National Fuel Gas Distribution Corporation 2013 Purchased Gas Cost Filing Docket No. R : Supplement No.145 to Tariff Gas Pa. P.U.C. No.

@ national Fuel July 31, 213 Rosemary Chiavetta, Secretary Pennsylvania Public Utility Commission Room 8-2, North Office Building Harrisburg, Pennsylvania 1712 Re: National Fuel Gas Distribution Corporation 213 Purchased Gas Cost Filing Docket No. R-213-2341534: Supplement No.145 to Tariff Gas Pa. P.U.C. No.9 Dear Secretary Chiavetta: Enclosed, for filing, is one (1) copy of Supplement No. 145 to National Fuel Gas Distribution's Tariff Gas- Pa. P.U.C. No. 9. Supplement No. 145 is being issued in compliance with the Commission's Order entered on July 22, 213 at Docket R-213-2341534, Distribution's 213 proceeding under Section 137(f) of the Public Utility Code 66 Pa. C.S. Section 137(f) to establish rates for recovery of purchased gas costs. Supplement No. 145 has an issue date of July 31, 213 and an effective date of August 1, 213. This filing is being electronically filed., Supplement No. 145 serves two purposes. First, Supplement No. 145 complies with the Commission Order in this proceeding, which establishes the purchased gas cost rate at $5.999/Mcf or a increase of $.754/Mcf. Second, the Supplement updates for actual gas costs through June 3, 213. Both sets of adjustments are reflected in rates contained in Supplement No. 145. In the compliance filing, we are including Page No. 116 which was inadvertently omitted from the settlement draft tariff. Page No. 116 states the LAUF percentage. Also included is the calculation of the State Tax Adjustment which increases to (.19 /o). As shown on the enclosed certificate of service, copies have been served on parties in the manner indicated. Please direct any questions concerning this filing to the undersigned at (716) 857-785 or Sheila Suarez at (716) 857-7568. ss/ehm Enclosure Rt:ull;:;_mitt;/A/) - ( '-', f/1' (j, L/" Eric H. Meinl General Manager, Rates And Regulatory Affairs NATIONAL FUEL GAS DISTRIBUTION CORPORATION I 6363 MAIN STREET I WILLIAMSVILLE, NY 14221-5887

CERTIFICATE OF SERVICE I hereby certify that I have this day served a true copy of the foregoing document upon the participants listed below in the manner indicated, in accordance with the requirements of 1.54 (relating to service by a participant). FIRST CLASS MAIL John H. lsom, Esquire Post & Schell, P.C. 17 North Second Street 1ih Floor Harrisburg, PA 1711-161 Richard Kanaskie, Esquire Bureau of Investigation & Enforcement Pennsylvania Public Utility Commission Commonwealth Keystone Building 4 North Street, 2nd Floor West Harrisburg, PA 1712 Jerome D. Mierzwa Exeter Associates Suite 3 1 48 Little Patuxent Parkway Columbia, MD 2144 Robert D. Knecht Industrial Economics Incorporated 267 Massachusetts Avenue Cambridge, MA 214 Christy M. Appleby, Esquire Office of Consumer Advocate 555 Walnut Street. Forum Place 5th Floor Harrisburg, PA 1711-1923 Steven C. Gray, Esquire Office of Small Business Advocate Suite 11 2, Commerce Building 3 North Second Street Harrisburg, PA 1711 Dated this 31st day of July 213. Enc H. Meinl General Manager, Rates And Regulatoiy Affairs

Supplement No. 145 to Gas - Pa. P.U.C. No. 9 NATIONAL FUEL GAS DISTRIBUTION CORPORATION BUFFALO 1 NEW YORK RATES 1 RULES AND REGULATIONS GOVERNING THE FURNISHING OF NATURAL GAS SERVICE IN TERRITORY DESCRIBED HEREIN Issued: July 31, 213 Effective: August 1, 213 In accordance with the Commission's Order entered July 22, 213 at Docket R-213-2341534 A. M. CELLINO, PRESIDENT BUFFALO, NEW YORK This Supplement Increases, Decreases and Changes Existing Rates See Page 2

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 One-Hundred-Twentieth Revised Page No. 2 Canceling One-Hundred-Fifteenth and One-Hundred-Nineteenth Revised Page No. 2 CHANGE: INCREASE: LIST OF CHANGES MADE BY THIS TARIFF 1. LIRA percentage discounts table changes. Pages 37A and 37B. 2. Change made to pass back Supplier Refunds in E-Factor. Page 152. 3. The calculation of the C-Factor in quarterly filings change. Page 155. 4. The Gas Adjustment Charge and Natural Gas Supply Charge for Residential, Commercial and Public Authority, Small Volume Industrial, Intermediate Volume Industrial, Large Volume Industrial and Large Industrial Service Classes increase. Pages 36, 36A, 41, 41A, 42, 53, 55, 65, 66, 76, 76A and 147. 5. Commodity Charges for Load Balancing Service increase. Pages 5, 62, 73, 8 and 82. 6. Natural Gas Vehicle rates increase. Pages 82, 83 and 84. 7. Priority Standby and Standby rates increase. Pages 93 and 95. 8. The price for purchase of gas by Distribution from a transportation service customer in the event of a curtailment or interruption will increase to $6.1459 per Mcf. Pages 16, 117 and 146G. 9. Under rate schedule SATS, extreme peak day percentage increases for the release of pipeline capacity. Page 131. 1. Purchase gas costs in Rider A increase. Page 147. 11. State Tax Adjustment in Rider B increases. Page 157. 12. LIRA charge in Rider F increase. Pages 164 and 167. 13. The merchant function charge increases. Page 168. 14. The gas procurement charge increases. Page 169. Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Thirty-Fourth Revised Page No. 3 Canceling Thirty-Second and Thirty-Third Revised Page No. 3 LIST OF CHANGES MADE BY THIS TARIFF DECREASE: 15. The Distribution Charge for Residential, Commercial and Public Authority, Small Volume Industrial, Intermediate Volume Industrial, Large Volume Industrial and large Industrial Service Classes decrease. Pages 36, 41, 41A, 42, 53, 55, 65, 76 and 147. 16. Demand Charges for Load Balancing Service decrease. Pages 48, 61, 72, 79 and 82. 17. The component for recovery of purchased gas cost included in transportation rates decreases. Pages 5, 63, 74, 81, 1 and 11. 18. State Tax Adjustment Surcharge included in NGV rates decrease. Pages 83 and 84. 19. SATC rates decrease. Pages 119A, 12, 121 and 147. 2. The allowance for losses (retainage) percentage decrease. Pages 116, 118B and 125A. 21. Under rate schedule SATS, percentage of extreme peak day requirements provided through ESS storage and EFT transportation decrease. Page 126. 22. Under rate schedule SATS the Demand Transfer Rate decreases. Page 127. 23. Weighted average demand cost of upstream capacity decreases. Page 131. Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 One-Hundred-Twentieth Revised Page No. 4 Canceling One-Hundred-Fifteenth and One-Hundred-Nineteenth Revised Page No. 4 TABLE OF CONTENTS Page List of Changes.............................. 2 3 3A 3B 3C Table of Contents............................ 4 5 6 7 7A Description of Territory... 8 9 Rules and Regulations... 1 11 12 13 14 15 16 16A 16B 17 18 19 2 2A 21 22 22A 23 24 25 26 27 28 29 3 31 32 33 34 34A 35 35A 358 35C 35D 35E 35F 35G 35H Residential Service Schedule... 36 Rate Schedule LIRAS Low Income Residential Assistance Service Issued: July 31, 213 36A 37 37A One-Hundred-Twentieth Rv Thirty-Fourth Revised Fifth Revised First Revised First Revised One-Hundred-Twentieth Rv Sixty-Eighth Revised Eighty-Seventh Revised Ninety-Fourth Revised Seventieth Revised Second Revised Second Revised Third Revised Sixth Revised Sixth Revised Second Revised Original Second Revised Second Revised First Revised Third Revised Fourth Revised Original Original Fourth Revised Original Fifth Revised Third Revised First Revised Second Revised Fourth Revised First Revised First Revised Third Revised First Revised Third Revised First Revised First Revised Seventh Revised First Revised Ninth Revised Second Revised Third Revised Third Revised First Revised Fifth Revised Third Revised Eighth Revised Original Original Original Sixty-Sixth Revised Fifth Revised Tenth Revised Sixty-Fourth Revised Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Sixty-Eighth Revised Page No. 5 Canceling Sixty-Fifth and Sixty-Seventh Revised Page No. 5 TABLE OF CONTENTS (Cont'd) Rate Schedule LIRAS (Con't) Low Income Residential Assistance Service Commercial and Public Authority Service Rate Schedule.... Commercial Rider BDS - Business Development Service Rider.... Rate Schedule CPA-LBS Load Balancing Service for Commercial and Public Authority Customers... Rate Schedule SVIS Small Volume Industrial Service.... Rate Schedule IVIS Intermediate Volume Industrial Service Intermediate Volume Industrial Service Rider BDS - Business Development Service Rider.... 37B 37C 37D 38 39 4 4A 41 41A 42 42A 43 44 45 46 47 48 49 5 51 52 53 53A 54 55 55A Rate Schedule IVI-LBS Load Balancing Service for Intermediate Volume Industrial Customers... 59 6 61 62 63 Rate Schedule LVIS Large Volume Industrial Service... 64 65 66 Large Volume Industrial Service BDS - Business Development Service Rider............................... 67 56 57 58 68 69 Fiftieth Revised Tenth Revised Fifth Revised Third Revised Third Revised Second Revised First Revised Sixty-Fifth Revised Nineteenth Revised Sixty-Fifth Revised First Revised Original Original Original Second Revised Original Fifty-Sixth Revised Sixth Revised Sixty-Second Revised Fourth Revised Original Sixty-Second Revised First Revised Original Sixty-Second Revised First Revised Original Original Original Second Revised Original Fifty-Sixth Revised Fifty-Ninth Revised Twentieth Revised Original Sixty-Second Revised Twentieth Revised Original Original Original Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Eighty-Seventh Revised Page No. 6 Canceling Eighty-Fourth and Eighty-Sixth Revised Page No. 6 TABLE OF CONTENTS (Cont'd) Rate Schedule LVI-LBS Load Balancing Service for Large Volume Industrial Customers 7 71 72 73 74 Rate Schedule LIS Large Industrial Service... 75 Rate Schedule LI-LBS Load Balancing Service for Large Industrial Customers Rate Schedule NGV Natural Gas Vehicle Service... 82 Rate Schedule BP Service for Customers with Bypass Facilities Rate Schedule PSB Priority Standby Service... 93 Rate Schedule SB Standby Service.............................. 94 76 76A 77 78 79 8 81 83 84 84A Rate Schedule for Monthly Metered Transportation Service... 98 99 1 11 12 13 14 15 16 17 18 85 86 87 88 89 9 91 92 95 96 97 Second Revised Original Fifty-Sixth Revised Fifty-Ninth Revised Twentieth Revised Original Sixty-Second Revised Fifth Revised Second Revised Original Fifty-Sixth Revised Fifty-Ninth Revised Twentieth Revised Fifty-Seventh Revised Seventy-Seventh Revised Seventy-second Revised First Revised Original Sixth Revised Original Original Original Original Original Original Thirty-First Revised Original Thirty-First Revised Eighth Revised Original Fourth Revised Sixth Revised Twenty-Eighth Revised Twenty-Seventh Revised Eighth Revised Seventh Revised Sixth Revised Sixty-First Revised Sixty-Second Revised Fourth Revised Fourth Revised Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Ninety-Fourth Revised Page No. 7 Canceling Ninetieth and Ninety-Third Revised Page No. 7 TABLE OF CONTENTS (Cont'd) Rate Schedule for Daily Metered Transportation Service... 19 11 111 112 113 Original Fourth Revised Eighth Revised Eighth Revised Fourth Revised 114 First Revised 115 Original 116 Seventh Revised 117 Sixty-First Revised 118 Fifth Revised Monthly Metered Natural Gas Supplier Service Rate Schedule SATC Small Aggregation Transportation Customer Service............. Rate Schedule SATS Small Aggregation Transportation Supplier Service................. 118A Fifth Revised 118B Twelfth Revised 118C Sixth Revised 118 Ninth Revised 118E Eighth Revised 118F Tenth Revised 118G Fourth Revised 118H Fourth Revised 118I Seventh Revised 118J Third Revised 119 Forty-Third Revised 119A Fifteenth Revised 12 Sixty-Fourth Revised 121 Sixty-Fourth Revised 121A First Revised 122 Original 123 First Revised 124 Original 125 Fifth Revised 125A Fifth Revised 126 Twenty-Sixth Revised 127 Thirty-First Revised 128 Third Revised 129 Eighth Revised 13 First Revised 131 Twenty-Ninth Revised 132 Original 133 Third Revised 134 Tenth Revised 135 Tenth Revised 135A Original 136 Twelfth Revised 136A Original 137 Second Revised 138 First Revised 139 First Revised 139A Original 14 Ninth Revised 141 Second Revised Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Seventieth Revised Page No. 7A Canceling Sixty-Sixth and Sixty-Ninth Revised Page No. 7A TABLE OF CONTENTS Rate Schedule SATS (Con't) Small Aggregation Transportation Supplier Service................. (Cont'd) Page 142 143 144 145 146 Original Original Original Original Original Daily Metered Large Manufacturing Transportation Service..... Rider A - Section 137(f) Purchased Gas Costs... 146A 146B 146C 146D 146E 146F 146G 146H 147 147A 147B 148 149 15 151 152 153 154 155 156 Original Original Second Revised Original Original Second Revised Thirty-First Revised Third Revised Fifty-Eighth Revised First Revised First Revised Fourth Revised Fourth Revised Sixth Revised Second Revised Fourth Revised Original Second Revised Ninth Revised Original Rider B - State Tax Adjustment Surcharge... 157 Blank Page...................................... 158 159 16 161 Rider E - Customer Education Charge... 162 163 Rider F - LIRA Discount Rate Rider G Merchant Function Charge (MFC) Rider Rider H 164 165 166 167 168 Gas Procurement Charge (GPC)............ 169 Blank Page...................................... 17 Forty-First Revised Fifth Revised Sixth Revised First Revised First Revised Thirteenth Revised First Revised Sixty-Eighth Revised Sixth Revised Fifth Revised Thirty-Second Revised Seventeenth Revised Fourth Revised First Revised Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Sixty-Sixth Revised Page No. 36 Canceling Sixty-Third and Sixty-Fifth Revised Page No. 36 RESIDENTIAL SERVICE RATE SCHEDULE RESIDENTIAL CLASSIFICATION This classification shall include gas supplied for residential purposes such as a private dwelling, apartment house with a single meter supplying four or less dwelling units, separately metered apartments of a multiple dwelling, accessory buildings to dwellings or apartment houses such as garages, except at residences receiving service under Rate Schedule LIRAS for Low Income Residential Assistance Service and other places of residence where gas is used for residential purposes. Churches and missions (places of worship) shall be entitled to Service under the Residential service rate schedule. AVAILABILITY OF SERVICE Gas Service shall be available at one location, except as otherwise provided, for residential customers. APPLICABILITY Applicable in all areas served under this tariff. MONTHLY RATE Basic Service Charge $12. per Month Distribution Charges 35.371 per 1 cubic feet for the first 5, cubic feet 25.13 per 1 cubic feet for all over 5, cubic feet Gas Adjustment Charge (1.181 ) per 1 cubic feet Purchased Gas Cost Component (Rider A) (.26 ) per 1 cubic feet Merchant Function Charge (Rider G) (1.27 ) Per 1 cubic feet Total Gas Adjustment Charge (D) (D) (I) (I) (I) For a period of 12 months starting when gas supply service hereunder is initiated to a former SATC, MMT or DMT customer by the Company, the rates for service under this rate schedule shall exclude the Gas Adjustment Charge. Former SATC, MMT or DMT customers will be charged during this 12 month period the DEDC factor as defined in Rider A to this tariff and as contained in the Distribution charges set forth above, as amended from time to time. (I) Indicates Increase (D) Indicates Decrease Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Supplement No. 145 to Gas - Pa. P.U.C. No. 9 Fifth Revised Page No. 36A Canceling Fourth Revised Page No. 36A RESIDENTIAL SERVICE RATE SCHEDULE (Cont.) Natural Gas Supply Charge 58.791 per 1 cubic feet Purchased Gas Cost Component (Rider A) 1.311 per 1 cubic feet Merchant Function Charge (Rider G) 1.5 per 1 cubic feet Gas Procurement Charge (Rider H) 61.152 per 1 cubic feet Total Natural Gas Supply Charge (I) (I) (I) The Natural Gas Supply Charge shall include a Merchant Function Charge (Rider G) to recover uncollectible costs associated with purchase gas costs of 2.231% and the Gas Procurement Charge (Rider H) to recover costs of procuring natural gas pursuant to 52 Pa. Code 62.223. The above rates shall be subject to surcharges in accordance with the provisions of Rider B - State Tax Adjustment Surcharge and Rider F - LIRA Discount Charge as set forth in this tariff. RULES AND REGULATIONS The rules and regulations set forth in this tariff shall govern, where applicable, the supply of gas service under this rate schedule. (I) Indicates Increase (C) Indicates Change Issued: July 31, 213 (D) Indicates Decrease Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Sixty-Fourth Revised Page No. 37A Canceling Sixty-First and Sixty-Third Revised Page No. 37A MONTHLY RATE After completion of selection of the customers to receive service under this rate schedule, the following percentage discounts shall be applied to the Residential Rate Schedule Basic Service Charge, Distribution Charge, Gas Adjustment Charge and Natural Gas Supply Charge: Program changes associated with the Order at Docket Nos. R-7242 and M-7219 will be implemented the first calendar day of the month following the entry date of the Commission Order if the entry date is at least 5 days prior to the first calendar day of the month. If the entry date is within the 5-day window, program changes will become effective the first day of the subsequent calendar month. (C) ANNUAL INCOME HOUSEHOLD SIZE 1 2 3 4 5 6 7 $ - $999 1.