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þ
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ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
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¨
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TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
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New Jersey
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13-1086010
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(State or other jurisdiction of
incorporation or organization)
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(I.R.S. Employer
Identification No.)
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6363 Main Street
Williamsville, New York
(Address of principal executive offices)
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14221
(Zip Code)
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Title of Each Class
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Name of Each Exchange
on Which Registered
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Common Stock, par value $1.00 per share, and
Common Stock Purchase Rights
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New York Stock Exchange
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Large accelerated filer
þ
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Accelerated filer
¨
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Non-accelerated filer
¨
(Do not check if a smaller reporting company)
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Smaller reporting company
¨
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Emerging growth company
¨
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CONTENTS
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Page
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Part I
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ITEM 1
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ITEM 1A
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ITEM 1B
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ITEM 2
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ITEM 3
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ITEM 4
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Part II
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ITEM 5
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ITEM 6
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ITEM 7
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ITEM 7A
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ITEM 8
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ITEM 9
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ITEM 9A
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ITEM 9B
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Part III
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ITEM 10
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ITEM 11
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ITEM 12
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ITEM 13
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ITEM 14
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Part IV
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ITEM 15
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Item 1
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Business
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•
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Seneca’s Northeast Division, which markets timber from Appalachian land holdings. At September 30, 2017, the Company owned approximately 93,000 acres of timber property and managed approximately 3,000 additional acres of timber cutting rights.
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Name and Age (as of
November 15, 2017)
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Current Company Positions and
Other Material Business Experience
During Past Five Years
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Ronald J. Tanski
(65)
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Chief Executive Officer of the Company since April 2013 and President of the Company since July 2010. Mr. Tanski previously served as Chief Operating Officer of the Company from July 2010 through March 2013.
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John R. Pustulka
(65)
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Chief Operating Officer of the Company since February 2016. Mr. Pustulka previously served as President of Supply Corporation from July 2010 through January 2016.
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David P. Bauer
(48)
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President of Supply Corporation since February 2016. Treasurer and Principal Financial Officer of the Company since July 2010. Treasurer of Seneca since April 2015; Treasurer of Distribution Corporation since April 2015; Treasurer of Midstream Corporation since April 2013; Treasurer of Supply Corporation since June 2007; and Treasurer of Empire since June 2007. Mr. Bauer previously served as Assistant Treasurer of Distribution Corporation from April 2004 through March 2015.
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Carl M. Carlotti
(62)
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President of Distribution Corporation since February 2016. Mr. Carlotti previously served as Senior Vice President of Distribution Corporation from January 2008 through January 2016.
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Ronald C. Kraemer
(61)
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President of Empire Pipeline, Inc. since August 2008 and Senior Vice President of Supply Corporation since June 2016. Mr. Kraemer previously served as Vice President of Supply Corporation from August 2008 through May 2016.
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John P. McGinnis
(57)
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President of Seneca Resources Corporation since May 2016. Mr. McGinnis previously served as Chief Operating Officer of Seneca Resources Corporation from October 2015 through April 2016 and Senior Vice President of Seneca Resources Corporation from March 2007 through September 2015.
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Paula M. Ciprich
(57)
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Senior Vice President of the Company since April 2015; Secretary of the Company since July 2008; General Counsel of the Company since January 2005; Secretary of Distribution Corporation since July 2008.
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Karen M. Camiolo
(58)
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Controller and Principal Accounting Officer of the Company since April 2004; Vice President of Distribution Corporation since April 2015; Controller of Midstream Corporation since April 2013; Controller of Empire since June 2007; and Controller of Distribution Corporation and Supply Corporation since April 2004.
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Donna L. DeCarolis
(58)
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Vice President Business Development of the Company since October 2007.
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Ann M. Wegrzyn
(59) |
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Chief Information Officer of the Company since February 2017. Mrs. Wegrzyn previously served as Vice President of Distribution Corporation from December 2010 through January 2017.
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(1)
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The executive officers serve at the pleasure of the Board of Directors. The information provided relates to the Company and its principal subsidiaries. Many of the executive officers also have served or currently serve as officers or directors of other subsidiaries of the Company.
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Item 1A
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Risk Factors
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Item 1B
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Unresolved Staff Comments
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Item 2
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Properties
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For The Year Ended September 30
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||||||||||||
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2017
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2016
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2015
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||||||
United States
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||||||
Appalachian Region
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||||||
Average Sales Price per Mcf of Gas
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$
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2.52
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(1)
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$
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1.94
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(1)
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$
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2.48
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(1)
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Average Sales Price per Barrel of Oil
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$
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48.27
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$
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52.15
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$
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57.44
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Average Sales Price per Mcf of Gas (after hedging)
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$
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2.93
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|
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$
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3.01
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$
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3.35
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Average Sales Price per Barrel of Oil (after hedging)
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$
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48.27
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$
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52.15
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$
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57.44
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Average Production (Lifting) Cost per Mcf Equivalent of Gas and Oil Produced
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$
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0.71
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(1)
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$
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0.73
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(1)
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$
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0.81
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(1)
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Average Production per Day (in MMcf Equivalent of Gas and Oil Produced)
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422
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(1)
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385
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(1)
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374
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(1)
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|||
West Coast Region
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||||||
Average Sales Price per Mcf of Gas
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$
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4.00
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$
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3.25
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$
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4.11
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Average Sales Price per Barrel of Oil
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$
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46.14
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|
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$
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35.26
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$
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51.37
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Average Sales Price per Mcf of Gas (after hedging)
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$
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4.00
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$
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3.25
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$
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4.52
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Average Sales Price per Barrel of Oil (after hedging)
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$
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53.85
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$
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57.97
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$
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70.49
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Average Production (Lifting) Cost per Mcf Equivalent of Gas and Oil Produced
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$
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2.91
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$
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2.47
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$
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2.69
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Average Production per Day (in MMcf Equivalent of Gas and Oil Produced)
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53
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56
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58
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|||
Total Company
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Average Sales Price per Mcf of Gas
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$
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2.55
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$
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1.97
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$
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2.51
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Average Sales Price per Barrel of Oil
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$
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46.18
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|
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$
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35.42
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$
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51.43
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Average Sales Price per Mcf of Gas (after hedging)
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$
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2.95
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$
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3.02
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$
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3.38
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Average Sales Price per Barrel of Oil (after hedging)
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$
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53.87
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|
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$
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57.91
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|
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$
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70.36
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Average Production (Lifting) Cost per Mcf Equivalent of Gas and Oil Produced
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$
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0.96
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$
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0.96
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$
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1.06
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Average Production per Day (in MMcf Equivalent of Gas and Oil Produced)
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475
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|
|
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441
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432
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(1)
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The Marcellus Shale fields (which exceed 15% of total reserves at September 30, 2017, 2016 and 2015) contributed 399 MMcfe, 372 MMcfe and 357 MMcfe of daily production in 2017, 2016 and 2015, respectively. The average sales price (per Mcfe) was $2.52 ($2.93 after hedging) in 2017, $1.94 ($3.01 after hedging) in 2016 and $2.48 ($3.35 after hedging) in 2015. The average lifting costs (per Mcfe) were $0.71 in 2017, $0.72 in 2016 and $0.79 in 2015.
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Appalachian
Region
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West Coast
Region
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Total Company
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||||||||||||
At September 30, 2017
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Gas
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Oil
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Gas
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Oil
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Gas
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Oil
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||||||
Productive Wells — Gross
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423
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|
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—
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—
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2,224
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423
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2,224
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Productive Wells — Net
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328
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—
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—
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2,173
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328
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2,173
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At September 30, 2017
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Appalachian
Region
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West Coast
Region
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Total
Company
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||||
Developed Acreage
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— Gross
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541,528
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23,269
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564,797
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— Net
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532,435
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21,531
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553,966
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Undeveloped Acreage
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||||
— Gross
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356,080
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|
4,518
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360,598
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— Net
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342,015
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689
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342,704
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Total Developed and Undeveloped Acreage
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|
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||||
— Gross
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897,608
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27,787
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925,395
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— Net
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874,450
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(1
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)
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22,220
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896,670
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(1)
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Of the 874,450 Total Developed and Undeveloped Net Acreage in the Appalachian region as of September 30, 2017, there are a total of 800,747 net acres in Pennsylvania. Of the 800,747 total net acres in Pennsylvania, shale development in the Marcellus, Utica or Geneseo shales has occurred on approximately 50,467 net acres, or only 6.3% of Seneca’s total net acres in Pennsylvania. The high amount of developed acreage in the table largely reflects development in the Upper Devonian geological formation and masks the potential for development beneath this formation, which includes the Marcellus, Utica and Geneseo shales.
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Productive
|
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Dry
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||||||||||||||
For the Year Ended September 30
|
2017
|
|
2016
|
|
2015
|
|
2017
|
|
2016
|
|
2015
|
||||||
United States
|
|
|
|
|
|
|
|
|
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|
||||||
Appalachian Region
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Net Wells Completed
|
|
|
|
|
|
|
|
|
|
|
|
||||||
— Exploratory
|
9.000
|
|
|
1.000
|
|
|
3.000
|
|
|
—
|
|
|
—
|
|
|
—
|
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— Development
|
25.400
|
|
|
31.800
|
|
|
49.000
|
|
|
3.000
|
|
|
1.000
|
|
|
2.000
|
|
West Coast Region
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Net Wells Completed
|
|
|
|
|
|
|
|
|
|
|
|
||||||
— Exploratory
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
— Development
|
14.000
|
|
|
25.000
|
|
|
45.000
|
|
|
—
|
|
|
—
|
|
|
1.000
|
|
Total Company
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Net Wells Completed
|
|
|
|
|
|
|
|
|
|
|
|
||||||
— Exploratory
|
9.000
|
|
|
1.000
|
|
|
3.000
|
|
|
—
|
|
|
—
|
|
|
—
|
|
— Development
|
39.400
|
|
|
56.800
|
|
|
94.000
|
|
|
3.000
|
|
|
1.000
|
|
|
3.000
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|
At September 30, 2017
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Appalachian
Region
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|
West Coast Region
|
|
Total Company
|
|||
Wells in Process of Drilling(1)
|
|
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|||
— Gross
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84.000
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|
|
—
|
|
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84.000
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— Net
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69.500
|
|
|
—
|
|
|
69.500
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|
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(1)
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Includes wells awaiting completion.
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Item 3
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Legal Proceedings
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Item 4
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Mine Safety Disclosures
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Item 5
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Market for the Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
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Period
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Total Number
of Shares
Purchased(a)
|
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Average Price
Paid per
Share
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Total Number of
Shares Purchased
as Part of
Publicly Announced
Share Repurchase
Plans or Programs
|
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Maximum Number
of Shares that May
Yet Be Purchased Under Share Repurchase Plans or Programs(b)
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|||||
July 1-31, 2017
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—
|
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N/A
|
|
|
—
|
|
|
6,971,019
|
|
|
Aug. 1-31, 2017
|
469
|
|
|
$
|
58.65
|
|
|
—
|
|
|
6,971,019
|
|
Sept. 1-30, 2017
|
5,310
|
|
|
$
|
58.72
|
|
|
—
|
|
|
6,971,019
|
|
Total
|
5,779
|
|
|
$
|
58.71
|
|
|
—
|
|
|
6,971,019
|
|
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(a)
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Represents shares of common stock of the Company tendered to the Company by holders of stock options, SARs, restricted stock units or shares of restricted stock for the payment of option exercise prices or applicable withholding taxes. During the quarter ended September 30, 2017, the Company did not purchase any shares of its common stock pursuant to its publicly announced share repurchase program.
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(b)
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In September 2008, the Company’s Board of Directors authorized the repurchase of eight million shares of the Company’s common stock. The repurchase program has no expiration date. The Company has not repurchased any shares since September 17, 2008 and has no plans to make further purchases in the near future.
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|
2012
|
2013
|
2014
|
2015
|
2016
|
2017
|
National Fuel
|
$100
|
$130
|
$136
|
$99
|
$111
|
$120
|
S&P 500 Index
|
$100
|
$119
|
$143
|
$142
|
$164
|
$194
|
PHLX Utility Sector Index (UTY)
|
$100
|
$105
|
$121
|
$128
|
$151
|
$169
|
S&P 500 Oil & Gas Exp & Prod SUB Industry Index GICS Level 4 (S5OILP)
|
$100
|
$127
|
$138
|
$81
|
$96
|
$86
|
Item 6
|
Selected Financial Data
|
|
Year Ended September 30
|
||||||||||||||||||
|
2017
|
|
2016
|
|
2015
|
|
2014
|
|
2013
|
||||||||||
|
(Thousands, except per share amounts and number of registered shareholders)
|
||||||||||||||||||
Summary of Operations
|
|
|
|
|
|
|
|
|
|
||||||||||
Operating Revenues:
|
|
|
|
|
|
|
|
|
|
||||||||||
Utility and Energy Marketing
Revenues
|
$
|
755,485
|
|
|
$
|
624,602
|
|
|
$
|
860,618
|
|
|
$
|
1,103,149
|
|
|
$
|
942,309
|
|
Exploration and Production and Other
Revenues
|
617,666
|
|
|
611,766
|
|
|
696,709
|
|
|
808,595
|
|
|
707,734
|
|
|||||
Pipeline and Storage and Gathering
Revenues
|
206,730
|
|
|
216,048
|
|
|
203,586
|
|
|
201,337
|
|
|
179,508
|
|
|||||
|
1,579,881
|
|
|
1,452,416
|
|
|
1,760,913
|
|
|
2,113,081
|
|
|
1,829,551
|
|
|||||
Operating Expenses:
|
|
|
|
|
|
|
|
|
|
||||||||||
Purchased Gas
|
275,254
|
|
|
147,982
|
|
|
349,984
|
|
|
605,838
|
|
|
460,432
|
|
|||||
Operation and Maintenance:
|
|
|
|
|
|
|
|
|
|
||||||||||
Utility and Energy Marketing
|
199,293
|
|
|
192,512
|
|
|
203,249
|
|
|
196,534
|
|
|
180,997
|
|
|||||
Exploration and Production and Other
|
145,099
|
|
|
160,201
|
|
|
184,024
|
|
|
188,622
|
|
|
175,014
|
|
|||||
Pipeline and Storage and Gathering
|
98,200
|
|
|
88,801
|
|
|
82,730
|
|
|
77,922
|
|
|
86,079
|
|
|||||
Property, Franchise and Other Taxes
|
84,995
|
|
|
81,714
|
|
|
89,564
|
|
|
90,711
|
|
|
82,431
|
|
|||||
Depreciation, Depletion and Amortization
|
224,195
|
|
|
249,417
|
|
|
336,158
|
|
|
383,781
|
|
|
326,760
|
|
|||||
Impairment of Oil and Gas Producing Properties
|
—
|
|
|
948,307
|
|
|
1,126,257
|
|
|
—
|
|
|
—
|
|
|||||
|
1,027,036
|
|
|
1,868,934
|
|
|
2,371,966
|
|
|
1,543,408
|
|
|
1,311,713
|
|
|||||
Operating Income (Loss)
|
552,845
|
|
|
(416,518
|
)
|
|
(611,053
|
)
|
|
569,673
|
|
|
517,838
|
|
|||||
Other Income (Expense):
|
|
|
|
|
|
|
|
|
|
||||||||||
Other Income
|
4,113
|
|
|
9,820
|
|
|
8,039
|
|
|
9,461
|
|
|
4,697
|
|
|||||
Interest Income
|
7,043
|
|
|
4,235
|
|
|
3,922
|
|
|
4,170
|
|
|
4,335
|
|
|||||
Interest Expense on Long-Term Debt
|
(116,471
|
)
|
|
(117,347
|
)
|
|
(95,916
|
)
|
|
(90,194
|
)
|
|
(90,273
|
)
|
|||||
Other Interest Expense
|
(3,366
|
)
|
|
(3,697
|
)
|
|
(3,555
|
)
|
|
(4,083
|
)
|
|
(3,838
|
)
|
|||||
Income (Loss) Before Income Taxes
|
444,164
|
|
|
(523,507
|
)
|
|
(698,563
|
)
|
|
489,027
|
|
|
432,759
|
|
|||||
Income Tax Expense (Benefit)
|
160,682
|
|
|
(232,549
|
)
|
|
(319,136
|
)
|
|
189,614
|
|
|
172,758
|
|
|||||
Net Income (Loss) Available for Common Stock
|
$
|
283,482
|
|
|
$
|
(290,958
|
)
|
|
$
|
(379,427
|
)
|
|
$
|
299,413
|
|
|
$
|
260,001
|
|
Per Common Share Data
|
|
|
|
|
|
|
|
|
|
||||||||||
Basic Earnings (Loss) per Common Share
|
$
|
3.32
|
|
|
$
|
(3.43
|
)
|
|
$
|
(4.50
|
)
|
|
$
|
3.57
|
|
|
$
|
3.11
|
|
Diluted Earnings (Loss) per Common Share
|
$
|
3.30
|
|
|
$
|
(3.43
|
)
|
|
$
|
(4.50
|
)
|
|
$
|
3.52
|
|
|
$
|
3.08
|
|
Dividends Declared
|
$
|
1.64
|
|
|
$
|
1.60
|
|
|
$
|
1.56
|
|
|
$
|
1.52
|
|
|
$
|
1.48
|
|
Dividends Paid
|
$
|
1.63
|
|
|
$
|
1.59
|
|
|
$
|
1.55
|
|
|
$
|
1.51
|
|
|
$
|
1.47
|
|
Dividend Rate at Year-End
|
$
|
1.66
|
|
|
$
|
1.62
|
|
|
$
|
1.58
|
|
|
$
|
1.54
|
|
|
$
|
1.50
|
|
At September 30:
|
|
|
|
|
|
|
|
|
|
||||||||||
Number of Registered Shareholders
|
11,211
|
|
|
11,751
|
|
|
12,147
|
|
|
12,654
|
|
|
13,215
|
|
|||||
|
|
|
|
|
|
|
|
|
|
|
Year Ended September 30
|
||||||||||||||||||
|
2017
|
|
2016
|
|
2015
|
|
2014
|
|
2013
|
||||||||||
|
(Thousands, except per share amounts and number of registered shareholders)
|
||||||||||||||||||
Net Property, Plant and Equipment
|
|
|
|
|
|
|
|
|
|
||||||||||
Exploration and Production
|
$
|
1,196,521
|
|
|
$
|
1,083,804
|
|
|
$
|
2,126,265
|
|
|
$
|
2,897,744
|
|
|
$
|
2,600,448
|
|
Pipeline and Storage
|
1,524,197
|
|
|
1,463,541
|
|
|
1,387,516
|
|
|
1,187,924
|
|
|
1,074,079
|
|
|||||
Gathering
|
455,701
|
|
|
439,660
|
|
|
400,409
|
|
|
292,793
|
|
|
161,111
|
|
|||||
Utility
|
1,435,414
|
|
|
1,403,286
|
|
|
1,351,504
|
|
|
1,297,179
|
|
|
1,246,943
|
|
|||||
Energy Marketing
|
1,503
|
|
|
1,745
|
|
|
1,989
|
|
|
2,070
|
|
|
2,002
|
|
|||||
All Other
|
57,960
|
|
|
59,054
|
|
|
60,404
|
|
|
61,236
|
|
|
62,554
|
|
|||||
Corporate
|
2,778
|
|
|
3,392
|
|
|
3,808
|
|
|
4,145
|
|
|
4,589
|
|
|||||
Total Net Plant
|
$
|
4,674,074
|
|
|
$
|
4,454,482
|
|
|
$
|
5,331,895
|
|
|
$
|
5,743,091
|
|
|
$
|
5,151,726
|
|
Total Assets
|
$
|
6,103,320
|
|
|
$
|
5,636,387
|
|
|
$
|
6,564,939
|
|
|
$
|
6,687,717
|
|
|
$
|
6,125,618
|
|
Capitalization
|
|
|
|
|
|
|
|
|
|
||||||||||
Comprehensive Shareholders’ Equity
|
$
|
1,703,735
|
|
|
$
|
1,527,004
|
|
|
$
|
2,025,440
|
|
|
$
|
2,410,683
|
|
|
$
|
2,194,729
|
|
Long-Term Debt, Net of Current Portion and Unamortized Discount and Debt Issuance Costs
|
2,083,681
|
|
|
2,086,252
|
|
|
2,084,009
|
|
|
1,637,443
|
|
|
1,635,630
|
|
|||||
Total Capitalization
|
$
|
3,787,416
|
|
|
$
|
3,613,256
|
|
|
$
|
4,109,449
|
|
|
$
|
4,048,126
|
|
|
$
|
3,830,359
|
|
Item 7
|
Management’s Discussion and Analysis of Financial Condition and Results of Operations
|
1.
