National Fuel Reports Third Quarter Earnings

National Fuel Gas Company (“National Fuel” or the “Company”) (NYSE:NFG) today announced consolidated results for the third quarter of its 2017 fiscal year and for the nine months ended June 30, 2017.

FISCAL 2017 THIRD QUARTER SUMMARY

• Consolidated net income of $59.7 million, or $0.69 per share, compared to consolidated net income of $8.3 million, or $0.10 per share, and operating results of $58.1 million, or $0.68 per share, in the prior year (see reconciliation below)
• Adjusted EBITDA of $179.0 million versus $189.8 million in the prior year (non-GAAP reconciliation on page 23)
• Gross natural gas production in Appalachia of 567 MMcf per day, a 6% increase from the prior year
• Net production of 42.7 Bcfe, a 3% decrease from prior year
• Average natural gas prices, after the impact of hedging, of $2.94 per Mcf, up $0.08 per Mcf from the prior year
• Average oil prices, after the impact of hedging, of $53.02 per Bbl, down $5.77 per Bbl from the prior year
• Gathering revenues of $26.9 million on 48.8 Bcf of system throughput, both an increase of 5% from the prior year

MANAGEMENT COMMENTS

Ronald J. Tanski, President and Chief Executive Officer of National Fuel Gas Company, stated: “Our fiscal third quarter was a strong one with each of our business segments posting solid financial results that were in-line with expectations. Across the system, our talented teams continue to execute on our operational plans. As is typical during the summer period, our utility and transmission pipeline construction crews are busy maintaining the safety and integrity of our thousands of miles of pipelines that will assure safe, reliable, and affordable natural gas services for our region and local communities.

“As we look ahead, we continue to manage around the delay in the Northern Access Project and see plenty of opportunity in the meantime to extract value from our world class natural gas assets in Appalachia. After a year of testing, we believe we have de-risked the Utica potential in our Western Development Area, adding years of economic drilling inventory on the very same acreage we have already developed for the Marcellus. Over the next 18 months, we will continue to optimize our well designs and transition into a Utica development program that will leverage existing upstream and midstream infrastructure to drive capital, operational, and marketing efficiencies. While the commodities futures markets indicate that Seneca Resources, our exploration and production company, will likely achieve lower prices for its production next year, our proven success in driving down finding and development costs and our ability to develop our upstream and midstream assets efficiently allows us to continue to grow our integrated business, maintain a strong financial position, and add shareholder value throughout the commodity price cycle.”

DISCUSSION OF RESULTS BY SEGMENT

The following discussion of the earnings of each segment is summarized in a tabular form on pages 8 through 11 of this report. It may be helpful to refer to those tables while reviewing this discussion. Note that management defines Operating Results as reported GAAP earnings before items impacting comparability and Adjusted EBITDA as reported GAAP earnings before the following items: interest expense, depreciation and amortization, interest and other income, impairments, items impacting comparability, and income taxes.

Upstream Business

Exploration and Production Segment

The Exploration and Production segment operations are carried out by Seneca Resources Corporation ("Seneca"). Seneca explores for, develops and produces natural gas and oil reserves, primarily in Pennsylvania and California.

Net income for the Exploration and Production segment in the third quarter was $30.1 million, or $0.35 per share, compared to a net loss of $19.2 million, or $0.22 per share, in the prior year third quarter. The $49.3 million increase in the segment’s earnings was primarily attributable to the non-recurrence of two items that reduced earnings in the prior year. In the prior year third quarter, Seneca recorded an $82.7 million ($47.9 million after-tax) ceiling test impairment charge to reduce the book value of Seneca’s oil and gas properties. Seneca also incurred $3.2 million ($1.8 million after-tax) in the prior year third quarter for professional and legal expenses related to the extension of the joint development agreement that Seneca executed in June 2016.

Excluding these items, operating results for the segment declined $0.5 million, or $0.01 per share, as the impact of higher realized natural gas prices, lower depreciation, depletion and amortization (“DD&A”) expense, and a lower effective income tax rate were more than offset by a decline in net natural gas and oil production, lower realized oil prices and an increase in lease operating and transportation (“LOE”) expense.