% 1.% 1.% 1.% 2.% 2.% 2.% $1, - $1,999 1.% 1.% 2.% 2.% 2.% 2.% 2.% $2,- $2,999 2.% 2.% 3.% 3.% 3.% 3.% 3.% $3, - $3,999 3.% 3.% 3.% 3.% 4.% 4.% 4.% $4,- $41 999 4.% 4.% 4.% 4.% 4.% 4.% 4.% $5, - $5,999 3.% 4.% 4.% 4.% 4.% 4.% 4.% $6,- $6,999 2.% 3.% 4.% 4.% 4.% 4.% 4.% $7, - $71 999 2.% 3.% 4.% 4.% 4.% 4.% 4.% $8, - $8,999 1.% 2.% 3.% 3.% 4.% 4.% 4.% $9, - $9,999 1.% 1.% 3.% 3.% 3.% 3.% 3.% $1, - $1,999 1.% 1.% 1.% 3.% 3.% 3.% 3.% $11,- $11,999 1.% 1.% 1.% 2.% 3.% 3.% 3.% $12, - $12,999 1.% 1.% 1.% 1.% 2.% 2.% 2.% $13, - $13,999 1.% 1.% 1.% 1.% 2.% 2.% 2.% $14, - $14,999 1.% 1.% 1.% 1.% 1.% 2.% 2.% $15, - $15,999 1.% 1.% 1.% 1.% 1.% 1.% 1.% $16, - $16,999 1.% 1.% 1.% 1.% 1.% 1.% 1.% $17,- $17,999 1.% 1.% 1.% 1.% 1.% 1.% 1.% $18, - $18,999.% 1.% 1.% 1.% 1.% 1.% 1.% $19, - $19,999.% 1.% 1.% 1.% 1.% 1.% 1.% $2,- $2,999.% 1.% 1.% 1.% 1.% 1.% 1.% $21, - $21,999.% 1.% 1.% 1.% 1.% 1.% 1.% $22,- $22,999.% 1.% 1.% 1.% 1.% 1.% 1.% $23, - $23,999.% 1.% 1.% 1.% 1.% 1.% 1.% $24, - $24,999.%.% 1.% 1.% 1.% 1.% 1.% $25,- $25,999.%.% 1.% 1.% 1.% 1.% 1.% $26, - $26,999.%.% 1.% 1.% 1.% 1.% 1.% $27, - $27,999.%.% 1.% 1.% 1.% 1.% 1.% $28, - $28,999.%.% 1.% 1.% 1.% 1.% 1.% $29,- $29,999.%.% 1.% 1.% 1.% 1.% 1.% (C) Indicates Change Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Fiftieth Revised Page No. 378 Canceling Forty-Seventh and Forty-Ninth Revised Page No. 378 MONTHLY RATE (con't) (C) - ANNUAL INCOME HOUSEHOLD SIZE 8 9 1 11 12 13 14 $ - $999 2.% 2.% 1.% 1.% 1.% 1.% 1.% $1,- $1,999 2.% 2.% 3.% 3.% 3.% 3.% 3.% $2,- $2,999 3.% 3.% 3.% 3.% 3.% 3.% 3.% $3,- $3,999 4.% 4.% 4.% 3.% 3.% 3.% 3.% $4, - $4,999 4.% 4.% 4.% 4.% 4.% 4.% 4.% $5,- $5,999 4.% 4.% 4.% 4.% 4.% 4.% 4.% $6, - $6,999 4.% 4.% 4.% 4.% 4.% 4.% 4.% $7, - $7,999 4.% 4.% 4.% 4.% 4.% 4.% 4.% $8, - $8,999 4.% 4.% 4.% 4.% 4.% 4.% 4.% $9, - $9,999 3.% 4.% 4.% 4.% 4.% 4.% 4.% $1, - $1,999 3.% 3.% 3.% 3.% 3.% 3.% 3.% $11, - $11,999 3.% 3.% 3.% 3.% 3.% 3.% 3.% $12, - $12,999 2.% 3.% 3.% 3.% 3.% 3.% 3.% $13, - $13,999 2.% 2.% 2.% 2.% 2.% 2.% 2.% $14, - $14,999 2.% 2.% 2.% 2.% 2.% 2.% 2.% $15, - $15,999 1.% 1.% 1.% 1.% 1.% 1.% 1.% $16, - $16,999 1.% 1.% 1.% 1.% 1.% 1.% 1.% $17, - $17,999 1.% 1.% 1.% 1.% 1.% 1.% 1.% $18, - $18,999 1.% 1.% 1.% 1.% 1.% 1.% 1.% $19, - $19,999 1.% 1.% 1.% 1.% 1.% 1.% 1.% $2, - $2,999 1.% 1.% 1.% 1.% 1.% 1.% 1.% $21, - $21,999 1.% 1.% 1.% 1.% 1.% 1.% 1.% $22, - $22,999 1.% 1.% 1.% 1.% 1.% 1.% 1.% $23, - $23,999 1.% 1.% 1.% 1.% 1.% 1.% 1.% $24, - $24,999 1.% 1.% 1.% 1.% 1.% 1.% 1.% $25, - $25,999 1.% 1.% 1.% 1.% 1.% 1.% 1.% $26, - $26,999 1.% 1.% 1.% 1.% 1.% 1.% 1.% $27, - $27,999 1.% 1.% 1.% 1.% 1.% 1.% 1.% $28, - $28,999 1.% 1.% 1.% 1.% 1.% 1.% 1.% $29, - $29,999 1.% 1.% 1.% 1.% 1.% 1.% 1.% (C) Indicates Change Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Sixty-Fifth Revised Page No. 41 Canceling Sixty-Second and Sixty-Fourth Revised Page No. 41 COMMERCIAL AND PUBLIC AUTHORITY SERVICE RATE SCHEDULE (cont.) APPLICABILITY Applicable in all areas served under this tariff. MONTHLY RATE For "Small" Commercial/Public Authority Customers using not more than 25, cubic feet per year: Basic Service Charge $19.89 per Month Distribution Charges 29.29 per 1 cubic feet for the first 5, cubic feet 26.32 per 1 cubic feet for all over 5, cubic feet Gas Adjustment Charge (1.181 ) per 1 cubic feet Purchased Gas Cost Component (Rider A) (.3 ) per 1 cubic feet Merchant Function Charge (Rider G) (1.184 ) per 1 cubic feet Total Gas Adjustment Charge (D) (D) (I) (I) (I) For a period of 12 months starting when gas supply service hereunder is initiated to a former SATC, MMT or DMT customer by the Company, the rates for service under this rate schedule shall exclude the Gas Adjustment Charge. Former SATC, MMT or DMT customers will be charged during this 12 month period the DEDC factor as defined in Rider A to this tariff and as contained in the Distribution charges set forth above, as amended from time to time. Natural Gas Supply Charge 58.791 per 1 cubic feet Purchased Gas Cost Component (Rider A).135 per 1 cubic feet Merchant Function Charge (Rider G) 1.5 per 1 cubic feet Gas Procurement Charge (Rider H) 59.976 per 1 cubic feet Total Natural Gas Supply Charge (I) (I) (I) The Natural Gas Supply Charge shall include a Merchant Function Charge (Rider G) to recover uncollectible costs associated with purchase gas costs of.2285% and the Gas Procurement Charge (Rider H) to recover costs of procuring natural gas pursuant to 52 Pa. Code 62.223. The above rates shall be subject to surcharges in accordance with the provisions of Rider B - State Tax Adjustment Surcharge as set forth in this tariff. (D) Indicates Decrease (I) Indicates Increase Issued: July 31, 213 (C) Indicates Change Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Nineteenth Revised Page No. 41A Canceling Sixteenth and Eighteenth Revised Page No. 41A COMMERCIAL AND PUBLIC AUTHORITY SERVICE RATE SCHEDULE (Cont'd) For "Small" Commercial/Public Authority Customers using greater than 25, cubic feet but not more than 1,, cubic feet per year: Basic Service Charge $27.53 per Month Distribution Charges 21.83 per 1 cubic feet for the first 2, cubic feet 2.439 per 1 cubic feet for all over 2, cubic feet (D) (D) Gas Adjustment Charge (1.181 ) per 1 cubic feet (.3 ) per 1 cubic feet (1.184 ) per 1 cubic feet Purchased Gas Cost Component (Rider A) Merchant Function Charge (Rider G) Total Gas Adjustment Charge (I) (I) (I) For a period of 12 months starting when gas supply service hereunder is initiated to a former SATC, MMT or DMT customer by the Company, the rates for service under this rate schedule shall exclude the Gas Adjustment Charge. Former SATC, MMT or DMT customers will be charged during this 12 month period the DEDC factor as defined in Rider A to this tariff and as contained in the Distribution charges set forth above, as amended from time to time. Natural Gas Supply Charge 58.791 per 1 cubic feet Purchased Gas Cost Component (Rider A).135 per 1 cubic feet Merchant Function Charge (Rider G) 1.5 per 1 cubic feet Gas Procurement Charge (Rider H) 59.976 per 1 cubic feet Total Natural Gas Supply Charge (I) (I) (I) The Natural Gas Supply Charge shall include a Merchant Function Charge (Rider G) to recover uncollectible costs associated with purchase gas costs of.2285% and the Gas Procurement Charge (Rider H) to recover costs of procuring natural gas pursuant to 52 Pa. Code 62.223. The above rates shall be subject to surcharges in accordance with the provisions of Rider B - State Tax Adjustment Surcharge as set forth in this tariff. (D) Indicates Decrease (I) Indicates Increase Issued: July 31, 213 (C) Indicates Change Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Sixty-Fifth Revised Page No. 42 Canceling Sixty-Second and Sixty-Fourth Revised Page No. 42 Commercial and Public Authority Service Rate Schedule (Cont'd) For "Large" Commercial/Public Authority Customers: Basic Service Charge $121.1 per Month Distribution Charges 18.67 per 1 cubic feet for the first 3, cubic feet (D) 16.875 per 1 cubic feet for the next 1,7, cubic feet (D) 14.691 per 1 cubic feet for all over 2,, cubic feet (D) Gas Adjustment Charge (1.181 ) per 1 cubic feet Purchased Gas Cost Component (Rider A) (.3 ) per 1 cubic feet Merchant Function Charge (Rider G) (1.184 ) per 1 cubic feet Total Gas Adjustment Charge (I) (I) (I) For a period of 12 months starting when gas supply service hereunder is initiated to a former SATC, MMT or DMT customer by the Company, the rates for service under this rate schedule shall exclude the Gas Adjustment Charge. Former SATC, MMT or DMT customers will be charged during this 12 month period the DEDC factor as defined in Rider A to this tariff and as contained in the Distribution charges set forth above, as amended from time to time. Natural Gas Supply Charge 58.791 per 1 cubic feet Purchased Gas Cost Component (Rider A).135 per 1 cubic feet Merchant Function Charge (Rider G) 1.5 per 1 cubic feet Gas Procurement Charge (Rider H) 59.976 per 1 cubic feet Total Natural Gas Supply Charge (I) (I) (I) The Natural Gas Supply Charge shall include a Merchant Function Charge (Rider G) to recover uncollectible costs associated with purchase gas costs of.2285% and the Gas Procurement Charge (Rider H) to recover costs of procuring natural gas pursuant to 52 Pa. Code 62.223. The above rates shall be subject to surcharges in accordance with the provisions of Rider B - State Tax Adjustment Surcharge as set forth in this tariff. APPLICATION PERIOD The Application Period shall be the twelve months beginning March 1 of each year. RULES AND REGULATIONS The Rules and Regulations set forth in this tariff shall govern, where applicable, the supply of gas service under this rate schedule. (I) Indicates Increase (D) Indicates Decrease Issued: July 31, 213 (C) Indicates Change Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Fifty-Sixth Revised Page No. 48 Canceling Fifty-Fourth and Fifty-Fifth Revised Page No. 48 1. The purchased gas demand costs applicable to the Residential, Commercial and Public Authority, Small Volume Industrial, Intermediate Volume Industrial, Large Volume Industrial and Large Industrial classes, the "DC", shall be obtained from Rider "A" - Section 137(f) Purchased Gas Costs. 2. The number 12 shall be multiplied by the sum of (a) the volume of gas (expressed in Mcf) purchased from the Company by all Residential, Commercial and Public Authority, Small Volume Industrial, Intermediate Volume Industrial, Large Volume Industrial and Large Industrial customers, during the Company peak Sales Month and (b) the volume of service (expressed in Mcf) to all customers under the "Monthly Volume" provisions of Rate Schedule SB, during the Company Peak Sales Month. (a) (b) "Company Peak Sales Month" is defined as the calendar month within which the Company experienced the System-Wide Peak Sales Day, such month being December, January or February preceding the Section 137(f) Application Period for which the determination of the rate per Gas BDU is being made. "System-Wide Peak Sales Day" is defined as the day of maximum gas purchased by the Company, including all volumes of gas purchased from the Company throughout its entire system in the states of Pennsylvania and New York. 3. The amount determined in Item 1 above shall be divided by the amount determined in Item 2 above to determine the amount included in the rate for recovery of purchased gas costs. 4. The rate per Gas BDU shall be the amount for purchased gas demand costs (Item 3). The current rate per Gas BDU is as follows: Purchased Gas Demand Cost $.8319/BPU (D) Each time there is a change in the provision for recovery of purchased gas costs pursuant to Rider "A" of this tariff, a recomputation shall be made, under Items 1, 2 and 3, above, of the component to be included in the rate for purchased gas demand costs and the rate per Gas BDU shall be changed accordingly. (D) Indicates Decrease Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Sixty-Second Revised Page No. 5 Canceling Sixtieth and Sixty-First Revised Page No. 5 B. COMMODITY CHARGES FOR SALES AND FOR TRANSPORTATION SERVICE 1. Commodity Charge for Sales Service The monthly Commodity Charge for Sales Service shall be the product of multiplying the rate per Mcf, determined as provided below, by the volume of gas sold to the Customer by the Company during the applicable billing cycle. The rate per Mcf shall be determined as follows and shall be $4.7916 per Mcf, subject to revision as provided below: (I) The current components of the rate are as follows: Purchased Gas Commodity Costs, set forth in Rider "A" Non Gas Costs $4.235/Mcf $.5566/Mcf (I) a. Determination of Rate 2er Mcf The rate per Mcf shall be the sum of: 1. The net amount per Mcf for recovery of the commodity component of purchased gas costs and for recovery or refund of "E" factor amounts, the "PGCC", as determined in Rider "A"- Section 137(f) Purchased Gas Costs of this tariff; plus 2. The amount of $.5566 per Mcf for recovery of non-gas costs. Each time there is a change in the provision for recovery of purchased gas costs pursuant to Rider "A" of this tariff, a recomputation shall be made of the commodity component of purchased gas costs (Item 1, above) and the rate per Mcf shall be changed accordingly. The component included in the rate for recovery of non-gas costs shall remain constant until changed in accordance with a procedure, other than a proceeding pursuant to Section 137(f) of the Public Utility Code, 66 Pa.C.S. Section 137(f). 2. Commodity Charge for Transportation Service The monthly Commodity Charge for Transportation Service shall be the product of multiplying the rate per Mcf, determined as provided below, by the volume of gas transported by the Company to the Customer's load balancing facilities. The rate per Mcf for transportation of gas under this rate schedule shall be $.8266 per Mcf, which includes $.5566 for recovery of non-gas costs and $.26 for recovery of purchased gas. (D) (D) Indicates Decrease (I) Indicates Increase Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Sixty-Second Revised Page No. 53 Canceling Fifty-Ninth and Sixty-First Revised Page No. 53 MONTHLY RATE SVIS Small Volume Industrial Service Rate Schedule (Cont'd) Basic Service Charge $65.6 per Month Distribution Charges 23.77 per 1 cubic feet (D) Gas Adjustment Charge (1.181 ) per 1 cubic feet (.3 ) per 1 cubic feet (1.184 ) per 1 cubic feet Purchased Gas Cost Component (Rider A) Merchant Function Charge (Rider G) Total Gas Adjustment Charge (I) (I) (I) For a period of 12 months starting when gas supply service hereunder is initiated to a former SATC, MMT or DMT customer by the Company, the rates for service under this rate schedule shall exclude the Gas Adjustment Charge. Former SATC, MMT or DMT customers will be charged during this 12 month period the DEDC factor as defined in Rider A to this tariff and as contained in the Distribution charges set forth above, as amended from time to time. Natural Gas Supply Charge 58.791 per 1 cubic feet Purchased Gas Cost Component (Rider A).135 per 1 cubic feet Merchant Function Charge (Rider G) 1.5 per 1 cubic feet Gas Procurement Charge (Rider H) 59.976 per 1 cubic feet Total Natural Gas Supply Charge (I) (I) (I) The Natural Gas Supply Charge shall include a Merchant Function Charge, (Rider G) to recover uncollectible costs associated with purchase gas costs of ol.2285% and the Gas Procurement Charge (Rider H) to recover costs of procuring natural gas pursuant to 52 Pa. Code 62.223. The above rates shall be subject to surcharges in accordance with the provisions of Rider B - State Tax Adjustment Surcharge. APPLICATION PERIOD The Application Period shall be the twelve months beginning March 1 of each year. RULES AND REGULATIONS The Rules and Regulations set forth in this tariff shall govern, where applicable, the supply of gas service under this rate schedule. (D) Indicates Decrease (I) Indicates Increase Issued: July 31, 213 (C) Indicates Change Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Sixty-Second Revised Page No. 55 Canceling Fifty-Ninth and Sixty-First Revised Page No. 55 IVIS INTERMEDIATE VOLUME INDUSTRIAL SERVICE RATE SCHEDULE (Cont'd) MONTHLY RATE Basic Service Charge $21.91 per Month Distribution Charges 17.826 per 1 cubic feet for the first 1, cubic feet (D) 13.745 per 1 cubic feet for the next 1,9, cubic feet (D) 1.551 per 1 cubic feet for all over 2,, cubic feet (D) Gas Adjustment Charge (1.181 ) per 1 cubic feet Purchased Gas Cost Component (Rider A) (.3 ) per 1 cubic feet Merchant Function Charge (Rider G) (1.184 ) per 1 cubic feet Total Gas Adjustment Charge (I) (I) (I) For a period of 12 months starting when gas supply service hereunder is initiated to a former SATC, MMT or DMT customer by the Company, the rates for service under this rate schedule shall exclude the Gas Adjustment Charge. Former SATC, MMT or DMT customers will be charged during this 12 month period the DEDC factor as defined in Rider A to this tariff and as contained in the Distribution charges set forth above, as amended from time to time. Natural Gas Supply Charge 58.791 per 1 cubic feet Purchased Gas Cost Component (Rider A).135 per 1 cubic feet Merchant Function Charge (Rider G) 1.5 per 1 cubic feet Gas Procurement Charge (Rider H) 59.976 per 1 cubic feet Total Natural Gas Supply Charge (I) (I) (I) The Natural Gas Supply Charge shall include a Merchant Function Charge (Rider G) to recover uricollectible costs associated with purchase gas costs of.2285% and the Gas Procurement Charge (Rider H) to recover costs of procuring natjral gas pursuant to 52 Pa. Code 62.223. The above rates shall be subject to surcharges in accordance with the provisions of Rider B - State Tax Adjustment Surcharge as set forth in this tariff. APPLICATION PERIOD year. The Application Period shall be the twelve months beginning March 1 of each RULES AND REGULATIONS The rules and regulations set forth in this tariff shall govern, where applicable, the supply of gas service under this rate schedule. (I) Indicates Increase (D) Indicates Decrease Issued: July 31, 213 (C) Indicates Change Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Fifty-Sixth Revised Page No. 61 Canceling Fifty-Fourth and Fifty-Fifth Revised Page No. 61 Industrial and Large Industrial customers, during the Company peak Sales Month defined in Rate Schedule CPA-LBS and (b) the volumes of service (expressed in Mcf) to all customers under the "Monthly Volume" provisions of Rate Schedule SB, during the Company Peak Sales Month defined in Rate Schedule CPA-LBS. 3. The amount determined in Item 1 above shall be divided by the amount determined in Item 2 above to determine the amount included in the rate for recovery of purchased gas costs. 