hesm-10k_20191231.htm

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes ☐ 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 ☐ 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 of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐

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

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

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

The aggregate market value of common units representing limited partner interests (“Common Units”) in Hess Midstream Operations LP (formerly known as Hess Midstream Partners LP, the predecessor registrant to Hess Midstream LP) held by non‑affiliates of the registrant was approximately $321.7 million on June 28, 2019, based on the outstanding Common Units and closing market price $19.50 per Common Unit on such date, which is the last business day of the registrant’s most recently completed second fiscal quarter.

17,960,655 Class A shares representing limited partner interests (“Class A Shares”) in the registrant were outstanding as of February 10, 2020.

This Annual Report on Form 10-K, including information incorporated by reference herein, contains “forward-looking statements” within the meaning of U.S. federal securities laws. Words such as “anticipate,” “estimate,” “expect,” “forecast,” “guidance,” “could,” “may,” “should,” “would,” “believe,” “intend,” “project,” “plan,” “predict,” “will,” “target” and similar expressions identify forward-looking statements, which are not historical in nature. Our forward-looking statements may include, without limitation: our future financial and operational results; our business strategy; our industry; our expected revenues; our future profitability; our projected budget and capital expenditures (including for maintenance or expansion projects and environmental expenditures) and the impact of such expenditures on our performance; and future economic and market conditions in the oil and gas industry.

Forward-looking statements are based on our current understanding, assessments, estimates and projections of relevant factors and reasonable assumptions about the future. Forward-looking statements are subject to certain known and unknown risks and uncertainties that could cause actual results to differ materially from our historical experience and our current projections or expectations of future results expressed or implied by these forward-looking statements. The following important factors could cause actual results to differ materially from those in our forward-looking statements:

As and when made, we believe that our forward-looking statements are reasonable. However, given these risks and uncertainties, caution should be taken not to place undue reliance on any such forward-looking statements since such statements speak only as of the date when made and there can be no assurance that such forward-looking statements will occur and actual results may differ materially from those contained in any forward-looking statement we make. Except as required by law, we undertake no obligation to publicly update or revise any forward-looking statements, whether because of new information, future events or otherwise.

Unless otherwise stated or the context otherwise indicates, references in this report to “Predecessor,” “we,” “us” or like terms, when referring to periods prior to April 10, 2017, refer to Hess Midstream Partners LP Predecessor (“Predecessor”), our predecessor for accounting purposes. All references to “Hess Midstream Operations LP,” “the Partnership,” “us,” “we” or similar terms, when referring to periods between April 10, 2017 and December 16, 2019, refer to Hess Midstream Operations LP (formerly known as Hess Midstream Partners LP, the predecessor registrant to Hess Midstream LP), including its consolidated subsidiaries. All references to “Hess Midstream LP,” “the Company,” “us,” “our,” “we” or similar terms, when referring to periods subsequent to December 16, 2019, refer to Hess Midstream LP, including its consolidated subsidiaries.

Throughout this report, the following company or industry specific terms and abbreviations are used:

Barrel: One stock tank barrel, or 42 U.S. gallons liquid volume, used in reference to crude oil or other liquid hydrocarbons.

Btu: One British thermal unit—a measure of the amount of energy required to raise the temperature of a one‑pound mass of water one degree Fahrenheit at sea level.

Cf: Cubic foot or feet is a common unit of gas measurement. One standard cubic foot equals the volume of gas in one cubic foot measured at standard temperature (60 degrees Fahrenheit) and standard pressure (14.73 pounds standard per square inch).

Common carrier pipeline: A pipeline engaged in the transportation of crude oil, refined petroleum products or NGL as a common carrier for hire.

Crude oil: A mixture of hydrocarbons that exists in liquid phase in underground reservoirs.

Fractionation: Fractionation is accomplished by controlling the temperature and pressure of the stream of mixed NGL in order to take advantage of the different boiling points of separate components. NGL fractionation facilities separate mixed NGL streams into discrete components such as ethane, propane, normal butane, isobutane and natural gasoline.

Liquefied petroleum gas: A mixture of hydrocarbon gases commonly used as a fuel, including propane and butane.

NGL: Natural gas liquids, which are the hydrocarbon liquids contained within natural gas.

Sour gas: Natural gas that is relatively high in sulfur content, requiring additional processing to remove the sulfur.

Throughput: The volume of crude oil, natural gas, NGLs, water and refined petroleum products transported or passing through a pipeline, plant, terminal or other facility during a particular period.

Williston Basin: One of the largest structural-sedimentary basins in North America, spanning across North Dakota, South Dakota, Montana, Saskatchewan and Manitoba, with a surface area of approximately 143,000 square miles within the United States and multiple petroleum reservoirs.

Y‑grade: A classification used to describe the extent to which certain hydrocarbons can be stored at a specified pressure, making the hydrocarbon easier to move in a liquid state.

We are a fee-based, growth-oriented, limited partnership formed by Hess Infrastructure Partners GP LLC (“HIP GP LLC”) and our general partner in 2019 to own, operate, develop and acquire a diverse set of midstream assets and provide fee-based services to Hess Corporation (“Hess”) and third-party customers. We are managed and controlled by Hess Midstream GP LLC (“GP LLC”), the general partner of our general partner.

Our assets are primarily located in the Bakken and Three Forks shale plays in the Williston Basin area of North Dakota, which we collectively refer to as the Bakken and which is one of the most prolific crude oil producing basins in North America. Hess dedicated substantially all of its existing and future owned or controlled production in the Bakken under our long-term, fee-based agreements and intends to use us as the primary midstream vehicle to support the growth of its Bakken production assets and grow its midstream business. We generate substantially all of our revenues by charging fees for gathering, compressing and processing natural gas and fractionating NGLs; gathering, terminaling, loading and transporting crude oil and NGLs; storing and terminaling propane; and gathering and disposing of produced water.

On December 16, 2019, the Company and the Partnership completed the transactions (the “Restructuring”) contemplated by the partnership restructuring agreement, dated October 3, 2019, by and among the Company, the Partnership and the other parties thereto. As a result of the Restructuring, the Company was delegated control of the Partnership and replaced the Partnership as its publicly traded successor.

Prior to the Restructuring, the Company and the Partnership were indirectly controlled by HIP GP LLC, the general partner of Hess Infrastructure Partners LP (“HIP”). HIP was originally formed as a joint venture between Hess and GIP II Blue Holding Partnership, L.P. (“GIP” and together with Hess, the “Sponsors”).

Pursuant to the Restructuring, which was consummated on December 16, 2019, the Partnership acquired HIP, including HIP’s 80% interest in the Joint Interest Assets, 100% interest in Hess Water Services and the outstanding economic general partner interest and IDRs. The Partnership’s organizational structure converted from a master limited partnership into an “Up-C” structure in which the Partnership’s public unitholders received newly issued Class A shares (“Class A Shares”) representing limited partner interests in Hess Midstream LP in a one-for-one exchange. The Partnership changed its name to “Hess Midstream Operations LP” and became a consolidated subsidiary of the Company. The acquisition of HIP was accounted for as an acquisition of a business under common control. See Item 8. Financial Statements and Supplementary Data. Note 3, Acquisitions.

On March 22, 2019, we acquired 100% of the membership interest in Tioga Midstream Partners LLC, which owns oil, gas, and water gathering assets, from Summit Midstream Partners, LP (the “Tioga System Acquisition”). The Tioga System, located in Williams County in western North Dakota, is complementary to our infrastructure, and is currently delivering volumes into our gathering system. We paid $89.2 million in cash at closing, net of cash acquired, and recognized a contingent liability for additional potential payments of $10 million in future periods subject to certain performance metrics.

On March 1, 2019, HIP acquired 100% of the membership interest in Hess Water Services, which owns Hess’ Bakken water services business, for $225.0 million in cash.

See Item 8. Financial Statements and Supplementary Data. Note 3, Acquisitions for further details.

On January 25, 2018, we entered into a 50/50 joint venture with Targa Resources Corp. (“Targa”) to construct a new 200 MMcf/d gas processing plant called Little Missouri 4 (“LM4”). LM4 was placed in service in the third quarter of 2019. Targa is the operator of the plant.

We conduct our business through three operating segments: (1) gathering, (2) processing and storage and (3) terminaling and export. See Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations for further details.

We intend to expand our business and have multiple potential alternatives to pursue, including capitalizing on organic growth opportunities in the Bakken and pursuing opportunities to add additional Hess and third‑party throughput volumes in the future, and by acquiring additional midstream assets from Hess or third parties.

Our gathering business consists of the Partnership’s 100% interest in (i) Hess North Dakota Pipelines Operations LP (“Gathering Opco”), which owns our North Dakota natural gas, NGL and crude oil gathering systems, and (ii) Hess Water Services, which owns our produced water gathering and disposal facilities. The following sections describe in more detail these assets and the related services that we provide.

A natural gas gathering and compression system located primarily in McKenzie, Williams and Mountrail Counties, North Dakota connecting Hess and third‑party owned or operated wells to the Tioga Gas Plant, the LM4 plant, and third‑party pipeline facilities. This gathering system consists of approximately 1,350 miles of high and low pressure natural gas and NGL gathering pipelines with a current capacity of up to approximately 450 MMcf/d, including an aggregate compression capacity of approximately 240 MMcf/d. Our natural gas gathering system includes approximately 80 miles of gas gathering pipelines that we acquired from Summit Midstream Partners, LP in the Tioga System Acquisition. In addition, included within our natural gas gathering and compression system, the Hawkeye Gas Facility, located in McKenzie County, has the capability to compress approximately 50 MMcf/d of natural gas, extract imbedded NGLs and remove water vapor. The Hawkeye Gas Facility entered into service in 2017. The compressed gas and mixed NGLs are transported to the Tioga Gas Plant and the LM4 plant either as separate or combined streams for processing. Our gathering system capacity can be increased via installation of additional compression equipment.

A crude oil gathering system located primarily in McKenzie, Williams and Mountrail Counties, North Dakota, connecting Hess and third‑party owned or operated wells to the Ramberg Terminal Facility, the Tioga Rail Terminal and the Johnson’s Corner Header System. The crude oil gathering system consists of approximately 550 miles of crude oil gathering pipelines with a current capacity of up to approximately 240 MBbl/d. Our crude oil gathering system includes approximately 75 miles of crude oil gathering pipelines that we acquired from Summit Midstream Partners, LP in the Tioga System Acquisition.

Included within our crude oil gathering system is our Hawkeye Oil Facility, which is a crude oil pumping and truck unloading facility located in McKenzie County, North Dakota. The Hawkeye Oil Facility entered into service in 2017. The facility receives crude oil through pipeline and truck deliveries from Hess and third parties and transports it by pipeline to the Ramberg Terminal Facility. Total receipt capacity of the facility is approximately 75 MBbl/d which can be filled solely through our crude oil gathering system or through a combination of our crude oil gathering system and truck unloading bays. The facility has six truck unloading bays with an aggregate capacity of approximately 30 MBbl/d. The facility has a redelivery capability of approximately 75 MBbl/d through a 12‑inch pipeline connected to the Ramberg Terminal Facility. The facility also has two crude oil storage tanks with a combined working storage capacity of approximately 10 MBbls. Our gathering system capacity can be increased through the installation of additional pumping equipment.

A produced water gathering system located primarily in Williams and Mountrail counties, North Dakota that transports produced water from the wellsite by approximately 250 miles of pipeline in gathering systems or by third-party trucking to water handling facilities for disposal. Our produced water gathering system includes approximately 75 miles of water gathering pipelines that we acquired from Summit Midstream Partners, LP in the Tioga System Acquisition. As of December 31, 2019, we had 2 water handling and disposal facilities that were mechanically complete, with a combined permitted disposal capacity of 20 MBbl/d. These water handling and disposal facilities are owned and operated by Hess Water Services and primarily service the water pipeline gathering systems. We also transport produced water to 12 water handling and disposal facilities operated by third parties that have a combined permitted disposal capacity of approximately 170 MBbl/d.

The following table sets forth certain information regarding our gathering assets, which operate under long‑term, fee‑based commercial agreements with Hess:

Our processing and storage business consists of (i) the Partnership’s 100% interest in Hess TGP Operations LP (“HTGP Opco”), which owns the Tioga Gas Plant, (ii) the Partnership’s 50% interest in the LM4 gas processing plant operated by Targa, and (iii) the Partnership’s 100% interest in Hess Mentor Storage Holdings LLC (“Mentor Holdings”), which owns the Mentor Storage Terminal. The following sections describe in more detail these assets and the related services that we provide.

The Tioga Gas Plant (“TGP”) is located in Tioga, North Dakota, and consists of (i) a 250 MMcf/d state‑of‑the‑art cryogenic processing facility with full ethane extraction capabilities that produces low Btu, pipeline‑quality natural gas and (ii) a 60 MBbl/d fractionation facility with full NGL fractionation capabilities for ethane, propane, butane and natural gasoline. The plant receives natural gas produced from Hess‑operated and third‑party operated wells in the Bakken through our North Dakota gathering systems as well as third‑party gathering systems. The Tioga Gas Plant is one of the largest natural gas processing and fractionation plants in North Dakota. The plant is capable of processing sour gas and can recover up to 225 long tons per day of sulfur.

The plant was initially constructed in 1954. The plant subsequently underwent a large‑scale expansion, refurbishment and optimization project that was completed in 2014, during which a new cryogenic processing train with a current processing capacity of 250 MMcf/d was installed. In 2019, we announced plans to expand natural gas processing capacity at the Tioga Gas Plant by 150 MMcf/d for total processing capacity of 400 MMcf/d, to be in service by mid-2021. The150 MMcf/d expansion is expected to add residue and y-grade liquids processing capacity to the existing full fractionation and ethane extraction capability of the current plant, and product takeaway has been secured.

The plant includes the North Dakota Natural Gas Pipeline, an approximately 60‑mile, 10.75‑inch residue gas pipeline that connects to the interstate Northern Border Pipeline near Cherry Creek in McKenzie County, North Dakota. This pipeline was constructed in 1992 and is capable of delivering 65 MMcf/d of residue gas to the Northern Border Pipeline at Cherry Creek and up to 25 MMcf/d of residue gas to gas lift operations in McKenzie and Williams Counties, North Dakota. The plant also has direct residue gas pipeline connections at the tailgate of the plant to both the Alliance Pipeline and the Williston Basin Interstate Pipeline. The total residue gas offtake capacity from the plant is approximately 190 MMcf/d, consisting of 65 MMcf/d to the Alliance Pipeline, 65 MMcf/d to the Northern Border Interstate Pipeline, 35 MMcf/d to the Williston Basin Interstate Pipeline and 25 MMcf/d to gas lift operations in McKenzie and Williams Counties.

The plant also includes four NGL truck loading racks with an aggregate loading capacity of approximately 10 MBbl/d of propane to serve the local propane market, as well as 22 NGL bullet storage tanks and five NGL storage tanks with a combined shell capacity of approximately 35 MBbls of propane, 20 MBbls of butane and 35 MBbls of natural gasoline. The total NGL production capability of the plant is approximately 60 MBbl/d, with interconnections into the Vantage Pipeline, the Alliance Pipeline and interconnecting pipelines with our Tioga Rail Terminal. Additionally, the plant includes a CNG terminal that is capable of compressing approximately 2.5 MMcf/d of natural gas to 3,600 psig and loading in excess of 100 light duty CNG‑fueled vehicles and up to 10 CNG cylinder trailers per day for drilling and hydraulic fracturing operations, for a combined capacity of approximately 20 MGal/d.

The Partnership owns a 50% interest in a joint venture with Targa, which constructed and placed in service in the third quarter of 2019, a new 200 MMcf/d gas processing plant called Little Missouri 4, or LM4, located at Targa’s existing Little Missouri facility, south of the Missouri River in McKenzie County, North Dakota. We are entitled to 100 MMcf/d of the plant’s processing capacity. The plant receives natural gas produced from Hess-operated and third-party operated wells in the Bakken through our gathering systems as well as third-party gathering systems. The plant also has direct residue gas and NGL pipeline connections at the tailgate of the plant, with export capacity of approximately 100 MMcf/d of natural gas to the Northern Border Interstate Pipeline and 40 MBbl/d of NGLs to ONEOK Elk Creek Pipeline.

Our Mentor Storage Terminal consists of a propane storage cavern and a rail and truck loading and unloading facility located on approximately 40 acres in Mentor, Minnesota. The Mentor Storage Terminal has an aggregate working storage capacity of approximately 330 MBbls, consisting of an underground cavern with a working storage capacity of approximately 325 MBbls and three above‑ground bullet storage tanks with an aggregate working storage capacity of approximately 5 MBbls. The terminal also has a dehydration facility, 11 rail unloading racks and two truck loading racks. The cavern and truck loading racks each have a propane injection and withdrawal capacity of approximately 6 MBbl/d.

The Mentor Storage Terminal, a mined cavern for liquefied petroleum gas, was constructed in 1962. The rock from which the cavern was constructed is classified as zoisite, a rare, marble‑like rock that has essentially no porosity or permeability, which makes it excellent for the purpose of liquid hydrocarbon storage. Constant underground temperature provides uniform operating conditions in the cavern.

Propane is received at the Mentor Storage Terminal by rail, and shipments and deliveries vary by season. Hess utilizes our propane storage services to mitigate the impact on its operations from seasonal variations in the demand for propane. As a result, at Hess’ direction, we generally fill the cavern with propane during the warmer months when demand for propane is low, and gradually withdraw propane from the cavern during colder months when demand is higher.

The following table sets forth certain information regarding our processing and storage assets, which operate under long‑term, fee‑based commercial agreements with Hess:

Our terminaling and export business consists of the Partnership’s 100% interest in Hess North Dakota Export Logistics Operations LP (“Logistics Opco”), which owns the Ramberg Terminal Facility, the Tioga Rail Terminal, our crude oil rail cars and the Johnson’s Corner Header System. The following sections describe in more detail these assets and the related services that we provide.

Our Ramberg Terminal Facility is a crude oil pipeline and truck unloading facility located in Williams County, North Dakota that receives crude oil by pipeline and truck from Hess and third parties and exports crude oil by transporting it by pipeline to our Tioga Rail Terminal for loading onto crude oil rail cars or by injecting it directly into third‑party interstate pipeline systems. The facility has a combined pipeline and truck receipt capability of approximately 200 MBbl/d. Up to approximately 130 MBbl/d of crude oil can enter the facility through our crude oil gathering system. Crude oil can also enter the facility through fourteen truck unloading bays with a combined truck unloading capacity of approximately 70 MBbl/d.

The facility has a redelivery capability of up to approximately 285 MBbl/d through the following pipelines:

The Ramberg Terminal Facility was constructed in 2006 and expanded in 2016. The facility has a combined shell storage capacity of approximately 40 MBbls, with an additional combined 240 MBbls of storage capacity with third parties.

A 140 MBbl/d crude oil and 30 MBbl/d NGL rail loading terminal in Tioga, North Dakota that is connected to the Tioga Gas Plant, the Ramberg Terminal Facility and our crude oil gathering system.

The approximate 140 MBbl/d crude oil loading facility includes a dual loop track with 21 crude oil loading arms that commenced service in 2011. The terminal loads crude oil rail cars owned by us and third parties. The terminal also has three crude oil storage tanks with a combined shell storage capacity of approximately 290 MBbls. The terminal receives up to 30 MBbl/d of crude oil directly from our crude oil gathering system and through a 14‑inch crude oil pipeline connected to, and included as part of, our Ramberg Terminal Facility.

The terminal is capable of loading crude oil unit trains, which are dedicated trains (typically ranging from approximately 100 to 110 cars) chartered for a single delivery destination that usually receive priority scheduling and result in a more cost‑effective method of shipping than standard rail shipment.

The terminal is capable of receiving up to 30 MBbl/d of NGLs through three NGL pipelines connected to the Tioga Gas Plant, including: (i) an eight‑inch propane pipeline with a capacity of approximately 35 MBbl/d; (ii) a six‑inch butane pipeline with a capacity of approximately 15 MBbl/d; and (iii) a six‑inch mixed NGL pipeline with a capacity of approximately 10 MBbl/d. The terminal also includes separate ladder tracks with track space for over 385 NGL rail cars and 16 NGL loading arms that commenced service in 2014. The NGL rail cars are leased by Hess and third parties.

The terminal has a direct rail connection to the BNSF Railway, which in turn connects to the Union Pacific, CSX, Norfolk Southern and other Class 1 railroads. From the BNSF Railway, rail cars enter the Tioga Rail Terminal to be loaded with crude oil. Crude oil loaded onto rail cars at the terminal may be transported to various delivery points in the East Coast, West Coast and Gulf Coast regions of the United States. The terminal receives NGLs for loading onto rail cars for transportation to various delivery points in North America.

We own a total of 550 crude oil rail cars, which we operate as unit trains consisting of approximately 100 to 110 crude oil rail cars, with which we provide crude oil transportation services to Hess or third parties from the Tioga Rail Terminal to various delivery points in the East Coast, West Coast and Gulf Coast regions of the United States. Our crude oil rail cars were constructed between April 2015 and October 2015 to the most recent DOT‑117 safety standards. The effective capacity of the crude oil rail cars depends on round‑trip times to destination. For the year ended December 31, 2019, the average round‑trip duration was approximately 12 days and, based on this, the aggregate working capacity of our crude oil rail cars was approximately 32 MBbl/d. Our crude oil rail cars have a shell capacity of 728 Bbls per car and an effective loading capacity of approximately 92%, or approximately 670 Bbls per car.

The Johnson’s Corner Header System is a crude oil pipeline header system located in McKenzie County, North Dakota that receives crude oil by pipeline from Hess and third parties and delivers crude oil to third‑party interstate pipeline systems. It has a delivery capacity of approximately 100 MBbl/d of crude oil. The Johnson’s Corner Header System entered into service in 2017.

The following table sets forth certain information regarding our terminaling and export assets, which operate under a long‑term, fee‑based commercial agreement with Hess:

Effective January 1, 2014, we entered into fee-based commercial agreements with certain subsidiaries of Hess to provide (i) gas gathering, (ii) crude oil gathering, (iii) gas processing and fractionation, (iv) storage services, and (v) terminal and export services. Effective January 1, 2019, in connection with acquisition of Hess Water Services, we entered into long-term fee-based water services agreements with certain subsidiaries of Hess. In addition, in 2018 and for a portion of 2017, Hess Water Services had documented intercompany arrangements with certain subsidiaries of Hess pursuant to which it provided produced water gathering and disposal services and charged agreed-upon fees per barrel for the services performed.

Under our commercial agreements, we provide gathering, compression, processing, fractionation, storage, terminaling, loading, transportation and produced water disposal services to Hess, for which we receive a fee per barrel of crude oil, barrel of water, Mcf of natural gas, or Mcf equivalent of NGLs, as applicable, delivered during each month, and Hess is obligated to provide us with minimum volumes of crude oil, water, natural gas and NGLs. These agreements also include inflation escalators and fee recalculation mechanisms that allow fees to be adjusted annually.

In September 2018, we amended and restated our gas gathering and gas processing and fractionation agreements with Hess to enable us to provide certain services to Hess in respect of volumes to be delivered to and processed at the LM4 plant. Effective January 1, 2019, Hess pays us a combined processing fee per Mcf of natural gas, or Mcf equivalent of NGLs, as applicable, for aggregate volumes processed at LM4 and TGP. In addition, the fee recalculation mechanism continues to apply to the amended and restated agreements and, effective January 1, 2019, incorporates the revenues received and expected to be received by Hess from sourcing third-party dedicated production in order to further align the interests of us and Hess in promoting the growth of third-party volumes on our Bakken assets.

Except for the water services agreements and except for a certain gathering sub-system as described below, each of our commercial agreements with Hess retains its initial 10-year term effective January 1, 2014 (“Initial Term”) and we have the unilateral right to extend each commercial agreement for one additional 10-year term (“Secondary Term”). The Initial Term for the water services agreements is 14 years effective January 1, 2019 and the Secondary Term is 10 years. The amended and restated gas gathering agreement also extends the Initial Term of the gathering agreement with respect to a certain gathering sub-system by 5 years to provide for a 15-year Initial Term and decreases the Secondary Term for that gathering sub-system by 5 years to provide for a 5-year Secondary Term. During the Secondary Term of the agreements, the fee recalculation model will be replaced by an inflation-based fee structure.

We believe these commercial agreements provide us with stable and predictable cash flows and minimal direct exposure to commodity prices. The following table sets forth additional information regarding our commercial agreements with Hess:

Our operations are subject to extensive and frequently‑changing federal, state and local laws, regulations and ordinances relating to the protection of the environment. Among other things, these laws and regulations govern the emission or discharge of pollutants into or onto the land, air and water, the handling and disposal of solid and hazardous wastes and the remediation of contamination. As with the industry generally, compliance with existing and anticipated environmental laws and regulations increases our overall cost of business, including our capital costs to construct, maintain, operate and upgrade equipment and facilities. While these laws and regulations affect our maintenance capital expenditures and net income, we believe they do not currently affect our competitive position. However, these laws and regulations are subject to changes, or to changes in the interpretation of such laws and regulations, by regulatory authorities, and continued and future compliance with such laws and regulations may require us to incur significant expenditures. Additionally, violation of environmental laws, regulations and permits can result in the imposition of significant administrative, civil and criminal penalties, injunctions limiting our operations, investigatory or remedial liabilities or bans or delays in the construction of additional facilities or equipment. Additionally, a release of hydrocarbons or hazardous substances into the environment could, to the extent the event is not insured, subject us to substantial expenses, including costs to comply with applicable laws and regulations and to resolve claims by third parties for personal injury or property damage, or by the U.S. federal government or state governments for natural resources damages. These impacts could directly and indirectly affect our business and have an adverse impact on our financial position, results of operations and liquidity. We cannot currently determine the amounts of such potential future impacts.

Our operations are subject to the Clean Air Act and its regulations and comparable state and local statutes and regulations in connection with air emissions from our operations. Under these laws, permits may be required before construction can commence on a new source of potentially significant air emissions, and operating permits may be required for sources that are already constructed. These permits may require controls on our air emission sources, and we may become subject to more stringent regulations requiring the installation of additional emission control technologies.

Future expenditures may be required to comply with the Clean Air Act and other federal, state and local requirements for our various sites, including our pipeline, processing, transportation, and storage facilities.

These air emissions requirements also affect Hess’ Bakken operations from which we receive a substantial portion of our revenues. Hess has been required in the past, and may be required in the future, to incur significant capital expenditures to comply with new legislative and regulatory requirements relating to its operations. To the extent these capital expenditures have a material effect on Hess, they could have a material effect on our business and results of operations.

Legislative and regulatory measures to address greenhouse gas emissions (including carbon dioxide, methane and other gases) are in various phases of discussion or implementation. These include requirements to report emissions of greenhouse gases to the Environmental Protection Agency, or EPA, and state actions to develop and implement statewide or regional programs, each of which require or could require reductions in our greenhouse gas emissions or those of Hess. Requiring reductions in greenhouse gas emissions could result in increased costs to (i) operate and maintain our facilities, (ii) install new emission controls at our facilities and (iii) administer and manage any greenhouse gas emissions programs, including acquiring emission credits or allotments. These requirements may also significantly affect Hess’ Bakken operations and may have an indirect effect on our business, financial condition and results of operations.

Further, the EPA has proposed regulations under the Clean Air Act addressing greenhouse gases, to which some of our facilities may become subject. Rules and regulations have been proposed, as amended and challenged, including rules and regulations governing methane emissions from oil and natural gas production and natural gas processing and transmission facilities. Substantial uncertainty regarding their implementation and timing remains. Congress continues to periodically consider legislation on greenhouse gas emissions, which may include a delay in the implementation of greenhouse gas regulations by EPA or a limitation on EPA’s authority to regulate greenhouse gases, or potentially a tax on carbon, although the ultimate adoption and form of any federal legislation cannot presently be predicted.

In addition to potential domestic regulation of greenhouse gases, there continues to be international interest in a global framework for greenhouse gas reductions. While significant uncertainty exists as to future regulation of methane or other greenhouse gas emissions under the Clean Air Act or other local, regional, or international regulatory regimes, the impact of future regulatory and legislative developments, if adopted or enacted, including any cap-and-trade program, is likely to result in increased compliance costs, increased utility costs, additional operating restrictions on our business and an increase in the cost of products generally. Although such costs may impact our business directly or indirectly by impacting Hess’ facilities or operations, the extent and magnitude of that impact cannot be reliably or accurately estimated due to the present uncertainty regarding the additional measures and how they will be implemented.

Many of the environmental laws and regulations affecting our operations relate to the release of hazardous substances or solid wastes into soils, groundwater and surface water, and include measures to control pollution of the environment. These laws generally regulate the generation, storage, treatment, transportation and disposal of solid and hazardous waste. They also require corrective action, including investigation and remediation, at a facility where such waste may have been released or disposed.

CERCLA. The Comprehensive Environmental Response, Compensation, and Liability Act, or CERCLA, which is also known as Superfund, and comparable state laws impose liability, without regard to fault or to the legality of the original conduct, on certain classes of persons that contributed to the release of a “hazardous substance” into the environment. These persons include former and present owners or operators of the site where the release occurred and the transporters and generators of the hazardous substances found at the site. Under CERCLA, these persons may be subject to joint and several liability for the costs of cleaning up the hazardous substances that have been released into the environment, for damages to natural resources, and for the costs of certain health studies. CERCLA also authorizes the EPA and, in some instances, third parties to act in response to threats to the public health or the environment and to seek to recover from the responsible persons the costs they incur. It is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by hazardous substances or other pollutants released into the environment. In the course of our ordinary operations, we may generate waste and use substances that fall within CERCLA’s definition of a “hazardous substance” and, as a result, may be jointly and severally liable under CERCLA for all or part of the costs required to clean up sites contaminated by those substances. Pursuant to our amended omnibus agreement, the Sponsors will indemnify us and will fund, subject to the below limit, the costs for required remedial action for our known historical and legacy spills and releases and, subject to a deductible of $100,000 per claim, for spills and releases, if any, that were existing but unknown at the time of closing of our IPO to the extent such existing but unknown spills and releases are identified within five years after closing of our IPO and relate to the Joint Interest Assets. There is a $4.5 million limit (inclusive of any punitive, special, indirect or consequential damages) on the amount for which our Sponsors will indemnify us for environmental liabilities under the amended omnibus agreement once we meet the deductible.

RCRA. We also generate solid wastes, including hazardous wastes, that are subject to the requirements of the federal Resource Conservation and Recovery Act, or RCRA, and comparable state statutes. From time to time, the EPA considers the adoption of stricter disposal standards for non‑hazardous wastes. Hazardous wastes are subject to more rigorous and costly disposal requirements than are non‑hazardous wastes. Any changes in the regulations for treatment, storage or disposal of RCRA‑regulated waste could increase our maintenance capital expenditures and operating expenses. We continue to seek methods to minimize the generation of hazardous wastes in our operations.

Hydrocarbon wastes. We currently own and lease, and Hess has in the past owned and leased, properties where hydrocarbons have been handled for many years. Although we have utilized operating and disposal practices that we believe were standard in the industry at the time, hydrocarbons or other waste may have been disposed of or released on or under the properties owned or leased by us or on or under other locations where these wastes have been taken for disposal. In addition, many of these properties have been operated by third parties whose treatment and disposal or release of hydrocarbons or other wastes was not under our control. These properties and wastes disposed thereon may be subject to CERCLA, RCRA and analogous state laws. Assuming liability is established under these laws, we could be required to remove or remediate previously disposed wastes (including wastes disposed of or released by prior owners or operators), to clean up contaminated property (including contaminated groundwater) or to perform remedial operations to prevent further contamination.

Our operations have the potential to result in the discharge of pollutants, including crude oil. Regulations under the Clean Water Act, or CWA, the Oil Pollution Act of 1990, or OPA‑90, and state laws impose regulatory burdens on our operations. Spill prevention control and countermeasure requirements of federal laws and some state laws require containment to mitigate or prevent contamination of jurisdictional waters in the event of an oil overflow, rupture or leak. For example, the Clean Water Act requires us to maintain Spill Prevention Control and Countermeasure, or SPCC, plans at many of our facilities. We maintain discharge permits for facilities required under the National Pollutant Discharge Elimination System program of the Clean Water Act and have implemented processes to oversee our compliance efforts.

In addition, the transportation and storage of crude oil or other hazardous substances over and adjacent to water involves risk and subjects us to the provisions of OPA‑90 and related state requirements. Among other requirements, OPA‑90 and the National Contingency Plan requires the owner or operator of a tank vessel or a facility to maintain an emergency plan to respond to releases of oil or other hazardous substances. Also, in case of any such release, OPA‑90 requires the responsible company to pay resulting removal costs and damages. OPA‑90 also provides for civil penalties and imposes criminal sanctions for violations of its provisions. We operate facilities at which releases of oil or other hazardous substances could occur. We have implemented emergency oil response plans for our components and facilities covered by OPA‑90, and we have established SPCC plans for facilities subject to Clean Water Act SPCC requirements.

Construction or maintenance of our pipelines, terminals and storage facilities may impact wetlands, which are also regulated under the Clean Water Act by the EPA and the U.S. Army Corps of Engineers. Regulatory requirements governing wetlands (including associated mitigation projects) may result in the delay of our pipeline projects while we obtain necessary permits and may increase the costs of new projects and maintenance activities.

We are subject to the requirements of the Occupational Safety and Health Administration, or OSHA, and comparable state statutes that regulate the protection of the health and safety of workers. In addition, the OSHA hazard communication standard requires that information be maintained about hazardous materials used or produced in operations and that this information be provided as applicable to employees, state and local government authorities and citizens.

The Endangered Species Act restricts and carries civil and criminal liability for activities that may affect endangered species or their habitats. At the federal level, the law is administered by the Fish and Wildlife Service. While some of our facilities are in areas that may be designated as habitat for endangered species, we have not incurred any material costs to comply or restrictions on our operations. However, the discovery of previously unidentified endangered species or designation of previously unidentified endangered or threatened species could cause us to incur additional costs or become subject to operating restrictions or bans in the affected area.

In the wake of derailments several years ago, the Federal Railroad Administration, or FRA, of the U.S. Department of Transportation, or DOT, and the DOT’s Pipeline Hazardous Materials Safety Administration, or PHMSA, issued several Safety Advisories and Emergency Orders directing offerors and rail carriers to take additional precautionary measures to enhance the safe shipment of bulk quantities of crude oil.

In May 2015, DOT finalized new regulations applicable to “high hazard flammable trains.” The final rule created a new North American rail car standard known as the DOT Specification 117, or DOT‑117, rail car with thicker steel and redesigned bottom outlet valves, compared to the DOT‑111 rail car. The rule also included a schedule for the phase-out or upgrade of non‑jacketed DOT‑111 rail cars in Packing Group 1 service. Currently, we believe all of our rail cars in crude oil service meet the new DOT‑117 standard. In addition, the adoption of additional federal, state or local laws or regulations, including any voluntary measures by the rail industry regarding rail car design or crude oil and liquid hydrocarbon rail transport activities, or efforts by local communities to restrict or limit rail traffic involving crude oil, could affect our business by increasing compliance costs and decreasing demand for our services, which could adversely affect our financial position and cash flows. Moreover, any disruptions in the operations of railroads, including those due to shortages of rail cars, locomotives or labor, weather‑related problems, flooding, drought, derailments, mechanical difficulties, strikes, lockouts or bottlenecks, or other force majeure events could adversely impact our customers’ ability to move their product and, as a result, could affect our business.

