facility, declare any outstanding principal of thatdebt, together with accrued and unpaid interest, to be immediately due and payable. If the payment of our debt is accelerated, our assets may be insufficient torepay such debt in full, and our unitholders could experience a partial or total loss of their investment. The credit facility also has cross default provisions thatapply to any other indebtedness we may have with an aggregate principal amount in excess of $15.0 million. Our future debt levels may limit our flexibility to obtain financing and to pursue other business opportunities. We have the ability to incur debt, subject to limitations in our credit facility. Our level of debt could have important consequences to us, including thefollowing: · our ability to obtain additional financing, if necessary, for working capital, capital expenditures, acquisitions or other purposes may beimpaired or such financing may not be available on favorable terms;· our funds available for operations, future business opportunities and distributions to unitholders will be reduced by that portion of our cashflow required to make interest payments on our debt;· we may be more vulnerable to competitive pressures or a downturn in our business or the economy generally; and· our flexibility in responding to changing business and economic conditions may be limited. Our ability to service our debt will depend upon, among other things, our future financial and operating performance, which will be affected byprevailing economic conditions and financial, business, regulatory and other factors, some of which are beyond our control. If our operating results are notsufficient to service our current or future indebtedness, we will be forced to take actions such as reducing distributions, reducing or delaying our 34Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. business activities, acquisitions, investments or capital expenditures, selling assets or seeking additional equity capital. We may not be able to effect any ofthese actions on satisfactory terms or at all. The credit and risk profile of our general partner and its owner, EQT, could adversely affect our credit ratings and risk profile, which couldincrease our borrowing costs or hinder our ability to raise capital. The credit and business risk profiles of our general partner and EQT may be factors considered in credit evaluations of us. This is because ourgeneral partner, which is owned by EQT, controls our business activities, including our cash distribution policy and growth strategy. Any adverse change inthe financial condition of EQT, including the degree of its financial leverage and its dependence on cash flow from us to service its indebtedness, or adowngrade of EQT’s investment grade credit rating, may adversely affect our credit ratings and risk profile. If we were to seek a credit rating in the future, our credit rating may be adversely affected by the leverage of our general partner or EQT, as creditrating agencies such as Standard & Poor’s Ratings Services and Moody’s Investors Service may consider the leverage and credit profile of EQT and itsaffiliates because of their ownership interest in and control of us. Any adverse effect on our credit rating would increase our cost of borrowing or hinder ourability to raise financing in the capital markets, which would impair our ability to grow our business and make distributions to our unitholders. Increases in interest rates could adversely impact demand for our storage capacity, our unit price, our ability to issue equity or incur debt foracquisitions or other purposes and our ability to make cash distributions at our intended levels. There is a financing cost for our customers to store natural gas in our storage facilities. That financing cost is impacted by the cost of capital orinterest rates incurred by the customer in addition to the commodity cost of the natural gas in inventory. Absent other factors, a higher financing cost adverselyimpacts the economics of storing natural gas for future sale. As a result, a significant increase in interest rates could adversely affect the demand for ourstorage capacity independent of other market factors. In addition, interest rates on future credit facilities and debt offerings could be higher than current levels, causing our financing costs to increaseaccordingly. As with other yield-oriented securities, our unit price is impacted by our level of our cash distributions and implied distribution yield. Thedistribution yield is often used by investors to compare and rank yield-oriented securities for investment decision-making purposes. Therefore, changes ininterest rates, either positive or negative, may affect the yield requirements of investors who invest in our units, and a rising interest rate environment couldhave an adverse impact on our unit price, our ability to issue equity or incur debt for acquisitions or other purposes and our ability to make cash distributionsat our intended levels. The amount of cash we have available for distribution to unitholders depends primarily on our cash flow rather than on our profitability, whichmay prevent us from making distributions, even during periods in which we record net income. The amount of cash we have available for distribution depends primarily upon our cash flow and not solely on profitability, which will be affectedby non-cash items. As a result, we may make cash distributions during periods when we record losses for financial accounting purposes and may not makecash distributions during periods when we record net earnings for financial accounting purposes. The lack of diversification of our assets and geographic locations could adversely affect our ability to make distributions to our unitholders. We rely exclusively on revenues generated from transmission, storage and gathering systems, which are exclusively located in the Appalachian Basinin Pennsylvania and West Virginia. Due to our lack of diversification in assets and geographic location, an adverse development in these businesses or ourareas of operations, including adverse developments due to catastrophic events, weather, regulatory action and decreases in demand for natural gas, couldhave a significantly greater impact on our results of operations and distributable cash flow to our unitholders than if we maintained more diverse assets andlocations. 35Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. If we fail to maintain an effective system of internal controls, we may not be able to report our financial results accurately or prevent fraud,which would likely have a negative impact on the market price of our common units. Prior to the IPO in July 2012, we were not required to file reports with the SEC. Upon the completion of the IPO, we became subject to the publicreporting requirements of the Securities Exchange Act of 1934, as amended, or the Exchange Act. We prepare our consolidated financial statements inaccordance with GAAP, but prior to the IPO our internal accounting controls were not required to meet all standards applicable to companies with publiclytraded securities. Effective internal controls are necessary for us to provide reliable financial reports, prevent fraud and to operate successfully as a publiclytraded partnership. Our efforts to develop and maintain our internal controls may not be successful, and we may be unable to maintain effective controls overour financial processes and reporting in the future or to comply with our obligations under Section 404 of the Sarbanes-Oxley Act of 2002, which we refer to asSection 404. For example, Section 404 will require us, among other things, to annually review and report on, and our independent registered public accountingfirm to attest to, the effectiveness of our internal controls over financial reporting. We must comply with Section 404 (except for the requirement for an auditor’sattestation report, as described below) beginning with for our fiscal year ending December 31, 2013. Any failure to develop, implement or maintain effectiveinternal controls or to improve our internal controls could harm our operating results or cause us to fail to meet our reporting obligations. Given the difficultiesinherent in the design and operation of internal controls over financial reporting, we can provide no assurance as to our, or our independent registered publicaccounting firm’s conclusions about the effectiveness of our internal controls, and we may incur significant costs in our efforts to comply with Section 404.Ineffective internal controls will subject us to regulatory scrutiny and a loss of confidence in our reported financial information, which could have an adverseeffect on our business and would likely have a negative effect on the trading price of our common units. For as long as we are an emerging growth company, we will not be required to comply with certain disclosure requirements that apply to otherpublic companies. In April 2012, President Obama signed into law the Jumpstart Our Business Startups Act, or the JOBS Act. For as long as we remain an “emerginggrowth company” as defined in the JOBS Act, we may take advantage of certain exemptions from various reporting requirements that are applicable to otherpublic companies that are not emerging growth companies, including not being required to provide an auditor’s attestation report on management’s assessmentof the effectiveness of our system of internal control over financial reporting pursuant to Section 404 of the Sarbanes-Oxley Act and reduced disclosureobligations regarding executive compensation in our periodic reports. We will remain an emerging growth company for up to five years, although we will losethat status sooner if we have more than $1.0 billion of revenues in a fiscal year, have more than $700 million in market value of our limited partner interestsheld by non-affiliates, or issue more than $1.0 billion of non-convertible debt over a three-year period. In addition, the JOBS Act provides that an emerging growth company can delay adopting new or revised accounting standards until such time asthose standards apply to private companies. We have irrevocably elected to “opt out” of this exemption and, therefore, will be subject to the same new orrevised accounting standards as other public companies that are not emerging growth companies. To the extent that we rely on any of the exemptions available to emerging growth companies, our unitholders will receive less information about ourexecutive compensation and internal control over financial reporting than issuers that are not emerging growth companies. If some investors find our commonunits to be less attractive as a result, there may be a less active trading market for our common units and our trading price may be more volatile. Terrorist attacks aimed at our facilities or surrounding areas could adversely affect our business. The U.S. government has issued warnings that energy assets, specifically the nation’s pipeline and terminal infrastructure, may be the future targetsof terrorist organizations. Any terrorist attack at our facilities, those of our customers and, in some cases, those of other pipelines, refineries or terminals couldmaterially and adversely affect our business, financial condition, results of operations, liquidity or ability to make distributions. 36Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Risks Inherent in an Investment in Us Our general partner and its affiliates, including EQT, have conflicts of interest with us and limited duties to us and our unitholders, and theymay favor their own interests to the detriment of us and our other common unitholders. EQT indirectly owns and controls our general partner and appointed all of the officers and directors of our general partner. All of our initial officersand a majority of our initial directors are also officers and/or directors of EQT. Although our general partner has a duty to manage us in a manner that isbeneficial to us and our unitholders, the directors and officers of our general partner have a fiduciary duty to manage our general partner in a manner that isbeneficial to EQT. Conflicts of interest will arise between EQT and our general partner, on the one hand, and us and our unitholders, on the other hand. Inresolving these conflicts of interest, our general partner may favor its own interests and the interests of EQT over our interests and the interests of ourunitholders. These conflicts include the following situations, among others: · Neither our partnership agreement nor any other agreement requires EQT to pursue a business strategy that favors us, and the directors andofficers of EQT have a fiduciary duty to make these decisions in the best interests of EQT, which may be contrary to our interests. EQT maychoose to shift the focus of its investment and growth to areas not served by our assets.· EQT, as our primary customer, has an economic incentive to cause us not to seek higher tariff rates or gathering fees, even if such higher ratesor fees would reflect rates and fees that could be obtained in arm’s-length, third party transaction.· EQT is not limited in its ability to compete with us and may offer business opportunities or sell midstream assets to third parties without firstoffering us the right to bid for them.· Our general partner is allowed to take into account the interests of parties other than us, such as EQT, in resolving conflicts of interest.· All of the officers and a majority of the directors of our general partner are also officers and/or directors of EQT and owe fiduciary duties toEQT. The officers of our general partner also devote significant time to the business of EQT and are compensated by EQT accordingly.· Our partnership agreement replaces the fiduciary duties that would otherwise be owed by our general partner with contractual standardsgoverning its duties, limits our general partner’s liabilities and restricts the remedies available to our unitholders for actions that, without suchlimitations, might constitute breaches of fiduciary duty.· Except in limited circumstances, our general partner has the power and authority to conduct our business without unitholder approval.· Disputes may arise under our commercial agreements with EQT and its affiliates.· Our general partner determines the amount and timing of asset purchases and sales, borrowings, issuance of additional partnership securitiesand the creation, reduction or increase of reserves, each of which can affect the amount of distributable cash flow.· Our general partner determines the amount and timing of any capital expenditures and whether a capital expenditure is classified as amaintenance capital expenditure, which reduces operating surplus, or an expansion or investment capital expenditure, which does not reduceoperating surplus. This determination can affect the amount of cash that is distributed to our unitholders and the ability of the subordinatedunits to convert to common units.· Our general partner determines which costs incurred by it are reimbursable by us.· Our general partner may cause us to borrow funds in order to permit the payment of cash distributions, even if the purpose or effect of theborrowing is to make a distribution on the subordinated units, to make incentive distributions or to accelerate the expiration of the subordinationperiod.· Our partnership agreement permits us to classify up to $30 million as operating surplus, even if it is generated from asset sales, non-workingcapital borrowings or other sources that would otherwise constitute capital surplus. This cash may be used to fund distributions on oursubordinated or general partner units or to our general partner in respect of the incentive distribution rights.· Our partnership agreement does not restrict our general partner from causing us to pay it or its affiliates for any services rendered to us orentering into additional contractual arrangements with any of these entities on our behalf.· Our general partner intends to limit its liability regarding our contractual and other obligations. 37Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. · Our general partner may exercise its right to call and purchase all of the common units not owned by it and its affiliates if they own more than80% of the common units.· Our general partner controls the enforcement of the obligations that it and its affiliates owe to us, including EQT’s obligations under theomnibus agreement and its commercial agreements with us.· Our general partner decides whether to retain separate counsel, accountants or others to perform services for us.· Our general partner may transfer its incentive distribution rights without unitholder approval.· Our general partner may elect to cause us to issue common units to it in connection with a resetting of the target distribution levels related to ourgeneral partner’s incentive distribution rights without the approval of the conflicts committee of the board of directors of our general partner orour unitholders. This election may result in lower distributions to our common unitholders in certain situations. EQT and other affiliates of our general partner are not restricted in their ability to compete with us. Our partnership agreement provides that our general partner will be restricted from engaging in any business activities other than acting as our generalpartner and those activities incidental to its ownership of interests in us. Affiliates of our general partner, including EQT and its other subsidiaries, are notprohibited from owning assets or engaging in businesses that compete directly or indirectly with us. EQT currently holds interests in, and may makeinvestments in and purchases of, entities that acquire, own and operate other natural gas midstream assets. EQT will be under no obligation to make anyacquisition opportunities available to us. Moreover, while EQT may offer us the opportunity to buy additional assets from it, it is under no contractualobligation to accept any offer we might make with respect to such opportunity. Pursuant to the terms of our partnership agreement, the doctrine of corporate opportunity, or any analogous doctrine, does not apply to our generalpartner or any of its affiliates, including its executive officers and directors and EQT. Any such person or entity that becomes aware of a potential transaction,agreement, arrangement or other matter that may be an opportunity for us will not have any duty to communicate or offer such opportunity to us. Any suchperson or entity will not be liable to us or to any limited partner for breach of any fiduciary duty or other duty by reason of the fact that such person or entitypursues or acquires such opportunity for itself, directs such opportunity to another person or entity or does not communicate such opportunity or informationto us. This may create actual and potential conflicts of interest between us and affiliates of our general partner and result in less than favorable treatment of usand our common unitholders. Our partnership agreement requires that we distribute all of our available cash, which could limit our ability to grow and make acquisitions. We expect that we will distribute all of our available cash to our unitholders and will rely primarily upon external financing sources, includingcommercial bank borrowings and the issuance of debt and equity securities, to fund our acquisitions and expansion capital expenditures. As a result, to theextent we are unable to finance growth externally, our cash distribution policy will significantly impair our ability to grow. In addition, because we intend to distribute all of our available cash, our growth may not be as fast as that of businesses that reinvest their availablecash to expand ongoing operations. To the extent we issue additional units in connection with any acquisitions or expansion capital expenditures, the paymentof distributions on those additional units may increase the risk that we will be unable to maintain or increase our per unit distribution level. There are nolimitations in our partnership agreement, and we do not anticipate there being limitations in our credit facility, on our ability to issue additional units,including units ranking senior to the common units. The incurrence of additional commercial borrowings or other debt to finance our growth strategy wouldresult in increased interest expense, which in turn may impact the available cash that we have to distribute to our unitholders. The NYSE does not require a publicly traded partnership like us to comply with certain of its corporate governance requirements. Unlike most corporations, we are not required by NYSE rules to have, and we do not intend to have, a majority of independent directors on ourgeneral partner’s board of directors or a compensation committee or a nominating and corporate governance committee. Additionally, any future issuance ofadditional common units or other securities, including to affiliates, will not be subject to the NYSE’s shareholder approval rules. Accordingly, 38Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. unitholders will not have the same protections afforded to certain corporations that are subject to all of the NYSE corporate governance requirements. If any of our unitholders are not eligible taxable holders, such unitholders will not be entitled to allocations of income or loss or distributions orvoting rights on their common units and their common units will be subject to redemption. In order to avoid any material adverse effect on the maximum applicable rates that can be charged to customers by our subsidiaries on assets that aresubject to rate regulation by FERC or analogous regulatory body, we have adopted certain requirements regarding those investors who may own our commonunits. Eligible holders are individuals or entities subject to United States federal income taxation on the income generated by us or entities not subject to UnitedStates federal income taxation on the income generated by us, so long as all of the entity’s owners are subject to such taxation. If any of our unitholders are notpersons who fit the requirements to be eligible taxable holders, such unitholders will not receive allocations of income or loss or distributions or voting rightson their units and they run the risk of having their units redeemed by us at the market price calculated in accordance with our partnership agreement as of thedate of redemption. The redemption price will be paid in cash or by delivery of a promissory note, as determined by our general partner. Our partnership agreement replaces our general partner’s fiduciary duties to holders of our common units with contractual standards governingits duties. Our partnership agreement contains provisions that eliminate the fiduciary standards to which our general partner would otherwise be held by statefiduciary duty law and replace those duties with several different contractual standards. For example, our partnership agreement permits our general partner tomake a number of decisions in its individual capacity, as opposed to in its capacity as our general partner, free of any duties to us and our unitholders otherthan the implied contractual covenant of good faith and fair dealing, which means that a court will enforce the reasonable expectations of the partners where thelanguage in the partnership agreement does not provide for a clear course of action. This provision entitles our general partner to consider only the interests andfactors that it desires and relieves it of any duty or obligation to give any consideration to any interest of, or factors affecting, us, our affiliates or our limitedpartners. Examples of decisions that our general partner may make in its individual capacity include: · how to allocate corporate opportunities among us and its affiliates;· whether to exercise its limited call right;· whether to seek approval of the resolution of a conflict of interest by the conflicts committee of the board of directors of our general partner;· how to exercise its voting rights with respect to the units it owns;· whether to elect to reset target distribution levels;· whether to transfer the incentive distribution rights or any units it owns to a third party; and· whether or not to consent to any merger, consolidation or conversion of the partnership or amendment to the partnership agreement. By purchasing a common unit, a common unitholder agrees to become bound by the provisions in the partnership agreement, including theprovisions discussed above. Our partnership agreement restricts the remedies available to holders of our common units for actions taken by our general partner that mightotherwise constitute breaches of fiduciary duty. Our partnership agreement contains provisions that restrict the remedies available to unitholders for actions taken by our general partner that mightotherwise constitute breaches of fiduciary duty under state fiduciary duty law. For example, our partnership agreement provides that: · whenever our general partner, the board of directors of our general partner or any committee thereof (including the conflicts committee) makes adetermination or takes, or declines to take, any other action in their respective capacities, our general partner, the board of directors of ourgeneral partner and any committee thereof (including the conflicts committee), as applicable, is required to make such determination, or take ordecline to take such other action, in good faith, meaning that it subjectively believed that the decision was in the best interests of our partnership,and, except as specifically 39Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. provided by our partnership agreement, will not be subject to any other or different standard imposed by our partnership agreement, Delawarelaw, or any other law, rule or regulation, or at equity;· our general partner will not have any liability to us or our unitholders for decisions made in its capacity as a general partner so long as suchdecisions are made in good faith;· our general partner and its officers and directors will not be liable for monetary damages to us or our limited partners resulting from any act oromission unless there has been a final and non-appealable judgment entered by a court of competent jurisdiction determining that our generalpartner or its officers and directors, as the case may be, acted in bad faith or engaged in fraud or willful misconduct or, in the case of a criminalmatter, acted with knowledge that the conduct was criminal; and· our general partner will not be in breach of its obligations under the partnership agreement (including any duties to us or our unitholders) if atransaction with an affiliate or the resolution of a conflict of interest is: – approved by the conflicts committee of the board of directors of our general partner, although our general partner is not obligated toseek such approval;– approved by the vote of a majority of the outstanding common units, excluding any common units owned by our general partner andits affiliates;– determined by the board of directors of our general partner to be on terms no less favorable to us than those generally being provided toor available from unrelated third parties; or– determined by the board of directors of our general partner to be fair and reasonable to us, taking into account the totality of therelationships among the parties involved, including other transactions that may be particularly favorable or advantageous to us. In connection with a situation involving a transaction with an affiliate or a conflict of interest, any determination by our general partner or theconflicts committee must be made in good faith. If an affiliate transaction or the resolution of a conflict of interest is not approved by our common unitholdersor the conflicts committee and the board of directors of our general partner determines that the resolution or course of action taken with respect to the affiliatetransaction or conflict of interest satisfies either of the standards set forth in the third and fourth bullets above, then it will be presumed that, in making itsdecision, the board of directors acted in good faith, and in any proceeding brought by or on behalf of any limited partner or the partnership challenging suchdetermination, the person bringing or prosecuting such proceeding will have the burden of overcoming such presumption. Reimbursements due to our general partner and its affiliates for services provided to us or on our behalf will reduce distributable cash flow toour common unitholders. The amount and timing of such reimbursements will be determined by our general partner. Prior to making any distribution on our common units, we will reimburse our general partner and its affiliates, including EQT, for expenses theyincur and payments they make on our behalf. Under the omnibus agreement, we will reimburse our general partner and its affiliates for certain expensesincurred on our behalf, including administrative costs, such as compensation expense for those persons who provide services necessary to run our business,and insurance expenses. Our partnership agreement provides that our general partner will determine in good faith the expenses that are allocable to us. Thereimbursement of expenses and payment of fees, if any, to our general partner and its affiliates will reduce the amount of available cash to pay cashdistributions to our common unitholders. Holders of our common units have limited voting rights and are not entitled to elect our general partner or its directors. Unlike the holders of common stock in a corporation, unitholders have only limited voting rights on matters affecting our business and, therefore,limited ability to influence management’s decisions regarding our business. Unitholders will have no right on an annual or ongoing basis to elect our generalpartner or its board of directors. Rather, the board of directors of our general partner will be appointed by EQT. Furthermore, if the unitholders are dissatisfiedwith the performance of our general partner, they will have little ability to remove our general partner. As a result of these limitations, the price at which thecommon units will trade could be diminished because of the absence or reduction of a takeover premium in the trading price. Our partnership agreement alsocontains provisions limiting the ability of unitholders to call meetings or to acquire information about our operations, as well as other provisions limiting theunitholders’ ability to influence the manner or direction of management. 40Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Even if holders of our common units are dissatisfied, they cannot initially remove our general partner without its consent. Unitholders initially will be unable to remove our general partner without its consent because our general partner and its affiliates, including EQT,owns sufficient units to be able to prevent its removal. The vote of the holders of at least 66/3% of all outstanding common and subordinated units votingtogether as a single class is required to remove our general partner. EQT indirectly owns 58.5% of our outstanding common and subordinated units. Also, ifour general partner is removed without cause during the subordination period and units held by our general partner and its affiliates are not voted in favor ofthat removal, all remaining subordinated units will automatically convert into common units and any existing arrearages on our common units will beextinguished. A removal of our general partner under these circumstances would adversely affect our common units by prematurely eliminating theirdistribution and liquidation preference over our subordinated units, which would otherwise have continued until we had met certain distribution andperformance tests. Cause is narrowly defined to mean that a court of competent jurisdiction has entered a final, non-appealable judgment finding our generalpartner liable for actual fraud or willful misconduct in its capacity as our general partner. Cause does not include most cases of charges of poor management ofthe business, so the removal of our general partner because of unitholder dissatisfaction with the performance of our general partner in managing ourpartnership will most likely result in the termination of the subordination period and conversion of all subordinated units to common units. Our partnership agreement restricts the voting rights of unitholders owning 20% or more of our common units. Unitholders’ voting rights are further restricted by a provision of our partnership agreement providing that any units held by a person that owns 20%or more of any class of units then outstanding, other than our general partner, its affiliates, their transferees and persons who acquired such units with theprior approval of the board of directors of our general partner, cannot vote on any matter. Our general partner interest or the control of our general partner may be transferred to a third party without unitholder consent. Our general partner may transfer its general partner interest to a third party in a merger or in a sale of all or substantially all of its assets without theconsent of the unitholders. Furthermore, our partnership agreement does not restrict the ability of EQT to transfer all or a portion of its ownership interest inour general partner to a third party. The new owner of our general partner would then be in a position to replace the board of directors and officers of ourgeneral partner with its own designees and thereby exert significant control over the decisions made by the board of directors and officers. The incentive distribution rights of our general partner may be transferred to a third party without unitholder consent. Our general partner may transfer its incentive distribution rights to a third party at any time without the consent of our unitholders. If our generalpartner transfers its incentive distribution rights to a third party but retains its general partner interest, our general partner may not have the same incentive togrow our partnership and increase quarterly distributions to unitholders over time as it would if it had retained ownership of its incentive distribution rights.For example, a transfer of incentive distribution rights by our general partner could reduce the likelihood of EQT selling or contributing additional midstreamassets to us, as EQT would have less of an economic incentive to grow our business, which in turn would impact our ability to grow our asset base. We may issue additional units without unitholder approval, which would dilute our unitholders’ existing ownership interests. Our partnership agreement does not limit the number of additional limited partner interests, including limited partner interests that rank senior to thecommon units, that we may issue at any time without the approval of our unitholders. The issuance by us of additional common units or other equitysecurities of equal or senior rank will have the following effects: · our existing unitholders’ proportionate ownership interest in us will decrease;· the amount of distributable cash flow on each unit may decrease; 412Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. · because a lower percentage of total outstanding units will be subordinated units, the risk that a shortfall in the payment of the minimumquarterly distribution will be borne by our common unitholders will increase;· because the amount payable to holders of incentive distribution rights is based on a percentage of the total distributable cash flow, thedistributions to holders of incentive distribution rights will increase even if the per unit distribution on common units remains the same;· the ratio of taxable income to distributions may increase;· the relative voting strength of each previously outstanding unit may be diminished; and· the market price of the common units may decline. EQT may sell units in the public or private markets, and such sales could have an adverse impact on the trading price of the common units. EQT indirectly holds an aggregate of 2,964,718 common units and 17,339,718 subordinated units. All of the subordinated units will convert intocommon units at the end of the subordination period and may convert earlier under certain circumstances. In addition, we have agreed to provide EQT withcertain registration rights. The sale of these units in the public or private markets could have an adverse impact on the price of the common units or on anytrading market that may develop. Our general partner intends to limit its liability regarding our obligations. Our general partner intends to limit its liability under contractual arrangements so that the counterparties to such arrangements have recourse onlyagainst our assets, and not against our general partner or its assets. Our general partner may therefore cause us to incur indebtedness or other obligations thatare nonrecourse to our general partner. Our partnership agreement permits our general partner to limit its liability, even if we could have obtained morefavorable terms without the limitation on liability. In addition, we are obligated to reimburse or indemnify our general partner to the extent that it incursobligations on our behalf. Any such reimbursement or indemnification payments would reduce the amount of cash otherwise available for distribution to ourunitholders. Our general partner has a limited call right that may require our unitholders to sell their units at an undesirable time or price. If at any time our general partner and its affiliates own more than 80% of the common units, our general partner will have the right, which it mayassign to any of its affiliates or to us, but not the obligation, to acquire all, but not less than all, of the common units held by unaffiliated persons at a pricethat is not less than their then-current market price, as calculated pursuant to the terms of our partnership agreement. As a result, our unitholders may berequired to sell their common units at an undesirable time or price and may not receive any return on their investment. Our unitholders may also incur a taxliability upon a sale of their units. EQT indirectly owns approximately 17.1% of our outstanding common units. At the end of the subordination period,assuming no additional issuances of common units (other than upon the conversion of the subordinated units), EQT will indirectly own approximately58.5% of our outstanding common units. Our general partner, or any transferee holding a majority of the incentive distribution rights, may elect to cause us to issue common units to it inconnection with a resetting of the minimum quarterly distribution and the target distribution levels related to the incentive distribution rights,without the approval of the conflicts committee of our general partner or our unitholders. This election may result in lower distributions to ourcommon unitholders in certain situations. The holder or holders of a majority of the incentive distribution rights, which is initially our general partner, have the right, at any time when thereare no subordinated units outstanding and the holders have received incentive distributions at the highest level to which they are entitled (48.0%) for each of theprior four consecutive fiscal quarters (and the amount of each such distribution did not exceed adjusted operating surplus for each such quarter), to reset theminimum quarterly distribution and the initial target distribution levels at higher levels based on our cash distribution at the time of the exercise of the resetelection. Following a reset election, the minimum quarterly distribution will be reset to an amount equal to the average cash distribution per unit for the twofiscal quarters immediately preceding the reset election (such amount is referred to as the “reset minimum quarterly distribution”), and the target distributionlevels will be reset to correspondingly higher levels based on percentage 42Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. increases above the reset minimum quarterly distribution. Our general partner has the right to transfer the incentive distribution rights at any time, in whole orin part, and any transferee holding a majority of the incentive distribution rights shall have the same rights as our general partner with respect to resetting targetdistributions. In the event of a reset of the minimum quarterly distribution and the target distribution levels, the holders of the incentive distribution rights will beentitled to receive, in the aggregate, the number of common units equal to that number of common units which would have entitled the holders to an averageaggregate quarterly cash distribution in the prior two quarters equal to the average of the distributions on the incentive distribution rights in the prior twoquarters. Our general partner will also be issued the number of general partner units necessary to maintain its general partner interest in us that existedimmediately prior to the reset election. We anticipate that our general partner would exercise this reset right in order to facilitate acquisitions or internal growthprojects that would not otherwise be sufficiently accretive to cash distributions per common unit. It is possible, however, that our general partner or atransferee could exercise this reset election at a time when it is experiencing, or expects to experience, declines in the cash distributions it receives related to itsincentive distribution rights and may therefore desire to be issued common units rather than retain the right to receive incentive distribution payments based ontarget distribution levels that are less certain to be achieved in the then current business environment. This risk could be elevated if our incentive distributionrights have been transferred to a third party. As a result, a reset election may cause our common unitholders to experience dilution in the amount of cashdistributions that they would have otherwise received had we not issued common units to our general partner in connection with resetting the target distributionlevels. Our unitholders’ liability may not be limited if a court finds that unitholder action constitutes control of our business. A general partner of a partnership generally has unlimited liability for the obligations of the partnership, except for those contractual obligations of thepartnership that are expressly made without recourse to the general partner. Our partnership is organized under Delaware law, and we conduct business in anumber of other states. The limitations on the liability of holders of limited partner interests for the obligations of a limited partnership have not been clearlyestablished in some of the other states in which we do business. Our unitholders could be liable for any and all of our obligations as if our unitholders were ageneral partner if a court or government agency were to determine that: · we were conducting business in a state but had not complied with that particular state’s partnership statute; or· our unitholders right to act with other unitholders to remove or replace our general partner, to approve some amendments to our partnershipagreement or to take other actions under our partnership agreement constitute “control” of our business. Unitholders may have liability to repay distributions that were wrongfully distributed to them. Under certain circumstances, unitholders may have to repay amounts wrongfully returned or distributed to them. Under Section 17-607 of theDelaware Revised Uniform Limited Partnership Act, we may not make a distribution to our unitholders if the distribution would cause our liabilities to exceedthe fair value of our assets. Delaware law provides that for a period of three years from the date of an impermissible distribution, limited partners who receivedthe distribution and who knew at the time of the distribution that it violated Delaware law will be liable to the limited partnership for the distribution amount.Transferees of common units are liable both for the obligations of the transferor to make contributions to the partnership that were known to the transferee atthe time of transfer and for those obligations that were unknown if the liabilities could have been determined from the partnership agreement. Neither liabilitiesto partners on account of their partnership interest nor liabilities that are non-recourse to the partnership are counted for purposes of determining whether adistribution is permitted. We incur increased costs as a result of being a publicly traded partnership. We had no history operating as a publicly traded partnership prior to the IPO. As a publicly traded partnership, we incur significant legal,accounting and other expenses. 43Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Tax Risks to Common Unitholders Our tax treatment depends on our status as a partnership for federal income tax purposes. If the IRS were to treat us as a corporation forfederal income tax purposes, which would subject us to entity-level taxation, then our distributable cash flow to our unitholders would besubstantially reduced. The anticipated after-tax economic benefit of an investment in the common units depends largely on our being treated as a partnership for federalincome tax purposes. We have not requested, and do not plan to request, a ruling from the IRS regarding our qualification as a partnership for tax purposes. Despite the fact that we are a limited partnership under Delaware law, it is possible in certain circumstances for a partnership such as ours to betreated as a corporation for federal income tax purposes. A change in our business or a change in current law could cause us to be treated as a corporation forfederal income tax purposes or otherwise subject us to taxation as an entity. If we were treated as a corporation for federal income tax purposes, we would pay federal income tax on our taxable income at the corporate tax rate,which is currently a maximum of 35.0%, and would likely pay state and local income tax at varying rates. Distributions would generally be taxed again ascorporate dividends (to the extent of our current and accumulated earnings and profits), and no income, gains, losses, deductions, or credits would flowthrough to you. Because a tax would be imposed upon us as a corporation, our distributable cash flow to our unitholders would be substantially reduced.Therefore, if we were treated as a corporation for federal income tax purposes there would be a material reduction in the anticipated cash flow and after-taxreturn to our unitholders, likely causing a substantial reduction in the value of our common units. Our partnership agreement provides that, if a law is enacted or existing law is modified or interpreted in a manner that subjects us to taxation as acorporation or otherwise subjects us to entity-level taxation for federal, state or local income tax purposes, the minimum quarterly distribution amount and thetarget distribution amounts may be adjusted to reflect the impact of that law on us. If we were subjected to a material amount of additional entity-level taxation by individual states, it would reduce our distributable cash flow toour unitholders. Changes in current state law may subject us to additional entity-level taxation by individual states. Because of widespread state budget deficits andother reasons, several states are evaluating ways to subject partnerships to entity-level taxation through the imposition of state income, franchise and otherforms of taxation. Imposition of such additional tax on us by a state would reduce the distributable cash flow to our unitholders. Our partnership agreementprovides that, if a law is enacted or existing law is modified or interpreted in a manner that subjects us to entity-level taxation, the minimum quarterlydistribution amount and the target distribution amounts may be adjusted to reflect the impact of that law on us. The tax treatment of publicly traded partnerships or an investment in our common units could be subject to potential legislative, judicial oradministrative changes and differing interpretations, possibly on a retroactive basis. The present federal income tax treatment of publicly traded partnerships, including us, or an investment in our common units may be modified byadministrative, legislative or judicial interpretation at any time. For example, from time to time, members of the U.S. Congress propose and considersubstantive changes to the existing federal income tax laws that affect publicly traded partnerships. Currently, one such legislative proposal would eliminatethe qualifying income exception upon which we rely for our treatment as a partnership for U.S. federal income tax purposes. We are unable to predict whetherany of these changes or any other proposals will ultimately be enacted, but it is possible that a change in law could affect us and may, if enacted, be appliedretroactively. Any such changes could negatively impact the value of an investment in our common units. Our unitholders’ share of our income will be taxable to them for U.S. federal income tax purposes even if they do not receive any cashdistributions from us. 44Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Because a unitholder will be treated as a partner to whom we will allocate taxable income which could be different in amount than the cash wedistribute, a unitholder’s allocable share of our taxable income will be taxable to it, which may require the payment of federal income taxes and, in some cases,state and local income taxes on its share of our taxable income even if it receives no cash distributions from us. Our unitholders may not receive cashdistributions from us equal to their share of our taxable income or even equal to the actual tax liability that results from that income. If the IRS contests the federal income tax positions we take, the market for our common units may be adversely impacted and the cost of any IRScontest will reduce our distributable cash flow to our unitholders. We have not requested a ruling from the IRS with respect to our treatment as a partnership for federal income tax purposes. The IRS may adoptpositions that differ from the conclusions of our counsel expressed in prospectus or from the positions we take, and the IRS’s positions may ultimately besustained. It may be necessary to resort to administrative or court proceedings to sustain some or all of our counsel’s conclusions or the positions we take andsuch positions may not ultimately be sustained. A court may not agree with some or all of our counsel’s conclusions or the positions we take. Any contest withthe IRS, and the outcome of any IRS contest, may have a materially adverse impact on the market for our common units and the price at which they trade. Inaddition, our costs of any contest with the IRS will be borne indirectly by our unitholders and our general partner because the costs will reduce ourdistributable cash flow. Tax gain or loss on the disposition of our common units could be more or less than expected. If our unitholders sell their common units, our unitholders will recognize a gain or loss for federal income tax purposes equal to the difference betweenthe amount realized and their tax basis in those common units. Because distributions in excess of our unitholders allocable share of our net taxable incomedecrease their tax basis in their common units, the amount, if any, of such prior excess distributions with respect to the common units our unitholders sellwill, in effect, become taxable income to our unitholders if they sell such common units at a price greater than their tax basis in those common units, even ifthe price our unitholders receive is less than their original cost. Furthermore, a substantial portion of the amount realized on any sale or other disposition of ourunitholders common units, whether or not representing gain, may be taxed as ordinary income due to potential recapture items, including depreciationrecapture. In addition, because the amount realized includes a unitholder’s share of our nonrecourse liabilities, if our unitholders sell their common units, ourunitholders may incur a tax liability in excess of the amount of cash they receive from the sale. Tax-exempt entities and non-U.S. persons face unique tax issues from owning our common units that may result in adverse tax consequences tothem. Investment in common units by tax-exempt entities, such as employee benefit plans and individual retirement accounts (known as IRAs), and non-U.S. persons raises issues unique to them. For example, virtually all of our income allocated to organizations that are exempt from federal income tax,including IRAs and other retirement plans, will be unrelated business taxable income and will be taxable to them. Distributions to non-U.S. persons will bereduced by withholding taxes at the highest applicable effective tax rate, and non-U.S. persons will be required to file U.S. federal income tax returns and paytax on their share of our taxable income. If our unitholders are a tax-exempt entity or a non-U.S. person, our unitholders should consult a tax advisor beforeinvesting in our common units. We will treat each purchaser of common units as having the same tax benefits without regard to the actual common units purchased. The IRSmay challenge this treatment, which could adversely affect the value of the common units. Because we cannot match transferors and transferees of common units and because of other reasons, we will adopt depreciation and amortizationpositions that may not conform to all aspects of existing Treasury Regulations. A successful IRS challenge to those positions could adversely affect the amountof tax benefits available to you. Our counsel is unable to opine as to the validity of such filing positions. It also could affect the timing of these tax benefits orthe amount of gain from our unitholders sale of common units and could have a negative impact on the value of our common units or result in auditadjustments to our unitholders tax returns. 45Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. We prorate our items of income, gain, loss and deduction for U.S. federal income tax purposes between transferors and transferees of our unitseach month based upon the ownership of our units on the first day of each month, instead of on the basis of the date a particular unit istransferred. The IRS may challenge this treatment, which could change the allocation of items of income, gain, loss and deduction among ourunitholders. We will prorate our items of income, gain, loss and deduction for U.S. federal income tax purposes between transferors and transferees of our unitseach month based upon the ownership of our units on the first day of each month, instead of on the basis of the date a particular unit is transferred. The useof this proration method may not be permitted under existing Treasury Regulations. Recently, however, the U.S. Treasury Department issued proposedTreasury Regulations that provide a safe harbor pursuant to which publicly traded partnerships may use a similar monthly simplifying convention to allocatetax items among transferor and transferee unitholders. Nonetheless, the proposed regulations do not specifically authorize the use of the proration method wehave adopted. If the IRS were to challenge this method or new Treasury regulations were issued, we may be required to change the allocation of items ofincome, gain, loss and deduction among our unitholders. Our counsel has not rendered an opinion with respect to whether our monthly convention forallocating taxable income and losses is permitted by existing Treasury Regulations. A unitholder whose common units are loaned to a “short seller” to cover a short sale of common units may be considered as having disposed ofthose common units. If so, he would no longer be treated for federal income tax purposes as a partner with respect to those common units duringthe period of the loan and may recognize gain or loss from the disposition. Because a unitholder whose common units are loaned to a “short seller” to cover a short sale of common units may be considered as having disposedof the loaned common units, he may no longer be treated for federal income tax purposes as a partner with respect to those common units during the period ofthe loan to the short seller and the unitholder may recognize gain or loss from such disposition. Moreover, during the period of the loan to the short seller, anyof our income, gain, loss or deduction with respect to those common units may not be reportable by the unitholder and any cash distributions received by theunitholder as to those common units could be fully taxable as ordinary income. Our counsel has not rendered an opinion regarding the treatment of a unitholderwhere common units are loaned to a short seller to cover a short sale of common units; therefore, our unitholders desiring to assure their status as partners andavoid the risk of gain recognition from a loan to a short seller are urged to consult a tax advisor to discuss whether it is advisable to modify any applicablebrokerage account agreements to prohibit their brokers from loaning their common units. We will adopt certain valuation methodologies and monthly conventions for U.S. federal income tax purposes that may result in a shift of income,gain, loss and deduction between our general partner and our unitholders. The IRS may challenge this treatment, which could adversely affectthe value of the common units. When we issue additional units or engage in certain other transactions, we will determine the fair market value of our assets and allocate anyunrealized gain or loss attributable to our assets to the capital accounts of our unitholders and our general partner. Our methodology may be viewed asunderstating the value of our assets. In that case, there may be a shift of income, gain, loss and deduction between certain unitholders and our general partner,which may be unfavorable to such unitholders. Moreover, under our valuation methods, subsequent purchasers of common units may have a greater portionof their Internal Revenue Code Section 743(b) adjustment allocated to our tangible assets and a lesser portion allocated to our intangible assets. The IRS maychallenge our valuation methods, or our allocation of the Section 743(b) adjustment attributable to our tangible and intangible assets, and allocations of taxableincome, gain, loss and deduction between our general partner and certain of our unitholders. A successful IRS challenge to these methods or allocations could adversely affect the amount of taxable income or loss being allocated to ourunitholders. It also could affect the amount of taxable gain from our unitholders’ sale of common units and could have a negative impact on the value of thecommon units or result in audit adjustments to our unitholders’ tax returns without the benefit of additional deductions. The sale or exchange of 50% or more of our capital and profits interests during any twelve-month period will result in the termination of ourpartnership for federal income tax purposes. 46Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. We will be considered to have technically terminated our partnership for federal income tax purposes if there is a sale or exchange of 50% or more ofthe total interests in our capital and profits within a twelve-month period. For purposes of determining whether the 50% threshold has been met, multiple salesof the same interest will be counted only once. Our technical termination would, among other things, result in the closing of our taxable year for all unitholders,which would result in us filing two tax returns (and our unitholders could receive two Schedules K-1 if relief was not available, as described below) for onefiscal year and could result in a deferral of depreciation deductions allowable in computing our taxable income. In the case of a unitholder reporting on a taxableyear other than a fiscal year ending December 31, the closing of our taxable year may also result in more than twelve months of our taxable income or lossbeing includable in his taxable income for the year of termination. Our termination currently would not affect our classification as a partnership for federalincome tax purposes, but instead we would be treated as a new partnership for tax purposes. If treated as a new partnership, we must make new tax electionsand could be subject to penalties if we are unable to determine that a termination occurred. The IRS has recently announced a publicly traded partnershiptechnical termination relief program whereby, if a publicly traded partnership that technically terminated requests publicly traded partnership technicaltermination relief and such relief is granted by the IRS, among other things, the partnership will only have to provide one Schedule K-1 to unitholders for theyear notwithstanding two partnership tax years. As a result of investing in our common units, our unitholders may become subject to state and local taxes and return filing requirements injurisdictions where we operate or own or acquire properties. In addition to federal income taxes, our unitholders will likely be subject to other taxes, including state and local taxes, unincorporated business taxesand estate, inheritance or intangible taxes that are imposed by the various jurisdictions in which we conduct business or own property now or in the future,even if they do not live in any of those jurisdictions. Our unitholders will likely be required to file state and local income tax returns and pay state and localincome taxes in some or all of these various jurisdictions. Further, our unitholders may be subject to penalties for failure to comply with those requirements.We own property or conduct business in Pennsylvania and West Virginia, each of which currently impose a personal income tax on individuals. Each of thesestates also impose an income tax on corporations and other entities. As we make acquisitions or expand our business, we may own property or conductbusiness in additional states that impose a personal income tax. It is our unitholders responsibility to file all U.S. federal, state and local tax returns. Ourcounsel has not rendered an opinion on the state or local tax consequences of an investment in our common units. Compliance with and changes in tax laws could adversely affect our performance. We are subject to extensive tax laws and regulations, including federal, state and foreign income taxes and transactional taxes such as excise,sales/use, payroll, franchise and ad valorem taxes. New tax laws and regulations and changes in existing tax laws and regulations are continuously beingenacted that could result in increased tax expenditures in the future. Many of these tax liabilities are subject to audits by the respective taxing authority. Theseaudits may result in additional taxes as well as interest and penalties. See also Item 7A, “Quantitative and Qualitative Disclosures About Market Risk,” for further discussion regarding the Company’s exposure tomarket risks, which is incorporated herein by reference. Item 1B. Unresolved Staff Comments None. Item 2. Properties For a description of material properties, see Item 1, “Business,” which is incorporated herein by reference. Item 3. Legal Proceedings In connection with its construction of the Big Sandy Pipeline in 2007, Equitrans entered into an agreement related to mining operations on both sidesof the Big Sandy Pipeline. The agreement provided that once mining was 47Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. concluded, Equitrans would pay the coal owner, Prater Branch Resources, the fair market value of any recoverable, merchantable coal underlying the BigSandy Pipeline which could not be recovered because of the existence of the pipeline. The agreement provided that any dispute related to the amount ofunrecoverable coal and the value thereof would be submitted to arbitration. In April 2011, Prater Branch submitted a claim to Equitrans. Equitrans did notagree with the amount or the value of the alleged unrecovered coal and commenced an arbitration proceeding with the American Arbitration Association (AAA)pursuant to the terms of the agreement. In July 2011, Equitrans and Prater Branch agreed to forego an arbitration administered by AAA and to proceed with a private mediation. The BigSandy Pipeline was sold to an unrelated third party in 2011, but Equitrans retained the liability under the Prater Branch agreement. In connection with theIPO, EQT agreed to indemnify Equitrans for any liabilities, claims or losses associated with its prior ownership of the Big Sandy Pipeline, including thePrater Branch claim. The parties settled the claim on November 20, 2012, with Equitrans agreeing to pay $2.7 million. EQT indemnified Equitrans for thefull amount of this payment. In the ordinary course of business, various other legal and regulatory claims and proceedings are pending or threatened against the Company. Whilethe amounts claimed may be substantial, the Company is unable to predict with certainty the ultimate outcome of such claims and proceedings. The Companyaccrues legal or other direct costs related to loss contingencies when actually incurred. The Company has established reserves it believes to be appropriate forpending matters, and after consultation with counsel and giving appropriate consideration to available insurance, the Company believes that the ultimateoutcome of any matter currently pending against the Company will not materially affect the business, financial condition, results of operations, liquidity orability to make distributions. Item 4. Mine Safety and Health Administration Data Not applicable. 48Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. PART II Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities The Company’s common units have been listed on the New York Stock Exchange (NYSE) under the symbol “EQM” since June 27, 2012. Prior tothat, the Company’s equity securities were not listed on any exchange or traded on any public trading market. Prior to the IPO, the operations comprising theCompany were owned by EQT. The following table sets forth the high and low sales prices reflected in the NYSE Composite Transactions of the commonunits, as reported by the NYSE, as well as the amount of cash distributions declared per quarter from the closing of the IPO through December 31, 2012. Common Unit Data by Quarter Unit Price RangeDistributions perHighLowCommon Unit2 Quarter (a)$ 24.62$ 22.58N/A3 Quarter$ 30.72$ 23.70N/A4 Quarter$ 31.39$ 27.70$ 0.35 (a) Since June 27, 2012, the commencement date of trading. As of February 1, 2013, there were 3 unitholders of record of the Company’s common units. A cash distribution of $0.35 per common unit wasdeclared on January 22, 2013 and was paid on February 14, 2013. Based on the Company’s current projections, the Company expects its first distributionincrease to occur with its next quarterly distribution. The Company has also issued 17,339,718 subordinated units and 707,744 general partner units, for which there is no established public tradingmarket. All of the subordinated units and general partner units are held by affiliates of the Company’s general partner. The general partner and its affiliatesreceive quarterly distributions on these units only after sufficient distributions have been paid to the common units. Set forth below under “Distributions ofAvailable Cash” is a summary of the significant provisions of the Company’s partnership agreement that relate to distributions of available cash, minimumquarterly distributions and incentive distribution rights. Market Repurchases The Company did not repurchase any of its common units during 2012. Distributions of Available Cash General The Company’s partnership agreement requires that, within 45 days after the end of each quarter, beginning with the quarter ended September 30,2012, the Company distribute all of its available cash (described below) to unitholders of record on the applicable record date. Available Cash Available cash generally means, for any quarter, all cash and cash equivalents on hand at the end of that quarter: · less, the amount of cash reserves established by the Company’s general partner to:– provide for the proper conduct of the Company’s business (including reserves for future capital expenditures, anticipated future debtservice requirements and refunds of collected 49ndrdthSource: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. rates reasonably likely to be refunded as a result of a settlement or hearing related to FERC rate proceedings or rate proceedings underapplicable law subsequent to that quarter);– comply with applicable law, any of the Company’s debt instruments or other agreements; or– provide funds for distributions to the Company’s unitholders and to the Company’s general partner for any one or more of the nextfour quarters (provided that the Company’s general partner may not establish cash reserves for distributions if the effect of theestablishment of such reserves will prevent the Company from distributing the minimum quarterly distribution on all common unitsand any cumulative arrearages on such common units for the current quarter);· plus, if the Company’s general partner so determines, all or any portion of the cash on hand on the date of determination of available cash forthe quarter resulting from working capital borrowings made subsequent to the end of such quarter. Subordinated Units All subordinated units are held by EQT. The partnership agreement provides that, during the period of time referred to as the “subordinationperiod,” the common units will have the right to receive distributions of available cash from operating surplus each quarter in an amount equal to $0.35 percommon unit, which amount is defined in the partnership agreement as the minimum quarterly distribution, plus any arrearages in the payment of theminimum quarterly distribution on the common units from prior quarters, before any distributions of available cash from operating surplus may be made onthe subordinated units. The practical effect of the subordinated units is to increase the likelihood that during the subordination period there will be availablecash to distribute the minimum quarterly distribution to the common units. The subordination period will end, and the subordinated units will convert tocommon units, on a one-for-one basis, when certain distribution requirements, as defined in the partnership agreement, have been met. The earliest date atwhich the subordination period may end is June 30, 2013. Incentive Distribution Rights All incentive distribution rights are held by the Company’s general partner. Incentive distribution rights represent the right to receive an increasingpercentage (13.0%, 23.0% and 48.0%) of quarterly distributions of available cash from operating surplus after the minimum quarterly distribution and thetarget distribution levels described below have been achieved. The Company’s general partner may transfer the incentive distribution rights separately from itsgeneral partner interest, subject to restrictions in the partnership agreement. The following discussion assumes that the Company’s general partner continues to own both its 2.0% general partner interest and the incentivedistribution rights. If for any quarter: · the Company has distributed available cash from operating surplus to the common and subordinated unitholders in an amount equal to theminimum quarterly distribution; and · the Company has distributed available cash from operating surplus on outstanding common units in an amount necessary to eliminate anycumulative arrearages in payment of the minimum quarterly distribution; then, the Company will distribute any additional available cash from operating surplus for that quarter among the unitholders and the Company’sgeneral partner in the following manner: · first, 98.0% to all unitholders, pro rata, and 2.0% to the Company’s general partner, until each unitholder receives a total of $0.4025 per unitfor that quarter (the “first target distribution”); · second, 85.0% to all unitholders, pro rata, and 15.0% to the Company’s general partner, until each unitholder receives a total of $0.4375 perunit for that quarter (the “second target distribution”); · third, 75.0% to all unitholders, pro rata, and 25.0% to the Company’s general partner, until each unitholder receives a total of $0.5250 perunit for that quarter (the “third target distribution”); and · thereafter, 50.0% to all unitholders, pro rata, and 50.0% to the Company’s general partner. 50Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Equity Compensation Plans The information relating to the Company’s equity compensation plans required by Item 5 is included in Item 12, “Security Ownership of CertainBeneficial Owners and Management and Related Stockholder Matters” contained herein. Item 6. Selected Financial Data The following selected financial data should be read in conjunction with Item 7, “Management’s Discussion and Analysis of Financial Conditionand Results of Operations” and Item 8, “Financial Statements and Supplementary Data.” The Company closed its IPO on July 2, 2012. Equitrans, L.P. (Equitrans) is a Pennsylvania limited partnership and the predecessor for accountingpurposes of EQT Midstream Partners. For periods prior to the IPO, the following selected financial data and related notes reflect the assets, liabilities andresults of operations of Equitrans presented on a carve-out basis, excluding the financial position and results of operations of the Big Sandy Pipeline (asdescribed in Note 1 to the Consolidated Financial Statements under Item 8, “Financial Statements and Supplementary Data”), prior to the contribution byEQT of all of the partnership interests in Equitrans to EQT Midstream Partners, in connection with the IPO. The selected financial data covering periods priorto the closing of the IPO may not necessarily be indicative of the actual results of operations had those contributed entities been operated separately during thoseperiods. As of and for the years ended December 31,20122011201020092008Statements of Consolidated Operations(Thousands, except per share amounts) Total operating revenues$136,910$109,613$91,600$80,057$71,862Operating income$70,691$54,620$37,937$28,704$20,231Net income$55,306$32,589$19,241$14,031$8,347Net income per limited partner unit (a):Basic$0.91N/AN/AN/AN/ADiluted$0.90N/AN/AN/AN/ACash distributions declared per unit$0.35N/AN/AN/AN/A Balance SheetTotal assets$707,604$546,442$415,001$386,682$349,352Long-term debt$—$135,235$135,235$57,107$57,107Long-term lease obligation$203,305$—$—$—$— (a) Reflective of general and limited partners’ interests in Net Income since the closing of the IPO on July 2, 2012. See Note 1 in Item 8, “FinancialStatements and Supplementary Data” for further discussion. Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations EQT Midstream Partners, LP (the Partnership, EQT Midstream Partners or the Company), which closed its initial public offering (IPO) tobecome publicly traded on July 2, 2012, is a growth-oriented Delaware limited partnership formed in January 2012. Equitrans, L.P. (Equitrans) is aPennsylvania limited partnership and the predecessor for accounting purposes (the Predecessor) of EQT Midstream Partners (the Successor). References in the following discussion to the “Company,” when used for periods prior to the IPO, refer to Equitrans. References in the followingdiscussion to the “Company,” when used for periods beginning at or following the IPO, refer collectively to the Partnership and its consolidatedsubsidiaries. Immediately prior to the closing of the IPO, EQT Corporation contributed all of the partnership interests in Equitrans to the Partnership.Therefore, the historical financial statements contained in this report reflect the assets, liabilities and operations of Equitrans (excluding the results ofoperations of Big Sandy Pipeline, a FERC-regulated transmission pipeline sold to an unrelated party in 51Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. July 2011) for periods ending before July 2, 2012 and EQT Midstream Partners for periods beginning at or following July 2, 2012. The following discussion analyzes, among other things, the financial condition and results of operations of the Predecessor and Successor.You should read the following discussion and analysis of financial condition and results of operations in conjunction with the consolidated financialstatements, and the notes thereto, included in Item 8, “Financial Statements and Supplementary Data.” References in the following discussion andanalysis to ‘‘EQT’’ refer collectively to EQT Corporation and its consolidated subsidiaries. Executive Overview The Company is a growth-oriented limited partnership formed by EQT Corporation (NYSE: EQT) to own, operate, acquire and develop midstreamassets in the Appalachian Basin. The Company provides substantially all of its natural gas transmission, storage and gathering services under contracts withfixed reservation and/or usage fees, with a significant portion of its revenues being generated pursuant to long-term firm contracts. On July 2, 2012, the Company closed its IPO of 14,375,000 common units at a price of $21.00 per unit, which included the full exercise of theunderwriters’ over-allotment option, and represented 40.6% of the Company’s outstanding equity. Immediately prior to the closing of the IPO, EQTcontributed all of the partnership interests in Equitrans to the Partnership. EQT retained a 59.4% equity interest in the Company, including 2,964,718common units, 17,339,718 subordinated units and a 2% general partner interest. The Company reported net income of $55.3 million in 2012 compared with $32.6 million in 2011. The increase was primarily related to an increasein operating income of $16.1 million and a decrease in income tax expense of $7.7 million. Transmission and storage revenues increased by $27.1 millionprimarily due to increased firm transmission service and increased system throughput, which were driven by production development in the Marcellus play.Total operating expenses increased consistent with the overall growth of the transmission system. The decrease in income tax expense was due to theCompany’s limited partnership structure subsequent to the IPO, as the Company is no longer subject to U.S. federal and state income taxes. Subsequent to the IPO in 2012, net income per limited partner unit was $0.91 and diluted net income per limited partner unit was $0.90. For the sixmonths ended December 31, 2012, adjusted EBTIDA was $40.0 million and distributable cash flow was $26.4 million, which exceeded the $24.8 million ofdistributable cash flow necessary to meet the minimum quarterly distributions. The Company paid all unitholders a quarterly cash distribution of $0.35 perunit during the year ended December 31, 2012 and declared a cash distribution to unitholders of $0.35 on January 22, 2013. For a discussion of the non-GAAP financial measures adjusted EBITDA and distributable cash flow, please read the discussion below of “Non-GAAP Financial Measures” and“Reconciliation of Non-GAAP Measures.” The Company reported net income of $32.6 million in 2011 compared with $19.2 million in 2010. The increase was primarily related to an increasein operating income of $16.7 million. Transmission and storage revenues increased by $19.3 million primarily due to the completion of a portion of theEquitrans 2010 Marcellus expansion project in the fourth quarter of 2010 and the addition of new receipt point interconnects with EQT’s gathering system. 52Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Consolidated Results of Operations Years Ended December 31,20122011%change2012 -20112010%change2011 -2010FINANCIAL DATA(Thousands, other than per unit and per day amounts)Operating revenues:Transmission and storage revenues$120,797$93,70728.9$74,39326.0Gathering revenues16,11315,9061.317,207(7.6)Total operating revenues136,910109,61324.991,60019.7 Operating expenses:Operating and maintenance29,40526,22112.124,3007.9Selling, general and administrative16,57517,302(4.2)18,477(6.4)Depreciation and amortization20,23911,47076.510,8865.4Total operating expenses66,21954,99320.453,6632.5Operating income70,69154,62029.437,93744.0Other income, net7,7013,826101.3498668.3Interest expense, net9,9555,05097.15,164(2.2)Income before income taxes68,43753,39628.233,27160.5Income tax expense13,13120,807(36.9)14,03048.3Net income$55,306$32,58969.7$19,24169.4Net income per limited partner unitBasic (1)$0.91N/AN/AN/AN/ADiluted (1)$0.90N/AN/AN/AN/AAdjusted EBITDA (1)$40,022N/AN/AN/AN/ADistributable cash flow (1)$26,441N/AN/AN/AN/ACAPITAL EXPENDITURE AND OPERATING DATATransmission pipeline throughput (BBtu per day)60639752.620494.6Gathered volumes (BBtu per day)78780.083(6.0)Capital expenditures:Expansion capital expenditures, excluding Sunrise Pipeline project$40,620$23,52272.7$10,549123.0Sunrise Pipeline project capital expenditures95,49485,45911.712,228598.9Maintenance capital expenditures:Ongoing maintenance13,81520,185(31.6)10,005101.7Funded regulatory compliance (2)6,9932143,167.8288(25.7)Reimbursable maintenance (2)10,1406,45157.23,33493.5Total maintenance capital expenditures30,94826,85015.313,62797.0Total capital expenditures$167,062$135,83123.0$36,404273.1 (1) Presented for the post-IPO period only. For a discussion of the non-GAAP financial measures adjusted EBITDA and distributable cash flow,please read the sections below titled “Non-GAAP Financial Measures” and “Reconciliation of Non-GAAP Measures.”(2) For more information regarding funded regulatory compliance and reimbursable maintenance see the discussion in the sections below titled“Capital Requirements.” 53Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Business Segment Results Operating segments are evaluated on their contribution to the Company’s consolidated results based on operating income. Interest and other incomeare managed on a consolidated basis. The Company has presented each segment’s operating income and various operational measures in the sections below.Management believes that presentation of this information provides useful information to management and investors regarding the financial condition, resultsof operations and trends of segments. In addition, management uses these measures for budget planning purposes. The Company has reconciled eachsegment’s operating income to the Company’s consolidated operating income and net income in Note 2 to the Consolidated Financial Statements. Years Ended December 31,20122011%change2012 -20112010%change2011 -2010SEGMENT FINANCIAL DATA –TRANSMISSION AND STORAGE(Thousands, other than per day amounts)Operating revenues:Operating revenues – affiliate$95,849$76,44925.4$62,96121.4Operating revenues – third party24,94817,25844.611,43251.0Total operating revenues120,79793,70728.974,39326.0Operating expenses:Operating and maintenance15,19111,67730.110,00916.7Selling, general and administrative11,53912,274(6.0)13,892(11.6)Depreciation and amortization17,4008,85096.68,2127.8Total operating expenses44,13032,80134.532,1132.1Operating income$76,667$60,90625.9$42,28044.1SEGMENT OPERATIONAL DATA –TRANSMISSIONAND STORAGETransmission pipeline throughput (BBtu per day)60639752.620494.6Capital expenditures$161,683$131,90222.6$33,158297.8 SEGMENT FINANCIAL DATA – GATHERINGOperating revenues:Operating revenues – affiliate$10,331$10,1072.2$11,067(8.7)Operating revenues – third party5,7825,799(0.3)6,140(5.6)Total operating revenues16,11315,9061.317,207(7.6)Operating expenses:Operating and maintenance14,21414,544(2.3)14,2911.8Selling, general and administrative5,0365,0280.24,5859.7Depreciation and amortization2,8392,6208.42,674(2.0)Total operating expenses22,08922,192(0.5)21,5503.0Operating loss$(5,976)$(6,286)(4.9)$(4,343)44.7 SEGMENT OPERATIONAL DATA –GATHERINGGathering volumes (BBtu per day)78780.083(6.0)Capital expenditures$5,379$3,92936.9$3,24621.0 54Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Year Ended December 31, 2012 Compared to Year Ended December 31, 2011 Operating revenues and operating expenses related to the Sunrise Pipeline do not have an impact on distributable cash flow as the excess of theSunrise Pipeline revenues over operating and maintenance and selling, general and administrative operating expenses is paid to EQT as the current monthlylease payment. Total operating revenues were $136.9 million for the year ended December 31, 2012 compared to $109.6 million for the year ended December 31,2011. The increase was primarily related to a $27.1 million increase in transmission and storage operating revenues. Gathering revenues were essentially flatyear over year. Transmission and storage revenues increased as a result of increased firm transmission service and increased system throughput. This includes$12.2 million of reservation fees and usage charges under firm contracts on the Sunrise Pipeline, $11.8 million of fees associated with transported volumes inexcess of firm capacity and increased reservation fees and usage charges under other firm contracts, which includes contracts for the Blacksville CompressorStation. These increases primarily resulted from increased production development in the Marcellus play. The average daily transmission throughputincreased by 209 BBtu per day during the year ended December 31, 2012 compared to the year ended December 31, 2011. For the year ended December 31,2012, approximately 62% of the Company’s total operating revenues were generated from firm capacity reservation charges. These increases were partly offsetby a decrease in storage and parking services. Operating expenses totaled $66.2 million for the year ended December 31, 2012 compared to $55.0 million for the year ended December 31, 2011.The increase in operating expenses was due to an $8.8 million increase in depreciation and amortization expense and a $3.2 million increase in operating andmaintenance expense, which were slightly offset by a decrease in selling, general and administrative expense. The increase in depreciation and amortization expense was primarily in transmission and storage as a result of Sunrise Pipeline capital leasedepreciation expense of $7.1 million and increased investment in transmission infrastructure. The Sunrise Pipeline capital lease is depreciated over the 15 yearlife of the lease, resulting in increased depreciation expense compared to the 40 year expected life of the pipeline. The increase in operating and maintenance expense resulted from a $3.5 million increase in transmission and storage expenses partly offset by a $0.3million decline in gathering operating and maintenance expense. Transmission and storage expenses increased primarily as a result of increased amortizationof pipeline safety costs of $1.4 million, additional operating costs of $0.9 million associated with operating the Sunrise Pipeline and non-income based taxes of$0.5 million. The decrease in gathering expense primarily resulted from lower purchased gas costs of $0.9 million which was partly offset by increasedrepairs and maintenance expenses of $0.7 million. Fuel usage and lost and unaccounted for volumes on the gathering system have historically exceeded thenatural gas retained from the Company’s gathering customers as compensation for its fuel usage and lost and unaccounted for volumes. Purchased gas costswere recorded for the difference. The decline in purchased gas costs during 2012 was primarily the result of lower prices, partly offset by increased lost andunaccounted for volumes due to higher system pressures. In the transmission and storage segment, selling, general and administrative expenses decreased by $0.7 million primarily due to a $2.5 millionreduction of a reserve on the collectability of long-term regulatory assets and a $0.6 million reduction to a legal reserve. The storage reserve was established forthe recovery of base storage gas from excess customer retention provided in the Company’s 2006 rate settlement. At December 31, 2012, the majority of the gashas been recovered and the related reserve was reduced. These expense reductions were partly offset by increased expenses associated with being a publiclytraded partnership of $1.4 million and $1.0 million due to the additional costs attributable to the Sunrise Pipeline. Other income primarily represents the equity portion of AFUDC which generally increases during periods of increased construction and decreasesduring periods of reduced construction. The increase in other income for the year ended December 31, 2012 when compared to the year ended December 31,2011 primarily resulted from an increase in applicable construction expenditures in connection with the Sunrise Pipeline project, which was placed into serviceon July 28, 2012. 55Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Income taxes for the year ended December 31, 2012 totaled $13.1 million compared to $20.8 million for the year ended December 31, 2011. The $7.7million decrease is primarily attributable to income taxes not being recorded after the IPO and an increased benefit related to equity AFUDC. The Predecessor’sfinancial statements include U.S. federal and state income tax expense. Due to the Company’s limited partnership structure subsequent to the IPO, theCompany is no longer subject to U.S. federal and state income taxes and therefore no income tax expense was recorded for the third and fourth quarters of2012. Year Ended December 31, 2011 Compared to Year Ended December 31, 2010 Total operating revenues were $109.6 million for the year ended December 31, 2011 compared to $91.6 million for the year ended December 31,2010. The $18.0 million increase was due to a $19.3 million increase in transmission and storage operating revenues, partly offset by a $1.3 million decreasein gathering operating revenues. The majority of the increase in transmission and storage operating revenues was attributable to an increase in firm transmission service reservationrevenues associated with an average daily increase of 193 BBtu of firm transmission service provided during the year ended December 31, 2011 whencompared to the year ended December 31, 2010. This increased firm transmission capacity sold was due to the completion of a portion of the Equitrans 2010Marcellus expansion project in the fourth quarter of 2010 and the addition of new receipt point interconnects with EQT’s gathering systems. The increasedfirm transmission capacity sold also resulted in higher usage fees based on increased throughput for the period, which also contributed to the increasedrevenues. Gathering revenues decreased due to fewer volumes gathered for the year ended December 31, 2011 when compared to the year ended December 31,2010. The decreased volumes were primarily due to the addition of new direct interconnects between EQT’s gathering systems and the Company’stransmission and storage system, resulting in decreased usage by EQT of the Company’s gathering system for connection onto its transmission and storagesystem. Volumes also decreased as a result of the natural decline in natural gas production from mature wells and limited additional development of some ofthe shallow, low-pressure formations served by the Company’s gathering system. Operating expenses totaled $55.0 million for the year ended December 31, 2011 compared to $53.7 million for the year ended December 31, 2010.The increase in operating expenses was primarily due to a $1.9 million increase in operating and maintenance expense partly offset by a $1.2 million decreasein selling, general and administrative expense. The increase in operating and maintenance expense for both transmission and storage and gathering was primarily due to the increased activity on theexpanded system. These increased expenses included costs related to compliance, training and engineering. Selling, general and administrative expensedecreased primarily as a result of completing the amortization of previously deferred costs for post-retirement benefits other than pensions in 2010. Depreciation and amortization expense increased $0.6 million year over year due to the increased investment in transmission infrastructure, whichincluded the Equitrans 2010 Marcellus expansion project and a large compressor station all in the transmission and storage segment. The $3.3 million increase in other income for the year ended December 31, 2011 compared to the year ended December 31, 2010 was primarily theresult of increased construction expenditures in connection with the Sunrise Pipeline project. Income taxes for the year ended December 31, 2011 totaled $20.8 million compared to $14.0 million for the year ended December 31, 2010. The$6.8 million increase was primarily driven by an increase in pre-tax income offset by a lower effective tax rate in 2011 primarily as a result of an increasedbenefit related to equity AFUDC. 56Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Non-GAAP Financial Measures As used herein, the Company defines adjusted EBITDA as net income plus net interest expense, income tax expense (if applicable), depreciation andamortization expense, non-cash long-term compensation expense and other non-cash adjustments less other income and the Sunrise Pipeline lease payment. Asused herein, the Company defines distributable cash flow as adjusted EBITDA less net cash paid for interest expense, maintenance capital expenditures andincome taxes (if applicable). Distributable cash flow should not be viewed as indicative of the actual amount of cash that the Company has available fordistributions or that the Company plans to distribute. Adjusted EBITDA and distributable cash flow are non-GAAP supplemental financial measures thatmanagement and external users of the Company’s consolidated financial statements, such as industry analysts, investors, lenders and rating agencies, use toassess: · the Company’s operating performance as compared to other publicly traded partnerships in the midstream energy industry, without regard tohistorical cost basis or, in the case of adjusted EBITDA, financing methods;· the ability of the Company’s assets to generate sufficient cash flow to make distributions to the Company’s unitholders;· the Company’s ability to incur and service debt and fund capital expenditures; and· the viability of acquisitions and other capital expenditure projects and the returns on investment of various investment opportunities. The Company believes that adjusted EBITDA and distributable cash flow provide useful information to investors in assessing the Company’sfinancial condition and results of operations. Adjusted EBITDA and distributable cash flow should not be considered alternatives to net income, operatingincome, cash flows from operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP. AdjustedEBITDA and distributable cash flow have important limitations as analytical tools because they exclude some but not all items that affect net income and netcash provided by operating activities. Additionally, because adjusted EBITDA and distributable cash flow may be defined differently by other companies inits industry, the Company’s definition of adjusted EBITDA and distributable cash flow may not be comparable to similarly titled measures of othercompanies, thereby diminishing their utility. 57Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Reconciliation of Non-GAAP Measures The following tables present a reconciliation of adjusted EBITDA and distributable cash flow, which are non-GAAP financial measures, to the mostcomparable GAAP financial measures of net income and net cash provided by operating activities. The amounts presented reflect the results for the year endedDecember 31, 2012 as presented in this Annual Report on Form 10-K less the results for the six months ended June 30, 2012 as presented in the Company’sForm 10-Q for the second quarter of 2012. Six Months EndedDecember 31, 2012(Thousands) Net income$32,171Add:Depreciation and amortization14,031Interest expense, net7,202Non-cash long-term compensation expense535Non-cash reserve adjustment(2,508)Less:Other income(1,073)Sunrise Pipeline lease payment(10,336)Adjusted EBITDA$40,022Less:Cash interest, net(445)Ongoing maintenance capital expenditures(1)(9,753)Reimbursable maintenance capital expenditures(2)(7,627)Add:Reimbursement of reimbursable maintenance capital expenditures(2)4,244Distributable cash flow$26,441 Six Months EndedDecember 31, 2012(Thousands) Net cash provided by operating activities$31,022Adjustments:Interest expense, net7,202Sunrise Pipeline lease payment(10,336)Other, including changes in working capital12,134Adjusted EBITDA$40,022 (1) Ongoing maintenance capital expenditures are expenditures (including expenditures for the construction or development of new capital assets or thereplacement, improvement or expansion of existing capital assets) made to maintain, over the long term, the Company’s operating capacity or operatingincome.(2) EQT has reimbursement obligations to the Company for certain capital expenditures for plugging and abandonment of natural gas wells and bare steelpipe replacement. For further explanation of these reimbursable maintenance capital expenditures, see the “Capital Requirements” section below. 58Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Outlook The Company’s principal business objective is to increase the quarterly cash distributions that it pays to its unitholders over time while ensuring theongoing growth of its business. The Company believes that it is well-positioned to achieve growth based on the combination of its relationship with EQT andits strategically located assets, which cover portions of the Marcellus Shale that lack substantial natural gas pipeline infrastructure. As production increases inthe Company’s areas of operations, the Company believes it will have a competitive advantage in attracting volumes to its transmission and storage systemthrough relatively low-cost capacity expansions. Additionally, the Company may acquire additional midstream assets from EQT, or pursue selected assetacquisitions from third parties, to the extent such acquisitions complement the Company’s or EQT’s existing asset base or allow the Company to captureoperational efficiencies from EQT’s production. Should EQT choose to pursue midstream asset sales, it is under no contractual obligation to offer the assetsto the Company. In the near term, the Company expects that the following internal transmission and storage expansion projects will allow it to capitalize on increaseddrilling activity by EQT and other third-party producers: · New Delivery Interconnect Expansion. The Morris III interconnect is expected to have 300 BBtu of incremental daily capacity into TexasEastern Transmission LP at an estimated cost of approximately $3 million. The Company expects this project will be placed into service in thesecond quarter of 2013. · Low Pressure East Expansion Project. This project involves uprating or replacing 26 miles of existing transmission pipeline in Greene,Washington and Allegheny counties in Pennsylvania at a cost of approximately $25 million. The Company expects to complete and place thisproject into service in the fourth quarter of 2013. When complete, this project will triple the current maximum allowable operating pressure of thepipeline, thereby creating approximately 150 BBtu per day of incremental firm transmission capacity on the system. For the year ended December 31, 2013, the Company forecasts adjusted EBITDA of approximately $80 - $83 million and distributable cash flow ofapproximately $61 - $64 million. This does not include the financial impacts of any potential acquisitions. For a discussion of the non-GAAP financialmeasures adjusted EBITDA and distributable cash flow, please read the discussion above of “Non-GAAP Financial Measures” and “Reconciliation of Non-GAAP Measures.” Capital Resources and Liquidity The Company’s principal liquidity requirements are to finance its operations, fund capital expenditures and acquisitions, make cash distributionsand satisfy any indebtedness obligations. The Company’s ability to meet these liquidity requirements will depend on its ability to generate cash in the future.Prior to the IPO, the Company’s primary sources of liquidity included cash generated from operations and cash contributions provided by EQT. TheCompany also participated in EQT’s cash management program prior to the IPO, whereby EQT swept cash balances residing in the Company’s bankaccounts on a periodic basis. Therefore, historical financial statements prior to the IPO reflect little or no cash balances. Capital expenditures previouslyfunded through amounts due to EQT and the classification of these amounts due to EQT as current liabilities have been responsible for the Company’shistorical working capital deficits. From and after the IPO, the Company’s available sources of liquidity include: · cash generated from operations; · $350 million available for borrowing under the Company’s credit facility; · cash on hand; · debt offerings; and · issuances of additional partnership units. 59Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Working Capital Working capital is the amount by which current assets exceed current liabilities. As of December 31, 2012, the Company had working capital of$10.3 million compared to a working capital deficiency of $61.0 million at December 31, 2011. As described above, the working capital deficiency prior tothe IPO was primarily due to the amounts due to EQT used to fund maintenance and expansion capital expenditures. The increase in working capital was dueto the decrease in amounts due to EQT as this mechanism is no longer being used to fund capital expenditures, no income taxes payable at December 31,2012, an increase in cash from the proceeds of the IPO and a decrease in accounts payable related to reduced capital expenditures payable at December 31,2012. This increase was offset slightly by the portion of the Sunrise Pipeline lease obligation which was current at December 31, 2012. Immediately prior tothe closing of the IPO, all amounts then due to/from EQT were settled. The Company’s working capital requirements have been and will continue to be primarily driven by changes in accounts receivable and accountspayable, including transactions with affiliates. These changes are primarily impacted by such factors as the timing of collections from customers and the levelof spending for maintenance and expansion capital activity. Changes in the terms of the Company’s transmission and storage agreements have a direct impacton its generation and use of cash from operations due to their impact on cash receipts, along with the related changes in working capital. A material adversechange in operations or available financing under the Company’s revolving credit facility described below may impact the Company’s ability to fundrequirements for liquidity and capital resources. The Company believes that cash on hand, cash generated from operations and availability under the credit facility will be adequate to meet theCompany’s operating short-term capital, debt service and cash distribution requirements. The Company believes that future internal growth projects andpotential acquisitions will be funded primarily through borrowings under the credit facility or through issuances of debt securities and additional partnershipunits. Operating Activities Net cash provided by operating activities during 2012 was $76.9 million compared to $47.6 million for 2011. The increase was primarily a resultof an increase in transmission and storage operating revenues due to increased firm transmission service and fees associated with transported volumes inexcess of firm capacity related to production development in the Marcellus play. This increase was partly offset by the distribution to EQT of approximately$12.2 million of trade and other accounts receivable prior to the initial public offering. Proceeds from the offering of $12.2 million were retained to replenishworking capital and are reflected in the financing activities section. Other working capital fluctuations in accounts payable, due to/from EQT affiliates andother assets and liabilities are mainly related to timing. Subsequent to the IPO, affiliate payables and receivables are settled monthly and are classified asoperating activities. Net cash provided by operating activities during 2011 was $47.6 million compared to $28.7 million for 2010. This increase was primarilyattributable to increases in net income and third party accounts payable. Net income increased $13.3 million for the year ended December 31, 2011 comparedto the year ended December 31, 2010. The favorable variance in net income was attributable to an $18.0 million increase in firm transmission service as aresult of increased reservation revenues and the associated average daily increase of 193 BBtu of firm transmission service provided during the year endedDecember 31, 2011 when compared to the year ended December 31, 2010. The increase in third party accounts payable was due to higher accrued costs atDecember 31, 2011 as a result of increased construction activity during the year primarily related to the Sunrise Pipeline project. Investing Activities Cash flows used in investing activities totaled $167.1 million for 2012 as compared to $135.8 million for 2011. The increase in capitalexpenditures was primarily attributable to the Sunrise Pipeline project prior to its transfer to EQT in connection with the IPO and the Blacksville CompressorStation project completed in the third quarter of 2012. Net cash used in investing activities was $41.7 million for the third and fourth quarters of 2012. Theseexpenditures mainly related to the completion of the Blacksville Compressor Station as well as expenditures for maintenance and regulatory complianceprojects. 60Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Cash flows used in investing activities totaled $135.8 million for 2011 as compared to $36.4 million for 2010. The increase was primarilyattributable to the Sunrise Pipeline project, new delivery interconnect projects and maintenance expenditures on one of the Company’s main measuring andregulating stations. See further discussion of capital expenditures, including the transfer to EQT of the Sunrise Pipeline project, in the “Capital Requirements” sectionbelow. Financing Activities The Company received net proceeds from the initial public offering of approximately $277 million, after deducting the underwriters’ discount and astructuring fee of approximately $20 million and offering expenses of approximately $5 million. Approximately $231 million of the proceeds were distributedto EQT, $12 million was retained by the Company to replenish amounts distributed by Equitrans to EQT prior to the IPO, $32 million was retained by theCompany to pre-fund certain maintenance capital expenditures, and $2 million was used by the Company to pay revolving credit facility origination feesassociated with its $350 million revolving credit agreement described below. During the third and fourth quarters of 2012, the Company paid approximately$3 million in principal payments on the Sunrise Pipeline capital lease and during the fourth quarter of 2012, the Company made its first cash distribution tounitholders of approximately $12 million. Based on the Company’s current projections, the Company expects its first distribution increase to occur with itsnext quarterly distribution. EQT has reimbursement obligations to the Company for certain capital expenditures for plugging and abandonment of natural gas wells and baresteel pipe replacement. The Company may request reimbursement for these expenditures quarterly based on actual expenditures to date and projections for theapplicable period. The Company requested reimbursement of $1.9 million for qualifying expenditures made in the third quarter of 2012 and received the cashfrom EQT in the fourth quarter of 2012. This is presented as a capital contribution from EQT and therefore is a cash inflow from financing. During thefourth quarter of 2012, the Company requested reimbursement of $2.4 million. The Company expects to receive the cash from EQT in the first quarter of2013. Prior to the IPO, the Company had financing cash inflows of $276.5 million for capital contributions from EQT and financing cash outflows of$10.2 million for distributions paid, $49.7 million related to reimbursements to EQT and $135.2 million to retire long-term intercompany debt to EQT. Priorto the IPO, certain advances from affiliates were viewed as financing transactions as the Company would have otherwise obtained demand notes or term loansfrom EQT Capital Corporation (EQT Capital) to fund these transactions. Subsequent to the IPO, these transactions reflect services rendered on behalf of theCompany by EQT and its affiliates for operating expenses and will be settled monthly. Therefore, these are classified as operating activities subsequent to theIPO. On July 2, 2012, in connection with the IPO, the Company entered into a $350 million revolving credit facility with Wells Fargo Bank, NationalAssociation, as administrative agent, and a syndicate of lenders, which will mature on July 2, 2017. The credit facility is available to fund working capitalrequirements and capital expenditures, to purchase assets, to pay distributions and repurchase units and for general partnership purposes. The credit facilityhas an accordion feature that allows the Company to increase the available revolving borrowings under the facility by up to an additional $150 million,subject to the Company’s receipt of increased commitments from existing lenders or new commitments from new lenders and the satisfaction of certain otherconditions. No amounts were borrowed during the third or fourth quarters of 2012. The credit facility contains various covenants and restrictive provisions and also requires maintenance of a consolidated leverage ratio of not morethan 5.00 to 1.00 (or, after the Company obtains an investment grade rating, not more than 5.50 to 1.00 for certain measurement periods following theconsummation of certain acquisitions) and, until the Company obtains an investment grade rating, a consolidated interest coverage ratio of not less than 3.00to 1.00. As of December 31, 2012, the Company was in compliance with all debt provisions and covenants. Net cash provided by financing activities for the year ended December 31, 2011 increased by $71.2 million as compared to the year endedDecember 31, 2010. The increase in cash provided by financing activities was primarily related to advances from EQT. The net use of this cash was forcapital expenditures discussed in the investing activities section above. 61Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Capital Requirements The transmission, storage and gathering businesses can be capital intensive, requiring significant investment to maintain and upgrade existingoperations. The below table presents capital expenditures forecasted for 2013 as well as actual amounts expended for 2012, 2011 and 2010. 2013Forecast2012Actual2011Actual2010Actual(Thousands)Expansion capital expenditures, excluding Sunrise Pipeline project$37,700$40,620$23,522$10,549Sunrise Pipeline project capital expenditures—95,49485,45912,228Maintenance capital expenditures:Ongoing maintenance17,20013,81520,18510,005Funded regulatory compliance12,4006,993214288Reimbursable maintenance6,00010,1406,4513,334Total maintenance capital expenditures35,60030,94826,85013,627Total capital expenditures$73,300$167,062$135,831$36,404 Expansion capital expenditures excluding the Sunrise Pipeline project totaled $40.6 million, $23.5 million and $10.5 million for the years endedDecember 31, 2012, 2011 and 2010, respectively. The increase in 2012 was primarily related to the Blacksville Compressor Station project, which wasplaced into service in September 2012 and cost approximately $30 million. The increase in 2011 as compared to 2010 was primarily due to expendituresassociated with new delivery interconnects. Sunrise Pipeline project capital expenditures were $95.5 million, $85.5 million and $12.2 million for the years ended December 31, 2012, 2011and 2010, respectively. On June 18, 2012, the Company transferred ownership of the Sunrise Pipeline to EQT and therefore, the Company will have nofuture capital expenditures related to this project. Maintenance capital expenditures are expenditures (including expenditures for the construction or development of new capital assets or thereplacement, improvement or expansion of existing capital assets) made to maintain, over the long term, the Company’s operating capacity or operatingincome. Examples of maintenance capital expenditures are expenditures to repair, refurbish and replace pipelines, to connect new wells to maintain throughput,to maintain equipment reliability, integrity and safety and to address environmental laws and regulations. Ongoing maintenance capital expenditures are all maintenance capital expenditures other than funded regulatory compliance and reimbursablemaintenance capital expenditures described below. Ongoing maintenance capital expenditures were $13.8 million, $20.2 million and $10.0 million for the yearsended December 31, 2012, 2011 and 2010, respectively. The increase in 2011 as compared to 2012 and 2010 relates to the completion of a project late in 2011to install over pressure protection and replace internal piping and measurement at one of the Company’s main measuring and regulating stations. Funded regulatory compliance capital expenditures are previously identified maintenance capital expenditures necessary to comply with certainregulatory and other legal requirements. Prior to the IPO, the Company identified two specific regulatory compliance initiatives, which will require it to expendapproximately $32 million, the majority of which is expected to be incurred over the two years following the IPO. The Company retained approximately $32million from the net proceeds of the IPO, which the Company anticipates will fully fund these expenditures. Note that the amounts included as fundedregulatory compliance for periods prior to the IPO were included for comparative purposes. As these amounts were spent in prior periods, they were notincluded in the 62Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Company’s estimate of $32 million for the initiatives identified prior to the IPO. Funded regulatory compliance capital expenditures were $7.0 million, $0.2million and $0.3 million for the years ended December 31, 2012, 2011 and 2010, respectively. Subsequent to the IPO, funded regulatory compliance capitalexpenditures were $6.8 million. The increases in 2012 relate primarily to costs incurred to install remote valve and pressure monitoring equipment on theCompany’s transmission and storage system. Expenditures to relocate certain valve operators above ground and apply corrosion protection also contributed tothe increase over the prior periods. Under the omnibus agreement that the Company entered into with EQT and its general partner at the closing of the IPO, EQT has reimbursementobligations to the Company related to certain capital expenditures. For a period of ten years after the closing of the IPO, EQT will reimburse the Company forplugging and abandonment expenditures and other expenditures for certain identified wells of EQT and third parties. The reimbursement obligation of EQTwith respect to wells owned by third parties is capped at $1.2 million per year. Additionally, EQT has agreed to reimburse the Company for bare steelreplacement capital expenditures in the event that ongoing maintenance capital expenditures (other than capital expenditures associated with plugging andabandonment liabilities to be reimbursed by EQT) exceed $17.2 million (with respect to the Company’s assets owned at the time of the IPO) in any year. Ifsuch ongoing maintenance capital expenditures and bare steel replacement capital expenditures exceed $17.2 million during a year, EQT will reimburse theCompany for the lesser of (i) the amount of bare steel replacement capital expenditures during such year and (ii) the amount by which such ongoing capitalexpenditures and bare steel replacement capital expenditures exceeds $17.2 million. This bare steel replacement reimbursement obligation is capped at anaggregate amount of $31.5 million over the ten years following the IPO. Note that the amounts included as reimbursable maintenance for periods prior to theIPO were included for comparative purposes. As these amounts were spent in prior periods, EQT has no reimbursement obligations for them under theomnibus agreement. Reimbursable maintenance capital expenditures were $10.1 million, $6.5 million and $3.3 million for the years ended December 31, 2012, 2011 and2010, respectively. The year over year growth was due to increases in costs associated with the Company’s program to replace bare steel pipe in its storagesystem and well plugging and abandonment expenditures. In 2012 prior to the IPO, reimbursable maintenance capital expenditures were approximately $2.5million. Since the IPO, plugging and abandonment capital expenditures totaled $1.6 million and the Company requested reimbursement of $1.6 million fromEQT for these capital expenditures. In 2012, ongoing maintenance capital expenditures totaled $13.8 million and bare steel replacement capital expenditures(post-IPO) totaled $6.1 million, for a total of $19.9 million. As a result, the Company requested bare steel reimbursements of $2.7 million for 2012. The Company’s future expansion capital expenditures may vary significantly from period to period based on the available investment opportunities.Maintenance related capital expenditures are expected to vary quarter to quarter, primarily based on weather. The Company expects to fund future capitalexpenditures through a combination of funds generated from its operations, cash on hand, borrowings under its credit facility and the issuance of additionalpartnership units and debt offerings. Distributions On October 23, 2012, the Company announced that the Board of Directors of its general partner declared a cash distribution to the Company’sunitholders of $0.35 per unit for the period beginning with the closing of its IPO on July 2, 2012 through September 30, 2012. The cash distribution waspaid on November 14, 2012 to unitholders of record at the close of business on November 5, 2012. On January 22, 2013, the Company announced that the Board of Directors of its general partner declared a cash distribution to the Company’sunitholders of $0.35 per unit for the period of October 1, 2012 through December 31, 2012. The cash distribution was paid on February 14, 2013 tounitholders of record at the close of business on February 4, 2013. Based on the Company’s current projections, the Company expects its first distribution increase to occur with its next quarterly distribution. 63Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Contractual Obligations TotalLess than1 Year2-3Years4-5 YearsMore than5 Years(Thousands)Capital lease obligations$342,459$25,368$51,176$51,176$214,739 Contemporaneously with the Company’s transfer of the Sunrise Pipeline to EQT, the Company entered into a capital lease with EQT for the lease ofthe Sunrise Pipeline. Under the capital lease, the Company operates the facilities as part of its transmission and storage system under the rates, terms andconditions of the Company’s FERC-approved tariff. While this lease agreement was effective June 18, 2012, lease payments pursuant to this lease agreementbegan when the Sunrise Pipeline was placed into service during the third quarter of 2012. The lease payment due in any given month is the lesser of thefollowing alternatives: (1) a revenue-based payment reflecting the revenues generated by the operation of the Sunrise Pipeline minus the actual costs of operatingthe Sunrise Pipeline and (2) a payment based on depreciation expense and pre-tax return on invested capital for the Sunrise Pipeline. As a result, the paymentsthe Company makes under the Sunrise Pipeline lease are variable and as described above in Item 7, “Management’s Discussion and Analysis of FinancialCondition and Results of Operations” are not expected to have a net positive or negative impact on the Company’s distributable cash flow. The amountspresented in the above table represent the future projected payments associated with the lease obligations (including interest) as of December 31, 2012. Commitments and Contingencies In the ordinary course of business, various legal and regulatory claims and proceedings are pending or threatened against the Company. While theamounts claimed may be substantial, the Company is unable to predict with certainty the ultimate outcome of such claims and proceedings. The Companyaccrues legal or other direct costs related to loss contingencies when actually incurred. The Company has established reserves it believes to be appropriate forpending matters and after consultation with counsel and giving appropriate consideration to available insurance, the Company believes that the ultimateoutcome of any matter currently pending against the Company will not materially affect its business, financial condition, results of operations, liquidity orability to make distributions. See also the “Contractual Obligations” discussion. Off-Balance Sheet Arrangements The Company does not have any off-balance sheet arrangements. Critical Accounting Policies and Significant Estimates The Company’s significant accounting policies are described in Note 1 to the Consolidated Financial Statements included in Item 8 of this Form 10-K. The discussion and analysis of the Consolidated Financial Statements and results of operations are based upon EQT Midstream Partners’ ConsolidatedFinancial Statements, which have been prepared in accordance with U.S. generally accepted accounting principles. The preparation of these ConsolidatedFinancial Statements requires management to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses andthe related disclosure of contingent assets and liabilities. The following critical accounting policies, which were reviewed by the Company’s Audit Committee,relate to the Company’s more significant judgments and estimates used in the preparation of its Consolidated Financial Statements. Actual results could differfrom those estimates. Revenue Recognition: Revenues relating to the transmission, storage and gathering of natural gas are recognized in the period service is provided.Reservation revenues on firm contracted capacity are recognized over the contract period based on the contracted volume regardless of the amount of natural gasthat is transported. Revenues associated with interruptible services are recognized as physical deliveries of natural gas are made. Revenue is recognized forgathering activities when deliveries of natural gas are made. 64Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. The Company encounters risks associated with the collection of its accounts receivable. As such, the Company records a monthly provision foraccounts receivable that are considered to be uncollectible. In order to calculate the appropriate monthly provision, a historical rate of accounts receivable lossesas a percentage of total revenue is utilized. This historical rate is applied to the current revenues on a monthly basis and is updated periodically based onevents that may change the rate, such as a significant change to the natural gas industry or to the economy as a whole. Management reviews the adequacy ofthe allowance on a quarterly basis using the assumptions that apply at that time. The Company believes that the accounting estimates related to revenue recognition and the allowance for doubtful accounts receivable are “criticalaccounting policies” because the underlying assumptions used for the allowance can change from period to period and the changes in the allowance couldpotentially have a material impact on the results of operations and on working capital. In addition, the actual mix of customers and their ability to pay mayvary significantly from management’s estimates and may impact the collectability of customer accounts. Regulatory Accounting: The Company’s operations consist of interstate pipeline, intrastate gathering and storage operations subject to regulation bythe FERC. Rate regulation provided by the FERC is designed to recover the costs of providing the regulated services. The application of ASC Topic 980“Regulated Operations” allows the Company to defer expenses and income on its consolidated balance sheets as regulatory assets and liabilities when it isprobable that those expenses and income will be allowed in the rate setting process in a period different from the period in which they would have been reflectedin the statements of consolidated operations for a non-regulated company. The deferred regulatory assets and liabilities are then recognized in the statements ofconsolidated operations in the period in which the same amounts are reflected in rates. The amounts deferred in the consolidated balance sheets relate primarilyto the pre-IPO accounting for income taxes and post-retirement benefit costs. The Company believes that it will continue to be subject to rate regulation that willprovide for the recovery of deferred costs. The Company believes that the accounting estimates related to regulatory accounting are “critical accounting policies” because the underlyingassumptions regarding the recovery of deferred costs and revenues in future rates can change from period to period and changes in the recoverability of theseamounts could potentially have a material impact on the results of operations and on working capital. Actual rate recovery amounts and periods may varysignificantly from management’s estimates and may impact the realization or recovery of regulatory assets and liabilities. Property, Plant and Equipment: Property, plant and equipment are stated at amortized cost. Maintenance projects that do not increase the overall lifeof the related assets are expensed as incurred. Expenditures that extend the useful life of the underlying asset are capitalized. Depreciation is recorded using composite rates on a straight-line basis. The overall rate of depreciation for the years ended December 31, 2012, 2011and 2010 were approximately 2.6%, 1.9% and 2.1%, respectively. The Company estimates its pipelines have useful lives ranging from 37 years to 65 yearsand its compression equipment has useful lives of 45 years. The Sunrise Pipeline capital lease is depreciated over the 15 year life of the lease, as compared tothe 40 year expected life of the pipeline, and is included in the overall depreciation rate for the year ended December 31, 2012. Depreciation rates are re-evaluatedeach time the Company files with the FERC for a change in its transportation and storage rates. Whenever events or changes in circumstances indicate that the carrying amount of long-lived assets may not be recoverable, the Company reviewsthe long-lived assets for impairment by first comparing the carrying value of the assets to the sum of the undiscounted cash flows expected to result from theuse and eventual disposition of the assets. If the carrying value exceeds the sum of the assets’ undiscounted cash flows, the Company estimates an impairmentloss by taking the difference between the carrying value and fair value of the assets. The Company believes that the accounting estimate related to asset impairment is a “critical accounting estimate” as it is highly susceptible to changefrom period to period because it requires management to make assumptions about cash flows over future years. These assumptions affect the amount of animpairment, which would have an impact on the results of operations and financial position. Management’s assumptions about future cash flows requiresignificant judgment because actual operating levels have fluctuated in the past and are expected to do so in the future. 65Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Contingencies and Asset Retirement Obligations: The Company is involved in various regulatory and legal proceedings that arise in the ordinarycourse of business. A liability is recorded for contingencies based upon the Company’s assessment that a loss is probable and that the amount of the loss canbe reasonably estimated. The Company considers many factors in making these assessments, including history and specifics of each matter. Estimates aredeveloped in consultation with legal counsel and are based upon an analysis of potential results. The Company operates and maintains its transmission and storage system and its gathering system and intends to do so as long as supply anddemand for natural gas exists, which is expected for the foreseeable future. Therefore, the Company believes that it cannot reasonably estimate the assetretirement obligations for its system assets as these assets have indeterminate lives. The Company believes that the accounting estimates related to contingencies and asset retirement obligations are “critical accounting estimates”because it must assess the probability of loss related to contingencies and the expected amount and timing of asset retirement obligations. In addition, theCompany must determine the estimated present value of future liabilities. Future results of operations for any particular quarterly or annual period could bematerially affected by changes in the assumptions. Equity-Based Compensation: The Company has awarded equity-based compensation in connection with the EQT Midstream Services, LLC 2012Long-Term Incentive Plan. These awards will be paid in units, and as such the Company treats these programs as equity awards. Awards that have a fixedestimate due to a market condition require the Company to obtain a valuation. Significant assumptions made in valuing the Company’s awards include themarket price of units at payout date, total unitholder return threshold to be achieved, volatility, risk-free rate, term, dividend yield and forfeiture rate. The Company believes that the accounting estimates related to equity-based compensation are “critical accounting estimates” because of theassumptions affecting the ultimate payout of the awards and the market price and volatility of the Company’s common units. Future results of operations forany particular quarterly or annual period could be materially affected by changes in the Company’s assumptions. Emerging Growth Company: The JOBS Act provides that an emerging growth company may delay adopting new or revised accounting standardsuntil such time as those standards apply to private companies. The Company has irrevocably elected to opt out of this exemption and, therefore, will besubject to the same new or revised accounting standards as other public companies that are not emerging growth companies. Item 7A. Quantitative and Qualitative Disclosures About Market Risk Commodity Price Risk Other than the base gas the Company purchases and uses in its natural gas storage facilities, which is necessary to maintain pressure anddeliverability in its storage pools, and purchases of a small amount of natural gas for system operations, the Company generally does not take title to thenatural gas that is stored or transported on its transmission system; accordingly, the Company is not exposed to commodity price fluctuations on natural gasstored in its facilities or transported through its pipelines by its customers. Base gas purchased and used in natural gas storage facilities, which was generallypurchased more than 30 years ago, is considered a long-term asset and is not re-valued at current market prices. A certain amount of gas is naturally lost inconnection with transporting natural gas across a pipeline system, and under the Company’s contractual arrangements with its customers the Company isentitled to retain a specified volume of natural gas in order to compensate the Company for such lost and unaccounted for volumes as well as its fuel usage.Historically the natural gas volumes retained from the Company’s transmission and storage customers as compensation for its fuel usage and lost andunaccounted for volumes pursuant to the Company’s transmission and storage agreements have been sufficient to cover its fuel usage and lost andunaccounted for volumes on the transmission and storage system. However, fuel usage and lost and unaccounted for volumes on its gathering system havehistorically exceeded the natural gas volumes retained from the Company’s gathering customers as compensation for its fuel usage and lost and unaccountedfor volumes pursuant to its gathering agreements. As a consequence, the Company has purchased natural gas to make up for the difference. For the yearsended December 31, 2012, 2011 and 2010, the Company’s actual fuel usage and lost and unaccounted for volumes exceeded the amounts recovered from itsgathering customers by approximately 1,800 BBtu, 1,300 BBtu and 1,500 BBtu, respectively, for which the Company recognized $4.0 million, $4.9 millionand 66Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. $5.7 million, respectively, of purchased gas cost as a component of operating and maintenance expense. Except for the base gas in its natural gas storagefacilities, which the Company considers to be a long-term asset, and volume and pricing variations related to the volumes of fuel purchased to make up forfuel usage and lost and unaccounted for volumes in excess of amounts recovered from customers, the Company’s current business model is designed tominimize its exposure to fluctuations in commodity prices. As a result, absent other market factors that could adversely impact its operations, changes in theprice of natural gas over the intermediate term should not materially impact the Company’s operations. The Company has not historically engaged in materialcommodity hedging activities relating to its assets. However, the Company may engage in commodity hedging activities in the future, particularly if itundertakes growth projects or engages in acquisitions that expose it to direct commodity price risk. Interest Rate Risk Prior to the IPO, the Company’s operating and acquisition activities were funded through intercompany borrowings with EQT at market rates. At the closing of the IPO on July 2, 2012, the Company entered into a new $350 million revolving credit facility. The Company may from time totime hedge the interest on portions of its borrowings under the revolving credit facility in order to manage risks associated with floating interest rates. Credit Risk The Company is exposed to credit risk. Credit risk represents the loss that it would incur if a counterparty fails to perform under its contractualobligations. Approximately 87% and 49% of the Company’s third party accounts receivable balances of $3.7 million and $5.1 million as of December 31,2012 and 2011, respectively, represent amounts due from marketers. The Company manages its exposure to credit risk associated with customers to whom itextends credit through credit analysis, credit approval, credit limits and monitoring procedures. For certain transactions, the Company may request letters ofcredit, cash collateral, prepayments or guarantees as forms of credit support. The Company’s tariff requires customers that do not meet specified creditstandards to provide three months of credit support; however, the Company is exposed to credit risk beyond this three month period when its tariff does notrequire its customers to provide additional credit support. For some of the Company’s more recent long-term contracts associated with system expansions, ithas entered into negotiated credit agreements that provide for enhanced forms of credit support if certain credit standards are not met. The Company hashistorically experienced only minimal credit losses in connection with its receivables. In connection with the IPO, EQT guaranteed all payment obligations, upto a maximum of $50 million, due and payable to Equitrans by EQT Energy, one of Equitrans’ largest customers. The EQT guaranty will terminate onNovember 30, 2023 unless terminated earlier by EQT by providing 10 days written notice. At December 31, 2012, EQT’s public senior debt had aninvestment grade credit rating. Item 8. Financial Statements and Supplementary Data Page Reference Report of Independent Registered Public Accounting Firm68 Statements of Consolidated Operations for each of the three years in the period endedDecember 31, 201269 Statements of Consolidated Cash Flows for each of the three years in the period endedDecember 31, 201270 Consolidated Balance Sheets as of December 31, 2012 and 201171 Consolidated Statements of Partner’s Capital for each of the three years in the period endedDecember 31, 201272 Notes to Consolidated Financial Statements73 67Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM The Board of Directors of EQT Midstream Services, LLC and Unitholders ofEQT Midstream Partners, LP We have audited the accompanying consolidated balance sheets of EQT Midstream Partners, LP (including its Predecessor as defined in Note 1 andcollectively, the Company) as of December 31, 2012 and 2011, and the related statements of consolidated operations, cash flows and partners’ capital for eachof the three years in the period ended December 31, 2012. These financial statements are the responsibility of the Company’s management. Our responsibilityis to express an opinion on these financial statements based on our audits. We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standardsrequire that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. We were notengaged to perform an audit of the Company’s internal control over financial reporting. Our audits included consideration of internal control over financialreporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on theeffectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a testbasis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates madeby management, and evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion. In our opinion, the financial statements referred to above present fairly, in all material respects, the consolidated financial position of EQT MidstreamPartners, LP at December 31, 2012 and 2011, and the consolidated results of its operations and its cash flows for each of the three years in the period endedDecember 31, 2012 in conformity with U.S. generally accepted accounting principles. Pittsburgh, PennsylvaniaFebruary 21, 2013 68Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LP STATEMENTS OF CONSOLIDATED OPERATIONS YEARS ENDED DECEMBER 31, 201220112010(Thousands, except per unit amounts)Revenues:Operating revenues - affiliate$106,180$86,556$74,028Operating revenues – third party30,73023,05717,572Total operating revenues136,910109,61391,600 Operating expenses:Operating and maintenance29,40526,22124,300Selling, general and administrative16,57517,30218,477Depreciation and amortization20,23911,47010,886Total operating expenses66,21954,99353,663 Operating income70,69154,62037,937 Other income, net7,7013,826498Interest expense, net9,9555,0505,164Income before income taxes68,43753,39633,271Income tax expense13,13120,80714,030Net income$55,306$32,589$19,241 Calculation of Limited Partner Interest in Net Income:Net income (a)$32,060N/A (b)N/ALess general partner interest in net income(640)N/AN/ALimited partner interest in net income$31,420N/AN/A Net income per limited partner unit – basic$0.91N/AN/ANet income per limited partner unit – diluted$0.90N/AN/A Limited partner units outstanding – basic34,679N/AN/ALimited partner units outstanding – diluted34,734N/AN/A (a) Presented for the post-initial public offering (IPO) period only. Reflects general and limited partner interest in net income from and after the closing of the Company’s IPO onJuly 2, 2012. See Note 1 of Notes to the Consolidated Financial Statements.(b) Not applicable. See notes to consolidated financial statements. 69Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LP STATEMENTS OF CONSOLIDATED CASH FLOWS YEARS ENDED DECEMBER 31, 201220112010(Thousands)Cash flows from operating activities:Net income$55,306$32,589$19,241Adjustments to reconcile net income to net cash provided by operating activities:Depreciation and amortization20,23911,47010,886Deferred income taxes6,78912,50611,115Other income(7,701)(3,826)(498)Non-cash long term compensation expense2,2822,2491,292Non-cash reserve adjustment(2,508)——Changes in other assets and liabilities:Accounts receivable(10,825)(492)(1,885)Accounts payable(11,070)14,470(1,727)Regulatory assets1,793(1,743)1,929Due (to)/from EQT affiliates28,555(16,846)(10,509)Other assets and other liabilities(5,923)(2,813)(1,128)Net cash provided by operating activities76,93747,56428,716 Cash flows from investing activities:Capital expenditures(167,062)(135,831)(36,404)Net cash used in investing activities(167,062)(135,831)(36,404) Cash flows from financing activities:Proceeds from the issuance of common units, net of offering costs276,780——Distribution of proceeds(230,887)——Due (to)/ from EQT(49,657)58,405(875)Retirements of long-term debt(135,235)——Partners’ investments276,54327,2508,601Capital contributions1,863——Distributions paid to EQT(10,193)(11,729)(4,975)Distributions paid to unitholders(12,386)——Payment of revolver fees(1,864)——Capital lease principal payments(2,889)——Net cash provided by financing activities112,07573,9262,751 Net change in cash and cash equivalents21,950(14,341)(4,937)Cash and cash equivalents at beginning of year—14,34119,278Cash and cash equivalents at end of year$21,950$—$14,341 Cash paid during the year for:Interest paid11,9965,6635,199 Non-cash activity during the year for:Capital lease obligation$215,731$—$—Non-cash distributions$205,949$—$—Elimination of net current and deferred tax liabilities$143,587$—$— See notes to consolidated financial statements. 70Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LP CONSOLIDATED BALANCE SHEETS YEARS ENDED DECEMBER 31, 20122011(Thousands, except number ofunits)Assets Current assets:Cash and cash equivalents$21,950$—Accounts receivable (net of allowance for doubtful accounts of $64 in 2012 and $77 in 2011)3,7435,147Accounts receivable - affiliate11,9119,283Due from related party2,38240,369Other current assets6451,661Total current assets40,63156,460 Property, plant and equipment795,498608,231Less: accumulated depreciation(148,212)(137,339)Net property, plant and equipment647,286470,892 Regulatory assets17,87718,247Other assets1,810843Total assets$707,604$546,442 Liabilities and Partners’ Capital Current liabilities:Accounts payable$9,452$20,522Due to related party1,13068,161Income taxes payable—17,498Lease obligation - current9,537—Accrued liabilities10,20711,247Total current liabilities30,326117,428 Notes payable – affiliate—135,235Deferred income taxes and investment tax credits—112,218Lease obligation203,305—Other long-term liabilities2,7607,928Total liabilities236,391372,809 Partners’ capital:Common units (17,339,718 units issued and outstanding at December 31, 2012)310,679—Subordinated units (17,339,718 units issued and outstanding at December 31, 2012)148,397—General partner interest (707,744 units issued and outstanding at December 31, 2012)12,137—Parent’s net investment—173,633Total partners’ capital471,213173,633Total liabilities and partners’ capital$707,604$546,442 See notes to consolidated financial statements. 71Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LP CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL YEARS ENDED DECEMBER 31, 2012, 2011 and 2010 Partners’ CapitalParent NetLimited PartnersGeneralInvestmentCommonSubordinatedPartnerTotal(Thousands)Balance at January 1, 2010$102,656$—$—$—$102,656Investment by partners8,601———8,601Distributions paid(4,975)———(4,975)Net income19,241———19,241Balance at December 31, 2010125,523———125,523Investment by partners27,250———27,250Distributions paid(11,729)———(11,729)Net income32,589———32,589Balance at December 31, 2011173,633———173,633Net income attributable to the period January 1, 2012 throughJuly 1, 201223,246———23,246Investment by partners276,543———276,543Distributions paid(10,193)———(10,193)Non-cash distributions(205,949)———(205,949)Elimination of net current and deferred tax liabilities143,587———143,587Contribution of net assets to EQT Midstream Partners, LP(400,867)56,560330,80513,502—Issuance of common units to public, net of offering costs—276,780——276,780Distribution of proceeds—(32,837)(192,049)(6,001)(230,887)Capital contribution———4,2444,244Equity-based compensation plans—535——535Net income attributable to the period July 2, 2012 throughDecember 31, 2012—15,71015,71064032,060Distributions to unitholders—(6,069)(6,069)(248)(12,386)Balance at December 31, 2012$—$310,679$148,397$12,137$471,213 See notes to consolidated financial statements. 72Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LPNOTES TO CONSOLIDATED FINANCIAL STATEMENTSDECEMBER 31, 2012 1. Summary of Operations and Significant Accounting Policies Organization EQT Midstream Partners, LP (the Partnership, EQT Midstream Partners or the Company), which closed its initial public offering (IPO) to becomepublicly traded on July 2, 2012, is a growth-oriented Delaware limited partnership formed by EQT Corporation in January 2012. Equitrans, L.P. (Equitrans)is a Pennsylvania limited partnership and the predecessor for accounting purposes (the Predecessor or EQT Midstream Partners Predecessor) of EQTMidstream Partners. EQT Midstream Services, LLC is the Company’s general partner. References in these consolidated financial statements to the“Company,” when used for periods prior to the IPO, refer to Equitrans. References in these consolidated financial statements to the “Company,” when usedfor periods beginning at or following the IPO, refer collectively to the Partnership and its consolidated subsidiaries. References in these consolidated financialstatements to ‘‘EQT’’ refer collectively to EQT Corporation and its consolidated subsidiaries. For periods prior to the IPO, the accompanying consolidatedfinancial statements and related notes include the assets, liabilities and results of operations of Equitrans presented on a carve-out basis, excluding thefinancial position and results of operations of the Big Sandy Pipeline (as described below), prior to the contribution by EQT of all of the partnership interestsin Equitrans to EQT Midstream Partners, in connection with the Partnership’s IPO. As of January 1, 2011, Equitrans was owned 97.25% by EQT Corporation and 2.75% by ET Blue Grass, LLC, a subsidiary of EQTCorporation. The Company does not have any employees. Operational support for the Company is provided by EQT Gathering, LLC (EQT Gathering), one ofEQT’s operating subsidiaries engaged in certain midstream business operations. EQT Gathering’s employees manage and conduct the Company’s dailybusiness operations. Prior to July 2011, Equitrans owned an approximately 70 mile FERC-regulated transmission pipeline located in eastern Kentucky (Big SandyPipeline). Construction on the Big Sandy Pipeline began in 2006 and was completed in 2008. Equitrans operated the pipeline until April 2011, when it wastransferred to an affiliate. Such affiliate was subsequently sold in July 2011 to an unrelated third party pipeline operator. Equitrans has no continuingoperations in Kentucky or any retained interest in the Big Sandy Pipeline. On June 18, 2012, the Company transferred ownership of the Sunrise Pipeline, an approximately 40 mile, FERC-regulated transmission pipelinewhich was under construction, to EQT via a non-cash distribution of $193.7 million. Contemporaneously with this transfer, the Company entered into acapital lease obligation with EQT for the lease of the Sunrise Pipeline. Under the capital lease, the Company operates the pipeline as part of its transmissionand storage system under the rates, terms and conditions of its FERC-approved tariff. The Sunrise Pipeline was placed into service on July 28, 2012. TheCompany makes monthly lease payments to EQT based on the lesser of a payment based on revenues collected less the actual cost to operate the pipeline and apayment based on depreciation expense and pre-tax return on invested capital for the Sunrise Pipeline. Immediately prior to the closing of the IPO, EQT contributed all of the partnership interests in Equitrans to the Partnership and Equitrans distributedits accounts receivable to EQT via a non-cash distribution of approximately $12 million. The Company issued 14,375,000 common units in the IPO, whichincluded the full exercise of the underwriters’ over-allotment option, and represented 40.6% of the Company’s outstanding equity. EQT retained a 59.4%equity interest in the Company, including 2,964,718 common units, 17,339,718 subordinated units, and a 2% general partner interest. The Companyreceived net proceeds of approximately $277 million, after deducting the underwriters’ discount and a structuring fee of approximately $20 million, andestimated offering expenses of approximately $5 million. Approximately $231 million of the proceeds were distributed to EQT, $12 million was retained bythe Company to replenish amounts distributed by Equitrans to EQT prior to the IPO, $32 million was retained by the Company to pre-fund certainmaintenance capital expenditures, and $2 million was used by the Company to pay revolving credit facility origination fees associated with its $350 millionrevolving credit agreement described in Note 6. In connection with the IPO, Equitrans’ net current and deferred taxes of approximately $144 million wereeliminated. See further discussion in Note 4. 73Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LPNOTES TO CONSOLIDATED FINANCIAL STATEMENTSDECEMBER 31, 2012 Nature of Business The Company is a growth-oriented limited partnership formed by EQT to own, operate, acquire and develop midstream assets in the AppalachianBasin. The Company provides midstream services to EQT and third parties in the Appalachian Basin across 22 counties in Pennsylvania and West Virginiathrough two primary assets: the transmission and storage system and the gathering system. Transmission and Storage System: The Company’s transmission and storage system includes an approximately 700 mile FERC-regulated interstatepipeline that connects to five long-haul interstate pipelines and multiple distribution companies. The transmission and storage system is supported by 14associated natural gas storage reservoirs with approximately 400 MMcf per day of peak withdrawal capability and 32 Bcf of working gas capacity. As ofDecember 31, 2012, the transmission assets had total throughput capacity of approximately 1.4 TBtu per day. Revenues are primarily driven by theCompany’s firm transmission and storage contracts. Gathering System: The Company’s gathering system consists of approximately 2,000 miles of FERC-regulated low-pressure gathering lines.Substantially all of the revenues associated with the Company’s gathering system are generated under interruptible gathering service contracts. Significant Accounting Policies Principles of Consolidation: The Consolidated Financial Statements include the accounts of EQT Midstream Partners, LP and all subsidiaries andpartnerships. Transactions between the Company and EQT have been identified in the Consolidated Financial Statements as transactions between affiliates inNote 3. Segments: Operating segments are revenue-producing components of the enterprise for which separate financial information is produced internallyand are subject to evaluation by the Company’s chief operating decision maker in deciding how to allocate resources. The Company reports its operations in two segments, which reflect its lines of business. Transmission and storage includes the Company’s FERC-regulated interstate pipeline and storage business. Gathering includes the FERC-regulated low pressure gathering system. The operating segments are evaluatedon their contribution to the Company’s operating income. All of the Company’s operating revenues, income from continuing operations and assets are generated or located in the United States. Use of Estimates: The preparation of financial statements in conformity with United States generally accepted accounting principles requiresmanagement to make estimates and assumptions that affect the amounts reported in the Consolidated Financial Statements and accompanying notes. Actualresults could differ from those estimates. Cash and Cash Equivalents: The Company considers all highly liquid investments with an original maturity of three months or less whenpurchased to be cash equivalents. Interest earned on cash equivalents is included as a reduction to interest expense, net in the accompanying statements ofconsolidated operations. Trade and Other Receivables: Trade and other receivables are stated at their historical carrying amount. Judgment is required to assess the ultimaterealization of accounts receivable, including assessing the probability of collection and the creditworthiness of customers. Based upon management’sassessments, allowances for doubtful accounts of approximately $0.1 million were provided at December 31, 2012 and 2011. The Company also maintainscertain receivables due from EQT. Refer to Note 3 for further discussion. Property, Plant and Equipment: The Company’s property, plant and equipment are stated at amortized cost. Maintenance projects that do notincrease the overall life of the related assets are expensed as incurred. Expenditures that extend the useful life of the underlying asset are capitalized. 74Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LPNOTES TO CONSOLIDATED FINANCIAL STATEMENTSDECEMBER 31, 2012 As of December 31,20122011(Thousands)Transmission and storage assets$691,898$511,089Accumulated depreciation(125,129)(114,485)Net transmission and storage assets566,769396,604Gathering assets103,60097,142Accumulated depreciation(23,083)(22,854)Net gathering assets80,51774,288Net property, plant and equipment$647,286$470,892 Depreciation is recorded using composite rates on a straight-line basis. The overall rate of depreciation for the years ended December 31, 2012, 2011and 2010 were approximately 2.6%, 1.9% and 2.1%, respectively. The Company estimates the pipelines have useful lives ranging from 37 years to 65 yearsand the compression equipment has a useful life of 45 years. The Sunrise Pipeline capital lease is depreciated over the 15 year life of the lease, as compared tothe 40 year expected life of the pipeline and is included in the overall depreciation rate for the year ended December 31, 2012. Depreciation rates are re-evaluatedeach time the Company files with the FERC for a change in the Company’s transportation and storage rates. Whenever events or changes in circumstances indicate that the carrying amount of long-lived assets may not be recoverable, the Company reviews itslong-lived assets for impairment by first comparing the carrying value of the assets to the sum of the undiscounted cash flows expected to result from the useand eventual disposition of the assets. The transmission, storage and gathering systems are evaluated as one asset group for impairment purposes because thecash flows are not independent of one another. If the carrying value exceeds the sum of the assets’ undiscounted cash flows, the Company estimates animpairment loss equal to the difference between the carrying value and fair value of the assets. Natural Gas Imbalances: The Company experiences natural gas imbalances when the actual amount of natural gas delivered from a pipelinesystem or storage facility differs from the amount of natural gas scheduled to be delivered. The Company values these imbalances due to or from shippers andoperators at current index prices. Imbalances are settled in-kind, subject to the terms of the FERC tariff. Imbalances as of December 31, 2012 and 2011 were $1.8 million and $1.1 million, respectively, and are included in accrued liabilities in theaccompanying consolidated balance sheets. In addition, the Company classifies all imbalances as current as it expects to settle them within a year. Accrued Liabilities: Included in accrued liabilities in the Company’s consolidated balance sheets is approximately $5 million and $6 million ofincentive compensation at December 31, 2012 and 2011, respectively. Regulatory Accounting: The Company’s operations consist of interstate pipeline, intrastate gathering and storage operations subject to regulation bythe FERC. Rate regulation provided by the FERC is designed to enable the Company to recover the costs of providing the regulated services plus an allowedreturn on invested capital. The application of regulatory accounting allows the Company to defer expenses and income in its balance sheets as regulatory assetsand liabilities when it is probable that those expenses and income will be allowed in the rate setting process in a period different from the period in which theywould have been reflected in the statements of operations for a non-regulated company. The deferred regulatory assets and liabilities are then recognized in thestatements of operations in the period in which the same amounts are reflected in rates. The amounts deferred are to be recovered over the regulated period. Theamounts deferred in the balance sheets relate primarily to the accounting for income taxes, AFUDC and post-retirement benefit costs. The amounts establishedfor accounting for income taxes and AFUDC were generated during the pre-IPO period when the Company was reported and included as part of EQT’sconsolidated federal tax return. The Company believes that it will continue to be subject to rate regulation that will provide for the recovery of deferred costs. On April 5, 2006, the FERC approved a settlement to Equitrans’ consolidated 2005 and 2004 rate case filings. The settlement became effective onJune 1, 2006. This settlement (i) increased the Company’s base tariff 75Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LPNOTES TO CONSOLIDATED FINANCIAL STATEMENTSDECEMBER 31, 2012 rates, (ii) implemented an annual surcharge for the tracking and recovery of certain pipeline safety costs among other programs, which surcharge is currentlysubject to two customer protests for which the Company is seeking FERC approval of a proposed settlement which would replace the annual tracker with afixed pipeline safety cost rate and (iii) implemented a mechanism for recovering migrated base gas. The Company previously established a storage reserve forthe recovery of base storage gas from excess customer retention provided in the Company’s 2006 rate settlement. At December 31, 2012, the majority of thegas has been recovered and the related reserve was reduced. Revenue Recognition: Revenues relating to the transmission, storage and gathering of natural gas are recognized in the period service is provided.Reservation revenues on firm contracted capacity are recognized ratably over the contract period based on the contracted volume regardless of the amount ofnatural gas that is transported. Revenues associated with interruptible services are recognized as physical deliveries of natural gas are made. Revenue isrecognized for gathering activities when deliveries of natural gas are made. AFUDC: The Company capitalizes the carrying costs for the construction of certain regulated long-term assets and amortizes the costs over the lifeof the related assets. The calculated AFUDC includes capitalization of the cost of financing construction of assets subject to regulation by the FERC. Acomputed interest cost and a designated cost of equity for financing the construction of these regulated assets are recorded in the consolidated financialstatements. AFUDC applicable to equity funds recorded in other income in the statements of consolidated operations for the years ended December 31, 2012,2011 and 2010 were $6.2 million, $3.8 million and $0.1 million, respectively. AFUDC applicable to interest cost for the years ended December 31, 2012,2011 and 2010 was $1.7 million, $0.8 million and $0.1 million, respectively, and is included as a reduction of interest expense, net in the statements ofconsolidated operations. Asset Retirement Obligations: The Company operates and maintains its transmission and storage system and its gathering system, and intends todo so as long as supply and demand for natural gas exists, which is expected for the foreseeable future. Therefore, the Company believes that it cannotreasonably estimate the asset retirement obligations for its system assets as these assets have indeterminate lives. Equity-Based Compensation: The Company has awarded equity-based compensation in connection with the EQT Midstream Services, LLC 2012Long-Term Incentive Plan. These awards will be paid in units, and as such the Company treats these programs as equity awards. Awards that have a fixedestimate due to a market condition require the Company to obtain a valuation. Significant assumptions made in valuing the Company’s awards include themarket price of units at payout date, total unitholder return threshold to be achieved, volatility, risk-free rate, term, dividend yield and forfeiture rate. Net Income per Limited Partner Unit: Net income per limited partner unit is calculated utilizing the two-class method by dividing the limitedpartner interest in net income by the weighted average number of limited partner units outstanding during the period. The limited partner interest in net incomeis determined by first allocating net income (earned from the close of the IPO) to the general partner based upon the general partner’s ownership interest of 2%.The common units issued during the period are included on a weighted-average basis for the days in which they were outstanding. Diluted net income perlimited partner unit reflects the potential dilution that could occur if securities or other agreements to issue common units, such as performance awards, wereexercised, settled or converted into common units. Income Taxes: Prior to the IPO, the Company’s income was reported and included as part of EQT’s consolidated federal tax return. Equitrans is aPennsylvania limited partnership that was a tax partnership through December 31, 2010 at which time as a result of an internal restructuring it was deemed tobe solely owned by EQT and became a disregarded entity for federal income tax purposes. In conjunction with the contribution by EQT of the ownership ofEquitrans to the Partnership immediately prior to the IPO, approximately $143.6 million of net current and deferred tax liabilities were eliminated throughequity. Effective July 2, 2012, as a result of its limited partnership structure, the Company is a partnership for income tax purposes and no longer subject tofederal and state income taxes. For federal and state income tax purposes, all income, expenses, gains, losses and tax credits generated flow through to theowners, and accordingly, do not result in a provision for income taxes for the Company. Net income for financial statement purposes may differ significantlyfrom taxable income of unitholders because of differences between the tax basis and financial reporting basis of assets and liabilities and the taxable 76Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LPNOTES TO CONSOLIDATED FINANCIAL STATEMENTSDECEMBER 31, 2012 income allocation requirements under the Company’s partnership agreement. The aggregate difference in the basis of our net assets for financial and taxreporting purposes cannot be readily determined because information regarding each partner’s tax attributes is not available to us. Subsequent Events: The Company has evaluated subsequent events through the date of the financial statement issuance. Recently Issued Accounting Standards Under the Jumpstart Our Business Startups Act (JOBS Act), for as long as the Company remains an ‘‘emerging growth company’’ as defined in theJOBS Act, the Company may take advantage of certain exemptions from Securities and Exchange Commission (SEC) reporting requirements that areapplicable to other public companies that are not emerging growth companies, including not being required to provide an auditor’s attestation report onmanagement’s assessment of the effectiveness of its system of internal control over financial reporting pursuant to Section 404 of the Sarbanes-Oxley Act,reduced disclosure obligations regarding executive compensation in the Company’s periodic reports and proxy statements, exemptions from the requirements ofholding a nonbinding advisory vote on executive compensation and seeking shareholder approval of any golden parachute payments not previously approved.The Company may take advantage of these reporting exemptions until the Company is no longer an emerging growth company. The Company will remain anemerging growth company for up to five years, although it will lose that status sooner if it has more than $1.0 billion of revenues in a fiscal year, the limitedpartner interests held by non-affiliates have a market value of more than $700 million, or the Company issues more than $1.0 billion of non-convertible debtover a three-year period. The JOBS Act also provides that an emerging growth company can delay adopting new or revised accounting standards until such time as thosestandards apply to private companies. The Company has irrevocably elected to ‘‘opt out’’ of this exemption and, therefore, will be subject to the same new orrevised accounting standards as other public companies that are not emerging growth companies. 