4. The rate per Gas BDU shall be the amount for purchased gas demand costs (Item 3). The current rate per Gas BDU is as follows: Purchased Gas Demand Cost $.8319/BDU (D) Each time there is a change in the provision for recovery of purchased gas costs pursuant to Rider "A" of this tariff, a recomputation shall be made, under Items 1, 2 and 3, above, of the component to be included in the rate for purchased gas demand costs and the rate per Gas BDU shall be changed accordingly. b. Determination of Customer's Gas BDUs The Customer's Gas BDUs shall be determined as follows: The actpal volumes of gas purchased by the Customer from the Company and used by the Customer in the separately-metered load balancing facilities during such Customer's Peak billing Cycle, as defined hereinafter, shall be multiplied by a fraction. The numerator shall be the number 3. The denominator shall be the number of days of service for which such Customer was billed in such Customer's Peak Billing Cycle. The Customer's Peak Billing Cycle shall be the single billing cycle of 1 maximum delivery to the Customer's separately-metered load balancing facilities that ended during one of the months of December, January, February and March during the period beginning with the most recently-complete4 billing cycle ended in December and ending with the current billing cycle. i If the customer used no gas under this rate schedule during the most recently concluded billing cycles ended in December, January, February or March, then the level of Gas BDUs applicable to Customer shall be zero (). (D) Indicates Decrease Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Fifty-Ninth Revised Page No. 62 Canceling Fifty-Seventh and Fifty-Eighth Revised Page No. 62 2. Margin Demand Charge a. The rate per Margin BDU shall be $.5122 per Margin BDU. b. Determination of Customer's Margin BDUs The Customer's Margin BDUs shall be determined as follows: The actual deliveries of gas to the Customer by Company, including not only volumes of gas purchased by the Customer from the Company and used by the Customer in the separately-metered load balancing facilities but also volumes of Customerowned gas transported to the Customer's load balancing facilities through the Company's facilities, during such Customer's Peak billing Cycle, as defined hereinafter, shall be multiplied by a fraction. The numerator shall be the number 3. The denominator shall be the number of days of service for which such Customer was billed in such Customer's Peak Billing Cycle. The Customer's Peak Billing Cycle shall be the single billing cycle of maximum delivery to the Customer's separately-metered load balancing facilities that ended during one of the months of December, January, February and March during the period beginning with the most recently-completed billing cycle ended in December and ending with the current billing cycle. If the customer used no gas under this rate schedule during the most recently concluded billing cycles ended in December, January, February or March, then the level of Margin BDUs applicable to Customer shall be zero (). B. COMMODITY CHARGES FOR SALES AND FOR TRANSPORTATION SERVICE 1. Commodity Charge for Sales Service The monthly Commodity Charge for Sales Service shall be the product of multiplying the rate per Mcf, determined as provided below, by the volume of gas sold to the Customer by the Company during the applicable billing cycle. The rate per Mcf shall be determined as follows and shall be $4.6158 per Mcf, subject to revision as provided below: (I) The current components of the rate are as follows: Purchased Gas Commodity Costs, set forth in Rider "Au Non Gas Costs $4.235/Mcf $.388/Mcf (I) a. Determination of Rate 2er Mcf The rate per Mcf shall be the sum of: 1. The net amount per Mcf for recovery of the commodity component of purchased gas costs and for recovery or refund of "Eu factor amounts, the "PGCCu, as determined in Rider "Au- Section 137(f) Purchased Gas Costs of this tariff; plus (D) Indicates Decrease Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Twentieth Revised Page No. 63 Canceling Eighteenth and Nineteenth Revised Page No. 63 2. The amount of $.388 per Mcf for recovery of non-gas costs. Each time there is a change in the provision for recovery of purchased gas costs pursuant to Rider "A" of this tariff, a recomputation shall be made of the commodity component of purchased gas costs (Item 1, above) and the rate per Mcf shall be changed accordingly. The component included in the rate for recovery of non-gas costs shall remain constant until changed in accordance with a procedure, other than a proceeding pursuant to Section 137(f) of the Public Utility Code, 66 Pa.C.S. Section 137(f). 2. Commodity Charge for Transportation Service The monthly Commodity Charge for Transportation Service shall be the product of multiplying the rate per Mcf, determined as provided below, by the volume of gas transported by the Company to the Customer's load balancing facilities. The rate per Mcf for transportation of gas under this rate schedule shall be $.648 per Mcf, which includes $.388 for recovery of non-gas costs and $.26 for recovery of purchased gas. (D) (D) V. SURCHARGE The Demand Charges and the Commodity Charge for Sales Service and the Commodity Charge for Transportation Service shall be subject to surcharges in accordance with provisions of Rider B - State Tax Adjustment Surcharge. VI. AMOUNTS TO BE INCLUDED IN OVER/UNDERCOLLECTION OF GAS COSTS Purchased gas cost revenues billed under this rate schedule shall be included as revenues for recovery of gas costs for purposes of computing Factor "E" of Company's 137(f) rate in accordance with procedures set forth in Rider "A"- Section 137(f) Purchased Gas Costs. VII. SPECIAL PROVISIONS Monthly metered Special Provisions A through J contained in the Company's Rate Schedule for Transportation Service shall apply to transportation service under this rate schedule. VIII. RULES AND REGULATIONS The rules and regulations set forth in this tariff shall govern, where applicable, the supply of gas service under this rate schedule. (D) Indicates Decrease (I) Indicates Increase Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Sixty-Second Revised Page No. 65 Canceling Fifty-Ninth and Sixty-First Revised Page No. 65 LVIS Large Volume Industrial Service (Cont'd) C. An Industrial Customer, for which the Company estimates that the total volumes of gas purchased from the Company or transported by the Company during the next succeeding twelve months will be not less than 5, Mcf, if the Industrial Customer has used total volumes of gas in at least one billing month of not less than 4,167 Mcf, even if the Customer disagrees with the Company's estimate. D. An Industrial Customer for which the Company estimates that total volumes of gas to be used by the customer during the next succeeding twelve months will not be less than 5, Mcf of gas per year whether the gas is purchased by the Industrial Customer from the Company, delivered by the Company to the Industrial Customer, or obtained by the customer from another source. An Industrial Customer that meets the above criteria under this rate schedule at the beginning of an Application Period is required to continue to be subject to this rate schedule during all months of such Application Period. An Industrial Customer that meets the above criteria under this rate schedule during an Application Period is required to continue to be subject to this rate schedule during all or remaining months of such Application Period. MONTHLY RATE Basic Service Charge $89. per Month Distribution Charges 13.346 per 1 cubic feet for the first 1, cubic feet (D) 11.528 per 1 cubic feet for the next 1,9, cubic feet (D) 9.44 per 1 cubic 8.68 per 1 cubic feet for feet for the all next 18,, cubic feet over 2,, cubic feet (D) (D) Gas Adjustment Charge (1.181 ) per 1 cubic feet Purchased Gas Cost Component (Rider A) (.3 ) per 1 cubic feet Merchant Function Charge (Rider G) (1.184 ) Per 1 cubic feet Total Gas Adjustment Charge (I) (I) (I) For a period of 12 months starting when gas supply service hereunder is initiated to a former SATC, MMT or DMT customer by the Company, the rates for service under this rate schedule shall exclude the Gas Adjustment Charge. Former SATC, MMT or DMT customers will be charged during this 12 month period the DEDC factor as defined in Rider A to this tariff and as contained in the Distribution charges set forth above, as amended from time to time. (D) Indicates Decrease (I) Indicates Increase Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Twentieth Revised Page No. 66 Canceling Seventeenth and Nineteenth Revised Page No. 66 LVIS Large Volume Industrial Service (Cont'd) Natural Gas Supply Charge 58.791 per 1 cubic feet Purchased Gas Cost Component (I) (Rider A).135 per 1 cubic feet Merchant Function Charge (I) (Rider G) 1.5 per 1 cubic feet Gas Procurement Charge (Rider H) 59.976 per 1 cubic feet Total Natural Gas Supply (I) Charge The Natural Gas Supply Charge shall include a Merchant Function Charge (Rider G) to recover uncollectible costs associated with purchase gas costs of.2285% and the Gas Procurement Charge (Rider H) to recover costs of procuring natural gas pursuant to 52 Pa. Code 62.223. The above rates shall be subject to surcharges in accordance with provisions of Rider B - State Tax Adjustment Surcharge. RULES AND REGULATIONS The Rules and Regulations set forth in this tariff shall govern, where applicable, the supply of gas service under this rate schedule. APPLICABLE PERIOD year. The Application Period shall be the twelve months beginning March 1 of each (D) Indicates Decrease (I) Indicates Increase Issued: July 31, 213 (C) Indicates Change Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Fifty-Sixth Revised Page No. 72 Canceling Fifty-Fourth and Fifty-fifth Revised Page No. 72 Commercial and Public Authority, Small Volume Industrial, Intermediate Volume Industrial, Large Volume Industrial and Large Industrial customers, during the Company Peak Sales Month defined in Rate Schedule CPA-LBS and (b) the volume of service (expressed in Mcf) to all customers under the "Monthly Volume" provisions of Rate Schedule SB, during the Company Peak Sales Month defined in Rate Schedule CPA-LBS. 3. The amount determined in Item 1 above shall be divided by the amount determined in Item 2 above to determine the amount included in the rate for recovery of purchased gas costs. 4. The rate per Gas BDU shall be the amount for purchased gas demand costs (Item 3). The current rate per Gas BDU is as follows: Purchased Gas Demand Cost $.8319/BDU (D) Each time there is a change in the provision for recovery of purchased gas costs pursuant to Rider "A" of this tariff, a recomputation shall be made, under Items 1, 2 and 3, above, of the component to be included in the rate for purchased gas demand costs and the rate per Gas BDU shall be changed accordingly. b. Determination of Customer's Gas BDUs The Customer's Gas BDUs shall be determined as follows: The actual volumes of gas purchased by the Customer from the Company and used by the Customer in the separately-metered qualifying load balancing facilities during such Customer's Peak billing Cycle, as defined hereinafter, shall be multiplied by a fraction. The numerator shall be the number 3. The denominator shall be the number of days of service for which such Customer was billed in such Customer's Peak Billing Cycle. The Customer's Peak Billing Cycle shall be the single billing cy~le of maximum delivery to the Customer's separately-metered qualifying load balancing facilities that ended during on of the months of December, January, February and March during the period beginning with the most recentlycompleted billing cycle and ending with the current billing cycle. If the customer used no gas under this rate schedule during the most recently concluded billing cycles ended in December, January, February or March, then the level of Gas BDUs applicable to Customer shall be zero (). (D) Indicates Decrease Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Fifty-Ninth Revised Page No. 73 Canceling Fifty-Seventh and Fifty-Eighth Revised Page No. 73 2. Margin Demand Charge a. The rate per Margin BDU shall be $.3182 per Margin BDU. b. Determination of Customer's Margin BDUs The Customer's Margin BDUs shall be determined as follows: The actual deliveries of gas to the Customer by Company, including not only volumes of gas purchased by the Customer from the Company and used by the Customer in the separately-metered load balancing facilities but also volumes of Customerowned gas transported to the Customer's load balancing facilities through the Company's facilities, during such Customer's Peak billing Cycle, as defined hereinafter, shall be multiplied by a fraction. The numerator shall be the number 3. The denominator shall be the number of days of service for which such Customer was billed in such Customer's Peak Billing Cycle. The Customer's Peak Billing Cycle shall be the single billing cycle of maximum delivery to the Customer's separately-metered load balancing facilities that ended during one of the months of December, January, February and March during the period beginning with the most recently-completed billing cycle ended in December and ending with the current billing cycle. If the customer used no gas under this rate schedule during the most recently concluded billing cycles ended in December, January, February or March, then the level of Margin BDUs applicable to Customer shall be zero (). B. COMMODITY CHARGES FOR SALES AND FOR TRANSPORTATION SERVICE 1. Commodity Charge for Sales Service The monthly Commodity Charge for Sales Service shall be the product of multiplying the rate per Mcf, determined as provided below, by the volume of gas sold to the Customer by the Company during the applicable billing cycle. The rate per Mcf shall be determined as follows and shall be $4.4823 per Mcf, subject to revision as provided below: (I) The current components of the rate are as follows: Purchased Gas Commodity. Costs, set forth in Rider "A" Non Gas Costs $4.235/Mcf $.2473/Mcf (I) a. Determination of Rate eer Mcf The rate per Mcf shall be the sum of: 1. The net amount per Mcf for recovery of the commodity component of purchased gas costs and for recovery or refund of "E" factor amounts, the "PGCC", as determined in Rider "A"- Section 137(f) Purchased Gas Costs of this tariff; plus (D) Indicates Decrease (I) Indicates Increase Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P. U. C. No. 9 Twentieth Revised Page No. 74 Canceling Eighteenth and Nineteenth Revised Page No. 74 2. The amount of $.2473 per Mcf for recovery of non-gas costs. Each time there is a change in the provision for recovery of purchased gas costs pursuant to Rider "A" of this tariff, a recomputation shall be made of the commodity component of purchased gas costs (Item 1, above) and the rate per Mcf shall be changed accordingly. The component included in the rate for recovery of non-gas costs shall remain constant until changed in accordance with a procedure, other than a proceeding pursuant to Section 137(f) of the Public Utility Code, 66 Pa.C.S. Section 137(f). 