Section 1(b) of the Natural Gas Act, or the NGA, exempts natural gas gathering facilities from regulation by the Federal Energy Regulatory Commission, or FERC, under the NGA. Although the Federal Energy Regulatory Commission, or FERC, has not made any formal determinations with respect to our natural gas gathering facilities upstream of the Tioga Gas Plant, we believe that the natural gas pipelines in our gathering systems meet the traditional tests FERC has used to establish whether a pipeline is unregulated under the Natural Gas Act, or NGA. Similarly, we believe that the crude oil and NGL pipelines in our gathering system are not subject to FERC tariff requirements under the Interstate Commerce Act, or ICA, because they fall outside FERC’s tariff jurisdiction. However, the classification and regulation of our gathering facilities may be subject to change based on future determinations by FERC, the courts, or Congress. If it is subsequently determined that an individual facility is not exempt from FERC regulation under the NGA, such determination could decrease revenue, increase operating costs, and, depending upon the facility in question, adversely affect our results of operations and cash flows. In addition, if any of our facilities were found to have violated the NGA or the Natural Gas Policy Act, FERC has civil penalty authority under the NGA and NGPA to impose penalties for current violations of up to $1,291,894 per day for each violation and disgorgement of profits associated with any violation.

State regulation of gathering facilities and intrastate transportation pipelines generally includes various safety, environmental and, in some circumstances, nondiscriminatory take and common purchaser requirements, as well as complaint‑based rate regulation. Other state regulations may not directly apply to our business, but may nonetheless affect the availability of natural gas, crude oil and NGLs for purchase, compression and sale.

Our terminal operations, including associated pipelines, are subject to strict safety laws and regulations, including regulations under OSHA and comparable state and local regulations. We believe our terminal facilities are operated in a manner consistent with industry safe practices and standards and have fire protection in compliance with local, state and federal regulations. The tanks designed for crude oil storage at our terminals are equipped with appropriate controls that minimize emissions and promote safety. Our terminal facilities have response plans, spill prevention and control plans and other programs to respond to emergencies. Generally, rail operations are subject to federal regulations and the Association of American Railroad rules.

The transportation and storage of crude oil and other hydrocarbon products involve a risk that hazardous liquids may be released into the environment, potentially causing harm to the public or the environment. The DOT, through PHMSA and state agencies, enforces safety regulations with respect to the design, construction, operation, maintenance, inspection and management of our pipeline and storage facilities. PHMSA requires pipeline operators to implement integrity management programs, including more frequent inspections and other measures to ensure pipeline safety in high‑consequence areas, or HCAs, defined as those areas that are unusually sensitive to environmental damage, that cross a navigable waterway, or that have a high population density. The regulations require operators, including us, to (i) perform ongoing assessments of pipeline integrity, (ii) identify and characterize applicable threats to pipeline segments that could impact a HCA, (iii) improve data collection, integration and analysis, (iv) repair and remediate pipelines as necessary and (v) implement preventive and mitigating actions. These regulations contain requirements for the development and implementation of pipeline integrity management programs, which include the inspection and testing of pipelines and the correction of anomalies. PHMSA’s regulations also require that pipeline operation and maintenance personnel meet certain qualifications and that pipeline operators develop comprehensive spill response plans, including extensive spill response training for pipeline personnel. In April 2016, PHMSA published a proposed rulemaking that would expand integrity management requirements and impose new pressure testing requirements on currently regulated gas transmission pipelines. The proposal would also significantly expand the regulation of gas gathering lines, subjecting previously unregulated pipelines to requirements regarding damage prevention, corrosion control, public education programs, maximum allowable operating pressure limits, and other requirements.

States are largely preempted by federal law from regulating pipeline safety for interstate lines but most states are certified by the DOT to assume responsibility for enforcing federal intrastate pipeline regulations and inspection of intrastate pipelines. States may adopt stricter standards for intrastate pipelines than those imposed by the federal government for interstate lines; however, states vary considerably in their authority and capacity to address pipeline safety. State standards may include requirements for facility design and management in addition to requirements for pipelines. Our internal review of our assets and operations revealed small pipelines or sections of facilities that may be subject to PHMSA regulation. PHMSA may initiate proceedings with respect to any non-compliance at a future date. Nevertheless, we do not expect these developments to have a material effect on our operations or revenues.

We inspect our pipelines to determine their condition and use the inspection information to evaluate appropriate preventative maintenance activities to validate line integrity and safety. Our inspections sometimes include the use of internal line inspection tools that provide information on the physical condition of our pipelines.

On January 18, 2019, the North Dakota Industrial Commission, or NDIC, issued Oil Conditioning Order No. 29398 revising Order No. 25417, which requires producers in a Bakken, Bakken/Three Forks, Three Forks or Sanish pool fields, (collectively referred to by the Order as “the Bakken Petroleum System”), effective April 1, 2015, to heat their produced fluids to a specified minimum temperature or demonstrate that crude oil has a vapor pressure no greater than 13.7 psi prior to separation. The Order revisions allow operators more flexibility in evaluating and demonstrating compliance with the state’s vapor pressure requirements. Our commercial agreements with Hess contain product quality specification limits. However, if new or more stringent federal, state or local legal restrictions relating to the quality specification of crude oil or to crude oil transportation are adopted in areas where Hess and our other customers operate, Hess and our other customers could incur potentially significant added costs to comply with such requirements and experience delays or curtailment in the pursuit of production or development activities, which could reduce demand for our midstream services.

In October 2019, PHMSA submitted three major rules to the Federal Register, including rules focused on: the safety of gas transmission pipelines (the first of three parts of the Mega Rule), the safety of hazardous liquid pipelines, and enhanced emergency order procedures. The gas transmission rule requires operators of gas transmission pipelines constructed before 1970 to determine the material strength of their lines by reconfirming maximum allowable operating pressure (“MAOP”). In addition, the rule updates reporting and records retention standards for gas transmission pipelines. This rule will take effect on July 1, 2020. PHMSA is then expected to issue the second part of the Mega Rule focusing on repair criteria in high-consequence areas (“HCAs”) and creating new repair criteria for non-HCAs, requirements for inspecting pipelines following extreme events, updates to pipeline corrosion control requirements, and various other integrity management requirements. PHMSA is expected to subsequently issue the final part of the gas Mega Rule, the Gas Gathering Rule, focusing on requirements relating to gas gathering lines.

The safety and hazardous liquid pipelines rule (submitted by PHMSA in October 2019) extended leak detection requirements to all non-gathering hazardous liquid pipelines and requires operators to inspect affected pipelines following extreme weather events or natural disasters to address any resulting damage. This rule will also take effect on July 1, 2020. Finally, the enhanced emergency procedures rule focuses on increased emergency safety measures. In particular, this rule increases the authority of PHMSA to issue an emergency order that addresses unsafe conditions or hazards that pose an imminent threat to pipeline safety. Unlike the other two rules submitted in October 2019, this rule took effect on December 2, 2019.

The Department of Homeland Security’s, or DHS, Chemical Facility Anti‑Terrorism Standards are designed to regulate the security of high‑risk chemical facilities. The DHS issued an interim rule in April 2007 regarding risk‑based performance standards to be attained pursuant to this act and, on November 20, 2007, further issued an Appendix A to the interim rules that establishes chemicals of interest and their respective threshold quantities that trigger compliance with these interim rules. Covered facilities determined by DHS to pose a high level of security risk are required to prepare and submit Security Vulnerability Assessments or Site Security Plans as well as comply with other regulatory requirements, including those regarding inspections, audits, recordkeeping and protection of chemical‑terrorism vulnerability information. Certain of our facilities may be subject to these requirements.

Since the September 11, 2001, terrorist attacks on the United States, the U.S. government has issued warnings that energy infrastructure assets may be future targets of terrorist organizations. These developments have subjected our operations to increased risks. Increased security measures taken by us as a precaution against possible terrorist attacks may have resulted in increased costs to our business. Where required by federal, state or local laws, we believe we have prepared effective security plans for the storage and distribution facilities we operate. Terrorist attacks aimed at our facilities and any global and domestic economic repercussions from terrorist activities could adversely affect our financial condition, results of operations and cash available for distribution to our shareholders.

Governmental standards for the protection of computer-based systems and technology from cyber threats and attacks, have either been adopted or are being considered in the U.S. Congress and by U.S. Executive Branch departments and agencies, including the Department of Homeland Security. We currently may be subject to existing standards or standards implemented in the future. We have implemented cyber security programs and protocols. While we cannot guarantee their effectiveness, we continually seek to improve these protocols. A significant cyber‑attack could have a material adverse effect on our operations and those of our customers.

Certain of the pipelines connecting our facilities are constructed on rights‑of‑way granted by the apparent record owners of the property and in some instances these rights‑of‑way are revocable at the election of the grantor. In several instances, lands over which rights‑of‑way have been obtained could be subject to prior liens that have not been subordinated to the right‑of‑way grants. We have obtained permits from public authorities to cross over or under, or to lay pipelines in or along, watercourses, county roads, municipal streets and state highways and, in some instances, these permits are revocable at the election of the grantor. We have also obtained permits from railroad companies to cross over or under lands or rights-of-way, many of which are also revocable at the grantor’s election.

We believe we have satisfactory permits and/or title to all our rights-of-way. We also believe that we have satisfactory title to all of our assets.

As a result of our contractual relationship with Hess under our commercial agreements and our direct connections to Hess’ production operations in the Williston Basin, we believe that we will not face significant competition from other midstream service providers for Hess’ crude oil, natural gas or NGL gathering, processing or terminaling services or for other midstream services relating to Hess’ production operations in the Bakken.

If Hess’ production volumes decrease or if Hess’ customers reduce their purchases of crude oil, natural gas or NGLs from Hess due to the increased availability of less expensive products from other suppliers or for other reasons, Hess may meet only the minimum volume requirements of our commercial agreements (or pay the shortfall fee if it does not meet the minimum volume), which could cause a material decrease in our revenues.

The crude oil, natural gas and NGLs that we handle, process and store are directly affected by the level of supply and demand for crude oil, natural gas and NGLs in the markets served directly or indirectly by our assets. For example, we generally fill the storage cavern at our Mentor Storage Terminal with propane during the warmer months when demand for propane is low, and gradually withdraw propane from the cavern during the colder months when demand is higher. However, we believe that many effects of seasonality on our revenues are substantially mitigated through the use of our fee-based commercial agreements with Hess that include minimum volume commitments.

Our assets may experience physical damage as a result of an accident or natural disaster. These hazards have the potential to cause personal injury and loss of life, severe damage to and destruction of property and equipment, pollution or environmental damage, and suspension of operations. We are insured under certain of Hess’ corporate insurance policies and are subject to the shared deductibles and limits under those policies. We also carry insurance policies separate from Hess for business interruption, certain property damage and third-party liabilities, which include sudden and accidental pollution liabilities, at varying levels of deductibles and limits that we believe are reasonable and prudent under the circumstances to cover our operations and assets. As we continue to grow, we will continue to evaluate our policy limits and deductibles as they relate to the overall cost and scope of our insurance program.

We are managed by the board of directors and executive officers of Hess Midstream GP LLC, the general partner of our general partner. Neither we nor our subsidiaries have any employees. Hess Midstream GP LLC, as the general partner of our general partner, has the sole responsibility for providing the employees and other personnel necessary to conduct our operations. All of the employees that conduct our business are employed by affiliates of our general partner including Hess. As of December 31, 2019, Hess Midstream GP LLC and its affiliates had approximately 176 full‑time equivalent employees supporting our operations, including employees in the field performing services and support staff from other offices.

The principal office of our Company is located at 1501 McKinney Street, Houston, Texas 77010.

We make available free of charge through our website, at www.hessmidstream.com, our annual report on Form 10‑K, quarterly reports on Form 10‑Q, current reports on Form 8‑K and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), as soon as reasonably practicable after such material is electronically filed with or furnished to the SEC. The information on our website is not incorporated by reference in this report. Our Code of Business Conduct and Ethics, Corporate Governance Guidelines, and the Audit Committee charter are available on our website and are also available free of charge upon request to Investor Relations at our principal executive office. We also file with the New York Stock Exchange (NYSE) an annual certification that our Chief Executive Officer is unaware of any violation of the NYSE’s corporate governance standards.

Our business activities and the value of our securities are subject to significant risks, including the risk factors described below. These risk factors could negatively affect our operations, financial condition, liquidity and results of operations, and as a result, holders and purchasers of our securities could lose part or all of their investments. It is possible that additional risks relating to our securities may be described in a prospectus if we issue securities in the future.

Hess currently accounts for substantially all of our revenues. If Hess changes its business strategy, is unable for any reason, including financial or other limitations, to satisfy its obligations under our commercial agreements, our revenues would decline and our financial condition, results of operations, cash flows and ability to make distributions to our shareholders could be materially and adversely affected.

For the year ended December 31, 2019, substantially all of our revenues were attributable to our fee‑based commercial agreements with Hess, including revenues from third‑party volumes delivered under these agreements. We expect that we will continue to derive substantially all of our revenues in the near term under multiple commercial agreements with Hess and any event, whether in our areas of operation or elsewhere, that materially and adversely affects Hess’ financial condition, results of operations or cash flows may adversely affect our ability to sustain or increase cash distributions to our shareholders. Accordingly, we are indirectly subject to the operational and business risks of Hess, the most significant of which include the following:

We may not generate sufficient distributable cash flow to support the payment of the minimum quarterly distribution to our shareholders.

In order to support the payment of the minimum quarterly distribution of $0.30 per Class A Share per quarter, or $1.20 per Class A Share on an annualized basis, we must generate distributable cash flow of approximately $85.3 million per quarter, or approximately $341.3 million per year, based on Hess’ and GIP’s noncontrolling interest in us and the number of Class A Shares outstanding as of December 31, 2019. We may not generate sufficient distributable cash flow each quarter to support the payment of the minimum quarterly distribution. The amount of cash we can distribute on our Class A Shares principally depends upon the amount of cash we generate from our operations, which will fluctuate from quarter to quarter based on, among other things:

In addition, the actual amount of distributable cash flow we generate will also depend on other factors, some of which are beyond our control, including:

Hess may suspend, reduce or terminate its obligations under our commercial agreements in certain circumstances, which could have a material adverse effect on our financial condition, results of operations, cash flows and ability to make distributions to our shareholders.

Our commercial agreements with Hess include provisions that permit Hess to suspend or terminate its obligations under the applicable agreement if certain events occur. These events include our failure to perform or comply with a material warranty, covenant or obligation under the applicable commercial agreement following the expiration of a specified cure period. In addition, Hess may suspend or reduce its obligations under our commercial agreements if a force majeure event prevents us from performing required services under the applicable agreement. Hess has the ability to make such decisions notwithstanding the fact that they may significantly and adversely affect us. Any such reduction or suspension or termination of Hess’ obligations would have a material adverse effect on our financial condition, results of operations, cash flows and ability to make distributions to our shareholders.

Because of the natural decline in production from existing wells in our areas of operation, our success depends, in part, on Hess and other producers replacing declining production and also on our ability to secure new sources of natural gas and crude oil. Any decrease in the volumes of natural gas or crude oil that we handle could adversely affect our business and operating results.

The natural gas and crude oil volumes that support our business depend on the level of production from natural gas and crude oil wells connected to our facilities, which may be less than expected and will naturally decline over time. As a result, our cash flows associated with these wells will also decline over time. In order to maintain or increase throughput levels at our facilities, Hess and other producers for which we currently or in the future may handle volumes at our facilities must replace declining production, or we must obtain new sources of natural gas and crude oil. The primary factors affecting our ability to obtain non‑dedicated sources of natural gas and crude oil include (i) the level of successful drilling activity in our areas of operation, (ii) our ability to compete for volumes from successful new wells and (iii) our ability to compete successfully for volumes from sources connected to other pipelines.

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 systems or the rate at which production from a well declines. In addition, we have no control over Hess or other producers or their drilling or production decisions, which are affected by, among other things:

Fluctuations in commodity prices can also greatly affect the development of crude oil and natural gas reserves. Drilling and production activity generally decreases as crude oil and natural gas prices decrease. Declines in crude oil and natural gas prices could have a negative impact on exploration, development and production activity, and if sustained, could lead to a material decrease in such activity. For example, as a result of the decline in crude oil prices beginning in late 2014, Hess reduced its rig count to two rigs in the Bakken by the end of 2016. Hess subsequently increased its rig count and operated six rigs in the Bakken in 2019. Sustained reductions in exploration or production activity in our areas of operation could lead to reduced utilization of our assets.

Because of these and other factors, even if crude oil and natural gas reserves are known to exist in areas served by our assets, producers may choose not to develop those reserves. If reductions in drilling activity result in our inability to maintain the current levels of throughput on our systems, those reductions could reduce our revenues and cash flow and adversely affect our ability to make cash distributions to our shareholders.

If Hess does not maintain its drilling activities, or if we do not pursue third-party customer contracts, the demand for our produced water disposal services could be reduced, which could have a material adverse effect on our results of operations, cash flow and ability to make distributions to our shareholders.

The produced water disposal services that we provide to Hess and any other customers assist in their drilling activities. If Hess does not maintain its drilling activities, its demand for our produced water disposal services will be reduced regardless of whether we continue to provide other midstream services for their production. If the demand for our produced water disposal services declines for this or any other reason, our financial condition and results of operations could be adversely affected.

Our success depends on our ability to attract and maintain customers in a limited number of geographic areas.

Substantially all of our assets are located in the Bakken, and we intend to focus our future capital expenditures largely on developing our business in that area. As a result, our financial condition, results of operations and cash flows are significantly dependent upon the demand for our services in that area. Due to our focus on the Bakken, an adverse development in crude oil or natural gas production from that area would have a significantly greater impact on our financial condition and results of operations than if we spread expenditures more evenly over a wider geographic area. For example, a change in the rules and regulations governing operations in or around the Bakken could cause Hess or other producers to reduce or cease drilling or to permanently or temporarily shut‑in their production within the area, which could lead to a decrease in the volumes of natural gas and crude oil that we handle and have a material adverse effect on our business, results of operations, financial condition and our ability to make cash distributions to our shareholders.

Seasonal weather conditions may adversely affect our customers’ ability to conduct drilling activities in some of the areas where we operate and our ability to operate our assets and to construct additional facilities.

Crude oil and natural gas operations in North Dakota are adversely affected by seasonal weather conditions. In the Bakken, drilling and other crude oil and natural gas activities can be adversely affected during the winter months. Severe winter weather conditions limit and may reduce or temporarily halt our customers’ ability to operate during such conditions, leading to the decrease in drilling activity and the potential shut‑in of producing wells which the producers are unable to service. This could result in a decrease in the volumes of crude oil, natural gas and NGLs supplied to our assets. In addition, seasonal weather conditions during the winter months may adversely impact the operations of our assets and our ability to construct additional facilities, by causing temporary delays and shutdowns. These constraints and the resulting impacts could have a material adverse effect on our business, results of operations, financial condition and our ability to make cash distributions to our shareholders.

Our operations and Hess’ Bakken production operations are subject to many risks and operational hazards, some of which may result in business interruptions and shutdowns of our or Hess’ operations and damages for which may not be fully covered by insurance. If a significant accident or event occurs that results in a business interruption or shutdown for which we are not adequately insured, our operations and financial results could be materially and adversely affected.

Our operations are subject to all of the risks and operational hazards inherent in gathering, compressing, processing, fractionating, terminaling, storing, loading and transporting crude oil, natural gas and NGLs and gathering and disposing of produced water, including:

These risks could result in substantial losses due to personal injury and/or loss of life, severe damage to and destruction of property and equipment and pollution or other environmental damage, as well as business interruptions or shutdowns of our facilities. Any such event or unplanned shutdown could have a material adverse effect on our business, financial condition and results of operations. In addition, Hess’ Bakken production operations, on which our operations are substantially dependent, are subject to similar operational hazards and risks inherent in producing crude oil and natural gas. A serious accident at our facilities or at Hess’ facilities could result in serious injury or death to our employees or contractors or those of Hess or its affiliates and could expose us to significant liability for personal injury claims and reputational risk. We have no control over the operations at Hess’ Bakken operations and their associated facilities.

We do not maintain insurance coverage against all potential losses and could suffer losses for uninsurable or uninsured risks or in amounts in excess of existing insurance coverage. We carry insurance coverage for certain property damage and third-party liabilities, which includes sudden and accidental pollution liabilities. We are also insured under certain of Hess’ liability policies and are subject to Hess’ policy limits under these policies. The occurrence of an event that is not fully covered by insurance or failure by one or more insurers to honor its coverage commitments for an insured event could have a material adverse effect on our business, financial condition and results of operations.

In the future we may face increased obligations relating to the closing of our produced water facilities and may be required to provide an increased level of financial assurance to guarantee the appropriate closure activities occur for our produced water facilities.

Obtaining a permit to own or operate produced water facilities generally requires us to establish performance bonds, letters of credit or other forms of financial assurance to address clean-up and closure obligations. As we acquire additional produced water facilities or expand our existing produced water facilities, these obligations will increase. Additionally, in the future, regulatory agencies may require us to increase the amount of our closure bonds at existing produced facilities. Actual costs could exceed our current expectations, as a result of, among other things, federal, state or local government regulatory action, increased costs charged by service providers that assist in closing produced facilities and additional environmental remediation requirements. The obligation to satisfy increased regulatory requirements associated with our produced water facilities could result in an increase of our operating costs and adversely affect our financial condition and results of operations.

We may not be able to significantly increase our third‑party revenues due to competition and other factors, which could limit our ability to grow and extend our dependence on Hess.

Part of our growth strategy includes diversifying our customer base by identifying opportunities to offer services to third parties with our existing assets or by constructing or acquiring new assets independently from Hess. Our ability to increase our third‑party revenues is subject to numerous factors beyond our control, including prevailing commodity prices, competition from third parties and the extent to which we lack available capacity when third‑party customers require it. For example, the decline in crude oil prices beginning in late 2014 caused producers to reduce exploration, development and production activities, which resulted in a decrease in third‑party volumes available to be handled by our assets. In addition, our natural gas and crude oil gathering systems and processing plants are subject to competition from existing and future third‑party natural gas and crude oil gathering systems and natural gas processing and fractionation plants in the Bakken, while our terminals and crude oil rail cars compete with third‑party terminals, pipelines and crude oil rail cars for available third‑party volumes. To the extent that we have available capacity on our gathering systems, at TGP or LM4 for third-party volumes, we may not be able to compete effectively with third‑party gathering systems or processing plants for additional natural gas production in the area. To the extent that we have available capacity at our terminals or crude oil rail cars for third‑party volumes, competition from other existing or future terminals or crude oil rail cars owned by third parties may limit our ability to utilize this available capacity.

We have historically provided midstream services to third parties on only a limited basis, and we can provide no assurance that we will be able to attract any material third‑party service opportunities. Our efforts to attract new unaffiliated customers may be adversely affected by our relationship with Hess and our desire to provide services pursuant to fee‑based contracts. Our potential customers may prefer to obtain services under other forms of contractual arrangements under which we would be required to assume direct commodity exposure.

The completion of capital projects by us may not result in revenue increases and will be subject to regulatory, environmental, political, legal and economic risks, which could adversely affect our operations and financial condition.

As part of our growth strategy, we intend to increase utilization of our existing asset base and increase revenue at our facilities by handling additional volumes of natural gas and crude oil resulting from the completion of various capital projects by us. For example, we recently completed a construction and reconfiguration of facilities and pipelines in McKenzie and Williams Counties that increased our throughput capacity for crude oil and natural gas originating from south of the Missouri River and moving northward to our natural gas processing and crude oil and NGL terminaling assets in Tioga and Ramberg. We also invested in construction of the LM4 gas processing plant south of the Missouri River as part of our joint venture with Targa and announced plans to expand natural gas processing capacity at TGP by 150 MMcf/d for total processing capacity of 400 MMcf/d.

There are inherent risks associated with undertaking these and other capital projects, including numerous regulatory, environmental, political and legal uncertainties, most of which are beyond our control. If we undertake these projects, they may not be completed on schedule or at all or at the budgeted cost, limiting our capacity until completion, or their completion may not result in the anticipated increase in volumes at our facilities, which could materially and adversely affect our results of operations and financial condition and our ability in the future to make distributions to our shareholders.

Our industry is highly competitive and increased competitive pressure could adversely affect our business and operating results.

We compete with other midstream companies in our areas of operation. In addition, some of our competitors have assets in closer proximity to crude oil and natural gas supplies and have available idle capacity in existing assets that would not require new capital investments for use. Some of our competitors are large companies that have greater financial, managerial and other resources than we do. Our competitors may expand or construct gathering systems, processing plants, terminals or storage facilities that would create additional competition for the services we provide to our customers. Our ability to renew or replace existing contracts with our customers at rates sufficient to maintain current revenue and cash flow could be adversely affected by the activities of our competitors and our customers. All of these competitive pressures could have a material adverse effect on our business, results of operations, financial condition and our ability to make cash distributions to our shareholders.

We generate substantially all of our revenues under fee‑based commercial agreements with Hess under which we are paid based on the volumes of crude oil, natural gas and NGLs that we handle and the ancillary services we provide, rather than the value of the commodities themselves. As a result, our operations and cash flows generally have minimal direct exposure to commodity price risk. While the initial term of our commercial agreements provides for an annual fee recalculation mechanism to target a return on capital deployed, the secondary term of our commercial agreements changes to an inflation-based fee structure, which may provide greater exposure to price volatility. In addition, we may acquire or develop additional assets in the future or enter into transactions that have a greater exposure to fluctuations in commodity prices than our current operations. Our efforts to negotiate contractual arrangements to minimize our direct exposure to commodity price risk in the future may not be successful. Increased exposure to the volatility of crude oil, natural gas and NGL prices in the future could have a material adverse effect on our revenues and cash flow and our ability to make distributions to our shareholders.

We do not own all of the land on which certain of the pipelines connecting our facilities are located, which could result in disruptions to our operations.

We do not own all of the land on which our pipelines are located, and we are, therefore, subject to the possibility of more onerous terms and increased costs to retain necessary land use if we do not have valid leases or rights‑of‑way or if such rights‑of‑way lapse or terminate. We obtain the rights to construct and operate our pipelines on land owned by third parties and governmental agencies, and some of our agreements may grant us those rights for only a specific period of time. Our loss of these rights, through our inability to renew right‑of‑way contracts or otherwise, could have a material adverse effect on our business, results of operations, financial condition and ability to make cash distributions to our shareholders.

We utilize contract operator services at certain of our assets, and we may face higher costs associated with terminal services in the future.

We utilize contract operator services at certain of our assets. For example, we utilize contract operator services at our Tioga Rail Terminal under a rail and transload services agreement with a third‑party operator that may be terminated by us with 90-day notice. Under the terms of the agreement, third‑party contract personnel supervised by Hess employees control, monitor, record and report on the operation of the Tioga Rail Terminal. Contract personnel also provide inspection, crude oil loading, railroad consulting, inventory management, repair, data reporting, general maintenance and technical support and safety compliance services. Under this agreement, we are liable for any losses resulting from actions of the third‑party operator unless such losses result from the negligence of the third‑party operator. If disputes arise over the operation of the terminal, or if the third‑party operator fails to provide the services contracted under contract operator services agreements, our business, results of operation, and financial condition could be adversely affected. We previously extended the term of this agreement and expanded services to include rail car qualification and maintenance management and we expect to renew the agreement before it expires. Costs of these services under a negotiated renewal of the existing agreement or a similar agreement may increase relative to historical costs. Any such increased costs associated with terminal operation services will decrease the amount of cash available for distribution to our shareholders.

Restrictions in our credit facilities could adversely affect our business, financial condition, results of operations, ability to make cash distributions to our shareholders and the value of our Class A Shares.

We are dependent upon the earnings and cash flow generated by our operations in order to meet any debt service obligations and to allow us to make cash distributions to our shareholders. In December 2019, we entered into senior secured credit facilities consisting of a $1.0 billion 5-year revolving credit facility and a fully drawn $400.0 million 5-year Term Loan A facility, which contain various operating and financial restrictions and covenants. The operating and financial restrictions and covenants in our credit facilities restrict, and any future financing agreements could similarly restrict, our ability to finance our future operations or capital needs or to expand or pursue our business activities, which may, in turn, limit our ability to make cash distributions to our shareholders. In addition, borrowings on our credit facilities may use the London Interbank Offered Rate (“LIBOR”) as a benchmark for establishing the rate. LIBOR is the subject of recent national, international and other regulatory guidance and proposals for reform. These reforms and other pressures may cause LIBOR to be discontinued or to perform differently than in the past. The consequences of these developments cannot be entirely predicted but could include fluctuations in interest rates or an increase in the cost of credit facility borrowings.

The provisions of our credit facilities could affect our ability to obtain future financing and pursue attractive business opportunities and our flexibility in planning for, and reacting to, changes in business conditions. In addition, a failure to comply with the provisions of our credit facilities would result in an event of default which would enable our lenders to declare the outstanding principal of that debt, together with accrued interest, to be immediately due and payable. If the payment of our debt is accelerated, defaults under our other debt instruments, if any, may be triggered, and our assets may be insufficient to repay such debt in full, and the holders of our shares could experience a partial or total loss of their investment. Please read “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Capital Resources and Liquidity” for additional information about our credit facilities.

The level and terms of our and Hess’ indebtedness and any reduction in Hess’ credit ratings could adversely affect our ability to grow our business and our ability to make cash distributions to our shareholders. Our ability to obtain credit in the future may also be adversely affected by the credit ratings of Hess.

We and Hess must devote a portion of our cash flows from operating activities to service our respective indebtedness, and therefore cash flows may not be available for use in pursuing our and Hess’ growth strategy. Furthermore, a higher level of indebtedness at Hess in the future would increase the risk that it may default on its obligations to us under our commercial agreements. As of December 31, 2019, Hess had total consolidated indebtedness of approximately $7.1 billion, including our indebtedness of $1.7 billion, which is non-recourse to Hess.

Two of the three major credit rating agencies that rate Hess’ debt have assigned Hess an investment grade rating. If these credit ratings are lowered in the future, the interest rate and fees Hess pays on its credit facilities may increase. Credit rating agencies may consider Hess’ debt ratings when assigning ours because of its ownership interest in us, the significant commercial relationships between Hess and us, and our reliance on commercial agreements with Hess for substantially all of our revenues. If one or more credit rating agencies were to downgrade the outstanding indebtedness of Hess, we could experience an increase in our borrowing costs or difficulty accessing the capital markets. Such a development could adversely affect our ability to grow our business and to make cash distributions to our shareholders.

We have a significant amount of consolidated indebtedness that may adversely affect our business, results of operations and ability to make quarterly distributions.

We have a significant amount of consolidated indebtedness. As of December 31, 2019, we had $1,350.0 million of outstanding senior notes of the Partnership, $32.0 million of borrowings outstanding under the Partnership’s senior secured revolving credit facility and $400.0 million of borrowings outstanding under the Partnership’s senior secured term loan facility.

The degree to which we are leveraged, combined with lease and other financial obligations and contractual commitments, could have important consequences to us, including the following:

Our ability to service our indebtedness will depend upon, among other things, our future financial and operating performance, which will be affected by prevailing economic conditions and financial, business, regulatory and other factors, some of which are beyond our control. If our operating results are not sufficient to service our current or future indebtedness, we will be forced to take actions such as reducing or delaying business activities, acquisitions, investments or capital expenditures, selling assets, restructuring or refinancing debt, or seeking additional equity capital, and such results may adversely affect our ability to make cash distributions.

Restrictions in the terms of our consolidated indebtedness could adversely affect our business, financial condition, results of operations and ability to make quarterly cash distributions.

The terms of our consolidated indebtedness limit our ability to conduct our business, including our ability to:

Our consolidated indebtedness also contains covenants requiring us to maintain certain financial ratios. Our ability to meet those financial ratios and tests can be affected by events beyond our control, and there can be no assurance that we will meet any such ratios or tests.

Our assets and operations are subject to federal, state, and local laws and regulations relating to environmental protection and safety that could require us to make substantial expenditures.

Certain of our assets and operations are subject to federal, state, and local laws and regulations, which impose numerous obligations on our and our customers’ operations, including: the acquisition of permits to conduct regulated activities; the incurrence of capital or operating expenditures to limit or prevent releases of materials from our or our customers’ operations; the imposition of specific standards addressing worker protection, and the imposition of substantial liabilities and remedial obligations for pollution or contamination resulting from our and our customers’ operations. Failure to comply with these laws and regulations may result in joint and several or strict liability and the assessment by governmental authorities of administrative, civil and criminal penalties, the imposition of remedial obligations, and the issuance of injunctions limiting or preventing some or all of our operations. In addition, we may experience a delay in obtaining or be unable to obtain required permits, which may cause us to lose potential and current customers, interrupt operations, and limit growth and revenues. Private parties may also have the right to pursue legal actions to enforce compliance, as well as to seek damages for non-compliance, with environmental and safety laws and regulations or for personal injury or property damage. In addition, we may experience a delay in obtaining or be unable to obtain required permits, which may cause us to lose potential and current customers, interrupt operations, and limit growth and revenues, which in turn could affect our profitability.

The handling of crude oil, natural gas and NGLs involves inherent risks of spills and releases. We have contracted with various spill response service companies in the areas in which we gather, load, transport or store crude oil and NGLs; however, these companies may not be able to adequately contain a discharge in all instances, and we cannot ensure that all of their services would be available at any given time.

If our assets become subject to FERC regulation, or if federal, state or local regulations or policies change, or if we fail to comply with such regulations, our financial condition, results of operations and cash flows could be materially and adversely affected.

Although the Federal Energy Regulatory Commission, or FERC, has not made any formal determinations with respect to our natural gas gathering facilities upstream of the Tioga Gas Plant, we believe that the natural gas pipelines in our gathering systems meet the traditional tests FERC has used to establish whether a pipeline is unregulated under the Natural Gas Act, or the NGA. However, the classification and regulation of our gathering facilities may be subject to change based on future determinations by FERC, the courts, or Congress. If it is subsequently determined that an individual facility is not exempt from FERC regulation under the NGA, such determination could decrease revenue, increase operating costs, and, depending upon the facility in question, adversely affect our results of operations and cash flows. In addition, if any of our facilities were found to have violated the NGA or the Natural Gas Policy Act, or the NGPA, FERC has civil penalty authority under the NGA and NGPA to impose penalties for current violations of up to $1,291,894 per day for each violation and disgorgement of profits associated with any violation. In addition, state regulation of gathering facilities and intrastate transportation pipelines generally include various safety, environmental, and in some circumstances, nondiscriminatory take and common purchaser requirements, as well as complaint-based rate regulation.

We may incur significant costs and liabilities as a result of pipeline integrity management program testing and any related pipeline repair or preventative or remedial measures.

The United States Department of Transportation, or DOT, through the Pipeline and Hazardous Materials Safety Administration, or PHMSA, has adopted regulations requiring pipeline operators to develop integrity management programs for transportation pipelines located in “high consequence areas” (i.e. where a leak or rupture could do the most harm).