|
The critical accounting estimates of the Company;
|
2.
|
Changes in revenues and earnings of the Company under the heading, “Results of Operations;”
|
3.
|
Operating, investing and financing cash flows under the heading “Capital Resources and Liquidity;”
|
4.
|
Off-Balance Sheet Arrangements;
|
5.
|
Contractual Obligations; and
|
6.
|
Other Matters, including: (a) 2017 and projected 2018 funding for the Company’s pension and other post-retirement benefits; (b) disclosures and tables concerning market risk sensitive instruments; (c) rate and regulatory matters in the Company’s New York, Pennsylvania and FERC-regulated jurisdictions; (d) environmental matters; and (e) new authoritative accounting and financial reporting guidance.
|
(Millions)
|
$0.25/MMBtu
Decrease in
Natural Gas Prices
|
|
$5.00/Bbl
Decrease in
Crude Oil Prices
|
|
$0.25/MMBtu
Decrease in
Natural Gas
Prices and
$5.00/Bbl
Decrease in
Crude Oil Prices
|
||||||
|
|
|
|
|
|
||||||
Excess of Ceiling over Book Value under Sensitivity Analysis
|
$
|
157.2
|
|
|
$
|
250.8
|
|
|
$
|
121.7
|
|
•
|
Non-cash impairment charges of $948.3 million ($550.0 million after tax) recorded during 2016 for the Exploration and Production segment’s oil and gas producing properties.
|
•
|
Joint development agreement professional fees of $4.6 million recorded in the Exploration and Production segment. The joint development agreement professional fees incurred were related to professional services associated with the Marcellus Shale drilling joint development agreement with IOG executed on December 1, 2015 and subsequently extended on June 13, 2016.
|
•
|
Non-cash impairment charges of $1.1 billion ($650.2 million after tax) recorded during 2015 for the Exploration and Production segment’s oil and gas producing properties.
|
•
|
A $4.7 million reversal of stock-based compensation expense related to performance based restricted stock units since performance conditions, which do not include any market conditions, were not met. The $4.7 million was allocated across the Exploration and Production segment, Pipeline and Storage segment, Utility segment and the All Other and Corporate category.
|
|
Year Ended September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
|
(Thousands)
|
||||||||||
Exploration and Production
|
$
|
129,326
|
|
|
$
|
(452,842
|
)
|
|
$
|
(556,974
|
)
|
Pipeline and Storage
|
68,446
|
|
|
76,610
|
|
|
80,354
|
|
|||
Gathering
|
40,377
|
|
|
30,499
|
|
|
31,849
|
|
|||
Utility
|
46,935
|
|
|
50,960
|
|
|
63,271
|
|
|||
Energy Marketing
|
1,509
|
|
|
4,348
|
|
|
7,766
|
|
|||
Total Reported Segments
|
286,593
|
|
|
(290,425
|
)
|
|
(373,734
|
)
|
|||
All Other
|
(342
|
)
|
|
778
|
|
|
(2
|
)
|
|||
Corporate
|
(2,769
|
)
|
|
(1,311
|
)
|
|
(5,691
|
)
|
|||
Total Consolidated
|
$
|
283,482
|
|
|
$
|
(290,958
|
)
|
|
$
|
(379,427
|
)
|
|
Year Ended September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
|
(Thousands)
|
||||||||||
Gas (after Hedging)
|
$
|
462,976
|
|
|
$
|
433,357
|
|
|
$
|
471,657
|
|
Oil (after Hedging)
|
147,599
|
|
|
169,263
|
|
|
213,488
|
|
|||
Gas Processing Plant
|
3,181
|
|
|
2,411
|
|
|
2,891
|
|
|||
Other
|
843
|
|
|
2,082
|
|
|
5,405
|
|
|||
Operating Revenues
|
$
|
614,599
|
|
|
$
|
607,113
|
|
|
$
|
693,441
|
|
|
Year Ended September 30
|
|||||||
|
2017
|
|
2016
|
|
2015
|
|||
Gas Production
(MMcf)
|
|
|
|
|
|
|||
Appalachia
|
154,093
|
|
|
140,457
|
|
|
136,404
|
|
West Coast
|
2,995
|
|
|
3,090
|
|
|
3,159
|
|
Total Production
|
157,088
|
|
|
143,547
|
|
|
139,563
|
|
Oil Production
(Mbbl)
|
|
|
|
|
|
|||
Appalachia
|
4
|
|
|
28
|
|
|
30
|
|
West Coast
|
2,736
|
|
|
2,895
|
|
|
3,004
|
|
Total Production
|
2,740
|
|
|
2,923
|
|
|
3,034
|
|
|
Year Ended September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
Average Gas Price/Mcf
|
|
|
|
|
|
||||||
Appalachia
|
$
|
2.52
|
|
|
$
|
1.94
|
|
|
$
|
2.48
|
|
West Coast
|
$
|
4.00
|
|
|
$
|
3.25
|
|
|
$
|
4.11
|
|
Weighted Average
|
$
|
2.55
|
|
|
$
|
1.97
|
|
|
$
|
2.51
|
|
Weighted Average After Hedging(1)
|
$
|
2.95
|
|
|
$
|
3.02
|
|
|
$
|
3.38
|
|
Average Oil Price/Barrel (Bbl)
|
|
|
|
|
|
||||||
Appalachia
|
$
|
48.27
|
|
|
$
|
52.15
|
|
|
$
|
57.44
|
|
West Coast
|
$
|
46.14
|
|
|
$
|
35.26
|
|
|
$
|
51.37
|
|
Weighted Average
|
$
|
46.18
|
|
|
$
|
35.42
|
|
|
$
|
51.43
|
|
Weighted Average After Hedging(1)
|
$
|
53.87
|
|
|
$
|
57.91
|
|
|
$
|
70.36
|
|
|
(1)
|
Refer to further discussion of hedging activities below under “Market Risk Sensitive Instruments” and in Note G — Financial Instruments in Item 8 of this report.
|
|
Year Ended September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
|
(Thousands)
|
||||||||||
Firm Transportation
|
$
|
221,609
|
|
|
$
|
229,895
|
|
|
$
|
214,611
|
|
Interruptible Transportation
|
1,690
|
|
|
3,995
|
|
|
2,971
|
|
|||
|
223,299
|
|
|
233,890
|
|
|
217,582
|
|
|||
Firm Storage Service
|
69,963
|
|
|
70,351
|
|
|
70,732
|
|
|||
Interruptible Storage Service
|
19
|
|
|
143
|
|
|
3
|
|
|||
|
69,982
|
|
|
70,494
|
|
|
70,735
|
|
|||
Other
|
1,144
|
|
|
2,045
|
|
|
3,023
|
|
|||
|
$
|
294,425
|
|
|
$
|
306,429
|
|
|
$
|
291,340
|
|
|
Year Ended September 30
|
|||||||
|
2017
|
|
2016
|
|
2015
|
|||
Firm Transportation
|
779,382
|
|
|
740,875
|
|
|
737,206
|
|
Interruptible Transportation
|
5,805
|
|
|
23,548
|
|
|
12,874
|
|
|
785,187
|
|
|
764,423
|
|
|
750,080
|
|
|
Year Ended September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
|
(Thousands)
|
||||||||||
Gathering
|
$
|
107,566
|
|
|
$
|
89,073
|
|
|
$
|
76,709
|
|
Processing and Other Revenues
|
115
|
|
|
374
|
|
|
497
|
|
|||
|
$
|
107,681
|
|
|
$
|
89,447
|
|
|
$
|
77,206
|
|
|
Year Ended September 30
|
|||||||
|
2017
|
|
2016
|
|
2015
|
|||
Gathered Volume
|
194,921
|
|
|
161,955
|
|
|
139,629
|
|
|
Year Ended September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
|
(Thousands)
|
||||||||||
Retail Revenues:
|
|
|
|
|
|
||||||
Residential
|
$
|
435,357
|
|
|
$
|
360,648
|
|
|
$
|
480,163
|
|
Commercial
|
58,988
|
|
|
44,994
|
|
|
61,099
|
|
|||
Industrial
|
2,376
|
|
|
1,785
|
|
|
2,655
|
|
|||
|
496,721
|
|
|
407,427
|
|
|
543,917
|
|
|||
Off-System Sales
|
3,997
|
|
|
1,877
|
|
|
11,773
|
|
|||
Transportation
|
129,509
|
|
|
124,120
|
|
|
142,289
|
|
|||
Other
|
9,744
|
|
|
10,723
|
|
|
18,288
|
|
|||
|
$
|
639,971
|
|
|
$
|
544,147
|
|
|
$
|
716,267
|
|
|
|
|
|
|
|
|
Percent (Warmer)
Colder Than
|
||||||
Year Ended September 30
|
|
|
Normal
|
|
Actual
|
|
Normal(1)
|
|
Prior Year(1)
|
||||
2017
|
Buffalo
|
|
6,617
|
|
|
5,708
|
|
|
(13.7
|
)%
|
|
1.7
|
%
|
|
Erie
|
|
6,147
|
|
|
5,179
|
|
|
(15.7
|
)%
|
|
(0.1
|
)%
|
2016
|
Buffalo
|
|
6,653
|
|
(2)
|
5,611
|
|
|
(15.7
|
)%
|
|
(19.5
|
)%
|
|
Erie
|
|
6,181
|
|
(2)
|
5,182
|
|
|
(16.2
|
)%
|
|
(21.3
|
)%
|
2015
|
Buffalo
|
|
6,617
|
|
|
6,968
|
|
|
5.3
|
%
|
|
(1.7
|
)%
|
|
Erie
|
|
6,147
|
|
|
6,586
|
|
|
7.1
|
%
|
|
(2.3
|
)%
|
|
(1)
|
Percents compare actual degree days to normal degree days and actual degree days to actual prior year degree days.
|
(2)
|
Normal degree day estimates changed to 6,653 for Buffalo and 6,181 for Erie as a result of updated information from the National Oceanic and Atmospheric Administration. In addition, normal degree days for 2016 reflect the fact that 2016 was a leap year.
|
|
Year Ended September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
|
(Thousands)
|
||||||||||
Natural Gas (after Hedging)
|
$
|
129,317
|
|
|
$
|
94,028
|
|
|
$
|
160,651
|
|
Other
|
63
|
|
|
434
|
|
|
55
|
|
|||
|
$
|
129,380
|
|
|
$
|
94,462
|
|
|
$
|
160,706
|
|
|
Year Ended September 30
|
|||||||
|
2017
|
|
2016
|
|
2015
|
|||
Natural Gas — (MMcf)
|
38,901
|
|
|
39,849
|
|
|
46,752
|
|
|
Year Ended September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
|
(Millions)
|
||||||||||
Provided by Operating Activities
|
$
|
684.3
|
|
|
$
|
589.0
|
|
|
$
|
853.6
|
|
Capital Expenditures
|
(450.3
|
)
|
|
(581.6
|
)
|
|
(1,018.2
|
)
|
|||
Net Proceeds from Sale of Oil and Gas Producing Properties
|
26.6
|
|
|
137.3
|
|
|
—
|
|
|||
Other Investing Activities
|
1.2
|
|
|
(9.2
|
)
|
|
(6.6
|
)
|
|||
Change in Notes Payable to Banks and Commercial Paper
|
—
|
|
|
—
|
|
|
(85.6
|
)
|
|||
Net Proceeds from Issuance of Long-Term Debt
|
295.2
|
|
|
—
|
|
|
444.6
|
|
|||
Net Proceeds from Issuance of Common Stock
|
7.7
|
|
|
13.8
|
|
|
10.5
|
|
|||
Dividends Paid on Common Stock
|
(139.1
|
)
|
|
(134.8
|
)
|
|
(130.7
|
)
|
|||
Excess Tax Benefits Associated with Stock-Based Compensation Awards
|
—
|
|
|
1.9
|
|
|
9.1
|
|
|||
Net Increase in Cash and Temporary Cash Investments
|
$
|
425.6
|
|
|
$
|
16.4
|
|
|
$
|
76.7
|
|
|
Year Ended September 30
|
|
||||||||||||
|
2017
|
|
|
2016
|
|
|
2015
|
|
||||||
|
(Millions)
|
|
||||||||||||
Exploration and Production:
|
|
|
|
|
|
|
|
|
||||||
Capital Expenditures
|
$
|
253.1
|
|
(1)
|
|
$
|
256.1
|
|
(2)
|
|
$
|
557.3
|
|
(3)
|
Pipeline and Storage:
|
|
|
|
|
|
|
|
|
||||||
Capital Expenditures
|
95.3
|
|
(1)
|
|
114.3
|
|
(2)
|
|
230.2
|
|
(3)
|
|||
Gathering:
|
|
|
|
|
|
|
|
|
||||||
Capital Expenditures
|
32.6
|
|
(1)
|
|
54.3
|
|
(2)
|
|
118.2
|
|
(3)
|
|||
Utility:
|
|
|
|
|
|
|
|
|
||||||
Capital Expenditures
|
80.9
|
|
(1)
|
|
98.0
|
|
(2)
|
|
94.4
|
|
(3)
|
|||
All Other and Corporate:
|
|
|
|
|
|
|
|
|
||||||
Capital Expenditures
|
0.2
|
|
|
|
0.4
|
|
|
|
0.4
|
|
|
|||
Total Expenditures
|
$
|
462.1
|
|
|
|
$
|
523.1
|
|
|
|
$
|
1,000.5
|
|
|
|
(1)
|
2017 capital expenditures for the Exploration and Production segment, the Pipeline and Storage segment, the Gathering segment and the Utility segment include $36.5 million, $25.1 million, $3.9 million and $6.7 million, respectively, of non-cash capital expenditures. The capital expenditures for the Exploration and Production segment do not include any proceeds received from the sale of oil and gas assets to IOG under the joint development agreement.
|
(2)
|
2016 capital expenditures for the Exploration and Production segment, the Pipeline and Storage segment, the Gathering segment and the Utility segment include $25.2 million, $18.7 million, $5.3 million and $11.2 million, respectively, of non-cash capital expenditures. The capital expenditures for the Exploration and Production segment do not include any proceeds from the sale of oil and gas assets to IOG under the joint development agreement.
|
(3)
|
2015 capital expenditures for the Exploration and Production segment, the Pipeline and Storage segment, the Gathering segment and the Utility segment include $46.2 million, $33.9 million, $22.4 million and $16.5 million, respectively, of non-cash capital expenditures.
|
|
Year Ended September 30
|
||||||||||
|
2018
|
|
2019
|
|
2020
|
||||||
|
(Millions)
|
||||||||||
Exploration and Production(1)
|
$
|
320
|
|
|
$
|
345
|
|
|
$
|
320
|
|
Pipeline and Storage
|
125
|
|
|
215
|
|
|
145
|
|
|||
Gathering
|
70
|
|
|
50
|
|
|
30
|
|
|||
Utility
|
95
|
|
|
95
|
|
|
95
|
|
|||
All Other
|
—
|
|
|
—
|
|
|
—
|
|
|||
|
$
|
610
|
|
|
$
|
705
|
|
|
$
|
590
|
|
|
(1)
|
Includes estimated expenditures for the years ended September 30, 2018, 2019 and 2020 of approximately $186 million, $98 million and $28 million, respectively, to develop proved undeveloped reserves. The Company is committed to developing its proved undeveloped reserves within five years as required by the SEC’s final rule on Modernization of Oil and Gas Reporting. The capital expenditures for the Exploration and Production segment do not include any proceeds received from the sale of oil and gas assets to IOG under the joint development agreement.
|
|
Payments by Expected Maturity Dates
|
||||||||||||||||||||||||||
|
2018
|
|
2019
|
|
2020
|
|
2021
|
|
2022
|
|
Thereafter
|
|
Total
|
||||||||||||||
|
(Millions)
|
||||||||||||||||||||||||||
Long-Term Debt, including interest expense(1)
|
$
|
409.3
|
|
|
$
|
348.6
|
|
|
$
|
85.8
|
|
|
$
|
85.8
|
|
|
$
|
565.5
|
|
|
$
|
1,493.6
|
|
|
$
|
2,988.6
|
|
Operating Lease Obligations
|
$
|
10.8
|
|
|
$
|
4.6
|
|
|
$
|
3.7
|
|
|
$
|
2.2
|
|
|
$
|
1.5
|
|
|
$
|
1.9
|
|
|
$
|
24.7
|
|
Purchase Obligations:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Gas Purchase Contracts(2)
|
$
|
198.6
|
|
|
$
|
21.0
|
|
|
$
|
12.5
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
232.1
|
|
Transportation and Storage Contracts(3)
|
$
|
63.8
|
|
|
$
|
63.6
|
|
|
$
|
65.4
|
|
|
$
|
70.9
|
|
|
$
|
61.7
|
|
|
$
|
504.9
|
|
|
$
|
830.3
|
|
Hydraulic Fracturing and Fuel Obligations
|
$
|
79.5
|
|
|
$
|
98.0
|
|
|
$
|
17.1
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
194.6
|
|
Pipeline, Compressor and Gathering Projects
|
$
|
61.7
|
|
|
$
|
0.7
|
|
|
$
|
0.2
|
|
|
$
|
0.3
|
|
|
$
|
0.3
|
|
|
$
|
1.1
|
|
|
$
|
64.3
|
|
Other
|
$
|
20.4
|
|
|
$
|
13.7
|
|
|
$
|
11.1
|
|
|
$
|
9.8
|
|
|
$
|
7.9
|
|
|
$
|
26.6
|
|
|
$
|
89.5
|
|
|
(1)
|
Refer to Note E — Capitalization and Short-Term Borrowings, as well as the table under Interest Rate Risk in the Market Risk Sensitive Instruments section below, for the amounts excluding interest expense. As noted in Note E, the Company redeemed its $300.0 million 6.50% notes in October 2017. These notes were scheduled to mature in April 2018. The impact of the October redemption is reflected in the table.