2. Commodity Charge for Transportation Service The monthly Commodity Charge for Transportation Service shall be the product of multiplying the rate per Mcf, determined as provided below, by the volume of gas transported by the Company to the Customer's load balancing facilities. The rate per Mcf for transportation of gas under this rate schedule shall be $.573 per Mcf, which includes $.2473 for recovery of non-gas costs and $.26 for recovery of purchased gas. (D) (D) V. SURCHARGE The Demand Charges and the Commodity Charge for Sales Service and the Commodity Charge for Transportation Service shall be subject to surcharges in accordance with provisions of Rider B - State Tax Adjustment Surcharge as set forth in this tariff. VI. AMOUNTS TO BE INCLUDED IN OVER/UNDERCOLLECTION OF GAS COSTS Purchased gas cost revenues billed under this rate schedule shall be included as revenues for recovery of gas costs for purposes of computing Factor "E" of Company's 137(f) rate in accordance with procedures set forth in Rider "A"- Section 137(f) Purchased Gas Costs. VII. SPECIAL PROVISIONS Monthly metered Special Provisions A through J contained in the Company's Rate Schedule for Transportation Service shall apply to transportation service under this rate schedule. VIII. RULES AND REGULATIONS The rules and regulations set forth in this tariff shall govern, where applicable, the supply of gas service under this rate schedule. (D) Indciates Decrease (I) Indicates Increase Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Sixty-Second Revised Page No. 76 Canceling Fifty-Nineth and Sixty-First Revised Page No. 76 LIS Large Industrial Service (Cont'd) C. An Industrial Customer, for which the Company estimates that the total volumes of gas purchased from the Company or transported by the Company during the next succeeding twelve months will be not less than 2, Me, if the Industrial Customer has used total volumes of gas in at least one billing month of not less than 17, Me, even if the Customer disagrees with the Company's estimate. An Industrial Customer that meets the above criteria under this rate schedule at the beginning of an Application Period is required to continue to be subject to this rate schedule during all months of such Application Period. An Industrial Customer that meets the above criteria under this rate schedule during an Application Period is required to continue to be subject to this rate schedule during all or remaining months of such Application Period. MONTHLY RATE Basic Service Charge $1,29. per Month Distribution Charges 11.37 per 1 cubic 9.237 per 1 cubic 7.168 per 1 cubic 5.81 per 1 cubic feet for feet for feet for feet for the the the all first 1, cubic feet next 1,9, cubic feet next 18,, cubic feet over 2,, cubic feet (D) (D) (D) (D) Gas Adjustment Charge (1.181 ) per 1 cubic (.3 ) per 1 cubic (1.184 ) per 1 cubic feet feet feet Purchased Gas Cost Component (Rider A) Merchant Function Charge (Rider G) Total Gas Adjustment Charge (I) (I) (I) For a period of 12 months starting when gas supply service hereunder is initiated to a former SATC, MMT or DMT customer by the Company, the rates for service under this rate schedule shall exclude the Gas Adjustment Charge. Former SATC, MMT or DMT customers will be charged during this 12 month period the DEDC factor as defined in Rider A to this tariff and as contained in the Distribution charges set forth above, as amended from time to time. (I) Indicates Increase (D) Indicates Decrease Issued: July 31, 213 (C) Indicates Change Effective: August 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Supplement No. 145 to Gas - Pa. P.U.C. No. 9 Fifth Revised Page No. 76A Canceling Fourth Revised Page No. 76A LIS Large Industrial Service (Cont'd) Natural Gas Supply Charge 58.791 per 1 cubic feet Purchased Gas Cost Component (Rider A).135 per 1 cubic feet Merchant Function Charge (Rider G) 1.5 per 1 cubic feet Gas Procurement Charge (Rider H) 59.976 per 1 cubic feet Total Natural Gas Supply Charge (I) (I) (I) The Natural Gas Supply Charge shall include a Merchant Function Charge (Rider G) to recover uncollectible costs associated with purchase gas costs of.2285% and the Gas Procurement Charge (Rider H) to recover costs of procuring natural gas pursuant to 52 Pa. Code 62.223. The above rates shall be subject to surcharges in accordance with provisions of Rider B - State Tax Adjustment Surcharge. GAS SHORTAGE CURTAILMENT Service under this schedule to an LIS Industrial Customer is subject to curtailment and excess consumption penalty as set forth in Rule 26 of this tariff. RULES AND REGULATIONS The rules and regulations set forth in this tariff shall govern, where applicable, the supply of gas service under this rate schedule. (D) Indicates Decrease (I) Indicates Increase Issued: July 31, 213 (C) Indicates Change Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Fifty-Sixth Revised Page No. 79 Canceling Fifty-Fourth and Fifty-Fifth Revised Page No. 79 LBS and (b) volume of service (expressed in Mcf) to all customers under the "Monthly Volume" provisions of Rate Schedule SB, during the Company Peak Sales Month defined in Rate Schedule CPA-LBS. 3. The amount determined in Item 1 above shall be divided by the amount determined in Item 2 above to determine the amount included in the rate for recovery of purchased gas costs. 4. The rate per Gas BDU shall be the amount for purchased gas demand costs (Item 3). The current rate per Gas BDU is as follows: Purchased Gas Demand Cost $.8319/BDU (D) Each time there is a change in the provision for recovery of purchased gas costs pursuant to Rider "A" of this tariff, a recomputation shall be made, under Items 1, 2 and 3, above, of the component to be included in the rate for purchased gas demand costs and the rate per Gas BDU shall be changed accordingly. b. Determination of Customer's Gas BDUs The Customer's Gas BDUs shall be determined as follows: The actual volumes of gas purchased by the Customer from the Company and used by the Customer in the separately-metered load balancing facilities during such Customer's Peak billing Cycle, as defined hereinafter, shall be multiplied by a fraction. The numerator shall be the number 3. The denominator shall be the number of days of service for which such Customer was billed in such Customer's Peak Billing Cycle. The Customer's Peak Billing Cycle shall be the single billing cycle of maximum delivery to the Customer's separately-metered load balancing facilities that ended during one of the months of December, January, February and March during the period beginning with the most recently-completed billing cycle ended in December and ending with the current billing cycle. If the customer used no gas under this rate schedule during the most recently concluded billing cycles ended in December, January, February or March, then the level of Gas BDUs applicable to Customer shall be zero (). (D) Indicates Decrease (I) Indicates Increase Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Fifty-Ninth Revised Page No. 8 Canceling Fifty-Seventh and Fifty-Eighth Revised Page No. 8 2. Margin Demand Charge a. The rate per Margin BDU shall be $.2517 per Margin BDU. b. Determination of Customer's Margin BDUs The Customer's Margin BDUs shall be determined as follows: The actual deliveries of gas to the Customer by Company, including not only volumes of gas purchased by the Customer from the Company and used by the Customer in the separately-metered load balancing facilities but also volumes of Customerowned gas transported to the Customer's load balancing facilities through the Company's facilities, during such Customer's Peak billing Cycle, as defined hereinafter, shall be multiplied by a fraction. The numerator shall be the number 3. The denominator shall be the number of days of service for which such Customer was billed in such Customer's Peak Billing Cycle. The Customer's Peak Billing Cycle shall be the single billing cycle of maximum delivery to the Customer's separately-metered load balancing facilities that ended during one of the months of December, January, February and March during the period beginning with the most recently-completed billing cycle ended in December and ending with the current billing cycle. If the customer used no gas under this rate schedule during the most recently concluded billing cycles ended in December, January, February or March, then the level of Margin BDUs applicable to Customer shall be zero (). B. COMMODITY CHARGES FOR SALES AND FOR TRANSPORTATION SERVICE 1. Commodity Charge for Sales Service The monthly Commodity Charge for Sales Service shall be the product of multiplying the rate per Mcf, determined as provided below, by the volume of gas sold to the Customer by the Company during the applicable billing cycle. The rate per Mcf shall be determined as follows and shall be $4.4274 per Mcf, subject to revision as provided below: (I) The current components of the rate are as follows: Purchased Gas Commodity Costs, set forth in Rider "A" Non Gas Costs $4.235/Mcf $.1924/Mcf (I) a. Determination of Rate per Mcf The rate per Mcf shall be the sum of: (I) Indicates Increase Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Twentieth Revised Page No. 81 Canceling Eighteenth and Nineteenth Revised Page No. 81 1. The net amount per Mcf for recovery of the commodity component of purchased gas costs and for recovery or refund of "E" factor amounts, the "PGCC", as determined in Rider "A"- Section 137(f) Purchased Gas Costs of this tariff; plus 2. The amount of $.1924 per Mcf for recovery of non-gas costs. Each time there is a change in the provision for recovery of purchased gas costs pursuant to Rider "A" of this tariff, a recomputation shall be made of the commodity component of purchased gas costs (Item 1, above) and the rate per Mcf sh~ll be changed accordingly. The component included in the rate for recovery of non-gas costs shall remain constant until changed in accordance with a procedure, other than a proceeding pursuant to Section 137(f) of the Public Utility Code, 66 Pa.C.S. Section 137(f). 2. Commodity Charge for Transportation Service The monthly Commodity Charge for Transportation Service shall be the product of multiplying the rate per Mcf, determined as provided below, by the volume of gas transported by the Company to the Customer's load balancing facilities. The rate per Mcf for transportation of gas under this rate schedule shall be $.4524 per Mcf, which includes $.1924 for recovery of non-gas costs and $.26 for recovery of purchased gas. (D) (D) V. SURCHARGE The Demand Charges and the Commodity Charge for Sales Service and the Commodity Charge for Transportation Service shall be subject to surcharges in accordance with provisions of Rider B - State Tax Adjustment Surcharge as set forth in this tariff. VI. AMOUNTS TO BE INCLUDED IN OVER/UNDERCOLLECTION OF GAS COSTS Purchased gas cost revenues billed under this rate schedule shal~ be included as revenues for recovery of gas costs for purposes of computing Factor "E" of Company's 137(f) rate in accordance with procedures set forth in Rider "A"- Section 137(f) Purchased Gas Costs. VII. SPECIAL PROVISIONS Monthly metered Special Provisions A through J contained in the Company's Rate Schedule for Transportation Service shall apply to transp?rtation service under this rate schedule. VIII. RULES AND REGULATIONS The rules and regulations set forth in this tariff shall govern, where applicable, the supply of gas service under this rate schedule. (I) Indicates Decrease (I) Indicates Increase Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Fifty-Seventh Revised Page No. 82 Canceling Fifty-Fifth and Fifty-Sixth Revised Page No. 82 RATE SCHEDULE - NGV NATURAL GAS VEHICLE SERVICE I. APPLICABILITY Throughout the territory served under this tariff. II. AVAILABILITY Sales Service under this rate schedule is available for use of natural gas by a customer directly in a natural gas motor vehicle ("NGV"). III. NATURE OF SERVICE Service provided in this rate schedule shall be firm service subject to the curtailment priorities of Rule 26. For curtailment purposes, service under this rate schedule shall be defined as curtailment priority number (6), firm large noncritical commercial and industrial requirements other than requirement for boiler fuel use. IV. RATE Rates per 1 cu. Ft. shall be established by the Company on the first day of each calendar month for each of the categories set forth below to compete with alternative vehicle fuels. The rates shall not be less than the 1% load factor base cost of gas, plus the take-or-pay surcharge, plus the surcharge for Transition Cost, plus the incremental operating cost incurred by the Company for operating Company owned NGV compression equipment on a per Ccf basis, if any, plus $.1 per cu. ft., plus the state tax adjustment surcharge, and not more than the tailblock rate of the Commercial and Public Authority Service Rate Schedule, including all applicable surcharges, plus the incremental operating cost incurred by the Company for operating Company owned NGV compression equipment on a per Ccf basis, if any. The 1% load factor base cost of gas shall be $.5669 per 1 cu. ft. (as calculated by adding the purchase gas components of the Load Balancing Service Rates). (I) Purchased Gas 1% Load Factor Demand Cost plus Purchased Gas Commodity Cost Equals 1% Load Factor Base Cost of Gas $.8319/Ccf $.4235/Ccf $.5669/Ccf (D) (I) (I) The incremental operating cost for compression shall be $.13436/Ccf. (D) Indicates Decrease (I) Indicates Increase Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Seventy-Seventh Revised Page No. 83 Canceling Seventy-Fourth and Seventy-Sixth Revised Page No. 83 Natural gas vehicle customers are classified into the following categories: NGV(1) All natural gas vehicle customers utilizing Company owned filling facilities. A uniform rate shall be established each month within the parameters set forth above, for customers utilizing Company-owned filling facilities. The minimum NGV(1) rate shall be: The current components of the minimum NGV(1) rate are as follows: 1% load factor base cost of gas: Incremental operating cost of Company owned NGV compression equipment: Transition Cost Surcharge State Tax Adjustment Surcharge Minimum allowable Non-Gas cost The maximum NGV(1) rate shall be: The current components of the maximum NGV(1) rate are as follows: Tailblock rate of the Commercial and Public Authority Service Rate schedule: Incremental operating cost of Company owned NGV compression equipment: State Tax Adjustment Surcharge $.64981/Ccf $.5669/Ccf $.13436/Ccf $./Ccf ($.124)/Ccf $.1/Ccf $.86754/Ccf $.73483/Ccf $.13436/Ccf ($.165)/Ccf (I) (I) (D) (I) (I) (D) NGV(2) Natural gas vehicle customers utilizing customer owned filling facilities. A uniform rate will be established each month within the parameters set forth above, to customers utilizing customer owned filling facilities. The minimum NGV(2) rate shall be: The current components of the minimum NGV(2) rate are as follows: 1% load factor base cost of gas: Transition Cost Surcharge State Tax Adjustment Surcharge Minimum allowable Non-Gas cost The maximum NGV(2) rate shall be: $.51571/Ccf $.5669/Ccf $./Ccf ($.98)/Ccf $.1/Ccf $.73343/Ccf (I) (I) (D) (I) (I) Indicates Increase (D) Indicates Decrease Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Seventy-Second Revised Page No. 84 Canceling Sixty-Ninth and Seventy-First Revised Page No. 84 The current components of the maximum NGV(2) rate are as follows: V. SURCHARGE Tailblock rate of the Commercial and Public Authority Service Rate schedule: State Tax Adjustment Surcharge $.73483/Ccf ($.14)/Ccf (I) (D) All charges under this rate schedule will be subject to surcharges in accordance with provisions of Rider B - State Tax Adjustment Surcharge as set forth in this tariff. VI. AMOUNTS TO BE INCLUDED IN OVER/UNDERCOLLECTION OF GAS COSTS Purchased gas cost revenues billed under this rate schedule shall be included as revenues for recovery of gas costs for purposes of computing Factor "E" of Company's 137(f) rate in accordance with procedures set forth in Rider "A"- section 137(f) Purchased Gas Costs. Purchased gas cost revenues recovered under this rate schedule shall be the 1% load factor base cost of gas as defined above. VII. RULES AND REGULATIONS The rules and regulations set forth in this tariff shall govern, where applicable, the supply of gas service under this rate schedule. (I) Indicates Increase (D) Indicates Decrease Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Thirty-First Revised Page No. 93 Canceling Twenty-Ninth and Thirtieth Revised Page