PHMSA regularly proposes revisions to existing regulations as well as new pipeline safety regulations. For example, in April 2016, pursuant to one of the requirements of the 2011 Pipeline Safety Act, PHMSA published a proposed rulemaking that would expand integrity management requirements and impose new pressure testing requirements on currently regulated gas transmission pipelines. The proposal would also significantly expand the regulation of gas gathering lines, subjecting previously unregulated pipelines to requirements regarding damage prevention, corrosion control, public education programs, maximum allowable operating pressure (“MAOP”) limits, and other requirements. PHMSA has not yet finalized such natural gas pipeline regulations. In October 2019, PHMSA submitted three major rules to the Federal Register, including rules focused on: the safety of gas transmission pipelines (the first of three parts of the Mega Rule), the safety of hazardous liquid pipelines, and enhanced emergency order procedures. The gas transmission rule requires operators of gas transmission pipelines constructed before 1970 to determine the material strength of their lines by reconfirming MAOP. In addition, the rule updates reporting and records retention standards for gas transmission pipelines. PHMSA is next expected to issue the second part of the Mega Rule focusing on repair criteria in high-consequence ares (“HCAs”) and creating new repair criteria for non-HCAs, requirements for inspecting pipelines following extreme events, updates to pipeline corrosion control requirements, and various other integrity management requirements. PHMSA is expected to subsequently issue the final part of the gas Mega Rule, the Gas Gathering Rule, focusing on requirements relating to gas gathering lines. The safety and hazardous liquid pipelines rule extended leak detection requirements to all non-gathering hazardous liquid pipelines and requires operators to inspect affected pipelines following extreme weather events or natural disasters to address any resulting damage. Finally, the enhanced emergency procedures rule focuses on increased emergency safety measures. In particular, this rule increases the authority of PHMSA to issue an emergency order that addresses unsafe conditions or hazards that pose an imminent threat to pipeline safety.

The adoption of these and other laws or regulations could require us to install new or modified safety controls, pursue new capital projects, or conduct maintenance programs on an accelerated basis, all of which could require us to incur increased operational costs that could be significant. While we cannot predict the outcome of legislative or regulatory initiatives, such legislative and regulatory changes could have a material effect on our cash flow.

In addition, if we fail to comply with applicable PHMSA regulations, rules, or orders, this could result in the imposition of civil penalties. Pursuant to the Pipeline Safety, Regulatory Certainty and Job Creation Act of 2011, or 2011 Pipeline Safety Act, PHMSA finalized rules that increased the maximum administrative civil penalties for violations of the pipeline safety laws and regulations to $200,000 per violation per day, with a maximum of $2,000,000 for a related series of violations. Effective July 31, 2019, those maximum civil penalties were increased by PHMSA to $218,647 per violation per day, with a maximum of $2,186,465 for a series of violations, to account for inflation.

Changes in laws or standards affecting crude oil rail cars or the transportation of North American crude oil by rail could require retrofitting our existing car fleet and/or reduce volumes throughput at our facilities, and as a result our revenues could decline, which could have a material adverse effect on our financial condition, results of operations, cash flows and ability to make distributions to shareholders.

Rail car derailments in Canada and the United States in the last several years have led to increased regulatory scrutiny over the safety of transporting Bakken crude oil by rail. The Federal Railroad Administration, or FRA, of the DOT, and the DOT’s PHMSA, have issued several Safety Advisories and Emergency Orders directing offerors and rail carriers to take additional precautionary measures to enhance the safe shipment of bulk quantities of crude oil. Currently, all of the rail cars in our fleet are DOT‑117 rail cars that meet the requirements of the final DOT rule. In addition, the adoption of additional federal, state or local laws or regulations, including any new voluntary measures by the rail industry regarding rail car design or crude oil and liquid hydrocarbon rail transport activities, or efforts by local communities to restrict or limit rail traffic involving crude oil, could increase compliance costs and decrease demand for our services, which could adversely affect our financial position and cash flows. Moreover, any disruptions in the operations of railroads, including those due to shortages of rail cars, locomotives or labor, weather‑related problems, or other force majeure events could adversely impact our customers’ ability to move their product and, as a result, could affect our business.

Evolving environmental laws and regulations on crude oil stabilization could have an effect on our financial performance.

In December 2014, the North Dakota Industrial Commission, or NDIC, issued Order No. 25417, which requires producers in the Bakken, among other fields, effective April 1, 2015, to heat their produced fluids to a specified minimum temperature or demonstrate that crude oil has a vapor pressure no greater than 13.7 psi prior to separation. In January 2019, the NDIC issued revisions to the order giving operators more flexibility for evaluating and demonstrating compliance with the state’s vapor pressure requirements.

Given the volume of tight crude oil like Bakken crude that was then being shipped by rail, the U.S. Department of Energy, or DOE, tasked Sandia National Laboratories to study the properties of tight crude oils as they relate to potential combustion events in the rail transport environment. On August 23, 2019, Sandia released its report “Pool Fire and Fireball Experiments in Support of the U.S. DOE/DOT/TC Crude Oil Characterization Research Study” (the “Sandia Study”). After studying the thermal hazard characteristics of crude oil samples from the Bakken System in comparison to crude oils from the Permian Basin in Texas and the Strategic Petroleum Reserve, Sandia concluded that “all the oils have comparable thermal hazard distances” and “none of the oils studied indicate outlier behavior.” Additionally, the Sandia Study found that “the results from this work do not support creating a distinction for crude oils based on vapor pressure.” Despite the conclusions of the Sandia Study, some federal, state or local regulators may continue to pursue regulation of crude oil vapor pressure for transportation purposes.

If new or more stringent federal, state or local legal restrictions relating to the quality specification of crude oil or to crude oil transportation are adopted in areas where Hess and our other customers operate, Hess and our other customers could incur potentially significant added costs to comply with such requirements and experience delays or curtailment in the pursuit of production or development activities, which could reduce demand for our midstream services.

Evolving environmental laws and regulations on climate change could adversely affect our financial performance.

Potential regulations regarding climate change could affect our operations. Currently, various federal and state legislative and regulatory bodies are considering measures to address greenhouse gas emissions. These measures include the Environmental Protection Agency, or the EPA, programs that require the crude oil and natural gas industry to report and to control greenhouse gas emissions, and states to develop statewide or regional programs to reduce greenhouse gas emissions. For example, in October 2015 the EPA finalized a rule to expand the Greenhouse Gas Reporting Rule to include emissions from gathering and boosting systems and blowdowns of natural gas transmission pipelines. These actions could result in increased (i) costs to operate and maintain our facilities, (ii) capital expenditures to install new emission controls on our facilities and (iii) costs to administer and manage any potential greenhouse gas emissions regulations or carbon trading or tax programs. These developments also could have an indirect effect on our business if Hess’ Bakken operations are adversely affected due to increased regulation of Hess’ facilities or reduced demand for crude oil, natural gas and NGLs.

Further, in May 2016 the EPA finalized new regulations that for the first-time established methane emission standards for new and modified oil and natural gas production and natural gas processing and transmission facilities. In April 2017, the EPA announced that it would review the 2016 methane rule and would initiate reconsideration proceedings to potentially revise or rescind portions of the rule. In September 2018, the EPA issued a proposed rulemaking that would reduce the 2016 standards’ fugitive emissions monitoring requirements and expand exceptions to controlling methane emissions from pneumatic pumps, among other changes. Various industry and environmental groups have separately challenged both the original 2016 standards and the EPA’s attempts to delay implementation of the rule. Further, in August 2019, the EPA proposed two options for further rescinding the 2016 standards. Under the EPA’s preferred alternative, the agency would rescind the methane limits for new, reconstructed and modified oil and natural gas production sources while leaving in place the general emission limits for volatile organic compounds, or VOCs, and relieve the EPA of its obligation to develop guidelines for methane emissions from existing sources. In addition, the proposal would remove from the oil and natural gas category the natural gas transmission and storage segment. The other proposed alternative would rescind the methane requirements of the 2016 standards applicable to all oil and natural gas sources, without removing any sources from that source category (and still requiring control of VOCs in general). As a result of these developments, future implementation of the rule is uncertain at this time based on pending legal challenges. In November 2016, the Bureau of Land Management, or “BLM” also finalized a rule to address methane emissions from crude oil and natural gas sources subject to BLM jurisdiction by limiting venting, flaring and leaking. In December 2017, BLM issued a final rule postponing compliance dates for portions of the rule until January 17, 2019. In September 2018, BLM issued a final rule rescinding parts and significantly modifying other parts of the November 2016 rule. The future of this rule is currently being challenged in federal court. Congress continues to periodically consider legislation on greenhouse gas emissions, which may include a delay in the implementation of greenhouse gas regulations by EPA or a limitation on EPA’s authority to regulate greenhouse gases, although the ultimate adoption and form of any federal legislation cannot presently be predicted.

In addition to potential domestic regulation of greenhouse gases, there continues to be international interest in a global framework for greenhouse gas reductions. While significant uncertainty exists as to future regulation of methane or other greenhouse gas emissions under the Clean Air Act or other local, regional, or international regulatory regimes, including any cap-and-trade program, their impact, if enacted, is likely to result in increased compliance costs, increased utility costs, additional operating restrictions on our business and an increase in the cost of products generally. However, the extent and magnitude of that impact cannot currently be reliably or accurately estimated.

Finally, many scientists have concluded that increasing concentrations of greenhouse gas emissions in the earth’s atmosphere may produce climate changes that have significant physical effects. To the extent any such effects were to occur, any associated market changes could have an adverse effect on our financial condition and operations.

We or Hess may be unable to obtain or renew permits or approvals necessary for our respective operations, which could inhibit our ability to do business and adversely affect our financial performance.

Our facilities and Hess’ and our other customers’ facilities that provide volumes to our facilities operate under federal, state and local permits, licenses and approvals with terms and conditions containing a significant number of prescriptive limits and performance standards that require a significant amount of monitoring, record keeping and reporting in order to demonstrate compliance. A decision by a government agency to deny or delay issuing a new or renewed permit or approval, or to revoke or substantially modify an existing permit or approval, could have an adverse impact on Hess’ ability to produce crude oil and natural gas or on our ability to handle volumes of crude oil, natural gas, NGLs or produced water at our facilities, which could have a material adverse effect on our financial condition, results of operations and cash flows. Additionally, noncompliance or incomplete documentation of our compliance status with respect to our existing permits or approvals may result in the imposition of fines, penalties and injunctive relief.

Evolving environmental laws and regulations on hydraulic fracturing could have an effect on our financial performance.

We do not conduct hydraulic fracturing operations, but Hess’ and our other customers’ crude oil and natural gas production operations often require hydraulic fracturing as part of the completion process. While hydraulic fracturing is typically regulated by state agencies, federal agencies have also asserted regulatory authority over the process. In addition, Congress may in the future further consider legislation giving the EPA direct authority to regulate hydraulic fracturing under the Safe Drinking Water Act. Many states have already adopted laws and/or regulations that require disclosure of the chemicals used in hydraulic fracturing and are considering legal requirements that could impose more stringent permitting, disclosure and well construction requirements on crude oil and/or natural gas drilling activities. If new or more stringent federal, state or local legal restrictions relating to the hydraulic fracturing process are adopted in areas where Hess and our other customers operate, Hess and our other customers could incur potentially significant added costs to comply with such requirements and experience delays or curtailment in the pursuit of production or development activities, which could reduce demand for our midstream services.

Certain plant or animal species could be designated as endangered or threatened, which could limit our ability to expand some of our existing operations or limit our customers’ ability to develop new crude oil and natural gas wells.

The federal Endangered Species Act, or ESA, restricts activities that may affect endangered or threatened species or their habitats. Many states have analogous laws designed to protect endangered or threatened species. The designation of previously unidentified endangered or threatened species under such laws may affect our and our customers’ operations.

Terrorist or cyber-attacks and threats, or escalation of military activity in response to these attacks, could have a material adverse effect on our business, financial condition or results of operations.

Terrorist attacks and threats, cyber‑attacks, escalation of military activity or acts of war may have significant effects on general economic conditions, fluctuations in consumer confidence and spending and market liquidity, each of which could materially and adversely affect our business. Strategic targets, such as energy‑related assets and transportation assets, may be at greater risk of future terrorist attacks than other targets in the United States. We do not maintain specialized insurance for possible liability or loss resulting from a terrorist attack or cyber‑attack on our assets that may shut down all or part of our business. It is possible that any of these occurrences, or a combination of them, could have a material adverse effect on our business, financial condition and results of operations.

Computers and telecommunication systems have become an integral part of our business. We use these systems to analyze and store financial and operating data and to communicate within our company and with outside business partners. Cyber‑attacks or phishing-attacks, unauthorized access, malicious software, data privacy breaches by employees or others with authorized access, ransomware, and other cyber security issues could compromise our computer and telecommunications systems and result in disruptions to our business operations, the loss or corruption of our data and proprietary information and communications interruptions. In addition, computers control oil and gas distribution systems globally and are necessary to deliver our customers’ products to market. A cyber‑attack impacting these distribution systems, or the networks and infrastructure on which they rely, could damage critical production, processing, distribution and/or storage assets, delay or prevent delivery to markets and make it difficult or impossible to accurately account for our services and settle transactions. As a result, a cyber breach of these operating systems, or of the networks and infrastructure on which they rely and any resulting investigation or remediation costs, litigation or regulatory action could have a material adverse impact on our cash flows and results of operations, reputation and competitiveness. We routinely experience attempts by external parties to penetrate and attack our networks and systems. Although such attempts to date have not resulted in any material breaches, disruptions, financial loss, or loss of business-critical information, our systems and procedures for protecting against such attacks and mitigating such risks may prove to be insufficient in the future and such attacks could have an adverse impact on our business and operations, including damage to our reputation and competitiveness, remediation costs, litigation or regulatory actions. In addition, as technologies evolve and these cyber security attacks become more sophisticated, we may incur significant costs to upgrade or enhance our security measures to protect against such attacks and we may face difficulties in fully anticipating or implementing adequate preventive measures or mitigating potential harm.

If we are unable to make acquisitions on economically acceptable terms from third parties, our future growth could be limited, and any acquisitions we may make may reduce, rather than increase, our cash flows and ability to make distributions to shareholders.

Part of our strategy to grow our business is dependent on our ability to make acquisitions. The acquisition component of our growth strategy is based, in large part, on our expectation of ongoing divestitures of midstream assets by industry participants.

If we are unable to make acquisitions from third parties, because (i) there is a material decrease in divestitures of midstream assets, (ii) we are unable to identify attractive acquisition candidates or negotiate acceptable purchase contracts, (iii) we are unable to obtain financing or to access the capital markets for future debt or equity offerings on economically acceptable terms, (iv) we are outbid by competitors or (v) for any other reason, our future growth and ability to increase our distributions will be limited. Our partnership agreement requires that we distribute all of our available cash to our shareholders. As a result, we expect to rely primarily upon external financing sources, including borrowings under our revolving credit facility and the issuance of debt and equity securities, to fund future acquisitions. Even if we are successful in obtaining funds for acquisitions through equity or debt financings, the terms thereof could limit our ability to pay distributions to our shareholders. In addition, issuing additional partner interests may result in significant shareholder dilution and increase the aggregate amount of cash required to maintain the then-current distribution rates, which could materially decrease our ability to pay distributions at the then-current distribution rates. If funding is not available to us when needed, or is available only on unfavorable terms, we may be unable to execute our business strategy, complete acquisitions or otherwise take advantage of business opportunities or respond to competitive pressures, any of which could have a material adverse effect on our business, financial condition, results of operations, liquidity and ability to make quarterly cash distributions to our shareholders.

Furthermore, even if we do consummate acquisitions that we believe will be accretive, they may in fact result in a decrease in distributions as a result of incorrect assumptions in our evaluation of such acquisitions or unforeseen consequences or other external events beyond our control. If we consummate any future acquisitions, shareholders will not have the opportunity to evaluate the economic, financial and other relevant information that we will consider in evaluating any such acquisitions.

Our general partner and its affiliates, including our Sponsors, have conflicts of interest with us and limited fiduciary duties to us and our shareholders, and they may favor their own interests to our detriment and that of our shareholders. Additionally, we have no control over the business decisions and operations of our Sponsors, and none of the Sponsors is under any obligation to adopt a business strategy that favors us.

The Sponsors indirectly own and control our general partner. Although our general partner has a duty to manage the Company in a manner that is in the best interests of the Company and its shareholders, the Company’s directors and officers also have a duty to manage our general partner in a manner that is in the best interests of its owner, HIP GP LLC, which is owned by the Sponsors. Conflicts of interest may arise between the Sponsors and their respective affiliates, including our general partner, on the one hand, and the Company and the Company’s shareholders, on the other hand. In resolving these conflicts, our general partner may favor its own interests and the interests of its affiliates, including the Sponsors, over the interests of the Company’s shareholders. These conflicts include, among others, the following situations:

Under the terms of our partnership agreement, the doctrine of corporate opportunity, or any analogous doctrine, does not apply to our general partner or any of its affiliates, including the Sponsors, HIP GP LLC or the executive officers and directors of the Company. Any such person or entity that becomes aware of a potential transaction, agreement, arrangement or other matter that may be an opportunity for the Company will not have any duty to communicate or offer such opportunity to the Company. Any such person or entity will not be liable to the Company or to any limited partner for breach of any fiduciary duty or other duty by reason of the fact that such person or entity pursues or acquires such opportunity for itself, directs such opportunity to another person or entity or does not communicate such opportunity or information to the Company. This may create actual and potential conflicts of interest between the Company and affiliates of our general partner and result in less than favorable treatment of the Company and its shareholders.

Our partnership agreement requires that we distribute all of our available cash, which could limit our ability to grow and make acquisitions.

Our partnership agreement requires that we distribute all of our available cash to our shareholders. As a result, we expect to rely primarily upon external financing sources, including borrowings under our revolving credit facility and the issuance of debt and equity securities, to fund our acquisitions and expansion capital expenditures. Therefore, to the extent we are unable to finance our growth externally, our cash distribution policy will significantly impair our ability to grow. In addition, because we will distribute all of our available cash, our growth may not be as fast as that of businesses that reinvest their available cash to expand ongoing operations. To the extent we issue additional shares in connection with any acquisitions or expansion capital expenditures, the payment of distributions on those additional shares may increase the risk that we will be unable to maintain or increase our per share distribution level. There are no limitations in our partnership agreement on our ability to issue additional shares, including shares ranking senior to our Class A Shares as to distributions or in liquidation or that have special voting rights and other rights, and our shareholders will have no preemptive or other rights (solely as a result of their status as shareholders) to purchase any such additional shares. The incurrence of additional commercial borrowings or other debt to finance our growth strategy would result in increased interest expense, which, in turn, may reduce the amount of cash that we have available to distribute to our shareholders.

Our partnership agreement designates the Court of Chancery of the State of Delaware as the exclusive forum for certain types of actions and proceedings that may be initiated by the Company’s shareholders, which would limit such shareholders’ ability to choose the judicial forum for disputes with us or our general partner’s directors, officers or other employees.

Our partnership agreement provides that, with certain limited exceptions, the Court of Chancery of the State of Delaware shall be the exclusive forum for, any claims, suits, actions or proceedings (i) arising out of or relating in any way to our partnership agreement (including any claims, suits or actions to interpret, apply or enforce the provisions of our partnership agreement or the duties, obligations or liabilities among partners or of partners to the Company, or the rights or powers of, or restrictions on, the partners or the Company), (ii) brought in a derivative manner on behalf of the Company, (iii) asserting a claim of breach of a duty (including any fiduciary duty) owed by any director, officer, or other employee of the Company or our general partner, or owed by our general partner, to the Company or its partners, (iv) asserting a claim arising pursuant to any provision of the Delaware Revised Uniform Limited Partnership Act (the “Delaware Act”) or (v) asserting a claim governed by the internal affairs doctrine. However, the exclusive forum provision would not apply to suits brought to enforce any liability or duty created by the Securities Act of 1933, as amended (the “Securities Act”), or the Exchange Act or any other claim for which the federal courts have exclusive jurisdiction. To the extent that any such claims may be based upon federal law claims, Section 27 of the Exchange Act creates exclusive federal jurisdiction over all suits brought to enforce any duty or liability created by the Exchange Act or the rules and regulations thereunder. Furthermore, Section 22 of the Securities Act creates concurrent jurisdiction for federal and state courts over all suits brought to enforce any duty or liability created by the Securities Act or the rules and regulations thereunder. Any person or entity purchasing or otherwise acquiring any interest in Class A Shares is deemed to have received notice of and consented to the foregoing provisions. Although we believe this choice of forum provision benefits the Company by providing increased consistency in the application of Delaware law in the types of lawsuits to which it applies, the provision may have the effect of discouraging lawsuits against the Company and our general partner’s directors and officers. The enforceability of similar choice of forum provisions in other companies’ certificates of incorporation or similar governing documents has been challenged in legal proceedings and it is possible that in connection with any action a court could find the choice of forum provisions contained in our partnership agreement to be inapplicable or unenforceable in such action. If a court were to find this choice of forum provision inapplicable to, or unenforceable in respect of, one or more of the specified types of actions or proceedings, we may incur additional costs associated with resolving such matters in other jurisdictions, which could adversely affect our business, financial condition and results of operations and our ability to make cash distributions to our shareholders.

Our partnership agreement provides that our shareholders irrevocably waive the right to trial by jury in any claim, suit, action or proceeding under either state or federal laws, including any claim under U.S. federal securities laws, which could result in less favorable outcomes to our shareholders in any such action.

Our partnership agreement provides that our shareholders, including those who become our shareholders by purchasing shares in us in secondary transactions, irrevocably waive the right to trial by jury for any claims, suits, actions or proceedings (i) arising out of or relating in any way to our partnership agreement (including any claims, suits or actions to interpret, apply or enforce the provisions of our partnership agreement or the duties, obligations or liabilities among the Company’s partners, or obligations or liabilities of the Company’s partners to the Company, or the rights or powers of, or restrictions on, the Company’s partners or the Company), (ii) brought in a derivative manner on the Company’s behalf, (iii) asserting a claim of breach of a duty owed by any of the Company’s, or our general partner’s, directors, officers, or other employees, or owed by our general partner, to the Company or the Company’s partners, (iv) asserting a claim against the Company arising pursuant to any provision of the Delaware Act or (v) asserting a claim against the Company governed by the internal affairs doctrine, in each case pursuant to either state or federal laws, including U.S. federal securities law. Regardless, such waiver of the right to trial by jury does not impact the ability of a shareholder of the Company to make a claim under either federal or state law.

The waiver of the right to a jury trial is not intended to be deemed a waiver by any shareholder with respect to the Company’s compliance with U.S. federal securities laws and the rules and regulations promulgated thereunder. If the Company or one of the Company shareholders opposed a jury trial demand based on the waiver, the applicable court would determine whether the waiver was enforceable based on the facts and circumstances of that case in accordance with applicable state and federal laws. To our knowledge, the enforceability of a contractual pre-dispute jury trial waiver in connection with claims arising under the U.S. federal securities laws has not been finally adjudicated by the United States Supreme Court. However, we believe that a contractual pre-dispute jury trial waiver provision is generally enforceable, including under the laws of the State of Delaware, which govern our partnership agreement.

If a shareholder brings a claim in connection with matters arising under our partnership agreement, including claims under U.S. federal securities laws, such Company shareholder may not be entitled to a jury trial with respect to such claims, which may have the effect of limiting and discouraging lawsuits. If a lawsuit is brought by a shareholder under our partnership agreement, it may be heard only by a judge or justice of the applicable trial court, which would be conducted according to different civil procedures and may result in a different outcome than a trial by jury, including results that could be less favorable to the Company shareholder(s) bringing such lawsuit.

Affiliates of our general partner, including our Sponsors, may compete with us, and neither our general partner nor its affiliates have any obligation to present business opportunities to us.

Neither our partnership agreement nor the partnership agreement of the Partnership prohibits the Sponsors or any other affiliates of our general partner from owning assets or engaging in businesses that compete directly or indirectly with the Company. Under the terms of our partnership agreement, the doctrine of corporate opportunity, or any analogous doctrine, does not apply to our general partner or any of its affiliates, including the Sponsors and the Company’s executive officers and directors. Any such entity that becomes aware of a potential transaction, agreement, arrangement or other matter that may be an opportunity for the Company will not have any duty to communicate or offer such opportunity to the Company. Consequently, the Sponsors and other affiliates of our general partner, including HIP GP LLC, may acquire, construct or dispose of additional midstream assets in the future without any obligation to offer the Company the opportunity to purchase any of those assets. As a result, competition from the Sponsors and other affiliates of our general partner could materially and adversely impact the Company’s results of operations and distributable cash flow.

Our partnership agreement replaces our general partner’s fiduciary duties to holders of the Company’s shares with contractual standards governing its duties.

Delaware law provides that Delaware limited partnerships may, in their partnership agreements, expand, restrict or eliminate the fiduciary duties otherwise owed by the general partner to limited partners and the partnership, provided that partnership agreements may not eliminate the implied contractual covenant of good faith and fair dealing. As permitted by Delaware law, our partnership agreement contains provisions that eliminate the fiduciary standards to which our general partner would otherwise be held by state fiduciary duty law and replaces those duties with several different contractual standards. For example, our partnership agreement permits our general partner to make 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 shareholders other than the implied contractual covenant of good faith and fair dealing. This provision entitles our general partner to consider only the interests and factors 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 limited partners. By purchasing a Class A Share, a shareholder is treated as having consented to the provisions in our partnership agreement, including the provisions discussed above.

Holders of our Class A Shares have very limited voting rights and, even if they are dissatisfied, they cannot initially remove our general partner without its consent.

Unlike the holders of common stock in a corporation, our shareholders have only limited voting rights on matters affecting our business and, therefore, limited ability to influence management’s decisions regarding our business. For example, unlike holders of stock in a public corporation, our shareholders do not have “say-on-pay” advisory voting rights. Our shareholders did not elect our general partner and will not elect any of the members of our general partner’s board of directors and have no right to elect our general partner or any of the members of our general partner’s board of directors on an annual or other continuing basis. Our board of directors is chosen by HIP GP LLC, which is controlled by our Sponsors. Furthermore, if our shareholders are dissatisfied with the performance of our general partner, they have little ability to remove our general partner. As a result of these limitations, the price at which Class A Shares trade could be diminished because of the absence or reduction of a takeover premium in the trading price.

Our shareholders are not able to remove our general partner without its consent because our general partner and its affiliates own sufficient shares to be able to prevent its removal. In addition, our general partner may only be removed for cause. “Cause” is narrowly defined under our partnership agreement to mean that a court of competent jurisdiction has entered a final, non-appealable judgment finding our general partner liable for actual fraud or willful or wanton misconduct in its capacity as our general partner. Cause does not include most cases of charges of poor management of the business. Even if cause for removal exists, the vote of the holders of at least 66 2/3% of all of our outstanding shares voting together as a single class is required to remove our general partner. As of December 31, 2019, our general partner and its affiliates collectively owned 94% of our Company shares.

Furthermore, our shareholders’ voting rights are further restricted by our partnership agreement, which provides that any shares held by a person that owns 20% or more of any class of shares then outstanding, other than our general partner, its affiliates, their transferees, and persons who acquired such shares with the prior approval of our board of directors, cannot vote on any matter.

Our partnership agreement also contains provisions limiting the ability of our shareholders to call meetings or to acquire information about our operations, as well as other provisions limiting our shareholders’ ability to influence the manner or direction of management.

Our general partner interest or the control of our general partner may be transferred to a third party without shareholder 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 the consent of our shareholders. Furthermore, there is no restriction in our partnership agreement on the ability of HIP GP LLC to transfer all of the partnership interests in our general partner, or all of the membership interests in GP LLC, the general partner of our general partner, to a third party. The new owner of our general partner or the general partner of our general partner would then be in a position to replace our board of directors and officers with its own choices. As a result, we could lose the provision of certain operational support and administrative services by Hess and its affiliates and our license to use certain Hess trademarks.

Our general partner has a limited call right that may require our shareholders to sell their Class A Shares at an undesirable time or price.

If at any time our general partner and its affiliates own more than a designated percentage of the issued and outstanding limited partner interests of any class, our general partner will have the right, but not the obligation, which it may assign to any of its affiliates or to us, to acquire all, but not less than all, of the limited partner interests of such class held by unaffiliated persons at a price not less than their then-current market price. This designated percentage is equal to (i) 80% with respect to all classes of limited partner interests other than Class A Shares and (ii) as of the consummation of the Restructuring, 97% of the Class A Shares and Class B Shares, taken together, which percentage is gradually adjusted downward in connection with decreases to the percentage of the limited partner interests held by our general partner and its affiliates. Generally, the designated percentage is three to five percent greater than the percentage of the limited partner interests owned by our general partner and its affiliates, until they own 75% of the limited partner interests, at which time the designated percentage will be fixed at 80%. As a result, our shareholders may be required to sell their Class A Shares at an undesirable time or price and may not receive any return on their investment. Our shareholders may also incur a tax liability upon a sale of their Class A Shares. For purposes of this calculation, the Class B Shares will be considered collectively with the Class A Shares as a single class. Our general partner and its affiliates currently own approximately 94% of the Class B Shares and the Class A Shares, considered as a single class.

Our partnership agreement restricts the remedies available to shareholders for actions taken by our general partner that might otherwise constitute breaches of fiduciary duty.

Our partnership agreement contains provisions that restrict the remedies available to shareholders for actions taken by our general partner that might otherwise constitute breaches of fiduciary duty under state fiduciary duty law. For example, our partnership agreement:

The market price of Class A Shares may fluctuate significantly and holders of Class A Shares could lose some or all of the value of their investment. In addition, the stock market has experienced significant price and volume fluctuations in recent times which, if they continue to occur, could have a material adverse effect on the market for, or liquidity of, Class A Shares, regardless of our actual operating performance.

Our Sponsors may sell Class A Shares in the public or private markets, and such sales could have an adverse impact on the trading price of the Class A Shares.

As of December 31, 2019, our Sponsors and their affiliates, including our general partner, collectively held 898,000 Class A Shares, 266,416,928 Class B Shares, and 266,416,928 Class B Units in the Partnership. The Class B Units in the Partnership are exchangeable, together with an equal number of Class B Shares, into Class A Shares on a one-to-one basis. We have agreed to provide our Sponsors with certain registration rights under applicable securities laws with respect to resales of the Class A Shares. The sale of these Class A Shares in the public or private markets could have an adverse impact on the price of the Class A Shares or any trading market that may develop.

We may issue an unlimited number of additional equity interests without shareholder approval, including equity interests with preferences senior to the Class A Shares, which would dilute shareholder interests.

Under our partnership agreement, we may, at any time, issue an unlimited number of general partner interests or limited partner interests of any type without the approval of our shareholders, and our shareholders will have no preemptive or other rights (solely as a result of their status as shareholders) to purchase any such general partner interests or limited partner interests. Further, there are no limitations in our partnership agreement on our ability to issue equity securities that rank equal or senior to the Class A Shares as to distributions or in liquidation or that have special voting rights and other rights.

The issuance by us of additional Class A Shares or other equity securities of equal or senior rank will have the following effects:

The issuance by us of additional general partner interests may have the following effects, among others, if such general partner interests are issued to a person who is not an affiliate of our general partner:

The NYSE does not require a publicly traded limited partnership like us to comply with certain of its corporate governance requirements.

Our Class A Shares are listed on the NYSE. Because we are a publicly traded limited partnership, the NYSE does not require us to have a majority of independent directors on our board of directors or to establish a compensation committee or a nominating and corporate governance committee. Additionally, any future issuances of additional Class A Shares or other securities, including to affiliates, are not subject to the NYSE’s shareholder approval rules that apply to a corporation. Accordingly, our shareholders do not have the same protections afforded to certain shareholders of corporations that are subject to all of the NYSE corporate governance requirements.

We are subject to U.S. federal income tax as a corporation at the corporate tax rate of 21% and to state income tax in various states at various rates. Distributions on our Class A Shares are treated as distributions on corporate stock for U.S. federal income tax purposes and taxed again as corporate dividends (to the extent of our current and accumulated earnings and profits). Because an entity-level tax is imposed on us due to our status as a corporation for U.S. federal and state income tax purposes, distributable cash flow will be reduced by any tax liabilities.

Although we may, from time to time, be involved in litigation and claims arising out of our operations in the normal course of business, we are not a party to any litigation or governmental or other proceeding that we believe will have a material adverse impact on our financial condition or results of operations.

Our Class A Shares are listed on the New York Stock Exchange and are traded under the symbol “HESM”.

As of December 31, 2019, there were 2 shareholders of record who owned a total of 17,960,655 of our Class A Shares, one of which is Hess Midstream GP LP. The number of holders does not include the holders for whom shares are held in a “nominee” or “street” name. In addition, as of December 31, 2019, Hess Midstream GP LP owned an aggregate of 266,416,928 Class B Shares. Hess and GIP indirectly own the Class A Shares and Class B Shares owned by Hess Midstream GP LP.

In 2017, the Partnership adopted the Hess Midstream Partners LP 2017 Long-Term Incentive Plan. Pursuant to the Restructuring, the Company assumed the Hess Midstream Partners LP 2017 Long-Term Incentive Plan and all obligations with respect to outstanding awards thereunder. The Company amended and restated the Hess Midstream Partners LP 2017 Long-Term Incentive Plan to, among other things, change the plan’s name to the Hess Midstream LP 2017 Long-Term Incentive Plan (the “LTIP”) and to reflect the Company’s assumption of the plan. The LTIP limits the number of shares that may be delivered pursuant to vested awards to 3,000,000 Class A Shares.

The following table summarizes information about our equity compensation plan as of December 31, 2019:

See Note 9, Equity‑Based Compensation in Notes to Consolidated Financial Statements for further discussion of our equity compensation plans.

Our partnership agreement requires that, within 45 days after the end of each quarter, we distribute all of our available cash to shareholders of record on the applicable record date. Except for splits and combinations as contemplated by our partnership agreement, no distribution shall be made under any circumstances in respect of any Class B Shares or our general partner interest.

The following table sets forth the cash distributions per unit or share declared on the Common Units or Class A Shares, as applicable, from the closing of our IPO on April 10, 2017, through December 31, 2019:

Available cash generally means, for any quarter, all cash and cash equivalents on hand at the end of that quarter:

The purpose and effect of the last bullet point above is to allow our general partner, if it so decides, to use cash from working capital borrowings made after the end of the quarter but on or before the date of determination of available cash for that quarter to pay distributions to shareholders. Under our partnership agreement, working capital borrowings are generally borrowings that are made under a credit facility, commercial paper facility or similar financing arrangement, and in all cases are used solely for working capital purposes or to pay distributions to partners and with the intent of the borrower to repay such borrowings within twelve months with funds other than from additional working capital borrowings.

Under our current cash distribution policy, we intend to make a minimum quarterly distribution to the holders of our Class A Shares of $0.30 per share, or $1.20 per share on an annualized basis, to the extent we have sufficient available cash after the establishment of cash reserves and the payment of costs and expenses, including reimbursements of expenses to our general partner. However, there is no guarantee that we will pay the minimum quarterly distribution on our Class A Shares in any quarter. The amount of distributions paid under our cash distribution policy and the decision to make any distribution will be determined by our general partner, taking into consideration the terms of our partnership agreement.

Our general partner owns a non-economic general partner interest in us and, as of December 31, 2019, 898,000 Class A Shares and 266,416,928 Class B Shares. Our general partner, in its capacity as a shareholder, is entitled to share in cash distributions on our Class A Shares, but is not otherwise entitled to receive cash distributions with respect to its general partner interest in us or its Class B Shares. However, our general partner may in the future own other equity interests in us and may be entitled to receive distributions on any such interests.