|
(2)
|
Gas prices are variable based on the NYMEX prices adjusted for basis.
|
(3)
|
Transportation service contractual obligations include the following precedent agreements executed by the Exploration and Production segment for transportation of Appalachian gas: $20.1 million for 2018, $21.5 million for 2019, $21.6 million for 2020, $27.3 million for 2021, $33.2 million for 2022 and $453.7 million thereafter.
|
|
Expected Maturity Dates
|
||||||||||||||||||||||
|
2018
|
|
2019
|
|
2020
|
|
2021
|
|
2022
|
|
Total
|
||||||||||||
Notional Quantities (Equivalent Bcf)
|
51.3
|
|
|
33.8
|
|
|
23.5
|
|
|
5.3
|
|
|
0.1
|
|
|
114.0
|
|
||||||
Weighted Average Fixed Rate (per Mcf)
|
$
|
3.44
|
|
|
$
|
3.26
|
|
|
$
|
3.17
|
|
|
$
|
3.13
|
|
|
$
|
3.05
|
|
|
$
|
3.32
|
|
Weighted Average Variable Rate (per Mcf)
|
$
|
3.16
|
|
|
$
|
3.01
|
|
|
$
|
2.90
|
|
|
$
|
3.01
|
|
|
$
|
3.00
|
|
|
$
|
3.06
|
|
|
|
||||||||||||||||||||||
|
2018
|
|
2019
|
|
2020
|
|
2021
|
|
2022
|
|
Total
|
||||||||||||
Notional Quantities (Equivalent Bbls)
|
1,755,000
|
|
|
1,068,000
|
|
|
324,000
|
|
|
156,000
|
|
|
156,000
|
|
|
3,459,000
|
|
||||||
Weighted Average Fixed Rate (per Bbl)
|
$
|
54.30
|
|
|
$
|
53.42
|
|
|
$
|
50.52
|
|
|
$
|
51.00
|
|
|
$
|
51.00
|
|
|
$
|
53.38
|
|
Weighted Average Variable Rate (per Bbl)
|
$
|
52.04
|
|
|
$
|
51.13
|
|
|
$
|
50.59
|
|
|
$
|
50.58
|
|
|
$
|
50.82
|
|
|
$
|
51.50
|
|
|
Expected Maturity Dates
|
||||||||||||||||||||||||||
|
2018
|
|
2019
|
|
2020
|
|
2021
|
|
2022
|
|
2023
|
|
Total
|
||||||||||||||
Net Contract Volume Purchased (Sold)
(Equivalent Bcf)
|
4.4
|
|
|
4.4
|
|
|
1.4
|
|
|
0.8
|
|
|
0.7
|
|
|
0.1
|
|
|
11.8
|
|
|||||||
Weighted Average Contract Price (per Mcf)
|
$
|
3.41
|
|
|
$
|
3.12
|
|
|
$
|
3.08
|
|
|
$
|
2.99
|
|
|
$
|
2.99
|
|
|
$
|
2.99
|
|
|
$
|
3.32
|
|
Weighted Average Settlement Price (per Mcf)
|
$
|
3.34
|
|
|
$
|
3.18
|
|
|
$
|
3.10
|
|
|
$
|
2.96
|
|
|
$
|
2.96
|
|
|
$
|
3.15
|
|
|
$
|
3.27
|
|
|
Expected Maturity Dates
|
||||||||||||||||||||||||||
|
2018
|
|
2019
|
|
2020
|
|
2021
|
|
2022
|
|
Thereafter
|
|
Total
|
||||||||||||||
Notional Quantities (Canadian Dollar in millions)
|
$
|
14.4
|
|
|
$
|
14.4
|
|
|
$
|
14.4
|
|
|
$
|
11.1
|
|
|
$
|
11.1
|
|
|
$
|
23.8
|
|
|
$
|
89.2
|
|
Weighted Average Fixed Rate ($Cdn/$US)
|
$
|
1.25
|
|
|
$
|
1.25
|
|
|
$
|
1.24
|
|
|
$
|
1.30
|
|
|
$
|
1.29
|
|
|
$
|
1.27
|
|
|
$
|
1.26
|
|
Weighted Average Variable Rate ($Cdn/$US)
|
$
|
1.24
|
|
|
$
|
1.25
|
|
|
$
|
1.25
|
|
|
$
|
1.27
|
|
|
$
|
1.26
|
|
|
$
|
1.26
|
|
|
$
|
1.25
|
|
|
Principal Amounts by Expected Maturity Dates
|
||||||||||||||||||||||||||
|
2018
|
|
2019
|
|
2020
|
|
2021
|
|
2022
|
|
Thereafter
|
|
Total
|
||||||||||||||
|
(Dollars in millions)
|
||||||||||||||||||||||||||
Long-Term Fixed Rate Debt
|
$
|
300.0
|
|
|
$
|
250.0
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
500.0
|
|
|
$
|
1,349.0
|
|
|
$
|
2,399.0
|
|
Weighted Average Interest Rate Paid
|
6.5
|
%
|
|
8.8
|
%
|
|
—
|
|
|
—
|
|
|
4.9
|
%
|
|
4.5
|
%
|
|
5.3
|
%
|
1.
|
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;
|
2.
|
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;
|
3.
|
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;
|
4.
|
Impairments under the SEC’s full cost ceiling test for natural gas and oil reserves;
|
5.
|
Changes in the price of natural gas or oil;
|
6.
|
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;
|
7.
|
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;
|
8.
|
Increasing health care costs and the resulting effect on health insurance premiums and on the obligation to provide other post-retirement benefits;
|
9.
|
Changes in price differentials between similar quantities of natural gas or oil 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;
|
10.
|
Other changes in price differentials between similar quantities of natural gas or oil having different quality, heating value, hydrocarbon mix or delivery date;
|
11.
|
The cost and effects of legal and administrative claims against the Company or activist shareholder campaigns to effect changes at the Company;
|
12.
|
Uncertainty of oil and gas reserve estimates;
|
13.
|
Significant differences between the Company’s projected and actual production levels for natural gas or oil;
|
14.
|
Changes in demographic patterns and weather conditions;
|
15.
|
Changes in the availability, price or accounting treatment of derivative financial instruments;
|
16.
|
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;
|
17.
|
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;
|
18.
|
The creditworthiness or performance of the Company’s key suppliers, customers and counterparties;
|
19.
|
Economic disruptions or uninsured losses resulting from major accidents, fires, severe weather, natural disasters, terrorist activities, acts of war, cyber attacks or pest infestation;
|
20.
|
Significant differences between the Company’s projected and actual capital expenditures and operating expenses; or
|
21.
|
Increasing costs of insurance, changes in coverage and the ability to obtain insurance.
|
Item 7A
|
Quantitative and Qualitative Disclosures About Market Risk
|
Item 8
|
Financial Statements and Supplementary Data
|
|
Page
|
Financial Statements and Financial Statement Schedule:
|
|
|
|
|
Year Ended September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
|
(Thousands of dollars, except per common share
amounts)
|
||||||||||
INCOME
|
|
|
|
|
|
||||||
Operating Revenues:
|
|
|
|
|
|
||||||
Utility and Energy Marketing Revenues
|
$
|
755,485
|
|
|
$
|
624,602
|
|
|
$
|
860,618
|
|
Exploration and Production and Other Revenues
|
617,666
|
|
|
611,766
|
|
|
696,709
|
|
|||
Pipeline and Storage and Gathering Revenues
|
206,730
|
|
|
216,048
|
|
|
203,586
|
|
|||
|
1,579,881
|
|
|
1,452,416
|
|
|
1,760,913
|
|
|||
|
|
|
|
|
|
||||||
Operating Expenses:
|
|
|
|
|
|
||||||
Purchased Gas
|
275,254
|
|
|
147,982
|
|
|
349,984
|
|
|||
Operation and Maintenance:
|
|
|
|
|
|
|
|
|
|||
Utility and Energy Marketing
|
199,293
|
|
|
192,512
|
|
|
203,249
|
|
|||
Exploration and Production and Other
|
145,099
|
|
|
160,201
|
|
|
184,024
|
|
|||
Pipeline and Storage and Gathering
|
98,200
|
|
|
88,801
|
|
|
82,730
|
|
|||
Property, Franchise and Other Taxes
|
84,995
|
|
|
81,714
|
|
|
89,564
|
|
|||
Depreciation, Depletion and Amortization
|
224,195
|
|
|
249,417
|
|
|
336,158
|
|
|||
Impairment of Oil and Gas Producing Properties
|
—
|
|
|
948,307
|
|
|
1,126,257
|
|
|||
|
1,027,036
|
|
|
1,868,934
|
|
|
2,371,966
|
|
|||
Operating Income (Loss)
|
552,845
|
|
|
(416,518
|
)
|
|
(611,053
|
)
|
|||
Other Income (Expense):
|
|
|
|
|
|
||||||
Other Income
|
7,043
|
|
|
9,820
|
|
|
8,039
|
|
|||
Interest Income
|
4,113
|
|
|
4,235
|
|
|
3,922
|
|
|||
Interest Expense on Long-Term Debt
|
(116,471
|
)
|
|
(117,347
|
)
|
|
(95,916
|
)
|
|||
Other Interest Expense
|
(3,366
|
)
|
|
(3,697
|
)
|
|
(3,555
|
)
|
|||
Income (Loss) Before Income Taxes
|
444,164
|
|
|
(523,507
|
)
|
|
(698,563
|
)
|
|||
Income Tax Expense (Benefit)
|
160,682
|
|
|
(232,549
|
)
|
|
(319,136
|
)
|
|||
Net Income (Loss) Available for Common Stock
|
283,482
|
|
|
(290,958
|
)
|
|
(379,427
|
)
|
|||
EARNINGS REINVESTED IN THE BUSINESS
|
|
|
|
|
|
||||||
Balance at Beginning of Year
|
676,361
|
|
|
1,103,200
|
|
|
1,614,361
|
|
|||
|
959,843
|
|
|
812,242
|
|
|
1,234,934
|
|
|||
Dividends on Common Stock
|
(140,090
|
)
|
|
(135,881
|
)
|
|
(131,734
|
)
|
|||
Cumulative Effect of Adoption of Authoritative Guidance for
Stock-Based Compensation
|
31,916
|
|
|
—
|
|
|
—
|
|
|||
Balance at End of Year
|
$
|
851,669
|
|
|
$
|
676,361
|
|
|
$
|
1,103,200
|
|
Earnings Per Common Share:
|
|
|
|
|
|
||||||
Basic:
|
|
|
|
|
|
||||||
Net Income (Loss) Available for Common Stock
|
$
|
3.32
|
|
|
$
|
(3.43
|
)
|
|
$
|
(4.50
|
)
|
Diluted:
|
|
|
|
|
|
||||||
Net Income (Loss) Available for Common Stock
|
$
|
3.30
|
|
|
$
|
(3.43
|
)
|
|
$
|
(4.50
|
)
|
Weighted Average Common Shares Outstanding:
|
|
|
|
|
|
||||||
Used in Basic Calculation
|
85,364,929
|
|
|
84,847,993
|
|
|
84,387,755
|
|
|||
Used in Diluted Calculation
|
86,021,386
|
|
|
84,847,993
|
|
|
84,387,755
|
|
|
Year Ended September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
|
(Thousands of dollars)
|
||||||||||
Net Income (Loss) Available for Common Stock
|
$
|
283,482
|
|
|
$
|
(290,958
|
)
|
|
$
|
(379,427
|
)
|
Other Comprehensive Income (Loss), Before Tax:
|
|
|
|
|
|
||||||
Increase (Decrease) in the Funded Status of the Pension and Other Post-Retirement Benefit Plans
|
15,661
|
|
|
(21,378
|
)
|
|
(31,538
|
)
|
|||
Reclassification Adjustment for Amortization of Prior Year Funded Status of the Pension and Other Post-Retirement Benefit Plans
|
13,433
|
|
|
10,068
|
|
|
9,217
|
|
|||
Unrealized Gain (Loss) on Securities Available for Sale Arising During the Period
|
4,008
|
|
|
1,524
|
|
|
(3,234
|
)
|
|||
Unrealized Gain (Loss) on Derivative Financial Instruments Arising During the Period
|
5,347
|
|
|
60,493
|
|
|
381,018
|
|
|||
Reclassification Adjustment for Realized (Gains) Losses on Securities Available for Sale in Net Income
|
(1,575
|
)
|
|
(1,374
|
)
|
|
(591
|
)
|
|||
Reclassification Adjustment for Realized (Gains) Losses on Derivative Financial Instruments in Net Income
|
(81,605
|
)
|
|
(220,919
|
)
|
|
(184,953
|
)
|
|||
Other Comprehensive Income (Loss), Before Tax
|
(44,731
|
)
|
|
(171,586
|
)
|
|
169,919
|
|
|||
Income Tax Expense (Benefit) Related to the Increase (Decrease) in the Funded Status of the Pension and Other Post-Retirement Benefit Plans
|
6,175
|
|
|
(8,351
|
)
|
|
(11,922
|
)
|
|||
Reclassification Adjustment for Income Tax Benefit Related to the Amortization of the Prior Year Funded Status of the Pension and Other Post-Retirement Benefit Plans
|
4,929
|
|
|
3,723
|
|
|
3,375
|
|
|||
Income Tax Expense (Benefit) Related to Unrealized Gain (Loss) on Securities Available for Sale Arising During the Period
|
1,505
|
|
|
592
|
|
|
(1,195
|
)
|
|||
Income Tax Expense (Benefit) Related to Unrealized Gain (Loss) on Derivative Financial Instruments Arising During the Period
|
2,009
|
|
|
18,648
|
|
|
160,872
|
|
|||
Reclassification Adjustment for Income Tax Benefit (Expense) on Realized Losses (Gains) from Securities Available for Sale in Net Income
|
(580
|
)
|
|
(527
|
)
|
|
(217
|
)
|
|||
Reclassification Adjustment for Income Tax Benefit (Expense) on Realized Losses (Gains) from Derivative Financial Instruments in Net Income
|
(34,286
|
)
|
|
(86,659
|
)
|
|
(78,345
|
)
|
|||
Income Taxes — Net
|
(20,248
|
)
|
|
(72,574
|
)
|
|
72,568
|
|
|||
Other Comprehensive Income (Loss)
|
(24,483
|
)
|
|
(99,012
|
)
|
|
97,351
|
|
|||
Comprehensive Income (Loss)
|
$
|
258,999
|
|
|
$
|
(389,970
|
)
|
|
$
|
(282,076
|
)
|
|
Year Ended September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
|
(Thousands of dollars)
|
||||||||||
Operating Activities
|
|
|
|
|
|
||||||
Net Income (Loss) Available for Common Stock
|
$
|
283,482
|
|
|
$
|
(290,958
|
)
|
|
$
|
(379,427
|
)
|
Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities:
|
|
|
|
|
|
||||||
Impairment of Oil and Gas Producing Properties
|
—
|
|
|
948,307
|
|
|
1,126,257
|
|
|||
Depreciation, Depletion and Amortization
|
224,195
|
|
|
249,417
|
|
|
336,158
|
|
|||
Deferred Income Taxes
|
117,975
|
|
|
(246,794
|
)
|
|
(357,587
|
)
|
|||
Excess Tax Benefits Associated with Stock-Based Compensation Awards
|
—
|
|
|
(1,868
|
)
|
|
(9,064
|
)
|
|||
Stock-Based Compensation
|
12,262
|
|
|
5,755
|
|
|
3,208
|
|
|||
Other
|
16,476
|
|
|
12,620
|
|
|
9,823
|
|
|||
Change in:
|
|
|
|
|
|
||||||
Hedging Collateral Deposits
|
(257
|
)
|
|
9,640
|
|
|
(8,390
|
)
|
|||
Receivables and Unbilled Revenue
|
(3,380
|
)
|
|
(6,408
|
)
|
|
51,638
|
|
|||
Gas Stored Underground and Materials and Supplies
|
(1,417
|
)
|
|
(3,532
|
)
|
|
3,438
|
|
|||
Unrecovered Purchased Gas Costs
|
(2,183
|
)
|
|
(2,440
|
)
|
|
—
|
|
|||
Other Current Assets
|
7,849
|
|
|
3,179
|
|
|
3,150
|
|
|||
Accounts Payable
|
17,192
|
|
|
(40,664
|
)
|
|
34,687
|
|
|||
Amounts Payable to Customers
|
(19,537
|
)
|
|
(37,241
|
)
|
|
23,033
|
|
|||
Customer Advances
|
939
|
|
|
(1,474
|
)
|
|
(2,769
|
)
|
|||
Customer Security Deposits
|
4,353
|
|
|
(471
|
)
|
|
729
|
|
|||
Other Accruals and Current Liabilities
|
27,004
|
|
|
3,453
|
|
|
(7,173
|
)
|
|||
Other Assets
|
(2,885
|
)
|
|
1,941
|
|
|
2,696
|
|
|||
Other Liabilities
|
2,183
|
|
|
(13,483
|
)
|
|
23,173
|
|
|||
Net Cash Provided by Operating Activities
|
684,251
|
|
|
588,979
|
|
|
853,580
|
|
|||
Investing Activities
|
|
|
|
|
|
||||||
Capital Expenditures
|
(450,335
|
)
|
|
(581,576
|
)
|
|
(1,018,179
|
)
|
|||
Net Proceeds from Sale of Oil and Gas Producing Properties
|
26,554
|
|
|
137,316
|
|
|
—
|
|
|||
Other
|
1,216
|
|
|
(9,236
|
)
|
|
(6,611
|
)
|
|||
Net Cash Used in Investing Activities
|
(422,565
|
)
|
|
(453,496
|
)
|
|
(1,024,790
|
)
|
|||
Financing Activities
|
|
|
|
|
|
||||||
Change in Notes Payable to Banks and Commercial Paper
|
—
|
|
|
—
|
|
|
(85,600
|
)
|
|||
Excess Tax Benefits Associated with Stock-Based Compensation Awards
|
—
|
|
|
1,868
|
|
|
9,064
|
|
|||
Net Proceeds from Issuance of Long-Term Debt
|
295,151
|
|
|
—
|
|
|
444,635
|
|
|||
Net Proceeds from Issuance of Common Stock
|
7,784
|
|
|
13,849
|
|
|
10,540
|
|
|||
Dividends Paid on Common Stock
|
(139,063
|
)
|
|
(134,824
|
)
|
|
(130,719
|
)
|
|||
Net Cash Provided by (Used in) Financing Activities
|
163,872
|
|
|
(119,107
|
)
|
|
247,920
|
|
|||
Net Increase in Cash and Temporary Cash Investments
|
425,558
|
|
|
16,376
|
|
|
76,710
|
|
|||
Cash and Temporary Cash Investments At Beginning of Year
|
129,972
|
|
|
113,596
|
|
|
36,886
|
|
|||
Cash and Temporary Cash Investments At End of Year
|
$
|
555,530
|
|
|
$
|
129,972
|
|
|
$
|
113,596
|
|
Supplemental Disclosure of Cash Flow Information
|
|
|
|
|
|
||||||
Cash Paid For:
|
|
|
|
|
|
||||||
Interest
|
$
|
116,894
|
|
|
$
|
119,563
|
|
|
$
|
90,747
|
|
Income Taxes
|
$
|
34,826
|
|
|
$
|
34,240
|
|
|
$
|
18,657
|
|
Non-Cash Investing Activities:
|
|
|
|
|
|
||||||
Non-Cash Capital Expenditures
|
$
|
72,216
|
|
|
$
|
60,434
|
|
|
$
|
118,959
|
|
Receivable from Sale of Oil and Gas Producing Properties
|
$
|
—
|
|
|
$
|
19,543
|
|
|
$
|
—
|
|
|
As of September 30
|
||||||
|
2017
|
|
2016
|
||||
|
(Thousands)
|
||||||
Exploration and Production
|
$
|
4,925,409
|
|
|
$
|
4,645,226
|
|
Pipeline and Storage
|
2,002,736
|
|
|
1,956,708
|
|
||
Gathering
|
484,768
|
|
|
454,343
|
|
||
Utility
|
2,045,074
|
|
|
1,998,605
|
|
||
Energy Marketing
|
3,564
|
|
|
3,528
|
|
||
All Other and Corporate
|
109,128
|
|
|
109,455
|
|
||
|
$
|
9,570,679
|
|
|
$
|
9,167,865
|
|
|
Year Ended September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
Exploration and Production, per Mcfe(1)
|
$
|
0.65
|
|
|
$
|
0.87
|
|
|
$
|
1.52
|
|
Pipeline and Storage
|
2.2
|
%
|
|
2.4
|
%
|
|
2.4
|
%
|
|||
Gathering
|
3.4
|
%
|
|
4.0
|
%
|
|
4.0
|
%
|
|||
Utility
|
2.8
|
%
|
|
2.7
|
%
|
|
2.6
|
%
|
|||
Energy Marketing
|
7.9
|
%
|
|
7.9
|
%
|
|
6.1
|
%
|
|||
All Other and Corporate
|
1.3
|
%
|
|
1.8
|
%
|
|
1.4
|
%
|
|
(1)
|
Amounts include depletion of oil and gas producing properties as well as depreciation of fixed assets. As disclosed in Note M — Supplementary Information for Oil and Gas Producing Activities, depletion of oil and gas producing properties amounted to
$0.63
,
$0.85
and
$1.49
per Mcfe of production in
2017
,
2016
and
2015
, respectively.