No. 93 RATE SCHEDULE PSB APPLICABILITY PRIORITY STANDBY SERVICE Throughout the territory served under this tariff. AVAILABILITY OF SERVICE Service under this rate schedule is available to all customers under the Residential, Commercial and Public Authority, and SVIS Rate Schedules which enter into a contract for service under this Rate Schedule. A customer will be permitted to enter into a contract, prepared by the Company, for service under this rate schedule, however, only if the Company projects that sufficient volumes of gas will be available to the Company during the period of the customer's contract for Priority Standby Service. Service under this rate schedule is mandatory for all customers categorized as Priority 1 under the curtailment priorities of Rule 26 who enter into contracts with the Company to receive Transportation Service and who do not have dual or alternate fuel equipment on site which is installed and operable with sufficient amounts of alternate fuel available on site during each winter period of each year commencing on December 1 and ending on March 31 of the following year. Service under this rate schedule is voluntary for all other customers. NATURE OF SERVICE Priority standby service shall permit the customer to purchase gas on a firm basis subject to curtailment priorities of Rule 26. The Company will take all reasonable steps to obtain or to maintain gas supplies sufficient to enable the Company to provide reasonably continuous service to each Customer receiving Priority Standby Service. MONTHLY RATE The monthly rate shall be $1.1112 per Mcf, which shall be applied to the total monthly volumes transported by the customer during the month. (I) The rate shall equal the PGDC portion of the commodity rate applicable to the corresponding sales rate classification. (I) Indicates Increase Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas- Pa. P.U.C. No. 9 Thirty-First Revised Page No. 95 Canceling Twenty-Ninth and Thirtieth Revised Page No. 95 MONTHLY RATE The monthly rate shall be $.5249 per Mcf, which shall be applied to the Monthly Volume, as defined below. (I) MONTHLY VOLUME The Mcf volume of gas to which the Monthly Rate set forth above shall be applied, shall be determined for each billing cycle, as set forth below; 1. The volume of gas specified in the Service Agreement under this rate schedule shall be adjusted for each billing cycle by, multiplying such volume, expressed in Mcf, by a fraction. The numerator of the fraction shall be the number of days in the billing cycle applicable to the customer and the denominator shall be thirty (3). 2. If the volume determined under item 1, above, is greater than the sum of the Mcf volume of gas purchased by the customer under rate schedules other than load balancing rate schedules during the billing cycle, the Monthly Rate shall be applied to the difference between: (a) the volume determined under item 1, above, and (b) the Mcf volume of gas purchased by the customer under the rate schedules other than load balancing rate schedules during such billing cycle. 3. If the volume determined under item 1, above, is equal to or less than the Mcf volume of gas purchased by the customer under rate schedules other than load balancing rate schedules during the billing cycle, then the Monthly Volume shall be zero () Mcf. (I) Indicates Increase Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Twenty-Eighth Revised Page No. 1 Canceling Twenty-Sixth and Twenty-Seventh Revised Page No. 1 RATE SCHEDULE FOR MONTHLY METERED TRANSPORTATION SCHEDULE (cont'd) MONTHLY RATES Commodity Rates The commodity rates set forth below contain a component, presently $.26 per Mcf, for recovery of purchased gas costs. (D) For transportation of gas to Residential Customers, the monthly rate for transportation of gas both within and outside the Commonwealth of Pennsylvania shall be: $3.398 Mcf (D) For transportation of gas to Commercial and Public Authority Customers, the monthly rate for transportation of gas produced within the Commonwealth of Pennsylvania shall be: $2.8972 per Mcf for Small Commercial/Public Authority using not more (D) than 25 Mcf per year $2.2341 per Mcf for Small Commercial/Public Authority using greater (D) than 25 Mcf but not more than 1, Mcf per year $1.7462 per Mcf for Large Commercial/Public Authority (D) For transportation of gas to Commercial and Public Authority Customers, the monthly rate for transportation of gas produced outside the Commonwealth of Pennsylvania shall be: $2.8972 per Mcf for Small Commercial/Public Authority using not more (D) than 25 Mcf per year $2.2341 per Mcf for Small Commercial/Public Authority using greater (D) than 25 Mcf but not more than 1, Mcf per year $1.7462 per Mcf for Large Commercial/Public Authority (D) For transportation of gas to Small Volume Industrial Customers, the monthly rate for transportation of gas produced within the Commonwealth of Pennsylvania shall be: $2.597 per Mcf for SVIS Customers (D) For transportation of gas to Small Volume Industrial Customers, the monthly rate for transportation of gas produced outside the Commonwealth of Pennsylvania shall be: $2.597 per Mcf for SVIS Customers (D) (I) Indicates Increase (D) Indicates Decrease Issued: July 31, 213 (C) Indicates Change Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Twenty-Seventh Revised Page No. 11 Canceling Twenty-Fifth and Twenty-Sixth Revised Page No. 11 RATE SCHEDULE FOR MONTHLY METERED TRANSPORTATION SCHEDULE (cont'd) For transportation of gas to Intermediate Volume Industrial Customers, the monthly rate for transportation of gas produced within the Commonwealth of Pennsylvania shall be: $1.366 per Mcf for IVIS Customers (D) For transportation of gas to Intermediate Volume Industrial Customers, the monthly rate for transportation of gas produced outside the Commonwealth of Pennsylvania shall be: $1.366 per Mcf for IVIS Customers (D) For transportation of gas to Large Volume Industrial Customers and any entity that is not a Gas Service Customer, the monthly rate for transportation of gas produced within the Commonwealth of Pennsylvania shall be: $1.129 per Mcf (D) For transportation of gas to Large Volume Industrial Customers and any entity that is not a Gas Service Customer, the monthly rate for transportation of gas produced outside the Commonwealth of Pennsylvania shall be: $1.129 per Mcf (D) For transportation of gas to Large Industrial Customers, the monthly rate for transportation of gas produced within the Commonwealth of Pennsylvania shall be: $.759 per Mcf (D) For transportation of gas to Large Industrial Customers, the monthly rate for transportation of gas produced outside the Commonwealth of Pennsylvania shall be: $.759 per Mcf (D) Provided, however, that the Company, in its sole discretion, may reduce by contract the portion of the above rates applicable to the Customer that are for recovery of gas or the portion of the rate for recovery of non-gas costs of service if it is reasonably necessary to do so to meet competition from another supplier of energy including gas from another supplier of gas that has constructed, or could construct, facilities to deliver supplies of gas to a MMT Customer of the Company without use of the Company's facilities or another transportation of gas. The Company may also reduce or eliminate the compensation for line losses provided for in Special Provisions paragraph B of this rate schedule in order to meet the competitive circumstances for alternate fuels or bypass situations cited above excluding competition from other Pennsylvania local distribution companies. The Company will reduce the applicable rate only if: (a) Either (1) the MMT Customer has facilities in place and operable to use an alternative fuel or obtain gas from an alternative supplier or (2) in the Company's judgment, such facilities would be constructed; (I) Indicates Increase (C) Indicates Change (D) Indicates Decrease Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Sixty-Second Revised Page No. 16 Canceling Sixtieth and Sixty-First Revised Page No. 16 E. In the event of interruption or curtailment of transportation service, pursuant to items C and D, above, and during such period of interruption or curtailment, the MMT Customer must sell to the Company all or a portion of the MMT Customer's supply of gas at the higher of (1) the Transportation Service Customer's cost of purchased gas at the point of delivery to the Company or (2) the Company's average cost of purchased gas per Mcf, as determined based upon the Company's Section 137(f) Rate, which is $6.1459. (I) F. If for any reason (including the default of an MMNGS Supplier), the MMNGS Supplier fails to provide sufficient daily deliveries of natural gas supplies to meet the MMT Customers DDQ pursuant to the terms of MMNGS supply service, and/or MMT Customer's MMNGS Supplier does not provide complete compensation to the Company for services provided under Rate Schedule MMNGS, Special Provision.3, the Company shall charge the MMT Customer for the deficient daily deliveries under the applicable gas sales rate schedule plus applicable surcharge as set forth in Rate Schedule SB Special Provisions. (I) Indicates Increase Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Supplement No. 145 to Gas - Pa. P.U.C. No. 9 Seventh Revised Page No. 116 Canceling Sixth Revised Page No. 116 BILLING Monthly charges, for transportation service pursuant to this rate schedule, are subject to the Late Payment Charges set forth in Section 16 of the Rules and Regulations of this Tariff. SPECIAL PROVISIONS A. The volume of gas delivered into the Company's distribution system, on any day in behalf of Transportation Service Customers for transportation service pursuant to this Rate Schedule, shall be determined by meters and as provided in B, below, at the delivery points specified in the service Agreement or to another point or points acceptable to the Company. If any such point of delivery is also a point at which the Company buys or exchanges gas for the Company's own account through the same meter, the volume of gas delivered into the Company's distribution system, in behalf of Transportation Service Customers for transportation service, shall be deemed to be the volume scheduled by the Company and such Customers to be delivered in behalf of such Customers, at such point on such day, determined after the adjustment provided in B, below, but shall not be more than the total amount actually delivered, determined after the adjustment provided in B below, through such meter into the Company's distribution system at such point on such day. B. To compensate for line losses, the volume of gas delivered into the Company's distribution system, shall be determined for purposes of this Rate Schedule, effective August 1, 213 to be equal to 99.85% of the amount indicated by a meter at the point of delivery into the Company's distribution system; provided however, that, where the only Company facilities involved in transporting gas to the Gas Service Customer are meters, meter installations, house regulators, house regulator installations and industrial measuring and regulating station equipment, no amount shall be deducted as compensation for line losses. (C) (D) C. Service under this Rate Schedule may be interrupted during periods of supply shortages but only based upon the schedule of priority of curtailment set forth in section 26 of the Rules and Regulations of this tariff. D. Transportation service under this Rate Schedule may be interrupted or curtailed whenever, in the event of a sudden and unforeseen supply deficiency, the Company invokes emergency curtailment provisions under Tariff Rule 26. (C) (D) Indicates Change Indicates Decrease Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Sixty-First Revised Page No. 117 Canceling Fifty-Ninth and Sixtieth Revised Page No. 117 E. In the event of interruption or curtailment of transportation service, pursuant to items C and D, above, and during such period of interruption or curtailment, the DMT Service Customer must sell to the Company all or a portion of the DMT Service Customer's supply of gas at the higher of (1) the Transportation Service Customer's cost of purchased gas at the point of delivery to the Company or (2) the Company's average cost of purchased gas per Mcf, as determined based upon the Company's Section 137(f) Rate, which is $6.1459. (I) F. If a Gas Service Customer receiving gas transported by the Company uses less than the amount of gas delivered into the Company's system for transportation to such Customer ("excess deliveries"), the Gas Service Customer receiving gas transported by the Company may use such gas during the banking/balancing period defined below, following which the Company shall have the right, but not the obligation, to purchase remaining excess deliveries of gas from the DMT service Customer at a rate equal to the lowest of (1) the cost at which it was acquired by the DMT Service Customer, including pipeline transportation charges, or (2) the Company's average commodity delivered cost of gas to National Fuel Gas Supply Corporation, or (3) the Company's average commodity cost of locally produced gas during the month when excess deliveries were received by the Company. The cost at which the DMT Service Customer acquired the gas will be determined from such Customer's contract with the supplier or by a sworn affidavit setting forth the Customer's cost of gas, including cost of delivery of such gas to the Company's system. Upon request by the Company, the DMT Service Customer will be required to furnish to the Company the DMT service Customer's choice of (1) a copy of this contract or (2) an affidavit. The banking/balancing period shall be the three billing months after the billing month in which the Company received excess deliveries in behalf of the Customer. G. "Underdeliveries" are volumes of gas taken from the Company by a Gas Service Customer in excess of the sum of (1) any excess deliveries of the customer at the beginning of the day and (2) the volume of gas delivered to the Company for the customer's account, after adjustment for line losses less volumes of volumes of gas determined to be sales by the Company to the customer. Cumulative underdeliveries, as determined each day, in excess of two percent of the volume of gas delivered by the Company to the customer that day, shall be a sale of gas by the Company to the customer under the applicable rate schedule plus applicable surcharges as set forth in Rate Schedule SB Special Provisions and shall not be recharacterized as transportation service under any circumstances. Cumulative underdeliveries of not more than two percent of the volume of gas delivered to a customer by the Company on any day may be offset by volumes of gas delivered to the Company for the customer's account, after adjustment for line losses, in excess of the volume of gas taken by the customer from the Company on subsequent days within the same billing month. (I) Indicates Increase Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Supplement No. 145 to Gas - Pa. P.U.C. No. 9 Twelfth Revised Page No. 1188 Canceling Eleventh Revised Page No. 1188 RATE SCHEDULE MMNGS MONTHLY METERED NATURAL GAS SUPPLIER SERVICE (Cont.) The Company shall provide the Supplier receiving standard Billing Service with meter reading information and other reports in the Company's standard electronic format on a basis corresponding to the MMT Customer's billing cycles. The Supplier shall provide the Company with all required Supplier billing and rate information necessary for customer billing as determined by the Company. The Supplier shall provide such billing information in the Company's required format. The Supplier shall provide its billing information no later than three business days before the last day of the month. The Company will bill the MMT Customer for gas supplies sold by the Supplier to the Customer subject to the Supplier entering into a billing service contract with the Company. Payments made by the MMT Customer under the billing service will be applied first to amounts to past service due under an amortization agreement with the Company, next to current bills due to the Company, next to gas supply charges owed to the Supplier, next to charges for other non-regulated service charges, and lastly to any "neighbor for neighbor" contribution. The terms and charges for the Supplier billing services other than Standard Billing Services may be negotiated between the Company and the Supplier. The Company shall be under no obligation to provide the Supplier billing services other than Standard billing Services if mutually agreeable terms and charges cannot be negotiated. SPECIAL PROVISIONS