If we combine our shares or other interests in us (“Company Interests”) into fewer shares or Company Interests (commonly referred to as a “reverse split”) or subdivide our shares or Company Interests into a greater number of shares or Company Interests (commonly referred to as a “split”), we will proportionately adjust the minimum quarterly distribution.

For example, if a two-for-one split of Class A Shares should occur, the minimum quarterly distribution would be reduced to 50% of its initial level. We will not make any adjustment by reason of the issuance of additional shares or Company Interests for cash or property (including additional Class A Shares issued under any compensation or benefit plans).

The following is a summary of selected financial and operating data that should be read in conjunction with both our Consolidated Financial Statements and Accompanying Notes, and Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations included elsewhere in this Annual Report on Form 10‑K:

	Year Ended December 31,
		2019			2018⁽¹⁾			2017⁽¹⁾			2016⁽¹⁾			2015⁽¹⁾
(in millions, except as noted)
Consolidated Statement of Operations Selected Data:
Revenues and other income		$	848.3		$	712.7		$	579.5		$	510.0		$	565.1
Net income			317.7			325.5			242.0			81.6			139.0
Net income attributable to Hess Midstream LP			70.1			70.8			41.2			-			-
Per Share/Unit Data:
Net income attributable to Hess Midstream LP per Common Unit (basic and diluted)		$	-		$	1.27		$	0.75		$	-		$	-
Net income attributable to Hess Midstream LP per subordinated unit (basic and diluted)		$	-		$	1.27		$	0.75		$	-		$	-
Net income attributable to Hess Midstream LP per Class A Share/limited partner unit (basic)		$	1.21		$	-		$	-		$	-		$	-
Net income attributable to Hess Midstream LP per Class A Share/limited partner unit (diluted)		$	1.20		$	-		$	-		$	-		$	-
Cash distributions declared per Class A Share/ limited partner unit		$	1.6173		$	1.4061		$	0.9028		$	-		$	-
Consolidated Statement of Cash Flows Selected Data:
Operating activities		$	470.7		$	466.9		$	336.5		$	247.5		$	253.7
Investing activities		$	(497.5	)	$	(307.6	)	$	(131.4	)	$	(268.6	)	$	(323.5	)
Financing activities		$	(79.2	)	$	(405.7	)	$	148.9		$	19.5		$	73.1
Other Financial Measures:
Adjusted EBITDA⁽²⁾		$	550.7		$	505.1		$	379.6		$	272.8		$	238.9
Distributable cash flow prior to Restructuring ⁽²⁾⁽³⁾		$	73.7		$	96.0		$	58.7		$	-		$	-
Distributable cash flow subsequent to Restructuring ⁽²⁾⁽³⁾		$	140.1		$	-		$	-		$	-		$	-
Capital expenditures:
Maintenance		$	4.9		$	6.9		$	18.8		$	8.0		$	18.5
Expansion		$	312.2		$	264.4		$	99.5		$	264.8		$	274.3
Balance Sheet Data
Total Assets		$	3,277.7		$	2,991.2		$	3,022.4		$	2,659.1		$	2,464.5
Total Liabilities		$	1,945.6		$	1,115.1		$	1,070.1		$	849.2		$	828.5
Operating volumes:
Gas gathering (MMcf/d)			275			248			213			202			214
Crude oil gathering (MBbl/d)			118			89			64			57			39
Gas processing (MMcf/d)			260			233			200			188			194
Crude oil terminaling (MBbl/d)			131			101			69			59			73
NGL loading (MBbl/d)			15			14			12			13			13
Water gathering (MBbl/d)			41			25			16			-			-

Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with the consolidated financial statements and notes thereto included in Item 8 of this Annual Report on Form 10‑K. Financial information presented in this report has been retrospectively adjusted for the acquisition of Hess Infrastructure Partners LP.

This discussion contains forward-looking statements that involve risks and uncertainties. Our actual results could differ materially from those discussed below. Factors that could cause or contribute to such differences include, but are not limited to, those identified below and those discussed in the section entitled “Risk Factors” included elsewhere in this report.

We are a fee-based, growth-oriented, limited partnership formed by Hess Infrastructure Partners GP LLC (“HIP GP LLC”) and our general partner to own, operate, develop and acquire a diverse set of midstream assets and provide fee-based services to Hess and third-party customers. We are managed and controlled by Hess Midstream GP LLC, the general partner of our general partner. Our assets are primarily located in the Bakken and Three Forks shale plays in the Williston Basin area of North Dakota, which we collectively refer to as the Bakken.

On March 1, 2019, Hess Infrastructure Partners LP (“HIP”) acquired 100% of the membership interest in Hess’ Bakken water services business (“Hess Water Services”) for cash consideration of $225.0 million.

On March 22, 2019, we acquired the crude oil, gas and water gathering assets of Summit Midstream Partners’ Tioga Gathering System for cash consideration of $89.2 million, with the potential for an additional $10.0 million of contingent payments in future periods subject to certain future performance metrics.

On April 25, 2019, we announced plans to expand natural gas processing capacity at the Tioga Gas Plant by 150 MMcf/d for total processing capacity of 400 MMcf/d for expected capital expenditures of approximately $150 million, to be in service by mid-2021.

On December 16, 2019, the Company and the Partnership completed the transactions (the “Restructuring”) contemplated by the Partnership Restructuring Agreement, dated October 3, 2019, by and among the Company, the Partnership and the other parties thereto. As a result of the Restructuring, the Company was delegated control of the Partnership and replaced the Partnership as its publicly traded successor. Prior to the Restructuring, the Company and the Partnership were indirectly controlled by HIP GP LLC, the general partner of HIP. HIP was originally formed as a joint venture between Hess and GIP (together, the “Sponsors”) and owned an 80% economic interest in certain of the Partnership’s existing assets (the “Joint Interest Assets”), a 100% interest in certain other businesses, including Hess Water Services and a 100% interest in Hess Midstream Partners GP LP (“MLP GP LP”), which held all of the Partnership’s outstanding incentive distribution rights and the general partner interest in the Partnership, and controlled the Partnership.

Pursuant to the Restructuring, the Partnership acquired HIP, including HIP’s 80% interest in the Joint Interest Assets, 100% interest in Hess Water Services and the outstanding economic general partner interest and incentive distribution rights in the Partnership. The Partnership’s organizational structure converted from a master limited partnership into an “Up-C” structure in which the Partnership’s public unitholders received newly issued Class A shares (“Class A Shares”) in Hess Midstream LP in a one-for-one exchange. The Partnership changed its name to “Hess Midstream Operations LP” and became a consolidated subsidiary of the Company. After consummation of the Restructuring, the Sponsors and their affiliates received an aggregate of 898,000 Class A Shares in the Company, 266,416,928 Class B units representing noncontrolling limited partner interests in the Partnership and received aggregate cash consideration of $601.8 million. The Sponsors own 100% interest in the general partner of the Company and, through their ownership of the general partner, continue to have the right to elect the entire board of directors.

The acquisition of HIP by the Partnership, including its 80% economic interest in the Joint Interest Assets and 100% interest in Hess Water Services, was accounted for as an acquisition of a business under common control. Accordingly, our consolidated financial statements prior to the acquisition date of December 16, 2019 were retrospectively recast to include the financial results of HIP.

Our principal business objective is to grow our business, free cash flow and distributable cash flow supported by fee-based contracts and disciplined financial strategy. We expect to achieve this objective through the following business strategies:

Our assets and operations are organized into the following three reportable segments: (i) gathering, (ii) processing and storage and (iii) terminaling and export.

Our gathering segment includes Hess North Dakota Pipeline Operations LP, or Gathering Opco, and Hess Water Services Holdings LLC, which own the following assets:

Our processing and storage segment includes Hess TGP Operations LP, or HTGP Opco, and Hess Mentor Storage Holdings LLC, or Mentor Holdings, which own the following assets, respectively:

Our terminaling and export segment includes Hess North Dakota Export Logistics Operations LP, or Logistics Opco, which owns each of the following assets:

Significant financial and operating results for the year ended December 31, 2019 include:

For additional information regarding our non‑GAAP financial measures, see “How We Evaluate Our Operations” and “Reconciliation of Non‑GAAP Financial Measures” below.

We generate substantially all of our revenues by charging fees for gathering, compressing and processing natural gas and fractionating NGLs; gathering, terminaling, loading and transporting crude oil and NGLs; storing and terminaling propane; and gathering and disposing of produced water. We have entered into long-term, fee-based commercial agreements with Hess dated effective January 1, 2014, for oil and gas services agreements, and effective January 1, 2019, for water services agreements. In addition, in 2018 and a portion of 2017, Hess Water Services had documented intercompany arrangements with certain subsidiaries of Hess pursuant to which it provided produced water gathering and disposal services and charged agreed-upon fees per barrel for the services performed.

Except for the water services agreements and except for a certain gathering sub-system, as described below, each of our commercial agreements with Hess has an initial 10-year term and we have the unilateral right to renew each of these agreements for one additional 10-year term. Initial term for the water services agreements is 14 years and the secondary term is 10 years. In September 2018, we amended our gas gathering and gas processing and fractionation agreements to enable us to provide certain services to Hess in respect of volumes to be delivered to and processed at the LM4 plant. The amended and restated gas gathering agreement also extends the initial term of the gathering agreement with respect to a certain gathering sub-system by 5 years to provide for a 15-year initial term and decreases the secondary term for that gathering sub-system by 5 years to provide for a 5-year secondary term. These agreements include dedications covering substantially all of Hess’ existing and future owned or controlled production in the Bakken, minimum volume commitments, inflation escalators and fee recalculation mechanisms, all of which are intended to provide us with cash flow stability and growth, as well as downside risk protection. In particular, Hess’ minimum volume commitments under our commercial agreements provide minimum levels of cash flows and the fee recalculation mechanisms under the agreements allow fees to be adjusted annually to provide us with cash flow stability. Our revenues also include revenues from third-party volumes contracted with Hess and delivered to us under these commercial agreements with Hess, as well as pass-through third-party rail transportation costs, third-party produced water trucking and disposal costs and electricity fees for which we recognize revenues in an amount equal to the costs. Together with Hess, we are pursuing strategic relationships with third-party producers and other midstream companies with operations in the Bakken in order to maximize our utilization rates.

Our management uses a variety of financial and operating metrics to analyze our operating results and profitability. These metrics include (i) volumes, (ii) operating and maintenance expenses, (iii) Adjusted EBITDA, (iv) free cash flow, and (v) distributable cash flow.

Volumes. The amount of revenues we generate primarily depends on the volumes of crude oil, natural gas, NGLs and produced water that we handle at our gathering, processing, terminaling, storage and disposal facilities. These volumes are affected primarily by the supply of and demand for crude oil, natural gas and NGLs in the markets served directly or indirectly by our assets, including changes in crude oil prices, which may further affect volumes delivered by Hess. Although Hess has committed to minimum volumes under our commercial agreements described above, our results of operations will be impacted by our ability to:

Operating and Maintenance Expenses. Our management seeks to maximize the profitability of our operations by effectively managing operating and maintenance expenses. These expenses are comprised primarily of costs charged to us under our omnibus agreement and employee secondment agreement, third‑party contractor costs, utility costs, insurance premiums, third‑party service provider costs, related property taxes and other non‑income taxes and maintenance expenses, such as expenditures to repair, refurbish and replace storage facilities and to maintain equipment reliability, integrity and safety. These expenses generally remain relatively stable across broad ranges of throughput volumes but can fluctuate from period to period depending on the mix of activities performed during that period and the timing of substantial expenses, such as gas plant turnarounds. We seek to manage our maintenance expenditures by scheduling periodic maintenance on our assets in order to minimize significant variability in these expenditures and minimize their impact on our cash flow.

Adjusted EBITDA, Free Cash Flow and Distributable Cash Flow. We define Adjusted EBITDA as net income (loss) before net interest expense, income tax expense (benefit), depreciation and amortization and our proportional share of depreciation of our equity affiliates, as further adjusted to eliminate the impact of certain items that we do not consider indicative of our ongoing operating performance, such as transaction costs, other income and other non‑cash, non‑recurring items, if applicable. We define free cash flow as Adjusted EBITDA less capital expenditures. We use distributable cash flow to analyze our liquidity and performance. We define distributable cash flow as Adjusted EBITDA less net interest, excluding amortization of deferred financing costs, cash paid for federal and state income taxes and maintenance capital expenditures. Distributable cash flow does not reflect changes in working capital balances.

Adjusted EBITDA, free cash flow and distributable cash flow are non‑GAAP supplemental financial measures that management and external users of our consolidated financial statements, such as industry analysts, investors, lenders and rating agencies, may use to assess:

We believe that the presentation of Adjusted EBITDA, free cash flow and distributable cash flow provides useful information to investors in assessing our financial condition and results of operations. The GAAP measures most directly comparable to Adjusted EBITDA, free cash flow and distributable cash flow are net income (loss) and net cash provided by (used in) operating activities. Adjusted EBITDA, free cash flow and distributable cash flow should not be considered as alternatives to GAAP net income (loss), income (loss) from operations, net cash provided by (used in) operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP. Adjusted EBITDA, free cash flow and distributable cash flow have important limitations as analytical tools because they exclude some but not all items that affect net income and net cash provided by operating activities. You should not consider Adjusted EBITDA, free cash flow or distributable cash flow in isolation or as a substitute for analysis of our results as reported under GAAP. Additionally, because Adjusted EBITDA, free cash flow and distributable cash flow may be defined differently by other companies in our industry, our definition of Adjusted EBITDA, free cash flow and distributable cash flow may not be comparable to similarly titled measures of other companies, thereby diminishing their utility.

The following tables summarize our consolidated results of operations for the years ended December 31, 2019, 2018 and 2017. The financial information presented has been retrospectively adjusted for the acquisition of HIP. See Note 3, Acquisitions in Item 8. Financial Statements and Supplementary Data. The results of operations are discussed in further detail following this overview (in millions, unless otherwise noted).

For the Year Ended December 31, 2019	Gathering		Processing and Storage		Terminaling and Export		Interest and Other			Consolidated Hess Midstream LP
Revenues
Affiliate services	$	422.9	$	294.7	$	130.0	$	-		$	847.6
Other income		-		0.6		0.1		-			0.7
Total revenues		422.9		295.3		130.1		-			848.3
Costs and expenses
Operating and maintenance expenses (exclusive of depreciation shown separately below)		145.4		73.1		58.3		-			276.8
Depreciation expense		81.6		44.7		16.2		-			142.5
General and administrative expenses		9.9		4.8		0.8		36.9			52.4
Total costs and expenses		236.9		122.6		75.3		36.9			471.7
Income (loss) from operations		186.0		172.7		54.8		(36.9	)		376.6
Income from equity investments		-		3.4		-		-			3.4
Interest expense, net		-		-		-		62.4			62.4
Income (loss) before income tax expense (benefit)		186.0		176.1		54.8		(99.3	)		317.6
Income tax expense (benefit)		-		-		-		(0.1	)		(0.1	)
Net income (loss)		186.0		176.1		54.8		(99.2	)		317.7
Less: Net income (loss) attributable to net parent investment		5.9		-		-		(60.9	)		(55.0	)
Less: Net income (loss) attributable to noncontrolling interest		145.5		141.5		44.3		(28.7	)		302.6
Net income (loss) attributable to Hess Midstream LP	$	34.6	$	34.6	$	10.5	$	(9.6	)	$	70.1

Throughput volumes
Gas gathering (MMcf/d)		275									275
Crude oil gathering (MBbl/d)		118									118
Gas processing (MMcf/d)				260							260
Crude oil terminaling (MBbl/d)						131					131
NGL loading (MBbl/d)						15					15
Water gathering (MBbl/d)		41									41

For the Year Ended December 31, 2018	Gathering		Processing and Storage		Terminaling and Export		Interest and Other			Consolidated Hess Midstream LP
Revenues
Affiliate services	$	375.2	$	251.4	$	85.4	$	-		$	712.0
Other income		-		-		0.7		-			0.7
Total revenues		375.2		251.4		86.1		-			712.7
Costs and expenses
Operating and maintenance expenses (exclusive of depreciation shown separately below)		103.5		56.1		33.9		-			193.5
Depreciation expense		67.2		43.9		15.8		-			126.9
General and administrative expenses		4.9		2.6		0.3		6.3			14.1
Total costs and expenses		175.6		102.6		50.0		6.3			334.5
Income (loss) from operations		199.6		148.8		36.1		(6.3	)		378.2
Interest expense, net		-		-		-		53.3			53.3
Gain on sale of property, plant and equipment		-		-		-		0.6			0.6
Net Income (loss)		199.6		148.8		36.1		(59.0	)		325.5
Less: Net income (loss) attributable to net parent investment		6.6		-		-		(53.4	)		(46.8	)
Less: Net income (loss) attributable to noncontrolling interest		154.6		118.1		28.8		-			301.5
Net income (loss) attributable to Hess Midstream Partners LP	$	38.4	$	30.7	$	7.3	$	(5.6	)	$	70.8

Throughput volumes
Gas gathering (MMcf/d)		248									248
Crude oil gathering (MBbl/d)		89									89
Gas processing (MMcf/d)				233							233
Crude oil terminaling (MBbl/d)						101					101
NGL loading (MBbl/d)						14					14
Water gathering (MBbl/d)		25									25

For the Year Ended December 31, 2017	Gathering		Processing and Storage		Terminaling and Export		Interest and Other			Consolidated Hess Midstream LP
Revenues
Affiliate services	$	285.5	$	227.3	$	66.7	$	-		$	579.5
Total revenues		285.5		227.3		66.7		-			579.5
Costs and expenses
Operating and maintenance expenses (exclusive of depreciation shown separately below)		91.2		58.5		36.3		-			186.0
Depreciation expense		57.8		43.6		15.1		-			116.5
General and administrative expenses		4.4		1.4		0.9		7.2			13.9
Total costs and expenses		153.4		103.5		52.3		7.2			316.4
Income (loss) from operations		132.1		123.8		14.4		(7.2	)		263.1
Interest expense, net		-		-		-		25.8			25.8
Gain on sale of property, plant and equipment		-		-		-		4.7			4.7
Net income (loss)		132.1		123.8		14.4		(28.3	)		242.0
Less: Net income (loss) attributable to net parent investment		16.4		31.7		2.3		(25.0	)		25.4
Less: Net income (loss) attributable to noncontrolling interest		92.4		73.3		9.7		-			175.4
Net income (loss) attributable to Hess Midstream Partners LP	$	23.3	$	18.8	$	2.4	$	(3.3	)	$	41.2

Throughput volumes
Gas gathering (MMcf/d)		213									213
Crude oil gathering (MBbl/d)		64									64
Gas processing (MMcf/d)				200							200
Crude oil terminaling (MBbl/d)						69					69
NGL loading (MBbl/d)						12					12
Water gathering (MBbl/d)		16									16

Revenues increased $47.7 million in 2019 compared to 2018, of which $21.2 million is attributable to higher third-party produced water trucking and disposal pass-through revenues and $3.9 million is attributable to pass-through electricity fees. In addition, $6.1 million of the increase is attributable to higher gas gathering and compression volumes, $5.8 million is attributable to higher water gathering volumes and $5.4 million is attributable to higher crude oil gathering volumes relative to 2018 minimum volume commitment levels driven by growing Hess production and additional third-party volumes contracted with Hess and delivered to us. The remaining $5.3 million of the increase in revenues is attributable to higher tariff rates. Operating and maintenance expenses increased $41.9 million, of which $21.2 million is attributable to higher third-party produced water trucking and disposal pass-through costs driven by growing Hess production, $14.1 million is attributable to higher maintenance activity on our expanded infrastructure, $3.9 million is attributable to pass-through electricity costs due to additional compressors coming online, and $2.7 million is attributable to higher property taxes due to additional assets acquired and placed into service. Depreciation expense increased $14.4 million due to gathering assets acquired from Summit Midstream Partners, LP at the end of the first quarter of 2019 and other new assets being brought into service. General and administrative expenses increased $5.0 million primarily attributable to higher charges from Hess under our omnibus and employee secondment agreements.

Revenues and other income increased $43.9 million in 2019 compared to 2018, of which $27.0 million is attributable to higher volumes, driven by LM4 ramp-up, which was placed into service in the third quarter of 2019, and continued backfilling of TGP with third-party volumes contracted with Hess and delivered to us. In addition, $15.2 million of the increase is attributable to higher tariff rates. The remaining $1.1 million of the increase in revenues is attributable to higher pass-through electricity fees and $0.6 million other income. Operating and maintenance expenses increased $17.0 million, of which $9.6 million is attributable to higher maintenance activity, including initial work on the TGP turnaround, which is planned for 2020, $6.3 million is attributable to LM4 processing fees and $1.1 million is attributable to pass-through electricity costs. The increase in general and administrative expenses of $2.2 million is primarily attributable to higher charges from Hess under our omnibus and employee secondment agreements.

Revenues and other income increased $44.0 million in 2019 compared to 2018, of which $23.4 million is attributable to higher rail transportation pass‑through revenues. In addition, $10.5 million of the increase is attributable to higher tariff rates and $10.1 million is attributable to higher crude oil throughput volumes at our terminals, driven by growing Hess production and increased third-party volumes contracted with Hess and delivered to us. Operating and maintenance expenses increased $24.4 million primarily attributable to higher rail transportation pass-through costs.

General and administrative expenses increased $30.6 million, of which $26.2 million is attributable to transaction costs incurred in the fourth quarter of 2019 in connection with the Restructuring and $4.4 million of the increase is attributable to higher other professional fees. Interest expense, net of interest income, increased $9.1 million primarily driven by borrowings on HIP revolving credit facility prior to the Restructuring and additional interest expense on newly issued $550 million of 5.125% fixed‑rate senior notes.

Revenues increased $89.7 million in 2018 compared to 2017, of which $36.4 million is attributable to higher third-party produced water trucking and disposal pass-through revenues and produced water gathering volumes driven by growing Hess production. In addition, $28.3 million is attributable to higher gas gathering and compression volumes driven by growing Hess production and additional third-party volumes contracted with Hess and delivered to us, and $20.4 million of the increase is attributable to higher crude oil gathering volumes also driven by growing Hess production and increased minimum volume commitments. The remaining $4.6 million of the increase is attributable to higher crude oil gathering tariff rates and pass-through electricity fees. Operating and maintenance expenses increased $12.3 million primarily attributable to higher produced water trucking and disposal costs driven by growing Hess production. Depreciation expense increased $9.4 million primarily due to a full year of depreciation of the Hawkeye Oil and Gas Facilities in 2018 compared to 2017 and additional new assets being brought into service in 2018.

Revenues increased $24.1 million in 2018 compared to 2017, of which $21.9 million of the increase is attributable to higher volumes processed through the Tioga Gas Plant, driven by growing Hess production and additional third-party volumes contracted with Hess and delivered to us. The remaining $2.2 million of the increase is primarily attributable to higher pass-through electricity fees in 2018 compared to 2017. Operating and maintenance expenses decreased $2.4 million primarily attributable to lower charges from Hess under our omnibus and employee secondment agreements. General and administrative expenses increased $1.2 million primarily attributable to professional fees related to the LM4 transaction.

Revenues increased $19.4 million in 2018 compared to 2017, of which $11.7 million is attributable to higher crude oil throughput volumes at our terminals, driven by completion of the Johnson’s Corner Header System in the second half of 2017, growing Hess production and increased third-party volumes contracted with Hess and delivered to us. In addition, $5.4 million of the increase is attributable to higher tariff rates in 2018 compared to 2017, $1.9 million of the increase is attributable to higher NGL volumes and $0.7 million of the increase is attributable to other income. These increases were partially offset by $0.3 million lower rail transportation pass-through revenue. Operating and maintenance expenses decreased $2.4 million primarily attributable to lower charges from Hess under our omnibus and employee secondment agreements.

General and administrative expenses decreased $0.9 million in 2018 compared to 2017, of which $1.8 million is attributable to fees incurred in 2017 related to the Partnership’s initial public offering and issuance of HIP fixed-rate senior notes, and $1.3 million of the decrease is attributable to rail car storage fees incurred in 2017. These decreases were partially offset by $2.2 million increase in public company costs as a result of us being a public company for the full year 2018 when compared to 2017. Interest expense, net of interest income increased $27.5 million, driven by the issuance of HIP fixed-rate senior notes in the fourth quarter of 2017. In 2018, we sold the remaining 105 older specification rail cars and recognized a gain of $0.6 million. As of December 31, 2018, we did not have any older specification rail cars in our fleet.

We currently generate substantially all of our revenues under fee‑based commercial agreements with Hess, including third parties contracted with affiliates of Hess. These contracts promote cash flow stability and minimize our direct exposure to commodity price fluctuations, since we generally do not own any of the crude oil, natural gas, or NGLs that we handle and do not engage in the trading of crude oil, natural gas, or NGLs. However, commodity price fluctuations indirectly influence our activities and results of operations over the long term, since they can affect production rates and investments by Hess and third parties in the development of new crude oil and natural gas reserves. For example, as a result of the decline in crude oil prices beginning in late 2014, Hess reduced its rig count to two rigs in the Bakken during 2016. During this time, minimum volume commitments provided minimum levels of cash flows and the fee recalculation mechanisms under the agreements supported cash flow stability. Hess subsequently increased its rig count and operated six rigs in the Bakken in 2019. The throughput volumes at our facilities depend primarily on the volumes of crude oil and natural gas produced by Hess in the Bakken, which, in turn, is ultimately dependent on Hess’ exploration and production margins. Exploration and production margins depend on the price of crude oil, natural gas, and NGLs. These prices are volatile and influenced by numerous factors beyond our or Hess’ control, including the domestic and global supply of and demand for crude oil, natural gas and NGLs. The commodities trading markets, as well as global and regional supply and demand factors, may also influence the selling prices of crude oil, natural gas and NGLs. Furthermore, our ability to execute our growth strategy in the Bakken will depend on crude oil and natural gas production in that area, which is also affected by the supply of and demand for crude oil and natural gas.

The following table presents a reconciliation of Adjusted EBITDA to net income and net cash provided by operating activities, the most directly comparable GAAP financial measures, for each of the periods indicated.

	Year Ended December 31,
	2019			2018			2017
(in millions)
Reconciliation of Adjusted EBITDA and Distributable Cash Flow to net income:
Net income	$	317.7		$	325.5		$	242.0
Plus:
Depreciation expense		142.5			126.9			116.5
Proportional share of equity affiliates' depreciation		2.0			-			-
Interest expense, net		62.4			53.3			25.8
Income tax expense (benefit)		(0.1	)		-			-
Transaction costs		26.2			-			-
Less:
Gain on sale of property, plant and equipment		-			0.6			4.7
Adjusted EBITDA	$	550.7		$	505.1		$	379.6
Adjusted EBITDA prior to Restructuring		392.3			505.1			379.6
Less:
Adjusted EBITDA attributable to noncontrolling interest and net parent investment prior to Restructuring		316.5			408.4			320.3
Cash interest paid, net⁽¹⁾		1.1			-			0.6
Maintenance capital expenditures, net⁽²⁾		1.0			0.7			-
Distributable cash flow prior to Restructuring, as previously reported⁽³⁾	$	73.7		$	96.0		$	58.7
Adjusted EBITDA subsequent to Restructuring		158.4
Less:
Interest, net		16.6
Maintenance capital expenditures		1.7
Distributable cash flow subsequent to Restructuring⁽³⁾	$	140.1

Reconciliation of Adjusted EBITDA and Distributable Cash Flow to net cash provided by operating activities:
Net cash provided by operating activities	$	470.7		$	466.9		$	336.5
Changes in assets and liabilities		(12.3	)		(9.6	)		19.6
Amortization of deferred financing costs		(5.1	)		(5.0	)		(3.8	)
Capitalized interest		4.1			-			-
Proportional share of equity affiliates' depreciation		2.0			-			-
Interest expense, net		62.4			53.3			25.8
Earnings from equity investments		3.4			-			-
Transaction costs		26.2			-			-
Other		(0.7	)		(0.5	)		1.5
Adjusted EBITDA	$	550.7		$	505.1		$	379.6
Adjusted EBITDA prior to Restructuring		392.3
Less:
Adjusted EBITDA attributable to noncontrolling interest and net parent investment prior to Restructuring		316.5			408.4			320.3
Cash interest paid, net⁽¹⁾		1.1			-			0.6
Maintenance capital expenditures, net⁽²⁾		1.0			0.7			-
Distributable cash flow prior to Restructuring, as previously reported⁽³⁾	$	73.7		$	96.0		$	58.7
Adjusted EBITDA subsequent to Restructuring		158.4
Less:
Interest, net		16.6
Maintenance capital expenditures		1.7
Distributable cash flow subsequent to Restructuring⁽³⁾	$	140.1

We believe that cash generated from these sources will be sufficient to meet our operating requirements, our planned capital expenditures, debt service requirements, our quarterly cash distribution requirements, future internal growth projects or potential acquisitions.

Our partnership agreement requires that we distribute all of our available cash to shareholders. During the year ended December 31, 2019, we made distributions of $85.4 million, to the holders of our equity securities representing limited partner interests in us. On January 27, 2020, we declared a quarterly cash distribution of $0.4258 per Class A Share that was paid on February 14, 2020 to shareholders of record on February 6, 2020.

In November 2017, HIP issued $800.0 million of 5.625% fixed‑rate senior notes due 2026 to qualified institutional investors. In December 2019, in connection with the Restructuring, the Partnership, Hess Midstream Operations LP, a consolidated subsidiary of the Company, assumed $800.0 million of outstanding HIP senior notes in a par-for-par exchange for newly issued 5.625% senior notes due 2026 of the Partnership and paid approximately $2.0 million of exchange consent fees. The notes are guaranteed by certain subsidiaries of the Partnership. Interest is payable semi‑annually on February 15 and August 15.

In December 2019, the Partnership issued $550.0 million of 5.125% fixed‑rate senior notes due 2028 to qualified institutional investors. The notes are guaranteed by certain subsidiaries of the Partnership. Interest is payable semi‑annually on June 15 and December 15. The Partnership used the net proceeds to finance the acquisition of HIP, including to repay borrowings under HIP’s credit facilities, and pay related fees and expenses.

Each of the indentures for the 2026 and 2028 senior notes contains customary covenants that restrict our ability and the ability of our restricted subsidiaries to (i) declare or pay any dividend or make any other restricted payments; (ii) transfer or sell assets or subsidiary stock; (iii) incur additional debt; or (iv) make restricted investments, unless, at the time of and immediately after giving pro forma effect to such restricted payments and any related incurrence of indebtedness or other transactions, no default has occurred and is continuing or would occur as a consequence of such restricted payment and if the leverage ratio does not exceed 4.25 to 1.00. As of December 31, 2019, we were in compliance with all debt covenants under the indentures.

In addition, the covenants included in the indentures governing the senior notes contain provisions that allow the Company to satisfy the Partnership’s reporting obligations under the indenture, as long as any such financial information of the Company contains information reasonably sufficient to identify the material differences, if any, between the financial information of the Company, on the one hand, and the Partnership and its subsidiaries on a stand-alone basis, on the other hand and the Company does not directly own capital stock of any person other than the Partnership and its subsidiaries, or material business operations that would not be consolidated with the financial results of the Partnership and its subsidiaries. The Company is a holding company and has no independent assets or operations. Other than the interest in the Partnership and the effect of federal and state income taxes that are recognized at the Company level, there are no material differences between the consolidated financial statements of the Partnership and the consolidated financial statements of the Company.

In December 2019, the Partnership entered into senior secured syndicated credit facilities (the “Credit Facilities”) consisting of a $1,000.0 million 5-year revolving credit facility and a fully drawn $400.0 million 5-year Term Loan A facility. Facility fees accrue on the total capacity of the revolving credit facility. Borrowings under the 5-year Term Loan A facility will generally bear interest at LIBOR plus an applicable margin ranging from 1.55% to 2.50%, while the applicable margin for the 5-year syndicated revolving credit facility ranges from 1.275% to 2.000%. Pricing levels for the facility fee and interest rate margins are based on the Partnership’s ratio of total debt to EBITDA (as defined in the Credit Facilities). If the Partnership obtains an investment grade credit rating, the pricing levels will be based on the Partnership’s credit ratings in effect from time to time. At December 31, 2019, borrowings of $32.0 million were drawn under the Partnership’s revolving credit facility, and borrowings of $400.0 million, excluding deferred issuance costs, were drawn under the Partnership’s Term Loan A facility.

The Credit Facilities can be used for borrowings and letters of credit for general corporate purposes. The Credit Facilities are guaranteed by each direct and indirect wholly owned material domestic subsidiary of the Partnership, and are secured by first priority perfected liens on substantially all of the presently owned and after-acquired assets of the Partnership and its direct and indirect wholly owned material domestic subsidiaries, including equity interests directly owned by such entities, subject to certain customary exclusions. The Credit Facilities contain representations and warranties, affirmative and negative covenants and events of default that the Partnership considers to be customary for an agreement of this type, including a covenant that requires the Partnership to maintain a ratio of total debt to EBITDA (as defined in the Credit Facilities) for the prior four fiscal quarters of not greater than 5.00 to 1.00 as of the last day of each fiscal quarter (5.50 to 1.00 during the specified period following certain acquisitions) and, prior to the Partnership obtaining an investment grade credit rating, a ratio of secured debt to EBITDA for the prior four fiscal quarters of not greater than 4.00 to 1.00 as of the last day of each fiscal quarter. As of December 31, 2019, the Partnership was in compliance with these financial covenants.

At December 31, 2018, HIP had $800 million of senior secured syndicated credit facilities maturing in 2022, consisting of a $600.0 million 5-year revolving credit facility and a drawn $200.0 million 5-year Term Loan A facility. In addition, the Partnership had a $300.0 million 4-year senior secured revolving credit facility maturing in 2021. In connection with the Restructuring, the Partnership entered into new Credit Facilities, as described above. The proceeds from the new Credit Facilities were used to finance the acquisition of HIP, including to repay borrowings under HIP’s credit facilities, and pay related fees.

Operating Activities. Cash flows provided by operating activities increased $3.8 million in 2019 compared to 2018. The change in operating cash flows resulted from an increase in revenues and other income of $135.6 million and an increase in cash provided by changes in working capital of $2.7 million, offset by an increase in expenses, other than depreciation, amortization, equity‑based compensation and other non-cash gains and losses of $134.5 million.

Cash flows provided by operating activities increased $130.4 million in 2018 compared to 2017. The change in operating cash flows resulted from an increase in revenues and other income of $133.2 million and an increase in cash provided by changes in working capital of $29.2 million, offset by an increase in expenses, other than depreciation, amortization, unit-based compensation and other non-cash gains and losses of $32.0 million.

Investing Activities. Cash flows used in investing activities increased $189.9 million in 2019 compared to 2018. The increase in investing cash outflows resulted from the acquisition of Summit Midstream Partners’ Tioga Gathering System of $89.2 million, net of cash acquired, the acquisition of $68.9 million of net assets in connection with the Hess Water Services acquisition, an increase in payments for capital expenditures of $64.5 million and a decrease in proceeds from sale of property, plant and equipment of $1.6 million. These cash outflows were offset by a decrease in our payments for our equity investment in LM4 of $34.3 million.

Cash flows used in investing activities increased $176.2 million in 2018 compared to 2017, primarily due to an increase in payments for capital expenditures of $97.7 million, our investment in the LM4 joint venture of $67.3 million and lower proceeds from sale of property, plant and equipment of $11.2 million.