|
|
Gains and Losses on Derivative Financial Instruments
|
|
Gains and Losses on Securities Available for Sale
|
|
Funded Status of the Pension and Other Post-Retirement Benefit Plans
|
|
Total
|
||||||||
Year Ended September 30, 2017
|
|
|
|
|
|
|
|
||||||||
Balance at October 1, 2016
|
$
|
64,782
|
|
|
$
|
6,054
|
|
|
$
|
(76,476
|
)
|
|
$
|
(5,640
|
)
|
Other Comprehensive Gains and Losses Before Reclassifications
|
3,338
|
|
|
2,503
|
|
|
9,486
|
|
|
15,327
|
|
||||
Amounts Reclassified From Other Comprehensive Loss
|
(47,319
|
)
|
|
(995
|
)
|
|
8,504
|
|
|
(39,810
|
)
|
||||
Balance at September 30, 2017
|
$
|
20,801
|
|
|
$
|
7,562
|
|
|
$
|
(58,486
|
)
|
|
$
|
(30,123
|
)
|
|
|
|
|
|
|
|
|
||||||||
Year Ended September 30, 2016
|
|
|
|
|
|
|
|
||||||||
Balance at October 1, 2015
|
$
|
157,197
|
|
|
$
|
5,969
|
|
|
$
|
(69,794
|
)
|
|
$
|
93,372
|
|
Other Comprehensive Gains and Losses Before Reclassifications
|
41,845
|
|
|
932
|
|
|
(13,027
|
)
|
|
29,750
|
|
||||
Amounts Reclassified From Other Comprehensive Loss
|
(134,260
|
)
|
|
(847
|
)
|
|
6,345
|
|
|
(128,762
|
)
|
||||
Balance at September 30, 2016
|
$
|
64,782
|
|
|
$
|
6,054
|
|
|
$
|
(76,476
|
)
|
|
$
|
(5,640
|
)
|
Details About Accumulated Other
Comprehensive Income (Loss) Components
|
|
Amount of Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) for the
Year Ended
September 30,
|
|
Affected Line Item in the Statement Where Net Income (Loss) is Presented
|
||||||
|
|
2017
|
|
2016
|
|
|
||||
Gains (Losses) on Derivative Financial Instrument Cash Flow Hedges:
|
|
|
|
|
|
|
||||
Commodity Contracts
|
|
|
$83,983
|
|
|
|
$216,823
|
|
|
Operating Revenues
|
Commodity Contracts
|
|
(1,921
|
)
|
|
4,520
|
|
|
Purchased Gas
|
||
Foreign Currency Contracts
|
|
(457
|
)
|
|
(424
|
)
|
|
Operation and Maintenance Expense
|
||
Gains (Losses) on Securities Available for Sale
|
|
1,575
|
|
|
1,374
|
|
|
Other Income
|
||
Amortization of Prior Year Funded Status of the Pension and Other Post-Retirement Benefit Plans:
|
|
|
|
|
|
|
||||
Prior Service Credit
|
|
(288
|
)
|
|
(333
|
)
|
|
(1)
|
||
Net Actuarial Loss
|
|
(13,145
|
)
|
|
(9,735
|
)
|
|
(1)
|
||
|
|
69,747
|
|
|
212,225
|
|
|
Total Before Income Tax
|
||
|
|
(29,937
|
)
|
|
(83,463
|
)
|
|
Income Tax Expense
|
||
|
|
|
$39,810
|
|
|
|
$128,762
|
|
|
Net of Tax
|
|
(1)
|
These accumulated other comprehensive income (loss) components are included in the computation of net periodic benefit cost. Refer to Note H — Retirement Plan and Other Post-Retirement Benefits for additional details.
|
|
Year Ended September 30
|
||||||
|
2017
|
|
2016
|
||||
|
(Thousands)
|
||||||
Prepayments
|
$
|
10,927
|
|
|
$
|
10,919
|
|
Prepaid Property and Other Taxes
|
13,974
|
|
|
13,138
|
|
||
Federal Income Taxes Receivable
|
—
|
|
|
11,758
|
|
||
State Income Taxes Receivable
|
9,689
|
|
|
3,961
|
|
||
Fair Values of Firm Commitments
|
1,031
|
|
|
3,962
|
|
||
Regulatory Assets
|
15,884
|
|
|
15,616
|
|
||
|
$
|
51,505
|
|
|
$
|
59,354
|
|
|
Year Ended September 30
|
||||||
|
2017
|
|
2016
|
||||
|
(Thousands)
|
||||||
Accrued Capital Expenditures
|
$
|
37,382
|
|
|
$
|
26,796
|
|
Regulatory Liabilities
|
34,059
|
|
|
14,725
|
|
||
Federal Income Taxes Payable
|
1,775
|
|
|
—
|
|
||
Other
|
38,673
|
|
|
32,909
|
|
||
|
$
|
111,889
|
|
|
$
|
74,430
|
|
|
Year Ended September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
|
(Thousands)
|
||||||||||
Balance at Beginning of Year
|
$
|
112,330
|
|
|
$
|
156,805
|
|
|
$
|
117,713
|
|
Liabilities Incurred
|
2,963
|
|
|
2,719
|
|
|
4,433
|
|
|||
Revisions of Estimates
|
(10,578
|
)
|
|
16,721
|
|
|
33,717
|
|
|||
Liabilities Settled
|
(4,967
|
)
|
|
(72,215
|
)
|
|
(6,825
|
)
|
|||
Accretion Expense
|
6,647
|
|
|
8,300
|
|
|
7,767
|
|
|||
Balance at End of Year
|
$
|
106,395
|
|
|
$
|
112,330
|
|
|
$
|
156,805
|
|
|
At September 30
|
||||||
|
2017
|
|
2016
|
||||
|
(Thousands)
|
||||||
Regulatory Assets(1):
|
|
|
|
||||
Pension Costs(2) (Note H)
|
$
|
125,175
|
|
|
$
|
203,755
|
|
Post-Retirement Benefit Costs(2) (Note H)
|
13,886
|
|
|
74,802
|
|
||
Recoverable Future Taxes (Note D)
|
181,363
|
|
|
177,261
|
|
||
Environmental Site Remediation Costs(2) (Note I)
|
19,665
|
|
|
23,392
|
|
||
Asset Retirement Obligations(2) (Note B)
|
12,764
|
|
|
12,490
|
|
||
Unamortized Debt Expense (Note A)
|
1,159
|
|
|
1,688
|
|
||
Other(3)
|
18,827
|
|
|
21,927
|
|
||
Total Regulatory Assets
|
372,839
|
|
|
515,315
|
|
||
Less: Amounts Included in Other Current Assets
|
(15,884
|
)
|
|
(15,616
|
)
|
||
Total Long-Term Regulatory Assets
|
$
|
356,955
|
|
|
$
|
499,699
|
|
|
At September 30
|
||||||
|
2017
|
|
2016
|
||||
|
(Thousands)
|
||||||
Regulatory Liabilities:
|
|
|
|
||||
Cost of Removal Regulatory Liability
|
$
|
204,630
|
|
|
$
|
193,424
|
|
Taxes Refundable to Customers (Note D)
|
95,739
|
|
|
93,318
|
|
||
Post-Retirement Benefit Costs (Note H)
|
102,891
|
|
|
67,204
|
|
||
Amounts Payable to Customers (See Regulatory Mechanisms in Note A)
|
—
|
|
|
19,537
|
|
||
Other(4)
|
44,884
|
|
|
47,310
|
|
||
Total Regulatory Liabilities
|
448,144
|
|
|
420,793
|
|
||
Less: Amounts included in Current and Accrued Liabilities
|
(34,059
|
)
|
|
(34,262
|
)
|
||
Total Long-Term Regulatory Liabilities
|
$
|
414,085
|
|
|
$
|
386,531
|
|
|
(1)
|
The Company recovers the cost of its regulatory assets but generally does not earn a return on them. There are a few exceptions to this rule. For example, the Company does earn a return on Unrecovered Purchased Gas Costs and, in the New York jurisdiction of its Utility segment, earns a return, within certain parameters, on the excess of cumulative funding to the pension plan over the cumulative amount collected in rates.
|
(2)
|
Included in Other Regulatory Assets on the Consolidated Balance Sheets.
|
(3)
|
$15,884
and
$15,616
are included in Other Current Assets on the Consolidated Balance Sheets at September 30, 2017 and 2016, respectively, since such amounts are expected to be recovered from ratepayers in the next 12 months.
$2,943
and
$6,311
are included in Other Regulatory Assets on the Consolidated Balance Sheets at September 30, 2017 and 2016, respectively.
|
(4)
|
$34,059
and
$14,725
are included in Other Accruals and Current Liabilities on the Consolidated Balance Sheets at September 30, 2017 and 2016, respectively, since such amounts are expected to be recovered from ratepayers in the next 12 months.
$10,825
and
$32,585
are included in Other Regulatory Liabilities on the Consolidated Balance Sheets at September 30, 2017 and 2016, respectively.
|
|
Year Ended September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
|
(Thousands)
|
||||||||||
Current Income Taxes —
|
|
|
|
|
|
||||||
Federal
|
$
|
32,034
|
|
|
$
|
(6,658
|
)
|
|
$
|
25,064
|
|
State
|
10,673
|
|
|
20,903
|
|
|
13,387
|
|
|||
Deferred Income Taxes —
|
|
|
|
|
|
||||||
Federal
|
103,046
|
|
|
(164,818
|
)
|
|
(244,336
|
)
|
|||
State
|
14,929
|
|
|
(81,976
|
)
|
|
(113,251
|
)
|
|||
|
160,682
|
|
|
(232,549
|
)
|
|
(319,136
|
)
|
|||
Deferred Investment Tax Credit
|
(173
|
)
|
|
(348
|
)
|
|
(414
|
)
|
|||
Total Income Taxes
|
$
|
160,509
|
|
|
$
|
(232,897
|
)
|
|
$
|
(319,550
|
)
|
Presented as Follows:
|
|
|
|
|
|
||||||
Other Income
|
$
|
(173
|
)
|
|
$
|
(348
|
)
|
|
$
|
(414
|
)
|
Income Tax Expense (Benefit)
|
160,682
|
|
|
(232,549
|
)
|
|
(319,136
|
)
|
|||
Total Income Taxes
|
$
|
160,509
|
|
|
$
|
(232,897
|
)
|
|
$
|
(319,550
|
)
|
|
Year Ended September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
|
(Thousands)
|
||||||||||
U.S. Income (Loss) Before Income Taxes
|
$
|
443,991
|
|
|
$
|
(523,855
|
)
|
|
$
|
(698,977
|
)
|
Income Tax Expense (Benefit), Computed at U.S. Federal Statutory Rate of 35%
|
$
|
155,397
|
|
|
$
|
(183,349
|
)
|
|
$
|
(244,642
|
)
|
State Income Taxes (Benefit)
|
16,641
|
|
|
(39,697
|
)
|
|
(64,912
|
)
|
|||
Federal Tax Credits
|
(6,679
|
)
|
|
(3,262
|
)
|
|
(732
|
)
|
|||
Miscellaneous
|
(4,850
|
)
|
|
(6,589
|
)
|
|
(9,264
|
)
|
|||
Total Income Taxes
|
$
|
160,509
|
|
|
$
|
(232,897
|
)
|
|
$
|
(319,550
|
)
|
|
At September 30
|
||||||
|
2017
|
|
2016
|
||||
|
(Thousands)
|
||||||
Deferred Tax Liabilities:
|
|
|
|
||||
Property, Plant and Equipment
|
$
|
1,141,432
|
|
|
$
|
1,049,100
|
|
Pension and Other Post-Retirement Benefit Costs
|
79,516
|
|
|
151,903
|
|
||
Unrealized Hedging Gains
|
19,127
|
|
|
50,179
|
|
||
Other
|
57,919
|
|
|
55,457
|
|
||
Total Deferred Tax Liabilities
|
1,297,994
|
|
|
1,306,639
|
|
||
Deferred Tax Assets:
|
|
|
|
||||
Pension and Other Post-Retirement Benefit Costs
|
(123,532
|
)
|
|
(195,829
|
)
|
||
Tax Loss and Credit Carryforwards
|
(200,344
|
)
|
|
(194,875
|
)
|
||
Other
|
(82,831
|
)
|
|
(92,140
|
)
|
||
Total Deferred Tax Assets
|
(406,707
|
)
|
|
(482,844
|
)
|
||
Total Net Deferred Income Taxes
|
$
|
891,287
|
|
|
$
|
823,795
|
|
|
Year Ended September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
|
(Thousands)
|
||||||||||
Balance at Beginning of Year
|
$
|
396
|
|
|
$
|
5,085
|
|
|
$
|
3,147
|
|
Additions for Tax Positions of Prior Years
|
1,251
|
|
|
396
|
|
|
2,504
|
|
|||
Reductions for Tax Positions of Prior Years
|
(396
|
)
|
|
(1,314
|
)
|
|
(566
|
)
|
|||
Reductions Related to Settlements with Taxing Authorities
|
—
|
|
|
(3,771
|
)
|
|
—
|
|
|||
Balance at End of Year
|
$
|
1,251
|
|
|
$
|
396
|
|
|
$
|
5,085
|
|
Jurisdiction
|
|
Tax Attribute
|
|
Amount
(Thousands)
|
|
Expires
|
||
Federal
|
|
Net Operating Loss
|
|
$
|
184,289
|
|
|
2028-2033
|
Pennsylvania
|
|
Net Operating Loss
|
|
324,572
|
|
|
2030-2035
|
|
California
|
|
Net Operating Loss
|
|
169,723
|
|
|
2029-2035
|
|
Federal
|
|
Alternative Minimum Tax Credit
|
|
81,683
|
|
|
Unlimited
|
|
California
|
|
Alternative Minimum Tax Credit
|
|
5,873
|
|
|
Unlimited
|
|
Federal
|
|
Enhanced Oil Recovery Credit
|
|
10,502
|
|
|
2029-2037
|
|
California
|
|
Enhanced Oil Recovery Credit
|
|
5,061
|
|
|
2021-2037
|
|
Federal
|
|
R&D Tax Credit
|
|
5,694
|
|
|
2031-2036
|
|
Common Stock
|
|
Paid In
Capital
|
|
Earnings
Reinvested
in the
Business
|
|
Accumulated
Other
Comprehensive
Income (Loss)
|
|||||||||||
Shares
|
|
Amount
|
|
|||||||||||||||
|
(Thousands, except per share amounts)
|
|||||||||||||||||
Balance at September 30, 2014
|
84,157
|
|
|
$
|
84,157
|
|
|
$
|
716,144
|
|
|
$
|
1,614,361
|
|
|
$
|
(3,979
|
)
|
Net Income (Loss) Available for Common Stock
|
|
|
|
|
|
|
(379,427
|
)
|
|
|
||||||||
Dividends Declared on Common Stock ($1.56 Per Share)
|
|
|
|
|
|
|
(131,734
|
)
|
|
|
||||||||
Other Comprehensive Income, Net of Tax
|
|
|
|
|
|
|
|
|
97,351
|
|
||||||||
Share-Based Payment Expense(2)
|
|
|
|
|
2,207
|
|
|
|
|
|
||||||||
Common Stock Issued Under Stock and Benefit Plans(1)
|
437
|
|
|
437
|
|
|
25,923
|
|
|
|
|
|
||||||
Balance at September 30, 2015
|
84,594
|
|
|
84,594
|
|
|
744,274
|
|
|
1,103,200
|
|
|
93,372
|
|
||||
Net Income (Loss) Available for Common Stock
|
|
|
|
|
|
|
(290,958
|
)
|
|
|
||||||||
Dividends Declared on Common Stock ($1.60 Per Share)
|
|
|
|
|
|
|
(135,881
|
)
|
|
|
||||||||
Other Comprehensive Loss, Net of Tax
|
|
|
|
|
|
|
|
|
(99,012
|
)
|
||||||||
Share-Based Payment Expense(2)
|
|
|
|
|
4,843
|
|
|
|
|
|
||||||||
Common Stock Issued Under Stock and Benefit Plans(1)
|
525
|
|
|
525
|
|
|
22,047
|
|
|
|
|
|
||||||
Balance at September 30, 2016
|
85,119
|
|
|
85,119
|
|
|
771,164
|
|
|
676,361
|
|
|
(5,640
|
)
|
||||
Net Income Available for Common Stock
|
|
|
|
|
|
|
283,482
|
|
|
|
||||||||
Dividends Declared on Common Stock ($1.64 Per Share)
|
|
|
|
|
|
|
(140,090
|
)
|
|
|
||||||||
Cumulative Effect of Adoption of Authoritative Guidance for Stock-Based Compensation
|
|
|
|
|
|
|
31,916
|
|
|
|
||||||||
Other Comprehensive Loss, Net of Tax
|
|
|
|
|
|
|
|
|
(24,483
|
)
|
||||||||
Share-Based Payment Expense(2)
|
|
|
|
|
10,902
|
|
|
|
|
|
||||||||
Common Stock Issued Under Stock and Benefit Plans
|
424
|
|
|
424
|
|
|
14,580
|
|
|
|
|
|
||||||
Balance at September 30, 2017
|
85,543
|
|
|
$
|
85,543
|
|
|
$
|
796,646
|
|
|
$
|
851,669
|
|
(3)
|
$
|
(30,123
|
)
|
|
(1)
|
Paid in Capital includes tax benefits of
$1.9 million
and
$9.1 million
for September 30, 2016 and 2015, respectively, related to stock-based compensation.