2. Financial Information by Business Segment Operating segments are revenue-producing components of the enterprise for which separate financial information is produced internally and is subjectto evaluation by the chief operating decision maker in deciding how to allocate resources. The Company reports its operations in two segments, which reflect its lines of business. Transmission and storage includes the Company’s FERC-regulated interstate pipeline and storage business. Gathering includes the FERC-regulated low pressure gathering system. The operating segments are evaluatedon their contribution to the Company’s results based on operating income. All of the Company’s operating revenues, income from operations and assets are generated or located in the United States. 77Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LPNOTES TO CONSOLIDATED FINANCIAL STATEMENTSDECEMBER 31, 2012 Years Ended December 31,201220112010(Thousands)Revenues from external customers:Transmission and storage$120,797$93,707$74,393Gathering16,11315,90617,207Total$136,910$109,613$91,600 Operating income (loss):Transmission and storage$76,667$60,906$42,280Gathering(5,976)(6,286)(4,343)Total operating income$70,691$54,620$37,937 Reconciliation of operating income to net income: Other income7,7013,826498Interest expense9,9555,0505,164Income taxes13,13120,80714,030Net income$55,306$32,589$19,241 As of December 31,20122011(Thousands)Segment assets:Transmission and storage$632,404$461,002Gathering75,20085,440Total assets$707,604$546,442 Years Ended December 31,201220112010(Thousands)Depreciation and amortization:Transmission and storage$17,400$8,850$8,212Gathering2,8392,6202,674Total$20,239$11,470$10,886 Expenditures for segment assets:Transmission and storage$161,683$131,902$33,158Gathering5,3793,9293,246Total$167,062$135,831$36,404 3. Related-Party Transactions In the ordinary course of business, the Company has transactions with affiliated companies. The Company has various contracts with affiliatesincluding, but not limited to, Transportation Service and Precedent Agreements, Storage Agreements and Gas Gathering Agreements. Accounts receivable—affiliate represents amounts due from subsidiaries of EQT, primarily related to transmission, storage and gathering services.For the years ended December 31, 2012, 2011 and 2010, the Company generated revenues of approximately $106.2 million, $86.6 million and$74.0 million, respectively, from services provided to subsidiaries of EQT. 78Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LPNOTES TO CONSOLIDATED FINANCIAL STATEMENTSDECEMBER 31, 2012 The accompanying consolidated balance sheets include amounts due from related parties of $2.4 million and $40.4 million as of December 31, 2012and 2011, respectively. Amounts due to related parties as of December 31, 2012 and 2011, respectively, totaled $1.1 million and $68.2 million. Theseamounts represent transactions with subsidiaries of EQT other than transmission, storage and gathering services. As discussed in Note 6 prior to the Company’s IPO, EQT provided financing to its subsidiaries directly or indirectly through EQT CapitalCorporation (EQT Capital), EQT’s subsidiary finance company, predominantly through intercompany term and demand loans. The Company had demandand term notes due to EQT Capital of approximately $135.2 million as of December 31, 2011, which were repaid prior to the IPO. Interest expense on affiliatelong-term debt and demand loans amounted to $4.1 million, $5.8 million, and $5.2 million for the years ended December 31, 2012, 2011 and 2010,respectively. In addition, operating and administrative expenses and capital expenditures incurred on the Company’s behalf by EQT result in intercompanyadvances recorded as amounts due to or due from EQT on the Company’s balance sheet. Prior to the IPO, these advances were related to changes in workingcapital, cash used for capital expenditures, as well as the Company’s cash flow needs. Prior to the IPO, these were viewed as financing transactions as theCompany would have otherwise obtained demand notes or term loans from EQT Capital to fund these transactions. Subsequent to the IPO, these transactionsreflect services rendered on behalf of the Company by EQT and its affiliates for operating expenses as described below and will be settled monthly. These areclassified as operating activities in the statement of cash flows. The personnel who operate the Company’s assets are employees of EQT. EQT directly charges the Company for the payroll and benefit costsassociated with employees and carries the obligations for other employee-related benefits in its consolidated financial statements. The Company is allocated aportion of EQT’s defined benefit pension plan and retiree medical and life insurance liability for the retirees of Equitrans based on an actuarial assessment ofthat liability. The Company’s share of those costs is charged through due to related parties and reflected in operating and maintenance expense and selling,general and administrative expense in the accompanying statements of consolidated operations. The Company is allocated a portion of the indirect operating and maintenance expense incurred by EQT Gathering, a subsidiary of EQT that incurscertain costs that are shared by the Company. For the years ended December 31, 2012, 2011 and 2010, operating and maintenance expenses allocated to theCompany were approximately $3.4 million, $2.5 million and $0.4 million, respectively. The allocation in 2010 was based on the Company’s percentage oflabor hours for certain operations and maintenance departments. Starting in 2011, EQT Gathering began allocating certain engineering and gas controlexpenses to the Company that were not previously allocated. The allocation in 2011 and 2012 is based on the Company’s percentage of a calculation basedupon net plant, revenue and headcount. EQT management believes allocating these expenses to the Company was necessary and appropriate due to the amountof such costs that were directly attributable to the Company as a result of its expansion efforts. For the years ended December 31, 2012, 2011 and 2010, corporate selling, general and administrative expenses allocated to the Company wereapproximately $4.6 million, $3.7 million and $3.9 million, respectively. Additionally, a portion of the selling, general and administrative expense incurred byEQT Gathering was allocated to the Company based on a calculation of its percentage of net plant, revenue and headcount. The historical financial statements of the Predecessor include long-term incentive compensation plan expenses associated with the EQT long-termincentive plan, which is not an expense of the Company subsequent to the IPO. See Note 11 for discussion of the Company’s equity-based compensationplans. Included within operating expenses in the accompanying statements of consolidated operations is EQT share-based compensation expense of $1.9million, $3.1 million and $2.9 million for the years ended December 31, 2012, 2011 and 2010, respectively. EQT’s share-based compensation programsconsist of restricted stock, stock options and performance-based units issued to employees. To the extent compensation related to employees directly involvedin transmission and storage or gathering operations, such amounts were charged to the Company by EQT and were reflected as operating and maintenanceexpenses. To the extent compensation cost related to employees indirectly involved in transmission and storage or gathering operations, such amounts werecharged to the Company by EQT and were reflected as general and administrative expenses. 79Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LPNOTES TO CONSOLIDATED FINANCIAL STATEMENTSDECEMBER 31, 2012 Agreements with EQT The Company and other parties have entered into various agreements with EQT, as summarized below. These agreements were negotiated inconnection with the IPO. Omnibus Agreement The Company entered into an omnibus agreement by and among the Company, its general partner and EQT. Pursuant to the omnibus agreement,EQT agreed to provide the Company with a license to use the name “EQT” and related marks in connection with the Company’s business. The omnibusagreement also provides for certain indemnification and reimbursement obligations between EQT and the Company. As more fully described in the omnibus agreement, the following matters are addressed: · the Company’s obligation to reimburse EQT and its affiliates for certain direct operating expenses they pay on the Company’s behalf; · the Company’s obligation to reimburse EQT and its affiliates for providing the Company corporate, general and administrative services andproviding the Company operation and management services pursuant to the operation and management services agreement; · EQT’s obligation to indemnify or reimburse the Company for losses or expenses relating to or arising from (i) certain plugging andabandonment obligations; (ii) certain bare steel replacement capital expenditures; (iii) certain pipeline safety costs; (iv) certain preclosingenvironmental liabilities; (v) certain title and rights-of-way matters; (vi) the Company’s failure to have certain necessary governmental consentsand permits; (vii) certain preclosing tax liabilities; (viii) assets previously owned by Equitrans, but retained by EQT and its affiliates followingthe IPO, including the Sunrise Pipeline; (ix) any claims related to Equitrans’ previous ownership of the Big Sandy Pipeline; and (x) anyamounts owed to the Company by a third party that has exercised a contractual right of offset against amounts owed by EQT to such thirdparty; and · the Company’s obligation to indemnify EQT for losses attributable to (i) the ownership or operation of the Company’s assets after the closing ofthe IPO, except to the extent EQT is obligated to indemnify the Company for such losses pursuant to the operation and management servicesagreement with EQT, and (ii) any amounts owed to EQT by a third party that has exercised a contractual right of offset against amounts owedby the Company to such third party. In 2012 for the post-IPO period of July 2, 2012 to December 31, 2012, the Company was obligated to reimburse EQT for approximately $8.5million of operating and maintenance expenses and approximately $7.7 million of selling, general and administrative expenses pursuant to the omnibusagreement. In 2012 for the post-IPO period of July 2, 2012 to December 31, 2012, EQT was obligated to reimburse the Company pursuant to the omnibusagreement for $1.6 million related to plugging and abandonment liabilities, $2.7 million related to bare steel replacement, and $2.7 million related to BigSandy Pipeline claims. Approximately $2.4 million of these obligations are recorded as due from related party in the consolidated balance sheet atDecember 31, 2012. Operation and Management Services Agreement The Company entered into an operation and management services agreement with EQT Gathering, pursuant to which EQT Gathering will providethe Company’s pipelines and storage facilities with certain operational and management services. The Company will reimburse EQT Gathering for suchservices pursuant to the terms of the omnibus agreement as described above. Under the operation and management services agreement, EQT Gathering will indemnify the Company with respect to claims, losses or liabilitiesincurred by the Company, including third party claims, arising out of EQT Gathering’s gross negligence or willful misconduct. The Company willindemnify EQT Gathering from any claims, losses or liabilities incurred by EQT Gathering, including any third-party claims, arising from the performanceof 80Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LPNOTES TO CONSOLIDATED FINANCIAL STATEMENTSDECEMBER 31, 2012 the agreement, but not to the extent of losses or liabilities caused by EQT Gathering’s gross negligence or willful misconduct. Sunrise Pipeline Lease Agreement As discussed further in Note 7, on June 18, 2012, the Company entered into the Sunrise Pipeline lease agreement with EQT. 4. Income Taxes The Predecessor’s financial statements for the period prior to the IPO include U.S. federal and state income tax as its income was reported andincluded as part of EQT’s consolidated federal tax return. In conjunction with the contribution by EQT of the ownership of Equitrans to the Partnershipimmediately prior to the IPO, approximately $143.6 million of net current and deferred income tax liabilities were eliminated through equity. Effective July 2,2012, as a result of its limited partnership structure, the Company is no longer subject to federal and state income taxes. For federal and state income taxpurposes, all income, expenses, gains, losses and tax credits generated flow through to the owners, and accordingly, do not result in a provision for incometaxes for the Company. The components of the federal income tax expense (benefit) for the years ended December 31, 2012, 2011 and 2010 are as follows: Years Ended December 31,201220112010(Thousands)Current:Federal$3,734$6,473$1,962State2,6992,0261,163Subtotal6,4338,4993,125Deferred:Federal6,5779,8498,782State2122,6572,333Subtotal6,78912,50611,115Amortization of deferred investment tax credit(91)(198)(210)Total$13,131$20,807$14,030 Prior to the IPO, tax obligations were transferred to EQT. EQT’s consolidated federal income tax was allocated among the group’s members on aseparate return basis with tax credits allocated to the members generating the credits. Income tax expense differed from amounts computed at the federal statutory rate of 35% on pre-tax book income from continuing operations asfollows: Years Ended December 31,201220112010(Thousands)Tax at statutory rate$23,953$18,689$11,645Partnership income not subject to income taxes(11,221)——State income taxes1,8923,0442,272Regulatory assets(1,323)(1,057)21Other(170)13192Income tax expense$13,131$20,807$14,030 Effective tax rate19.2%39.0%42.2% 81Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LPNOTES TO CONSOLIDATED FINANCIAL STATEMENTSDECEMBER 31, 2012 For the years ended December 31, 2012, 2011 and 2010, the effective tax rates were 19.2%, 39.0%, and 42.2%, respectively. The lower rates in 2012and 2011 were primarily the result of an increased benefit to equity AFUDC and during 2012, not recognizing taxes on the Company’s post-IPO income whichis not subject to tax. The following table reconciles the beginning and ending amount of reserve for uncertain tax positions (excluding interest and penalties): Years Ended December 31,201220112010(Thousands)Beginning Balance$1,903$2,044$1,953Additions for the current year—15581Additions for the prior year—59—Reductions for the prior years(1,903)(215)(490)Settlements and statute expiration———Ending Balance$—$1,903$2,044 Uncertain tax positions in the prior years were transferred to EQT in 2012 in connection with the IPO and the elimination of all current and deferredtaxes. In accounting for uncertainty in income taxes prior to the IPO, EQT utilized a recognition threshold and measurement attribute for the financialstatement recognition and measurement of a tax position taken or expected to be taken in a tax return. Included in the tabular reconciliation above atDecember 31, 2011 and 2010 are $1.7 million and $1.9 million, respectively, for tax positions for which the ultimate deductibility is highly certain but forwhich there is uncertainty about the timing of such deductibility. Because of the impact of deferred tax accounting, other than interest and penalties, thedisallowance of the shorter deductibility period would not affect the annual effective tax rate but would accelerate the payment of cash to the taxing authority toan earlier period. The Company recognized interest and penalties accrued related to unrecognized tax benefits in income tax expense. Interest of $0.3 million isincluded in unrecognized tax benefits at December 31, 2011 and 2010. The total amount of unrecognized tax benefits, inclusive of interest, was $2.2 millionand $2.4 million as of December 31, 2011 and 2010, respectively, and is included in other long-term liabilities on the balance sheet. The total amount ofunrecognized tax benefits (excluding interest and penalties) that, if recognized, would affect the effective tax rate was $0.2 million and $0.1 million as ofDecember 31, 2011 and 2010. There were no material changes to EQT’s methodology for determining unrecognized tax benefits during 2011 or 2010. The following table summarizes the source and tax effects of temporary differences between financial reporting and tax basis of assets and liabilities: December 31,20122011(Thousands)Deferred income taxes:Total deferred income tax assets$—$(4,590)Total deferred income tax liabilities—114,620Total net deferred income tax liabilities$—$110,030 Total deferred income tax (assets)/liabilities:PP&E tax deductions in excess of book deductions$—$105,104Regulatory temporary differences—9,516Postretirement benefits—(1,813)Other—(2,777)Total net deferred income tax liabilities (including amounts classified as current (assets) of $(1,513) in2011)$—$110,030 82Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LPNOTES TO CONSOLIDATED FINANCIAL STATEMENTSDECEMBER 31, 2012 At December 31, 2011, there was no valuation allowance relating to deferred tax assets as the entire balance was expected to be realized. The deferredtax liabilities principally consisted of temporary differences between financial and tax reporting for property, plant and equipment (PP&E) and regulatoryassets. Included in the deferred income taxes and investment tax credits on the consolidated balance sheets are investment tax credits of $0.7 million atDecember 31, 2011. Under the omnibus agreement, EQT has indemnified the Company from and against any losses suffered or incurred by the Company and related toor arising out of or in connection with any federal, state or local income tax liabilities attributable to the ownership or operation of the Partnership Assets (asdefined in the Partnership Agreement) prior to the closing of the IPO. Therefore, the Company does not anticipate any future liabilities arising from thehistorical deferred tax liabilities. 5. Regulatory Assets The following table summarizes the Company’s regulatory assets, net of amortization, as of December 31, 2012 and 2011. The regulatory assets arerecoverable or reimbursable over various periods. The Company believes that it will continue to be subject to rate regulation that will provide for the recovery ofits regulatory assets. December 31,20122011(Thousands)Deferred taxes$14,309$11,532Post-retirement benefits other than pensions3,2363,994Other recoverable costs3322,721Total regulatory assets$17,877$18,247 The regulatory asset associated with deferred taxes primarily represents deferred income taxes recoverable through future rates related to a deferred taxposition that existed at the time of normalization and the equity component of AFUDC. The Company expects to recover the amortization of the deferred taxposition ratably over the corresponding life of the underlying assets that created the difference. The deferred tax regulatory asset associated with AFUDC represents the offset to the deferred taxes associated with the equity component of theallowance for funds used during the construction of long-lived assets. Taxes on capitalized funds used during construction and the offsetting deferred incometaxes will be collected through rates over the depreciable lives of the long-lived assets to which they relate. The amounts established for deferred taxes were generated during the pre-IPO period when the Company was reported and included as part of EQT’sconsolidated federal tax return. Effective July 2, 2012, the Company is a partnership for income tax purposes and no longer subject to federal and stateincome taxes. As a result, the Company will not recognize any additional regulatory assets related to deferred taxes for financial statement purposes afterJuly 2, 2012. The Company defers expenses for on-going post-retirement benefits other than pensions which are subject to recovery in approved rates. Theregulatory asset for other post-retirement benefits other than pensions is expected to be recovered in rates within approximately 3 years. Other recoverable costs primarily represent the recovery of operation and maintenance expenses incurred in connection with the pipeline safetyprogram. The Company has been approved by the FERC to institute an annual surcharge for the tracking and recovery of all costs incurred. The remainingbalance represents the recovery of storage base gas. The Company is entitled to recover certain migrated storage base gas. A regulatory asset was established bymultiplying the recoverable volume of migrated base gas by the average cost of the base gas. The regulatory asset is reduced by the volumes of base gasrecovered through a component of the transmission system retention factor assessed to transmission service customers. The annual surcharge for 2012 issubject to two 83Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LPNOTES TO CONSOLIDATED FINANCIAL STATEMENTSDECEMBER 31, 2012 customer protests. The Company has submitted to FERC a Proposed Stipulation of Agreement which, if approved by FERC, would settle the customerprotests and replace the surcharge with a fixed pipeline safety cost rate. The following regulatory assets do not earn a return on investment: deferred taxes, other post-retirement benefits and base gas migration. 6. Debt Historically, EQT provided financing to the Company directly or indirectly through EQT Capital. Such financing was generally provided throughintercompany term and demand loans that were entered into between EQT Capital and EQT’s subsidiaries. The Company had notes payable due to EQTCapital of $135.2 million as of December 31, 2011. The interest rate on the demand notes was equal to a commercial rate plus 200 basis points. December 31,20122011(Thousands)Demand notes$—$78,1288.057% notes, due July 1, 2012—37,5005.50% notes, due July 1, 2012—9,0005.060% notes, due January 22, 2014—10,607Total long-term debt$—$135,235 On February 3, 2012, the Company refinanced with EQT Capital its intercompany term debt and demand loans into a 10-year term note maturingon February 1, 2022 at an interest rate of 6.01%. Accordingly, since the Company intended and arranged to finance such amounts on a long-term basis, therelated obligations were reflected as long-term debt at December 31, 2011 in the accompanying balance sheet. On June 21, 2012, the term note of $135.2 million was retired. On July 2, 2012, in connection with the IPO, the Company entered into a $350 million credit facility with Wells Fargo Bank, National Association,as administrative agent, and a syndicate of lenders, which will mature on July 2, 2017. The credit facility is available to fund working capital requirementsand capital expenditures, to purchase assets, to pay distributions and to repurchase units and for general partnership purposes. The credit facility has anaccordion feature that allows the Company to increase the available revolving borrowings under the facility by up to an additional $150 million, subject to theCompany’s receipt of increased commitments from existing lenders or new commitments from new lenders and the satisfaction of certain other conditions. Inaddition, the credit facility includes a sublimit up to $35 million for same-day swing line advances and a sublimit up to $150 million for letters of credit.Further, the Company has the ability to request that one or more lenders make term loans to it under the credit facility subject to the satisfaction of certainconditions, which term loans will be secured by cash and qualifying investment grade securities. The Company’s obligations under the revolving portion ofthe credit facility are unsecured. The credit facility contains various covenants and restrictive provisions and also requires maintenance of a consolidated leverage ratio of not morethan 5.00 to 1.00 (or, after the Company obtains an investment grade rating, not more than 5.50 to 1.00 for certain measurement periods following theconsummation of certain acquisitions) and, until the Company obtains an investment grade rating, a consolidated interest coverage ratio of not less than 3.00to 1.00. As of December 31, 2012, the Company was in compliance with all debt provisions and covenants. Loans under the credit facility (other than swing line loans) will bear interest at the Company’s option at either: · a base rate, which will be the highest of (i) the federal funds rate in effect on such day plus 0.50%, (ii) the administrative agent’s prime rate ineffect on such day and (iii) one-month LIBOR plus 1.0%, in each case, plus an applicable margin; or 84Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LPNOTES TO CONSOLIDATED FINANCIAL STATEMENTSDECEMBER 31, 2012 · a fixed period eurodollar rate plus an applicable margin. Swing line loans will bear interest at (i) the base rate plus an applicable margin or (ii) a daily floating eurodollar rate plus an applicable margin. Priorto the Company obtaining an investment grade rating, the applicable margin will vary based upon the Company’s consolidated leverage ratio and, uponobtaining an investment grade rating, the applicable margin will vary based upon the Company’s long term unsecured senior, non-credit-enhanced debt rating. The unused portion of the credit facility will be subject to a commitment fee ranging from (i) 0.25% to 0.35% per annum before the Company obtainsan investment grade rating and (ii) 0.15% to 0.35% per annum upon obtaining an investment grade rating. There were no borrowings outstanding under the credit facility at December 31, 2012. For the year ended December 31, 2012, interest expenseincludes commitment fees of $0.4 million, which averaged approximately 25 basis points in the third and fourth quarter of 2012 to maintain creditavailability under the revolving credit facility. 7. Lease Obligations On June 18, 2012, the Company transferred ownership of the Sunrise Pipeline, which was under construction at the time and placed into service onJuly 28, 2012, to EQT. Concurrent with the transfer, the Company entered into a capital lease with EQT for the lease of the Sunrise Pipeline. Under thecapital lease, the Company operates the pipeline as part of its transmission and storage system under the rates, terms, and conditions of its FERC-approvedtariff. While the lease agreement was effective June 18, 2012, no lease payments were due pursuant to this lease agreement until the Sunrise Pipeline wasplaced into service. The lease payment due each month following the in-service date, is the lesser of the following alternatives: (1) a revenue-based paymentreflecting the revenues generated by the operation of the Sunrise Pipeline minus the actual costs of operating the Sunrise Pipeline and (2) a payment based ondepreciation expense and pre-tax return on invested capital for the Sunrise Pipeline. As a result, the payments to be made under the Sunrise Pipeline lease willbe variable and are not expected to have a net positive or negative impact on distributable cash flow. Management determined that the Sunrise Pipeline lease was a capital lease as the present value of the estimated minimum lease payments exceeded thefair value of the leased property. Thus, the gross capital lease assets and obligations recorded in 2012 were approximately $216 million, which represented thecosts incurred to construct the pipeline to date and was estimated to be the fair value of the leased property. Additional closeout construction costs will beincurred by EQT which should also increase the fair value. Completion of the pipeline closeout construction is anticipated to continue into the first quarter of2013. Once closeout construction is complete, management will finalize the estimate of the fair value of the asset and will revise the estimates of the leaseobligation and related asset as necessary. Currently, management expects that the fair value of the asset will be approximately $225 million once closeoutconstruction is complete. For the year ended December 31, 2012, interest expense of $6.9 million and depreciation expense of $7.1 million were recorded related to this capitallease. At December 31, 2012, accumulated depreciation was $7.1 million, net capital lease assets were $208.6 million and capital lease obligations were$212.8 million. Additionally, Sunrise Pipeline lease payments related to 2012 were $10.3 million. The following is a schedule of the estimated future minimum lease payments under the capital lease together with the present value of the netminimum lease payments as of December 31, 2012: 85Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LPNOTES TO CONSOLIDATED FINANCIAL STATEMENTSDECEMBER 31, 2012 Year endingDecember 31,(Thousands)2013$25,368201425,588201525,588201625,588201725,588Later years214,739Total minimum lease payments(a)$342,459Less: Amount representing interest(b)(129,617)Present value of net minimum lease payments$212,842 (a) There were no amounts representing contingent rentals or executory costs (such as taxes, maintenance and insurance) included in the total minimumlease payments.(b) Amount necessary to reduce net minimum lease payments to the fair value of the property at December 31, 2012 as the present value calculated at theCompany’s incremental borrowing rate exceeded the fair value of the property at inception of the lease. 8. Pension and Other Postretirement Benefit Plans The personnel who operate the Company’s assets are employees of EQT. EQT directly charges the Company for the payroll and benefit costsassociated with its employees and for retirees of Equitrans. EQT carries the obligations for pension and other employee-related benefits in its financialstatements. Equitrans’ retirees participate in a defined benefit pension plan that is sponsored by EQT. For the years ended December 31, 2012, 2011 and 2010,the Company reimbursed approximately $0.3 million, $0.3 million and $0.1 million, respectively, to the plan sponsor in order to meet certain funding targets.The Company expects to make cash payments to EQT of approximately $0.2 million in 2013 to reimburse for defined benefit pension plan funding. Pensionplan contributions are designed to meet minimum funding requirements and keep plan assets at least equal to 80% of projected liabilities. The Company’sreimbursements to EQT are based on the proportion of the plan’s total liabilities allocable to Equitrans retirees. For the years ended December 31, 2012, 2011and 2010, the Company was allocated $0.1 million per year of the expenses associated with the plan. The dollar amount of a cash reimbursement to the plansponsor in any particular year will vary as a result of gains or losses sustained by the pension plan assets during the year due to market conditions. TheCompany does not expect the variability of contribution requirements to have a significant effect on its business, financial condition, results of operations,liquidity or ability to make distributions. The Company contributes to a defined contribution plan sponsored by EQT. The contribution amount is a percentage of each individual’s basesalary to an individual investment account for such individual. The amount of such contributions was $0.1 million in 2010. In 2011 and 2012, there were nodirect contributions but the Company was charged through the EQT payroll and benefit costs discussed in Note 3. The individuals who operate the Company’s assets and Equitrans retirees participate in certain other post-employment benefit plans sponsored byEQT. The Company was allocated $0.3 million, $0.3 million and $0.4 million in 2012, 2011 and 2010, respectively, of the expenses associated with theseplans. Under the July 1, 2005 Equitrans rate case settlement, the Company began amortizing post-retirement benefits other than pensions previouslydeferred over a five-year period. Currently, the Company recognizes expenses for ongoing post-retirement benefits other than pensions, which are now subjectto recovery in the approved rates. Expenses recognized by the Company for the year ended December 31, 2010 for amortization of post-retirement benefits otherthan pensions previously deferred were approximately $0.7 million. The previously deferred amounts were fully amortized in 2010. Expenses recognized bythe Company for the years ended December 31, 2012, 2011 and 2010 for ongoing post-retirement benefits other than pensions were approximately $1.2 millionper year. 86Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LPNOTES TO CONSOLIDATED FINANCIAL STATEMENTSDECEMBER 31, 2012 9. Fair Value of Financial Instruments The carrying value of cash equivalents and demand notes approximates fair value due to the short maturity of the instruments; these are consideredLevel 1 fair value measurements. The estimated fair value of the notes payable—affiliate on the accompanying balance sheets at December 31, 2011 wasapproximately $155 million. The fair value was estimated using an income approach model based on market rates reflective of the remaining maturity andrisk and, as a result, was considered a Level 2 fair value measurement. 10. Net Income per Limited Partner Unit and Cash Distributions Net income per limited partner unit is calculated utilizing the two-class method by dividing the limited partner interest in net income earned from theclose of the IPO by the weighted average number of limited partner units outstanding during the period. The limited partner interest in net income is determinedby first allocating net income (earned from the close of the IPO) to the general partner based upon the general partner’s ownership interest of 2%. The commonunits issued during the period are included on a weighted-average basis for the days in which they were outstanding. Diluted net income per limited partner unit reflects the potential dilution that could occur if securities or other agreements to issue common units,such as the performance awards, were exercised, settled or converted into common units. As of December 31, 2012 the performance condition was met for theperformance awards. The phantom units vested upon grant and the value of the phantom units will be paid in common units on the earlier of the director’sdeath or retirement from the general partner’s Board of Directors. As such, both awards were included in the diluted net income per limited partner unitcalculation. When it is determined that potential common units resulting from an award subject to performance or market conditions should be included in thediluted net income per limited partner unit calculation, the impact is reflected by applying the treasury stock method. The weighted-average number of unitsused to calculate diluted net income per limited partner unit for the period of July 2, 2012 through December 31, 2012 includes the effect of 4,780 phantomunits and 50,158 performance awards. The following table presents the Company’s calculation of net income per unit for common and subordinated limited partner units: July 2, 2012 toDecember 31, 2012(Thousands, exceptper unit data) Net income (from close of the IPO on July 2, 2012 to December 31, 2012)$32,060Less general partner interest in net income(640)Limited partner interest in net income$31,420 Net income allocable to common units$15,710Net income allocable to subordinated units15,710Limited partner interest in net income$31,420 Weighted average limited partner units outstanding – basicCommon units17,340Subordinated units17,339Total34,679 87Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LPNOTES TO CONSOLIDATED FINANCIAL STATEMENTSDECEMBER 31, 2012 July 2, 2012 toDecember 31, 2012(Thousands, exceptper unit data)Weighted average limited partner units outstanding – dilutedCommon units17,395Subordinated units17,339Total34,734 Net income per limited partner unit – basicCommon units$0.91Subordinated units$0.91 Net income per limited partner unit – dilutedCommon units$0.90Subordinated units$0.90 Net income per limited partner unit data is presented only for the period since the Company’s IPO on July 2, 2012. See Note 1 for further discussionof the IPO. The partnership agreement requires that, within 45 days after the end of each quarter, beginning with the quarter ended September 30, 2012, theCompany distribute all of its available cash (described below) to unitholders of record on the applicable record date. The first quarterly cash distribution of$0.35 per unit was declared on October 23, 2012, paid on November 14, 2012 to unitholders of record on November 5, 2012. As further discussed in Note15, a quarterly cash distribution was declared on January 22, 2013 and paid on February 14, 2013 to unitholders of record on February 4, 2013. Available cash Available cash generally means, for any quarter, all cash and cash equivalents on hand at the end of that quarter: · less, the amount of cash reserves established by the Company’s general partner to: – provide for the proper conduct of the Company’s business (including reserves for future capital expenditures, anticipated future debtservice requirements and refunds of collected rates reasonably likely to be refunded as a result of a settlement or hearing related toFERC rate proceedings or rate proceedings under applicable law subsequent to that quarter); – comply with applicable law, any of the Company’s debt instruments or other agreements; or – provide funds for distributions to the Company’s unitholders and to the Company’s general partner for any one or more of the nextfour quarters (provided that the Company’s general partner may not establish cash reserves for distributions if the effect of theestablishment of such reserves will prevent the Company from distributing the minimum quarterly distribution on all common unitsand any cumulative arrearages on such common units for the current quarter); · plus, if the Company’s general partner so determines, all or any portion of the cash on hand on the date of determination of available cash forthe quarter resulting from working capital borrowings made subsequent to the end of such quarter. 88Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LPNOTES TO CONSOLIDATED FINANCIAL STATEMENTSDECEMBER 31, 2012 Subordinated Units All subordinated units are held by EQT. The partnership agreement provides that, during the period of time referred to as the “subordinationperiod,” the common units will have the right to receive distributions of available cash from operating surplus each quarter in an amount equal to $0.35 percommon unit, which amount is defined in the partnership agreement as the minimum quarterly distribution, plus any arrearages in the payment of theminimum quarterly distribution on the common units from prior quarters, before any distributions of available cash from operating surplus may be made onthe subordinated units. The practical effect of the subordinated units is to increase the likelihood that during the subordination period there will be availablecash to distribute the minimum quarterly distribution to the common units. The subordination period will end, and the subordinated units will convert tocommon units, on a one-for-one basis, when certain distribution requirements, as defined in the partnership agreement, have been met. The earliest date atwhich the subordination period may end is June 30, 2013. Incentive Distribution Rights All incentive distribution rights are held by the Company’s general partner. Incentive distribution rights represent the right to receive an increasingpercentage (13.0%, 23.0% and 48.0%) of quarterly distributions of available cash from operating surplus after the minimum quarterly distribution and thetarget distribution levels described below have been achieved. The Company’s general partner may transfer the incentive distribution rights separately from itsgeneral partner interest, subject to restrictions in the partnership agreement. The following discussion assumes that the Company’s general partner continues to own both its 2.0% general partner interest and the incentivedistribution rights. If for any quarter: · the Company has distributed available cash from operating surplus to the common and subordinated unitholders in an amount equal to theminimum quarterly distribution; and · the Company has distributed available cash from operating surplus on outstanding common units in an amount necessary to eliminate anycumulative arrearages in payment of the minimum quarterly distribution; then, the Company will distribute any additional available cash from operating surplus for that quarter among the unitholders and the Company’sgeneral partner in the following manner: · first, 98.0% to all unitholders, pro rata, and 2.0% to the Company’s general partner, until each unitholder receives a total of $0.4025 per unitfor that quarter (the “first target distribution”); · second, 85.0% to all unitholders, pro rata, and 15.0% to the Company’s general partner, until each unitholder receives a total of $0.4375 perunit for that quarter (the “second target distribution”); · third, 75.0% to all unitholders, pro rata, and 25.0% to the Company’s general partner, until each unitholder receives a total of $0.5250 perunit for that quarter (the “third target distribution”); and · thereafter, 50.0% to all unitholders, pro rata, and 50.0% to the Company’s general partner. 11. Equity-Based Compensation Plans Equity-based compensation expense recorded by the Company was as follows: Years Ended December 31,201220112010(Thousands) Performance Awards$419$—$—Phantom Units116——Total equity-based compensation expense$535$—$— 89Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LPNOTES TO CONSOLIDATED FINANCIAL STATEMENTSDECEMBER 31, 2012 At the closing of the IPO on July 2, 2012, the Company’s general partner granted to its executive officers and certain other EQT employees,including its non-independent director who is not also an executive officer, performance awards representing 146,490 common units. The performancecondition related to the grant of performance awards will be satisfied on December 31, 2015 if the total unitholder return realized on the Company’s commonunits from the date of grant is at least 10%, including the value of distributions received during this period. If the unitholder return measure is not achieved asof December 31, 2015, the performance condition will nonetheless be satisfied if the 10% unitholder return threshold is satisfied as of the end of any calendarquarter ending after December 31, 2015 and on or before December 31, 2017. If earned, the units are expected to be distributed in Company common units. The Company accounted for these awards as equity awards using the $20.02 grant date fair value as determined using a fair value model. Themodel projected the unit price for Company common units at the ending point of the performance period. The price was generated using annual historicalvolatility of peer-group companies for the expected term of the awards, which is based upon the performance period. The range of expected volatilitiescalculated by the valuation model was 26.84% - 71.94%, and the weighted-average expected volatility was 38.2%. Additional assumptions included the risk-free rate for periods within the contractual life of the awards based on the U.S. Treasury yield curve in effect at the time of grant, and an expected dividendgrowth rate of 10%. Adjusting for forfeitures, as of December 31, 2012 there were 146,490 performance awards outstanding. As of December 31, 2012, therewas $2.5 million of total unrecognized compensation cost related to nonvested performance awards; which is expected to be recognized over a period of 3years. Additionally, the Company’s general partner granted 4,780 equity-based phantom units to the independent directors of its general partner, whichawards vested upon grant. The value of the phantom units will be paid in common units on the earlier of the director’s death or retirement from the generalpartner’s Board of Directors. The Company accounts for these awards as equity awards and recorded compensation expense for the fair value of the awardsat the grant date fair value. Common units to be delivered pursuant to vesting of the equity based awards may be common units acquired by EQM’s general partner in the openmarket, from any other person, directly from EQM or any combination of the foregoing. See also Note 3 for discussion of the EQT long-term incentive plan for periods prior to the IPO. 12. Concentrations of Credit Risk The Company’s transmission and storage and gathering operations include FERC-regulated interstate pipelines and storage service for Equitable GasCompany, LLC, a subsidiary of EQT Corporation, as well as other utility and end users customers located in the northeastern United States. The Companyalso provides service to customers engaged in commodity procurement and delivery, including large industrial, utility, commercial and institutional customersand certain marketers primarily in the Appalachian and mid-Atlantic regions. Approximately 87% and 49% of third party accounts receivable balances of $3.7 million and $5.1 million as of December 31, 2012 and 2011,respectively, represent amounts due from marketers. The Company manages the credit risk of sales to marketers by limiting the Company’s dealings to thosemarketers who meet specified criteria for credit and liquidity strength and by actively monitoring these accounts. The Company may request a letter of credit,guarantee, performance bond or other credit enhancement from a marketer in order for that marketer to meet the Company’s credit criteria. The Company didnot experience any significant defaults on accounts receivable during the years ended December 31, 2012, 2011 and 2010. 13. Commitments and Contingencies The Company is subject to federal, state and local environmental laws and regulations. These laws and regulations, which are constantly changing,can require expenditures for remediation and in certain instances result in assessment of fines. The Company has established procedures for ongoingevaluation of its operations to identify potential environmental exposures and assure compliance with regulatory policies and procedures. The estimated 90Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LPNOTES TO CONSOLIDATED FINANCIAL STATEMENTSDECEMBER 31, 2012 costs associated with identified situations that require remedial action are accrued. However, when recoverable through regulated rates, certain of these costs aredeferred as regulatory assets. Ongoing expenditures for compliance with environmental law and regulations, including investments in plant and facilities tomeet environmental requirements, have not been material. Management believes that any such required expenditures will not be significantly different in eithernature or amount in the future and does not know of any environmental liabilities that will have a material effect on its business, financial condition, results ofoperations, liquidity or ability to make distributions. In the ordinary course of business, various legal and regulatory claims and proceedings are pending or threatened against the Company. While theamounts claimed may be substantial, the Company is unable to predict with certainty the ultimate outcome of such claims and proceedings. The Companyaccrues legal or other direct costs related to loss contingencies when actually incurred. The Company has established reserves it believes to be appropriate forpending matters and after consultation with counsel and giving appropriate consideration to available insurance, the Company believes that the ultimateoutcome of any matter currently pending against the Company will not materially affect the business, financial condition, results of operations, liquidity orability to make distributions. The Company may recover the costs it incurs to comply with the Pipeline Safety Improvement Act of 2002 by seeking annual approval of such costsfrom the FERC. The Company’s filing for approval of its 2011 costs was made on March 1, 2012 and is pending subject to two protests. For a period of fiveyears after the closing of the IPO, EQT will reimburse the Company for the amount of qualifying pipeline safety costs that are not recovered through theannual pipeline safety cost tracker. The Company has submitted to FERC a Proposed Stipulation of Agreement which, if approved, would settle the customerprotests and replace the surcharge with a fixed pipeline safety cost rate. 14. Interim Financial Information (Unaudited) The following quarterly summary of operating results reflects variations due primarily to growth in the transmission and storage business and theseasonal nature of the Company’s utility customer contracts. Three months endedMarch 31June 30September 30December 31(Thousands, except per share amounts)2012 (a)Total operating revenues$31,003$29,665$34,452$41,790Operating income16,39215,99914,29724,003Net income11,12312,01212,01120,160Net income per limited partner unit (b):BasicN/AN/A$0.34$0.57DilutedN/AN/A$0.34$0.57 2011 (a)Total operating revenues$26,626$25,179$27,420$30,388Operating income15,0968,73214,00716,785Net income8,6354,9408,38110,633Net income per limited partner unit (b):BasicN/AN/AN/AN/ADilutedN/AN/AN/AN/A (a) The sum of the quarterly data in some cases may not equal the yearly total due to rounding.(b) Presented for post-IPO period only. 91Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT MIDSTREAM PARTNERS, LPNOTES TO CONSOLIDATED FINANCIAL STATEMENTSDECEMBER 31, 2012 15. Subsequent Events On January 22, 2013, the Company announced that the Board of Directors of its general partner declared a cash distribution to the Company’sunitholders of $0.35 per unit for the fourth quarter of 2012. The cash distribution was paid on February 14, 2013 to unitholders of record at the close ofbusiness on February 4, 2013. 92Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure Not Applicable. Item 9A. Controls and Procedures Evaluation of Disclosure Controls and Procedures Under the supervision and with the participation of management of the Company’s general partner, including the general partner’s PrincipalExecutive Officer and Principal Financial Officer, an evaluation of the Company’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (Exchange Act)), was conducted as of the end of the period covered by this report. Based uponthis evaluation, the Chief Executive Officer and Chief Financial Officer of the Company’s general partner have concluded that the Company’s disclosurecontrols and procedures were effective as of the end of the period covered by this report. Changes in Internal Control over Financial Reporting There were no changes in internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act)that occurred during the fourth quarter of 2012 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control overfinancial reporting. Management’s Report on Internal Control over Financial Reporting This annual report does not include a report of management’s assessment regarding internal control over financial reporting or an attestation report ofthe Company’s independent registered public accounting firm due to a transition period established by the rules of the Securities and Exchange Commissionfor newly public companies. Item 9B. Other Information Not Applicable. 93Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. PART III Item 10. Directors, Executive Officers and Corporate Governance Directors and Executive Officers of the Company’s General Partner The Company is managed and operated by the directors and officers of its general partner, EQT Midstream Services, LLC. The directors of theCompany’s general partner are appointed by EQT, and unitholders are not entitled to elect the directors of the general partner or directly or indirectly participatein the Company’s management or operations. The board of directors of the Company’s general partner is comprised of six directors, of which two membersare independent as defined under the independence standards established by the NYSE and the Exchange Act. The Company’s general partner intends toincrease the size of the board of directors to seven members by July 2, 2013. When the size of the general partner’s board increases to seven directors, theCompany’s general partner will have three directors who are independent. The NYSE does not require a publicly traded limited partnership like the Companyto have a majority of independent directors on the board of directors of its general partner or to establish a compensation or a nominating and corporategovernance committee. Executive officers of the Company’s general partner manage the day-to-day affairs of the Company’s business and conduct the Company’soperations. All of the executive officers of the Company’s general partner are employees of EQT and devote such portion of their productive time to theCompany’s business and affairs as is required to manage and conduct the Company’s operations. Pursuant to the terms of the omnibus agreement among theCompany, its general partner and EQT, the Company will reimburse EQT for allocated expenses of personnel who perform services for the Company’sbenefit, and the Company will reimburse EQT for allocated general and administrative expenses. Please read Item 13, “Certain Relationships and RelatedTransactions, and Director Independence – Agreements with EQT – Omnibus Agreement.” The executive officers and directors of the Company’s general partner as of February 21, 2013 are as follows: NameAgePosition with EQT Midstream Services, LLCDavid L. Porges55Chairman, President and Chief Executive OfficerPhilip P. Conti53Director, Senior Vice President and Chief Financial OfficerRandall L. Crawford50Director and Executive Vice PresidentLewis B. Gardner55DirectorTheresa Z. Bone49Vice President and Principal Accounting OfficerJulian M. Bott50DirectorMichael A. Bryson66Director Mr. Porges was appointed as Chairman of the Board and as President and Chief Executive Officer of the Company’s general partner inJanuary 2012. Mr. Porges is currently the Chairman, President and Chief Executive Officer of EQT and has held such positions since May 2011. Mr. Porgeswas President, Chief Executive Officer and Director of EQT from April 2010 through May 2011 and President, Chief Operating Officer and Director of EQTfrom February 2007 through April 2010. Mr. Porges has served as a member of EQT’s board since May 2002. Mr. Porges brings extensive business, leadership, management and financial experience, and tremendous knowledge of the Company’s operations,culture and industry, to the board. Mr. Porges has served in a number of senior management positions since joining EQT as Senior Vice President and ChiefFinancial Officer in 1998. He has also served as a member of EQT’s board since May 2002. Prior to joining EQT, Mr. Porges held various senior positionswithin the investment banking industry and also held several managerial positions with Exxon Corporation (now, Exxon Mobil corporation, an internationaloil and gas company). Mr. Porges served on the board of directors of Westport Resources Corp. (oil and natural gas production company) from April 2000through 2004. Mr. Porges’ strong financial and industry experience, along with his understanding of the Company’s business operations and culture, enableMr. Porges to provide unique and valuable perspectives on most issues facing the Company. Mr. Conti was appointed as a director and as Senior Vice President and Chief Financial Officer of the Company’s general partner in January 2012.Mr. Conti is currently the Senior Vice President and Chief Financial Officer of EQT and has held such positions since February 2007. 94Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Mr. Conti brings significant energy industry management, finance and corporate development experience to the board. Since joining EQT in 1996,Mr. Conti has served in a number of finance, business planning and business development senior management positions. Prior to joining EQT, Mr. Conti wasvice president in the natural resources department at PNC Bank from 1992 to 1996. Previously, he was a banking officer in the energy and utilitiesdepartment of Mellon Bank, N.A., and before that, senior production engineer at Tenneco Oil Company. Given his experience as Senior Vice President andChief Financial Officer of EQT, Mr. Conti has a thorough understanding of the Company’s capital structure and financing requirements, enabling him toprovide leadership to the board in these areas. Mr. Conti also brings valuable industry financial expertise from his prior role as an energy industry banker,including experience with capital markets transactions. Mr. Crawford was appointed as a director and as Executive Vice President of the Company’s general partner in January 2012. Mr. Crawford iscurrently the Senior Vice President and President, Midstream, Commercial and Distribution of EQT and has held such positions since April 2010.Mr. Crawford was Senior Vice President and President, Midstream and Distribution from January 2008 to April 2010. Mr. Crawford brings deep business, senior management and technical industry experience and in-depth knowledge of the Company’s businessoperations to the board. Since 2007, Mr. Crawford has served as President of EQT’s midstream operations, including the Company’s operations. In this role,Mr. Crawford is responsible for executing the growth strategy for EQT’s natural gas midstream and production marketing companies operating in the rapidlygrowing Marcellus Shale natural gas supply region. Prior to joining EQT, Mr. Crawford held various financial and regulatory management positions withConsolidated Natural Gas Company in Pittsburgh, and started his career with Price Waterhouse LLC Utility Services Practice. Mr. Crawford’s extensiveunderstanding of the Company’s assets and operations enables him to bring valuable perspectives to the board, particularly with respect to setting andimplementing the Company’s business strategy. Mr. Gardner was appointed as a director of the Company’s general partner in January 2012. Mr. Gardner is currently the General Counsel andVice President, External Affairs of EQT and has held such positions since April 2008. From January 2008 to March 2008, Mr. Gardner was ManagingDirector, External Affairs and Labor Relations of EQT. In his current role with EQT, Mr. Gardner oversees legal and external affairs, which includes the safety and environmental, governmental relationsand corporate communications functions. Prior to joining EQT in 2003, Mr. Gardner was a partner in the Houston and Austin, Texas offices of Brown,McCarroll & Oaks Hartline, general counsel to General Glass International Corp., a privately held glass manufacturing and trading company, and seniorcounsel, Employment Law with Northrop Grumman (formerly TRW, Inc.). Mr. Gardner’s experiences enable him to provide insight to the board with respectto legal and external affairs issues, along with providing valuable perspectives with respect to business management and corporate governance issues. Ms. Bone was appointed as Vice President and Principal Accounting Officer of the Company’s general partner in January 2012. Ms. Bone iscurrently the Vice President and Corporate Controller of EQT and has held such positions since July 2007. Mr. Bott was appointed as a director of the Company’s general partner in May 2012. Mr. Bott is currently the Chief Financial Officer of TexasAmerican Resources Company, a privately held oil and gas acquisition, exploration and production company, and has held such position sinceDecember 2009. From December 2008 to November 2009, Mr. Bott served as an advisor to Kensington Energy Partners, which is a firm that advised energycompanies and their stakeholders on financial and operational restructuring transactions. From January 2005 to December 2008, Mr. Bott was a principal andChief Financial Officer of 3DMD Technologies LTD, a company specializing in 3D data capturing technology and related applications for the biometric andmedical industries. Prior to that, Mr. Bott held various senior energy industry focused positions within the investment banking industry. Mr. Bott has significant experience in energy company senior management, finance and corporate development. Mr. Bott is able to draw upon hisdiverse senior management and investment banking experience to provide guidance with respect to accounting matters, financial markets, financingtransactions and energy company operations. 95Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Mr. Bryson was appointed as a director of the Company’s general partner in May 2012. Mr. Bryson retired in June 2008 as Executive Vice Presidentof The Bank of New York Mellon Corporation, a financial services firm. He obtained such position in July 2007 following the merger of Mellon FinancialCorporation and The Bank of New York. Prior to the merger, Mr. Bryson served in various senior management positions over a 33-year career with MellonFinancial Corporation, including his service as Executive Vice President and Chief Financial Officer from December 2001 to June 2007. Mr. Bryson brings to the board over three decades of management and financial experience, having served as Treasurer and Chief Financial Officerof a large publicly traded financial institution. In these roles, Mr. Bryson obtained a wealth of experience related to financial statement preparation, auditingand accounting matters, financial markets, financing transactions and investor relations. Meetings of Non-Management Directors and Communications with Directors At least annually, all of the independent directors of the Company’s general partner meet in executive session without management participation orparticipation by non-independent directors. Mr. Bryson, as the Chair of the audit committee, serves as the presiding director for such executive sessions. Thepresiding director may be contacted by mail or courier service c/o EQT Midstream Services, LLC, 625 Liberty Avenue, Suite 1700, Pittsburgh,Pennsylvania 15222, Attn: Presiding Director or by email at presidingdirector@eqtmidstreampartners.com. Committees of the Board of Directors The board of directors of the Company’s general partner has two standing committees: an audit committee and a conflicts committee. Audit Committee The NYSE does not require a publicly traded limited partnership like the Company to have a majority of independent directors on the board ofdirectors of its general partner or to establish a compensation or a nominating and corporate governance committee. The Company’s general partner is,however, required to have an audit committee of at least three members within twelve months of the date the Company’s common units were first traded on theNYSE (which was June 27, 2012), and all of the audit committee members must meet the independence and experience requirements established by the NYSEand the Exchange Act by such date. The audit committee is comprised of Messrs. Bryson (Chairman), Bott and Conti. Messrs. Bryson and Bott satisfy the independence requirementsestablished by the NYSE and the Exchange Act. Each member of the audit committee is financially literate. Additionally, the board of directors of theCompany’s general partner has determined that each member of the audit committee qualifies as an “audit committee financial expert” as such term is definedunder the SEC’s regulations. This designation is a disclosure requirement of the SEC related to each audit committee members’ experience and understandingwith respect to certain accounting and auditing matters. The designation does not impose upon the audit committee members any duties, obligations orliabilities that are greater than those generally imposed on them as members of the audit committee and the board of directors of the Company’s general partner. As audit committee financial experts, each member of the audit committee also has the accounting or related financial management expertise required by theNYSE rules. The audit committee assists the board of directors of the Company’s general partner in its oversight of the integrity of the Company’s financialstatements and compliance with legal and regulatory requirements and corporate policies and controls. The audit committee has the sole authority to retain andterminate the Company’s independent registered public accounting firm, approve all auditing services and related fees and the terms thereof, and pre-approveany non-audit services to be rendered by the Company’s independent registered public accounting firm. The audit committee is also responsible for confirmingthe independence and objectivity of the Company’s independent registered public accounting firm. Conflicts Committee The conflicts committee is comprised of Messrs. Bott (Chairman) and Bryson. The conflicts committee, upon request by the Company’s generalpartner, determines whether certain transactions, which may be deemed conflicts of interest, are in the best interests of the Company. There is no requirementthat the Company’s general 96Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. partner seek the approval of the conflicts committee for the resolution of any conflict. The members of the conflicts committee may not be officers or employeesof the Company’s general partner or directors, officers or employees of its affiliates, may not hold an ownership interest in the general partner or its affiliatesother than common units or awards under any long-term incentive plan, equity compensation plan or similar plan implemented by the general partner or theCompany, and must meet the independence standards established by the NYSE and the Exchange Act to serve on an audit committee of a board of directors.Any matters approved by the conflicts committee in good faith will be deemed to be approved by all of the Company’s partners and not a breach by theCompany’s general partner of any duties it may owe the Company or its unitholders. Any unitholder challenging any matter approved by the conflictscommittee will have the burden of proving that the members of the conflicts committee did not subjectively believe that the matter was in the best interests ofthe Company. Moreover, any acts taken or omitted to be taken in reliance upon the advice or opinions of experts such as legal counsel, accountants,appraisers, management consultants and investment bankers, where the Company’s general partner (or any members of the board of directors of theCompany’s general partner including any member of the conflicts committee) reasonably believes the advice or opinion to be within such person’s professionalor expert competence, shall be conclusively presumed to have been done or omitted in good faith. Governance Principles The Company has adopted a code of business conduct and ethics that applies to all directors, officers, employees, agents, consultants, contractors,temporary workers, and other personnel of the Company, the Company’s general partner and their respective subsidiaries. The Company will disclose anyfuture amendments to the code of business conduct and ethics that relate to executive officers of the Company’s general partner on the Company’s website, aswell as any waivers of the code of business conduct and ethics that relate to executive officers of the Company’s general partner. The Company maintains a corporate governance page on its website which includes key information about its corporate governance practices,including its corporate governance guidelines, code of business conduct and ethics and audit committee charter. The corporate governance page can be foundat www.eqtmidstreampartners.com, by clicking on the “Investors” link on the main page and then “Governance.” The Company will provide a copy of itscorporate governance guidelines, code of business conduct and ethics and/or audit committee charter upon request by a unitholder to the Corporate Secretary ofthe Company’s general partner by mail or courier service c/o EQT Midstream Services, LLC, 625 Liberty Avenue, Suite 1700, Pittsburgh, Pennsylvania15222, Attn: Corporate Secretary. Section 16(a) Beneficial Ownership Reporting Compliance Section 16(a) of the Exchange Act requires that the directors and executive officers of the Company’s general partner and all persons who beneficiallyown more than 10% of the Company’s common units file initial reports of ownership and reports of changes in ownership of the Company’s common unitswith the SEC. As a practical matter, the Company assists the directors and executive officers of the Company’s general partner by monitoring transactionsand completing and filing Section 16 reports on their behalf. Based solely upon the Company’s review of copies of filings or written representations from the reporting persons, the Company believes that allreports for the executive officers and directors of the Company’s general partner and persons who beneficially own more than 10% of the Company’s commonunits that were required to be filed under Section 16(a) of the Exchange Act in 2012 were filed on a timely basis. Item 11. Executive Compensation Executive Compensation The Company does not directly employ any of the persons responsible for managing its business. The Company is managed and operated by thedirectors and officers of its general partner, EQT Midstream Services, LLC. EQT employs all of the individuals who service the Company, including theexecutive officers of the Company’s general partner, and these individuals devote such portion of their productive time to the Company’s business and affairsas is required to manage and conduct the Company’s operations. The Company reimburses 97Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT for all salaries and related benefits and expenses for the employees of EQT who provide services to the Company pursuant to an allocation agreed uponbetween EQT and the Company under the terms of the omnibus agreement. Please read Item 13, “Certain Relationships and Related Transactions, andDirector Independence – Agreements with EQT – Omnibus Agreement.” The Summary Compensation Table below reflects the total compensation of the principal executive officer and of the two other most highlycompensated executive officers of the Company’s general partner for 2012 (the “named executive officers”) for services rendered to all EQT-related entities,including the Company, EQT Midstream Services, LLC and EQT for the fiscal year ending December 31, 2012. SUMMARY COMPENSATION TABLE NAME AND PRINCIPALPOSITIONYEARSALARYBONUSSTOCKAWARDSOPTIONAWARDSNON-EQUITYINCENTIVE PLANCOMPENSATIONALL OTHERCOMPENSATIONTOTAL($)($)($) (1)($) (2)($) (3)($) (4)($) David L. PorgesChairman, President and Chief Executive Officer2012826,923-4,176,3621,395,5021,996,000314,8938,709,680 Philip P. Conti Senior Vice President and Chief Financial Officer2012400,001-1,151,708427,356730,000144,9912,854,056 Randall L. Crawford Senior Vice President2012436,923-1,707,462590,912820,000161,0553,716,352 _______________ This column reflects the aggregate grant date fair values determined in accordance with ASC Topic 718 for performance units granted under the 2012 EPIPand EQM TR Program (each as defined and described under the caption “Narrative Disclosure to Summary Compensation Table” below), using theassumptions described below. Pursuant to SEC rules, the amounts shown in the Summary Compensation Table for awards subject to performanceconditions are based on the probable outcome as of the date of grant and exclude the impact of estimated forfeitures. The 2012 EPIP is a three year program that provides EQT stock-based awards. Each named executive officer was granted an award under the 2012 EPIPon January 1, 2012. The performance period for the 2012 EPIP is January 1, 2012 through December 31, 2014. The grant date fair values of the awardswere: $3,413,600 for Mr. Porges; $1,044,000 for Mr. Conti; and $1,445,600 for Mr. Crawford. The grant date fair values were computed by multiplyingthe number of units awarded to each named executive officer (42,670 for Mr. Porges; 13,050 for Mr. Conti; and 18,070 for Mr. Crawford) by $80.00, thegrant date fair value of each unit calculated using a Monte Carlo pricing model with the following assumptions: (i) risk-free rate of return: 0.36%;(ii) dividend yield: 0.0597; (iii) volatility: 37.26%; and (iv) term: three years. Assuming, instead, that the highest level of performance conditions wouldbe achieved, the grant date fair values of these awards would have been: $5,834,696 for Mr. Porges; $1,784,457 for Mr. Conti; and $2,470,892 forMr. Crawford. The EQM TR Program is a three and one-half year program (subject to certain quarterly extensions as described under “Stock Awards – EQM TRProgram” under the caption “Narrative Disclosure to Summary Compensation Table” below) that provides Company unit-based awards. Each namedexecutive officer was granted an award on July 2, 2012. The performance period for the EQM TR Program is June 27, 2012 through December 31, 2015(subject to quarterly extensions). The grant date fair values of the awards were: $762,762 for Mr. Porges; $107,708 for Mr. Conti; and $261,862 forMr. Crawford. The grant date fair values were computed by multiplying the number of units awarded to each named executive officer (38,100 forMr. Porges; 5,380 for Mr. Conti; and 13,080 for Mr. Crawford) by $20.02, the grant date fair value of each unit calculated using a Monte 98(1)Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Carlo pricing model with the following assumptions: (i) risk-free rate of return for periods within the contractual life of the awards based on the applicableU.S. Treasury yield curves in effect at the time of the grant; (ii) an expected quarterly distribution of $0.35 per Company common unit for the first yearand assuming annual increases of 10% per annum thereafter; (iii) the annual historical volatility of a peer group of companies for the expected term of theawards (the valuation model calculated a range of expected volatilities of 27% to 72% and a weighted average expected volatility of 38%); and (iv) a term offive years. See “Narrative Disclosure to Summary Compensation Table” below for a further discussion of the 2012 EPIP and the EQM TR Program. This column reflects the grant date fair values of EQT stock option awards issued on January 1, 2012. The grant date fair values of the 2012 EQT stock option awards were calculated by multiplying the number of options awarded to each named executiveofficer (105,800 for Mr. Porges; 32,400 for Mr. Conti; and 44,800 for Mr. Crawford) by $13.19, the grant date fair value of each option calculated using aBlack-Scholes option pricing model with the following assumptions: (i) risk-free rate of return: 0.89%; (ii) dividend yield: 1.64%; (iii) volatility factor:31.44%; and (iv) expected term: five years. See “Option Awards – EQT 2012 Options” under the caption “Narrative Disclosure to Summary Compensation Table” below for further discussion of theEQT 2012 options. This column reflects the dollar value of annual incentive compensation earned under the Executive STIP (as defined and described under the caption“Narrative Disclosure to Summary Compensation Table” below) during 2012. The awards were paid to the named executive officers in cash in the firstquarter of 2013. See “Non-Equity Incentive Plan Compensation – EQT Executive Short-Term Incentive Plan (Executive STIP) under the caption“Narrative Disclosure to Summary Compensation Table” below for further discussion of the Executive STIP for the 2012 plan year. This column includes the dollar value of premiums paid by EQT for group life, accidental death and dismemberment insurance, EQT’s contributions tothe 401(k) plan and the 2006 Payroll Deduction and Contribution Plan and perquisites. For 2012, these amounts were as follows: NAMEINSURANCE($)401(K)CONTRIBUTIONS($)2006PAYROLLDEDUCTIONANDCONTRIBUTIONPLAN($)PERQUISITES(SEE BELOW)($)TOTAL($)David L. Porges2,44822,500247,22342,722314,893Philip P. Conti1,15222,50085,50035,839144,991Randall L. Crawford1,27322,50096,47340,809161,055 Once 401(k) contributions for the named executive officers reach the maximum level permitted under the 401(k) plan or by regulation, EQT contributionsare continued on an after-tax basis under the 2006 Payroll Deduction and Contribution Plan through an annuity program offered by Fidelity InvestmentsLife Insurance Co. In 2012, EQT also contributed an amount equal to 9% of each named executive officer’s 2011 annual incentive award to suchprogram. 