Financing Activities. Cash flows used in financing activities decreased $326.5 million in 2019 compared to 2018 as a result of increased net borrowings of $767.6 million, net of any changes in financing costs, a decrease in distributions to Hess, GIP and our limited partners and other distributions of $160.7 million, offset by cash consideration paid related to the Restructuring of $601.8 million.

Cash flows used in financing activities increased $554.6 million in 2018 compared to 2017. In 2018, total distributions to Hess, GIP and our limited partners totaled $402.2 million. HIP also repaid $2.5 million of the Term Loan A facility and paid $1.0 million financing costs related to its fixed-rate senior notes. In 2017, net cash proceeds driven by the use of HIP credit facilities and debt restructuring activities were $243.0 million, net proceeds retained from the Partnership’s IPO were $10.0 million, offset by distributions to Hess, GIP, and our limited partners of $104.1 million.

Our operations can be capital intensive, requiring investments to expand, upgrade, maintain or enhance existing operations and to meet environmental and operational regulations. Our partnership agreement requires that we distinguish between maintenance capital expenditures and expansion capital expenditures. Maintenance capital expenditures are capital expenditures made to maintain, over the long term, our operating capacity, operating income or revenue. Examples of maintenance capital expenditures are expenditures to repair, refurbish or replace existing assets, to maintain equipment reliability, integrity and safety and to address environmental laws and regulations. In contrast, expansion capital expenditures are expenditures incurred for acquisitions or capital improvements that we expect will increase our operating capacity, operating income or revenue over the long term. Examples of expansion capital expenditures include the acquisition of equipment, construction, development or acquisition of additional capacity, or expenditures for connecting additional wells to our gathering systems, to the extent such capital expenditures are expected to expand our long‑term operating capacity, operating income or revenue.

The following table sets forth a summary of maintenance and expansion capital expenditures and reconciles capital expenditures on an accrual basis to additions to property, plant and equipment on a cash basis:

Capital expenditures are primarily attributable to continued expansion of our gathering system and compression capacity to support Hess and third-party growth. Capital expenditures in 2019 also include amounts attributable to engineering, procurement, civil construction and fabrication activities for the planned expansion of the Tioga Gas Plant. Additionally, in 2019, we acquired Hess Water Services for cash consideration of $225.0 million, of which $68.9 million was recognized as additions to property, plant, and equipment and $156.1 million was recognized as a distribution to Hess. We also acquired Summit Midstream Partners’ Tioga Gathering System for cash consideration of $89.2 million, with the potential for an additional $10 million of contingent payments in future periods subject to certain future performance metrics.

A summary of our contractual obligations as of December 31, 2019, is as follows:

	Total		2020		2021		2022		2023		2024		2025 and thereafter
(in millions)
Fixed-rate senior notes	$	1,350.0	$	-	$	-	$	-	$	-	$	-	$	1,350.0
Term Loan facility		400.0		-		10.0		20.0		30.0		340.0		-
Revolving credit facility		32.0		-		-		-		-		32.0		-
Operating leases		1.1		0.2		0.1		0.1		0.1		0.1		0.5
Purchase obligations		65.0		65.0		-		-		-		-		-
Total	$	1,848.1	$	65.2	$	10.1	$	20.1	$	30.1	$	372.1	$	1,350.5

We have not entered into any transactions, agreements or other contractual arrangements that would result in off‑balance sheet liabilities.

Accounting policies and estimates affect the recognition of assets and liabilities in our consolidated balance sheets and revenues and expenses in our consolidated statements of operations. The accounting methods used can affect net income, partners’ capital and various financial statement ratios. However, the accounting methods generally do not change cash flows or liquidity. We consider the following policies to be the most critical in understanding the judgments that are involved in preparing our financial statements and the uncertainties that could impact our financial condition and results of operations.

Property, plant and equipment are stated at the lower of historical cost less accumulated depreciation, subject to the results of impairment testing. We capitalize all construction-related direct labor and material costs, as well as indirect construction costs. Indirect construction costs include general engineering, taxes and the cost of funds used during construction of material projects. Costs, including complete asset replacements and enhancements or upgrades that increase the original efficiency, productivity or capacity of property, plant and equipment, are also capitalized. The costs of repairs, minor replacements and other projects, which do not increase the original efficiency, productivity or capacity of property, plant and equipment, are expensed as incurred. The determination of cost componentization and related estimated useful lives is a significant element in arriving at the results of operations. The estimates affect depreciation expense in our accompanying consolidated statements of operations and balance sheets.

We review long-lived assets for impairment whenever events or changes in business circumstances indicate the net book values of the assets may not be recoverable. Impairment is indicated when the undiscounted cash flows estimated to be generated by those assets are less than the assets’ net book value. Undiscounted cash flows are based on identifiable cash flows that are largely independent of the cash flows of other assets and liabilities. If impairment occurs, a loss is recognized for the difference between fair value and net book value. Such fair value is generally determined by discounting anticipated future net cash flows, an income valuation approach, or by a market-based valuation approach, which are Level 3 fair value measurements. Factors that indicate potential impairment include a significant decrease in the market value of the asset, operating or cash flow losses associated with the use of the asset, and a significant change in the asset’s physical condition or use. No impairments of long-lived assets were recorded during the periods included in the accompanying consolidated financial statements. The determination of impairments could be a significant element in arriving at the results of operations. Impairment charges would impact total costs and expenses and net Property, Plant & Equipment in our accompanying consolidated statements of operations and balance sheets.

We calculate depreciation using the straight‑line method based on the estimated useful lives after considering salvage values of our assets. When assets are placed into service, we make estimates with respect to their useful lives that we believe are reasonable. Depreciation lives related to our significant assets primarily range between 12 to 35 years. However, factors such as maintenance levels, economic conditions impacting the demand for these assets, and regulatory or environmental requirements could cause us to change our estimates, and impact our future calculation of depreciation. The determination of estimated useful lives is a significant element in arriving at depreciation expense. The estimates affect depreciation expense and cost componentization in our accompanying consolidated statements of operations and balance sheets.

In the ordinary course of business, we may become party to lawsuits, administrative proceedings and governmental investigations, including environmental, regulatory and other matters. Damages or penalties may be sought from us in some matters for which the likelihood of loss may be probable or possible but the amount of loss is not currently estimable. Costs that relate to an existing condition caused by past operations are expensed. Contingent liabilities are recorded when probable and reasonably estimable. On the basis of existing information, we believe that the resolution of any such matters, individually or in the aggregate, will not have a material adverse effect on our financial position or results of operations. Estimates related to contingencies affect operating expenses in our accompanying consolidated statements of operations and liabilities in our balance sheets.

Market risk is the risk of loss arising from adverse changes in market rates and prices. We generally do not take ownership of the crude oil, natural gas or NGLs that we currently gather, process, terminal, store or transport for our customers. Because we generate substantially all of our revenues by charging fees under long-term commercial agreements with Hess with minimum volume commitments, Hess bears the risks associated with fluctuating commodity prices and we have minimal direct exposure to commodity prices.

In the normal course of our business, we are exposed to market risks related to changes in interest rates. Our financial risk management activities may include transactions designed to reduce risk by reducing our exposure to interest rate movements. Interest rate swaps may be used to convert interest payments on certain long‑term debt. At December 31, 2019, we did not have in place any derivative instruments to hedge any exposure to changes in interest rates.

At December 31, 2019, our total long-term debt had a carrying value of $1,753.5 million and a fair value of approximately $1,820.1 million, based on Level 2 inputs in the fair value measurement hierarchy. A 15% increase or decrease in interest rates would decrease or increase the fair value of our fixed rate debt by approximately $57.4 million or $60.3 million, respectively. The carrying value of the amounts under our Term Loan A facility and revolving credit facility at the year end approximated their fair value. Any changes in interest rates do not impact cash outflows associated with fixed rate interest payments or settlement of debt principal, unless a debt instrument is repurchased prior to maturity.

We have audited Hess Midstream LP’s internal control over financial reporting as of December 31, 2019, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) (the COSO criteria). In our opinion, the Hess Midstream LP (the “Company”) maintained, in all material respects, effective internal control over financial reporting as of December 31, 2019, based on the COSO criteria.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheets of the Company as of December 31, 2019 and 2018, the related consolidated statements of operations, comprehensive income, changes in partners’ capital, and cash flows for each of the three years in the period ended December 31, 2019, and the related notes and our report dated February 21, 2020 expressed an unqualified opinion thereon.

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

We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects.

Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

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

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

We have audited the accompanying consolidated balance sheets of Hess Midstream LP (the “Company”) as of December 31, 2019 and 2018, the related consolidated statements of operations, comprehensive income, changes in partners’ capital, and cash flows for each of the three years in the period ended December 31, 2019, and the related notes (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the consolidated financial position of the Company at December 31, 2019 and 2018, and the consolidated results of its operations and its cash flows for each of the three years in the period ended December 31, 2019, in conformity with U.S. generally accepted accounting principles.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company’s internal control over financial reporting as of December 31, 2019, based on criteria established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework), and our report dated February 21, 2020 expressed an unqualified opinion thereon.

These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.

	December 31,		December 31,
	2019		2018⁽¹⁾
(in millions, except unit and share amounts)
Assets
Cash and cash equivalents	$	3.3	$	109.3
Accounts receivable—affiliate:
From contracts with customers		87.6		67.3
Other receivables		0.3		0.5
Other current assets		4.7		3.3
Total current assets		95.9		180.4
Equity investments		107.8		67.3
Property, plant and equipment, net		3,010.1		2,735.3
Long-term receivable—affiliate		1.2		1.3
Deferred tax asset		49.8		-
Other noncurrent assets		12.9		6.9
Total assets	$	3,277.7	$	2,991.2
Liabilities
Accounts payable—trade	$	30.6	$	18.6
Accounts payable—affiliate		47.9		15.8
Accrued liabilities		88.7		85.6
Current maturities of long-term debt		-		11.3
Other current liabilities		8.9		6.8
Total current liabilities		176.1		138.1
Long-term debt		1,753.5		969.8
Other noncurrent liabilities		16.0		7.2
Total liabilities		1,945.6		1,115.1
Partners' capital
Class A shares (17,960,655 shares issued and outstanding as of December 31, 2019; none issued and outstanding as of December 31, 2018)		131.1		-
Class B shares (266,416,928 shares issued and outstanding as of December 31, 2019; none issued and outstanding as of December 31, 2018)		-		-
Common unitholders—public (none issued and outstanding as of December 31, 2019; 17,014,377 units issued and outstanding as of December 31, 2018)		-		357.1
Common unitholders—affiliate (none issued and outstanding as of December 31, 2019; 10,282,654 units issued and outstanding as of December 31, 2018)		-		39.5
Subordinated unitholders—affiliate (none issued and outstanding as of December 31, 2019; 27,279,654 units issued and outstanding as of December 31, 2018)		-		105.3
General partner		-		14.9
Total partners' capital		131.1		516.8
Noncontrolling interest		1,200.6		2,194.1
Accumulated other comprehensive income		0.4		1.2
Net parent investment		-		(836.0	)
Total partners' capital		1,332.1		1,876.1
Total liabilities and partners' capital	$	3,277.7	$	2,991.2
⁽¹⁾ The financial information presented in this report has been retrospectively adjusted for the acquisition of Hess Infrastructure Partners LP.

	Year Ended December 31,
	2019			2018⁽¹⁾			2017⁽¹⁾
(in millions, except per unit/share data)
Revenues
Affiliate services	$	847.6		$	712.0		$	579.5
Other income		0.7			0.7			-
Total revenues		848.3			712.7			579.5
Costs and expenses
Operating and maintenance expenses (exclusive of depreciation shown separately below)		276.8			193.5			186.0
Depreciation expense		142.5			126.9			116.5
General and administrative expenses		52.4			14.1			13.9
Total costs and expenses		471.7			334.5			316.4
Income from operations		376.6			378.2			263.1
Income from equity investments		3.4			-			-
Interest expense, net		62.4			53.3			25.8
Gain on sale of property, plant and equipment		-			0.6			4.7
Income before income tax expense (benefit)		317.6			325.5			242.0
Income tax expense (benefit)		(0.1	)		-			-
Net income		317.7			325.5			242.0
Less: Net income (loss) attributable to net parent investment		(55.0	)		(46.8	)		25.4
Less: Net income (loss) attributable to noncontrolling interest		302.6			301.5			175.4
Net income attributable to Hess Midstream LP		70.1			70.8			41.2
Less: General partner's interest in net income prior to the Restructuring		3.4			1.7			0.8
Limited partners' interest in net income	$	66.7		$	69.1		$	40.4

Net income attributable to Hess Midstream LP per Class A share/limited partner unit:
Basic:	$	1.21
Diluted:	$	1.20
Net income attributable to Hess Midstream LP per limited partner unit (basic and diluted):
Common				$	1.27		$	0.75
Subordinated				$	1.27		$	0.75
Weighted average Class A shares outstanding subsequent to the Restructuring (basic and diluted):		18.0
Weighted average limited partner units outstanding prior to the Restructuring
Basic:
Common		27.3			27.3			26.9
Subordinated		27.3			27.3			26.9
Diluted:
Common		27.5			27.4			26.9
Subordinated		27.3			27.3			26.9
⁽¹⁾ The financial information presented in this report has been retrospectively adjusted for the acquisition of Hess Infrastructure Partners LP.

	Partners' Capital
	Limited Partners
	Common Unitholders Public			Common Unitholders Affiliate			Subordinated Unitholders Affiliate			General Partner			Noncontrolling Interest			Accumulated Other Comprehensive Income			Net Parent Investment			Total ⁽¹⁾
(in millions)
Balance at December 31, 2016	$	-		$	-		$	-		$	-		$	-		$	-		$	1,809.9		$	1,809.9
Contribution of net assets to Hess Midstream Partners LP		-			134.6			357.2			14.6			2,025.2			-			(2,531.6	)		-
IPO proceeds, net of underwriters' discounts		365.5			-			-			-			-			-			-			365.5
Distributions of IPO proceeds		-			(95.7	)		(253.8	)		-			-			-			-			(349.5	)
Offering costs		(10.7	)		-			-			-			-			-			-			(10.7	)
Net income		12.6			7.6			20.2			0.8			175.4			-			25.4			242.0
Other comprehensive income (loss)		-			-			-			-			-			1.6			-			1.6
Equity-based compensation		0.2			-			-			-			-			-			-			0.2
Distributions to unitholders - $0.5810 per unit		(9.9	)		(6.0	)		(15.8	)		-			-			-			-			(31.7	)
Distributions to general partner		-			-			-			(0.6	)		-			-			0.6			-
Distributions to noncontrolling interest		-			-			-			-			(244.6	)		-			244.6			-
Contributions from noncontrolling interest		-			-			-			-			78.5			-			(78.5	)		-
Other contributions (distributions)		-			-			-			-			-			-			(75.0	)		(75.0	)
Balance at December 31, 2017	$	357.7		$	40.5		$	107.8		$	14.8		$	2,034.5		$	1.6		$	(604.6	)	$	1,952.3
Net income		21.6			13.0			34.5			1.7			301.5			-			(46.8	)		325.5
Other comprehensive income (loss)		-			-			-			-			-			(0.4	)		-			(0.4	)
Equity-based compensation		0.9			-			-			-			-			-			-			0.9
Distributions to unitholders - $1.3578 per unit		(23.1	)		(14.0	)		(37.0	)		-			-			-			-			(74.1	)
Distributions to general partner		-			-			-			(1.6	)		-			-			1.6			-
Distributions to noncontrolling interest		-			-			-			-			(199.2	)		-			199.2			-
Contributions from noncontrolling interest		-			-			-			-			57.3			-			(57.3	)		-
Other contributions (distributions)		-			-			-			-			-			-			(328.1	)		(328.1	)
Balance at December 31, 2018	$	357.1		$	39.5		$	105.3		$	14.9		$	2,194.1		$	1.2		$	(836.0	)	$	1,876.1
(1) The financial information presented in this report has been retrospectively adjusted for the acquisition of Hess Infrastructure Partners LP.

	Partners' Capital
	Limited Partners
	Class A Shares			Class B Shares		Common Unitholders Public			Common Unitholders Affiliate			Subordinated Unitholders Affiliate			General Partner			Noncontrolling Interest			Accumulated Other Comprehensive Income			Net Parent Investment			Total ⁽¹⁾
(in millions)																											`
Balance at December 31, 2018	$	-		$	-	$	357.1		$	39.5		$	105.3		$	14.9		$	2,194.1		$	1.2		$	(836.0	)	$	1,876.1
Net income prior to Restructuring		-			-		20.8			12.9			33.5			3.4			309.4			-			(55.0	)		325.0
Equity-based compensation prior to Restructuring		-			-		1.3			-			-			-			-			-			-			1.3
Distributions to unitholders prior to Restructuring - $1.5616 per unit		-			-		(26.8	)		(16.0	)		(42.6	)		-			-			-			-			(85.4	)
Distributions to general partner prior to Restructuring		-			-		-			-			-			(3.8	)		-			-			3.8			-
Distributions to noncontrolling interest prior to Restructuring		-			-		-			-			-			-			(200.6	)		-			200.6			-
Contributions from noncontrolling interest prior to Restructuring		-			-		-			-			-			-			76.3			-			(76.3	)		-
Acquisition of Hess Water Services		-			-		-			-															(225.0	)		(225.0	)
Equity exchange related to Restructuring		81.4			-		(352.4	)		(36.4	)		(96.2	)		(14.5	)		(569.8	)		-			987.9			-
Cash consideration related to Restructuring		-			-		-			-			-			-			(601.8	)		-			-			(601.8	)
Recognition of Deferred Tax Asset		50.0			-		-			-			-			-			(0.2	)		-			-			49.8
Net income after Restructuring		(0.5	)		-		-			-			-			-			(6.8	)		-			-			(7.3	)
Equity-based compensation after restructuring		0.2			-		-			-			-			-			-			-			-			0.2
Other comprehensive income (loss)		-			-		-			-			-			-			-			(0.8	)		-			(0.8	)
Balance at December 31, 2019	$	131.1		$	-	$	-		$	-		$	-		$	-		$	1,200.6		$	0.4		$	-		$	1,332.1
(1) The financial information presented in this report has been retrospectively adjusted for the acquisition of Hess Infrastructure Partners LP.

	Year Ended December 31,
	2019			2018⁽¹⁾			2017⁽¹⁾
(in millions)
Cash flows from operating activities
Net income	$	317.7		$	325.5		$	242.0
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation expense		142.5			126.9			116.5
(Gain) loss on sale of property, plant and equipment		-			(0.6	)		(4.7	)
(Gain) loss on interest rate swaps		(0.8	)		(0.4	)		(1.7	)
(Income) loss from equity investments		(3.4	)		-			-
(Increase) decrease in capitalized interest		(4.1	)		-			-
Amortization of deferred financing costs		5.1			5.0			3.8
Equity-based compensation expense		1.5			0.9			0.2
Deferred income tax expense (benefit)		(0.1	)		-			-
Changes in assets and liabilities:
Accounts receivable – affiliate		(19.5	)		(6.3	)		(16.9	)
Other current and noncurrent assets		(1.4	)		1.9			1.2
Accounts payable – trade		11.5			4.0			(16.7	)
Accounts payable – affiliate		3.7			(6.4	)		7.5
Accrued liabilities		18.6			17.3			3.2
Other current and noncurrent liabilities		(0.6	)		(0.9	)		2.1
Net cash provided by (used in) operating activities		470.7			466.9			336.5
Cash flows from investing activities
Acquisitions from third parties, net of cash acquired		(89.2	)		-			-
Acquisitions from Hess		(68.9	)		-			-
Payments for equity investments		(33.0	)		(67.3	)		-
Proceeds from sale of property, plant and equipment		-			1.6			12.8
Additions to property, plant and equipment		(306.4	)		(241.9	)		(144.2	)
Net cash provided by (used in) investing activities		(497.5	)		(307.6	)		(131.4	)
Cash flows from financing activities
Proceeds from (repayments of) bank borrowings - revolver		32.0			-			(153.0	)
Term loan:
Borrowings		210.0			-			-
Repayments		(7.5	)		(2.5	)		(385.0	)
Proceeds from issuance of senior notes		550.0			-			800.0
Financing costs		(20.4	)		(1.0	)		(22.9	)
IPO proceeds, net of underwriters' discounts		-			-			365.5
Distribution of IPO proceeds to Hess and GIP		-			-			(349.5	)
Cash offering costs		-			-			(2.1	)
Distributions to Hess and GIP		-			(322.0	)		(100.0	)
Distributions to HESM limited partners		(85.4	)		(74.1	)		(31.7	)
Cash consideration paid related to Restructuring		(601.8	)		-			-
Capital distribution to Hess associated with acquisitions		(156.1	)		-			-
Other contributions (distributions)		-			(6.1	)		27.6
Net cash provided by (used in) financing activities		(79.2	)		(405.7	)		148.9
Increase (decrease) in cash and cash equivalents		(106.0	)		(246.4	)		354.0
Cash and cash equivalents, beginning of period		109.3			355.7			1.7
Cash and cash equivalents, end of period	$	3.3		$	109.3		$	355.7
Supplemental disclosure of non-cash investing and financing activities:
(Increase) decrease in accrued capital expenditures and related liabilities	$	(10.7	)	$	(29.4	)	$	25.9
Recognition of deferred tax asset	$	49.7		$	-		$	-
Removal of historical capitalized offering costs	$	-		$	-		$	8.6
⁽¹⁾ The financial information presented in this report has been retrospectively adjusted for the acquisition of Hess Infrastructure Partners LP.

Financial information presented in this report has been retrospectively adjusted for the acquisition of Hess Infrastructure Partners LP.

Unless the context otherwise requires, references in this report to the “Company,” “we,” “our,” “us” or like terms, refer to Hess Midstream LP and its subsidiaries. The “Partnership” refers to Hess Midstream Operations LP (formerly Hess Midstream Partners LP), a consolidated subsidiary of the Company. Our “general partner” refers to Hess Midstream GP LP. “Hess” refers collectively to Hess Corporation and its subsidiaries, other than us.

Description of Business. We are a fee-based, growth-oriented, Delaware limited partnership formed by Hess Infrastructure Partners GP LLC (“HIP GP LLC”) and our general partner in 2019 to own, operate, develop and acquire a diverse set of midstream assets and provide fee-based services to Hess and third-party customers. We are managed and controlled by Hess Midstream GP LLC, the general partner of our general partner. Our assets are primarily located in the Bakken and Three Forks shale plays in the Williston Basin area of North Dakota, which we collectively refer to as the Bakken.

Our assets and operations are organized into the following three segments: (i) gathering, (ii) processing and storage and (iii) terminaling and export (see Note 13, Segments).

The 2019 Restructuring. On December 16, 2019, the Company and the Partnership completed the transactions (the “Restructuring”) contemplated by the partnership restructuring agreement, dated October 3, 2019, by and among the Company, the Partnership and the other parties thereto. As a result of the Restructuring, the Company was delegated control of the Partnership and replaced the Partnership as its publicly traded successor.

Pursuant to the Restructuring, which was consummated on December 16, 2019, the Partnership acquired HIP, including HIP’s 80% interest in the Joint Interest Assets, 100% interest in Hess Water Services and the outstanding economic general partner interest and IDRs. The Partnership’s organizational structure converted from a master limited partnership into an “Up-C” structure in which the Partnership’s public unitholders received newly issued Class A shares (“Class A Shares”) representing limited partner interest in Hess Midstream LP in a one-for-one exchange. The Partnership changed its name to “Hess Midstream Operations LP” and became a consolidated subsidiary of the Company.

LM4 Joint Venture. On January 25, 2018, we entered into a 50/50 joint venture with Targa Resources Corp. (“Targa”) to construct a new 200 MMcf/d gas processing plant called Little Missouri 4 (“LM4”). LM4 was placed in service in the third quarter of 2019. Targa is the operator of the plant. See Note 4, Related Party Transactions.

Consolidation. The consolidated financial statements include our accounts and the accounts of entities over which we have a controlling financial interest through our ownership or the majority voting interests of the entity. We consolidate the activities of the Partnership, and prior to the Restructuring the activities of Gathering Opco, HTGP Opco and Logistics Opco, each as a variable interest entity (“VIE”) under U.S. Generally Accepted Accounting Principles (“GAAP”). We have concluded that we are the primary beneficiary of the VIE, as defined in the accounting standards, since we have the power, through our ownership, to direct those activities that most significantly impact the economic performance of the Partnership. This conclusion was based on a qualitative analysis that considered the Partnership’s governance structure and the delegation of control provisions, which provide us the ability to control the operations of the Partnership. All financial statement activities associated with the VIE are captured within gathering, processing and storage, and terminaling and export segments (see Note 14, Segments). Our noncontrolling interest represents the 93.68% interest in the Partnership retained by Hess and GIP. Prior to the Restructuring, our noncontrolling interest represented the 80% interest in the Joint Interest Assets retained by HIP. All intercompany transactions and balances have been eliminated.

Use of Estimates. We prepare our consolidated financial statements in conformity with the U.S. GAAP, which require management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the years presented. Changes in facts and circumstances may result in revised estimates and actual results could differ from those estimates.

Common Control Transactions. Assets and businesses acquired from Hess and its subsidiaries are accounted for as common control transactions whereby the net assets acquired are combined with net assets of the Company at Hess’ historical carrying value. If any recognized consideration transferred in such a transaction exceeds the carrying value of the net assets acquired, the excess is treated as a capital distribution to Hess, similar to a dividend. To the extent that such transactions require prior periods to be retrospectively adjusted, historical net equity amounts prior to the transaction date are reflected in “Net Parent Investment.” Cash consideration up to the carrying value of net assets acquired is presented as an investing activity in our consolidated statement of cash flows. Cash consideration in excess of the carrying value of net assets acquired is presented as a financing activity in our consolidated statement of cash flows.

Cash and Cash Equivalents. Cash equivalents consist of highly liquid investments, which are readily convertible into cash and have maturities of three months or less when acquired.

Accounts Receivable. We record affiliate accounts receivable upon performance of services to affiliated companies. Generally, we receive payments from affiliated companies on a monthly basis, shortly after performance of services. There were no doubtful accounts written off, nor have we provided an allowance for doubtful accounts, as of December 31, 2019 and 2018.

Property, Plant and Equipment. Property, plant and equipment are stated at the lower of historical cost less accumulated depreciation subject to the results of impairment testing. We capitalize all construction-related direct labor and material costs, as well as indirect construction costs. Indirect construction costs include general engineering, taxes and the cost of funds used during construction. Costs, including complete asset replacements and enhancements or upgrades that increase the original efficiency, productivity or capacity of property, plant and equipment, are also capitalized. The costs of repairs, minor replacements and other projects, which do not increase the original efficiency, productivity or capacity of property, plant and equipment, are expensed as incurred.

Capitalization of Interest. Interest charges from borrowings are capitalized on material projects using the weighted average cost of outstanding borrowings until the project is substantially complete and ready for its intended use. Capitalized interest is depreciated over the useful lives of the assets in the same manner as the depreciation of the underlying assets.

Impairment of Long‑Lived Assets. We review long-lived assets for impairment whenever events or changes in business circumstances indicate the net book values of the assets may not be recoverable. Impairment is indicated when the undiscounted cash flows estimated to be generated by those assets are less than the assets’ net book value. Undiscounted cash flows are based on identifiable cash flows that are largely independent of the cash flows of other assets and liabilities. If impairment occurs, a loss is recognized for the difference between the fair value and net book value. Such fair value is generally determined by discounting anticipated future net cash flows, an income valuation approach, or by a market-based valuation approach, which are Level 3 fair value measurements. Factors that indicate potential impairment include a significant decrease in the market value of the asset, operating or cash flow losses associated with the use of the asset, and a significant change in the asset’s physical condition or use. No impairments of long‑lived assets were recorded during the years ended December 31, 2019, 2018 and 2017.

Leases. We determine if an arrangement is a lease at inception. Operating lease right-of-use assets represent our right to use an underlying asset for the lease term and lease liabilities represent our obligation to make lease payments arising from the lease. Operating lease right-of-use assets and liabilities are recognized at commencement date based on the present value of lease payments over the lease term. As most of our leases do not provide an implicit rate, we use our incremental borrowing rate based on the information available at commencement date in determining the present value of lease payments. The operating lease right-of-use asset includes any initial direct costs and excludes lease incentives received. The lease term used in measurement of our lease obligations may include periods covered by an option to extend or terminate the lease when it is reasonably certain that we will exercise that option. Lease expense for lease payments is recognized on a straight-line basis over the lease term. The Company has elected not to recognize lease assets and lease liabilities for leases with a term of 12 months or less for all classes of underlying assets. Our lease agreements may include lease and non-lease components, which are generally accounted for separately.

As of December 31, 2019, we had $0.8 million of operating lease right-of-use assets included within other noncurrent assets on our consolidated balance sheet. Operating lease liabilities were $0.2 million and $0.6 million included within other current liabilities and other noncurrent liabilities, respectively, on our consolidated balance sheet. As of December 31, 2019, we did not have any finance leases.

Equity Investments. We account for our investment in LM4 under the equity method of accounting, as we do not control, but have a significant influence over, its operations. As of December 31, 2019, we contributed $100.3 million of cash for our gross interest in LM4 and capitalized $4.1 million of interest expense associated with our investment in LM4. Difference in the basis of the investment and the underlying net asset value of the equity investee is amortized into net income over the remaining useful lives of the underlying assets. Earnings from equity investments represent our proportionate share of net income generated by the equity investee. We classify distributions received from equity method investees on the basis of the nature of the activity of the investee that generated the distribution as either a return on investment classified as cash inflows from operating activities or a return of investment classified as cash inflows from investing activities when such information is available to us.

Deferred Financing Costs. We capitalize debt issuance costs and fees incurred related to the procurement of our credit facilities. We amortize such costs as additional interest expense over the life of the credit agreement using the straight-line method, which approximates the effective interest method. Unamortized deferred financing costs related to our revolving credit facility are presented in Other noncurrent assets (2019: $12.2 million, 2018: $6.9 million) and unamortized deferred financing costs related to our fixed-rate senior notes and our term loan are presented as a direct reduction to the Long-term debt (2019: $28.5 million, 2018: $16.5 million) in the accompanying consolidated balance sheets.

Asset Retirement Obligations. We record legal obligations to remove and dismantle long-lived assets. We recognize a liability for the fair value of legally required asset retirement obligations associated with long-lived assets in the period in which the retirement obligations are incurred if the liability can be reasonably estimated. The associated asset retirement costs are capitalized as part of the carrying amount of the long-lived assets. Accretion expense is included in Depreciation expense in the consolidated statement of operations. We have not incurred significant asset retirement obligations.

Net Parent Investment. Net parent investment represents HIP’s historical activity as well as Hess’ historical investment in Hess Water Services prior to its acquisition by HIP, the accumulated net operating results through the date when we obtained control of HIP, and the net effect of transactions between HIP and the Sponsors, and between Hess and Hess Water Services. Retrospectively adjusted financial information from prior to the acquisition of HIP is included in Net parent investment.

Revenue Recognition—Contracts with Customers. We earn substantially all of our revenues by charging fees for gathering, compressing and processing natural gas and fractionating NGLs; gathering, terminaling, loading and transporting crude oil and NGLs, gathering and disposing produced water, and storing and terminaling propane. We do not own or take title to the volumes that we handle. Effective January 1, 2014, we entered into i) gas gathering, ii) crude oil gathering, iii) gas processing and fractionation, iv) storage services, and v) terminal and export services fee‑based commercial agreements with certain subsidiaries of Hess, and effective January 1, 2019, we entered into water gathering and disposal services fee-based agreements with certain subsidiaries of Hess. In 2018 and partial year 2017, Hess Water Services had documented intercompany arrangements with certain subsidiaries of Hess pursuant to which it provided produced water gathering and disposal services and charged agreed-upon fees per barrel for the services performed.

Our responsibilities to provide each of the above services for each year under each of the commercial agreements are considered separate, distinct performance obligations. We recognize revenues for each performance obligation under our commercial agreements over‑time as services are rendered using the output method, measured using the amount of volumes serviced during the period. The minimum volume commitments are subject to fluctuation based on nominations covering substantially all of Hess’ production and projected third-party volumes that will be purchased in the Bakken. As the minimum volume commitments are subject to fluctuation, and these commercial agreements contain fee inflation escalators and fee recalculation mechanisms, substantially all of the transaction price, as this term is defined in ASC 606, is variable at inception of each of the commercial agreements. As the variability is resolved prior to the recognition of revenue, we do not apply a constraint to the transaction price at the inception of the commercial agreements. We elected the practical expedient to recognize revenue in the amount to which we have a right to invoice as permitted under ASC 606. Due to this election and as the transaction price allocated to our unsatisfied performance obligations is entirely variable, we have elected the exemption provided by ASC 606 from the disclosure of revenue recognizable in future periods as our unsatisfied performance obligations are fulfilled. There are no significant financing components in any of our commercial agreements.

The minimum volumes that Hess provides to our assets under our commercial agreements include dedicated production covering substantially all of Hess’ existing and future owned or controlled production in the Bakken and projected third-party volumes owned or controlled by Hess through dedicated third-party contracts. If Hess delivers volumes less than the applicable minimum volume commitments under our commercial agreements during any quarter, Hess is obligated to pay us a shortfall fee equal to the volume deficiency multiplied by the related gathering, processing and/or terminaling fee, as applicable. Our responsibility to stand-ready to service a minimum volume over each quarterly commitment period represents a separate, distinct performance obligation. Currently, and for the remainder of the Initial Term of each commercial agreement as described in Note 4, volume deficiencies are measured quarterly and recognized as revenue in the same period, as any associated shortfall payments are not subject to future reduction or offset. During the Secondary Term of each commercial agreement as described in Note 4, Hess will be entitled to receive a credit, calculated in barrels or Mcf, as applicable, with respect to the amount of any shortfall fee paid by Hess, which will initially be reported in deferred revenue. Hess may apply such credit against the fees payable for any volumes delivered to us under the applicable agreement in excess of Hess’ nominated volumes up to four quarters after such credit is earned. Unused credits by Hess will be recognized as revenue when they expire after four quarters. However, Hess will not be entitled to receive any such credit with respect to crude oil terminaling services under our terminal and export services agreement

Our revenues also included pass‑through third‑party rail transportation costs, third-party produced water trucking and disposal costs, and electricity fees for which we recognize revenues in an amount equal to the costs.

Depreciation Expense. We calculate depreciation using the straight-line method based on the estimated useful lives after considering salvage values of our assets. Depreciation lives range from 12 to 35 years. However, factors such as maintenance levels, economic conditions impacting the demand for these assets, and regulatory or environmental requirements could cause us to change our estimates, thus impacting the future calculation of depreciation.

Equity‑Based Compensation. Equity‑based compensation issued to the officers, directors and employees of our general partner is recorded at grant‑date fair value. Expense is recognized on a straight‑line basis over the vesting period of the award and is included in General and administrative expenses in the accompanying consolidated statements of operations. Forfeitures are recognized as they occur.

Income Taxes. Deferred income taxes are determined using the liability method and reflect temporary differences between the financial statement carrying amount and income tax basis of assets and liabilities recorded using the statutory income tax rate. Regular assessments are made of the likelihood of those deferred tax assets being realized. If it is more likely than not that some or all of the deferred tax assets will not be realized, a valuation allowance is recorded to reduce the deferred tax assets to the amount expected to be realized.