|
(2)
|
Paid in Capital includes compensation costs associated with stock option, SARs, performance share and/or restricted stock awards. The expense is included within Net Income Available For Common Stock, net of tax benefits.
|
(3)
|
The availability of consolidated earnings reinvested in the business for dividends payable in cash is limited under terms of the indentures covering long-term debt. At September 30, 2017,
$707.5 million
of accumulated earnings was free of such limitations.
|
|
Number of
Shares Subject
to Option
|
|
Weighted
Average
Exercise Price
|
|
Weighted
Average
Remaining
Contractual
Life (Years)
|
|
Aggregate
Intrinsic
Value
(In thousands)
|
||||||
Outstanding at September 30, 2016
|
19,000
|
|
|
$
|
39.48
|
|
|
|
|
|
|||
Granted in 2017
|
—
|
|
|
$
|
—
|
|
|
|
|
|
|||
Exercised in 2017
|
(19,000
|
)
|
|
$
|
39.48
|
|
|
|
|
|
|||
Forfeited in 2017
|
—
|
|
|
$
|
—
|
|
|
|
|
|
|||
Outstanding at September 30, 2017
|
—
|
|
|
$
|
—
|
|
|
—
|
|
|
$
|
—
|
|
Option shares exercisable at September 30, 2017
|
—
|
|
|
$
|
—
|
|
|
—
|
|
|
$
|
—
|
|
Shares available for future grant at September 30, 2017(1)
|
2,182,243
|
|
|
|
|
|
|
|
|
(1)
|
Includes shares available for options, SARs, restricted stock and performance share grants.
|
|
Number of
Shares Subject
To Option
|
|
Weighted
Average
Exercise Price
|
|
Weighted
Average
Remaining
Contractual
Life (Years)
|
|
Aggregate
Intrinsic
Value
(In thousands)
|
|||||
Outstanding at September 30, 2016
|
1,590,988
|
|
|
$
|
48.19
|
|
|
|
|
|
||
Granted in 2017
|
—
|
|
|
$
|
—
|
|
|
|
|
|
||
Exercised in 2017
|
(82,077
|
)
|
|
$
|
39.77
|
|
|
|
|
|
||
Forfeited in 2017
|
—
|
|
|
$
|
—
|
|
|
|
|
|
||
Expired in 2017
|
(3,000
|
)
|
|
$
|
52.10
|
|
|
|
|
|
||
Outstanding at September 30, 2017
|
1,505,911
|
|
|
$
|
48.64
|
|
|
2.52
|
|
$
|
13,144
|
|
SARs exercisable at September 30, 2017
|
1,505,911
|
|
|
$
|
48.64
|
|
|
2.52
|
|
$
|
13,144
|
|
|
|
|
|
|
|
|
Number of
Restricted
Share Awards
|
|
Weighted Average
Fair Value per
Award
|
|||
Outstanding at September 30, 2016
|
20,000
|
|
|
$
|
47.46
|
|
Granted in 2017
|
—
|
|
|
$
|
—
|
|
Vested in 2017
|
—
|
|
|
$
|
—
|
|
Forfeited in 2017
|
—
|
|
|
$
|
—
|
|
Outstanding at September 30, 2017
|
20,000
|
|
|
$
|
47.46
|
|
|
Number of
Restricted
Stock Units
|
|
Weighted Average
Fair Value per
Award
|
|||
Outstanding at September 30, 2016
|
239,151
|
|
|
$
|
49.67
|
|
Granted in 2017
|
87,143
|
|
|
$
|
52.13
|
|
Vested in 2017
|
(80,530
|
)
|
|
$
|
53.38
|
|
Forfeited in 2017
|
(12,565
|
)
|
|
$
|
53.75
|
|
Outstanding at September 30, 2017
|
233,199
|
|
|
$
|
48.99
|
|
|
Number of
Performance
Shares
|
|
Weighted Average
Fair Value per
Award
|
|||
Outstanding at September 30, 2016
|
438,234
|
|
|
$
|
44.98
|
|
Granted in 2017
|
184,148
|
|
|
$
|
56.39
|
|
Vested in 2017
|
(43,484
|
)
|
|
$
|
69.13
|
|
Forfeited in 2017
|
(51,150
|
)
|
|
$
|
60.74
|
|
Outstanding at September 30, 2017
|
527,748
|
|
|
$
|
45.44
|
|
|
Year Ended September 30
|
|||||||
|
2017
|
|
2016
|
|
2015
|
|||
Risk-Free Interest Rate
|
1.54
|
%
|
|
1.26
|
%
|
|
1.01
|
%
|
Remaining Term at Date of Grant (Years)
|
2.79
|
|
|
2.79
|
|
|
2.78
|
|
Expected Volatility
|
22.6
|
%
|
|
20.5
|
%
|
|
20.1
|
%
|
Expected Dividend Yield (Quarterly)
|
N/A
|
|
|
N/A
|
|
|
N/A
|
|
|
At September 30
|
||||||
|
2017
|
|
2016
|
||||
|
(Thousands)
|
||||||
Medium-Term Notes(1):
|
|
|
|
||||
7.4% due March 2023 to June 2025
|
$
|
99,000
|
|
|
$
|
99,000
|
|
Notes(1)(3)(4):
|
|
|
|
||||
3.75% to 8.75% due April 2018 to September 2027
|
2,300,000
|
|
|
2,000,000
|
|
||
Total Long-Term Debt
|
2,399,000
|
|
|
2,099,000
|
|
||
Less Unamortized Discount and Debt Issuance Costs
|
15,319
|
|
|
12,748
|
|
||
Less Current Portion(2)
|
300,000
|
|
|
—
|
|
||
|
$
|
2,083,681
|
|
|
$
|
2,086,252
|
|
|
(1)
|
The Medium-Term Notes and Notes are unsecured.
|
(2)
|
Current Portion of Long-Term Debt at September 30, 2017 consisted of
$300.0 million
of
6.50%
notes scheduled to mature in April 2018. The Company redeemed these notes on October 18, 2017 for
$307.0 million
, plus accrued interest. The call premium was recorded to Unamortized Debt Expense on the Consolidated Balance Sheet in October 2017.
|
(3)
|
The holders of these notes may require the Company to repurchase their notes at a price equal to 101% of the principal amount in the event of both a change in control and a ratings downgrade to a rating below investment grade.
|
(4)
|
The interest rate payable on
$300.0 million
of
3.95%
notes will be subject to adjustment from time to time, with a maximum of
2.00%
, if certain change of control events involving a material subsidiary result in a downgrade of the credit rating assigned to the notes to below investment grade (or if the credit rating assigned to the notes is subsequently upgraded).
|
|
At Fair Value as of September 30, 2017
|
||||||||||||||||||
Recurring Fair Value Measures
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Netting
Adjustments(1)
|
|
Total(1)
|
||||||||||
|
(Dollars in thousands)
|
||||||||||||||||||
Assets:
|
|
|
|
|
|
|
|
|
|
||||||||||
Cash Equivalents — Money Market Mutual Funds
|
$
|
527,978
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
527,978
|
|
Derivative Financial Instruments:
|
|
|
|
|
|
|
|
|
|
||||||||||
Commodity Futures Contracts — Gas
|
1,483
|
|
|
—
|
|
|
—
|
|
|
(963
|
)
|
|
520
|
|
|||||
Over the Counter Swaps — Gas and Oil
|
—
|
|
|
38,977
|
|
|
—
|
|
|
(4,206
|
)
|
|
34,771
|
|
|||||
Foreign Currency Contracts
|
—
|
|
|
1,227
|
|
|
—
|
|
|
(407
|
)
|
|
820
|
|
|||||
Other Investments:
|
|
|
|
|
|
|
|
|
|
||||||||||
Balanced Equity Mutual Fund
|
37,033
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
37,033
|
|
|||||
Fixed Income Mutual Fund
|
45,727
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
45,727
|
|
|||||
Common Stock — Financial Services Industry
|
3,150
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
3,150
|
|
|||||
Hedging Collateral Deposits
|
1,741
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
1,741
|
|
|||||
Total
|
$
|
617,112
|
|
|
$
|
40,204
|
|
|
$
|
—
|
|
|
$
|
(5,576
|
)
|
|
$
|
651,740
|
|
Liabilities:
|
|
|
|
|
|
|
|
|
|
||||||||||
Derivative Financial Instruments:
|
|
|
|
|
|
|
|
|
|
||||||||||
Commodity Futures Contracts — Gas
|
$
|
963
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
(963
|
)
|
|
$
|
—
|
|
Over the Counter Swaps — Gas and Oil
|
—
|
|
|
5,309
|
|
|
—
|
|
|
(4,206
|
)
|
|
1,103
|
|
|||||
Foreign Currency Contracts
|
—
|
|
|
407
|
|
|
—
|
|
|
(407
|
)
|
|
—
|
|
|||||
Total
|
$
|
963
|
|
|
$
|
5,716
|
|
|
$
|
—
|
|
|
$
|
(5,576
|
)
|
|
$
|
1,103
|
|
Total Net Assets/(Liabilities)
|
$
|
616,149
|
|
|
$
|
34,488
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
650,637
|
|
|
At Fair Value as of September 30, 2016
|
||||||||||||||||||
Recurring Fair Value Measures
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Netting
Adjustments(1)
|
|
Total(1)
|
||||||||||
|
(Dollars in thousands)
|
||||||||||||||||||
Assets:
|
|
|
|
|
|
|
|
|
|
||||||||||
Cash Equivalents — Money Market Mutual Funds
|
$
|
113,407
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
113,407
|
|
Derivative Financial Instruments:
|
|
|
|
|
|
|
|
|
|
||||||||||
Commodity Futures Contracts — Gas
|
2,623
|
|
|
—
|
|
|
—
|
|
|
(2,276
|
)
|
|
347
|
|
|||||
Over the Counter Swaps — Gas and Oil
|
—
|
|
|
119,654
|
|
|
—
|
|
|
(3,860
|
)
|
|
115,794
|
|
|||||
Foreign Currency Contracts
|
—
|
|
|
—
|
|
|
—
|
|
|
(2,337
|
)
|
|
(2,337
|
)
|
|||||
Other Investments:
|
|
|
|
|
|
|
|
|
|
||||||||||
Balanced Equity Mutual Fund
|
36,658
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
36,658
|
|
|||||
Fixed Income Mutual Fund
|
31,395
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
31,395
|
|
|||||
Common Stock — Financial Services Industry
|
2,902
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
2,902
|
|
|||||
Hedging Collateral Deposits
|
1,484
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
1,484
|
|
|||||
Total
|
$
|
188,469
|
|
|
$
|
119,654
|
|
|
$
|
—
|
|
|
$
|
(8,473
|
)
|
|
$
|
299,650
|
|
Liabilities:
|
|
|
|
|
|
|
|
|
|
||||||||||
Derivative Financial Instruments:
|
|
|
|
|
|
|
|
|
|
||||||||||
Commodity Futures Contracts — Gas
|
$
|
2,276
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
(2,276
|
)
|
|
$
|
—
|
|
Over the Counter Swaps — Gas and Oil
|
—
|
|
|
5,322
|
|
|
—
|
|
|
(3,860
|
)
|
|
1,462
|
|
|||||
Foreign Currency Contracts
|
—
|
|
|
2,337
|
|
|
—
|
|
|
(2,337
|
)
|
|
—
|
|
|||||
Total
|
$
|
2,276
|
|
|
$
|
7,659
|
|
|
$
|
—
|
|
|
$
|
(8,473
|
)
|
|
$
|
1,462
|
|
Total Net Assets/(Liabilities)
|
$
|
186,193
|
|
|
$
|
111,995
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
298,188
|
|
|
(1)
|
Netting Adjustments represent the impact of legally-enforceable master netting arrangements that allow the Company to net gain and loss positions held with the same counterparties. The net asset or net liability for each counterparty is recorded as an asset or liability on the Company’s balance sheet.
|
|
At September 30
|
||||||||||||||
|
2017 Carrying
Amount
|
|
2017 Fair
Value
|
|
2016 Carrying
Amount
|
|
2016 Fair
Value
|
||||||||
|
(Thousands)
|
||||||||||||||
Long-Term Debt
|
$
|
2,383,681
|
|
|
$
|
2,523,639
|
|
|
$
|
2,086,252
|
|
|
$
|
2,255,562
|
|
Commodity
|
Units
|
|
|
Natural Gas
|
114.3
|
|
Bcf (short positions)
|
Natural Gas
|
1.0
|
|
Bcf (long positions)
|
Crude Oil
|
3,459,000
|
|
Bbls (short positions)
|
Derivatives in Fair Value Hedging Relationships
|
|
Location of Gain or (Loss) on Derivative and Hedged Item Recognized in the Consolidated Statement of Income
|
|
Amount of Gain or
(Loss) on Derivative
Recognized in the
Consolidated
Statement of Income
for the Year Ended
September 30, 2017
|
|
Amount of Gain or
(Loss) on Hedged Item
Recognized in the
Consolidated
Statement of Income
for the Year Ended
September 30, 2017
|
||||
|
|
|
|
(In thousands)
|
||||||
Commodity Contracts
|
|
Operating Revenues
|
|
$
|
1,655
|
|
|
$
|
(1,655
|
)
|
Commodity Contracts
|
|
Purchased Gas
|
|
464
|
|
|
(464
|
)
|
||
|
|
|
|
$
|
2,119
|
|
|
$
|
(2,119
|
)
|
|
Retirement Plan
|
|
Other Post-Retirement Benefits
|
||||||||||||||||||||
|
Year Ended September 30
|
|
Year Ended September 30
|
||||||||||||||||||||
|
2017
|
|
2016
|
|
2015
|
|
2017
|
|
2016
|
|
2015
|
||||||||||||
|
(Thousands)
|
||||||||||||||||||||||
Change in Benefit Obligation
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Benefit Obligation at Beginning of Period
|
$
|
1,097,421
|
|
|
$
|
1,026,190
|
|
|
$
|
999,499
|
|
|
$
|
526,138
|
|
|
$
|
464,987
|
|
|
$
|
465,583
|
|
Service Cost
|
11,969
|
|
|
11,710
|
|
|
12,047
|
|
|
2,449
|
|
|
2,331
|
|
|
2,693
|
|
||||||
Interest Cost
|
38,383
|
|
|
42,315
|
|
|
41,217
|
|
|
19,007
|
|
|
20,386
|
|
|
19,285
|
|
||||||
Plan Participants’ Contributions
|
—
|
|
|
—
|
|
|
—
|
|
|
2,717
|
|
|
2,558
|
|
|
2,242
|
|
||||||
Retiree Drug Subsidy Receipts
|
—
|
|
|
—
|
|
|
—
|
|
|
1,553
|
|
|
1,925
|
|
|
1,338
|
|
||||||
Amendments(1)
|
—
|
|
|
—
|
|
|
7,752
|
|
|
—
|
|
|
—
|
|
|
—
|
|
||||||
Actuarial (Gain) Loss
|
(32,466
|
)
|
|
76,309
|
|
|
23,426
|
|
|
(62,215
|
)
|
|
60,402
|
|
|
(1,575
|
)
|
||||||
Benefits Paid
|
(60,481
|
)
|
|
(59,103
|
)
|
|
(57,751
|
)
|
|
(27,030
|
)
|
|
(26,451
|
)
|
|
(24,579
|
)
|
||||||
Benefit Obligation at End of Period
|
$
|
1,054,826
|
|
|
$
|
1,097,421
|
|
|
$
|
1,026,190
|
|
|
$
|
462,619
|
|
|
$
|
526,138
|
|
|
$
|
464,987
|
|
Change in Plan Assets
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Fair Value of Assets at Beginning of Period
|
$
|
869,775
|
|
|
$
|
834,870
|
|
|
$
|
869,791
|
|
|
$
|
494,320
|
|
|
$
|
477,959
|
|
|
$
|
497,601
|
|
Actual Return on Plan Assets
|
84,279
|
|
|
87,008
|
|
|
(13,370
|
)
|
|
40,157
|
|
|
37,415
|
|
|
534
|
|
||||||
Employer Contributions
|
17,146
|
|
|
7,000
|
|
|
36,200
|
|
|
3,853
|
|
|
2,839
|
|
|
2,161
|
|
||||||
Plan Participants’ Contributions
|
—
|
|
|
—
|
|
|
—
|
|
|
2,717
|
|
|
2,558
|
|
|
2,242
|
|
||||||
Benefits Paid
|
(60,481
|
)
|
|
(59,103
|
)
|
|
(57,751
|
)
|
|
(27,030
|
)
|
|
(26,451
|
)
|
|
(24,579
|
)
|
||||||
Fair Value of Assets at End of Period
|
$
|
910,719
|
|
|
$
|
869,775
|
|
|
$
|
834,870
|
|
|
$
|
514,017
|
|
|
$
|
494,320
|
|
|
$
|
477,959
|
|
Net Amount Recognized at End of Period (Funded Status)
|
$
|
(144,107
|
)
|
|
$
|
(227,646
|
)
|
|
$
|
(191,320
|
)
|
|
$
|
51,398
|
|
|
$
|
(31,818
|
)
|
|
$
|
12,972
|
|
Amounts Recognized in the Balance Sheets Consist of:
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Non-Current Liabilities
|
$
|
(144,107
|
)
|
|
$
|
(227,646
|
)
|
|
$
|
(191,320
|
)
|
|
$
|
(4,972
|
)
|
|
$
|
(49,467
|
)
|
|
$
|
(11,487
|
)
|
Non-Current Assets
|
—
|
|
|
—
|
|
|
—
|
|
|
56,370
|
|
|
17,649
|
|
|
24,459
|
|
||||||
Net Amount Recognized at End of Period
|
$
|
(144,107
|
)
|
|
$
|
(227,646
|
)
|
|
$
|
(191,320
|
)
|
|
$
|
51,398
|
|
|
$
|
(31,818
|
)
|
|
$
|
12,972
|
|
Accumulated Benefit Obligation
|
$
|
1,010,179
|
|
|
$
|
1,039,408
|
|
|
$
|
968,984
|
|
|
N/A
|
|
|
N/A
|
|
|
N/A
|
|
|||
Weighted Average Assumptions Used to Determine Benefit Obligation at September 30
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Discount Rate
|
3.77
|
%
|
|
3.60
|
%
|
|
4.25
|
%
|
|
3.81
|
%
|
|
3.70
|
%
|
|
4.50
|
%
|
||||||
Rate of Compensation Increase
|
4.70
|
%
|
|
4.70
|
%
|
|
4.75
|
%
|
|
4.70
|
%
|
|
4.70
|
%
|
|
4.75
|
%
|
|
Retirement Plan
|
|
Other Post-Retirement Benefits
|
||||||||||||||||||||
|
Year Ended September 30
|
|
Year Ended September 30
|
||||||||||||||||||||
|
2017
|
|
2016
|
|
2015
|
|
2017
|
|
2016
|
|
2015
|
||||||||||||
|
(Thousands)
|
||||||||||||||||||||||
Components of Net Periodic Benefit Cost
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Service Cost
|
$
|
11,969
|
|
|
$
|
11,710
|
|
|
$
|
12,047
|
|
|
$
|
2,449
|
|
|
$
|
2,331
|
|
|
$
|
2,693
|
|
Interest Cost
|
38,383
|
|
|
42,315
|
|
|
41,217
|
|
|
19,007
|
|
|
20,386
|
|
|
19,285
|
|
||||||
Expected Return on Plan Assets
|
(59,718
|
)
|
|
(59,369
|
)
|
|
(59,615
|
)
|
|
(31,458
|
)
|
|
(31,535
|
)
|
|
(34,089
|
)
|
||||||
Amortization of Prior Service Cost (Credit)
|
1,058
|
|
|
1,234
|
|
|
183
|
|
|
(429
|
)
|
|
(912
|
)
|
|
(1,913
|
)
|
||||||
Recognition of Actuarial Loss(2)
|
42,687
|
|
|
32,248
|
|
|
36,129
|
|
|
18,415
|
|
|
5,530
|
|
|
4,148
|
|
||||||
Net Amortization and Deferral for Regulatory Purposes
|
469
|
|
|
3,957
|
|
|
7,739
|
|
|
6,108
|
|
|
17,123
|
|
|
20,322
|
|
||||||
Net Periodic Benefit Cost
|
$
|
34,848
|
|
|
$
|
32,095
|
|
|
$
|
37,700
|
|
|
$
|
14,092
|
|
|
$
|
12,923
|
|
|
$
|
10,446
|
|
Weighted Average Assumptions Used to Determine Net Periodic Benefit Cost at September 30
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Discount Rate
|
3.60
|
%
|
|
4.25
|
%
|
|
4.25
|
%
|
|
3.70
|
%
|
|
4.50
|
%
|
|
4.25
|
%
|
||||||
Expected Return on Plan Assets
|
7.00
|
%
|
|
7.25
|
%
|
|
7.50
|
%
|
|
6.50
|
%
|
|
6.75
|
%
|
|
7.00
|
%
|
||||||
Rate of Compensation Increase
|
4.75
|
%
|
|
4.75
|
%
|
|
4.75
|
%
|
|
4.75
|
%
|
|
4.75
|
%
|
|
4.75
|
%
|
|
(1)
|
In fiscal 2015, the Company passed an amendment which updated the mortality table used in the Retirement Plan's definition of "actuarially equivalent" effective July 1, 2015. This increased the benefit obligation of the Retirement Plan.
