Kinder Morgan Declares Dividend of $0.125 for Third Quarter of 2017

Remains on Track to Return Value to Stockholders in 2018

HOUSTON–(BUSINESS WIRE)–$KMI #KinderMorgan–Kinder Morgan, Inc. (NYSE: KMI) today announced that its board of directors approved a cash dividend of $0.125 per share for the third quarter ($0.50 annualized) payable on November 15, 2017, to common stockholders of record as of the close of business on October 31, 2017. KMI continues to expect to declare dividends of $0.50 per share for 2017 before increasing the dividend to $0.80 per share for 2018 ($0.20 per share for Q1 2018). KMI also continues to expect to use cash in excess of dividend payments to fully fund growth investments, further strengthening its balance sheet.

“We remain on track to return increasing value to stockholders in 2018 through the combination of an attractive and growing dividend as well as the share repurchase program we announced last quarter. Our goal of maintaining robust dividend coverage while delivering a substantial dividend increase to stockholders out of operating cash flows in excess of growth capital remains clearly in sight,” said Richard D. Kinder, executive chairman.

“At the same time, we continue the important work of strengthening our balance sheet, continuing to fund all growth capital through operating cash flows with no need for external funding for growth capital,” said Kinder. “We continue to expect to end 2017 at a 5.2 times Net Debt-to-Adjusted EBITDA ratio, lower than our budget, and are confident of achieving our longer term leverage target of approximately 5.0 times. We are extremely pleased with the company’s financial strength and operational excellence.”

President and CEO Steve Kean said, “We had a solid third quarter, especially in the face of multiple named storms, including a historic rainfall event associated with Hurricane Harvey. Hundreds of our employees and their families were affected by these storms, but they and the assets they operate proved resilient and strong. Our response was robust and impacts on our customers and operations were minimized. We generated earnings per common share for the quarter of $0.15 and distributable cash flow (DCF) of $0.47 per common share, resulting in $774 million of excess DCF above our dividend.”

Kean added, “We continue to drive future growth by completing significant infrastructure development projects that we track as part of our project backlog. Our current project backlog is essentially flat quarter-to-quarter at $12.0 billion, with the small decrease primarily due to projects going into service. Excluding the CO₂ segment projects, we expect the projects in our backlog to generate an average capital-to-EBITDA multiple of approximately 6.8 times.”

KMI reported third quarter net income available to common stockholders of $334 million, compared to a net loss available to common stockholders of $227 million for the third quarter of 2016, and DCF of $1,055 million, down slightly from $1,081 million for the comparable period in 2016. The decrease in DCF was driven by: lower contributions from Southern Natural Gas Company (SNG) as a result of the 50 percent sale of SNG during the third quarter of 2016; reduced revenue due to Hurricane Harvey; a contribution to KMI’s pension plan; a reduction in contributions from KMI’s Canadian assets due to the successful second quarter initial public offering (IPO) of Kinder Morgan Canada Limited (KML); and higher sustaining capex. These reductions were partially offset by lower interest expense and higher contributions from Tennessee Gas Pipeline (TGP). Net income available to common stockholders was also impacted by a $576 million favorable change in total Certain Items (as described under “Non-GAAP Financial Measures” below) compared to the third quarter of 2016. Third quarter 2016 Certain Items were driven in part by an asset write-down in that quarter.

For the first nine months of 2017, KMI reported net income available to common stockholders of $1,072 million, up substantially compared to $382 million for the first nine months of 2016, and DCF of $3,292 million that was down from $3,364 million for the comparable period in 2016. The decrease in DCF was driven by the sale of 50 percent of SNG, the impacts of Harvey, the contribution to KMI’s pension plan, the KML IPO, and higher sustaining capex, partially offset by lower interest expense and lower general and administrative expenses. Net income available to common stockholders was also impacted by a $764 million decrease in total Certain Items compared to the first nine months of 2016. Certain Items in the first nine months of 2016 were driven by an asset write-down and project write-offs.

2017 Outlook

For 2017, KMI’s budget was set to declare dividends of $0.50 per common share, achieve DCF of approximately $4.46 billion ($1.99 per common share) and Adjusted EBITDA of approximately $7.2 billion. KMI also budgeted to invest $3.2 billion in growth projects during 2017, to be funded with internally generated cash flow without the need to access equity markets, and to end the year with a Net Debt-to-Adjusted EBITDA ratio of approximately 5.4 times.