Prior to the Restructuring on December 16, 2019, we were not a separate taxable entity for U.S. federal and state income tax purposes; therefore, we did not provide for income tax benefit or expense. Each partner was subject to income taxes on its share of the Partnership’s earnings.

On March 1, 2019, HIP acquired Hess Water Services (see Note 3, Acquisitions). For the periods prior to March 1, 2019, Hess Water Services was included in the consolidated income tax returns of Hess. The provision for Hess Water Services’ income taxes and income tax assets and liabilities were determined as if it were a standalone taxpayer for all periods presented. For the period from March 1, 2019 through the Restructuring date of December 16, 2019, Hess Water Services was not taxable itself and was not part of a separate taxable entity; therefore, no income tax provision was recognized.

Net Income Per Limited Partner Unit. Prior to the Restructuring, we identified the general partner interest and IDRs as participating securities and computed income per unit using the two‑class method under which net income per unit was calculated for common units and participating securities considering both distributions declared and participation rights in undistributed earnings as if all such earnings had been distributed during that period. Net income per unit applicable to limited partners, including subordinated unitholders, was computed by dividing limited partners' interest in net income, after deducting the general partner's 2% interest and IDRs, by the weighted‑average number of outstanding common and subordinated units.

Environmental and Legal Contingencies. We accrue and expense environmental costs on an undiscounted basis to remediate existing conditions related to past operations when the future costs are probable and reasonably estimable.

In the ordinary course of business, the Company is from time to time party to various judicial and administrative proceedings. We regularly assess the need for accounting recognition or disclosure of these contingencies. In the case of a known contingency, we accrue a liability when the loss is probable and the amount is reasonably estimable. If a range of amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued.

Fair Value Measurements. We measure assets and liabilities requiring fair value presentation using an exit price (i.e., the price that would be received to sell an asset or paid to transfer a liability) and disclose such amounts according to the level of valuation inputs under the following hierarchy:

Level 2: Inputs other than quoted prices that are directly or indirectly observable.

Level 3: Unobservable inputs that are significant to the fair value of assets or liabilities.

The classification of an asset or liability within the fair value measurement hierarchy is based on the lowest level of input significant to its fair value.

There were no nonrecurring fair value measurements during the years ended December 31, 2019 and 2018. We had other short‑term financial instruments, primarily cash and cash equivalents, accounts receivable and accounts payable, for which the carrying value approximated their fair value as of December 31, 2019 and 2018.

Derivatives. We may utilize derivative instruments for financial risk management activities. In these activities, we may use futures, forwards, options and swaps, individually or in combination, to mitigate our exposure to fluctuations in interest rates.

All derivative instruments are recorded at fair value in our consolidated balance sheet. Our policy for recognizing the changes in fair value of derivatives varies based on the designation of the derivative. The changes in fair value of derivatives that are not designated as hedges are recognized in earnings. Derivatives may be designated as hedges of expected future cash flows or forecasted transactions (cash flow hedges). Changes in fair value of derivatives that are designated as cash flow hedges are recorded as a component of other comprehensive income (loss). Amounts included in Accumulated other comprehensive income (loss) for cash flow hedges are reclassified into earnings in the same period that the hedged item is recognized in earnings.

In June 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standard Update (“ASU”) 2016-13, Financial Instruments – Credit Losses. This ASU makes changes to the impairment model for trade receivables, net investments in leases, debt securities, loans and certain other instruments. The standard requires the use of a forward-looking "expected loss" model compared with the current "incurred loss" model. We will adopt this ASU in the first quarter of 2020 when the standard becomes effective and it is not expected to have a material impact on our consolidated financial statements.

In February 2016, the FASB issued ASU 2016-02, Leases, as a new Accounting Standards Codification (“ASC”) Topic, ASC 842. We adopted ASC 842 on January 1, 2019 using the modified retrospective method. Accordingly, comparative financial statements for periods prior to the adoption date of ASC 842 were not affected. In addition, we have elected to apply the ‘package’ of practical expedients allowing us to avoid reassessing whether existing contracts are (or contain) leases, whether the lease classification for existing leases would differ under ASC 842, and whether initial direct costs incurred for existing leases are capitalizable under ASC 842. Finally, we have elected to apply the practical expedient allowing us to avoid reassessing land easements that were not previously accounted for as leases under ASC 840. We have not elected the ‘hindsight’ practical expedient when determining lease term. As a result, no cumulative effect adjustment to Partners’ capital was recognized. The adoption of ASC 842 did not have a material impact on our consolidated financial statements.

On March 1, 2019, HIP acquired 100% of the membership interest in Hess Water Services that owns Hess’ existing Bakken water services business for $225.0 million in cash. HIP funded the purchase price through a combination of cash on hand and borrowings under its revolving credit facility. In connection with the Hess Water Services acquisition, HIP acquired the following:

The transaction was accounted for as an acquisition of a business between entities under common control, and therefore, the related acquired assets and liabilities were transferred at Hess’ historical carrying value. We recognized $156.1 million of consideration in excess of the book value of net assets acquired as a capital distribution to Hess, which is reflected within Net parent investment in the accompanying consolidated statements of changes in partners’ capital.

Hess Water Services is included in our gathering segment (see Note 13, Segments).

On March 22, 2019, we acquired 100% of the membership interest in Tioga Midstream Partners LLC from Summit Midstream Partners, LP that owns oil, gas, and water gathering assets (the “Tioga System Acquisition”). The transaction was accounted for as an asset acquisition. The Tioga System, located in Williams County in western North Dakota, is complementary to our infrastructure, and is currently delivering volumes into our gathering system.

We paid $89.2 million in cash at closing, net of cash acquired, and recognized a contingent liability for additional potential payments of $10 million in future periods subject to certain performance metrics. We funded the purchase price through a combination of cash on hand and borrowings under our revolving credit facility.

The acquired Tioga System is included in our gathering segment (see Note 13, Segments).

On December 16, 2019, the Company and the Partnership completed the Restructuring, pursuant to which the Partnership acquired all of the partnership interests in HIP from Hess and GIP, including HIP’s retained 80% economic interest in the Joint Interest Assets, 100% interest in Hess Water Services and the outstanding economic general partner and incentive distribution rights in the Partnership. The Partnership’s organizational structure converted from a master limited partnership into an “Up-C” structure in which the Partnership’s public unitholders received newly issued Class A Shares in Hess Midstream LP in a one-for-one exchange. The Partnership changed its name to “Hess Midstream Operations LP” and became a consolidated subsidiary of the Company. As a result of the Restructuring, the Sponsors held 898,000 Class A Shares in the Company, 266,416,928 Class B Units representing noncontrolling limited partner interests in the Partnership and received cash consideration of $601.8 million. Class B Units of the Partnership together with the same number of Class B Shares of the Company are convertible to Class A Shares of the Company on a one-for-one basis (see Note 8, Partners’ Capital and Distributions).

Our consolidated financial statements include $26.2 million of costs associated with the Restructuring. These costs were expensed as general and administrative expenses.

The acquisition of HIP was accounted for as an acquisition of a business under common control. Accordingly, consolidated financial statements prior to the acquisition date of December 16, 2019 were retrospectively recast to include the financial results of HIP. The Partnership previously consolidated 100% of the Joint Interest Assets and reflected a noncontrolling interest of 80% in such assets representing HIP’s historical ownership of the Joint Interest Assets; therefore, the recast of the previously reported financial information did not result in any changes in segment information, other than inclusion of Hess Water Services in the gathering segment.

The following tables present our financial position as of December 31, 2018 and the results of operations and cash flows for the years ended December 31, 2018 and 2017, giving effect to the acquisition of HIP. The results of HIP prior to the effective date of the acquisition are included in “Acquisition of HIP” and the consolidated results are included in “Consolidated Results” within the tables below. The Partnership, as previously reported, did not have any items of other comprehensive income during the periods presented.

	December 31, 2018
	Partnership as Previously Reported		Acquisition of HIP			Consolidated Results
(in millions)
Assets
Cash and cash equivalents	$	20.3	$	89.0		$	109.3
Accounts receivable—affiliate:
From contracts with customers		62.2		5.1			67.3
Other receivables		0.8		(0.3	)		0.5
Other current assets		2.8		0.5			3.3
Total current assets		86.1		94.3			180.4
Equity Investments		67.3		-			67.3
Property, plant and equipment, net		2,664.1		71.2			2,735.3
Long-term receivable—affiliate		-		1.3			1.3
Other noncurrent assets		2.2		4.7			6.9
Total assets	$	2,819.7	$	171.5		$	2,991.2
Liabilities
Accounts payable—trade	$	15.3	$	3.3		$	18.6
Accounts payable—affiliate		15.8		-			15.8
Accrued liabilities		64.5		21.1			85.6
Current maturities of long-term debt		-		11.3			11.3
Other current liabilities		6.8		-			6.8
Total current liabilities		102.4		35.7			138.1
Long-term debt		-		969.8			969.8
Other noncurrent liabilities		6.4		0.8			7.2
Total liabilities		108.8		1,006.3			1,115.1
Common unitholders—public (17,014,377 units issued and outstanding)		357.1		-			357.1
Common unitholders—affiliate (10,282,654 units issued and outstanding)		39.5		-			39.5
Subordinated unitholders—affiliate (27,279,654 units issued and outstanding)		105.3		-			105.3
General partner		14.9		-			14.9
Total Hess Midstream Partners LP partners' capital		516.8		-			516.8
Noncontrolling interest		2,194.1		-			2,194.1
Accumulated other comprehensive income		-		1.2			1.2
Net parent investment		-		(836.0	)		(836.0	)
Total partners' capital		2,710.9		(834.8	)		1,876.1
Total liabilities and partners' capital	$	2,819.7	$	171.5		$	2,991.2

	Year Ended December 31, 2018
	Partnership as Previously Reported		Acquisition of HIP			Consolidated Results
(in millions)
Revenues and other income
Affiliate services	$	661.7	$	50.3		$	712.0
Other income		0.7		-			0.7
Total revenues and other income		662.4		50.3			712.7
Costs and expenses
Operating and maintenance expenses (exclusive of depreciation shown separately below)		154.3		39.2			193.5
Depreciation expense		123.0		3.9			126.9
General and administrative expenses		11.5		2.6			14.1
Total costs and expenses		288.8		45.7			334.5
Income from operations		373.6		4.6			378.2
Interest expense, net		1.3		52.0			53.3
Gain on sale of property, plant and equipment		-		0.6			0.6
Net income		372.3		(46.8	)		325.5
Less: Net income (loss) attributable to net parent investment		-		(46.8	)		(46.8	)
Less: Net income attributable to noncontrolling interest		301.5		-			301.5
Net income attributable to Hess Midstream Partners LP		70.8		-			70.8
Less: General partner's interest in net income attributable to Hess Midstream Partners LP		1.7		-			1.7
Limited partners' interest in net income attributable to Hess Midstream Partners LP	$	69.1		-		$	69.1
Net income attributable to Hess Midstream Partners LP per limited partner unit (basic and diluted):
Common	$	1.27				$	1.27
Subordinated	$	1.27				$	1.27
Weighted average limited partner units outstanding:
Basic:
Common		27.3					27.3
Subordinated		27.3					27.3
Diluted:
Common		27.4					27.4
Subordinated		27.3					27.3

	Year Ended December 31, 2017
	Partnership as Previously Reported		Acquisition of HIP			Consolidated Results
(in millions)
Revenues and other income
Affiliate services	$	565.6	$	13.9		$	579.5
Other income		0.2		(0.2	)		-
Total revenues and other income		565.8		13.7			579.5
Costs and expenses
Operating and maintenance expenses (exclusive of depreciation shown separately below)		158.4		27.6			186.0
Depreciation expense		113.1		3.4			116.5
General and administrative expenses		8.1		5.8			13.9
Total costs and expenses		279.6		36.8			316.4
Income from operations		286.2		(23.1	)		263.1
Interest expense, net		1.4		24.4			25.8
Gain on sale of property, plant and equipment		-		4.7			4.7
Net income		284.8		(42.8	)		242.0
Less: Net income (loss) attributable to net parent investment		68.2		(42.8	)		25.4
Less: Net income attributable to noncontrolling interest		175.4		-			175.4
Net income attributable to Hess Midstream Partners LP		41.2		-			41.2
Less: General partner's interest in net income attributable to Hess Midstream Partners LP		0.8		-			0.8
Limited partners' interest in net income attributable to Hess Midstream Partners LP	$	40.4	$	-		$	40.4
Net income attributable to Hess Midstream Partners LP per limited partner unit (basic and diluted):
Common	$	0.75				$	0.75
Subordinated	$	0.75				$	0.75
Weighted average limited partner units outstanding (basic and diluted):
Common		26.9					26.9
Subordinated		26.9					26.9

	Year Ended December 31, 2018
	Partnership as Previously Reported			Acquisition of HIP			Consolidated Results
(in millions)
Cash flows from operating activities
Net income	$	372.3		$	(46.8	)	$	325.5
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation expense		123.0			3.9			126.9
(Gain) loss on sale of property, plant and equipment		-			(0.6	)		(0.6	)
(Gain) loss on interest rate swaps		-			(0.4	)		(0.4	)
Amortization of deferred financing costs		1.0			4.0			5.0
Unit-based compensation		0.9			-			0.9
Changes in assets and liabilities:
Accounts receivable—affiliate		(3.2	)		(3.1	)		(6.3	)
Other current and noncurrent assets		1.6			0.3			1.9
Accounts payable—trade		3.1			0.9			4.0
Accounts payable—affiliate		(6.7	)		0.3			(6.4	)
Accrued liabilities		2.7			14.6			17.3
Other current and noncurrent liabilities		(1.1	)		0.2			(0.9	)
Net cash provided by (used in) operating activities		493.6			(26.7	)		466.9
Cash flows from investing activities
Payments for equity investments		(67.3	)		-			(67.3	)
Proceeds from sale of property, plant and equipment		-			1.6			1.6
Additions to property, plant and equipment		(235.6	)		(6.3	)		(241.9	)
Net cash provided by (used in) investing activities		(302.9	)		(4.7	)		(307.6	)
Cash flows from financing activities
Repayments of bank borrowings - term loan		-			(2.5	)		(2.5	)
Financing costs		-			(1.0	)		(1.0	)
Distributions to Hess and GIP		-			(322.0	)		(322.0	)
Distributions to noncontrolling interest		(199.2	)		199.2			-
Contributions from noncontrolling interests		57.3			(57.3	)		-
Distributions to HESM limited partners		(74.1	)		-			(74.1	)
Distributions to HESM general partner		(1.6	)		1.6			-
Other contributions (distributions)		-			(6.1	)		(6.1	)
Net cash provided by (used in) financing activities		(217.6	)		(188.1	)		(405.7	)
Net increase (decrease) in cash and cash equivalents		(26.9	)		(219.5	)		(246.4	)
Cash and cash equivalents at beginning of period		47.2			308.5			355.7
Cash and cash equivalents at end of period	$	20.3		$	89.0		$	109.3

	Year Ended December 31, 2017
	Partnership as Previously Reported			Acquisition of HIP			Consolidated Results
(in millions)
Cash flows from operating activities
Net income	$	284.8		$	(42.8	)	$	242.0
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation expense		113.1			3.4			116.5
(Gain) loss on sale of property, plant and equipment		-			(4.7	)		(4.7	)
(Gain) loss on interest rate swaps		-			(1.7	)		(1.7	)
Amortization of deferred financing costs		0.6			3.2			3.8
Unit-based compensation		0.2			-			0.2
Changes in assets and liabilities:
Accounts receivable—affiliate		(15.2	)		(1.7	)		(16.9	)
Other current and noncurrent assets		(1.7	)		2.9			1.2
Accounts payable—trade		(16.6	)		(0.1	)		(16.7	)
Accounts payable—affiliate		34.4			(26.9	)		7.5
Accrued liabilities		(1.9	)		5.1			3.2
Other current and noncurrent liabilities		2.2			(0.1	)		2.1
Net cash provided by (used in) operating activities		399.9			(63.4	)		336.5
Cash flows from investing activities
Proceeds from sale of property, plant and equipment		-			12.8			12.8
Additions to property, plant and equipment		(136.4	)		(7.8	)		(144.2	)
Net cash provided by (used in) investing activities		(136.4	)		5.0			(131.4	)
Cash flows from financing activities
Cash distributions to parent prior to the IPO on April 10, 2017		(95.3	)		95.3			-
Cash contributions from parent prior to the IPO on April 10, 2017		67.1			(67.1	)		-
Proceeds from (repayments of) bank borrowings - revolver		-			(153.0	)		(153.0	)
Repayments of bank borrowings - term loan		-			(385.0	)		(385.0	)
Proceeds from issuance of fixed-rate senior notes		-			800.0			800.0
Financing costs		(3.9	)		(19.0	)		(22.9	)
IPO proceeds, net of underwriters' discounts		365.5			-			365.5
Distribution of IPO proceeds to Hess and GIP		(349.5	)		-			(349.5	)
Cash offering costs		(2.1	)		-			(2.1	)
Distributions to Hess and GIP		-			(100.0	)		(100.0	)
Distributions to HESM limited partners		(31.7	)		-			(31.7	)
Distributions to HESM general partner		(0.6	)		0.6			-
Distributions to noncontrolling interest		(244.6	)		244.6			-
Contributions from noncontrolling interest		78.5			(78.5	)		-
Other contributions (distributions)		-			27.6			27.6
Net cash provided by (used in) financing activities		(216.6	)		365.5			148.9
Net increase (decrease) in cash and cash equivalents		46.9			307.1			354.0
Cash and cash equivalents at beginning of period		0.3			1.4			1.7
Cash and cash equivalents at end of period	$	47.2		$	308.5		$	355.7

We are part of the consolidated operations of Hess, and substantially all of our revenues as shown on the accompanying consolidated statements of operations for the years ended December 31, 2019, 2018 and 2017 were derived from transactions with Hess and its affiliates, although we plan to provide our services to third parties in the future. Hess also provides substantial operational and administrative services to us in support of our assets and operations.

Effective January 1, 2014, we entered into i) gas gathering, ii) crude oil gathering, iii) gas processing and fractionation, iv) storage services, and v) terminal and export services fee‑based commercial agreements with certain subsidiaries of Hess. Effective January 1, 2019, in connection with the Hess Water Services Acquisition, we entered into long-term fee-based water services agreements with certain subsidiaries of Hess. In addition, in 2018 and a portion of 2017, Hess Water Services had documented intercompany arrangements with certain subsidiaries of Hess pursuant to which it provided produced water gathering and disposal services and charged agreed-upon fees per barrel for the services performed.

Except for the water services agreements and except for a certain gathering sub-system as described below, each of our commercial agreements with Hess retains its initial 10‑year term (“Initial Term”) and we have the unilateral right to extend each commercial agreement for one additional 10‑year term (“Secondary Term”). Initial Term for the water services agreements is 14 years and the Secondary Term is 10 years. The amended and restated gas gathering agreement also extends the Initial Term of the gathering agreement with respect to a certain gathering sub-system by 5 years to provide for a 15-year Initial Term and decreases the Secondary Term for that gathering sub-system by 5 years to provide for a 5-year Secondary Term. During the Secondary Term of the agreements, the fee recalculation model will be replaced by an inflation-based fee structure.

For the years ended December 31, 2019, 2018 and 2017, approximately 100% of our revenues were attributable to our fee‑based commercial agreements with Hess, including revenues from third‑party volumes contracted with Hess and delivered to us under these agreements. Together with Hess, we are pursuing strategic relationships with third-party producers and other midstream companies with operations in the Bakken in order to maximize our utilization rates.

During the year ended December 31, 2019, we earned $8.3 million of minimum volume shortfall fee payments (2018: $47.5 million, 2017: $61.6 million). In addition, during the year ended December 31, 2019, we recognized, as part of the affiliate revenues, $40.2 million of reimbursements from Hess related to third‑party rail transportation costs (2018: $16.8 million, 2017: $17.0 million). Furthermore, during the year ended December 31, 2019, we recognized, as part of affiliate revenues, $57.7 million of reimbursements from Hess related third-party produced water trucking and disposal costs (2018: $36.5 million, 2017: $5.1 million). Finally, during the year ended December 31, 2019, we recognized, as part of affiliate revenues, $32.2 million of reimbursements from Hess related to electricity fees (2018: $27.2 million, 2017: $24.9 million). The related third-party rail transportation costs, produced water trucking and disposal costs and electricity fees were included in Operating and maintenance expenses in the accompanying consolidated statements of operations.

We entered into an omnibus agreement with Hess under which we pay Hess on a monthly basis an amount equal to the total allocable costs of Hess’ employees and contractors, subcontractors or other outside personnel engaged by Hess and its subsidiaries to the extent such employees and outside personnel perform operational and administrative services for us in support of our assets, plus a specified percentage markup of such amount depending on the type of service provided, as well as an allocable share of direct costs of providing these services.

We also entered into an employee secondment agreement with Hess under which certain employees of Hess are seconded to our general partner to provide services with respect to our assets and operations, including executive oversight, business and corporate development, unitholder and investor relations, communications and public relations, routine and emergency maintenance and repair services, routine operational services, routine administrative services, construction services, and such other operational, commercial and business services that are necessary to develop and execute the Company’s business strategy. On a monthly basis, we pay a secondment fee to Hess that is intended to cover and reimburse Hess for the total costs actually incurred by Hess and its affiliates in connection with employing the seconded employees to the extent such total costs are attributable to the provision of services with respect to the Company’s assets and operations.

For the years ended December 31, 2019, 2018 and 2017, we had the following charges from Hess. The classification of these charges between operating and maintenance expenses and general and administrative expenses is based on the fundamental nature of the services being performed for our operations.

Separately from our commercial agreements with Hess, effective January 24, 2018, we entered into a gas processing agreement with LM4 under which we deliver natural gas to LM4, and LM4 processes and redelivers certain volumes of residue gas and NGLs resulting from such processing services. The agreement has a 16-year initial term, after which it is automatically renewed for subsequent one-year terms unless terminated by either party. Under this agreement, we pay a processing fee per Mcf of natural gas and reimburse LM4 for our proportionate share of electricity costs. We are entitled to 50% of the available processing capacity of the LM4 gas processing plant. Should Targa not use all of the remaining processing capacity at the plant on any day, such unutilized portion of the available capacity will be available for our use. Regardless of the actual portion of the plant available capacity utilized by each joint venture member during a given period, under the LM4 amended and restated limited liability company agreement, profits and losses of the LM4 joint venture are allocated 50/50 between Targa and us. LM4 was placed in service in the third quarter of 2019.

During the year ended December 31, 2019, we incurred $6.3 million of expenses under the LM4 gas processing agreement, which are included in Operating and maintenance expenses in the accompanying consolidated statements of operations. In addition, during the year ended December 31, 2019, we recognized $3.4 million of earnings from equity investments, as presented in our accompanying consolidated statements of operations.

	Estimated useful lives	December 31, 2019			December 31, 2018
(in millions, except for number of years)
Gathering assets
Pipelines	22 years	$	1,352.7		$	1,098.1
Compressors, pumping stations and terminals	22 to 25 years		725.9			558.9
Gas plant assets
Pipelines, pipes and valves	22 to 25 years		460.0			460.0
Equipment	12 to 30 years		428.2			428.2
Buildings	35 years		182.3			182.3
Processing and fractionation facilities	25 years		188.6			185.5
Logistics facilities and railcars	20 to 25 years		385.5			385.8
Storage facilities	20 to 25 years		19.5			19.5
Other	20 to 25 years		13.0			11.4
Construction-in-progress	N/A		149.3			158.5
Total property, plant and equipment, at cost			3,905.0			3,488.2
Accumulated depreciation			(894.9	)		(752.9	)
Property, plant and equipment, net		$	3,010.1		$	2,735.3

As of December 31, 2019, the maturity profile of total debt, excluding deferred financing costs and discounts, is as follows:

In November 2017, HIP issued $800.0 million of 5.625% fixed‑rate senior notes due 2026 to qualified institutional investors. In December 2019, in connection with the Restructuring, the Partnership, Hess Midstream Operations LP, a consolidated subsidiary of the Company, assumed the $800.0 million of outstanding HIP senior notes in a par-for-par exchange for newly issued 5.625% senior notes due 2026 of the Partnership and paid approximately $2.0 million of exchange consent fees. The notes are guaranteed by certain subsidiaries of the Partnership. Interest is payable semi‑annually on February 15 and August 15.

In December 2019, in connection with the Restructuring, both HIP and the Partnership retired their existing senior secured revolving credit facilities, HIP retired its senior secured Term Loan A facility and the Partnership entered into new senior secured credit facilities (the “Credit Facilities”) consisting of a $1,000.0 million 5-year revolving credit facility and a fully drawn $400.0 million 5-year Term Loan A facility, receiving cash of $210.0 million at closing. Facility fees accrue on the total capacity of the revolving credit facility. Borrowings under the 5-year revolving credit facility will generally bear interest at LIBOR plus the applicable margin ranging from 1.275% to 2.000%, while the applicable margin for the 5-year syndicated revolving credit facility ranges from 1.275% to 2.000%. Pricing levels for the facility fee and interest-rate margins are based on the Partnership’s ratio of total debt to EBITDA (as defined in the Credit Facilities). If the Partnership obtains an investment grade credit rating, the pricing levels will be based on the Partnership’s credit ratings in effect from time to time. At December 31, 2019, borrowings of $32 million were drawn under the Partnership’s revolving credit facility, and borrowings of $400 million, excluding deferred issuance costs, were drawn under the Partnership’s Term Loan A facility.

At December 31, 2018, HIP had $800 million of senior secured syndicated credit facilities maturing in 2022, consisting of a $600 million 5-year revolving credit facility and a drawn $200 million 5-year Term Loan A facility. In addition, the Partnership had a $300.0 million 4-year senior secured revolving credit facility maturing in 2021. In connection with the Restructuring, the Partnership entered into new Credit Facilities, as described above. The proceeds from the new Credit Facilities were used to finance the acquisition of HIP, including to repay borrowings under HIP’s credit facilities, and pay related fees and expenses.

At December 31, 2019, our total long-term debt had a carrying value of $1,753.5 million and had a fair value of approximately $1,820.1 million, based on Level 2 inputs in the fair value measurement hierarchy. The carrying value of the amounts under the Term Loan A facility and revolving credit facility at December 31, 2019, approximated their fair value. Any changes in interest rates do not impact cash outflows associated with fixed rate interest payments or settlement of debt principal, unless a debt instrument is repurchased prior to maturity.

The total amount of interest paid on all credit facilities, including facility fees, during the years ended December 31, 2019, 2018 and 2017 was $60.8 million, $42.7 million and $18.8 million, respectively.

Prior to the Restructuring, our partners’ capital included common and subordinated units representing limited partner interests in the Partnership. Pursuant to the Restructuring, 17,062,655 public common units of the Partnership outstanding as of December 16, 2019, were converted into Class A Shares of the Company (economic and voting) on a one-for-one basis, the Sponsors received 898,000 Class A Shares of the Company, 266,416,928 Class B Units representing noncontrolling limited partner interests in the Partnership and a cash consideration of $601.8 million. In addition, our general partner purchased 266,416,928 Class B Shares of the Company (non-economic voting only) for a cash amount equal to $0.0001 per Class B Shares. Class B Units of the Partnership together with the equal number of Class B Shares of the Company are convertible to Class A Shares of the Company on a one-for-one basis.

Our partnership agreement requires that, within 45 days after the end of each quarter, we distribute all of our available cash to shareholders/unitholders of record on the applicable record date. The following table details the distributions declared and/or paid for the periods presented:

The following table details distributions paid by HIP to Hess and GIP prior to the Restructuring (in millions):

In the second quarter of 2017, we also made a special distribution of $349.5 million, distributed 50/50 to Hess and GIP from the proceeds of the Partnership’s initial public offering.

In 2017, the Partnership adopted the Hess Midstream Partners LP 2017 Long‑Term Incentive Plan. Pursuant to the Restructuring, the Company assumed the Hess Midstream Partners LP 2017 Long-Term Incentive Plan and all obligations with respect to outstanding awards thereunder. The Company amended and restated the Hess Midstream Partners LP 2017 Long-Term Incentive Plan to, among other things, change the plan’s name to Hess Midstream LP 2017 Long-Term Incentive Plan (the “LTIP”) and to reflect the Company’s assumption of the plan. Awards under the LTIP are available for officers, directors and employees of our general partner or its affiliates, and any individuals who perform services for the Company. The LTIP provides the Company with the flexibility to grant restricted share awards, restricted shares, phantom shares, share options, share appreciation rights, distribution equivalent rights, profits interest shares and other equity‑based awards. The LTIP limits the number of shares that may be delivered pursuant to vested awards to 3,000,000 Class A Shares.

Under the LTIP, we granted restricted share awards with distribution equivalent rights to certain officers, employees and directors. These restricted shares and distribution equivalent rights vest ratably over a three‑year period for officers and employees, and vest after one year for directors. Each restricted share represents the right to receive one Class A Share upon vesting (or an equivalent amount of cash). Cash distributions on the restricted shares accumulate and are paid upon vesting. Fair value of restricted shares is based on the fair value of the Company’s Class A Shares on the grant date.

Equity‑based award activity for the year ended December 31, 2019 was as follows:

During the year ended December 31, 2019, we recognized compensation expense related to the outstanding awards of $1.5 million (2018: $0.9 million, 2017: 0.2 million). As of December 31, 2019, $1.7 million of compensation cost related to our unvested restricted shares awarded under the LTIP remains to be recognized over an expected weighted‑average period of 1.8 years.

Earnings per limited partner unit prior to the Restructuring on December 16, 2019, were computed by dividing the respective limited partners’ interest in net income attributable to Hess Midstream Partners LP by the weighted average number of common and subordinated units outstanding. Because we had more than one class of participating securities, we used the two‑class method when calculating earnings per limited partner unit. The classes of participating securities included common units, subordinated units, general partner interest and incentive distribution rights. Our net income includes earnings related to businesses acquired through transactions between entities under common control for periods prior to their acquisition by us. We have allocated these pre-acquisition earnings to Net income attributable to net parent investment.

Subsequent to the Restructuring, we calculate earnings per Class A Share and we do not have any other participating securities. Class B Units of the Partnership together with the equal number of Class B Shares of the Company are convertible to Class A Shares of the Company on a one-for-one basis. In addition, our restricted equity-based awards may have a dilutive effect on our earnings per share. Diluted earnings per Class A Share are calculated using the “treasury stock method” or “if-converted method”, whichever is more dilutive.

		Year Ended December 31,
(in millions, except per share amounts)	2019		2018		2017
Net income	$	317.7	$	325.5	$	242.0
Less: Net income attributable to net parent investment		(55.0)		(46.8)		25.4
Less: Net income attributable to noncontrolling interest		302.6		301.5		175.4
Net income attributable to Hess Midstream LP		70.1		70.8		41.2
Less: General partner's interest in net income prior to the Restructuring		3.4		1.7		0.8
Limited partners' interest in net income	$	66.7	$	69.1	$	40.4
Common unitholders' interest in net income attributable to Hess Midstream LP			$	34.6	$	20.2
Subordinated unitholders' interest in net income attributable to Hess Midstream LP			$	34.5	$	20.2
Net income attributable to Hess Midstream LP per Class A Share/limited partner unit*:
Basic:	$	1.21
Diluted:	$	1.20
Net income attributable to Hess Midstream LP per limited partner unit (basic and diluted):
Common			$	1.27	$	0.75
Subordinated			$	1.27	$	0.75
Weighted average Class A Shares outstanding subsequent to the Restructuring (basic and diluted):		18.0
Weighted average limited partner units outstanding prior to the Restructuring
Basic:
Common		27.3		27.3		26.9
Subordinated		27.3		27.3		26.9
Diluted:
Common		27.5		27.4		26.9
Subordinated		27.3		27.3		26.9

Hess represented approximately 100% of our total revenues and accounts receivable from contracts with customers for the years ended December 31, 2019, 2018 and 2017.

The Company is subject to federal, state and local laws and regulations relating to the environment. As of December 31, 2019, our reserve for estimated remediation liabilities included in Accrued liabilities and Other noncurrent liabilities was $0.7 million and $2.1 million, respectively. As of December 31, 2018, we had $0.6 million and $2.0 million, respectively.

As of December 31, 2019, and 2018, we did not have accrued liabilities for any legal contingencies. Based on currently available information, we believe it is remote that the outcome of known matters would have a material adverse impact on our financial condition, results of operations or cash flows.

We enter into certain lease and purchase commitments in connection with ongoing business activities. The following table presents our future undiscounted minimum lease payments (in millions). The discounted amount recognized on our accompanying consolidated balance sheet as of December 31, 2019, is $0.6 million included within other noncurrent liabilities.

In addition, as of December 31, 2019, we have unconditional purchase commitments of $65.0 million for the year ending December 31, 2020 and none for the years thereafter.

Our operations are located in the United States and are organized into three reportable segments: (i) gathering, (ii) processing and storage and (iii) terminaling and export. Our reportable segments comprise the structure used by our Chief Operating Decision Maker (“CODM”) to make key operating decisions and assess performance. These segments are strategic business units with differing products and services. The accounting policies of the segments are identical to those described in Note 2, Summary of Significant Accounting Policies and Basis of Presentation. Our CODM evaluates the segments’ operating performance based on multiple measures including Adjusted EBITDA, defined as net income (loss) before interest expense, income tax (benefit), depreciation and amortization, and our proportional share of depreciation of our equity affiliates as further adjusted for other non‑cash, non‑recurring items, if applicable.

Processing and Storage. Our processing and storage segment consists of the following assets:

Terminaling and Export. Our terminaling and export segment consists of the following assets:

The following tables reflect certain financial data for each reportable segment. The acquisition of HIP, which included Hess Water Services caused a change in composition of reportable segments and, as a result, the corresponding items of segment information for earlier periods have been restated.

	Gathering		Processing and Storage		Terminaling and Export		Interest and Other			Consolidated
(in millions)
For the Year Ended December 31, 2019
Revenues and other income	$	422.9	$	295.3	$	130.1	$	-		$	848.3
Net income (loss)		186.0		176.1		54.8		(99.2	)		317.7
Net income (loss) attributable to Hess Midstream LP		34.6		34.6		10.5		(9.6	)		70.1
Depreciation expense		81.6		44.7		16.2		-			142.5
Proportional share of equity affiliates' depreciation		-		2.0		-		-			2.0
Income from equity investments		-		3.4		-		-			3.4
Interest expense, net		-		-		-		62.4			62.4
Income tax expense (benefit)		-		-		-		(0.1	)		(0.1	)
Transaction costs		-		-		-		26.2			26.2
Adjusted EBITDA		267.6		222.8		71.0		(10.7	)		550.7
Capital expenditures*		373.6		42.5		0.2		-			416.3
	Gathering		Processing and Storage		Terminaling and Export		Interest and Other			Consolidated
(in millions)
For the Year Ended December 31, 2018
Revenues and other income	$	375.2	$	251.4	$	86.1	$	-		$	712.7
Net income (loss)		199.6		148.8		36.1		(59.0	)		325.5
Net income (loss) attributable to Hess Midstream LP		38.4		30.7		7.3		(5.6	)		70.8
Depreciation expense		67.2		43.9		15.8		-			126.9
Interest expense, net		-		-		-		53.3			53.3
Gain on sale of property, plant and equipment		-		-		-		0.6			0.6
Adjusted EBITDA		266.8		192.7		51.9		(6.3	)		505.1
Capital expenditures		257.0		10.0		4.3		-			271.3

	Gathering		Processing and Storage		Terminaling and Export		Interest and Other			Consolidated
(in millions)
For the Year Ended December 31, 2017
Revenues and other income	$	285.5	$	227.3	$	66.7	$	-		$	579.5
Net income (loss)		132.1		123.8		14.4		(28.3	)		242.0
Net income (loss) attributable to Hess Midstream LP		23.3		18.8		2.4		(3.3	)		41.2
Depreciation expense		57.8		43.6		15.1		-			116.5
Interest expense, net		-		-		-		25.8			25.8
Gain on sale of property, plant and equipment		-		-		-		4.7			4.7
Adjusted EBITDA		189.9		167.4		29.5		(7.2	)		379.6
Capital expenditures		77.8		15.9		24.6		-			118.3
*Includes acquisition, expansion and maintenance capital expenditures.