|
(2)
|
Distribution Corporation’s New York jurisdiction calculates the amortization of the actuarial loss on a vintage year basis over
10 years
, as mandated by the NYPSC. All the other subsidiaries of the Company utilize the corridor approach.
|
|
Retirement
Plan
|
|
Other
Post-Retirement
Benefits
|
|
Non-Qualified
Benefit Plans
|
||||||
|
(Thousands)
|
||||||||||
Amounts Recognized in Accumulated Other Comprehensive Income (Loss), Regulatory Assets and Regulatory Liabilities(1)
|
|
|
|
|
|
||||||
Net Actuarial Loss
|
$
|
(203,887
|
)
|
|
$
|
(19,578
|
)
|
|
$
|
(24,332
|
)
|
Prior Service (Cost) Credit
|
(6,133
|
)
|
|
3,687
|
|
|
—
|
|
|||
Net Amount Recognized
|
$
|
(210,020
|
)
|
|
$
|
(15,891
|
)
|
|
$
|
(24,332
|
)
|
Changes to Accumulated Other Comprehensive Income (Loss), Regulatory Assets and Regulatory Liabilities Recognized During Fiscal 2017(1)
|
|
|
|
|
|
||||||
Decrease (Increase) in Actuarial Loss, excluding amortization(2)
|
$
|
57,028
|
|
|
$
|
70,915
|
|
|
$
|
(1,351
|
)
|
Change due to Amortization of Actuarial Loss
|
42,687
|
|
|
18,415
|
|
|
4,059
|
|
|||
Prior Service (Cost) Credit
|
1,058
|
|
|
(429
|
)
|
|
—
|
|
|||
Net Change
|
$
|
100,773
|
|
|
$
|
88,901
|
|
|
$
|
2,708
|
|
Amounts Expected to be Recognized in Net Periodic Benefit Cost in the Next Fiscal Year(1)
|
|
|
|
|
|
||||||
Net Actuarial Loss
|
$
|
(37,205
|
)
|
|
$
|
(10,558
|
)
|
|
$
|
(3,549
|
)
|
Prior Service (Cost) Credit
|
(938
|
)
|
|
429
|
|
|
—
|
|
|||
Net Amount Expected to be Recognized
|
$
|
(38,143
|
)
|
|
$
|
(10,129
|
)
|
|
$
|
(3,549
|
)
|
|
(1)
|
Amounts presented are shown before recognizing deferred taxes.
|
(2)
|
Amounts presented include the impact of actuarial gains/losses related to return on assets, as well as the Actuarial (Gain) Loss amounts presented in the Change in Benefit Obligation.
|
|
Benefit Payments
|
|
Subsidy Receipts
|
||||
2018
|
$
|
26,483
|
|
|
$
|
(1,910
|
)
|
2019
|
$
|
27,456
|
|
|
$
|
(2,074
|
)
|
2020
|
$
|
28,359
|
|
|
$
|
(2,225
|
)
|
2021
|
$
|
29,173
|
|
|
$
|
(2,369
|
)
|
2022
|
$
|
29,757
|
|
|
$
|
(2,515
|
)
|
2023 through 2027
|
$
|
152,957
|
|
|
$
|
(14,271
|
)
|
|
2017
|
|
|
2016
|
|
|
2015
|
|
|||
Rate of Medical Cost Increase for Pre Age 65 Participants
|
5.67
|
%
|
(1)
|
|
5.75
|
%
|
(1)
|
|
6.93
|
%
|
(2)
|
Rate of Medical Cost Increase for Post Age 65 Participants
|
4.75
|
%
|
(1)
|
|
4.75
|
%
|
(1)
|
|
6.68
|
%
|
(2)
|
Annual Rate of Increase in the Per Capita Cost of Covered Prescription Drug Benefits
|
8.45
|
%
|
(1)
|
|
9.00
|
%
|
(1)
|
|
7.17
|
%
|
(2)
|
Annual Rate of Increase in the Per Capita Medicare Part B Reimbursement
|
4.75
|
%
|
(1)
|
|
4.75
|
%
|
(1)
|
|
6.68
|
%
|
(2)
|
Annual Rate of Increase in the Per Capita Medicare Part D Subsidy
|
7.33
|
%
|
(1)
|
|
7.20
|
%
|
(1)
|
|
6.65
|
%
|
(2)
|
|
(1)
|
It was assumed that this rate would gradually decline to
4.5%
by 2039.
|
(2)
|
It was assumed that this rate would gradually decline to
4.5%
by 2028.
|
|
Total Fair
Value Amounts at
September 30, 2017
|
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Measured at NAV(7)
|
||||||||||
Retirement Plan Investments
|
|
|
|
|
|
|
|
|
|
||||||||||
Domestic Equities(1)
|
$
|
290,716
|
|
|
$
|
209,421
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
81,295
|
|
International Equities(2)
|
123,069
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
123,069
|
|
|||||
Global Equities(3)
|
121,008
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
121,008
|
|
|||||
Domestic Fixed Income(4)
|
348,501
|
|
|
1,664
|
|
|
346,837
|
|
|
—
|
|
|
—
|
|
|||||
International Fixed Income(5)
|
422
|
|
|
422
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|||||
Global Fixed Income(6)
|
75,428
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
75,428
|
|
|||||
Real Estate
|
3,391
|
|
|
—
|
|
|
—
|
|
|
3,391
|
|
|
—
|
|
|||||
Cash Held in Collective Trust Funds
|
26,058
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
26,058
|
|
|||||
Total Retirement Plan Investments
|
988,593
|
|
|
211,507
|
|
|
346,837
|
|
|
3,391
|
|
|
426,858
|
|
|||||
401(h) Investments
|
(64,728
|
)
|
|
(14,026
|
)
|
|
(23,001
|
)
|
|
(225
|
)
|
|
(27,476
|
)
|
|||||
Total Retirement Plan Investments (excluding 401(h) Investments)
|
$
|
923,865
|
|
|
$
|
197,481
|
|
|
$
|
323,836
|
|
|
$
|
3,166
|
|
|
$
|
399,382
|
|
Miscellaneous Accruals, Interest Receivables, and Non-Interest Cash
|
(13,146
|
)
|
|
|
|
|
|
|
|
|
|||||||||
Total Retirement Plan Assets
|
$
|
910,719
|
|
|
|
|
|
|
|
|
|
|
Total Fair
Value
Amounts at September 30, 2016 |
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Measured at NAV(7)
|
||||||||||
Retirement Plan Investments
|
|
|
|
|
|
|
|
|
|
||||||||||
Domestic Equities(1)
|
$
|
256,796
|
|
|
$
|
188,253
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
68,543
|
|
International Equities(2)
|
104,592
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
104,592
|
|
|||||
Global Equities(3)
|
120,025
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
120,025
|
|
|||||
Domestic Fixed Income(4)
|
342,442
|
|
|
1,647
|
|
|
340,795
|
|
|
—
|
|
|
—
|
|
|||||
International Fixed Income(5)
|
744
|
|
|
407
|
|
|
337
|
|
|
—
|
|
|
—
|
|
|||||
Global Fixed Income(6)
|
81,146
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
81,146
|
|
|||||
Real Estate
|
2,970
|
|
|
—
|
|
|
—
|
|
|
2,970
|
|
|
—
|
|
|||||
Cash Held in Collective Trust Funds
|
24,812
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
24,812
|
|
|||||
Total Retirement Plan Investments
|
933,527
|
|
|
190,307
|
|
|
341,132
|
|
|
2,970
|
|
|
399,118
|
|
|||||
401(h) Investments
|
(58,707
|
)
|
|
(12,025
|
)
|
|
(21,555
|
)
|
|
(188
|
)
|
|
(24,939
|
)
|
|||||
Total Retirement Plan Investments (excluding 401(h) Investments)
|
$
|
874,820
|
|
|
$
|
178,282
|
|
|
$
|
319,577
|
|
|
$
|
2,782
|
|
|
$
|
374,179
|
|
Miscellaneous Accruals, Interest Receivables, and Non-Interest Cash
|
(5,045
|
)
|
|
|
|
|
|
|
|
|
|||||||||
Total Retirement Plan Assets
|
$
|
869,775
|
|
|
|
|
|
|
|
|
|
|
(1)
|
Domestic Equities include mostly collective trust funds, common stock, and exchange traded funds.
|
(2)
|
International Equities are comprised of collective trust funds.
|
(3)
|
Global Equities are comprised of collective trust funds.
|
(4)
|
Domestic Fixed Income securities include mostly collective trust funds, corporate/government bonds and mortgages, and exchange traded funds.
|
(5)
|
International Fixed Income securities are comprised mostly of an exchange traded fund.
|
(6)
|
Global Fixed Income securities are comprised of a collective trust fund.
|
(7)
|
Reflects the adoption of the new authoritative guidance related to investments measured at the net asset value (NAV) practical expedient.
|
|
Total Fair
Value
Amounts at September 30, 2017 |
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Measured at NAV(1)
|
||||||||||
Other Post-Retirement Benefit Assets held in VEBA Trusts
|
|
|
|
|
|
|
|
|
|
||||||||||
Collective Trust Funds — Domestic Equities
|
$
|
130,864
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
130,864
|
|
Collective Trust Funds — International Equities
|
52,063
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
52,063
|
|
|||||
Exchange Traded Funds — Fixed Income
|
256,099
|
|
|
256,099
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|||||
Cash Held in Collective Trust Funds
|
9,569
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
9,569
|
|
|||||
Total VEBA Trust Investments
|
448,595
|
|
|
256,099
|
|
|
—
|
|
|
—
|
|
|
192,496
|
|
|||||
401(h) Investments
|
64,728
|
|
|
14,026
|
|
|
23,001
|
|
|
225
|
|
|
27,476
|
|
|||||
Total Investments (including 401(h) Investments)
|
$
|
513,323
|
|
|
$
|
270,125
|
|
|
$
|
23,001
|
|
|
$
|
225
|
|
|
$
|
219,972
|
|
Miscellaneous Accruals (Including Current and Deferred Taxes, Claims Incurred But Not Reported, Administrative)
|
694
|
|
|
|
|
|
|
|
|
|
|||||||||
Total Other Post-Retirement Benefit Assets
|
$
|
514,017
|
|
|
|
|
|
|
|
|
|
|
Total Fair
Value
Amounts at September 30, 2016 |
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Measured at NAV(1)
|
||||||||||
Other Post-Retirement Benefit Assets held in VEBA Trusts
|
|
|
|
|
|
|
|
|
|
||||||||||
Collective Trust Funds — Domestic Equities
|
$
|
139,617
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
139,617
|
|
Collective Trust Funds — International Equities
|
51,488
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
51,488
|
|
|||||
Exchange Traded Funds — Fixed Income
|
230,761
|
|
|
230,761
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|||||
Cash Held in Collective Trust Funds
|
13,176
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
13,176
|
|
|||||
Total VEBA Trust Investments
|
435,042
|
|
|
230,761
|
|
|
—
|
|
|
—
|
|
|
204,281
|
|
|||||
401(h) Investments
|
58,707
|
|
|
12,025
|
|
|
21,555
|
|
|
188
|
|
|
24,939
|
|
|||||
Total Investments (including 401(h) Investments)
|
$
|
493,749
|
|
|
$
|
242,786
|
|
|
$
|
21,555
|
|
|
$
|
188
|
|
|
$
|
229,220
|
|
Miscellaneous Accruals (Including Current and Deferred Taxes, Claims Incurred But Not Reported, Administrative)
|
571
|
|
|
|
|
|
|
|
|
|
|||||||||
Total Other Post-Retirement Benefit Assets
|
$
|
494,320
|
|
|
|
|
|
|
|
|
|
|
(1)
|
Reflects the adoption of the new authoritative guidance related to investments measured at the net asset value (NAV) practical expedient.
|
|
Retirement Plan Level 3 Assets
(Thousands)
|
|||||||||||||||
|
Hedge
Funds
|
|
Real
Estate
|
|
Excluding
401(h)
Investments
|
|
Total
|
|||||||||
Balance at September 30, 2015
|
$
|
26,490
|
|
|
$
|
4,724
|
|
|
$
|
(1,885
|
)
|
|
$
|
29,329
|
|
|
Realized Gains/(Losses)
|
5,878
|
|
|
—
|
|
|
(354
|
)
|
|
5,524
|
|
|||||
Unrealized Gains/(Losses)
|
(5,445
|
)
|
|
(404
|
)
|
|
344
|
|
|
(5,505
|
)
|
|||||
Sales
|
(26,923
|
)
|
|
(1,350
|
)
|
|
1,707
|
|
|
(26,566
|
)
|
|||||
Balance at September 30, 2016
|
—
|
|
|
2,970
|
|
|
(188
|
)
|
|
2,782
|
|
|||||
Unrealized Gains/(Losses)
|
—
|
|
|
421
|
|
|
(37
|
)
|
|
384
|
|
|||||
Balance at September 30, 2017
|
$
|
—
|
|
|
$
|
3,391
|
|
|
$
|
(225
|
)
|
|
$
|
3,166
|
|
|
|
Other Post-Retirement Benefit Level 3 Assets
(Thousands)
|
||
|
|
401(h)
Investments
|
||
|
|
|||
Balance at September 30, 2015
|
|
$
|
1,885
|
|
Realized Gains/(Losses)
|
|
354
|
|
|
Unrealized Gains/(Losses)
|
|
(344
|
)
|
|
Sales
|
|
(1,707
|
)
|
|
Balance at September 30, 2016
|
|
188
|
|
|
Unrealized Gains/(Losses)
|
|
37
|
|
|
Balance at September 30, 2017
|
|
$
|
225
|
|
|
Year Ended September 30, 2015
|
||||||||||||||||||||||||||||||||||
|
Exploration
and Production |
|
Pipeline
and
Storage
|
|
Gathering
|
|
Utility
|
|
Energy
Marketing
|
|
Total
Reportable
Segments
|
|
All
Other
|
|
Corporate
and
Intersegment
Eliminations
|
|
Total
Consolidated
|
||||||||||||||||||
|
(Thousands)
|
||||||||||||||||||||||||||||||||||
Revenue from External Customers(1)
|
$
|
693,441
|
|
|
$
|
203,089
|
|
|
$
|
497
|
|
|
$
|
700,761
|
|
|
$
|
159,857
|
|
|
$
|
1,757,645
|
|
|
$
|
2,352
|
|
|
$
|
916
|
|
|
$
|
1,760,913
|
|
Intersegment Revenues
|
$
|
—
|
|
|
$
|
88,251
|
|
|
$
|
76,709
|
|
|
$
|
15,506
|
|
|
$
|
849
|
|
|
$
|
181,315
|
|
|
$
|
—
|
|
|
$
|
(181,315
|
)
|
|
$
|
—
|
|
Interest Income
|
$
|
2,554
|
|
|
$
|
474
|
|
|
$
|
140
|
|
|
$
|
2,220
|
|
|
$
|
195
|
|
|
$
|
5,583
|
|
|
$
|
66
|
|
|
$
|
(1,727
|
)
|
|
$
|
3,922
|
|
Interest Expense
|
$
|
46,726
|
|
|
$
|
27,658
|
|
|
$
|
1,627
|
|
|
$
|
28,176
|
|
|
$
|
27
|
|
|
$
|
104,214
|
|
|
$
|
—
|
|
|
$
|
(4,743
|
)
|
|
$
|
99,471
|
|
Depreciation, Depletion and Amortization
|
$
|
239,818
|
|
|
$
|
38,178
|
|
|
$
|
10,829
|
|
|
$
|
45,616
|
|
|
$
|
209
|
|
|
$
|
334,650
|
|
|
$
|
832
|
|
|
$
|
676
|
|
|
$
|
336,158
|
|
Income Tax Expense (Benefit)
|
$
|
(428,217
|
)
|
|
$
|
48,113
|
|
|
$
|
24,721
|
|
|
$
|
33,143
|
|
|
$
|
4,547
|
|
|
$
|
(317,693
|
)
|
|
$
|
13
|
|
|
$
|
(1,456
|
)
|
|
$
|
(319,136
|
)
|
Significant Non-Cash Item: Impairment of Oil and Gas Producing Properties
|
$
|
1,126,257
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
1,126,257
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
1,126,257
|
|
Segment Profit: Net Income (Loss)
|
$
|
(556,974
|
)
|
|
$
|
80,354
|
|
|
$
|
31,849
|
|
|
$
|
63,271
|
|
|
$
|
7,766
|
|
|
$
|
(373,734
|
)
|
|
$
|
(2
|
)
|
|
$
|
(5,691
|
)
|
|
$
|
(379,427
|
)
|
Expenditures for Additions to Long-Lived Assets
|
$
|
557,313
|
|
|
$
|
230,192
|
|
|
$
|
118,166
|
|
|
$
|
94,371
|
|
|
$
|
128
|
|
|
$
|
1,000,170
|
|
|
$
|
—
|
|
|
$
|
339
|
|
|
$
|
1,000,509
|
|
|
At September 30, 2015
|
||||||||||||||||||||||||||||||||||
|
(Thousands)
|
||||||||||||||||||||||||||||||||||
Segment Assets
|
$
|
2,439,801
|
|
|
$
|
1,590,524
|
|
|
$
|
444,358
|
|
|
$
|
1,934,731
|
|
|
$
|
90,676
|
|
|
$
|
6,500,090
|
|
|
$
|
77,350
|
|
|
$
|
(12,501
|
)
|
|
$
|
6,564,939
|
|
|
(1)
|
All Revenue from External Customers originated in the United States.