As a result of the successful IPO of its Canadian assets and impacts from Hurricane Harvey, KMI now expects to end the year with: a Net Debt-to-Adjusted EBITDA ratio of approximately 5.2 times, as proceeds from the KML IPO were used to pay down debt; growth capital investment of $3.1 billion; and DCF less than 1 percent below budget. The $3.1 billion in growth capital does not include KML-related expansion capex as KML is a self-funding entity and KMI does not anticipate making further contributions. Excluding the full-year impacts of KMI’s sale of a 30 percent interest in its Canadian assets in the IPO (approximately $22 million) and Hurricane Harvey, DCF is forecasted to be on plan. KMI estimates that Hurricane Harvey will have a 2017 DCF impact of approximately $20 million, excluding repair costs that are treated as Certain Items. KMI expects that these repair costs, both those incurred in the third quarter and those expected to be incurred in the fourth quarter, will largely be recovered from insurance proceeds. KMI does not provide budgeted net income attributable to common stockholders (the GAAP financial measure most directly comparable to DCF and Adjusted EBITDA) due to the inherent difficulty and impracticality of predicting certain amounts required by GAAP, such as ineffectiveness on commodity, interest rate and foreign currency hedges, unrealized gains and losses on derivatives marked to market, and potential changes in estimates for certain contingent liabilities.

KMI’s expectations assume average annual prices for West Texas Intermediate (WTI) crude oil of $53 per barrel and Henry Hub natural gas of $3 per MMBtu, consistent with forward pricing during the company’s budget process. The vast majority of cash KMI generates is fee-based and therefore not directly exposed to commodity prices. The primary area where KMI has commodity price sensitivity is in its CO₂ segment, with the majority of the segment’s next 12 months of oil and NGL production hedged to minimize this sensitivity. The segment is currently hedged for 34,200 barrels per day (Bbl/d) at $58.91/Bbl for the remainder of the year, as well as 23,532 Bbl/d at $59.03/Bbl in 2018; 13,100 Bbl/d at $55.34/Bbl in 2019; 7,300 Bbl/d at $53.08/Bbl in 2020; and 2,400 Bbl/d at $52.45/Bbl in 2021.

Overview of Business Segments

“The Natural Gas Pipelines segment’s performance for the third quarter of 2017 relative to the third quarter of 2016 was impacted by the third quarter 2016 sale of a 50 percent interest in SNG, Harvey-related and other declines from reduced volumes on many of our midstream gathering and processing assets, and a negative impact on our Colorado Interstate Gas Company (CIG) pipeline tariff rates as a result of a rate case settlement reached during 2016. The segment again benefited from increased contributions from TGP driven by incremental short-term capacity sales and projects placed in service; from the Elba Express pipeline, resulting from the completion of an expansion project; and from El Paso Natural Gas (EPNG) due to additional Permian capacity sales and the completion of an expansion project,” Kean said.

Natural gas transport volumes were up 3 percent compared to the third quarter of 2016, driven by higher throughput on the Texas Intrastate Natural Gas Pipelines from incremental transportation contracts serving Mexico and contracts going into effect after the third quarter of 2016, as well as higher throughput on EPNG as noted above, and higher throughput on Elba Express resulting from the expansion on that system. The increases were partially offset by lower throughput on TransColorado, due to lower Rockies production, on Cheyenne Plains due to mild weather and fuel switching to coal, and on Citrus, also due to mild weather. Natural gas gathering volumes were down 14 percent from the third quarter of 2016 due primarily to Hurricane Harvey impacts and to lower natural gas volumes on multiple systems gathering from the Eagle Ford Shale and on the KinderHawk system.