A. Gas Quality Gas delivered by the Supplier must satisfy the quality specifications included in the Rules for Transportation Service section of this tariff. For deliveries to the Company, such deliveries must be made at an appropriate Company facility located within the Territory, as described in this tariff, or at another point or points acceptable to the Company. B. Allocation Priority If any such point of delivery is also a point at which the Company buys or exchanges gas for the Company's own account though the same meter, the volume of gas delivered into the Company's distribution system, in behalf of MMT customers, shall be deemed in behalf of such MMT Customers, at such point on such day, determined after the adjustment provided in C, below, but shall not be more than the total amount actually delivered, determined after the adjustment provided in C below, through such meter into the Company's distribution system at such point on such day. C. Allowance for Losses As allowance for losses incurred in the process of delivery except as provided in Special Provision B under the MMT Rate schedule, Leaf No. 15, the Supplier shall provide the Company with a volume of gas equal to.15% of the amount delivered to the Company. (D) (D) Indicates Decrease Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Fifteenth Revised Page No. 119A Canceling Thirteenth and Fourteenth Revised Page No. 119A RATES AND CHARGES RATE SCHEDULE SATC SMALL AGGREGATION TRANSPORTATION CUSTOMER SERVICE (Cont'd) A. Customer Transportation Service Rates The Company will provide transportation services to deliver gas supplies to the SATC Customer(s). The Customer shall be billed the charges for the transportation services rendered for it at the appropriate charges provided herein for which service the SATC Customer qualifies. The SATC Customer shall pay the following transportation charges for the transportation of gas. The commodity rates set forth below contain a component, presently $.238 per Ccf, for the recovery of purchased gas demand costs and shall be adjusted pursuant to Rider A of the tariff. Such purchased gas costs collected though these rates shall be included as revenues for the recovery of purchased gas costs as specified in Rider A of this tariff. (D) (D) Indicates Decrease Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Sixty-Fourth Revised Page No. 12 Canceling Sixty-First and Sixty-Third Revised Page No. 12 RATE SCHEDULE SATC SMALL AGGREGATION TRANSPORTATION CUSTOMER SERVICE (Cont.) 1. Residential Transportation Rates SATC Customers that meet the qualifications under the Residential Service Rate Schedule classification: Rates per Residential SATC Customer per Month: $12. $.35371 $.2513 Basic Service Charge per 1 cubic feet for the first 5, cubic feet per 1 cubic feet for all over 5, cubic feet (D) (D) 2. Commercial and Public Authority Transportation Rates SATC Customers that meet the qualifications under the Commercial and Public Authority Service Rate Schedule classification: a. Rates per Commercial/Public Authority customer per month for "Small" Commercial/Public Customers using not more than 25, cubic feet per year: $19.89 $.2929 $.2632 Basic Service Charge per 1 cubic feet for the first 5, cubic feet per 1 cubic feet for all over 5, cubic feet (D) (D) b. Rates per Commercial/Public Authority customer per month for "Small" Commercial/Public Customers using greater than 25, cubic feet but not more than 1,, cubic feet per year: $27.53 $.2183 $.2439 Basic Service Charge per 1 cubic feet for the first 2, cubic feet per 1 cubic feet for all over 2, cubic feet (D) (D) c. Rates per Commercial/Public Authority customer per month for "Large" Commercial/Public Customers: $121.1 $.1867 $.16875 $.14691 Basic Service Charge per 1 cubic feet for the first 3, cubic feet per 1 cubic feet for the next 1,7, cubic feet per 1 cubic feet for all over 2,, cubic feet (D) (D) (D) (D) Indicates Decrease Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Sixty-Fourth Revised Page No. 121 Canceling Sixty-First and Sixty-Third Revised Page No. 121 RATE SCHEDULE SATC SMALL AGGREGATION TRANSPORTATION CUSTOMER SERVICE (Cont.) 3. Small Volume Industrial Service Transportation Rates SATC Customers that meet the qualifications under the Small Volume Industrial Service Rate Schedule classification: Rates per Small Volume Industrial Service SATC Customer per Month: $65.6 $.2377 Basic Service Charge per 1 cubic feet (D) 4. Intermediate Volume Industrial Service Transportation Rates SATC Customers that meet the qualifications under the Intermediate Volume Industrial Service Rate Schedule classification: Month: Rates per Intermediate Volume Industrial Service SATC Customer per $21.91 $.17826 $.13745 $.1551 Basic Service Charge per 1 cubic feet for the first 1, cubic feet per 1 cubic feet for the next 1,9, cubic feet per 1 cubic feet for all over 2,, cubic feet (D) (D) (D) B. Miscellaneous Customer Surcharges 1. Gas Adjustment Charges For a period of 12 months starting when service hereunder is rendered to the SATC Customer by the SATS Suppliers, the rates for transportation services under this service classification shall include an amount per 1 cubic feet equal to the sum of the Gas Adjustment Charge included in the currently applicable Purchased Gas rate as specified in Rider A plus the applicable Merchant Function Charge ("MFC") as specified in Rider G, both of this tariff and as adjusted from time to time. 2. Transition costs associated with FERC Order No. 636. The rates for service rendered pursuant to the service classification shall be subject to a monthly transition cost surcharge as described in Rider D to this tariff. 3. Residential rates shall be subject to surcharges in accordance with Rider F - LIRA Discount Charge as set forth in this tariff. 4. The above SATC rates shall be subject to surcharges in accordance with provisions of Rider B - State Tax Adjustment Surcharge. (D) Indicates Decrease Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Supplement No. 145 to Gas - Pa. P.U.C. No. 9 Fifth Revised Page No. 125A Canceling Fourth Revised Page No. 125A RATE SCHEDULE SATS SMALL AGGREGATION TRANSPORTATION SUPPLIER SERVICE (Cont.) SPECIAL PROVISION A. Gas Quality Gas delivered by the Supplier must satisfy the quality specification of the pipelines used to transport Supplier's gas. For deliveries to the Company, such deliveries must be made at an appropriate Company facility located within the Territory, as described in this tariff, or at another point or points acceptable to the Company. B. Allowance for Losses As allowance for losses incurred in the process of delivery, the Supplier shall provide the Company with a volume of gas equal to.15% of the amount delivered to the Company. In addition, for deliveries into Company capacity retained pursuant to Sections C.3. and C.5., Suppliers shall provide incremental quantities of gas equal to the amount of retainage required to transport gas from the receipt point into such Company retained capacity to the entry point to the Company's system ("City Gate"). (D) (D) Indicates Decrease Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Twenty-Sixth Revised Page No. 126 Canceling Twenty-Fourth and Twenty-Fifth Revised Page No. 126 RATE SCHEDULE SATS SMALL AGGREGATION TRANSPORTATION SUPPLIER SERVICE (Cont.) C. Total Upstream Capacity Requirements for SATS Suppliers SATS Suppliers shall be required to provide sufficient firm pipeline transportation and storage capacity to meet the estimated extreme day requirements of their SATC Customer groups as further described below. The SATS Suppliers' estimated extreme day requirements of their SATC Customer Group used for Supplier capacity allocations and requirements shall be based on a sixty-two (62) degree day extreme peak day calculation. The Company shall utilize peaking and temperature swing storage capacity retained by the Company and recovered through SATC rates to provide for any variances between actual and forecasted usage and for any peak delivery requirements for days colder than sixty-two (62) degree days. Such sufficient pipeline transportation and storage capacity shall be provided through the following means: 1. Released ESS Storage Capacity and Associated EFT Capacity a. Requirements To Be Met Through ESS Storage 6% of extreme peak day requirements shall be provided through the Company's ESS storage and associated EFT transportation capacity on NFGSC. Such NFGSC Storage and transmission capacity shall be released to SATS Suppliers at the maximum rate under the pipeline's FERC gas tariff. (D) b. Initial Assignment of ESS Storage Capacity In a month a SATS Supplier begins to serve SATC customers, it shall be provided with an initial assignment of storage capacity, based on the percentage set forth at C.l.a. above, to meet the Supplier's requirements for the upcoming winter period. Approximately fifteen days prior to the close of nominations for the month, the Company will calculate the quantity of storage capacity released to match the SATS Supplier's winter requirements based on the number of SATC Customers aggregated by the Supplier. If the initial assignment takes place in a month other than April, the Company will transfer storage gas to the Supplier pursuant to C.l.c below. The SATS Supplier shall be responsible for all taxes and pipeline fees associated with moving or transferring the storage gas to the Company. (D) Indicates Decrease (I) Indicates Increase Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Thirty-First Revised Page No. 127 Canceling Twenty-Ninth and Thirtieth Revised Page No. 127 RATE SCHEDULE SATS SMALL AGGREGATION TRANSPORTATION SUPPLIER SERVICE (Cont.) c. Additional Assignments of ESS Storage Capacity Approximately fifteen days prior to the close of nominations for each month, the Company will recalculate the quantity of storage capacity released to match the SATS Supplier's revised winter requirements based on the number of SATC Customers aggregated by the Supplier. If additional SATC Customers join a SATS Supplier's SATC Customer Group, the Company will release additional capacity as required, based on the percentage set forth at C.1.a. above. In addition, the SATS Supplier will be required to pay the Company for storage gas transferred and all taxes and pipeline fees associated with moving or transferring the storage gas to the Supplier. The storage gas transfer rate shall be the sum of (1) the higher of the Company's average cost of gas based upon the Company's Section 137f rate, or the DMI for the first day of month in which gas is transferred plus all transportation costs to the Company's City Gate, plus (2) the demand Transfer Recovery Rate ("DTR Rate"). The DTR rate shall equal the per Mcf System Average Unrecovered Demand Charge revenue beginning in the month of April through the initial month that storage capacity is released to the Supplier. The System Average Unrecovered demand Charge Revenue shall equal the sum of the differences between the average demand charge revenues and the average fixed demand costs beginning the month of April through the initial month that storage capacity is released to the Supplier. The DTR by month shall be as follows: Capacity Transfer Month DTR $/Mcf April $. May $. June $. July $. August $. September $. October $. November $.17 December $.42 January $.29 February $.1 March $. (D) (D) (D) (D) (D) Indicates Decrease Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Twenty-Ninth Revised Page No. 131 anceling Twenty-Seventh and Twenty-Eighth Revised Page No. 131 RATE SCHEDULE SATS SMALL AGGREGATION TRANSPORTATION SUPPLIER SERVICE (Cont.) 2. Released Transmission Capacity Not Included in SATC Transportation Rates 4% of extreme peak day requirements is to be provided by the release (I) of pipeline capacity upstream of NFGSC and the release of associated EFT transportation capacity on NFGSC which is not included in transportation rates. All such capacity shall be released to SATS Suppliers, and SATS Suppliers shall take such released capacity, at the maximum rate under the pipeline's FERC gas tariff. The actual pipeline capacity path upstream of NFGSC to be released to the Supplier by the Company shall be designated by the Company from its available capacity. The Company will attempt to accommodate a Supplier's request for particular capacity on a first-come first-serve basis. As an alternative to the above, the Company may designate an alternative capacity path(s) from its available capacity. The capacity release rate for the pipeline capacity path released to the Supplier shall be $13.8762/Dth which equals the weighted average demand cost of upstream capacity, however, capacity released on NFGSC will be released at the maximum rate under NFGSC's FERC gas tariff. The Company will post a listing of the alternative capacity path(s) designated, including the associated quantity of capacity, on its web site. (D) For capacity termination notices, prior to the termination notice date of any capacity contract in this Section C.2., the Company will issue a request for proposals to qualified Suppliers under this tariff to determine if the Company should terminate, renew, or replace such contract, in whole or in part. The Company will terminate a proportionate share of the capacity contract if: (1) Suppliers demonstrate that they will provide comparable firm capacity to serve the Company's core customers, (2) the Suppliers agree to assign such comparable capacity at the contracted price to the Company upon Company request if such capacity is required to meet supply requirements of SATC Customers due to the termination of the SATS Supplier pursuant to Section H.1. or if the Supplier has reduced the level of delivery requirements from the previous periods requirements, and 3) the Commission approves such comparable capacity. Comparable capacity must have firm rights for at least the seven (7) winter months, and such capacity must have primary delivery rights into available primary receipt rights on NFGSC held by the Company. Comparable capacity must have firm capacity rights sufficient in volume and duration (with renewal rights) to serve the customers to be served by the SATS Supplier. The Company will post a listing of capacity contracts, including the associated quantity of capacity, that it determines to be of critical status on its web site. (D) Indicates Decrease Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Thirty-First Revised Page No. 146G Canceling Twenty-Ninth and Thirtieth Revised Page No. 146G E. In the event of interruption or curtailment of transportation service, pursuant to items C and D, above, and during such period of interruption or curtailment, the DMLMT Service customer must sell to the Company all or a portion of the DMLMT Service Customer's supply of gas at the higher of (1) the Transportation Service Customer's cost of purchased gas at the point of delivery to the Company or (2) the Company's average cost of purchased gas per Mcf, as determined based upon the Company's Section 137(f) Rate which is $6.1459. (I) F. If a Gas Service Customer receiving gas transported by the Company uses less than the amount of gas delivered into the Company's system for transportation to such Customer ("excess deliveries"), the Gas Service Customer receiving gas transported by the Company may use such gas during the banking/balancing period defined below, following which the Company shall have the right, but not the obligation, to purchase remaining excess deliveries of gas from the DMLMT Service Customer at a rate equal to the lowest of (1) the cost at which it was acquired by the DMLMT Service Customer, including pipeline transportation charges, or (2) the Company's average commodity delivered cost of gas to National Fuel Gas Supply Corporation, or (3) the Company's average commodity cost of locally-produced gas during the month when excess deliveries were received by the Company. The cost at which the DMLMT Service Customer acquired the gas will be determined from such Customer's contract with the supplier or by a sworn affidavit setting forth the Customer's cost of gas, including cost of delivery of such gas to the Company's system. Upon request by the Company, the DMLMT service Customer will be required to furnish to the Company the DMLMT Service Customer's choice of (1) a copy of this contract or (2) an affidavit. The banking/balancing period shall be the three billing months after the billing month in which the Company received excess deliveries in behalf of the Customer. G. "Underdeliveries" are volumes of gas taken from the Company by a Gas Service Customer in excess of the sum of (1) any excess deliveries of the customer at the beginning of the day and (2) the volume of gas delivered to the Company for the customer's account, after adjustment for line losses less volumes of gas determined to be sales by the Company to the customer. Cumulative underdeliveries, as determined each day, in excess of two percent of the volume of gas delivered by the Company to the customer that day, shall be a sale of gas by the Company to the customer under the applicable rate schedule plus applicable surcharges as set forth in Rate Schedule SB Special Provisions and shall not be recharacterized as transportation service under any circumstances. Cumulative underdeliveries of not more than two percent of the volume of gas delivered to a customer by the Company on any day may be offset by volumes of gas delivered to the Company for the customer's account, after adjustment for line losses, in excess of the volume of gas taken by the customer from the Company on subsequent days within the same billing month. (I) Indicates Increase Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Fifty-Eighth Revised Page No. 147 Canceling Fifty-Sixth and Fifty-Seventh Revised Page No. 147 RIDER A SECTION 137(F) PURCHASED GAS COSTS PROVISION FOR RECOVERY OF PURCHASED GAS COSTS Rates for each Mcf (1, cubic feet) of gas supplied under Residential, Low Income Residential Assistance Service, Commercial and Public Authority, Commercial and Public Authority Load Balancing Service ("LBS"), Small Volume Industrial, Intermediate Volume Industrial, Intermediate Volume Industrial LBS, Large Industrial, Large Industrial LBS, Large Volume Industrial, Large Volume Industrial LBS and Natural Gas Vehicle Service rate schedules of this tariff, shall include $4.235 per Mcf for recovery of purchased gas commodity costs, calculated in the manner set forth below, pursuant to Section 137(f) of the Public Utility Code. Rates for each Mcf (1, cubic feet) of gas supplied under Residential, Commercial and Public Authority, Small Volume Industrial Service, Intermediate Volume Industrial, Large Volume Industrial Service, Large Industrial Service and Standby Service rate schedules of this tariff, shall include $1.526 per Mcf for recovery of purchased gas demand costs, calculated in the manner set forth below, pursuant to Section 1~7(f) of the Public Utility Code. Rates for each Mcf (1, cubic feet) of gas transported under the Small Aggregation Transportation Customer Rate Schedule shall include $.238 per Mcf for the recovery of purchased gas demand costs. (I) (D) (D) Such rates for gas service shall be increased or decreased, from time to time, as provided by Section 137(f) of the Public Utility Code and the Commission's regulations, to reflect changes in the level of purchased gas costs. The amounts per Mcf for recovery of purchased gas costs (commodity and demand) included in rates under each rate schedule of the tariff are as follows: Re~idential Low Income Residential Assistance Service Commercial/Public Authority Small Volume Industrial Intermediate Volume Industrial Large Volume Industrial Large Industrial Standby Priority Standby Small Aggregation Transportation Customer Rate Schedule Distribution Gas Adjustment Natural Gas Total Charges Charge SUJ2J2ly Charge $5.999 $.238 ($.1181) $5.8791 $5.999 $.238 ($.1181) $5.8791 $5.999 $.238 ($.1181) $5.8791 $5.999 $.238 ($.1181) $5.8791 $5.999 $.238 ($.1181) $5.8791 $5.999 $.238 ($.1181) $5.8791 $5.999 $.238 ($.1181) $5.8791 $.5249 $1.1112 $.238 $.238 (I) (I) (I) (I) (I) (I) (I) (I) (I) (D) (I) Indicates Increase (D) Indicates Decrease Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Supplement No. 145 to Gas - Pa. P.U.C. No. 9 Fourth Revised Page No. 148 Canceling Second and Third Revised Page No. 148 COMPUTATION OF PURCHASED GAS COMMODITY COSTS PER MCF INCLUDED IN NATURAL GAS SUPPLY CHARGES Purchased gas commodity costs, per Mcf, shall be computed to the nearest one-hundredth cent (.1 ) in accordance with the formula set forth below: PGCC = cc ) (S) Purchased gas commodity costs, so computed, shall be included in Natural Gas Supply Charge rates charged to customers for gas service under the Residential, Commercial and Public Authority, Commercial and Public Authority Load Balancing Service ("LBS"), Small Volume Industrial, Intermediate Volume Industrial, Intermediate Volume Industrial LBS, Large Industrial, Large Industrial LBS, Large Volume Industrial and Large Volume Industrial LBS Service rate schedules for an initial period determined by the Commission and for consecutive twelve month periods beginning August l of each year thereafter, unless such period is revised by the Commission. The amount of purchased gas commodity costs, per Mcf, will vary, if appropriate, based upon annual filings, by the Company, pursuant to Section l37(f) of the Public Utility Code and such supplemental filings as may be required or be appropriate under Section l37(f) or the Commission's regulations adopted pursuant thereto. In computing purchased gas commodity costs, per Mcf, pursuant to the formula, above, the following definitions shall apply: "PGCC" - purchased gas commodity costs determined to the nearest onehundredth cent (.1 ) to be included in rates for each Mcf of gas supplied under Residential, Low Income Residential Assistance Service, Commercial and Public Authority, Commercial and Public Authority Load Balancing Service ("LBS"), Small Volume Industrial, Intermediate Volume Industrial, Intermediate Volume Industrial LBS, Large Industrial, Large Industrial LBS, Large Volume Industrial, Large Volume Industrial LBS and Natural Gas Vehicle Service rate schedules of this tariff. "CC" - the estimated current commodity cost of gas including all associated hedging costs and deferrals, shall be determined as follows: (a) for all type of purchased gas, project the commodity cost for each purchase (adjusted for net current gas stored) for the projected period when rates will be in effect plus (b) the arithmetical sum of (1) the projected book value of noncurrent gas at the beginning of the computation year minus (2) the projected book value of noncurrent gas at the end of the computation year. This factor shall include no amount for purchased gas demand or winter requirement charges of an interstate pipeline company. (C) Indicates Change Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Supplement No. 145 to Gas - Pa. P.U.C. No. 9 Fourth Revised Page No. 149 Canceling Second and Third Revised Page No. 149 "S" - projected Mcf of gas to be billed to customers under the commodity charges of the Residential, Commercial and Public Authority, Commercial and Public Authority Load Balancing Service ("LBS"), Small Volume Industrial, Intermediate Volume Industrial, Intermediate Volume Industrial LBS, Large Industrial, Large Industrial LBS, Large Volume Industrial and Large Volume Industrial LBS Service rate schedules of this tariff during the period when rates will be in effect. COMPUTATION OF PURCHASED GAS DEMAND COSTS PER MCF OF GAS INCLUDED IN NATURAL GAS SUPPLY CHARGES UNDER THE RESIDENTIAL, COMMERCIAL AND PUBLIC AUTHORITY, SMALL VOLUME INDUSTRIAL, INTERMEDIATE VOLUME INDUSTRIAL, LARGE VOLUME INDUSTRIAL, LARGE INDUSTRIAL AND STANDBY SERVICE RATE SCHEDULES Purchased gas demand costs, per Mcf, to be included in Natural Gas Supply Charge rates under Residential, Commercial and Public Authority, Small Volume Industrial, Intermediate Volume Industrial, Large Volume Industrial, Large Industrial and Standby rate schedules shall be computed to the nearest onehundredth cent (.1c), in accordance with the formula set forth below: PGDC = ( (DC) ) ( (S - (SBS) ) Purchased gas demand costs, so computed, shall be included in the rates charged to customers for gas service, pursuant to the Residential, Commercial and Public Authority, Small Volume Industrial Service, Intermediate Volume Industrial Service, Large Volume Industrial Service, Large Industrial Service and Standby Service rate schedules, for an initial period determined by the Commission and for consecutive twelve-month periods beginning August 1 of each year thereafter unless such period is revised by the Commission. The amount of purchased gas demand costs, per Mcf, will vary, if appropriate, based upon annual filings, by the Company, pursuant to Section 137(f) of the Public Utility Code and such supplemental filings as may be required or be appropriate under Section 137(f) or the Commission's regulations adopted pursuant thereto. In computing purchased gas demand costs, per Mcf, pursuant to the formula, above, the following definitions shall apply: "PGDC" - purchased gas demand costs determined to the nearest onehundredth cent (.1c) to be included in rates for each Mcf of gas supplied under Residential, Commercial and Public Authority, Small Volume Industrial Service, Intermediate Volume Industrial Service, Large Volume Industrial Service, Large Industrial Service and Standby Service rate schedules of this tariff. "DC" - the estimated current demand cost of gas, determined by projecting, for all types of purchased gas, the total demand and winterrequirement charges from any interstate pipeline company or any other source of gas supply purchased by the Company for the projected period when rates will be in effect less projected current purchased gas demand cost revenue recovered through Distribution charges. Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Supplement No. 145 to Gas - Pa. P.U.C. No. 9 Sixth revised Page No. 15 Canceling Fourth and Fifth Revised Page No. 15 "S" - projected Mcf to be billed to customers during the projected period under the Residential, Commercial and Public Authority, Small Volume Industrial, Intermediate Volume Industrial, Large Industrial and Large Volume Industrial Service rate schedules. "SBS" - projected Mcf volume to be billed to customers during the projected period under the Standby Service rate schedule. COMPUTATION OF PURCHASED GAS DEMAND COSTS PER MCF OF GAS INCLUDED IN THE DISTRIBUTION CHARGES UNDER THE SALES RATE SCHEDULES AND THE RATE SCHEDULE SMALL AGGREGATION TRANSPORTATION CUSTOMER SERVICE Purchased gas demand costs transportation, per Mcf, to be included in Distribution Charges under the Residential, Commercial and Public Authority, Small Volume Industrial, Intermediate Volume Industrial, Large Industrial and Large Volume Industrial Service rate schedules and the Rate Schedule Small Aggregation Transportation Customer Service shall be computed to the nearest one-hundredth cent (.1c), in accordance with the formula set forth below: PGDCT (OCT + DEDC) (S + SATCV) - (SBS) "PGDCT" - Purchased gas demand costs transportation, per Mcf, to be included in Distribution Charges under the Residential, Commercial and Public Authority, Small Volume Industrial, Intermediate Volume Industrial, Large Industrial and Large Volume Industrial Service rate schedules and the Rate Schedule Small Aggregation Transportation Customer Service. "OCT" - the estimated current demand cost of gas, determined by projecting, for all types of demand purchased gas capacity costs included in the Distribution Charges for Sales Service Rate Schedules and the Small Aggregation Transportation Customer Service Rates, the total usage, demand and winter-requirement charges from any interstate pipeline company or any other source of gas supply purchased by the Company for the projected period when rates will be in effect. "DEDC" - experienced net overcollection or undercollection of purchased gas demand costs included in the Distribution Charges. Such experienced net overcollection or undercollection shall be determined for the most recent period permitted under law which shall begin with the month following the last month which was included in the previous over-under collection calculation reflected in rates. The annual filing date shall be the date specified by the Company's Section 137(f) tariff filing and not the date established by the Commission for prefiling of certain information pursuant to 52 Pa. Code Sections 53.64(b) (1) and 53.65. Supplier demand refunds received for capacity associated with the SATS capacity release provisions will be included in the calculation of the "DEDC" with interest added at the annual rate of six percent (6%) calculated from the month received to the effective month such refund is refunded. All other Supplier demand refunds received will be included in the calculation of the "DE" with interest added at the annual rate of six percent (6%) calculated from the month received to the effective month such refund is refunded. Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Supplement No. 145 to Gas - Pa. P.U.C. No. 9 Fourth Revised Page No. 152 Canceling Second and Third Revised Page No. 152 The annual filing date shall be the date specified by the Company's Section 137(f) tariff filing and not the date established by the Commission for pre-filing of certain information pursuant to 52 Pa. Code Sections 53. 64 (b) ( 1) and 53. 65. Supplier commodity refunds received will be included in the calculation of "CE" with interest added at the annual rate of six percent (6%) calculated from the month received to the effective month such refund is refunded. Supplier commodity refunds will be included in the next quarterly filing after refunds are received pursuant to Case R-213-2341534. (C) "DE" - experienced net overcollection or undercollection of purchased gas demand costs. For the initial filing, pursuant to 137(f) of the Public Utility Code, in order to achieve an orderly transition from Gas Cost Rate procedures to Section 137(f) procedures, such experienced net overcollection or undercollection, to be reflected in rates effective September 1, 1985, shall be the net overcollection or undercollection arising under the Gas Cost Rate procedure. The amount of such net overcollection or undercollection shall include the historic net amount as of March 31, 1985 together with the projected net overcollection or undercollection for the five-month period ending,august 31, 1985. After the transition from the Gas Cost Rate procedures, established pursuant to the Commission's order of October 1, 1978 at M-78555, (52 Pa P.U.C. 217) as amended, to procedures established pursuant to Section 137(f) of the Public Utility Code, such experienced net overcollection or undercollection shall be determined for the most recent period permitted under law which shall begin with the month following the last month which was included in the previous over-under collection calculation reflected in rates. The annual filing date shall be the date specified by the Company's Section 137(f) tariff filing and not the date established by the Commission for pre-filing of certain information pursuant to 52 Pa. Code Sections 53.64(b)(1) and 53.65. Supplier demand refunds received will be included in the calculation of "DE" with interest added at the annual rate of six percent (6%) calculated from the month received to the effective month such refund is refunded. Supplier demand refunds will be included in the next quarterly filing after refunds are received pursuant to Case R-213-2341534. (C) "S1" - projected Mcf of gas to be billed to customers under the natural gas supply charges of the Residential, Commercial and Public Authority, Commercial and Public Authority Load Balancing Service ("LBS"), Small Volume Industrial, Intermediate Volume Industrial, Intermediate Volume Industrial LBS, Large Industrial, Large Industrial LBS, Large Volume Industrial and Large Volume Industrial LBS Service rate schedules of this tariff during the period when rates will be in effect. For a period of twelve months sales volumes associated with former SATC customers returning to sales service shall be excluded from the projected Mcf used in this calculation. "SATCV1" - Projected customer volume to be transported for the first twelve months of transportation service to former sales customers during the projected period under the Small Aggregation Transportation Rate Schedule. (C) Indicates Change Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Ninth Revised Page No. 155 Canceling Seventh and Eighth Revised Page No. 155 (9) An amount determined by multiplying volumes billed under the Small Aggregation Transportation Service rate schedule times the PGDCT charge recovered through rates under rate schedule Small Aggregation Transportation Customer Service. (1) An amount equal to the revenues from Daily Metered Transportation customers produced by charges for overdeliveries of transportation gas to such customers. (11) An amount equal to 75% of the revenues generated from the release of pipeline transmission and storage capacity other than releases for SATS customers. The Company shall retain the remaining 25%. (12) An amount equal to 75% of the savings from gas storage