In the normal course of our business, we are exposed to market risks related to changes in interest rates. Financial risk management activities include transactions designed to reduce risk by reducing our exposure to interest rate movements. Interest rate swaps may be used to convert interest payments on certain long‑term debt.

As of December 31, 2019 and 2018, there were no outstanding interest rate swaps designated as cash flow hedges. At December 31, 2019, deferred income in Accumulated other comprehensive income in connection with the settled instruments was $0.4 million, of which $0.4 million will be reclassified into earnings during the next 12 months.

Prior to the Restructuring on December 16, 2019, the Partnership was not a separate taxable entity for U.S. federal and state income tax purposes; therefore, we did not recognize income tax expense or benefit in those periods. Each partner was subject to income taxes on its share of the Partnership’s earnings. As a result of the Restructuring, the Company holds a 6.32% controlling interest in the Partnership and is subject to federal and state income taxes on its share of the Partnership’s earnings. Although the Company is a Delaware limited partnership, it is subject to corporate income tax, because of our election to be treated as a corporation for U.S. federal and state income tax purposes in connection with the Restructuring.

In connection with the Restructuring, we became a partial owner of the Partnership and recognize income tax expense or benefit on our allocable share of the Partnership’s income or loss subsequent to the Restructuring. For the period from December 16, 2019 through December 31, 2019, we recognized a deferred tax benefit of $0.1 million and we did not have any current income tax expense. As part of the Restructuring, we recognized a deferred tax asset of $49.8 million for the temporary differences related to our investment in the Partnership. The effect of recognizing the deferred tax asset was included in Class A shareholders’ equity balance in the accompanying consolidated statement of changes in partners’ capital due to the Restructuring being characterized as a transaction among or with shareholders.

On March 1, 2019, HIP acquired Hess Water Services (see Note 3, Acquisitions). For the periods prior to March 1, 2019, Hess Water Services was included in the consolidated income tax returns of Hess. The provision for Hess Water Services’ income taxes and income tax assets and liabilities were determined as if it were a standalone taxpayer for all periods presented and is included in our retrospectively recast financial statements.

The difference between the effective income tax rate and the U.S. statutory rate is reconciled below:

The 2019 deferred tax position presented in the schedule above primarily represents our deferred tax asset for temporary differences related to our investment in the Partnership. The 2018 deferred tax position presented in the table above represents the results of Hess Water Services as if it were a stand-alone entity for the period. The related activity was included in Hess’s federal and state income tax returns and the related attributes are not available on income tax filings of HIP and its partners. Hess Water Services was in a three-year cumulative loss position at the end of 2018, which constitutes objective negative evidence to which accounting standards require we assign significant weight relative to subjective estimates, such as income projections. As a result, a full valuation allowance was maintained against the net deferred tax assets of Hess Water Services at December 31, 2018.

We have no unrecognized tax benefits or interest and penalties related to tax liabilities recorded in the financial statements. For the years presented, we earned all net income before taxes in the United States. We file income tax returns in the U.S. and various states. We are not subject to examinations by income tax authorities for years prior to 2019.

On January 27, 2020 the board of directors of our general partner declared a quarterly cash distribution of $0.4258 per Class A Share for the quarter ended December 31, 2019, an increase of 15% compared with the quarter ended December 31, 2018. The distribution was paid on February 14, 2020 to shareholders of record as of the close of business on February 6, 2020.

	2019
	First Quarter		Second Quarter		Third Quarter		Fourth Quarter
(in millions, except per share/unit amounts)
Revenues and other income	$	189.6	$	190.3	$	214.9	$	253.5
Income from operations	$	95.8	$	91.2	$	99.3	$	90.3
Net income	$	80.8	$	74.4	$	87.4	$	75.1
Net income attributable to Hess Midstream LP	$	18.1	$	16.8	$	19.1	$	16.1
Net income attributable to Hess Midstream LP per Class A Share/limited partner unit (basic and diluted):
Class A Share	$	-	$	-	$	-	$	0.28
Common unit	$	0.32	$	0.29	$	0.33	$	-
Subordinated unit	$	0.32	$	0.29	$	0.33	$	-

	2018
	First Quarter		Second Quarter		Third Quarter		Fourth Quarter
(in millions, except per share/unit amounts)
Revenues and other income	$	166.5	$	176.5	$	183.8	$	185.9
Income from operations	$	90.8	$	96.3	$	99.0	$	92.1
Net income	$	77.7	$	82.8	$	86.1	$	78.9
Net income attributable to Hess Midstream LP	$	17.0	$	17.8	$	18.8	$	17.2
Net income attributable to Hess Midstream LP per limited partner unit (basic and diluted):
Common	$	0.30	$	0.32	$	0.34	$	0.31
Subordinated	$	0.30	$	0.32	$	0.34	$	0.31

Amounts in the tables above have been retrospectively adjusted for the acquisition of Hess Infrastructure Partners LP, which was accounted for as an acquisition of a business under common control. See Note 3, Acquisitions. No other adjustments have been made to the quarterly financial information as previously reported by Hess Midstream Partners LP.

Based upon their evaluation of the Company’s disclosure controls and procedures (as defined in Exchange Act Rules 13a‑15(e) and 15d‑15(e)) as of December 31, 2019, John B. Hess, Chief Executive Officer, and Jonathan C. Stein, Chief Financial Officer, concluded that these disclosure controls and procedures were effective as of December 31, 2019.

There was no change in internal control over financial reporting, as defined in Rules 13a‑15(f) and 15d‑15(f) under the Exchange Act, in the quarter ended December 31, 2019 that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rules 13a‑15(f). Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an evaluation of the effectiveness of our internal control over financial reporting, as required by Section 404 of the Sarbanes‑Oxley Act, based on the framework in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework). Based on our evaluation, management concluded that our internal control over financial reporting was effective as of December 31, 2019.

Ernst & Young LLP, the independent registered public accounting firm that audited our consolidated financial statements included in this report, has issued an attestation report (the “Attestation Report”) on the effectiveness of the Company’s internal controls over financial reporting as of December 31, 2019. The Attestation Report is included in Item 8. Financial Statements and Supplementary Data of this annual report on Form 10‑K.

We are managed by the directors and officers of Hess Midstream GP LLC (“GP LLC”), the general partner of our general partner. We sometimes refer to the directors and officers of GP LLC in this annual report on Form 10‑K as our directors and officers. Because our general partner is a limited partnership, we are managed by the directors and executive officers of its general partner, GP LLC, a wholly owned subsidiary of HIP GP LLC. Our shareholders are not entitled to elect our general partner, the general partner of our general partner, or the directors on its board of directors, or directly or indirectly participate in its management or operations. Hess and GIP each have the right to nominate certain individuals to serve on the board of directors of GP LLC (the “Company Board”). Because GP LLC is wholly owned by HIP GP LLC, HIP GP LLC has the right to elect the entire Company Board, including the independent directors, following their nomination by Hess and GIP.

Neither we nor our subsidiaries have any employees. GP LLC, as the general partner of our general partner, has the sole responsibility for providing the employees and other personnel necessary to conduct our operations. All of the employees that conduct our business are employed by affiliates of our general partner, but we sometimes refer to these individuals in this annual report on Form 10-K as our employees.

Directors have been elected by HIP GP LLC and will hold office until their successors have been elected or qualified or until their earlier death, resignation, removal or disqualification. Executive officers have been appointed by, and will serve at the discretion of, the Company Board. The following table shows information for the directors and executive officers of GP LLC as of February 21, 2020.

John B. Hess. John B. Hess was appointed as Chairman of the Company Board in September 2019 and has served as Chief Executive Officer of GP LLC since September 2019. Mr. Hess served as Chairman of the board of directors (the “Partnership Board”) of Hess Midstream Partners GP LLC (“MLP GP LLC”) from September 2014 to December 2019 and as Chief Executive Officer of MLP GP LLC from July 2014 to December 2019. Mr. Hess has served as Chief Executive Officer of Hess since 1995. Mr. Hess joined Hess in May 1977 and was elected a director in November 1978. He served as Chairman of the Board and Chief Executive Officer of Hess from 1995 until 2013. Mr. Hess has been a member of the board of directors of KKR & Co. Inc. (formerly KKR & Co. L.P.), since 2011 and of Dow Chemical Company from 2006 until 2013. We believe that Mr. Hess’ extensive experience in the energy industry, including his more than 40-year career with Hess and his extensive leadership experience in his roles as Chief Executive Officer and Chairman of the Board of Hess, makes him well qualified to serve as Chairman of the Company Board.

John A. Gatling. John A. Gatling was appointed President and Chief Operating Officer of GP LLC in September 2019. Mr. Gatling served as Chief Operating Officer of MLP GP LLC from December 2015 to December 2019. Mr. Gatling is also the head of Hess’ Midstream Business and leads Hess’ Onshore Infrastructure, Commercial, Land, Supply Chain and Finance functions. In addition, Mr. Gatling has served as Director of Operational Excellence and Strategic Business Planning for Hess since 2012. Prior to his current roles, Mr. Gatling served as the Senior Manager of Global Production Strategic Planning and Performance Management at Hess from 2010 until 2012. Prior to joining Hess in 2010, Mr. Gatling spent 14 years with Aera Energy, a joint venture affiliate of Shell and ExxonMobil, where he provided leadership for operational excellence, execution of projects, strategic planning and commercial.

Jonathan C. Stein. Jonathan C. Stein was appointed Chief Financial Officer of GP LLC in September 2019. Mr. Stein served as Chief Financial Officer of MLP GP LLC from July 2014 to December 2019. Mr. Stein continues his role as Vice President, Chief Risk Officer of Hess which he has held since June 2004. In such capacity, he is responsible for Hess’ Corporate Financial Forecasting process, Hess’ Midstream segment financial reporting, derivative disclosure and accounting policy and is a member of Hess’ disclosure review committee. Prior to his current roles, Mr. Stein served as Corporate Risk Manager at Hess. Prior to joining Hess in 2001, Mr. Stein was a consultant with Ernst & Young LLP’s Risk Management and Regulatory Practice, where he assisted financial services and energy trading clients in establishing their risk management infrastructure. Mr. Stein is on the Board of Trustees of the Global Association of Risk Professionals and is a Certified Management Accountant.

Timothy B. Goodell. Timothy B. Goodell was appointed General Counsel and Secretary of GP LLC in September 2019. Mr. Goodell served as General Counsel and Secretary of MLP GP LLC from July 2014 to December 2019. He serves as Senior Vice President and General Counsel of Hess since January 2009, as Corporate Secretary of Hess since September 2016 and as Chief Compliance Officer since 2017. Prior to joining Hess in 2009, Mr. Goodell was a partner at the law firm of White & Case LLP, where his practice concentrated in the areas of mergers and acquisitions and securities, as well as general corporate and corporate governance matters.

John P. Rielly. John P. Rielly was appointed a Director of the Company Board and Vice President of GP LLC in September 2019. Mr. Rielly served as a Vice President of MLP GP LLC from July 2014 to December 2019 and as a member of the Partnership Board from September 2014 to December 2019. Mr. Rielly serves as Senior Vice President and Chief Financial Officer of Hess since April 2004. He served as Vice President and Controller of Hess from May 2001 to April 2004. Prior to joining Hess, Mr. Rielly was a partner at Ernst & Young LLP. We believe that Mr. Rielly’s extensive experience, particularly his knowledge of industry accounting and financial practices gained during his employment at Hess and Ernst & Young LLP, makes him well qualified to serve as a member of the Company Board.

Gregory P. Hill. Gregory P. Hill was appointed a member of the Company Board in September 2019. Mr. Hill served a member of the Partnership Board from September 2014 to December 2019. He serves as Chief Operating Officer of Hess since May 2014 and as President, Exploration and Production of Hess since January 2009. In addition, Mr. Hill served on the board of directors of Hess from 2009 to 2013. Prior to joining Hess in 2009, Mr. Hill spent 25 years at Shell, where he performed a variety of operations, engineering, technical and business leadership roles in Asia-Pacific, Europe and the United States, including Executive Vice President—Exploration and Production of Singapore-based Shell Asia Pacific from 2006 to 2008 while also serving as Chairman of Shell’s Global Production Leadership Team. We believe that Mr. Hill’s extensive experience in the energy industry, particularly his experience in operations and strategic planning, makes him well qualified to serve as a member of the Company Board.

Michael R. Turner. Michael R. Turner was appointed a member of the Company Board in September 2019. He has served as Senior Vice President for Hess since January 1, 2020. He previously served as Senior Vice President, Global Production for Hess from January 2017 to December 2019 and as Senior Vice President, Onshore at Hess from 2009 to December 2016. Prior to joining Hess in 2009, Mr. Turner spent 28 years with Shell in a variety of production leadership positions around the world. Mr. Turner will retire from Hess effective April 3, 2020. We believe that Mr. Turner’s extensive executive and industry experience makes him well qualified to serve as a member of the Company Board.

William J. Brilliant. William J. Brilliant was appointed a member of the Company Board in December 2019. Mr. Brilliant served as a member of the Partnership Board from December 2015 to December 2019. Mr. Brilliant is currently a Partner of GIP and focuses on North American energy investments. Mr. Brilliant is a member of GIP’s Investment and Operating Committees. He has served as a member of GIP’s investment team since May 2007 and led GIP’s investment in HIP. Prior to joining GIP, Mr. Brilliant was an investment banker in the Global Financial Sponsors Group at Lehman Brothers from 2005 to 2007, providing M&A and financial advisory to investment funds throughout their investment cycle. Mr. Brilliant has been a director of the managing member of EnLink Midstream, LLC and the general partner of EnLink Midstream Partners LP, since July 2018 and previously served as a director of the general partner of Access Midstream Partners L.P. from June 2012 until July 2014. We believe that Mr. Brilliant’s energy industry background, particularly his expertise in mergers and acquisitions, brings important experience and skill to the Company Board.

Scott E. Telesz. Scott E. Telesz was appointed a member of the Company Board in December 2019. Mr. Telesz served as a member of the Partnership Board from December 2018 to December 2019. Mr. Telesz is currently a Partner of GIP and has over 25 years of experience in the manufacturing industry. Prior to joining GIP in August 2018, Mr. Telesz spent 8 years as an executive at Praxair, an industrial gas manufacturing company, most recently as executive vice president in charge of Praxair’s U.S. atmospheric gases businesses, Canada and surface technologies from 2014 until May 2018. Before joining Praxair, Mr. Telesz spent 12 years at GE/SABIC where he ran various electrical products and plastics businesses. We believe that Mr. Telesz’s extensive experience, particularly the leadership skills he developed while serving in several executive positions, brings important experience and skill to the Company Board.

Matthew C. Harris. Matthew C. Harris was appointed a member of the Company Board in December 2019. Mr. Harris is a Founding Partner of GIP and serves as a member of its Investment, Operating and Portfolio Valuation Committees. He leads GIP’s global energy industry investment team including natural gas, crude oil and refined products, electricity, LNG and metals and mining. Mr. Harris has been intimately involved in GIP’s investment, management and strategic activities since its formation in 2006. Prior to the formation of GIP in 2006, Mr. Harris was a Managing Director in the Investment Banking Division at Credit Suisse and Co-Head of the Global Energy Group and Head of the EMEA Emerging Markets Group. Prior to his tenure at Credit Suisse, he was a senior member of the Mergers and Acquisitions Group at Kidder Peabody & Co. Incorporated. He is a member of the Board of Directors of Freeport LNG, LLC, EnLink Midstream, LLC and previously served as a director of the general partner of Access Midstream Partners L.P. from January 2010 through December 2013. We believe that Mr. Harris’s extensive executive, financial and industry experience makes him well qualified to serve as a member of the Company Board.

David W. Niemiec. David W. Niemiec was appointed a member of the Company Board in December 2019. Mr. Niemiec served as a member of the Partnership Board from April 2017 to December 2019. Mr. Niemiec is a private equity investor and has served as an advisor to, and previously a managing director of, Saratoga Partners since 1998. Prior to his affiliation with Saratoga, Mr. Niemiec was Vice Chairman of the investment banking firm Dillon, Read & Co. Inc., where he also served as Chief Financial Officer from 1982 to 1997. Mr. Niemiec is a director or trustee of several mutual funds in the Franklin Templeton Investments family. Mr. Niemiec previously served as director of Emeritus Corporation from 1999 to 2010 and OSI Pharmaceuticals from 2006 to 2010. We believe that Mr. Niemiec’s extensive financial and investment experience makes him well qualified to serve as a member of the Company Board.

John P. Reddy. John P. Reddy was appointed a member of the Company Board in December 2019. Mr. Reddy served as a member of the Partnership Board from June 2017 to December 2019. Mr. Reddy has over 20 years of experience in senior financial roles at public companies in the midstream energy sector. Mr. Reddy most recently served as Chief Financial Officer of Spectra Energy Corporation, an owner and operator of pipeline and midstream energy assets, from 2009 to 2017, and Chief Financial Officer of its sponsored master limited partnership, Spectra Energy Partners. Prior to that, he served as Senior Vice President and Chief Financial Officer of Atmos Energy Corporation and in various financial roles with Pacific Enterprises Corporation. Mr. Reddy currently serves on the board of directors of Overseas Shipholding Group Inc., and previously was a member of the board of directors of DCP Midstream, LLC from 2009 until 2017, and Paragon Offshore Plc from July 2014 until July 2017. We believe that Mr. Reddy’s extensive financial and industry experience makes him well qualified to serve as a member of the Company Board.

Stephen J.J. Letwin. Stephen J.J. Letwin was appointed a member of the Company Board in December 2019. Mr. Letwin served as a member of the Partnership Board from February 2018 to December 2019. Mr. Letwin has over 30 years of experience in senior operating and financial roles in the midstream energy and resources sectors. Mr. Letwin has served as President and Chief Executive Officer of Mancal Corporation since February 1, 2020. Mr. Letwin previously served as the President and Chief Executive Officer of IAMGOLD Corporation from November 2010 to February 2020. Prior to joining IAMGOLD, Mr. Letwin served in senior management roles at Enbridge, Inc., from 1999 through September 2010, most recently as Executive Vice President, Gas Transportation & International, from May 2006 to September 2010, where he was responsible for Enbridge’s natural gas operations and prior to that as Managing Director of Enbridge Energy Partners. Mr. Letwin previously spent 12 years in senior management roles at TransCanada Pipelines Limited, Numac Energy Inc., and Encor Energy Partners. Mr. Letwin currently serves as Chairman of the board of directors of ONEnergy Inc. and previously was a member of the board of directors of IAMGOLD from 2010 until January 2020 and Precision Drilling Corporation from 2006 until 2018. We believe that Mr. Letwin’s extensive executive, financial and industry experience makes him well qualified to serve as a member of the Company Board.

Although most companies listed on the NYSE are required to have a majority of independent directors serving on the board of directors of the listed company, the NYSE does not require a publicly traded limited partnership like us to have a majority of independent directors on our board of directors or to establish a compensation or a nominating and corporate governance committee. We do not currently intend to establish a compensation or a nominating and corporate governance committee. Accordingly, shareholders will not have the same protections afforded to equity holders of companies that are subject to all of the corporate governance requirements of the NYSE. We are, however, required to have an audit committee of at least three members, and all of our audit committee members are required to satisfy the independence and experience standards established by the NYSE and the Exchange Act.

The Company Board has a standing audit committee and may have a conflicts committee and such other committees as the Company Board shall determine from time to time.

The audit committee of the Company Board is currently comprised of three directors, each of whom satisfy the independence and experience standards established by the NYSE and the Exchange Act and all are “audit committee financial experts” as this term is defined by applicable SEC rules. The current members are Messrs. Niemiec, Reddy and Letwin and Mr. Niemiec serves as the chair of the committee. The audit committee assists the Company Board in its oversight of the integrity of our financial statements and our compliance with legal and regulatory requirements and corporate policies and controls. The audit committee has the sole authority to retain and terminate our independent registered public accounting firm, approve all auditing services and related fees and the terms thereof, and pre-approve any non-audit services to be rendered by our independent registered public accounting firm. The audit committee is also responsible for confirming the independence and objectivity of our independent registered public accounting firm. Our independent registered public accounting firm will be given unrestricted access to the audit committee. The charter of the audit committee is available on our website (www.hessmidstream.com) under the “Company” tab.

While the audit committee oversees our financial reporting process on behalf of the Company Board, management has the primary responsibility for preparing the financial statements and the reporting process, including the systems of internal controls. In fulfilling its oversight responsibilities, the audit committee reviews and discusses with management the audited financial statements contained in this Annual Report on Form 10‑K.

The Company Board has the ability to establish, from time to time, a conflicts committee under our partnership agreement. If established, at least two members of the board of directors will serve on any conflicts committee to review specific matters that may involve conflicts of interest in accordance with the terms of our partnership agreement. The board of directors will determine whether to refer a matter to a conflicts committee on a case by case basis. The members of any conflicts committee may not be officers or employees of our general partner or directors, officers or employees of its affiliates (including the Sponsors) and must meet the independence and experience standards established by the NYSE and the Exchange Act to serve on an audit committee of a board of directors. In addition, the members of any conflicts committee may not own any interest in our general partner or any of its affiliates or any interest in the Company or its subsidiaries other than Class A Shares or awards under our long-term incentive plan. If our general partner seeks approval from a conflicts committee, then it will be presumed that, in making its decision, the conflicts committee acted in good faith, and in any proceeding brought by or on behalf of any limited partner or the Company challenging such determination, the person bringing or prosecuting such proceeding will have the burden of overcoming such presumption.

The chief executive officer of our general partner serves as the chairman of the Company Board. The Company Board has no policy with respect to the separation of the offices of chairman of the board of directors and chief executive officer. Instead, that relationship is defined and governed by the amended and restated limited liability company agreement of our general partner, which permits the same person to hold both offices. Members of the Company Board are elected by HIP GP LLC. Accordingly, unlike holders of common stock in a corporation, our shareholders have only limited voting rights on matters affecting our business or governance, subject in all cases to any specific shareholder rights contained in our partnership agreement.

Independent directors generally meet in executive sessions after each regularly scheduled board meeting. Mr. Niemiec, the Chairman of the Audit Committee, presides at these sessions.

The Company Board has primary responsibility for assessing the major risks facing us and the options for their mitigation. The audit committee assists the Company Board in its risk oversight responsibilities by reviewing the policies that management implements to monitor such exposures, including our financial risk exposures, and the implementation and effectiveness of our compliance programs.

Any shareholder or interested party who wishes to communicate with members of the Company Board or with non-management directors will be able to do so by writing to them in care of the General Counsel and Secretary at Hess Midstream LP, 1501 McKinney Street, Houston, Texas 77010. Such communications should specify the intended recipient or recipients.

We have adopted a Code of Business Conduct and Ethics for directors and employees designed to help directors and employees resolve ethical issues in an increasingly complex business environment. Our Code of Business Conduct and Ethics applies to all directors and employees, including the Chief Executive Officer and the Chief Financial Officer. Our Code of Business Conduct and Ethics is available on our website (www.hessmidstream.com) under the “Company” tab.

Section 16(a) of the Securities Exchange Act of 1934 (the Act) requires directors and executive officers of our general partner, and persons who own more than 10% of a registered class of our equity securities, to file reports of ownership and changes in ownership of our shares with the SEC and the NYSE, and to furnish us with copies of the forms they file. To our knowledge, based solely upon a review of the copies of such reports furnished to us and written representations of our officers and directors, during the year ended December 31, 2019, all Section 16(a) reports applicable to our officers and directors were filed on a timely basis.

Neither we nor GP LLC employ any of the persons who serve as executive officers of GP LLC and are responsible for managing our business. We are managed by GP LLC, the executive officers of which are employees of Hess. Our general partner has entered into an employee secondment agreement with Hess and certain of its subsidiaries pursuant to which, among other matters, Hess and its subsidiaries make available to our general partner the services of the employees who serve as our executive officers in exchange for a fee. Except with respect to awards granted under our LTIP, we do not pay compensation to any of the executive officers and do not participate in any compensation decisions for the Named Executive Officers.

For purposes of simplicity and ease of understanding, we have presented this Compensation Discussion and Analysis (“CD&A”) on a basis that reflects our current organizational structure following the Restructuring and therefore references in this CD&A and the accompanying executive compensation tables to us and to GP LLC with respect to periods prior to the Restructuring should be interpreted as referring to the Partnership and to the general partner of the Partnership’s general partner, as in effect prior to the Restructuring.

All of the NEOs perform responsibilities for both us and for Hess and its affiliates unrelated to our business and, except as described herein, their compensation is set and paid by Hess under its compensation programs, none of which are specific to us or our business. Except with respect to awards that may be granted from time to time under our LTIP, our NEOs do not receive any separate or additional compensation for their services to us or as executive officers of GP LLC.

Except with respect to awards granted under our LTIP, Hess has sole decision-making authority with respect to the compensation paid by Hess to our NEOs. Such decisions are overseen by Hess’s board of directors and we do not have any authority and do not provide any input with respect to such decisions. The compensation that is paid by Hess to our NEOs is determined solely based on the roles they perform for Hess, which includes their seconded role as executive officers.

We have adopted the Hess Midstream LP Long-Term Incentive Plan (the “LTIP”) for officers, directors and employees of GP LLC or its affiliates and other individuals who perform services for us. The LTIP provides for the grant, from time to time at the discretion of the plan administrator or any delegate thereof, subject to applicable law, of unit awards, restricted units, phantom units, unit options, unit appreciation rights, distribution equivalent rights, profits interest units and other unit-based awards.

The LTIP is generally administered by the board of directors of GP LLC and, from time to time, we have granted awards of phantom units with distribution equivalent rights to certain of our NEOs. Such awards are granted for the purpose of providing incentive compensation to these NEOs that is directly tied to the performance of our Class A Shares and to align the economic interests of the NEOs with the interests of our shareholders.

Decisions with respect to awards of phantom units to our NEOs are made by the board of directors of GP LLC in consultation with Hess’ board of directors and Hess’ executive officers, taking into account the NEO’s role within our organization, including duties, responsibilities and seniority levels. For 2019, such awards were not granted to our NEOs who are also executive officers of Hess on the basis that the scope of their duties involving us relative to their overall duties as executive officers of Hess did not warrant such awards.

For 2019, phantom unit awards to our NEOs included distribution equivalent rights and vest ratably over a three year period following the date of grant, subject to the NEO’s continued service to Hess through the vesting date. Upon vesting, each phantom unit is paid in the form of a Class A Share in us, or an equivalent amount of cash, subject to applicable tax withholdings. Award amounts, which are set forth below were determined based on the judgement and industry experience of the board members (in consultation with Hess, as described above), taking into account the factors discussed above. We did not engage an independent compensation consultant or other advisor in making such decisions and did not benchmark award amounts against any specific peer group of companies.

The following table summarizes the compensation for services rendered to us by the NEOs during 2019, 2018 and 2017, which is limited to awards granted under our LTIP. Our NEOs have separately received compensation from Hess, none of which is specifically attributable to us. Under our secondment agreement with Hess, we pay Hess a fee in exchange for making the services of NEOs available to us.

Name and Principal Position	Year	Salary		Bonus		Unit Awards⁽¹⁾		All Other Compensation		Total
John B. Hess, Chief Executive Officer	2019	$	-	$	-	$	-	$	-	$	-
	2018		-		-		-		-		-
	2017		-		-		-		-		-
Jonathan C. Stein, Chief Financial Officer	2019		-		-	$	249,996		-	$	249,996
	2018		-		-	$	249,996		-	$	249,996
	2017		-		-	$	100,000		-	$	100,000
John A. Gatling, President and Chief Operating Officer	2019		-		-	$	249,996		-	$	249,996
	2018		-		-	$	249,996		-	$	249,996
	2017		-		-	$	100,000		-	$	100,000
Timothy B. Goodell, General Counsel and Secretary	2019		-		-		-		-		-
	2018		-		-		-		-		-
	2017		-		-		-		-		-
John P. Rielly, Vice President	2019		-		-		-		-		-
	2018		-		-		-		-		-
	2017		-		-		-		-		-

The following table provides information regarding phantom units granted to our NEOs in 2019. The phantom units include distribution equivalent rights and vest ratably over three years following the date of grant.

(1) Amount shown represents the grant date fair value of phantom unit awards granted pursuant to our LTIP, determined in accordance with FASB ASC Topic 718.

The following table provides information regarding phantom units with distribution equivalent rights received by our NEOs and outstanding as of December 31, 2019.

The following table provides information regarding the exercise of options and vesting of shares held by our NEOs during the fiscal year ended December 31, 2019.

(1) Represents the value of vested units calculated by multiplying (i) the gross number of the Partnership units acquired on vesting by (ii) the closing price of the Partnership units on the date of vesting.

We do not provide pension or nonqualified deferred compensation benefits to any of our NEOs and we have no obligations with respect to any such benefits that may be provided to the NEOs under the pension and nonqualified deferred compensation plans of Hess.

None of our NEO’s have entered into any employment, severance or similar agreements in relation to their services to us or our general partner and, except with respect to the phantom units issued pursuant to our LTIP, as of December 31, 2019, there were no arrangements pursuant to which our NEOs would receive any payments or benefits in connection with a change in control of us.

The phantom unit awards granted pursuant to the LTIP generally contemplate that the individual grants of phantom units will vest in three equal annual installments based on the grantee’s continued employment through the vesting dates, subject to acceleration upon (i) the grantee’s death or disability, (ii) the grantee’s retirement after attaining age 65 with at least five years of continuous service with Hess or its affiliates, (iii) upon a termination without cause or a resignation for good reason following the occurrence of a change in control of us, or (iv) in the discretion of the plan administrator, which may provide for pro‑rated vesting, upon an early retirement, which is generally defined as a retirement after attaining age 55 with 10 years of service with Hess and its affiliates. The board of directors of our general partner may also accelerate the vesting of the phantom units in its discretion at any time.

Set forth below is the total estimated value, assuming that a change in control occurred on December 31, 2019 and the employment of each NEO terminated on that date under circumstances entitling them to accelerated vesting of the phantom units.

The amounts in the table above were calculated assuming a change in control occurred on December 31, 2019 using the closing price of our Class A Shares on December 31, 2019 (the last trading day of our fiscal year) of $22.68 per Class A Share.

The officers or employees of Hess or GIP who also serve as our directors do not receive additional compensation for their service as a director of Hess Midstream GP LLC. Our directors who are not officers or employees of Hess or GIP, or “non‑employee directors,” receive cash and equity‑based compensation for their services as directors. The non‑employee director compensation program consists of the following:

Such directors also receive reimbursement for out‑of‑pocket expenses associated with attending board or committee meetings and are covered by our director and officer liability insurance policies. All directors are indemnified by us for actions associated with being a director to the fullest extent permitted under Delaware law.

The following table provides information regarding the compensation earned by our non‑employee directors during the year ended December 31, 2019:

ITEM 12.Security Ownership of Certain Beneficial Owners and Management and Related Shareholder Matters

The following table sets forth the beneficial ownership of shares of Hess Midstream LP as held by beneficial owners of 5% or more of the shares, by each of our directors and named executive officers, and by all of our directors and executive officers as a group. The number and percentage of shares beneficially owned is based on a total of shares outstanding as of February 10, 2020 for the named directors and executive officers and as of December 31, 2019 for the other beneficial owners. Amounts for directors and named executive officers include phantom units outstanding pursuant to the Hess Midstream LP 2017 Long‑Term Incentive Plan that vest within 60 days of February 10, 2020.

	Shares Beneficially Owned by Certain Beneficial Owners
	Class A Shares				Class B Shares⁽¹⁾				Combined Voting Power⁽²⁾
Name of beneficial owner	Number		% of class		Number		% of class		Number		% of class
Entities Affiliated with Hess Midstream GP LP, our general partner ⁽³⁾		267,314,928	94.00%⁽⁴⁾			266,416,928	100%			267,314,928	94.00%
Kayne Anderson Capital Advisors, LP Richard A. Kayne 1800 Avenue of the Stars, Third Floor Los Angeles, CA 90067		2,165,539	12.06%⁽⁵⁾			-		-		2,165,539	*
FMR LLC 245 Summer Street Boston, MA 02210		1,841,266	10.25%⁽⁶⁾			-		-		1,841,266	*

Directors/Named Executive Officers
John B. Hess⁽⁷⁾		434,800	2.42%			-		-		434,800	*
John A. Gatling		48,235	*			-		-		48,235	*
Jonathan C. Stein		22,251	*			-		-		22,251	*
John P. Rielly		20,000	*			-		-		20,000	*
Gregory P. Hill		4,350	*			-		-		4,350	*
Michael R. Turner		4,500	*			-		-		4,500	*
Timothy B. Goodell		12,500	*			-		-		12,500	*
William J. Brilliant⁽⁸⁾		-		-		-		-		-		-
Scott E. Telesz⁽⁸⁾		-		-		-		-		-		-
Matthew C. Harris⁽⁸⁾		-		-		-		-		-		-
David W. Niemiec		33,851	*			-		-		33,851	*
John P. Reddy		7,761	*			-		-		7,761	*
Stephen J.J. Letwin		5,747	*			-		-		5,747	*
All Directors and Executive Officers as a group (13 persons)		593,995	3.31%			-		-		593,995	*

The following table sets forth the number of shares of Hess Corporation common stock beneficially owned as of February 10, 2020, except as otherwise noted, by each of our directors and named executive officers and by all directors and executive officers as a group.

Name	Total number of shares beneficially owned and nature of beneficial ownership^(a)		Percent of outstanding shares of common stock owned			Of total number of shares beneficially owned, number of option shares
Directors/Named Executive Officers
John B. Hess	33,764,001^(b)(c)(d)(e)			11.01	%		720,132
John A. Gatling		18,419	*				1,770
Jonathan C. Stein		37,630	*				12,612
John P. Rielly		381,210	*				130,064
Gregory P. Hill		353,648	*				231,142
Timothy B. Goodell		262,733	*				130,064
Michael R. Turner		128,260	*				49,650
William J. Brilliant		-		-			-
Scott E. Telesz		-		-			-
Matthew C. Harris		-		-			-
David W. Niemiec		-		-			-
John P. Reddy		-		-			-
Stephen J.J. Letwin		-		-			-
All Directors and Executive Officers as a group (13 persons)		34,945,901		11.42	%		1,275,434

*The percentage of shares beneficially owned by each director or executive officer does not exceed 1% of the common shares outstanding.

2,485,946 shares held by trusts as to which Mr. Hess has sole voting power. These shares (representing 0.7% of Hess common stock outstanding) have been pledged by the trusts. Mr. Hess is not a trustee of these trusts and has no financial or economic interest in the shares pledged by the trusts.