Natural gas is critical to the American economy and to meeting the world’s evolving energy and manufacturing needs. Objective analysts project U.S. natural gas demand, including net exports of liquefied natural gas (LNG) and net exports to Mexico, will increase by more than 30 percent to greater than 100 billion cubic feet per day (Bcf/d) by 2026. Of the natural gas consumed in the U.S., about 40 percent moves on KMI pipelines. While a substantial majority of natural gas is consumed in industrial, commercial and residential heating uses, KMI expects future natural gas infrastructure opportunities will also be driven by greater demand for gas-fired power generation across the country, LNG exports, exports to Mexico, and continued industrial development, particularly in the petrochemical industry. Compared to the third quarter of 2016, natural gas deliveries on KMI pipelines to Mexico were up 3 percent, and despite some reductions due to Hurricane Harvey, deliveries to the Sabine Pass LNG facility increased by 37 percent.

“The CO₂ segment was impacted by lower commodity prices, as our realized weighted average oil price for the quarter was $58.29 per barrel compared to $62.12 per barrel for the third quarter of 2016,” Kean said. “Combined oil production across all of our fields was down 1 percent compared to 2016 on a net to Kinder Morgan basis. Third quarter 2017 net NGL sales volumes of 9.6 thousand barrels per day (MBbl/d) were down 9 percent from 2016, due to lower hydrocarbon content in the produced gas stream year over year.”

Combined gross oil production volumes averaged 52.9 MBbl/d for the third quarter, down 1 percent from 53.7 MBbl/d for the same period last year. SACROC’s third quarter gross production was 5 percent below third quarter 2016 results but slightly above 2017 budget, and Yates gross production was 4 percent below third quarter 2016 results and below plan. Both decreases were partially driven by reallocating capital to higher return projects with longer lead times. Third quarter gross production from Katz, Goldsmith and Tall Cotton was 21 percent above the same period in 2016, but below plan. Gross NGL sales volumes were 20 MBbl/d during the quarter, 8 percent below third quarter 2016.

“The Terminals segment earnings contributions were essentially flat compared to the third quarter of 2016 despite several strategic divestitures and operational disruptions associated with Hurricane Harvey. Excluding these items, the segment’s earnings would have been higher in the third quarter 2017 by approximately $20 million.

Growth in the liquids business during the quarter versus the third quarter of 2016 was primarily driven by increased contributions from our Jones Act tankers and also benefited from various expansions across our network, including the Kinder Morgan Export Terminal, a 1.5 million-barrel liquids terminal development along the Houston Ship Channel,” Kean said. A new-build Jones Act tanker, the American Liberty, was placed on-hire with a major refiner in the third quarter. All of KMI’s Jones Act tankers are contracted with major energy customers under term charter agreements.

The bulk terminals contribution was down largely due to the impact of certain non-core asset divestitures and disruptions to petcoke handling operations servicing Gulf Coast refiners impacted by Hurricane Harvey, while performance at our coal and steel handling operations continues to benefit from stabilizing global market conditions.

“The Products Pipelines segment contributions were up compared with third quarter 2016 performance due largely to increased throughput on SFPP and Kinder Morgan Southeast Terminals,” Kean said.

Total refined products volumes were up 1 percent for the third quarter versus the same period in 2016. Crude and condensate pipeline volumes were significantly impacted by Hurricane Harvey, down 8 percent from the third quarter of 2016.

Kinder Morgan Canada contributions were up in the third quarter of 2017 compared to the third quarter of 2016 largely due to currency translation gains on strengthening of the Canadian dollar. The business also had higher capitalized equity financing costs (recognized in other income) due to spending on the Trans Mountain expansion project. These positives were partially offset by lower Washington state revenues and timing of operating costs.

Kinder Morgan Canada Limited (KML) includes the Trans Mountain pipeline, the Canadian portion of the Cochin pipeline, the Puget Sound and Trans Mountain Jet Fuel pipelines, the Westridge marine and Vancouver Wharves terminals in British Columbia as well as various crude oil loading facilities in Edmonton, Alberta. KMI owns approximately 70 percent of KML and KML’s results are consolidated in KMI financial statements and reported on a 100 percent basis at the segment level.