Over the past two years, Seneca significantly reduced its capital expenditures in response to low commodity prices by entering into a Joint Development Agreement (“JDA”), where a partner agreed to participate in 75 new Marcellus wells as an 80 percent working interest owner, and reducing the rig count in Appalachia and activity in California. As a result, Seneca's net natural gas and oil production declined 1.3 billion cubic feet equivalent ("Bcfe"), or 3 percent, to 42.7 Bcfe in the third quarter. Net natural gas production was down nearly 1.0 Bcf due mainly to a lower average revenue interest on production from the Western Development Area (“WDA”) resulting from new JDA wells as well as natural declines in Marcellus production from the Eastern Development Area (“EDA”). Seneca’s oil production decreased 58 thousand barrels ("Mbbl") due mainly to temporary changes in steam operations and a reduction in well workover activity at its North Midway Sunset field in California, offset partially by increased activity at South Midway Sunset.

Seneca continues to grow its base of gross natural gas production. Average daily gross natural gas production during the quarter increased 6 percent to 567 million cubic feet (“MMcf’) per day driven primarily by new Marcellus and Utica wells in Appalachia. In the WDA, average daily natural gas production increased approximately 38 MMcf per day, or 16 percent, to 284 MMcf per day during the quarter. Seneca is now producing from 63 of the 75 Marcellus wells that are being developed in the Clermont / Rich Valley area under the JDA entered into with a partner in fiscal 2016. The 12 remaining JDA wells are expected to be completed and brought on-line in the first half of fiscal 2018.

In the EDA, average daily gross natural gas production decreased 4 MMcf per day, or 1 percent, to 283 MMcf per day as natural declines in Marcellus production from Tioga and Lycoming counties were partially offset by new production from the Company’s Utica well on DCNR Tract 007 in Tioga County, Pa., which has produced nearly 2.5 Bcf since it was first turned on-line in November 2016. In May, Seneca added a second rig and resumed Marcellus development activities in Lycoming County, Pa., which is expected to arrest natural production declines and maintain a base of production that will utilize firm transportation capacity on the Atlantic Sunrise pipeline expansion project forecasted to be available in the summer of 2018.

Seneca's average realized natural gas price, after the impact of hedging, for the third quarter was $2.94 per thousand cubic feet ("Mcf"), an increase of $0.08 per Mcf versus the prior year. Seneca's average realized oil price, after the impact of hedging, was $53.02 per barrel ("Bbl"), a decrease of $5.77 per Bbl. Seneca's average realized natural gas and oil prices benefited from an uplift of $0.35 per Mcf and $7.38 per Bbl, respectively, from financial hedges settled during the quarter.

LOE increased $1.8 million, or $0.07 per Mcf equivalent ("Mcfe") on a cost per unit of production basis, due primarily to higher steam fuel and well repair costs in California offset partially by lower gathering and compression costs in Appalachia. DD&A expense decreased $3.8 million due to lower production and a decrease in Seneca’s full cost pool depletion rate. Seneca’s per unit DD&A decreased by $0.07 per Mcfe to $0.64 per Mcfe due mainly to a lower depletable fixed asset balance resulting from the ceiling test impairment charges recorded in the second half of fiscal 2016.

A decrease in Seneca’s effective tax rate increased the segment’s earnings by $2.4 million in the third quarter. The decrease in the effective tax rate was due primarily to an enhanced oil recovery tax credit related to Seneca’s California properties. This credit was applicable this year as a result of relatively low domestic crude oil prices.

Midstream Businesses

Pipeline and Storage Segment

The Pipeline and Storage segment’s operations are carried out by National Fuel Gas Supply Corporation (“Supply Corporation”) and Empire Pipeline, Inc. (“Empire”). The Pipeline and Storage segment provides natural gas transportation and storage services to affiliated and non-affiliated companies through an integrated system of pipelines and underground natural gas storage fields in western New York and Pennsylvania.

The Pipeline and Storage segment's third quarter earnings decreased $1.3 million, or 7 percent, from the prior year due to a decline in operating revenues offset partially by a lower effective income tax rate. The $4.1 million decrease in operating revenues was expected due to a reduction in Supply Corporation and Empire’s rates related to their respective rate case settlements that went into effect in 2016, lower reservation revenues resulting from recent contract terminations and restructurings, and a decline in short-term interruptible transportation service in the current quarter.

Gathering Segment

The Gathering segment’s operations are carried out by National Fuel Gas Midstream Corporation’s subsidiary limited liability companies. The Gathering segment constructs, owns and operates natural gas gathering pipelines and compression facilities in the Appalachian region which currently delivers Seneca’s gross Appalachian production to the interstate pipeline system.