|
Geographic Information
|
At September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
|
(Thousands)
|
||||||||||
Long-Lived Assets:
|
|
|
|
|
|
||||||
United States
|
$
|
5,285,040
|
|
|
$
|
5,223,356
|
|
|
$
|
6,189,138
|
|
Quarter Ended
|
Operating
Revenues
|
|
Operating
Income (Loss)
|
|
Net
Income (Loss)
Available for
Common Stock
|
|
Earnings (Loss) per
Common Share
|
|||||||||||||
Basic
|
|
Diluted
|
||||||||||||||||||
|
(Thousands, except per common share amounts)
|
|||||||||||||||||||
2017
|
|
|
|
|
|
|
|
|
|
|||||||||||
9/30/2017
|
$
|
286,937
|
|
|
$
|
87,395
|
|
|
$
|
45,577
|
|
|
$
|
0.53
|
|
|
$
|
0.53
|
|
|
6/30/2017
|
$
|
348,369
|
|
|
$
|
123,354
|
|
|
$
|
59,714
|
|
|
$
|
0.70
|
|
|
$
|
0.69
|
|
|
3/31/2017
|
$
|
522,075
|
|
|
$
|
169,957
|
|
|
$
|
89,283
|
|
|
$
|
1.05
|
|
|
$
|
1.04
|
|
|
12/31/2016
|
$
|
422,500
|
|
|
$
|
172,139
|
|
|
$
|
88,908
|
|
|
$
|
1.04
|
|
|
$
|
1.04
|
|
|
2016
|
|
|
|
|
|
|
|
|
|
|||||||||||
9/30/2016
|
$
|
292,472
|
|
|
$
|
81,244
|
|
|
$
|
37,553
|
|
(1)
|
$
|
0.44
|
|
|
$
|
0.44
|
|
|
6/30/2016
|
$
|
335,617
|
|
|
$
|
45,162
|
|
|
$
|
8,286
|
|
(2)
|
$
|
0.10
|
|
|
$
|
0.10
|
|
|
3/31/2016
|
$
|
449,132
|
|
|
$
|
(237,000
|
)
|
|
$
|
(147,688
|
)
|
(3)
|
$
|
(1.74
|
)
|
|
$
|
(1.74
|
)
|
|
12/31/2015
|
$
|
375,195
|
|
|
$
|
(305,924
|
)
|
|
$
|
(189,109
|
)
|
(4)
|
$
|
(2.23
|
)
|
|
$
|
(2.23
|
)
|
|
(1)
|
Includes a non-cash
$32.7 million
impairment charge (
$19.0 million
after tax) associated with the Exploration and Production segment's oil and gas producing properties.
|
(2)
|
Includes a non-cash
$82.7 million
impairment charge (
$47.9 million
after tax) associated with the Exploration and Production segment's oil and gas producing properties.
|
(3)
|
Includes a non-cash
$397.4 million
impairment charge (
$230.5 million
after tax) associated with the Exploration and Production segment's oil and gas producing properties.
|
(4)
|
Includes a non-cash $
435.5 million
impairment charge (
$252.6 million
after tax) associated with the Exploration and Production segment's oil and gas producing properties.
|
|
Price Range
|
|
Dividends
Declared
|
||||||||
Quarter Ended
|
High
|
|
Low
|
|
|||||||
2017
|
|
|
|
|
|
||||||
9/30/2017
|
$
|
59.92
|
|
|
$
|
54.89
|
|
|
$
|
0.415
|
|
6/30/2017
|
$
|
61.20
|
|
|
$
|
53.03
|
|
|
$
|
0.415
|
|
3/31/2017
|
$
|
61.25
|
|
|
$
|
54.67
|
|
|
$
|
0.405
|
|
12/31/2016
|
$
|
58.78
|
|
|
$
|
50.61
|
|
|
$
|
0.405
|
|
2016
|
|
|
|
|
|
||||||
9/30/2016
|
$
|
59.62
|
|
|
$
|
53.81
|
|
|
$
|
0.405
|
|
6/30/2016
|
$
|
57.06
|
|
|
$
|
47.49
|
|
|
$
|
0.405
|
|
3/31/2016
|
$
|
51.53
|
|
|
$
|
39.79
|
|
|
$
|
0.395
|
|
12/31/2015
|
$
|
56.64
|
|
|
$
|
37.03
|
|
|
$
|
0.395
|
|
|
At September 30
|
||||||
|
2017
|
|
2016
|
||||
|
(Thousands)
|
||||||
Proved Properties(1)
|
$
|
4,832,301
|
|
|
$
|
4,554,929
|
|
Unproved Properties
|
80,932
|
|
|
135,285
|
|
||
|
4,913,233
|
|
|
4,690,214
|
|
||
Less — Accumulated Depreciation, Depletion and Amortization
|
3,765,710
|
|
|
3,657,239
|
|
||
|
$
|
1,147,523
|
|
|
$
|
1,032,975
|
|
|
(1)
|
Includes asset retirement costs of
$54.4 million
and
$63.6 million
at September 30, 2017 and 2016, respectively.
|
|
Total as of
September 30,
2017
|
|
Year Costs Incurred
|
||||||||||||||||
|
|
2017
|
|
2016
|
|
2015
|
|
Prior
|
|||||||||||
|
(Thousands)
|
||||||||||||||||||
Acquisition Costs
|
$
|
55,193
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
55,193
|
|
Development Costs
|
11,879
|
|
|
4,388
|
|
|
6,707
|
|
|
416
|
|
|
368
|
|
|||||
Exploration Costs
|
13,388
|
|
|
2,376
|
|
|
7,593
|
|
|
3,419
|
|
|
—
|
|
|||||
Capitalized Interest
|
472
|
|
|
235
|
|
|
149
|
|
|
88
|
|
|
—
|
|
|||||
|
$
|
80,932
|
|
|
$
|
6,999
|
|
|
$
|
14,449
|
|
|
$
|
3,923
|
|
|
$
|
55,561
|
|
|
Year Ended September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
|
(Thousands)
|
||||||||||
United States
|
|
||||||||||
Property Acquisition Costs:
|
|
|
|
|
|
||||||
Proved
|
$
|
8,908
|
|
|
$
|
1,342
|
|
|
$
|
1,767
|
|
Unproved
|
262
|
|
|
2,165
|
|
|
19,998
|
|
|||
Exploration Costs(1)
|
40,975
|
|
|
27,561
|
|
|
53,222
|
|
|||
Development Costs(2)
|
200,639
|
|
|
219,386
|
|
|
454,605
|
|
|||
Asset Retirement Costs
|
(9,175
|
)
|
|
(49,653
|
)
|
|
37,595
|
|
|||
|
$
|
241,609
|
|
|
$
|
200,801
|
|
|
$
|
567,187
|
|
|
(1)
|
Amounts for 2017, 2016 and 2015 include capitalized interest of
$0.3 million
,
$0.3 million
and
$0.4 million
, respectively.
|
(2)
|
Amounts for 2017, 2016 and 2015 include capitalized interest of
$0.2 million
,
$0.2 million
and
$0.5 million
, respectively.
|
|
Year Ended September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
United States
|
(Thousands, except per Mcfe amounts)
|
||||||||||
Operating Revenues:
|
|
|
|
|
|
||||||
Natural Gas (includes transfers to operations of $2,357, $1,765 and $1,946, respectively)(1)
|
$
|
399,975
|
|
|
$
|
282,619
|
|
|
$
|
350,673
|
|
Oil, Condensate and Other Liquids
|
126,517
|
|
|
103,533
|
|
|
156,048
|
|
|||
Total Operating Revenues(2)
|
526,492
|
|
|
386,152
|
|
|
506,721
|
|
|||
Production/Lifting Costs
|
165,991
|
|
|
153,914
|
|
|
167,800
|
|
|||
Franchise/Ad Valorem Taxes
|
15,372
|
|
|
13,794
|
|
|
20,167
|
|
|||
Purchased Emission Allowance Expense
|
1,391
|
|
|
700
|
|
|
3,089
|
|
|||
Accretion Expense
|
4,896
|
|
|
6,663
|
|
|
6,186
|
|
|||
Depreciation, Depletion and Amortization ($0.63, $0.85 and $1.49 per Mcfe of production, respectively)
|
108,471
|
|
|
136,579
|
|
|
234,480
|
|
|||
Impairment of Oil and Gas Producing Properties
|
—
|
|
|
948,307
|
|
|
1,126,257
|
|
|||
Income Tax Expense (Benefit)
|
86,657
|
|
|
(368,940
|
)
|
|
(444,393
|
)
|
|||
Results of Operations for Producing Activities (excluding corporate overheads and interest charges)
|
$
|
143,714
|
|
|
$
|
(504,865
|
)
|
|
$
|
(606,865
|
)
|
|
(1)
|
There were no revenues from sales to affiliates for all years presented.
|
(2)
|
Exclusive of hedging gains and losses. See further discussion in Note G — Financial Instruments.
|
|
(1)
|
Extensions and discoveries include
598
Bcf (during 2015),
179
Bcf (during 2016) and
181
Bcf (during 2017), of Marcellus Shale gas in the Appalachian region.
|
(2)
|
Production includes
130,291
MMcf (during 2015),
135,598
MMcf (during 2016) and
145,452
MMcf (during 2017), from Marcellus Shale fields (which exceed
15%
of total reserves).
|
|
Oil Mbbl
|
|||||||
|
U. S.
|
|
|
|||||
|
Appalachian
Region
|
|
West Coast
Region
|
|
Total
Company
|
|||
Proved Developed and Undeveloped Reserves:
|
|
|
|
|
|
|||
September 30, 2014
|
253
|
|
|
38,224
|
|
|
38,477
|
|
Extensions and Discoveries
|
—
|
|
|
533
|
|
|
533
|
|
Revisions of Previous Estimates
|
(3
|
)
|
|
(2,251
|
)
|
|
(2,254
|
)
|
Production
|
(30
|
)
|
|
(3,004
|
)
|
|
(3,034
|
)
|
September 30, 2015
|
220
|
|
|
33,502
|
|
|
33,722
|
|
Extensions and Discoveries
|
—
|
|
|
530
|
|
|
530
|
|
Revisions of Previous Estimates
|
(46
|
)
|
|
(2,201
|
)
|
|
(2,247
|
)
|
Production
|
(28
|
)
|
|
(2,895
|
)
|
|
(2,923
|
)
|
Sales of Minerals in Place
|
(73
|
)
|
|
—
|
|
|
(73
|
)
|
September 30, 2016
|
73
|
|
|
28,936
|
|
|
29,009
|
|
Extensions and Discoveries
|
—
|
|
|
674
|
|
|
674
|
|
Revisions of Previous Estimates
|
(12
|
)
|
|
3,305
|
|
|
3,293
|
|
Production
|
(4
|
)
|
|
(2,736
|
)
|
|
(2,740
|
)
|
Sales of Minerals in Place
|
(29
|
)
|
|
—
|
|
|
(29
|
)
|
September 30, 2017
|
28
|
|
|
30,179
|
|
|
30,207
|
|
Proved Developed Reserves:
|
|
|
|
|
|
|||
September 30, 2014
|
253
|
|
|
37,002
|
|
|
37,255
|
|
September 30, 2015
|
220
|
|
|
33,150
|
|
|
33,370
|
|
September 30, 2016
|
73
|
|
|
28,698
|
|
|
28,771
|
|
September 30, 2017
|
28
|
|
|
29,771
|
|
|
29,799
|
|
Proved Undeveloped Reserves:
|
|
|
|
|
|
|
||
September 30, 2014
|
—
|
|
|
1,222
|
|
|
1,222
|
|
September 30, 2015
|
—
|
|
|
352
|
|
|
352
|
|
September 30, 2016
|
—
|
|
|
238
|
|
|
238
|
|
September 30, 2017
|
—
|
|
|
408
|
|
|
408
|
|
|
Year Ended September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
|
(Thousands)
|
||||||||||
United States
|
|
|
|
|
|
||||||
Future Cash Inflows
|
$
|
6,144,317
|
|
|
$
|
3,768,463
|
|
|
$
|
6,916,775
|
|
Less:
|
|
|
|
|
|
||||||
Future Production Costs
|
2,378,262
|
|
|
1,994,916
|
|
|
2,854,142
|
|
|||
Future Development Costs
|
411,578
|
|
|
375,152
|
|
|
761,922
|
|
|||
Future Income Tax Expense at Applicable Statutory Rate
|
1,160,469
|
|
|
303,397
|
|
|
1,117,433
|
|
|||
Future Net Cash Flows
|
2,194,008
|
|
|
1,094,998
|
|
|
2,183,278
|
|
|||
Less:
|
|
|
|
|
|
||||||
10% Annual Discount for Estimated Timing of Cash Flows
|
1,080,962
|
|
|
452,470
|
|
|
860,244
|
|
|||
Standardized Measure of Discounted Future Net Cash Flows
|
$
|
1,113,046
|
|
|
$
|
642,528
|
|
|
$
|
1,323,034
|
|
|
Year Ended September 30
|
||||||||||
|
2017
|
|
2016
|
|
2015
|
||||||
|
(Thousands)
|
||||||||||
United States
|
|
|
|
|
|
||||||
Standardized Measure of Discounted Future
|
|
|
|
|
|
||||||
Net Cash Flows at Beginning of Year
|
$
|
642,528
|
|
|
$
|
1,323,034
|
|
|
$
|
2,066,878
|
|
Sales, Net of Production Costs
|
(345,075
|
)
|
|
(218,444
|
)
|
|
(318,753
|
)
|
|||
Net Changes in Prices, Net of Production Costs
|
828,187
|
|
|
(1,066,593
|
)
|
|
(1,752,843
|
)
|
|||
Extensions and Discoveries
|
170,500
|
|
|
47,742
|
|
|
266,159
|
|
|||
Changes in Estimated Future Development Costs
|
8,816
|
|
|
143,752
|
|
|
164,510
|
|
|||
Sales of Minerals in Place
|
(9,849
|
)
|
|
(95,849
|
)
|
|
(1
|
)
|
|||
Previously Estimated Development Costs Incurred
|
101,134
|
|
|
92,840
|
|
|
161,833
|
|
|||
Net Change in Income Taxes at Applicable Statutory Rate
|
(393,353
|
)
|
|
387,739
|
|
|
545,442
|
|
|||
Revisions of Previous Quantity Estimates
|
39,078
|
|
|
6,202
|
|
|
(16,573
|
)
|
|||
Accretion of Discount and Other
|
71,080
|
|
|
22,105
|
|
|
206,382
|
|
|||
Standardized Measure of Discounted Future Net Cash Flows at End of Year
|
$
|
1,113,046
|
|
|
$
|
642,528
|
|
|
$
|
1,323,034
|
|
Description
|
Balance at Beginning of Period
|
|
Additions Charged to Costs and Expenses
|
|
Additions Charged to Other Accounts(1)
|
|
Deductions (2)
|
|
Balance at End of Period
|
||||||||||
Year Ended September 30, 2017
|
|
|
|
|
|
|
|
|
|
||||||||||
Allowance for Uncollectible Accounts
|
$
|
21,109
|
|
|
$
|
6,301
|
|
|
$
|
1,774
|
|
|
$
|
6,658
|
|
|
$
|
22,526
|
|
Year Ended September 30, 2016
|
|
|
|
|
|
|
|
|
|
||||||||||
Allowance for Uncollectible Accounts
|
$
|
29,029
|
|
|
$
|
6,819
|
|
|
$
|
1,521
|
|
|
$
|
16,260
|
|
|
$
|
21,109
|
|
Year Ended September 30, 2015
|
|
|
|
|
|
|
|
|
|
||||||||||
Allowance for Uncollectible Accounts
|
$
|
31,811
|
|
|
$
|
9,316
|
|
|
$
|
2,585
|
|
|
$
|
14,683
|
|
|
$
|
29,029
|
|
|
(1)
|
Represents the discount on accounts receivable purchased in accordance with the Utility segment’s 2005 New York rate agreement.
|
(2)
|
Amounts represent net accounts receivable written-off.
|
Item 9
|
Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
|
Item 9A
|
Controls and Procedures
|
Item 9B
|
Other Information
|
Item 10
|
Directors, Executive Officers and Corporate Governance
|
Item 11
|
Executive Compensation
|
Item 12
|
Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
|
Item 13
|
Certain Relationships and Related Transactions, and Director Independence
|
Item 14
|
Principal Accountant Fees and Services
|
Item 15
|
Exhibits and Financial Statement Schedules
|
(a)1.
|
Financial Statements
|
(a)2.
|
Financial Statement Schedules
|
(a)3.