Other News

Natural Gas Pipelines

• On Sept. 18, 2017, the Federal Energy Regulatory Commission (FERC) authorized the company to install its 10 modular liquefaction trains for the nearly $2 billion Elba Liquefaction Project at KMI’s existing Southern LNG Company facility at Elba Island near Savannah, Georgia. The federally approved liquefaction project is supported by a 20-year contract with Shell. Initial in-service is expected in mid-2018. Final units coming on line by mid-2019 will bring total liquefaction capacity to approximately 2.5 million tonnes per year of LNG, equivalent to approximately 350 million cubic feet per day of natural gas. Elba Liquefaction Company, L.L.C. (ELC), a KMI joint venture with EIG Global Energy Partners as a 49 percent partner, will own 10 liquefaction units and other ancillary equipment comprising approximately 70 percent of the project. Certain other facilities associated with the project are 100 percent owned by KMI.
• On Aug. 18, 2017, the FERC issued a favorable environmental assessment for the approximately $240 million SNG Fairburn Expansion Project in Georgia. SNG is a joint venture equally owned by subsidiaries of KMI and Southern Company. The project is designed to provide approximately 340,000 dekatherms per day (Dth/d) of incremental long-term firm natural gas transportation capacity into the Southeast market beginning in the fourth quarter of 2018.
• On July 28, 2017, the FERC issued Kinder Morgan Louisiana Pipeline (KMLP) an environmental assessment for its proposed project to provide 600,000 Dth/d of capacity to serve Train 5 at Cheniere’s Sabine Pass LNG Terminal. The approximately $122 million KMLP project is expected to be placed into service in the fourth quarter of 2019.
• All critical path permits have been approved and significant work is underway on TGP’s Broad Run Expansion Project, which is expected to be placed in service in June 2018. The project will provide an incremental 200,000 Dth/d of firm transportation capacity along the same north-south path as the already in-service Broad Run Flexibility Project. Antero Resources was awarded a total of 790,000 Dth/d of 15-year firm capacity under the two projects from a receipt point on TGP’s existing Broad Run Lateral in West Virginia to delivery points in Mississippi and Louisiana. Estimated capital expenditures for the combined projects total approximately $800 million.
• TGP’s approximately $128 million Susquehanna West Project was placed into commercial service ahead of schedule on Sept. 1, 2017. The project provides 145,000 Dth/d of additional capacity to an interconnection with National Fuel Supply in Potter County, Pennsylvania, and is fully subscribed by StatOil Natural Gas LLC.
• Construction is nearly complete on three TGP projects following required regulatory approvals. The following projects are expected to be placed into service in the fourth quarter of 2017:
  • The approximately $99 million Connecticut Expansion Project is fully subscribed and will provide 72,100 Dth/d of capacity for three local distribution company customers in the Northeast. The project is expected to be placed into service in November 2017.
  • The approximately $109 million Orion Project will provide 135,000 Dth/d of capacity for three customers and is ahead of schedule. TGP has reached agreement with the project customers for early in-service which is anticipated as early as December 2017.
  • The approximately $59 million Triad Project will provide 180,000 Dth/d of capacity for one customer and is ahead of schedule. TGP anticipates that the project facilities will be available for service in November 2017, with commercial contracts in service on June 1, 2018, as originally planned.
• On Oct. 4, 2017, Kinder Morgan Texas Pipeline (KMTP), DCP Midstream and an affiliate of Targa Resources Corp. announced they have signed a letter of intent with respect to the joint development of the proposed Gulf Coast Express Pipeline Project (GCX Project), which would provide an outlet for increased natural gas production from the Permian Basin to growing markets along the Texas Gulf Coast. The participation of the three parties involved with the GCX Project is subject to negotiation and execution of definitive agreements among KMTP, DCP Midstream and Targa. As part of the definitive agreements, Targa and DCP Midstream would commit significant volumes to the project, including certain volumes provided by Pioneer Natural Resources Company, a joint owner in Targa’s WestTX Permian Basin system. The capacity of the GCX Project is expected to be approximately 1.92 Bcf/d and would include a lateral into the Midland Basin to serve gas processing facilities owned by Targa as well as facilities owned jointly by Targa and Pioneer. The mostly 42-inch pipeline would traverse approximately 450 miles and be in service in the second half of 2019, pending final shipper commitments and a final investment decision by all three entities. Per the terms of the letter of intent, KMI would build, operate and own a 50 percent interest in the GCX Project, and DCP Midstream and Targa would each hold a 25 percent equity interest in the project.
• Natural Gas Pipeline of America LLC (NGPL) expects the FERC to issue a Certificate of Public Convenience and Necessity for NGPL’s approximately $212 million Gulf Coast Southbound Expansion Project by the end of the year. The project, which is fully subscribed under long-term contracts, is designed to transport 460,000 Dth/d of incremental firm transportation service from NGPL’s interstate pipeline interconnects in Illinois, Arkansas and Texas to points south on NGPL’s pipeline system to serve growing demand in the Gulf Coast area. The project is anticipated to be fully in service by the fourth quarter of 2018.
• NGPL and Wyoming Interstate Company, LLC (WIC) each submitted to the FERC an Offer of Settlement in separate proceedings pursuant to Section 5 of the Natural Gas Act. The presiding administrative law judge in both proceedings certificated the settlements as uncontested, and the companies expect FERC approval by the end of the year. As currently negotiated, the settlements would not have a material adverse impact on KMI’s results of operations or cash flows from operations.