The Gathering segment’s third quarter earnings increased $0.6 million, or 7 percent, versus the prior year due primarily to higher operating revenues. Operating revenues increased $1.4 million as the increase in Seneca’s gross natural gas production in Appalachia, which includes production from joint development wells, helped drive higher throughput across the Company’s gathering systems. The Gathering segment transported 48.8 Bcf on its systems in the third quarter, up 2.5 Bcf or 5 percent from the prior year. Higher depreciation expense associated with new gathering and compression assets placed in service during the last twelve months partially offset the impact of higher operating revenues.

Downstream Businesses

Utility Segment

The Utility segment operations are carried out by National Fuel Gas Distribution Corporation (“Distribution”), which sells or transports natural gas to customers located in western New York and northwestern Pennsylvania.

The Utility segment’s third quarter earnings increased $2.2 million due primarily to lower O&M expense offset partially by higher DD&A expenses. O&M expense decreased $2.5 million versus the prior year due mainly to lower pension and personnel costs. DD&A expense increased $0.9 million due to higher average plant balances for the quarter ended June 30, 2017, which was primarily driven by the replacement of Distribution’s customer information system that was placed in service in May 2016.

Energy Marketing Segment

The Energy Marketing segment's operations are carried out by National Fuel Resources, Inc. (“NFR”). NFR markets natural gas to industrial, wholesale, commercial, public authority and residential customers primarily in western and central New York and northwestern Pennsylvania, offering competitively priced natural gas to its customers.

The Energy Marketing segment's third quarter earnings were largely unchanged when compared to the prior year.

Corporate and All Other

The Corporate and All Other category had a net loss of $0.3 million for the third quarter compared to a net loss of $0.9 million in the prior year. The $0.6 million improvement impacted consolidated earnings by less than $0.01 per share.

GUIDANCE

The Company is raising and tightening its earnings guidance for fiscal 2017 to a range of $3.25 to $3.35 per share to reflect the impact of actual results for the nine months ended June 30, 2017, and updates to key forecast assumptions, including revisions to the Exploration and Production segment’s forecasted production, oil pricing and operating expense assumptions, as outlined in the table below.

The Company is also initiating preliminary earnings, production, capital expenditures, and certain business segment operational guidance for fiscal 2018. National Fuel is projecting that its fiscal 2018 earnings will be within a range of $2.70 to $3.05 per share, or $2.875 per share at the midpoint of the range. The $0.425 per share decrease from the fiscal 2017 earnings guidance midpoint is being driven primarily by lower expected price realizations after hedging on Seneca’s natural gas and oil production and higher expected operating costs at the Company’s regulated businesses, offset partially by the impact of normal weather on the Utility segment's earnings and an increase in projected natural gas production in Appalachia, which will benefit earnings for the Company’s Exploration and Production and Gathering segments.

Seneca’s fiscal 2018 net production is expected to be in the range of 185 to 200 Bcfe. Natural gas production in the East Division is expected to be in a range of 165 to 180 Bcf, an 11 percent increase versus fiscal 2017. Seneca added a second rig and resumed Marcellus shale development activities in Lycoming County, Pa. this past May, which is the main driver of the 17.5 Bcf increase. Seneca’s oil operations in California are expected to produce approximately 20 Bcfe, relatively flat versus fiscal 2017. The midpoint of the production range does not assume any price related curtailments.

Due to the expiration of physical firm sales and financial hedge contracts with favorable pricing relative to current market prices and hedge book, Seneca is projecting a significant decrease in natural gas and oil price realizations in fiscal 2018. Seneca’s fiscal 2018 natural gas production is 52 percent hedged at an average hedge price of $2.90 per MMBtu. Assuming NYMEX natural gas pricing of $3.00 per MMBtu, average Appalachian basin spot prices of $2.40 per MMBtu, and adjustments for transportation costs, contracted firm sale differentials, and Btu uplift, Seneca expects its fiscal 2018 net realized gas price after hedging to be approximately $2.55 per Mcf, which is a decrease of $0.41 per Mcf from Seneca’s realized pricing after hedging of $2.96 per Mcf for the nine months ended June 30, 2017. Seneca is approximately 45 percent hedged on an expected 3 million bbls of oil production in fiscal 2018 at an average hedge price of $55.46 per Bbl.

Additional details on the Company's forecast assumptions and business segment guidance for fiscal 2018 are outlined in the table below.