|
Exhibits
|
Exhibit
Number
|
Description of
Exhibits
|
|
|
3(i)
|
Articles of Incorporation:
|
|
|
•
|
|
|
|
3(ii)
|
By-Laws:
|
|
|
•
|
|
|
|
|
|
|
|
Exhibit
Number
|
Description of
Exhibits
|
4
|
Instruments Defining the Rights of Security Holders, Including Indentures:
|
|
|
•
|
Indenture, dated as of October 15, 1974, between the Company and The Bank of New York Mellon (formerly Irving Trust Company) (Exhibit 2(b) in File No. 2-51796)
|
|
|
•
|
Third Supplemental Indenture, dated as of December 1, 1982, to Indenture dated as of October 15, 1974, between the Company and The Bank of New York Mellon (formerly Irving Trust Company) (Exhibit 4(a)(4) in File No. 33-49401)
|
|
|
•
|
Eleventh Supplemental Indenture, dated as of May 1, 1992, to Indenture dated as of October 15, 1974, between the Company and The Bank of New York Mellon (formerly Irving Trust Company) (Exhibit 4(b), Form 8-K dated February 14, 1992)
|
|
|
•
|
Twelfth Supplemental Indenture, dated as of June 1, 1992, to Indenture dated as of October 15, 1974, between the Company and The Bank of New York Mellon (formerly Irving Trust Company) (Exhibit 4(c), Form 8-K dated June 18, 1992)
|
|
|
•
|
Thirteenth Supplemental Indenture, dated as of March 1, 1993, to Indenture dated as of October 15, 1974, between the Company and The Bank of New York Mellon (formerly Irving Trust Company) (Exhibit 4(a)(14) in File No. 33-49401)
|
|
|
•
|
Fourteenth Supplemental Indenture, dated as of July 1, 1993, to Indenture dated as of October 15, 1974, between the Company and The Bank of New York Mellon (formerly Irving Trust Company) (Exhibit 4.1, Form 10-K for fiscal year ended September 30, 1993)
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
10
|
Material Contracts:
|
|
|
•
|
|
|
|
•
|
|
|
|
|
|
|
|
Exhibit
Number
|
Description of
Exhibits
|
|
Management Contracts and Compensatory Plans and Arrangements:
|
|
|
•
|
|
|
|
10.1
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
Exhibit
Number
|
Description of
Exhibits
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
•
|
|
|
|
Exhibit
Number
|
Description of
Exhibits
|
•
|
|
|
|
12
|
|
|
|
21
|
|
|
|
23
|
Consents of Experts:
|
|
|
23.1
|
|
|
|
23.2
|
|
|
|
31
|
Rule 13a-14(a)/15d-14(a) Certifications:
|
|
|
31.1
|
|
|
|
31.2
|
|
|
|
32••
|
|
|
|
99
|
Additional Exhibits:
|
|
|
99.1
|
|
|
|
99.2
|
|
|
|
101
|
Interactive data files submitted pursuant to Regulation S-T: (i) the Consolidated Statements of Income and Earnings Reinvested in the Business for the years ended September 30, 2017, 2016 and 2015, (ii) the Consolidated Statements of Comprehensive Income for the years ended September 30, 2017, 2016 and 2015 (iii) the Consolidated Balance Sheets at September 30, 2017 and September 30, 2016, (iv) the Consolidated Statements of Cash Flows for the years ended September 30, 2017, 2016 and 2015 and (v) the Notes to Consolidated Financial Statements.
|
|
|
•
|
Incorporated herein by reference as indicated.
|
|
|
|
All other exhibits are omitted because they are not applicable or the required information is shown elsewhere in this Annual Report on Form 10-K.
|
|
|
••
|
In accordance with Item 601(b)(32)(ii) of Regulation S-K and SEC Release Nos. 33-8238 and 34-47986, Final Rule: Management’s Reports on Internal Control Over Financial Reporting and Certification of Disclosure in Exchange Act Periodic Reports, the material contained in Exhibit 32 is “furnished” and not deemed “filed” with the SEC and is not to be incorporated by reference into any filing of the Registrant under the Securities Act of 1933 or the Exchange Act, whether made before or after the date hereof and irrespective of any general incorporation language contained in such filing, except to the extent that the Registrant specifically incorporates it by reference.
|
|
|
|
National Fuel Gas Company
|
||
(Registrant)
|
||
|
|
|
By
|
|
/s/ R. J. Tanski
|
|
|
R. J. Tanski
|
|
|
President and Chief Executive Officer
|
Signature
|
|
Title
|
|
|
|
|
|
|
|
/s/ D. F. Smith
|
|
Chairman of the Board and Director
|
|
Date: November 17, 2017
|
D. F. Smith
|
|
|
|
|
|
|
|
|
|
/s/ P. C. Ackerman
|
|
Director
|
|
Date: November 17, 2017
|
P. C. Ackerman
|
|
|
|
|
|
|
|
|
|
/s/ D. C. Carroll
|
|
Director
|
|
Date: November 17, 2017
|
D. C. Carroll
|
|
|
|
|
|
|
|
|
|
/s/ S. E. Ewing
|
|
Director
|
|
Date: November 17, 2017
|
S. E. Ewing
|
|
|
|
|
|
|
|
|
|
/s/ J. N. Jaggers
|
|
Director
|
|
Date: November 17, 2017
|
J. N. Jaggers
|
|
|
|
|
|
|
|
|
|
/s/ C. G. Matthews
|
|
Director
|
|
Date: November 17, 2017
|
C. G. Matthews
|
|
|
|
|
|
|
|
|
|
/s/ R. Ranich
|
|
Director
|
|
Date: November 17, 2017
|
R. Ranich
|
|
|
|
|
|
|
|
|
|
/s/ J. W. Shaw
|
|
Director
|
|
Date: November 17, 2017
|
J. W. Shaw
|
|
|
|
|
|
|
|
|
|
/s/ T. E. Skains
|
|
Director
|
|
Date: November 17, 2017
|
T. E. Skains
|
|
|
|
|
|
|
|
|
|
/s/ R. J. Tanski
|
|
President, Chief Executive Officer and Director
|
|
Date: November 17, 2017
|
R. J. Tanski
|
|
|
|
|
|
|
|
|
|
/s/ D. P. Bauer
|
|
Treasurer and Principal
Financial Officer
|
|
Date: November 17, 2017
|
D. P. Bauer
|
|
|
|
|
|
|
|
|
|
/s/ K. M. Camiolo
|
|
Controller and Principal
Accounting Officer
|
|
Date: November 17, 2017
|
K. M. Camiolo
|
|
|
|
|
|
|
|
|
|
|
Page
|
||||
|
|
|
||||||||
1.
|
Operation of Agreement
|
2
|
||||||||
|
|
|
||||||||
2.
|
Change in Control
|
2
|
||||||||
|
|
|
||||||||
3.
|
Employment Period
|
2
|
||||||||
|
|
|
||||||||
4.
|
Position and Duties
|
2
|
||||||||
|
|
|
||||||||
5.
|
Compensation
|
2
|
||||||||
|
a.
|
Base Salary
|
2
|
|||||||
|
b.
|
Annual Bonus
|
3
|
|||||||
|
c.
|
Long-term Incentive Compensation Programs
|
3
|
|||||||
|
d.
|
Benefit Plans
|
3
|
|||||||
|
e.
|
Expenses
|
3
|
|||||||
|
f.
|
Vacation and Fringe Benefits
|
3
|
|||||||
|
g.
|
Indemnification
|
4
|
|||||||
|
|
|
|
|
||||||
6.
|
Termination
|
4
|
||||||||
|
a.
|
Death, Disability or Retirement
|
4
|
|||||||
|
b.
|
Voluntary Termination
|
4
|
|||||||
|
c.
|
Cause
|
4
|
|||||||
|
d.
|
Good Reason
|
4
|
|||||||
|
e.
|
Notice of Termination
|
5
|
|||||||
|
f.
|
Date of Termination
|
6
|
|||||||
|
|
|
|
|
||||||
7.
|
Obligations of the Company upon Termination
|
6
|
||||||||
|
a.
|
Death or Disability
|
6
|
|||||||
|
b.
|
Cause and Voluntary Termination
|
7
|
|||||||
|
c.
|
Termination by the Company other than for Cause
|
|
|||||||
|
|
and Termination by the Executive for Good Reason
|
7
|
|||||||
|
|
i.
|
Severance Benefits
|
|
7
|
|||||
|
|
ii.
|
Continuation of Medical Benefits
|
|
7
|
|||||
|
|
iii.
|
Continuation of Other Welfare Benefits
|
|
8
|
|
|
iv.
|
Vesting of Retirement Benefit Account
|
|
8
|
|||||
|
d.
|
Discharge of the Company's Obligations
|
8
|
|||||||
|
e.
|
Limit on Payments by the Company
|
9
|
|||||||
|
|
i.
|
Application of Section 7(e)
|
9
|
||||||
|
|
ii.
|
Calculation of Benefits
|
9
|
||||||
|
|
iii.
|
Imposition of Payment Cap
|
9
|
||||||
|
|
iv.
|
Application of Section 280G
|
10
|
||||||
|
|
v.
|
Applicable Tax Rates
|
10
|
||||||
|
|
vi.
|
Adjustments in Respect of the Payment Cap
|
11
|
||||||
|
f.
|
If Termination of Employment Occurs After the
|
|
|||||||
|
|
Executive Has Reached Age 62
|
12
|
|||||||
|
|
|
||||||||
8.
|
Non-exclusivity of Rights
|
12
|
||||||||
|
|
|
||||||||
9.
|
No Offset
|
12
|
||||||||
|
|
|
|
|
|
|
|
|
|
|
10.
|
Non-Competition and Non-Solicitation
|
12
|
||||||||
|
a.
|
Noncompete
|
12
|
|||||||
|
b.
|
Non-Solicitation of Employees
|
13
|
|||||||
|
c.
|
Confidential Information
|
13
|
|||||||
|
d.
|
Non-disparagement
|
13
|
|||||||
|
e.
|
Company Property
|
13
|
|||||||
|
f.
|
Additional Payment
|
14
|
|||||||
|
|
|
|
|
|
|
|
|
|
|
11.
|
Injunctive Relief and Other Remedies with Respect to
|
|
||||||||
|
Covenants
|
14
|
||||||||
|
|
|
||||||||
12.
|
Successors
|
14
|
||||||||
|
|
|
||||||||
13.
|
Miscellaneous
|
15
|
||||||||
|
a.
|
Applicable Law
|
15
|
|||||||
|
b.
|
Arbitration
|
15
|
|||||||
|
c.
|
Amendments
|
15
|
|||||||
|
d.
|
Entire Agreement
|
16
|
|||||||
|
e.
|
Notices
|
16
|
|||||||
|
f.
|
Source of Payments
|
16
|
|||||||
|
g.
|
Tax Withholding
|
17
|
|||||||
|
h.
|
Severability; Reformation
|
17
|
|||||||
|
i.
|
Waiver
|
17
|
|||||||
|
j.
|
Counterparts
|
17
|
|||||||
|
k.
|
Captions
|
17
|
|||||||
|
|
|
|
|
||||||
Signature
|
|
|
||||||||
Page
|
|
18
|
|
Fiscal Year Ended September 30,
|
||||||||||||||
|
|
|
|
|
|
||||||||||
|
2017
|
2016
|
2015
|
2014
|
2013
|
||||||||||
(Dollars in Thousands)
|
|
|
|
|
|
||||||||||
EARNINGS:
|
|
|
|
|
|
||||||||||
Net Income (Loss) Available for Common Stock
|
$
|
283,482
|
|
$
|
(290,958
|
)
|
$
|
(379,427
|
)
|
$
|
299,413
|
|
$
|
260,001
|
|
Plus Income Tax Expense (Benefit)
|
160,682
|
|
(232,549
|
)
|
(319,136
|
)
|
189,614
|
|
172,758
|
|
|||||
Less Investment Tax Credit (A)
|
(173
|
)
|
(348
|
)
|
(414
|
)
|
(434
|
)
|
(426
|
)
|
|||||
(Less Income) Plus Loss from Unconsolidated Subsidiaries
|
—
|
|
—
|
|
—
|
|
(397
|
)
|
204
|
|
|||||
Plus Distributions from Unconsolidated Subsidiaries
|
—
|
|
—
|
|
—
|
|
—
|
|
—
|
|
|||||
Plus Interest Expense on Long-Term Debt
|
116,471
|
|
117,347
|
|
95,916
|
|
90,194
|
|
90,273
|
|
|||||
Plus Other Interest Expense
|
3,366
|
|
3,697
|
|
3,555
|
|
4,083
|
|
3,838
|
|
|||||
Less Amortization of Loss on Reacquired Debt
|
(529
|
)
|
(529
|
)
|
(529
|
)
|
(529
|
)
|
(721
|
)
|
|||||
Plus Allowance for Borrowed Funds Used in Construction
|
1,655
|
|
2,006
|
|
1,964
|
|
900
|
|
827
|
|
|||||
Plus Other Capitalized Interest
|
1,275
|
|
238
|
|
4,191
|
|
3,560
|
|
1,801
|
|
|||||
Plus Rentals (B)
|
4,615
|
|
9,479
|
|
13,866
|
|
13,700
|
|
14,204
|
|
|||||
|
|
|
|
|
|
||||||||||
|
$
|
570,844
|
|
$
|
(391,617
|
)
|
$
|
(580,014
|
)
|
$
|
600,104
|
|
$
|
542,759
|
|
FIXED CHARGES:
|
|
|
|
|
|
||||||||||
Interest & Amortization of Premium and Discount of Funded Debt
|
$
|
116,471
|
|
$
|
117,347
|
|
$
|
95,916
|
|
$
|
90,194
|
|
$
|
90,273
|
|
Plus Other Interest Expense
|
3,366
|
|
3,697
|
|
3,555
|
|
4,083
|
|
3,838
|
|
|||||
Less Amortization of Loss on Reacquired Debt
|
(529
|
)
|
(529
|
)
|
(529
|
)
|
(529
|
)
|
(721
|
)
|
|||||
Plus Allowance for Borrowed Funds Used in Construction
|
1,655
|
|
2,006
|
|
1,964
|
|
900
|
|
827
|
|
|||||
Plus Other Capitalized Interest
|
1,275
|
|
238
|
|
4,191
|
|
3,560
|
|
1,801
|
|
|||||
Plus Rentals (B)
|
4,615
|
|
9,479
|
|
13,866
|
|
13,700
|
|
14,204
|
|
|||||
|
|
|
|
|
|
||||||||||
|
$
|
126,853
|
|
$
|
132,238
|
|
$
|
118,963
|
|
$
|
111,908
|
|
$
|
110,222
|
|
RATIO OF EARNINGS TO FIXED CHARGES
|
4.50
|
|
(D)
|
|
(C)
|
|
5.36
|
|
4.92
|
|
(A)
|
Investment Tax Credit is included in Other Income.
|
(B)
|
Rentals shown above represent the portion of all rentals (other than delay rentals) deemed representative of the interest factor.
|
(C)
|
The ratio coverage for the fiscal year ended September 30, 2015 was less than 1:1. The Company would have needed to generate additional earnings of $698,977 to achieve a coverage of 1:1 for the fiscal year ended September 30, 2015.
|
(D)
|
The ratio coverage for the fiscal year ended September 30, 2016 was less than 1:1. The Company would have needed to generate additional earnings of $523,855 to achieve a coverage of 1:1 for the fiscal year ended September 30, 2016.
|
Exhibit 21
|
|
|
|
|
|
Subsidiaries of National Fuel Gas Company
|
||
As of September 30, 2017
|
||
|
|
|
|
|
State or Other
|
|
|
Jurisdiction of Incorporation
|
Legal Name
|
|
or Organization
|
|
|
|
National Fuel Gas Distribution Corporation
|
|
New York
|
National Fuel Gas Supply Corporation
|
|
Pennsylvania
|
Seneca Resources Corporation
|
|
Pennsylvania
|
Empire Pipeline, Inc.
|
|
New York
|
National Fuel Resources, Inc.
|
|
New York
|
National Fuel Gas Midstream Corporation
|
|
Pennsylvania
|
NFG Midstream Covington, LLC
|
|
Pennsylvania
|
NFG Midstream Trout Run, LLC
|
|
Pennsylvania
|
NFG Midstream Processing, LLC
|
|
Pennsylvania
|
NFG Midstream Mt. Jewett, LLC
|
|
Pennsylvania
|
Seneca-NFG Midstream Owls Nest, LLC
|
|
Pennsylvania
|
NFG Midstream Tionesta, LLC
|
|
Pennsylvania
|
NFG Midstream Clermont, LLC
|
|
Pennsylvania
|
NFG Midstream Wellsboro, LLC
|
|
Pennsylvania
|
Highland Field Services, LLC
|
|
Pennsylvania
|
|
|
|
|
|
|
|
NETHERLAND, SEWELL & ASSOCIATES, INC.
|
|
|||
|
By:
|
/s/ Danny D. Simmons
|
|
||
|
|
Danny D. Simmons, P.E.
|
|
||
|
|
President and Chief Operating Officer
|
|
||
|
/s/ R. J. Tanski
|
R. J. Tanski
|
President and Chief Executive Officer
|
/s/ D. P. Bauer
|
D. P. Bauer
|
Treasurer and Principal Financial Officer
|
All Properties
|
||||||||
|
|
Net Reserves
|
|
Future Net Revenue (M$)
|
||||
|
|
Oil
|
|
Gas
|
|
|
|
Present Worth
|
Category
|
|
(MBBL)
|
|
(MMCF)
|
|
Total
|
|
at 10%
|
|
|
|
|
|
|
|
|
|
Proved Developed
|
|
29,799
|
|
1,363,102
|
|
2,698,295
|
|
1,366,140
|
Proved Undeveloped
|
|
408
|
|
610,018
|
|
656,183
|
|
243,533
|
|
|
|
|
|
|
|
|
|
Total Proved
|
|
30,207
|
|
1,973,120
|
|
3,354,478
|
|
1,609,672
|
|
|
Oil
|
|
Gas
|
||||
|
|
Pricing
Index
|
|
Average Posted Price
|
|
Pricing
Index
|
|
Average
Spot Price |
Division
|
|
|
($/Barrel)
|
|
|
($/MMBTU)
|
||
|
|
|
|
|
|
|
|
|
East Coast
|
|
ARG-Group 1 (OH/PA/NY)
|
|
48.810
|
|
Appalachia-Dominion South Point
|
|
2.080
|
|
|
ConocoPhillips 66 West Texas Intermediate
|
|
46.428
|
|
Canadian Gas-Dawn, Ontario
|
|
3.097
|
|
|
|
|
|
|
Citygates-Transco Zone 5 Delivered
|
|
2.902
|
|
|
|
|
|
|
Citygates-Transco Zone 6 Non-NY
|
|
2.484
|
|
|
|
|
|
|
Citygates-Transco Zone 6 NY
|
|
2.437
|
|
|
|
|
|
|
Henry Hub Gas Daily
|
|
3.001
|
|
|
|
|
|
|
Mississippi-Alabama-Transco Zone 4
|
|
2.948
|
|
|
|
|
|
|
Tennessee Zone 4-300 Leg
|
|
2.033
|
|
|
|
|
|
|
Tennessee Zone 4-313 Pool
|
|
2.154
|
|
|
|
|
|
|
Transco Leidy Line Receipts
|
|
2.061
|
|
|
|
|
|
|
|
|
|
West Coast
|
|
CA Buena Vista Oil Average Calculation
|
|
50.217
|
|
Henry Hub Gas Daily
|
|
3.001
|
|
|
CA Midway Sunset Oil Average Calculation
|
|
45.192
|
|
|
|
|
|
|
ConocoPhillips 66 West Texas Intermediate
|
|
46.428
|
|
|
|
|
|
|
Sincerely,
|
|
|
|
NETHERLAND, SEWELL & ASSOCIATES, INC.
|
|
|
|
Texas Registered Engineering Firm F-2699
|
|
|
|
|
|
|
|
|
|
|
|
|
/s/ C.H. (Scott) Rees III
|
|
|
By:
|
|
|
|
|
C.H. (Scott) Rees III, P.E.
|
|
|
|
Chairman and Chief Executive Officer
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
/s/ Richard B. Talley, Jr.
|
|
/s/ Edward C. Roy III
|
By:
|
|
By:
|
|
|
Richard B. Talley, Jr., P.E. 102425
|
|
Edward C. Roy III, P.G. 2364
|
|
Senior Vice President
|
|
Vice President
|
|
|
|
|
Date Signed: October 20, 2017
|
Date Signed: October 20, 2017
|