99(2)(3)(4)Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. The perquisites EQT provided to each named executive officer in 2012 are itemized below: NAMECARALLOWANCE($)COUNTRYANDDININGCLUBANNUALDUES($)FINANCIALPLANNING($)PARKING($)PHYSICAL($)SEATLICENSES($)TOTALPERQUISITES($)David L. Porges9,18012,98214,9502,6103,000-42,722Philip P. Conti9,0609,20410,1202,6102,9251,92035,839Randall L. Crawford9,06011,91912,3002,6103,0001,92040,809 The car allowance is an amount paid to the executive intended to cover the annual cost of acquiring, maintaining and insuring a car. The entire cost ofcountry and dining club dues has been included in the table although EQT believes that only a portion of the cost represents a perquisite. Financialplanning is the actual cost to EQT of providing to each executive financial planning and tax preparation services. The named executive officers may usetwo tickets purchased by EQT to attend up to four sporting or other events when such tickets are not otherwise being used for business purposes. Thecosts of such tickets used for personal purposes are considered de minimis by EQT and are not included as perquisites in the Summary CompensationTable because there are no incremental costs to EQT associated with such use. In 2012, none of the named executive officers used tickets purchased byEQT to attend sporting or other events in excess of the four event de minimis level. In addition, in 2012, EQT transferred two seat licenses for PittsburghSteelers home games at Heinz Field to each of Messrs. Conti and Crawford. The incremental cost of each seat license to EQT was $960 based on EQT’soriginal acquisition cost of each license. In connection with the Company’s IPO in July 2012, certain individuals, including the named executive officers,were offered the opportunity to purchase Company units through the Company’s directed unit program (DUPP). There were no incremental costs to thecompany associated with the DUPP. NARRATIVE DISCLOSURE TO SUMMARY COMPENSATION TABLE Set forth below is a discussion of the material elements of compensation paid to our named executive officers as reflected in the SummaryCompensation Table. This discussion should be read in conjunction with the Summary Compensation Table above. Base Salary The base salary for each named executive officer reflected in the Summary Compensation Table above is the base salary actually earned and reflectsa proportionate amount of any increase made during the applicable year. Non-Equity Incentive Plan Compensation – EQT Executive Short-Term Incentive Plan (Executive STIP) Early each year, the Management Development and Compensation Committee of EQT (the “MDC Committee”) establishes the performance measurefor determining awards under the Executive STIP. This performance measure establishes the maximum annual incentive award that the Committee mayapprove as “performance-based compensation” for tax purposes pursuant to Code Section 162(m) subject to the shareholder approved individual limit setforth in the Executive STIP but does not set an expectation for the amount of annual incentive that will actually be paid. The MDC Committee is permitted toexercise, and has generally exercised, discretion downward in determining the actual payout under the annual incentive plan. The MDC Committee may notexercise upward discretion. The 2012 performance measure approved for the Executive STIP was the EQT adjusted 2012 EBITDA compared to EQT’s 2012business plan as follows: 100Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. EQT ADJUSTED 2012 EBITDACOMPARED TO BUSINESS PLAN PERCENTAGE OF EQT ADJUSTED2012 EBITDA AVAILABLE FOR ALLEXECUTIVE OFFICER 2012ANNUAL INCENTIVE AWARDS At or above plan2%5% below plan1.5%10% below plan1%Greater than 10% below planNo bonus The percentage of EQT adjusted 2012 EBITDA available for all executive officer bonuses was interpolated between levels and capped at 2%. EQT’sactual adjusted 2012 EBITDA exceeded plan by 3.2%, which allowed the MDC Committee to award annual incentives to EQT’s executive officers in anaggregate amount of $23.5 million, subject to a $5 million cap per executive officer. The MDC Committee exercised its discretion to pay each named executiveofficer a lesser amount based on the individual’s 2012 target award and 2012 performance on EQT, business unit and individual value drivers. The Executive STIP provides that the annual awards will be paid in cash, subject to MDC Committee discretion to pay in equity. The MDCCommittee typically considers settling awards in equity rather than cash only when an executive has not satisfied the applicable equity ownership guidelines. Stock Awards – EQT 2012 Executive Performance Incentive Plan (2012 EPIP) Awards under the 2012 EPIP were granted on January 1, 2012. Each named executive officer was granted an award under the 2012 EPIP. The performance measures for the 2012 EPIP are: · EQT’s total shareholder return (TSR) over the period January 1, 2012 through December 31, 2014, as ranked among the comparably measuredTSR of the applicable peer group; and· cumulative cash flow per share, which is the aggregate net cash provided by operating activities excluding changes in operating assets andliabilities during the performance period, adjusted to reflect a fixed natural gas price of $4.00 per Mcf, divided by the aggregate diluted commonshares of EQT outstanding as of the end of each year in the performance period. The payout opportunity under the 2012 EPIP ranges from: · no payout if EQT is one of the nine lowest-ranking companies in the applicable peer group as to TSR and has a cumulative cash flow per shareover the performance period of less than $15.90;· to target payout if EQT ranks seventeenth to fourteenth in the applicable peer group as to TSR and has a cumulative cash flow per share overthe performance period equal to $19.30;· to three times the target award if EQT is one of the four highest-ranking companies in the applicable peer group as to TSR and has a cumulativecash flow per share over the performance period of at least $27.49. If earned, the EQT share units are expected to be distributed in shares of EQT common stock equal to the target award (including accrueddividends) multiplied by the applicable payout multiple. Stock Awards – EQT Midstream Partners, LP Total Return Program (EQM TR Program) Performance awards under the EQM TR Program, a program adopted under EQT’s 2009 Long-Term Incentive Plan and the EQT MidstreamServices, LLC 2012 Long-Term Incentive Plan, were granted on July 2, 2012. Each named executive officer was awarded performance units under the EQMTR Program. The performance measure for the program is total Company unitholder return of at least 10%, measured from June 27, 2012 through December 31,2015. If the unitholder return measure is not achieved as of 101Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. December 31, 2015, the performance condition will nonetheless be satisfied if the 10% unitholder return threshold is satisfied as of the end of any calendarquarter ending after December 31, 2015 and on or before December 31, 2017. The payout opportunity under the EQM TR Program is: · no payout if the total Company unitholder return is less than 10% over the performance period; or· target payout if the total unitholder return equals or exceeds 10% over the performance period. If earned, the performance awards are expected to be distributed in Company common units equal to the target award (including accrueddistributions). See Item 12, “Securities Authorized for Issuance under Equity Compensation Plans” below for a discussion of the EQT Midstream Services, LLC2012 Long-Term Incentive Plan. Option Awards – EQT 2012 Options Each named executive officer was awarded options for EQT common stock on January 1, 2012 with an exercise price of $54.79. The options areten-year options and vest as follows: 50% vested on January 1, 2013 and 50% will vest on January 1, 2014, contingent upon continued employment withEQT on such date. 102Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. OUTSTANDING EQUITY AWARDS AT FISCAL YEAR-END The following table reflects all outstanding equity awards as of December 31, 2012, including equity awards of both EQT and the Company. OPTION AWARDSEQUITY AWARDS NAMENUMBEROFSECURITIESUNDERLYINGUNEXERCISEDOPTIONSEXERCISABLENUMBEROFSECURITIESUNDERLYINGUNEXERCISEDOPTIONSUNEXERCISABLEOPTIONEXERCISEPRICEOPTIONEXPIRATIONDATENUMBEROFSHARESORUNITSOFSTOCKTHATHAVENOTVESTEDMARKETVALUEOFSHARESOR UNITSOFSTOCKTHATHAVENOTVESTEDEQUITYINCENTIVEPLANAWARDS:NUMBEROFUNEARNEDSHARES,UNITS OROTHERRIGHTSTHATHAVE NOTVESTEDEQUITYINCENTIVEPLANAWARDS:MARKET ORPAYOUTVALUE OFUNEARNEDSHARES,UNITS OROTHERRIGHTSTHAT HAVENOT VESTED(#)(#) (2)($)(#)($)(#) (3)($) (4) David L.Porges95,000109,20057,20076,80038,350-------38,350105,80017.8848.9143.9238.5344.8444.8454.792/27/20138/5/20151/1/20178/2/20171/1/20181/1/20181/1/2022--------------103,485130,38038,569----6,103,5457,689,8121,201,424---- Philip P. Conti56,20027,30014,150-----14,15032,40048.9143.9244.8444.8454.798/5/20151/1/20171/1/20181/1/20181/1/2022----------38,16639,8765,446--2,251,0312,351,886169,643-- Randall L.Crawford87,00021,40019,250-----19,25044,80048.9143.9244.8444.8454.798/5/20151/1/20171/1/20181/1/20181/1/2022----------51,92455,21213,241--3,062,4783,256,404412,457-- _______________ On January 28, 2013, Mr. Porges exercised 95,000 stock options which were scheduled to expire on February 27, 2013. The options reflected in this column are EQT options which vest according to the following schedule: of the options expiring in 2018, 100% were vested asof January 1, 2013 and of the options expiring in 2022, 50% vested on January 1, 2013 and 50% will vest on January 1, 2014. This column reflects performance units awarded but that have not yet vested pursuant to the EQT 2011 Volume and Efficiency Program (the “2011VEP”), the 2012 EPIP and the EQM TR Program (including accrued dividends for the 2011 VEP and 2012 EPIP and accrued distributions for the EQMTR Program). The number of performance units under the 2011 VEP and 2012 EPIP reflects maximum award levels because, through December 31,2012, payout was projected above the target level for each program. The number of performance 103(1)(1)(2)(3)Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. units under the EQM TR Program reflects target award levels because, through December 31, 2012, total Company unitholder return was projected toexceed 10% at the end of the performance period and there is no award level above target for this program. Awards under the 2011 VEP, the 2012 EPIP andthe EQM TR Program do not vest until payment following the end of the respective performance periods. This column reflects the payout values at December 31, 2012 of unearned performance units granted under the 2011 VEP, the 2012 EPIP and the EQMTR Program (including accrued dividends for the 2011 VEP and 2012 EPIP and accrued distributions for the EQM TR Program). The payout values aredetermined by multiplying the number of units as shown in the previous column by $58.98, the closing price of EQT’s common stock on December 31,2012 (or, for the EQM TR Program, by $31.15, the closing price of the Company’s common units on December 31, 2012). The actual payout valuesunder the 2011 VEP and the 2012 EPIP will depend upon EQT’s actual performance through, and its stock price at the end of, the applicable performanceperiods. The actual payout values under the EQM TR Program will depend upon the Company’s actual performance through, and the Company’scommon unit price at the end of, the program’s performance period. Retirement Benefits The executive officers of the Company’s general partner participate in employee benefit plans and arrangements sponsored by EQT. Neither theCompany nor its general partner currently offers any deferred compensation program or any supplemental executive retirement plan to any of the executiveofficers of the Company’s general partner. EQT provides full discussion of these plans and arrangements in its filings with the SEC, including its annualproxy statement relating to the annual meeting of the shareholders of EQT, which are available on the SEC’s website at www.sec.gov and on EQT’s website atwww.EQT.com on the “SEC Filings” page under the “Investors Relations” tab. The secretary of our general partner will also provide a copy to you free ofcharge upon request. POTENTIAL PAYMENTS UPON TERMINATION OR CHANGE OF CONTROL EQT Midstream Services, LLC 2012 Long-Term Incentive Plan The EQT Midstream Services, LLC 2012 Long-Term Incentive Plan provides for certain rights upon the occurrence of a change of control, asdefined in the plan. Unless an award agreement otherwise provides or the plan administrator otherwise determines at the time of grant, in the event that achange of control occurs (1) all outstanding options, unit appreciation rights and other exercise rights will become immediately and fully exercisable, and(2) all restrictions, excluding performance-based restrictions, applicable to awards under the plan will lapse, and (3) all performance criteria and otherconditions to payment of awards under which payments are subject to performance conditions shall be deemed to be achieved or fulfilled, measured at theactual performance level achieved as of the end of the calendar quarter immediately preceding the date of the change of control, and payment of such awards onthat basis shall be made or otherwise settled at the time of the change of control, provided that if the awards constitute deferred compensation the awards shallvest on the basis described above and shall remain payable on the dates provided in the underlying award agreements. If within three years following the date of any change of control the employment or service of a participant is terminated voluntarily or involuntarilyfor any reason other than for “cause”, as defined in the plan, then unless otherwise provided in the applicable award agreement, any option, unit appreciationright or other purchase right shall be exercisable for a period of 90 days following the date of such termination of employment or service but not later than theexpiration date of the award. EQM TR Program Under the EQM TR Program, if a participant’s employment terminates for any reason, including retirement, at any time prior to the applicablevesting date, the participant’s awarded units are forfeited, except under the following circumstances: · If the participant’s employment is terminated voluntarily or involuntarily without fault on the participant’s part (including retirement) and theparticipant remains on the Board of Directors of EQT 104(4)Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. or the Board of Directors of EQT Midstream Services, LLC, the general partner of the Company, following termination, then the participant’sperformance awards continue to vest for so long as the participant remains on such Board; and · If a participant’s employment is otherwise terminated involuntarily and without fault (including a termination resulting from death or disability)prior to payment, the participant may receive payment for a percentage of the participant’s performance units following termination of theperformance period, contingent upon achievement of the performance condition, as follows: TERMINATION DATEAWARDED UNITSPrior to January 1, 20140%January 1, 2014 – December 31, 201425%January 1, 2015 and thereafter50% EQT Plans and Agreements EQT maintains and has entered into certain plans and agreements (including those described above in “Narrative Disclosure to SummaryCompensation Table”) that require EQT to provide compensation to the named executive officers, among others, in the event of a termination of employment ora change of control of EQT. EQT provides full discussion of these plans and agreements in its filings with the SEC, including its annual proxy statementrelating to the annual meeting of the shareholders of EQT, which are available on the SEC’s website at www.sec.gov and on EQT’s website at www.EQT.comon the “SEC Filings” page under the “Investors Relations” tab. The secretary of our general partner will also provide a copy to you free of charge upon request. Compensation of Directors Officers or employees of EQT or its affiliates who also serve as directors of EQT Midstream Services, LLC, the Company’s general partner, do notreceive additional compensation for their service as directors. Directors of the Company’s general partner who are not also officers or employees of EQT or itsaffiliates receive cash compensation on a quarterly basis as a retainer and for attending meetings of the board of directors and committee meetings as follows: · An annual cash retainer of $40,000.· A cash meeting fee of $1,500 for each board and committee meeting attended in person. If a director participates in a meeting by telephone, themeeting fee is $750.· For the audit committee chair and the conflicts committee chair, an annual committee chair retainer of $15,000. In addition, each non-employee director is reimbursed for out-of-pocket expenses in connection with attending meetings. The Company also providesnon-employee directors with $20,000 of life insurance and $250,000 of travel accident insurance while traveling on business for the Company. To further theCompany’s support for charitable giving, all directors are eligible to participate in the Matching Gifts Program of the EQT Foundation on the same terms asEQT employees and directors. Under this program, the EQT Foundation will match gifts of at least $100 made by the director to eligible charities, up to anaggregate total of $25,000 in any calendar year. At the closing of the IPO, the Company’s general partner granted to each of its non-employee directors phantom units with a value of $50,000 underthe 2012 Long-Term Incentive Plan (with the number of phantom units (2,390) determined by dividing the award value by the initial offering price of theCompany’s common units ($21 per unit) and rounding up to the next ten shares). The phantom units were fully vested as of the grant date, with distributionequivalents accruing on such units. The phantom units (and the accrued distribution equivalents) will be converted into common units on the date that thegrantee ceases to be a director. 105Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. The table below shows the total 2012 compensation of the Company’s non-employee directors: NAMEFEESEARNEDOR PAIDIN CASH($) (1)STOCKAWARDS($) (2)ALL OTHERCOMPENSATION($) (3)TOTAL($) Michael A. Bryson45,85250,19018,594114,636Julian M. Bott45,85250,19088796,929 _______(1) Includes cash retainer, meeting fees and committee chair fees. (2) This column reflects the aggregate grant date fair value of the phantom units awarded to each director during 2012. On July 2, 2012, theCompany’s general partner granted 2,390 phantom units to each non-employee director. The grant date fair value is computed as the sum of thenumber of phantom units awarded on the grant date multiplied by the initial offering price of the Company’s common units, which was $21 perunit. (3) This column reflects (i) distribution equivalents on phantom units, (ii) annual premiums of $50 per director paid for personal life insurancepolicies, and (iii) for Mr. Bryson, $17,708 of matching gifts made to qualifying organizations under the EQT Foundation’s Matching GiftsProgram. The non-employee directors may use a de minimis number of tickets purchased by EQT to attend sporting or other events when suchtickets are not otherwise being used for business purposes. The use of such tickets do not result in any incremental costs to the Company. Inconnection with the IPO, Messrs. Bryson and Bott were offered the opportunity to purchase the Company’s common units through the DUPP. Therewere no incremental costs to the Company associated with the DUPP. Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters Security Ownership of Certain Beneficial Owners and Management The following table sets forth the beneficial ownership of the Company’s units owned as of February 1, 2013, by:· each of the directors of the Company’s general partner;· each of the named executive officers of the Company’s general partner; and· all directors and executive officers of the Company’s general partner as a group. The amounts and percentage of units beneficially owned are reported on the basis of regulations of the SEC governing the determination of beneficialownership of securities. Under the rules of the SEC, a person is deemed to be a “beneficial owner” of a security if that person has or shares “voting power,”which includes the power to vote or to direct the voting of such security, or “investment power,” which includes the power to dispose of or to direct thedisposition of such security. Except as indicated by footnote, the persons named in the table below have sole voting and investment power with respect to allunits shown as beneficially owned by them, subject to community property laws where applicable. 106Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Percentage of total units beneficially owned is based on 17,339,718 common units and 17,339,718 subordinated units outstanding as ofFebruary 1, 2013. NAME OF BENEFICIAL OWNER(1)COMMONUNITSBENEFICIALLYOWNED (2)PERCENTAGEOFCOMMONUNITSBENEFICIALLYOWNEDSUBORDINATEDUNITSBENEFICIALLYOWNEDPERCENTAGEOFSUBORDINATEDUNITSBENEFICIALLYOWNEDPERCENTAGEOFTOTALCOMMONANDSUBORDINATEDUNITSBENEFICIALLYOWNEDDavid L. Porges20,000*—**Philip P. Conti10,000*—**Randall L. Crawford25,000*—**Lewis B. Gardner9,500*—**Julian M. Bott4,419*—**Michael A. Bryson7,419*—**All directors and executive officers as a group(seven persons)86,338*—** * Less than 1%. Unless otherwise indicated, the address for all beneficial owners in this table is c/o EQT Midstream Partners, LP, 625 Liberty Avenue, Pittsburgh, PA15222, Attn: General Counsel. This column reflects the number of common units held of record or beneficially owned through a bank, broker or other nominee. For Messrs. Bott andBryson, it includes 2,419 phantom units, including accrued distributions, to be settled in common units. Brokerage account agreements may grantsecurity interests in securities held at the broker to secure payment and performance obligations of the brokerage account holder in the ordinary course. Common units shown in the table for directors and executive officers of the Company’s general partner may be subject to this type of security interest. 107(1)(2)Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. The following table sets forth the beneficial ownership of each person known by the Company to be a beneficial owner of more than 5% of theoutstanding units of the Company: NAME OF BENEFICIAL OWNERCOMMONUNITSBENEFICIALLYOWNEDPERCENTAGEOFCOMMONUNITSBENEFICIALLYOWNEDSUBORDINATEDUNITSBENEFICIALLYOWNEDPERCENTAGEOFSUBORDINATEDUNITSBENEFICIALLYOWNEDPERCENTAGEOFTOTALCOMMONANDSUBORDINATEDUNITSBENEFICIALLYOWNEDEQT Corporation(1)2,964,71817.1%17,339,718100%58.5%625 Liberty AvenuePittsburgh, PA 15222ClearBridge Investments, LLC(2)1,599,4709.22%———620 8 AvenueNew York, NY 10018Tortoise Capital Advisors, LLC(3)1,431,8928.3%———11550 Ash Street, Suite 300Leawood, KS 66211 EQT Corporation is the ultimate parent company of EQT Investments Holdings, LLC, which is the sole owner of all of the membership interests of theCompany’s general partner, which is the sole owner of the Company’s general partner units. EQT Investments Holdings, LLC is also the sole owner ofEQT Midstream Investments, LLC, which is the sole owner of 2,964,718 common units and 17,339,718 subordinated units. EQT may, therefore, bedeemed to beneficially own the units held by EQT Investments Holdings, LLC. Information based on a SEC Schedule 13G filed on February 14, 2013, reporting that ClearBridge Investments, LLC has shared voting and dispositivepower over 1,599,470 units. Information based on a SEC Schedule 13G filed on February 12, 2013, reporting that Tortoise Capital Advisors, LLC has shared voting power over1,347,232 units and shared dispositive power over 1,431,892 units. 108th(1)(2)(3)Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. The following table sets forth, as of February 1, 2013, the number of shares of common stock of EQT Corporation owned by each of the namedexecutive officers and directors of the Company’s general partner and all directors and executive officers of the Company’s general partner as a group. NameExercisableStock Options (1)Number of SharesBeneficially Owned (2)Percent ofClass (3)David L. Porges Chairman, President and ChiefExecutive Officer372,800531,281*Philip P. ContiSenior Vice President and ChiefFinancial Officer128,00093,128*Randall L. CrawfordSenior Vice President169,30062,869*Lewis B. GardnerDirector70,05018,988*Julian M. BottDirector———Michael A. BrysonDirector———Directors and executive officers as a group (7 individuals)761,650743,194* ____________* Indicates ownership or aggregate voting percentage of less than 1%. This column reflects the number of shares of EQT Corporation common stock that the officers and directors of the Company’s general partner had a rightto acquire within 60 days after February 1, 2013 through the exercise of stock options. This column reflects shares held of record and shares beneficially owned through a bank, broker or other nominee (including, for executive officers,shares beneficially owned through EQT Corporation’s 401(k) plan and employee stock purchase plans and unvested restricted shares beneficially ownedthrough EQT’s long-term incentive plan). Brokerage account agreements may grant security interests in securities held at the broker to secure payment andperformance obligations of the brokerage account holder in the ordinary course. Shares shown in the table may be subject to this type of security interest. This column reflects the sum of the individual’s (or individuals’) shares beneficially owned plus stock options exercisable within 60 days of February 1,2013 as a percent of the sum of EQT Corporation’s outstanding shares at February 1, 2013, plus all options exercisable within 60 days of February 1,2013. Shares beneficially owned include 50,000 shares that are held in a trust of which Mr. Porges is a co-trustee and in which he has a beneficial interest andvoting and investment power. 109(4)(1)(2) (3)(4) Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Securities Authorized for Issuance under Equity Compensation Plans The following table provides information as of December 31, 2012 with respect to the Company’s common units that may be issued under the 2012Long-Term Incentive Plan, which did not require approval by the Company’s unitholders. PLAN CATEGORYNUMBER OFSECURITIES TOBEISSUED UPONEXERCISE OFOUTSTANDINGOPTIONS,WARRANTSAND RIGHTSWEIGHTEDAVERAGEEXERCISE PRICE OFOUTSTANDINGOPTIONS,WARRANTS ANDRIGHTSNUMBER OFSECURITIESREMAININGAVAILABLE FORFUTURE ISSUANCEUNDEREQUITYCOMPENSATIONPLANS (EXCLUDINGSECURITIESREFLECTED INCOLUMN A)(A)(B)(C) Equity Compensation Plans Approved by Unitholders——— Equity Compensation Plans Not Approved by Unitholders(1)153,133N/A1,846,867 Total153,133N/A1,846,867 _________________________(1) The board of directors of the Company’s general partner adopted the 2012 Long-Term Incentive Plan in connection with the IPO of the Company’scommon units. EQT Midstream Services, LLC 2012 Long-Term Incentive Plan The Company’s general partner adopted the EQT Midstream Services, LLC 2012 Long-Term Incentive Plan for employees and non-employeedirectors of the Company’s general partner and any of its affiliates. The Company’s general partner may issue long-term equity based awards under the plan. The Company is responsible for the cost of awards granted under the plan. Employees and non-employee directors of the Company’s general partner or anyaffiliate, including subsidiaries, are eligible to receive awards under the plan. The aggregate number of units that may be issued under the plan is 2,000,000 units, subject to proportionate adjustment in the event of unit splitsand similar events. Units underlying options and unit appreciation rights will count as one unit, and units underlying all other unit-based awards will countas two units, against the number of units available for issuance under the plan. Units subject to awards that terminate or expire unexercised, or are cancelled,forfeited or lapse for any reason, and units underlying awards that are ultimately settled in cash, will again become available for future grants of awards underthe plan. Units delivered by the participant or withheld from an award to satisfy tax withholding requirements, and units delivered or withheld to pay theexercise price of an option, will not be used to replenish the plan unit reserve. The plan is administered by the board of directors of the Company’s general partner or such other committee of the board as may be designated bythe board to administer the plan. The plan authorizes the granting of awards in any of the following forms: phantom units, performance awards, restricted units, distributionequivalent rights, market-priced options to purchase units, unit appreciation rights, other unit-based awards that are denominated or payable in, valued inwhole or in part by reference to, or otherwise based on units, and cash-based awards. The board of directors of the Company’s general partner may amend, suspend or terminate the plan at any time, except that no amendment may bemade without the approval of the Company’s unitholders if unitholder approval is required by any federal or state law or regulation or by the rules of anyexchange on which the units may 110Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. then be listed, or if the amendment, alteration or other change materially increases the benefits accruing to participants, increases the number of units availableunder the plan or modifies the requirements for participation under the plan, or if the Board in its discretion determines that obtaining such unitholderapproval is for any reason advisable. Common units to be delivered pursuant to awards under the plan may be common units acquired by the Company’s general partner in the openmarket, from any other person, directly from the Company or any combination of the foregoing. If the Company issues new common units upon the grant,vesting or payment of awards under the plan, the total number of common units outstanding will increase. Item 13. Certain Relationships and Related Transactions, and Director Independence Certain Relationships and Related Transactions As of February 1, 2013, EQT indirectly owned 2,964,718 common units and 17,339,718 subordinated units representing a 58.5% limited partnerinterest in the Company. In addition, the Company’s general partner owned a 2.0% general partner interest in the Company and the incentive distributionrights. Distributions and Payments to the Company’s General Partner and Its Affiliates The following information summarizes the distributions and payments made or to be made by the Company to the Company’s general partner andits affiliates in connection with the Company’s formation, ongoing operation and any liquidation. These distributions and payments were determined by andamong affiliated entities and, consequently, are not the result of arm’s-length negotiations. Formation Stage The aggregate consideration received by the Company’s general partner and its affiliates for the contribution of certain assets and liabilities to theCompany in connection with the IPO: · 2,964,718 common units· 17,339,718 subordinated units· 707,744 general partner units representing a 2.0% general partner interest;· all of the incentive distribution rights; and· a cash payment of approximately $231 million from the proceeds of the IPO. Operational Stage Distributions of available cash to the Company’s general partner and its affiliates. The Company will generally make cash distributions98.0% to the Company’s unitholders pro rata, including the Company’s general partner and its affiliates as holders of an aggregate of 2,964,718 commonunits and all of the subordinated units, and 2.0% to the Company’s general partner. In addition, if distributions exceed the minimum quarterly distributionand other higher target levels, the Company’s general partner, by virtue of its incentive distribution rights, will be entitled to increasing percentages of thedistributions, up to 48.0% of the distributions above the highest target level. Payments to the Company’s general partner and its affiliates. The Company’s general partner does not receive a management fee or othercompensation for managing the Company. The Company’s general partner and its affiliates are reimbursed, however, for all direct and indirect expensesincurred on the Company’s behalf. The Company’s general partner determines the amount of these expenses. In addition, the Company reimburses EQT andits affiliates for the payment of certain operating expenses and for the provision of various general and administrative services for the Company’s benefit. Withdrawal or removal of the Company’s general partner. If the Company’s general partner withdraws or is removed, its general partner interestand its incentive distribution rights will either be sold to the new general partner for cash or converted into common units, in each case for an amount equal tothe fair market value of those interests. 111Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Liquidation Stage Upon the Company’s liquidation, the partners, including the Company’s general partner, will be entitled to receive liquidating distributionsaccording to their capital account balances. Agreements with EQT The Company and its affiliates have entered into various agreements with EQT and its affiliates other than the Company, as described in detailbelow. These agreements were negotiated in connection with the formation of the Company and the IPO and address, among other things, the acquisition ofassets and the assumption of liabilities by the Company and its subsidiaries. These agreements were not the result of arm’s length negotiations and, as such,they or underlying transactions may not be based on terms as favorable as those that could have been obtained from unaffiliated third parties. Omnibus Agreement The Company and its general partner have entered into an omnibus agreement with EQT that governs the Company’s relationship with EQTregarding the following matters: · the Company’s obligation to reimburse EQT and its affiliates for certain direct operating expenses they pay on the Company’s behalf (the “directoperating expenses”);· the Company’s obligation to reimburse EQT and its affiliates for providing the Company corporate, general and administrative services (the“general and administrative expenses”);· the Company’s obligation to reimburse EQT and its affiliates for operation and management services pursuant to the operation and managementservices agreement (the “operation and management expenses”);· EQT’s obligation to indemnify or reimburse the Company for losses or expenses relating to or arising from (i) certain plugging andabandonment obligations; (ii) certain bare steel replacement capital expenditures; (iii) certain pipeline safety costs; (iv) certain preclosingenvironmental liabilities; (v) certain title and rights-of-way matters; (vi) the Company’s failure to have certain necessary governmental consentsand permits; (vii) certain preclosing tax liabilities; (viii) assets previously owned by the Company and retained by EQT and its affiliates,including the Sunrise Pipeline; (ix) any claims related to Equitrans’ previous ownership of the Big Sandy Pipeline; and (x) any amounts owed tothe Company by a third party that has exercised a contractual right of offset against amounts owed by EQT to such third party;· the Company’s obligation to indemnify EQT for losses attributable to (i) the ownership or operation of the Company’s assets after the closing ofthe IPO, except to the extent EQT is obligated to indemnify the Company for such losses pursuant to the Operation and Management ServicesAgreement with EQT, as described below under “—Operation and Management Services Agreement;” and (ii) any amounts owed to EQT by athird party that has exercised a contractual right of offset against amounts owed by the Company to such third party; and· the Company’s use of the name “EQT” and related marks. Reimbursement of Expenses Under the omnibus agreement, EQT will, or will cause its affiliates to, perform centralized corporate, general and administrative services for theCompany, such as legal, corporate recordkeeping, planning, budgeting, regulatory, accounting, billing, business development, treasury, insuranceadministration and claims processing, risk management, health, safety and environmental, information technology, human resources, investor relations, cashmanagement and banking, payroll, internal audit, taxes and engineering. In exchange, the Company will reimburse EQT and its affiliates for the expensesincurred by them in providing these services, except for any expenses associated with EQT’s long-term incentive programs. The omnibus agreement furtherprovides that the Company will reimburse EQT and its affiliates for the Company’s allocable portion of the premiums on any insurance policies covering theCompany’s assets. 112Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. The Company will also reimburse EQT for any additional state income, franchise or similar tax paid by EQT resulting from the inclusion of theCompany (and its subsidiaries) in a combined state income, franchise or similar tax report with EQT as required by applicable law. The amount of any suchreimbursement will be limited to the tax that the Company (and its subsidiaries) would have paid had they not been included in a combined group with EQT. The table below sets forth the amounts and categories of expenses described above for which the Company was obligated to reimburse EQT pursuantto the omnibus agreement for the year ended December 31, 2012. DESCRIPTION OF EXPENSESEXPENSE (IN MILLIONS) Reimbursement of general and administrative expenses$ 7.7Reimbursement of operation and management expenses$ 8.5 Indemnification EQT’s indemnification obligations to the Company will include the following: · Plugging and abandonment liabilities. For a period of ten years after the closing of the IPO, EQT will reimburse the Company for pluggingand abandonment expenditures and other expenditures for certain identified wells of EQT and third parties. The reimbursement obligation ofEQT with respect to wells owned by third parties is capped at $1.2 million per year. · Bare steel replacement. EQT has agreed to reimburse the Company for bare steel replacement capital expenditures in the event that ongoingmaintenance capital expenditures (other than capital expenditures associated with plugging and abandonment liabilities to be reimbursed byEQT) exceed $17.2 million (with respect to the Company’s assets at the time of the IPO) in any year. If such ongoing maintenance capitalexpenditures and bare steel replacement capital expenditures exceed $17.2 million during a year, EQT will reimburse the Company for the lesserof (i) the amount of bare steel replacement capital expenditures during such year and (ii) the amount by which such ongoing capital expendituresand bare steel replacement capital expenditures exceeds $17.2 million. This bare steel replacement reimbursement obligation is capped at anaggregate amount of $31.5 million over the ten years following the IPO. · Pipeline Safety Cost Tracker Reimbursement. For a period of five years after the closing of the IPO, EQT will reimburse the Company for theamount by which the qualifying pipeline safety costs included in the annual pipeline safety cost tracker filings made by Equitrans with theFERC exceed the qualifying pipeline safety costs actually recovered each year. · Environmental. For a period of three years after the closing of the IPO, EQT will indemnify the Company for certain potential environmentaland toxic tort claims, losses and expenses associated with the operation of the assets retained by the Company and occurring before the closingdate of the IPO. The maximum liability of EQT for these indemnification obligations will not exceed $15 million and EQT will not have anyobligation under these indemnification obligations until the Company’s aggregate losses exceed $250,000, after which EQT shall be liable for thefull amount of such claims in excess of $250,000. EQT will have no indemnification obligations with respect to environmental or toxic tortclaims made as a result of additions to, or modifications of, environmental laws promulgated after the closing of the IPO. · Title. For a period of three years after the closing of the IPO, EQT will indemnify the Company for losses relating to the Company’s failure tohave valid and indefeasible easement rights, rights-of-way, leasehold and/or fee ownership interests in and to the lands on which the Company’sassets are located, and such failure prevents the Company from using or operating its assets in substantially the same manner that such assetswere used and operated immediately prior to the closing of the IPO. · Governmental consents and permits. For a period of three years after the closing of the IPO, EQT will indemnify the Company for lossesrelating to its failure to have any consent or governmental permit 113Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. where such failure prevents the Company from using or operating its assets in substantially the same manner that such assets were used andoperated immediately prior to the closing of the IPO. · Taxes. Until 60 days after the expiration of any applicable statute of limitations, EQT will indemnify the Company for any income taxesattributable to operations or ownership of the assets prior to the closing of the IPO, including any such income tax liability of EQT and itsaffiliates that may result from the Company’s formation transactions. · Retained liabilities. EQT will indemnify the Company for any liabilities, claims or losses relating to or arising from assets owned orpreviously owned by the Company and retained by EQT and its affiliates following the closing of the IPO. · Big Sandy Pipeline. EQT will indemnify the Company for any claims related to Equitrans’ previous ownership of the Big Sandy Pipeline,which was sold to a third party, including claims arising under the Big Sandy Purchase Agreement. · Contractual Offsets. EQT will indemnify the Company for any amounts owed to the Company by a third party that has exercised acontractual right of offset against amounts owed by EQT to such third party. In no event will EQT be obligated to indemnify the Company for any claims, losses or expenses or income taxes referred to in the first seven bulletsabove to the extent either (i) reserved for in the Company’s financial statements as of December 31, 2011, or (ii) the Company recovers any such amountsunder available insurance coverage, from contractual rights or other recoveries against any third party or in the tariffs paid by the customers of the Company’saffected pipeline system. The Company will indemnify EQT for all losses attributable to (i) the post-closing operations of the assets retained by the Company, to the extentnot subject to EQT’s indemnification obligations; and (ii) any amounts owed to EQT by a third party that has exercised a contractual right of offset againstamounts owed by the Company to such third party. The table below sets forth the amounts and categories of obligations described above for which EQT was obligated to indemnify and/or reimburse theCompany pursuant to the omnibus agreement for the year ended December 31, 2012. DESCRIPTION OF OBLIGATIONAMOUNT OF OBLIGATION(IN MILLIONS) Plugging and abandonment liabilities$ 1.6Bare steel replacement$ 2.7Pipeline safety cost tracker reimbursement$ —Big Sandy Pipeline claims$ 2.7 Competition Under the Company’s partnership agreement, EQT and its affiliates are expressly permitted to compete with the Company. EQT and any of itsaffiliates may acquire, construct or dispose of additional transportation and storage or other assets in the future without any obligation to offer the Companythe opportunity to purchase or construct those assets. Amendment and Termination The omnibus