EARNINGS TELECONFERENCE

The Company will host a conference call on Friday, August 4, 2017, at 11 a.m. Eastern Time to discuss this announcement. There are two ways to access this call. For those with Internet access, visit the NFG Investor Relations News & Events page at National Fuel’s website at investor.nationalfuelgas.com. For those without Internet access, audio access is also provided by dialing (toll-free) 844-862-1432, using conference ID number “51109130.” For those unable to listen to the live conference call, an audio replay will be available approximately two hours following the teleconference at the same website link and by phone at (toll-free) 855-859-2056 using conference ID number “51109130.” Both the webcast and a telephonic replay will be available until the close of business on Friday, August 11, 2017.

National Fuel is an integrated energy company reporting financial results for five operating segments: Exploration and Production, Pipeline and Storage, Gathering, Utility, and Energy Marketing. Additional information about National Fuel is available at www.nationalfuelgas.com.

Certain statements contained herein, including statements identified by the use of the words “anticipates,” “estimates,” “expects,” “forecasts,” “intends,” “plans,” “predicts,” “projects,” “believes,” “seeks,” “will,” “may” and similar expressions, and statements which are other than statements of historical facts, are “forward-looking statements” as defined by the Private Securities Litigation Reform Act of 1995. Forward-looking statements involve risks and uncertainties, which could cause actual results or outcomes to differ materially from those expressed in the forward-looking statements. The Company’s expectations, beliefs and projections contained herein are expressed in good faith and are believed to have a reasonable basis, but there can be no assurance that such expectations, beliefs or projections will result or be achieved or accomplished. In addition to other factors, the following are important factors that could cause actual results to differ materially from those discussed in the forward-looking statements: delays or changes in costs or plans with respect to Company projects or related projects of other companies, including difficulties or delays in obtaining necessary governmental approvals, permits or orders or in obtaining the cooperation of interconnecting facility operators; governmental/regulatory actions, initiatives and proceedings, including those involving rate cases (which address, among other things, target rates of return, rate design and retained natural gas), environmental/safety requirements, affiliate relationships, industry structure, and franchise renewal; changes in laws, regulations or judicial interpretations to which the Company is subject, including those involving derivatives, taxes, safety, employment, climate change, other environmental matters, real property, and exploration and production activities such as hydraulic fracturing; impairments under the SEC’s full cost ceiling test for natural gas and oil reserves; changes in the price of natural gas or oil; financial and economic conditions, including the availability of credit, and occurrences affecting the Company’s ability to obtain financing on acceptable terms for working capital, capital expenditures and other investments, including any downgrades in the Company’s credit ratings and changes in interest rates and other capital market conditions; factors affecting the Company’s ability to successfully identify, drill for and produce economically viable natural gas and oil reserves, including among others geology, lease availability, title disputes, weather conditions, shortages, delays or unavailability of equipment and services required in drilling operations, insufficient gathering, processing and transportation capacity, the need to obtain governmental approvals and permits, and compliance with environmental laws and regulations; increasing health care costs and the resulting effect on health insurance premiums and on the obligation to provide other post-retirement benefits; changes in price differentials between similar quantities of natural gas or oil sold at different geographic locations, and the effect of such changes on commodity production, revenues and demand for pipeline transportation capacity to or from such locations; other changes in price differentials between similar quantities of natural gas or oil having different quality, heating value, hydrocarbon mix or delivery date; the cost and effects of legal and administrative claims against the Company or activist shareholder campaigns to effect changes at the Company; uncertainty of oil and gas reserve estimates; significant differences between the Company’s projected and actual production levels for natural gas or oil; changes in demographic patterns and weather conditions; changes in the availability, price or accounting treatment of derivative financial instruments; changes in laws, actuarial assumptions, the interest rate environment and the return on plan/trust assets related to the Company’s pension and other post-retirement benefits, which can affect future funding obligations and costs and plan liabilities; changes in economic conditions, including global, national or regional recessions, and their effect on the demand for, and customers’ ability to pay for, the Company’s products and services; the creditworthiness or performance of the Company’s key suppliers, customers and counterparties; economic disruptions or uninsured losses resulting from major accidents, fires, severe weather, natural disasters, terrorist activities, acts of war, cyber attacks or pest infestation; significant differences between the Company’s projected and actual capital expenditures and operating expenses; or increasing costs of insurance, changes in coverage and the ability to obtain insurance. The Company disclaims any obligation to update any forward-looking statements to reflect events or circumstances after the date thereof.