See Equity Compensation Plan Information in Item 5. Market for Registrant’s Common Equity, Related Shareholder Matters and Issuer Purchases of Equity Securities for information pertaining to securities authorized for issuance under our equity compensation plan.

As of December 31, 2019, the Sponsors own all of the ownership interests in HIP GP LLC, which owns all of the ownership interests in our general partner and in GP LLC, the general partner of our general partner. As of December 31, 2019, the Sponsors, through their ownership interests in our general partner, own, in the aggregate, 898,000 of our Class A Shares (economic and voting) and 266,416,928 of our Class B Shares (non-economic, voting only). In addition, as of December 31, 2019, the Sponsors own 266,416,928 of Class B Units in Hess Midstream Operations LP, or the Partnership, representing an approximate 93.68% noncontrolling interest in the consolidated entity. Class B Shares of the Company together with an equal number of Class B Units in the Partnership are convertible to Class A Shares of the Company on a one-for-one basis. The Sponsors obtained their Class A Shares of the Company, Class B Shares of the Company and Class B Units of the Partnership on December 16, 2019 at the closing of the Restructuring.

The following information summarizes the distributions and payments, made or to be made, by the Company and the Partnership to Hess Midstream GP LP, our general partner, and its affiliates, including the Sponsors, in connection with the Restructuring, ongoing operation and liquidation of the Company and the Partnership.

After consummation of the Restructuring, the Sponsors and their affiliates received an aggregate of 898,000 Class A Shares, 266,416,928 Class B Units representing noncontrolling limited partner interests in the Partnership and aggregate cash consideration of $601.8 million.

We will generally make cash distributions to holders of Class A Shares pro rata, including to Hess Midstream GP LP, our general partner in its capacity, as the holder of an aggregate of 898,000 Class A Shares. The Partnership will generally make cash distributions to holders of units in the Partnership, including to the Sponsors as holders of an aggregate of 266,416,928 Class B Units, pro rata.

If we dissolve in accordance with our partnership agreement, we will sell or otherwise dispose of our assets in a process called liquidation. We will first apply the proceeds of liquidation to the payment of our creditors. We will distribute any remaining proceeds to all record holders of Class A Shares, pro rata, and such distribution will be made by the end of such taxable period (or, if later, within 90 days after said date of such occurrence).

Under our partnership agreement, we are required to reimburse Hess Midstream GP LP, as our general partner, and its affiliates for all costs and expenses that they incur on our behalf for managing and controlling our business and operations. Except to the extent specified under our amended omnibus agreement and amended employee secondment agreement, our general partner determines the amount of these expenses and such determinations must be made in good faith under the terms of the partnership agreement. The costs and expenses for which we are required to reimburse our general partner and its affiliates are not subject to any caps or other limits.

In connection with the Restructuring, we entered into the merger agreement with the Partnership, MLP GP LP, the Company, Hess Midstream GP LP, HIP GP LLC and MergerSub, pursuant to which MergerSub merged with and into the Partnership, with the Partnership surviving the merger. After the completion of the merger, the certificate of formation and the limited liability company agreement of the Partnership in effect immediately prior to the completion of the merger continued to be the certificate of formation (except to the extent the limited liability company agreement is amended by the certificate of merger) and the limited liability company agreement of the surviving entity, in each case, until amended in accordance with its terms and applicable law.

In connection with the Restructuring, we amended and restated our omnibus agreement by entering into the amended omnibus agreement under which we pay Hess on a monthly basis an amount equal to the total allocable costs of Hess’ employees and contractors, subcontractors or other outside personnel engaged by Hess and its subsidiaries to the extent such employees and outside personnel perform operational and administrative services for us in support of our directly and indirectly owned assets, plus a specified percentage markup of such amount depending on the type of service provided, as well as an allocable share of direct costs of providing these services. The Sponsors will be obligated to reimburse us for certain matters, claims and losses arising from the ownership of assets, including certain environmental and tax liabilities, rights of way and real property losses. The amended omnibus agreement also provides for the Company to indemnify HIP GP LLC and the Hess entities for certain matters and claims arising after the consummation of the Restructuring.

In connection with the Restructuring, we amended and restated our secondment agreement by entering into amended employee secondment agreement with Hess and an affiliate of Hess pursuant to which Hess seconds certain personnel to Hess Midstream GP LLC to provide services with respect to our direct and indirect assets and operations, including executive oversight, business and corporate development, shareholder and investor relations, communications and public relations, routine and emergency maintenance and repair services, routine operational services, routine administrative services, construction services, and such other operational, commercial and business services that are necessary to develop and execute our business strategy.

On a monthly basis, Hess Midstream GP LLC pays a secondment fee to Hess that is intended to cover and reimburse Hess for the total costs actually incurred by Hess and its affiliates in connection with employing the seconded employees to the extent such total costs are attributable to the provision of services with respect to our direct and indirect assets and operations. Hess determines in good faith the percentage of the costs that are attributable to the services provided by the seconded employees based on Hess’ then-current corporate transfer pricing policies, as generally applied in a non-discriminatory manner, or based on such other reasonable cost allocation methodology as Hess shall determine. We reimburse Hess Midstream GP LLC for the cost of the secondment fee payable by Hess Midstream GP LLC under the amended employee secondment agreement.

In connection with the Restructuring, we amended and restated our registration rights agreement by entering into the amended registration rights agreement with Hess and GIP pursuant to which we granted each of Hess and GIP and certain of their affiliates certain demand and “piggyback” registration rights. Under the amended registration rights agreement, each of Hess and GIP and certain of their affiliates generally has the right to require us to file a registration statement for the public sale of all of the Class A Shares received, pursuant to our partnership agreement, in exchange for the Partnership’s Class B Units and the Company’s Class B Shares owned by them. In addition, if we sell any Class A Shares in a registered underwritten offering, each of Hess and GIP and certain of their affiliates will have the right, subject to specified limitations, to include their Class A Shares in that offering. We will generally pay all expenses relating to any demand or piggyback registration, except for underwriters or brokers’ commission or discounts and expenses of counsel or advisors to the selling holders of registrable securities.

We have entered into long‑term, fee‑based commercial agreements with Hess, each of which has an initial 10‑year term (except for a certain gathering subsystem, for which the initial term of the gas gathering agreement is 15 years) and is dated effective January 1, 2014. We have the unilateral right to extend each commercial agreement for one additional 10‑year term (except for a certain gathering subsystem, for which the additional term of the gas gathering agreement is 5 years). These agreements include dedications covering substantially all of Hess’ existing and future owned or controlled production in the Bakken, minimum volume commitments, inflation escalators and fee recalculation mechanisms, all of which are intended to provide us with cash flow stability and growth, as well as downside risk protection.

Under these commercial agreements, we provide gathering, compression, processing, fractionation, storage, terminaling, loading and transportation services to Hess, and Hess is obligated to provide us with minimum volumes of crude oil, natural gas and NGLs. These commercial agreements are currently the source of substantially all of our revenue.

We have entered into a 9‑year compressed natural gas agreement with Hess under which Hess delivers residue gas to us at the inlet of our CNG terminal at the Tioga Gas Plant, and we receive and compress the residue gas and deliver CNG to the tailgate of the CNG terminal for Hess. Hess pays us a fee per Mcf of CNG we deliver to Hess each month. Our compressed natural gas agreement is dated effective January 1, 2015.

Effective January 1, 2019, we entered into two 14-year water services agreements with an affiliate of Hess pursuant to which we provide produced water transport, including gathering, and disposal services to Hess at an agreed-upon fee per barrel of water delivered each month to us, subject to inflation escalators. One of the water services agreements covers volumes produced north of the Missouri River (the “NOR Agreement”) and the other agreement covers volumes produced south of the Missouri River (the “SOR Agreement”). Both water services agreements require Hess to deliver to us all produced water that is produced from the Bakken and Three Forks formations on oil and gas properties located in specified dedication areas north and south of the Missouri River in North Dakota, subject to customary exclusions, reservations and conflicting dedications. Additionally, the NOR Agreement requires Hess to provide minimum volumes, calculated on a quarterly basis, of produced water for gathering and disposal. The minimum volume commitments consist of 100% of the Hess nominations during the first three years of the agreements and 80% of its nominations thereafter.

Under the NOR Agreement, there is also a gathering service fee recalculation mechanism, at the option of either party to the agreement. Under the recalculation mechanism, gathering service fees may be adjusted annually to account for actual throughput and capital expenditures and for updated estimates of future cumulative throughput volumes and capital and operating expenditures. The disposal service fee recalculation mechanism, in contrast, may be adjusted annually only by the applicable inflation escalator, which shall not exceed 3% for any given year. The initial term for the water services agreements is 14 years and we have the unilateral right to extend the water services agreements for one additional 10‑year term. Thereafter, the water services agreements will renew for successive yearly periods unless terminated by either party.

See Note 4, Related Party Transactions in Notes to Consolidated Financial Statements for further discussion of our related party agreements and amounts paid thereunder.

Our board of directors has adopted a related party transactions policy that provides that our board of directors or its authorized committee will review on at least a quarterly basis all related person transactions that are required to be disclosed under SEC rules and, when appropriate, initially authorize or ratify all such transactions. In the event that our board of directors or its authorized committee considers ratification of a related person transaction and determines not to so ratify, our Code of Business Conduct and Ethics provides that our management will make all reasonable efforts to cancel or annul the transaction.

The related party transactions policy provides that, in determining whether or not to recommend the initial approval or ratification of a related person transaction, our board of directors or its authorized committee should consider all of the relevant facts and circumstances available, including (if applicable) but not limited to: (i) whether there is an appropriate business justification for the transaction; (ii) the benefits that accrue to us as a result of the transaction; (iii) the terms available to unrelated third parties entering into similar transactions; (iv) the impact of the transaction on a director’s independence (in the event the related person is a director, an immediate family member of a director or an entity in which a director or an immediate family member of a director is a partner, shareholder, member or executive officer); (v) the availability of other sources for comparable products or services; (vi) whether it is a single transaction or a series of ongoing, related transactions; and (vii) whether entering into the transaction would be consistent with the Code of Business Conduct and Ethics.

Please see Item 10. Directors, Executive Officers and Corporate Governance for information on director independence required by Item 407(a) of Regulation S‑K.

The table below sets forth the aggregate fees and expenses for professional services performed by our independent registered public accounting firm Ernst & Young LLP:

Audit Fees for the fiscal years ended December 31, 2019 and 2018 were for professional services rendered for the audit of our annual financial statements and of our internal control over financial reporting and quarterly review of the financial statements included in our Quarterly Reports on Form 10-Q.

Audit-Related Fees are fees not included in audit fees that are billed by the independent accountant for assurance and related services that are reasonably related to the performance of the audit or review of our financial statements, which include procedures in connection with registration statements subsequent to the Restructuring.

The audit committee of our board of directors has the sole authority to (i) retain and terminate our independent registered public accounting firm, (ii) approve all auditing services and related fees and the terms thereof performed by our independent registered public accounting firm and (iii) pre‑approve any non‑audit services and tax services to be rendered by our independent registered public accounting firm.

For the year ended December 31, 2019, the audit committee of the board of directors of our general partner approved 100% of the fees for the services described above.

The audit committee of our board of directors has approved the appointment of Ernst &Young LLP as independent registered public accounting firm to conduct the audit of the Company’s consolidated financial statements for the year ended December 31, 2020.

The financial statements filed as part of this Annual Report on Form 10-K are listed in the accompanying index to financial statements and schedules in Item 8. Financial Statements and Supplementary Data.

All other financial statement schedules required under SEC rules that are not included in this Annual Report on Form 10-K, are omitted either because they are not applicable or the required information is contained in Item 8. Financial Statements and Supplementary Data.

The exhibits required to be filed pursuant to Item 15(b) of Form 10-K are listed in the Exhibit Index filed herewith, which Exhibit Index is incorporated herein by reference.

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized, on the 21^st day of February 2020.

Each person whose signature appears below constitutes and appoints Jonathan C. Stein, Timothy B. Goodell and John P. Rielly or any of them, his true and lawful attorneys-in-fact and agents, with full power of substitution and resubstitution, for him and in his name, place and stead, in any and all capacities, to sign any and all amendments to Annual Report on Form 10-K, and to file the same, with all exhibits thereto, and other documents in connection therewith with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents, and each of them, full power and authority to do and to perform each and every act and thing requisite and necessary to be done in and about the premises, as fully and to all intents and purposes as he might or would do in person, hereby ratifying and confirming all that said attorneys-in-fact and agents or any of them, or their or his substitute or substitutes, may lawfully do or cause to be done by virtue hereof.

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 and in the capacities and on the dates indicated.

DELAWARE	84-3211812
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification Number)

1501 McKinney Street	77010
Houston, TX (Address of principal executive offices)	(Zip Code)

		Page
PART I
ITEMS 1 and 2.	Business and Properties	5
ITEM 1A.	Risk Factors	21
ITEM 1B.	Unresolved Staff Comments	36
ITEM 3.	Legal Proceedings	36
ITEM 4.	Mine Safety Disclosures	36
PART II
ITEM 5.	Market for Registrant’s Common Equity, Related Shareholder Matters and Issuer Purchases of Equity Securities	37
ITEM 6.	Selected Financial Data	40
ITEM 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	41
ITEM 7A.	Quantitative and Qualitative Disclosures About Market Risk	55
ITEM 8.	Financial Statements and Supplementary Data	56
ITEM 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	89
ITEM 9A.	Controls and Procedures	89
ITEM 9B.	Other Information	89
PART III
ITEM 10.	Directors, Executive Officers and Corporate Governance	90
ITEM 11.	Executive Compensation	94
ITEM 12.	Security Ownership of Certain Beneficial Owners and Management and Related Shareholder Matters	98
ITEM 13.	Certain Relationships and Related Party Transactions and Director Independence	100
ITEM 14.	Principal Accounting Fees and Services	103
PART IV
ITEM 15.	Exhibits and Financial Statement Schedules	104
ITEM 16.	Form 10-K Summary	106
	Signatures	107

Asset	Commodity	Description	Approximate Miles of Pipelines	Approximate Throughput Capacity	Third-Party and Affiliate Connections
Natural gas gathering pipelines	Natural gas NGLs	Natural gas and NGL gathering	1,350 miles	450 MMcf/d	Upstream: Hess and third-party wells Downstream: Tioga Gas Plant; LM4 plant; third-party facilities
Natural gas compression	Natural gas NGLs	Gas compression; NGL extraction	-	240 MMcf/d ⁽¹⁾
Crude oil gathering pipelines	Crude oil	Crude oil gathering	550 miles	240 MBbl/d ⁽²⁾	Upstream: Hess and third-party wells Downstream: Ramberg Terminal Facility; Tioga Rail Terminal; Johnson's Corner Header System
Hawkeye Oil Facility	Crude oil	Pump station; truck unloading	-	75 MBbl/d
Water gathering pipelines	Water	Produced water gathering	250 miles	-	Upstream: Hess and third-party wells Downstream: Hess and third-party water disposal facilities
Water disposal facilities	Water	Produced water disposal	-	20 MBbl/d

Asset	Commodity	Description	Approximate Throughput Capacity	Approximate Storage Capacity	Third-Party and Affiliate Connections
Tioga Gas Plant	Natural gas	Cryogenic	250 MMcf/d	-	Upstream: Natural gas gathering systems Downstream: Third-party long-haul pipelines
	NGLs	Fractionation	60 MBbl/d	90 MBbls ⁽²⁾	Downstream: Alliance Pipeline (propane); Vantage Pipeline (ethane); Tioga Rail Terminal; truck loading
	CNG	Compression	20 MGal/d ⁽³⁾	-	Upstream: Tioga Gas Plant Downstream: Truck loading; light duty vehicles
Little Missouri 4	Natural gas	Cryogenic	100 MMcf/d⁽¹⁾	-	Upstream: Natural gas gathering systems Downstream: Northern Border Pipeline
	NGLs	Cryogenic	40 MBbl/d	-	Downstream: ONEOK Elk Creek Pipeline
Mentor Storage Terminal	Propane	Storage; rail and truck loading and unloading	6 MBbl/d	330 MBbls ⁽⁴⁾	BNSF Railway; truck loading

Asset	Commodity	Description	Approximate Throughput Capacity	Approximate Storage Capacity	Third-Party and Affiliate Connections
Ramberg Terminal Facility	Crude oil	Truck unloading bays; pipeline connections	285 MBbl/d ⁽¹⁾	40 MBbls ⁽²⁾	Upstream: Crude oil gathering system Downstream: Tioga Rail Terminal connection; third-party long-haul pipelines
Tioga Rail Terminal	Crude oil NGLs	Dual loop Ladder track	140 MBbl/d 30 MBbl/d	290 MBbls ⁽³⁾	Upstream: Crude oil gathering system; Tioga Gas Plant; Ramberg Terminal Facility Downstream: BNSF Railway
Crude oil rail cars	Crude oil	Rail cars ⁽⁴⁾	32 MBbl/d ⁽⁵⁾	-
Johnson's Corner Header System	Crude oil	Pipeline connections	100 MBbl/d ⁽⁶⁾	-	Upstream: Crude oil gathering system; third-party gathering systems Downstream: Third-party long-haul pipelines

Title of each class	Trading Symbol(s)		Name of each exchange on which registered
Class A shares representing limited partner interests	HESM		New York Stock Exchange

Large accelerated filer	☐	Accelerated filer	☒

Non-accelerated filer	☐	Smaller reporting company	☐
		Emerging growth company	☐

					Remaining	Renewal
	Hess Minimum Volume Commitment⁽¹⁾			Initial Term	Initial Term	Term
Agreement	2020	2021	2022	(years)⁽²⁾	(years)⁽²⁾	(years)⁽³⁾
Gas Gathering Agreement - MMcf/d of gas	312	323	360	10	4	10
Crude Oil Gathering Agreement - MBbl/d of crude oil	126	130	117	10	4	10
Gas Processing and Fractionation Agreement - MMcf/d of gas	266	292	345	10	4	10
Terminaling and Export Services Agreement⁽⁴⁾ - MBbl/d of crude oil	143	153	145	10	4	10
Water Services Agreement⁽⁵⁾ - MBbl/d of water	69	84	67	14	13	10

	Quarterly Cash
Quarter Ended	Distribution per Unit/Share⁽¹⁾
June 30, 2017⁽²⁾	$	0.2703
September 30, 2017	$	0.3107
December 31, 2017	$	0.3218
March 31, 2018	$	0.3333
June 30, 2018	$	0.3452
September 30, 2018	$	0.3575
December 31, 2018	$	0.3701
March 31, 2019	$	0.3833
June 30, 2019	$	0.3970
September 30, 2019	$	0.4112
December 31, 2019	$	0.4258

		Page
Report of Independent Registered Public Accounting Firm		57
Consolidated Balance Sheets as of December 31, 2019 and 2018		59
Consolidated Statements of Operations for the Years Ended December 31, 2019, 2018 and 2017		60
Consolidated Statements of Comprehensive Income for the Years Ended December 31, 2019, 2018, and 2017		61
Consolidated Statements of Changes in Partners’ Capital for the Years Ended December 31, 2019, 2018 and 2017		62
Consolidated Statements of Cash Flows for the Years Ended December 31, 2019, 2018 and 2017		64
Notes to Consolidated Financial Statements		65
Note 1 Description of Business		65
Note 2 Summary of Significant Accounting Policies and Basis of Presentation		66
Note 3 Acquisitions		70
Note 4 Related Party Transactions		77
Note 5 Property, Plant and Equipment		79
Note 6 Accrued Liabilities and Other Current Liabilities		79
Note 7 Debt and Interest Expense		80
Note 8 Distributions		81
Note 9 Unit-Based Compensation		82
Note 10 Earnings per Share/Limited Partner Unit		83
Note 11 Concentration of Credit Risk		83
Note 12 Commitments and Contingencies		84
Note 13 Segments		84
Note 14 Financial Risk Management Activities		86
Note 15 Income Taxes		86
Note 16 Subsequent Events		87
Supplemental Quarterly Financial Information		88

Period	Record Date	Distribution Date	Distribution per Common and Subordinated Unit/Class A Share
First Quarter 2018	May 4, 2018	May 14, 2018	$0.3333
Second Quarter 2018	August 2, 2018	August 13, 2018	$0.3452
Third Quarter 2018	November 5, 2018	November 13, 2018	$0.3575
Fourth Quarter 2018	February 4, 2019	February 13, 2019	$0.3701
First Quarter 2019	May 3, 2019	May 14, 2019	$0.3833
Second Quarter 2019	August 5, 2019	August 13, 2019	$0.3970
Third Quarter 2019	November 4, 2019	November 13, 2019	$0.4112
Fourth Quarter 2019⁽¹⁾	February 6, 2020	February 14, 2020	$0.4258

Type of Distributions	Period	Distribution to Hess Corporation		Distribution to GIP		Total Distributions
HIP LP Distributions	Second Quarter 2017		27.1		22.9	$	50.0
HIP LP Distributions	Third Quarter 2017		25.0		25.0	$	50.0
HIP LP Distributions	Fourth Quarter 2018		160.0		162.0	$	322.0

		Weighted Average
		Award Date
	Number of Shares	Fair Value
Outstanding and unvested shares/units at December 31, 2018	114,237	$21.06
Granted	74,528	22.76
Forfeited	(4,427)	21.36
Vested	(48,278)	21.15
Outstanding and unvested shares at December 31, 2019	136,060	$21.95

	Year Ended December 31,
	2019 ⁽¹⁾				2018 ⁽²⁾				2017 ⁽²⁾
U.S. statutory rate		21.0		%		21.0		%		35.0		%
Non-taxable income from pre-Restructuring period		(21.4	)			(20.6	)			(37.6	)
Change in enacted tax laws		-				-				(1.7	)
Noncontrolling interest in partnership		0.4				-				-
Valuation allowance		-				(0.4	)			4.3
Effective rate		-		%		-		%		-		%
(1) Represents effective income tax rate reconciliation for Hess Midstream LP.
(2) Represents effective income tax rate reconciliation for the pre-Restructuring period, inclusive of stand-alone income tax provision for Hess Water Services.

	December 31,
	2019⁽¹⁾		2018⁽²⁾
(in millions)
Deferred tax liabilities
Investments	$	0.2	$	-
Property, plant and equipment		-		10.7
Total deferred tax liabilities		0.2		10.7
Deferred tax assets
Investments		49.8		-
Net operating loss carryforwards		0.2		16.9
Asset retirement obligations		-		0.2
Total deferred tax assets		50.0		17.1
Valuation allowance		-		(6.4	)
Total deferred tax assets, net of valuation allowance		50.0		10.7
Net deferred tax assets (liabilities)	$	49.8	$	-
(1) Represents components of deferred tax assets and liabilities for Hess Midstream LP.
(2) Represents components of deferred tax assets and liabilities for Hess Water Services.


Name	Age		Position with Hess Midstream GP LLC
John B. Hess		65	Chairman of the Board of Directors and Chief Executive Officer
John A. Gatling		46	President and Chief Operating Officer
Jonathan C. Stein		50	Chief Financial Officer
Timothy B. Goodell		62	General Counsel and Secretary
John P. Rielly		57	Director and Vice President
Gregory P. Hill		58	Director
Michael R. Turner		60	Director
William J. Brilliant		44	Director
Scott E. Telesz		52	Director
Matthew C. Harris		59	Director
David W. Niemiec		70	Director
John P. Reddy		67	Director
Stephen J. J. Letwin		64	Director

Name	Grant Date		All Other Unit Awards: Number of Units (#)		Grant Date Fair Value of Unit Awards ($)⁽¹⁾
John B. Hess		-		-	$	-
Jonathan C. Stein	3/8/2019			10,984	$	249,996
John A. Gatling	3/8/2019			10,984	$	249,996
Timothy B. Goodell		-		-	$	-
John P. Rielly		-		-	$	-

Name	Number of shares that have not vested⁽¹⁾		Market value of shares that have not vested⁽²⁾
John B. Hess		-	$	-
Jonathan C. Stein		20,560	$	466,301
John A. Gatling		20,560	$	466,301
Timothy B. Goodell		-	$	-
John P. Rielly		-	$	-

	Unit Awards
Name	Number of shares acquired on vesting (#)		Value realized on vesting ($)⁽¹⁾
John B. Hess		-	$	-
Jonathan C. Stein		5,512	$	123,323
John A. Gatling		5,512	$	123,323
Timothy B. Goodell		-	$	-
John P. Rielly		-	$	-

Name	Phantom Units ($)		Total ($)
John B. Hess		-		-
Jonathan C. Stein	$	466,301	$	466,301
John A. Gatling	$	466,301	$	466,301
Timothy B. Goodell		-		-
John P. Rielly		-		-

Name	Fees Earned or Paid in Cash		Unit Awards⁽¹⁾			Total
David W. Niemiec	$	80,000		$	65,003	$	145,003
John P. Reddy	$	65,000		$	65,003	$	130,003
Stephen J. J. Letwin	$	73,167		$	65,003	$	138,170

	Year Ended December 31,
(in thousands)	2019		2018
Audit Fees	$	1,324	$	1,285
Audit Related Fees		86		-
Tax Fees		-		-
Other Fees		-		-
Total Fees	$	1,410	$	1,285


Exhibit Number		Exhibit Description
2.1		Partnership Restructuring Agreement, dated as of October 3, 2019, by and among Hess Midstream Partners LP, Hess Midstream Partners GP LP, Hess Midstream Partners GP LLC, Hess Infrastructure Partners LP, Hess Infrastructure Partners GP LLC, Hess Midstream LP, Hess Midstream GP LP, Hess Midstream GP LLC, Hess Midstream New Ventures II, LLC, Hess Investments North Dakota LLC, GIP II Blue Holding Partnership, L.P., and Hess Infrastructure Partners Holdings LLC (incorporated by reference herein to Exhibit 2.1 to the Predecessor’s Current Report on Form 8-K (File No. 001-38050) filed on October 4, 2019)
2.2		Agreement and Plan of Merger, dated as of October 3, 2019, by and among Hess Midstream Partners LP, Hess Midstream Partners GP LP, Hess Infrastructure Partners GP LLC, Hess Midstream LP, Hess Midstream GP LP, and Hess Midstream New Ventures II, LLC (incorporated by reference herein to Exhibit 2.2 to the Predecessor’s Current Report on Form 8-K (File No. 001-38050) filed on October 4, 2019)
3.1		Certificate of Limited Partnership of Hess Midstream LP, dated as of September 27, 2019 (incorporated by reference herein to Exhibit 3.1 to the Company’s Registration Statement on Form S-4 (File No. 333-234095) filed on October 4, 2019)
3.2		Amended and Restated Agreement of Limited Partnership of Hess Midstream LP, dated as of December 16, 2019 (incorporated by reference herein to Exhibit 3.1 to the Company’s Current Report on Form 8-K12B (File No. 001-39163) filed on December 17, 2019)
4.1		Credit Agreement, dated as of December 16, 2019, by and among Hess Midstream Operations LP, JPMorgan Chase Bank, N.A. and the other parties thereto (incorporated by reference herein to Exhibit 4.1 to Predecessor’s Current Report on Form 8-K (File No. 001-38050) filed on December 16, 2019)
4.2		Indenture, dated as of December 16, 2019, by and among Hess Midstream Operations LP, Wells Fargo Bank, National Association, as trustee and certain guarantors party thereto (incorporated by reference herein to Exhibit 4.2 to Predecessor’s Current Report on Form 8-K (File No. 001-38050) filed on December 16, 2019)
4.3		Indenture, dated as of December 10, 2019, by and between Hess Midstream Partners LP and Wells Fargo Bank, National Association, as trustee (incorporated by reference herein to Exhibit 4.1 to Predecessor’s Current Report on Form 8-K (File No. 001-38050) filed on December 10, 2019)
4.4		Indenture, dated as of November 22, 2017, by and among Hess Infrastructure Partners LP, Hess Infrastructure Partners Finance Corporation, Wells Fargo Bank, National Association, as trustee, and certain guarantors party thereto (incorporated by reference herein to Exhibit 4.3 to Predecessor’s Current Report on Form 8-K (File No. 001-38050) filed on December 16, 2019)
4.5		First Supplemental Indenture, dated November 1, 2019 to the Indenture, dated as of November 22, 2017, by and among Hess Infrastructure Partners LP, Hess Infrastructure Partners Finance Corporation, Wells Fargo Bank, National Association, as trustee, and certain guarantors party thereto (incorporated by reference herein to Exhibit 4.4 to Predecessor’s Current Report on Form 8-K (File No. 001-38050) filed on December 16, 2019)


4.6		Second Supplemental Indenture, dated December 16, 2019 to the Indenture, dated as of November 22, 2017, by and among Hess Midstream Operations LP, Hess Infrastructure Partners LP, Hess Infrastructure Partners Finance Corporation, Wells Fargo Bank, National Association, as trustee, and certain guarantors party thereto (incorporated by reference hereinto Exhibit 4.5 to Predecessor’s Current Report on Form 8-K (File No. 001-38050) filed on December 16, 2019)
4.7		First Supplemental Indenture, dated December 16, 2019 to the Indenture, dated as of December 10, 2019, by and among Hess Midstream Operations LP, Wells Fargo Bank, National Association, as trustee, and certain guarantors party thereto (incorporated by reference herein to Exhibit 4.6 to Predecessor’s Current Report on Form 8-K (File No. 001-38050) filed on December 16, 2019)
4.8		Description of Class A Shares (incorporated by reference herein to Exhibit 99.1 to the Company’s Current Report on Form 8-K12B (File No. 001-39163) filed on December 17, 2019)
10.1		Amended and Restated Omnibus Agreement, dated December 16, 2019, by and among Hess Corporation, Hess Infrastructure Partners GP LLC, Hess Midstream LP, Hess Midstream GP LP, Hess Midstream GP LLC, Hess Midstream Operations LP, Hess Midstream Partners GP LP, Hess Midstream Partners GP LLC, and, for the limited purposes specified therein, Hess Investments North Dakota LLC and GIP II Blue Holding Partnership, L.P. (incorporated by reference herein to Exhibit 10.1 to the Predecessor’s Current Report on Form 8-K (File No. 001-38050) filed on December 16, 2019)
10.2		Amended and Restated Employee Secondment Agreement, dated as of December 16, 2019, by and among Hess Corporation, Hess Trading Corporation, Hess Midstream GP LP, Hess Midstream GP LLC, and, for the limited purposes specified therein, Hess Midstream Partners GP LP, and Hess Midstream Partners GP LLC (incorporated by reference herein to Exhibit 10.2 to the Company’s Current Report on Form 8-K12B (File No. 001-39163) filed on December 17, 2019)
10.3		Amended and Restated Registration Rights Agreement, dated December 16, 2019, by and among Hess Midstream LP, Hess Midstream GP LP, Hess Midstream GP LLC, Hess Investments North Dakota LLC and GIP II Blue Holding Partnership, L.P. (incorporated by reference herein to Exhibit 10.3 to the Company’s Current Report on Form 8-K12B (File No. 001-39163) filed on December 17, 2019)
10.4		Third Amended and Restated Agreement of Limited Partnership of Hess Midstream Operations LP (formerly known as Hess Midstream Partners LP), dated as of December 16, 2019 (incorporated by reference herein to Exhibit 3.2 to the Predecessor’s Current Report on Form 8-K (File No. 001-38050) filed on December 16, 2019)
10.5^#		Hess Midstream LP 2017 Long Term Incentive Plan (incorporated by reference herein to Exhibit 10.5 to the Company’s Current Report on Form 8-K12B (File No. 001-39163) filed on December 17, 2019)
10.6^#		Form of Phantom Unit Agreement (incorporated by reference herein to Exhibit 10.14 to the Predecessor’s Registration Statement on Form S‑1 (File No. 333‑198896) filed on February 13, 2017)
10.7^†		Second Amended and Restated Terminal and Export Services Agreement, effective as of January 1, 2014, by and between Hess Trading Corporation and Hess North Dakota Export Logistics LLC (incorporated by reference herein to Exhibit 10.8.1 to the Predecessor’s Registration Statement on Form S‑1 (File No. 333‑198896) filed on March 16, 2017).
10.8^†		Storage Services Agreement, effective as of January 1, 2014, by and between Solar Gas, Inc. and Hess Mentor Storage LLC (incorporated by reference herein to Exhibit 10.9 to the Predecessor’s Registration Statement on Form S‑1 (File No. 333‑198896) filed on March 16, 2017).
10.9^†		Amended and Restated Crude Oil Gathering Agreement, effective as of January 1, 2014, by and between Hess Trading Corporation and Hess North Dakota Pipelines LLC (incorporated by reference herein to Exhibit 10.10 to the Predecessor’s Registration Statement on Form S‑1 (File No. 333‑198896) filed on March 16, 2017).
10.10^†		Second Amended and Restated Gas Processing and Fractionation Agreement effective as of January 1, 2014 by and between Hess Trading Corporation and Hess Bakken Processing LLC (Incorporated by reference herein to Exhibit 10.1 to the Predecessor’s Current Report on Form 8-K (File No. 001-38050) filed on September 21, 2018).
10.11^†		Second Amended and Restated Gas Gathering Agreement effective as of January 1, 2014 by and between Hess Trading Corporation and Hess North Dakota Pipelines LLC (incorporated by reference herein to Exhibit 10.2 to the Predecessor’s Current Report on Form 8-K (File No. 001-38050) filed on September 21, 2018).
21.1		Subsidiaries of Hess Midstream LP


23.1		Consent of Independent Registered Public Accounting Firm
24.1		Power of Attorney (set forth on the signature page hereof)
31.1		Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.2		Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32.1		Certification Pursuant to 18 U.S.C Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2		Certification Pursuant to 18 U.S.C Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

101(INS)		XBRL Instance Document
101(SCH)		XBRL Schema Document
101(CAL)		XBRL Calculation Linkbase Document
101(LAB)		XBRL Labels Linkbase Document
101(PRE)		XBRL Presentation Linkbase Document
101(DEF)		XBRL Definition Linkbase Document
†Confidential treatment has been granted for certain portions of this exhibit pursuant to a confidential treatment order granted by the Securities and Exchange Commission. Such provisions have been omitted and filed separately with the Securities and Exchange Commission.
# Compensatory plan or arrangement.

		Hess Midstream LP (Registrant)
By:		Hess Midstream GP LP, its general partner
By:		Hess Midstream GP LLC, its general partner

By:		/s/ John B. Hess
		John B. Hess,
		Chairman of the Board of Directors and Chief Executive Officer


Signature	Title	Date
/s/ John B. Hess	Chairman and Chief Executive Officer (Principal Executive Officer)	February 21, 2020
John B. Hess


/s/ Jonathan C. Stein	Chief Financial Officer (Principal Financial and Accounting Officer)	February 21, 2020
Jonathan C. Stein
/s/ John P. Rielly	Director and Vice President	February 21, 2020
John P. Rielly
/s/ Gregory P. Hill	Director	February 21, 2020
Gregory P. Hill
/s/ Michael R. Turner	Director	February 21, 2020
Michael R. Turner
/s/ William J. Brilliant	Director	February 21, 2020
William J. Brilliant
/s/ Scott E. Telesz	Director	February 21, 2020
Scott E. Telesz
/s/ Matthew C. Harris	Director	February 21, 2020
Matthew C. Harris
/s/ David W. Niemiec	Director	February 21, 2020
David W. Niemiec
/s/ John P. Reddy	Director	February 21, 2020
John P. Reddy
/s/ Stephen J.J. Letwin	Director	February 21, 2020
Stephen J.J. Letwin