agreement can be amended by written agreement of all parties to the agreement. However, the Company may not agree to anyamendment or modification that would, in the determination of the Company’s general partner, be adverse in any material respect to the holders of theCompany’s common units without the prior approval of the conflicts committee. In the event of (i) a “change in control” (as defined in the omnibus agreement)of the Company, the Company’s general partner or EQT or (ii) the removal of EQT Midstream Services, LLC as the Company’s general partner incircumstances where (a) “cause” (as defined in the Company’s partnership agreement) does not exist and the common units held by the Company’s generalpartner and its affiliates were not 114Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. voted in favor of such removal or (b) cause exists, the omnibus agreement (other than the indemnification and reimbursement provisions therein) will beterminable by EQT, and the Company will have a 90-day transition period to cease the Company’s use of the name “EQT” and related marks. Operation and Management Services Agreement Upon the closing of the IPO, the Company entered into an operation and management services agreement with EQT Gathering, LLC, or EQTGathering, an indirect, wholly-owned subsidiary of EQT, under which EQT Gathering will provide the Company’s pipelines and storage facilities withcertain operational and management services, such as operation and maintenance of flow and pressure control, maintenance and repair of the Company’spipeline and storage facilities, conducting routine operational activities, managing transportation and logistics, contract administration, gas control andmeasurement, engineering support and such other services as the Company and EQT Gathering may mutually agree upon from time to time. The Companywill reimburse EQT Gathering for such services pursuant to the terms of the omnibus agreement as described above. The operation and management services agreement will terminate upon the termination of the omnibus agreement. If a force majeure event prevents aparty from carrying out its obligations (other than to make payments due), such party’s obligations under the agreement, to the extent affected by forcemajeure, will be suspended during the continuation of the force majeure event. These force majeure events include acts of God, strikes, lockouts or otherindustrial disturbances, wars, riots, fires, floods, storms, explosions, terrorist acts, breakage or accident to machinery or lines of pipe and inability to obtainor unavoidable delays in obtaining material, equipment or supplies and similar events or circumstances, so long as such events or circumstances are beyondthe reasonable control of the party claiming force majeure and could not have been prevented or overcome by such party’s reasonable diligence. Under the agreement, EQT Gathering will indemnify the Company from claims, losses or liabilities incurred by the Company, including third partyclaims, arising out of EQT Gathering’s gross negligence or willful misconduct. The Company will indemnify EQT Gathering from any claims, losses orliabilities incurred by EQT Gathering, including any third-party claims, arising from the performance of the agreement, but not to the extent of losses orliabilities caused by EQT Gathering’s gross negligence or willfull misconduct. Neither party is liable for any consequential, incidental or punitive damagesunder the agreement, except to the extent such damages are included in a third party claim for which a party is obligated to indemnify the other party pursuantto the agreement. Neither party may assign its rights or obligations under the agreement without the prior written consent of the other party, which shall not beunreasonably withheld, conditioned or delayed. Contracts with Affiliates Transportation Service and Precedent Agreements Equitable Gas Company and EQT Energy, each of which is a wholly-owned subsidiary of EQT, have contracted for an aggregate peak winter firmtransmission capacity of 898 BBtu per day on the Company’s transmission and storage system, including the Sunrise Pipeline project, pursuant to firmcontracts. All of Equitable Gas Company’s agreements currently have a primary term through March of 2016 and are contracted at the maximum ratespecified in the Company’s tariff, including two service agreements under the Company’s no-notice firm transportation rate schedule, which features a highermaximum tariff rate than the Company’s customary firm transportation service. On December 19, 2012, EQT and a direct wholly owned subsidiary, Distribution Holdco, LLC, executed a Master Purchase Agreement with PNGCompanies LLC (PNG Companies), the parent company of Peoples Natural Gas Company LLC, to transfer 100% ownership of EQT’s LDC, Equitable GasCompany, LLC (Equitable Gas Company) to PNG Companies. As consideration for the transfer, which is subject to various closing conditions, includingregulatory approvals, EQT will receive cash proceeds of $720 million, subject to adjustment, select midstream assets and commercial arrangements withPNG Companies and its affiliates. Upon the closing of the announced pending transfer of Equitable Gas Company to PNG Companies LLC, the primary terms of Equitable GasCompany’s firm transportation service and no-notice firm transportation service 115Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. agreements will be extended through March of 2034. An agreement to effect these term extensions will be executed upon the closing of the transfer of EquitableGas Company. EQT Energy has an agreement reserving 450 BBtu per day, which is contracted at a negotiated rate above the maximum rate allowed under theCompany’s tariff with a primary term through June of 2023. The reserved capacity under this contract is currently 390 BBtu per day and will increaseperiodically until it reaches its peak capacity of 450 BBtu pursuant to a binding precedent agreement. This peak capacity will be split between service on theCompany’s transmission and storage system and service on the Sunrise Pipeline, which the Company operates under a lease agreement with EQT pursuant tothe terms of the Company’s tariff, such that 260 BBtu will be provided on the Company’s transmission and storage system and 190 BBtu will be providedon the Sunrise Pipeline. These firm transportation agreements will automatically renew for one year periods upon the expiration of the primary term, subject to six monthsprior written notice by either party to terminate. In addition, the Company has also entered into an agreement with EQT Energy to provide interruptibletransmission service, which is currently renewing automatically for one month periods, subject to 30 days prior written notice by either party to terminate. Forthe years ended December 31, 2012, 2011 and 2010, the Company’s transportation agreements with EQT accounted for approximately 84%, 84% and 82%,respectively, of the natural gas throughput on the Company’s transmission system and 81%, 83% and 86%, respectively, of the Company’s transmissionrevenues. Storage Agreements The Company has entered into four agreements with Equitable Gas Company to provide firm storage services. Of these firm storage serviceagreements, two are contracted under a rate schedule filed with the Company’s tariff that limits the maximum daily amount that may be withdrawn fromstorage by a customer to 1/115th of 110% of such customer’s total annual storage quantity as specified in its service agreement. The remaining firm storageservice agreements are contracted under a similar rate schedule that limits the maximum daily amount that may be withdrawn from storage by a customer to1/60th of 110% of such customer’s total annual storage quantity as specified in their service agreement. These agreements currently have a primary termthrough March of 2016. Upon the closing of the announced pending transfer of Equitable Gas Company to PNG Companies, LLC, the primary terms ofthese firm storage service agreements will be extended through March of 2034, and will automatically renew for one year periods upon the expiration of theprimary term, subject to 12 months prior written notice by either party to terminate. An agreement to effect these term extensions will be executed upon theclosing of the transfer of Equitable Gas Company. The aggregate annual storage capacity subscribed under these firm storage agreements with EQT is equalto 13.5 TBtu. In addition, the Company has also entered into an agreement with Equitable Gas Company to provide interruptible storage services with aprimary term of one year, which will automatically renew for one month periods, subject to 30 days prior written notice by either party to terminate. For theyears ended December 31, 2012, 2011 and 2010, EQT accounted for approximately 68%, 77% and 82%, respectively, of the Company’s storage revenues. Gas Gathering Agreements The Company has entered into three gas gathering agreements with Equitable Gas Company and EQT Energy. These agreements have a primaryterm of one year and renew automatically for one month periods, subject to 30 days prior written notice by either party to terminate. Service provided underthese gathering agreements is fee-based at the rate specified in the Company’s tariff. These gathering agreements accounted for approximately 63%, 63% and64%, respectively, of the Company’s gathering throughput for the years ended December 31, 2012, 2011 and 2010. For the years ended December 31, 2012,2011 and 2010, EQT accounted for approximately 64% of the Company’s gathering revenues in each year. The table below sets forth the revenues recognized by the Company with respect to the transportation, storage and gathering agreements describedabove with EQT for the year ended December 31, 2012. DESCRIPTION OF REVENUEREVENUES (IN MILLIONS) Transmission and storage$95.8Gathering$10.3 116Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Asset Exchange Agreement In connection with the pending transfer of Equitable Gas Company to PNG Companies, LLC, EQT, Equitable Gas and Equitrans entered into anAsset Exchange Agreement, pursuant to which the parties agreed to transfer and exchange to one another certain assets prior to the closing of the transfer ofEquitable Gas Company. The asset transfers involving Equitrans consist of (a) the transfer from Equitrans to Equitable Gas of the natural gas pipelinesknown as the Tombaugh Pipeline, the M-85 Pipeline and the H-153 Pipeline, and the compressor station known as Crooked Creek, and (b) the transfer fromEquitable Gas to Equitrans of the natural gas pipeline known as the D-494 Pipeline. The asset transfers are subject to the receipt of required regulatoryapproval from FERC and the PA PUC. EQT Corporation Guaranty EQT has entered into a guaranty agreement to guarantee all payment obligations, plus interest and any other charges, due and payable by EQTEnergy to Equitrans pursuant to the agreements discussed above, up to $50 million. This guaranty will terminate on November 30, 2023 unless terminatedearlier by EQT by providing 10 days written notice. Acreage Dedication Pursuant to an acreage dedication to the Company by EQT, effective as of March 1, 2011, the Company has the right to elect to transport, at anegotiated rate, which will be the higher of a market or cost of service rate, all natural gas produced from wells drilled by EQT on the dedicated acreage, whichis an area covering approximately 60,000 acres surrounding the Company’s storage assets in Allegheny, Washington and Greene counties in Pennsylvania andWetzel, Marion, Taylor, Tyler, Doddridge, Harrison and Lewis counties in West Virginia. The acreage dedication is contained in a sublease agreement inwhich the Company granted to EQT all of the oil and gas interests, including the exclusive rights to drill, explore for, produce and market such oil and gas,the Company had received as part of certain of its oil and gas leasehold estates the Company uses for gas storage and protection. Furthermore, if EQTacquires acreage with natural gas storage rights within the area of mutual interest established by the acreage dedication, then EQT will enter into an agreementwith the Company to permit it to store natural gas on such acreage. Likewise, if the Company acquires acreage within the area of mutual interest with naturalgas or oil production, development, marketing and exploration rights, such acreage will automatically become subject to EQT’s rights under the acreagededication. Sunrise Pipeline Lease Agreement Contemporaneously with the Company’s transfer of the Sunrise Pipeline to EQT, the Company entered into a lease agreement with EQT for the leaseof the Sunrise Pipeline and the Company operates the facilities as part of its transmission and storage system under the rates, terms and conditions of theCompany’s FERC-approved tariff. The lease payment due in any given month will be the lesser of the following alternatives: (1) a revenue-based paymentreflecting the revenues generated by the operation of the Sunrise Pipeline minus the Company’s actual costs of operating the Sunrise Pipeline and (2) a paymentbased on depreciation expense and pre-tax return on invested capital for the Sunrise Pipeline. The first alternative is designed to pass through to EQT therevenues the Company collects for service, including reservation charges and usage charges, on the Sunrise Pipeline net of the Company’s costs of operatingand maintaining such facilities. This alternative is intended to protect the Company from adverse economic consequences in the event the Company does notsubscribe all of the available capacity on the Sunrise Pipeline, a possibility that may persist for the first few years following the in-service date of the SunrisePipeline until production in the Marcellus Shale region ramps up. The second lease payment alternative is designed to reflect the actual cost of service to operatethe Sunrise Pipeline. Currently, the lease payment is calculated under the first alternative. The lease payments related to 2012 totaled $10.3 million. The lease agreement has a primary term of 15 years from July 28, 2012, which is the date the Sunrise Pipeline was placed into service, unless EQTrequests an early termination at its sole discretion. Upon termination of the lease agreement, the Company is required to purchase the Sunrise Pipeline at a priceto be negotiated between the parties. The Company obtained FERC approval to transfer the Sunrise Pipeline to EQT and to contemporaneously lease thosefacilities. The Company also obtained pre-granted authorization from the FERC for the termination of the lease agreement and the Company’s acquisition of theSunrise Pipeline at the end of the 117Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. primary term or such other time as EQT requests, which may be prior to the end of the primary term. The lease agreement requires EQT to transfer ownershipof the Sunrise Pipeline to the Company at a price to be negotiated between the parties. If the Company cannot come to an agreement with EQT on the termsunder which it will acquire the Sunrise Pipeline, the lease agreement will remain in full force and effect, beyond the primary term if necessary, until anagreement can be reached. Review, Approval or Ratification of Transactions with Related Persons The board of directors of the Company’s general partner has adopted a related person transaction approval policy that establishes procedures for theidentification, review and approval of related person transactions. Pursuant to the policy, the management of the Company’s general partner is charged withprimary responsibility for determining whether, based on the facts and circumstances, a proposed transaction is a related person transaction. For purposes of the policy, a “Related Person” is any director or executive officer of the Company’s general partner, any nominee for director, anyunitholder known to the Company to be the beneficial owner of more than 5% of any class of the Company’s voting securities, and any immediate familymember of any such person. A “Related Person Transaction” is generally a transaction in which the Company is, or the Company’s general partner or any ofits subsidiaries is, a participant, where the amount involved exceeds $120,000, and a Related Person has a direct or indirect material interest. Transactionsresolved under the conflicts provision of the partnership agreement are not required to be reviewed or approved under the policy. Please read “Conflicts ofInterest” below. To assist management in making this determination, the policy sets forth certain categories of transactions that are deemed to be pre-approved by theboard under the policy. The transactions which are automatically pre-approved include (i) transactions involving employment of the Company’s executiveofficers, as long as the executive officer is not an immediate family member of another of the Company’s executive officers or directors and the compensationpaid to such executive officer was approved by the board; (ii) transactions involving compensation and benefits paid to the Company’s directors for service asa director; (iii) transactions on competitive business terms with another company in which a director or immediate family member of the director’s onlyrelationship is as an employee or executive officer, a director, or beneficial owner of less than 10% of that company’s shares, provided that the amountinvolved does not exceed the greater of $1,000,000 or 2% of the other company’s consolidated gross revenues; (iv) transactions where the interest of the RelatedPerson arises solely from the ownership of a class of equity securities of the Company, and all holders of that class of equity securities receive the same benefiton a pro rata basis; (v) transactions where the rates or charges involved are determined by competitive bids; (vi) transactions involving the rendering ofservices as a common or contract carrier or public utility at rates or charges fixed in conformity with law or governmental regulation; (vii) transactionsinvolving services as a bank depositary of funds, transfer agent, registrar, trustee under a trust indenture or similar services; and (viii) any charitablecontribution, grant or endowment by the Company or any affiliated charitable foundation to a charitable or non-profit organization, foundation or university inwhich a Related Person’s only relationship is as an employee or a director or trustee, if the aggregate amount involved does not exceed the greater of $1,000,000or 2% of the recipient’s consolidated gross revenues. If, after applying these categorical standards and weighing all of the facts and circumstances, management determines that a proposed transaction isa related person transaction, management must present the proposed transaction to the board of directors of the Company’s general partner for review or, ifimpracticable under the circumstances, to the chairman of the board. The board must then either approve or reject the transaction in accordance with the termsof the policy taking into account all facts and circumstances including, (i) the benefits to the Company of the transaction; (ii) the terms of the transaction;(iii) the terms available to unaffiliated third parties and employees generally; (iv) the extent of the affected director or executive officer’s interest in thetransaction; and (v) the potential for the transaction to affect the individual’s independence or judgment. The board of the Company’s general partner may, butis not required to, seek the approval of the conflicts committee for the resolution of any related person transaction. Conflicts of Interest Conflicts of interest exist and may arise in the future as a result of the relationships between the Company’s general partner and its affiliates,including EQT, on the one hand, and the Company and its limited partners, on the other hand. The directors and officers of the Company’s general partnerhave fiduciary duties to manage the 118Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Company’s general partner in a manner beneficial to its owners. At the same time, the Company’s general partner has a duty to manage the Company in amanner beneficial to the Company and its limited partners. The Delaware Revised Uniform Limited Partnership Act, which the Company refers to as theDelaware Act, provides that Delaware limited partnerships may, in their partnership agreements, expand, restrict or eliminate the fiduciary duties otherwiseowed by a general partner to limited partners and the partnership. Pursuant to these provisions, the Company’s partnership agreement contains variousprovisions replacing the fiduciary duties that would otherwise be owed by its general partner with contractual standards governing the duties of the generalpartner and the methods of resolving conflicts of interest. The Company’s partnership agreement also specifically defines the remedies available to limitedpartners for actions taken that, without these defined liability standards, might constitute breaches of fiduciary duty under applicable Delaware law. Whenever a conflict arises between the Company’s general partner or its affiliates, on the one hand, and the Company or any other partner, on theother, the Company’s general partner will resolve that conflict. The Company’s general partner may seek the approval of such resolution from the conflictscommittee of the board of directors of its general partner. There is no requirement that the Company’s general partner seek the approval of the conflictscommittee for the resolution of any conflict, and, under the Company’s partnership agreement, the Company’s general partner may decide to seek suchapproval or resolve a conflict of interest in any other way permitted by the partnership agreement, as described below, in its sole discretion. The Company’sgeneral partner will decide whether to refer the matter to the conflicts committee on a case-by-case basis. An independent third party is not required to evaluatethe fairness of the resolution. The Company’s general partner will not be in breach of its obligations under the partnership agreement or its duties to the Company or its limitedpartners if the resolution of the conflict is: · approved by the conflicts committee; · approved by the vote of a majority of the outstanding common units, excluding any common units owned by the Company’s general partner orany of its affiliates; · determined by the board of directors of the Company’s general partner to be on terms no less favorable to the Company than those generallybeing provided to or available from unrelated third parties; or · determined by the board of directors of the Company’s general partner to be fair and reasonable to the Company, taking into account the totalityof the relationships between the parties involved, including other transactions that may be particularly favorable or advantageous to theCompany. If the Company’s general partner does not seek approval from the conflicts committee and the board of directors of the Company’s general partnerdetermines that the resolution or course of action taken with respect to the conflict of interest satisfies either of the standards set forth in the third and fourthbullet points above, then it will be presumed that, in making its decision, the board of directors of the Company’s general partner acted in good faith, and inany proceeding brought by or on behalf of any limited partner or the Company challenging such determination, the person bringing or prosecuting suchproceeding will have the burden of overcoming such presumption. Unless the resolution of a conflict is specifically provided for in the Company’s partnershipagreement, the Company’s general partner or the conflicts committee of the general partner’s board of directors may consider any factors it determines in goodfaith to consider when resolving a conflict. When the Company’s partnership agreement requires someone to act in good faith, it requires that person tosubjectively believe that he is acting in the best interests of the Company or meets the specified standard, for example, a transaction on terms no less favorableto the Company than those generally being provided to or available from unrelated third parties. Director Independence The NYSE does not require a listed publicly traded limited partnership, such as the Company, to have a majority of independent directors on theboard of directors of its general partner. For a discussion of the independence of the board of directors of the Company’s general partner, please see Item 10,“Directors, Executive Officers and Corporate Governance-Committees of the Board of Directors.” 119Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. Item 14. Principal Accounting Fees and Services Ernst & Young LLP served as the Company’s independent auditor for the year ended December 31, 2012. The following chart details the fees billedby Ernst & Young LLP during 2012: 2012(Thousands) Audit Fees$306 Audit-Related Fees0 Tax Fees0 All Other Fees0 Total$306 Audit fees are primarily for the audit of the Company’s consolidated financial statements, including reviews of the Company’s financial statementsincluded in the Form 10-Qs. The above amounts represent fees paid by the Company. Certain fees approved by EQT and reimbursed by the Company fromIPO proceeds are not included in the above amounts. The excluded amounts total $0.6 million for 2012 and are solely attributable to audit fees and audit-related fees for the Company’s Predecessor for periods prior to its IPO. The audit committee of the Company’s general partner has adopted a policy regarding the services of its independent auditors under which theCompany’s independent accounting firm is not allowed to perform any service which may have the effect of jeopardizing the registered public accountant’sindependence. Without limiting the foregoing, the independent accounting firm shall not be retained to perform the following: · Bookkeeping or other services related to the accounting records or financial statements · Financial information systems design and implementation · Appraisal or valuation services, fairness opinions or contribution-in-kind reports · Actuarial services · Internal audit outsourcing services · Management functions · Human resources · Broker-dealer, investment adviser or investment banking services · Legal services · Expert services unrelated to the audit · Prohibited tax services All audit and permitted non-audit services must be pre-approved by the audit committee. The audit committee has delegated specific pre-approvalauthority with respect to permitted non-audit services to the Chair of the audit committee but only where pre-approval is required to be acted upon prior to thenext audit committee meeting and where the aggregate permitted non-audit services fees are not more than $75,000. The audit committee encouragesmanagement to seek pre-approval from the audit committee at its regularly scheduled meetings. The audit committee has approved the appointment of Ernst & Young LLP as the Company’s independent auditor to conduct the audit of theCompany’s consolidated financial statements for the year ended December 31, 2013. 120Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. PART IV Item 15. Exhibits and Financial Statement Schedules (a)1.Financial StatementsThe financial statements listed in the accompanying index to financial statements are filed as part of this Annual Report on Form 10-K. 2.Financial Statement ScheduleAll schedules are omitted since the subject matter thereof is either not present or is not present in amounts sufficient to require submission of theschedules. 3.ExhibitsThe exhibits listed on the accompanying index to exhibits (pages 122 through 124) are filed as part of this Annual Report on Form 10-K. EQT MIDSTREAM PARTNERS, LP INDEX TO FINANCIAL STATEMENTS COVEREDBY REPORT OF INDEPENDENT REGISTEREDPUBLIC ACCOUNTING FIRM 1. The following Consolidated Financial Statements of EQT Midstream Partners, LP and Subsidiaries are included in Item 8: Page Reference Statements of Consolidated Operations for each of the three years in the period endedDecember 31, 201269Statements of Consolidated Cash Flows for each of the three years in the period endedDecember 31, 201270Consolidated Balance Sheets as of December 31, 2012 and 201171Consolidated Statements of Partners’ Capital for each of the three years in the period endedDecember 31, 201272Notes to Consolidated Financial Statements73 121Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. INDEX TO EXHIBITS ExhibitsDescriptionMethod of Filing3.1Certificate of Limited Partnership of EQT Midstream Partners, LP.Filed as Exhibit 3.1 to Form S-1 Registration Statement (#333-179487) filed on February 13, 2012. 3.2First Amended and Restated Agreement of Limited Partnership of EQTMidstream Partners, LP, dated July 2, 2012.Filed as Exhibit 3.2 to Form 8-K (#001-35574) filed on July 2,2012. 3.3Certificate of Formation of EQT Midstream Services, LLC.Filed as Exhibit 3.3 to Form S-1 Registration Statement (#333-179487) filed on February 13, 2012. 3.4First Amended and Restated Limited Liability Company Agreement ofEQT Midstream Services, LLC, dated July 2, 2012.Filed as Exhibit 3.4 to Form 8-K (#001-35574) filed on July 2,2012. 10.1Contribution, Conveyance and Assumption Agreement, dated July 2,2012, by and among EQT Midstream Partners, LP, EQT MidstreamServices, LLC, Equitrans Investments, LLC, Equitrans, L.P.,Equitrans Services, LLC, EQT Midstream Investments, LLC, EQTInvestments Holdings, LLC, ET Blue Grass, LLC and EQTCorporation.Filed as Exhibit 10.1 to Form 8-K (#001-35574) filed on July 2,2012. 10.2Omnibus Agreement, dated July 2, 2012, by and among the EQTMidstream Partners, LP, EQT Midstream Services, LLC and EQTCorporation.Filed as Exhibit 10.2 to Form 8-K (#001-35574) filed on July 2,2012. 10.3Operation and Management Services Agreement, dated July 2, 2012,by and among Equitrans, L.P. and EQT Gathering, LLC.Filed as Exhibit 10.3 to Form 8-K (#001-35574) filed on July 2,2012. 10.4Revolving Credit Agreement, dated July 2, 2012, by and among EQTMidstream Partners, LP, Wells Fargo Bank, National Association, asadministrative agent, and a syndicate of lenders named therein.Filed as Exhibit 10.4 to Form 8-K (#001-35574) filed on July 2,2012. 10.5EQT Midstream Services, LLC 2012 Long-Term Incentive Plan, datedJuly 2, 2012.Filed as Exhibit 10.5 to Form 8-K (#001-35574) filed on July 2,2012. 10.6*Form of Phantom Unit Award Agreement.Filed as Exhibit 10.6 to Amendment No. 2 to Form S-1Registration Statement (#333-179487) filed on May 10, 2012. 10.7*Form of TSR Performance Award Agreement.Filed as Exhibit 10.7 to Amendment No. 2 to Form S-1Registration Statement (#333-179487) filed on May 10, 2012. Each management contract and compensatory arrangement in which any director or any named executive officer participates has been marked withan asterisk (*) 122Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. INDEX TO EXHIBITS ExhibitsDescriptionMethod of Filing10.8Transportation Service Agreement Applicable to Firm TransportationService Under Rate Schedule FTS between Equitrans, L.P. and EQTEnergy LLC, dated September 21, 2010.Filed as Exhibit 10.8 to Amendment No. 2 to Form S-1Registration Statement (#333-179487) filed on May 10, 2012. 10.9Form of Transportation Service Agreement Applicable to FirmTransportation Service Under Rate Schedule FTS betweenEquitrans, L.P. and Equitable Gas Company, LLC.Filed as Exhibit 10.9 to Amendment No. 2 to Form S-1Registration Statement (#333-179487) filed on May 10, 2012. 10.10Form of Transportation Service Agreement Applicable to No-NoticeFirm Transportation Service Under Rate Schedule NOFT betweenEquitrans, LP and Equitable Gas Company, LLC.Filed as Exhibit 10.10 to Amendment No. 2 to Form S-1Registration Statement (#333-179487) filed on May 10, 2012. 10.11EQT Guaranty dated April 25, 2012, executed by EQT Corporation infavor of Equitrans, L.P.Filed as Exhibit 10.11 to Amendment No. 2 to Form S-1Registration Statement (#333-179487) filed on May 10, 2012. 10.12Sublease Agreement between Equitrans, L.P. and EQT ProductionCompany, effective March 1, 2011.Filed as Exhibit 10.12 to Amendment No. 2 to Form S-1Registration Statement (#333-179487) filed on May 10, 2012. 10.13Amendment of Sublease Agreement between Equitrans, L.P. and EQTProduction Company, dated April 5, 2012.Filed as Exhibit 10.13 to Amendment No. 2 to Form S-1Registration Statement (#333-179487) filed on May 10, 2012. 10.14*Form of Director Indemnification Agreement.Filed as Exhibit 10.15 to Amendment No. 3 to Form S-1Registration Statement (#333-179487) filed on June 5, 2012. 10.15Sunrise Facilities Amended and Restated Lease Agreement betweenEquitrans, L.P. and Sunrise Pipeline, L.L.C., as amended and restatedas of October 25, 2012.Filed as Exhibit 10.19 to Form 10-Q (#001-35574) for thequarterly period ended September 30, 2012. 21.1List of Subsidiaries of EQT Midstream Partners, LP.Filed herewith as Exhibit 21.1. 23.1Consent of Independent Registered Public Accounting Firm.Filed herewith as Exhibit 23.1. 31.1Rule 13(a)-14(a) Certification of Principal Executive Officer.Filed herewith as Exhibit 31.1. 31.2Rule 13(a)-14(a) Certification of Principal Financial Officer.Filed herewith as Exhibit 31.2. Each management contract and compensatory arrangement in which any director or any named executive officer participates has been marked withan asterisk (*) 123Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. INDEX TO EXHIBITS ExhibitsDescriptionMethod of Filing32Section 1350 Certification of Principal Executive Officer and PrincipalFinancial Officer.Filed herewith as Exhibit 32. 101Interactive Data File.Filed herewith as Exhibit 101. Each management contract and compensatory arrangement in which any director or any named executive officer participates has been marked withan asterisk (*) 124Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results. 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 behalfby the undersigned, thereunto duly authorized. EQT Midstream Partners, LP By:EQT Midstream Services, LLC, its General Partner By:/s/ DAVID L. PORGESDavid L. PorgesChairman, President and Chief Executive OfficerFebruary 21, 2013 Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant andin the capacities and on the dates indicated. /s/ DAVID L. PORGESChairman, President, andFebruary 21, 2013David L. PorgesChief Executive Officer(Principal Executive Officer) /s/ PHILIP P. CONTIDirector, Senior Vice PresidentFebruary 21, 2013Philip P. Contiand Chief Financial Officer(Principal Financial Officer) /s/ THERESA Z. BONEVice President and PrincipalFebruary 21, 2013Theresa Z. BoneAccounting Officer(Principal Accounting Officer) /s/ JULIAN M. BOTTDirectorFebruary 21, 2013Julian M. Bott /s/ MICHAEL A. BRYSONDirectorFebruary 21, 2013Michael A. Bryson /s/ RANDALL L. CRAWFORDDirectorFebruary 21, 2013Randall L. Crawford /s/ LEWIS B. GARDNERDirectorFebruary 21, 2013Lewis B. Gardner 125Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results.Exhibit 21.1 EQT Midstream Partners, LPSubsidiaries Company Jurisdiction of Organization Equitrans Investments, LLC Delaware Equitrans Services, LLC Delaware Equitrans, L.P. Pennsylvania Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results.Exhibit 23.1 Consent of Independent Registered Public Accounting Firm We consent to the incorporation by reference in the Registration Statement (Form S-8 No. 333-182460) pertaining to the EQT Midstream Services, LLC 2012Long-Term Incentive Plan, of our report dated February 21, 2013, with respect to the consolidated financial statements of EQT Midstream Partners, LP,included in this Annual Report (Form 10-K) for the year ended December 31, 2012. /s/ Ernst & Young LLPPittsburgh, PennsylvaniaFebruary 21, 2013 Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results.Exhibit 31.1 CERTIFICATION I, David L. Porges, certify that: 1. I have reviewed this Annual Report on Form 10-K of EQT Midstream Partners, LP; 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 thestatements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by thisreport; 3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects thefinancial 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 and I are responsible for establishing and maintaining disclosure controls and procedures (as defined inExchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have: a. Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under oursupervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us byothers within those entities, particularly during the period in which this report is being prepared; b. Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about theeffectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and c. Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s mostrecent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likelyto materially affect, the registrant’s internal control over financial reporting; and 5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to theregistrant’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 arereasonably 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 internalcontrol over financial reporting. Date: February 21, 2013EQT Midstream Partners, LP /s/ David L. PorgesDavid L. PorgesChairman, President and Chief Executive Officer,EQT Midstream Services, LLC, the registrant’sGeneral Partner Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results.Exhibit 31.2 CERTIFICATION I, Philip P. Conti, certify that: 1. I have reviewed this Annual Report on Form 10-K of EQT Midstream Partners, LP; 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 thestatements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by thisreport; 3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects thefinancial 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 and I are responsible for establishing and maintaining disclosure controls and procedures (as defined inExchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have: a. Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under oursupervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us byothers within those entities, particularly during the period in which this report is being prepared; b. Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about theeffectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and c. Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s mostrecent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likelyto materially affect, the registrant’s internal control over financial reporting; and 5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to theregistrant’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 arereasonably 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 internalcontrol over financial reporting. Date: February 21, 2013EQT Midstream Partners, LP /s/ Philip P. ContiPhilip P. ContiSenior Vice President and Chief Financial Officer,EQT Midstream Services, LLC, the registrant’sGeneral Partner Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results.Exhibit 32 CERTIFICATION In connection with the Annual Report of EQT Midstream Partners, LP (the “Company”) on Form 10-K for the period ended December 31, 2012, as filed withthe Securities and Exchange Commission on the date hereof (the “Report”), the undersigned certify pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that: (1) The Report 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 the Report fairly presents, in all material respects, the financial condition and results of operations of theCompany. /s/ David L. PorgesFebruary 21, 2013David L. PorgesChairman, President and Chief Executive Officer, EQTMidstream Services, LLC, the Company’s General Partner /s/ Philip P. ContiFebruary 21, 2013Philip P. ContiSenior Vice President and Chief Financial Officer, EQTMidstream Services, LLC, the Company’s General Partner A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature thatappears in typed form within the electronic version of this written statement required by Section 906, has been provided to EQT Midstream Partners, LP andwill be retained by EQT Midstream Partners, LP and furnished to the Securities and Exchange Commission or its staff upon request. Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results.Source: EQT Midstream Partners, LP, 10-K, February 21, 2013Powered by Morningstar® Document Research℠The information contained herein may not be copied, adapted or distributed and is not warranted to be accurate, complete or timely. The user assumes all risks for any damages or losses arising from any use of this information,except to the extent such damages or losses cannot be limited or excluded by applicable law. Past financial performance is no guarantee of future results.

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