CO₂

• The approximately $66 million second phase of KMI’s Tall Cotton field project is more than 70 percent complete and is experiencing strong initial production results of over 900 Bbls/d of oil. Tall Cotton is the industry’s first greenfield Residual Oil Zone CO₂ project, marking the first time CO₂ has been used for enhanced oil recovery in a field without a main pay zone. Total combined production from the first and second phases of the project currently exceeds 2,300 Bbls/d of oil.
• KMI continues to find high-return enhanced oil recovery projects in the current price environment across its robust portfolio of assets.

Terminals

• Construction continues at the Base Line Terminal, a 50-50 joint venture crude oil merchant storage terminal being developed in Edmonton, Alberta, Canada, by KML and Keyera. In the third quarter, on-site facility mechanical work was materially completed and significant progress was made on the off-site pipe rack and bridges required to connect the terminal with KML’s other Edmonton-area facilities, including its North 40, Edmonton South, and Edmonton Rail terminals. Commissioning of the 12-tank, 4.8 million barrel new-build facility, which is fully contracted with long-term, firm take-or-pay agreements with creditworthy customers, is expected to begin in the first quarter of 2018, with tanks phased into service throughout that year. KML’s investment in the joint venture terminal is approximately C$396 million, including costs associated with the construction of a pipeline segment funded solely by KML, with total spend to date of C$250 million and remaining spend in 2017 of C$33 million. The project is forecast to be on schedule and on budget.
• Work is nearing completion on the Pit 11 expansion project at KMI’s Pasadena terminal. The approximately $186 million project, back-stopped by long-term commitments from existing customers, adds 2.0 million barrels of refined products storage to KMI’s best-in-class liquids storage hub along the Houston Ship Channel. Due to impacts from Hurricane Harvey, the company revised its tank commissioning schedule to place the first four tanks in-service by mid-November 2017, with the balance expected to follow by the end of the year.
• On July 27, 2017, KMI’s American Petroleum Tankers (APT) took delivery of the American Liberty product tanker from Philly Shipyard, Inc. (PSI) and later in the third quarter placed the vessel on-hire pursuant to a term charter agreement with a major refiner. APT’s construction program at PSI is nearing completion with the final tanker scheduled for delivery in the fourth quarter of 2017, bringing APT’s best-in-class fleet to 16 vessels. The entire fleet, including each of the 330,000-barrel capacity and LNG conversion-ready new-build tankers, is fixed under charter with a major energy company.
• On July 21, 2017, KMI closed the sale of a 40 percent interest in the Deeprock Development (Deeprock) crude oil terminal in Cushing, Oklahoma to Tallgrass Terminals, LLC (Tallgrass Terminals), an affiliate of Tallgrass Energy Partners, LP (Tallgrass), for a purchase price of approximately $57 million. KMI retains an 11 percent membership interest in the 2.25-million-barrel facility, and Tallgrass Terminals (69 percent) and Deeprock Energy Resources (20 percent) remain joint venture partners.

Contacts

Kinder Morgan, Inc.
Dave Conover, 713-369-9407
Media Relations
dave_conover@kindermorgan.com
or
Investor Relations
713-369-9490
km_ir@kindermorgan.com
www.kindermorgan.com

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