fill contracts as established in Case R-16789. The Company shall retain the remaining 25%. (13) An amount equal to 75% of asset management arrangements under FERC Order 712 for capacity releases associated with identified capacity contracts. The Company shall retain the remaining 25%. Interest shall be computed monthly at the appropriate rate provided for in Section 137(f) (5) of the Public Utility Code from the month that the over or under-collection occurs to the effective month such over-undercollection is refunded or recouped as appropriate. QUARTERLY UPDATES The Company's rates for recovery of purchased gas costs will be subject to quarterly adjustments under procedures set forth in the Commission's regulations at 52.Pa. Code 53.64(i) (5). Such updates will reflect, in addition to data specified in the regulation, changes in the projected commodity cost of purchased gas based upon the NYMEX source of data and method used in projecting the commodity cost of purchased gas approved by the Commission in the Company's most recent annual proceeding for recovery of purchased gas costs under Section 137(f) of the Public Utility Code. In addition, the Company will calculate rates in the November, February and May quarterly filings using remaining monthly sales volumes to determine the purchased gas cost rates. The projected remaining monthly sales volumes used in the February quarterly filing will also be used in the May quarterly filing. (C) The rate change will be no more than 25% of the rate using the prior 1 methodology of twelve months of sales volumes as allowed at Docket R-213-2341534. (C) Indicates Change Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Forty-First Revised Page No. 157 Canceling Thirty-Ninth and Fortieth Revised Page No. 157 RIDER B STATE TAX ADJUSTMENT SURCHARGE In addition to the charges provided in this tariff, a surcharge of (.19%) will apply to all charges for service rendered on or after August 1, (I) 213. The above surcharge will be recomputed using the same elements prescribed by the Commission. a. Whenever any of the tax rates used in calculation of the surcharge are changed; b. Whenever the utility makes effective any increased or decreased rates, and c. On March 31, 1971, and each year thereafter. The above recalculation will be submitted to the Commission within ten (1) days after the occurrence of the event or date which occasions such recomputation; and, if the recomputed surcharge is less than the one in effect, the Company will, and if the recomputed surcharge is more than the one then in effect, the Company may submit with such recomputation a tariff or supplement to reflect such recomputed surcharge, the effective date of which shall be ten (1) days after filing. (I) Indicates Increase Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Sixty-Eighth Revised Page No. 164 Canceling Sixty-Fifth and Sixty-Seventh Revised Page No. 164 RIDER F LIRA DISCOUNT CHARGE CURRENT LIRA RATE DISCOUNT Effective April 1, 22, a charge will be included in the rates subject to this Rider to provide for recovery of costs of the projected LIRA rate discounts for the upcoming 12 months. Such charge shall be updated quarterly and effective each February 1, May 1, August 1, and November 1 of the year. The charge will also be updated whenever there is a change to the Residential Sales Service Rate Customer Charge, Distribution Charge, Natural Gas Supply Charge, or Gas Adjustment Charge. APPLICABILITY In addition to the charges provided in this tariff, a charge calculated in the manner explained below shall be added to the otherwise applicable charge for each Mcf of sales and transportation volumes delivered by the Company to customers receiving service under the Residential Sales Service Rate Schedule and the Residential rates of the SATC, MMT, and DMT transportation rate schedules. CALCULATION OF RATE The charge will be recalculated as specified above. The charge shall be equal to the total annual projected discounts for LIRA customers for the upcoming 12 month period divided by the annual normalized throughput volumes of the qualified rate classes. The total annual projected discounts for the LIRA customers for the upcoming 12 month period shall equal the sum of the individual monthly total projected discounts for LIRA customers for the upcoming 12 months. The total monthly projected discounts for LIRA customers shall equal the residential bill for the average LIRA,customer consumption for the month multiplied by the average discount percentage for LIRA service multiplied by the projected number of LIRA customers for the month. The currently effective charge for the current LIRA Rate Discount to be included in rates is $.329/Mcf. (I) (I) Indicates Increase Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Thirty-Second Revised Page No. 167 Canceling Twenty-Ninth and Thirty-First Revised Page No. 167 RIDER F LIRA DISCOUNT CHARGE CAP FUNDING RECONCILIATION CHARGE (con't) CALCULATION OF RECONCILATION COMPONENT OF RATE (con't) The charge associated with the incremental customer credit will contain the following calculation: Effective February 1, 29 and thereafter, an annual credit of $35 per customer will be provided associated with the LIRA incremental customers. The credit will be based on the average number of LIRA customers billed during the previous fiscal period (October- September) less 11,411. The annual credit will continue until new base rates become effective as a result of a general rate proceeding. If the average number of LIRA customers billed during the previous fiscal period is 11,411 or less, the credit will be $. The CAP Funding Reconciliation Charge will be the summation of the charges calculated above divided by the projected February 1 through January 31 volumes. CAP Funding Reconciliation Charge Calculation LIRA Rate Discount $(296,63) + LIRA Program Costs $54,292 + LIRA Forgiven Pre-Program Arrear ages $(363,369) + LIRA Incremental Customer Credit $(14,875) Equals Total $(62,555) Divided by Projected Feb - Jan Volumes 16t59lt55 Mcf Cap Funding Reconciliation Charge I Mcf $(.374)/ Mcf ADJUSTMENT FOR OVER / UNDER RECOVERY OF PRIOR PERIOD CHARGE The filing to be effective February 1, 21 and every February 1 thereafter shall include a levelized rate for over/under collections for the prior (12) month period by comparing projected revenues under this Rider to actual revenue amounts experienced. The annual reconciliation shall be based upon actual revenues through December 31 and estimated revenues for January. Estimates for January shall be included in the following reconciliation period. The rate will be designed to recover or refund the applicable under or over recovery over the twelve (12) month period beginning February. RIDER F LIRA Discount Charge Component $/Mcf Current LIRA Rate Discount $.838 Cap Funding Reconciliation Charge $(.374) Adjustment for Over/Under Recovery of Prior Period Charge $(.135) Total RIDER F $.329 The currently effective charge to be included in rates is $.329/Mcf. (I) (I) (I) (D) Indicates Decrease (I) Indicates Increase Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS Supplement No. 145 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Seventeeth Revised Page No. 168 Canceling Fifteenth and Sixteenth Revised Page No. 168 Rider G Merchant Function Charge (MFC) Rider Applicability: The Merchant Function Charge (MFC) shall be added to the Natural Gas Supply Charge and Gas Adjustment Charge of Residential, LIRAS, Commercial and Public Authority, SVIS, IVIS, LVIS and LIS rate schedules. Such charges shall be updated quarterly and effective each February 1, May 1, August 1, and November 1 of the year. The charge will also be updated whenever there is a change to the Sales Service Rate Customer Charge, Distribution Charge, Natural Gas Supply Charge or Gas Adjustment Charge. Calculation of Rate: For customers receiving service in the Residential classification, the MFC shall equal 2.231% times the Natural Gas Supply Charge and the Gas Adjustment Clause as calculated for Rider A. The current Residential MFC Charge is: Natural Gas Supply Charge per Mcf Gas Adjustment clause (E-Factor) per Mcf Total Residential MFC per Mcf $.1311 ($.26) $.1285 (I) (I) (I) For customers receiving service in the Non-Residential classifications, the MFC shall equal.2285% times the Natural Gas Supply Charge and Gas Adjustment Clause as calculated for Rider A. The current Non-Residential MFC Charge is: Natural Gas Supply Charge per Mcf Gas Adjustment clause (E-Factor) per Mcf Total Non-Residential MFC per Mcf $.135 ($.3) $.132 (I) (I) (I) (I) Indicates Increase (D) Indicates Decrease Issued: July 31, 213 Effective: August 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Supplement No. 145 to Gas - Pa. P.U.C. No. 9 Fourth Revised Page No. 169 Canceling and Third Revised Page No. 169 Rider H Gas Procurement Charge (GPC) APPLICABILITY Effective June 1, 213, the Gas Procurement Charge will be included in the Natural Gas Supply Charge of Residential, LIRAS, Commercial and Public Authority, SVIS, IVIS, LVIS and LIS rate schedules. The charge is designed to recover the costs of procuring natural gas pursuant to 52 Pa. Code 62.223. The natural gas procurement costs included in the GPC charge will only be updated in a base rate case. The GPC to be included in the Natural Gas Supply Charge shall be $.15 I Mcf and is not reconcilable. Price To Compare Component Natural Gas Supply Charge Purchased Gas Cost Component (Rider A) Merchant Function Charge associated with Natural Gas Supply Charge(Rider G) Gas Procurement Charge (Rider H) Subtotal Natural Gas Supply Charge Gas Adjustment Charge Purchased Gas Cost Component (Rider A) Merchant Function Charge associated with Gas Adjustment Charge (Rider G) Subtotal Gas Adjustment Charge Total Price To Compare Non Residential Residential ( ( per 1 per 1 cubic cubic feet) feet) 58.791 58.791 1.311.135 1.5 1.5 61.152 59.976 (1.181) (1.181) (. 26) (.3) (1.27) (1.184) 59.945 58.792 1 (I) (D) Indicates Decrease (I) Indicates Increase Issued: July 31, 213 (C) Indicates Change Effective: August 1, 213

REDLINED VERSION

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Sixt Supplement No. 1454 to Gas - Pa. P.U.C. No. 9 Sixty-S: l'-f-:i:-f..t:..f Revised Page No. 36 c lf-:i::--r-5-t- and Sixty- t :;Fourth Revised Page No. 36 RESIDENTIAL SERVICE RATE SCHEDULE RESIDENTIAL CLASSIFICATION This classification shall include gas supplied for residential purposes such as a private dwelling, apartment house with a single meter supplying four or less dwelling units, separately metered apartments of a multiple dwelling, accessory buildings to dwellings or apartment houses such as garages, except at residences receiving service under Rate Schedule LIRAS for Low Income Residential Assistance Service and other places of residence where gas is used for residential purposes. Churches and missions (places of worship) shall be entitled to Service under the Residential service rate schedule. AVAILABILITY OF SERVICE Gas Service shall be available at one location, except as otherwise provided, for residential customers. APPLICABILITY Applicable in all areas served under this tariff. MONTHLY RATE Basic Service Charge $12. per Month Distribution Charges 35. 7-6-.1 per 1 cubic feet for the first 5, cubic feet (D) 25.1~3 per 1 cubic feet for all over 5, cubic feet (D) Gas Adjustment Charge (l+.1b1~ per 1 cubic feet Purchased Gas Cost Component (l) ) (Rider A) (.26-±-6-8- per 1 cubic feet Merchant Function Charge (l) l (Rider G) ( J+..?...9..!-=t-G-1- Per 1 cubic feet Total Gas Adjustment Charge ) For a period of 12 months starting when gas supply service hereunder is initiated to a former SATC, MMT or DMT customer by the Company, the rates for service under this rate schedule shall exclude the Gas Adjustment Charge. Former SATC, MMT or DMT customers will be charged during this 12 month period the DEDC factor as defined in Rider A to this tariff and as contained in the Distribution charges set forth above, as amended from time to time. (I) Indicates Increase (D) Indicates Decrease Issued: :;'May 31 ' 2 1 3 Effective:

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling ~;'q,jr' Supplement No. 14S4to Gas - Pa. P.U.C. No. 9 :,Fourth Revised Page No. 36A,:.;-e~~::t--frfltfr---'=THh=rlr- rre:d Revised Page No. 3 6A RESIDENTIAL SERVICE RATE SCHEDULE (cont.) Natural Gas Supply Charge 58-=t-.791~ per 1 cubic feet Purchased Gas Cost Component (I) (Rider A) 1.311Ri3- per 1 cubic feet Merchant Function Charge ~ (Rider G) 1.5 per 1 cubic feet Gas Procurement Charge +G+ (Rider H) 61 --9. L~ 2-6--. per 1 cubic feet Total Natural Gas Supply (I) -±- Charge The Natural Gas Supply Charge shall include a Merchant Function Charge (Rider G) to recover uncollectible costs associated with purchase gas costs of 2.231% and the Gas Procurement Charge (Rider H) to recover costs of procuring natural gas pursuant to 52 Pa. Code 62.223. The above rates shall be subject to surcharges in accordance with the provisions of Rider B - State Tax Adjustment Surcharge and Rider F - LIRA Discount Charge as set forth in this tariff. +G+ RULES AND REGULATIONS The rules and regulations set forth in this tariff shall govern, where applicable, the supply of gas service under this rate schedule. (I) Indicates Increase (C) Indicates Change Issued: yma-y 31, 213 (D) Indicates Decrease

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Supplement No. l4~4 to Gas - Pa. P. U. C. No. 9 Sixty- r-u~ Revised Page No. 37A _: Fifty ~Jinth and Sixty-'i'i! ht~~~<second Revised Page No. 37A MONTHLY RATE After completion of selection of the customers to receive service under this rate schedule, the following percentage discounts shall be applied to the Residential Rate Schedule Basic Service Charge, Distribution Charge, Gas Adjustment Charge and Natural Gas Supply Charge: Program changes associated with the Order at Docket Nos. R-7242 and M-7219 will be implemented the first calendar day of the month following the entry date of the Commission Order if the entry date is at least 5 days prior to the first calendar day of the month. If the entry date is within the 5-day window, program changes will become effective the first day of the subsequent calenda~ month. (C) I I I I I I I I I I I I I I I I I ANNUAL INCOME $ - $999 $1, - $1,999 $2, - $2,999 $3, - $3,999 $4, - $4,999 $5, - $5,999 $6, - $6,999 $7, - $7,999 $8, - $8,999 HOUSEHOLD SIZE 1 2 3 4 5 6 7 1.% 1.%~ 1.%~ 1.%4-(;h 2.%~ 2.%~ 2.%-Uh{) -W-:G% Q.% Q.% Q% Q.% Q% % 1.% 1.%4-(;h 2.%~ 2.%4-(;h 2.%~ 2.%~ 2.%2M -W-:G% Q% Q.% Q% Q% Q% % 2.% 2.%~ 3.%~ 3.%~ 3.%~ 3.%~ 3.%2M -W-:G% Q.% Q% Q% Q% Q% % 3.% 3.%~ 3.%3(h 3.%J\h 4.%J{h 4.%3(h 4.%~ ~ Q.% Q% Q% Q% Q% % 4.% 4.%3(h 4.%4-{h 4.%4-(h 4.%4-{h 4.%4-{h 4.%4-M ~ Q.% Q.% Q% Q% Q% % 3.% 4.%3(h 4.%3(h 4.%4-(h 4.%4-{h 4.%4(}.. 4.%4-M ~ Q.% Q% Q.% Q% Q% % 2.% 3.%3(h 4.%3(h 4.%J\h 4.%4-{h 4.%4-{h 4.%4-M ~ Q.% Q% Q.% Q% Q% % 2.% 3.%3(h 4.%3(h 4.%J\h 4.%3(h 4.%3(h 4.%~ ~ Q.% Q% Q.% Q% Q% % 1.% 2.%4-(;h 3.%3(h 3.%J\h 4.%J{h 4.%3(h 4.%~ -W-:G% Q.% Q.% Q.% Q% Q% % ----- --- --- -.. - -to:o% t.%4(h. 3.o/o~ 3.%:- -3.%-@@:---- 3:-%3G-:-- ae~o%j@m $9, - $9,999 ~ Q.% - Q.% (}% Q% Q% % 1.% 1.%~ 1.%~ 3.%~ 3.%~ 3.%3(h $1, - 3.%~ $1,999 ~ Q.% Q% Q-% Q.% Q% % 1.% 1.%4-(;h 1.%~ 2.%~ 3.%~ 3.%~ $11, - $11,999 3.%2M ~ Q.% Q% Q-% Q.% Q% % 1.% 1.%~ 1.%~ 1.%~ 2.%~ 2.%~ $12, - $12,999 2.%2M ~ Q.% Q% Q.% Q.% Q% % 1.% 1.%~ 1.%~ 1.%~ 2.%~ 2.%~ $13, - $13,999 2.%-1-(;h.Q ~ Q.% Q% Q.% Q.% Q.% % 1.% 1.%~ 1.%~ 1.%~ 1.%~ 2.%4(}.. $14, - $14,999 2.%4Q.;.Q ~ Q.% Q% Q.% Q% Q% % $15, - 1.% 1.%~ 1.%~ 1Q~%~ 1. %-1-G-:- 1.%4(}.. $15,999 1.%4Q.;.Q 4G:-Q.% Q.% Q.% Q.% Q% Q% % $16, - 1.% 1.%~ 1.%~ 1.%~ 1.%-1-G-:- 1.%4(}.. $16,999 1.%4Q.;.Q 4G:-Q.% Q.% Q.% Q.% Q% Q.% % $17, - 1.% 1.%~ 1.%4(}.. 1.%~ 1.%-1-G-:- 1.%4(}.. $17,999 1.%4Q.;.Q 4G:-Q.% Q.% Q% (}% Q% Q.% %.%(}.. 1.%~ $18, - 1. %-1-G-:- 1.%-Uh- 1.%-1-G-:- 1.%4(}.. $18,999 1.%4Q.;.Q Q% Q.% Q% Q.% Q% Q.% % $19, - $19,999.%(}.. 1.%~ 1.%~ 1.%-Uh- 1.%-1-G-:- 1.%4(}.. 1.%4Q.;.Q

$2, - $2,999 $21, - $21,999 $22, - $22,999 $23, - $23,999 $24,- $24,999 $25, - $25,999 $26, - $26,999 $27, - $27,999 $28, - $28,999 $29, - $29,999 % Q-% % % Q% % -%.%-:- 1. o/o.:f.g:. 1. o/o.:f.g:. 1. O%.:f.G:. 1.%~ 1.%4:- 1.%~ % Q-% % % Q% Q.% -%.%-:- 1.%~ 1. o/o.:f.g:. 1. %.:f.g:. 1.%~ 1.%4:- 1. /o~ % % % -% Q% % -%.%-:- 1. %.:f.g:. 1. o/o.:f.g:. 1.%4-:- 1.%~ 1. O%.:f.G:. 1.o/o~ % Q-% -% % Q% % -%.%-:- 1. %.:f.g:. 1. Oo/o.:f.G:. 1. %-1--:- 1.%~ 1. O%.:f.G:. 1.o/o~ % Q.% % -% Q% _Q% -%.%-:- O.O%M 1. /o.:f.g:- 1. O%.:f.G:. 1.%-Uh 1. o/o.:f.g:. 1.o/o~ Q-% -% % % Q% % -%.%-:- O.O%M 1. /o.:f.g:. 1.%4-:- 1.%-Uh 1. o/o.:f.g:. 1.%~ % % % % Q% % -%.%-:- O.O%M 1. Oo/o.:f.G:. 1 O.Oo/o.:f.G:. 1.%-Uh 1. Oo/o.:f.G:. 1.%~ G% % G% % Q% % -%.%-:- O.O%M 1. Oo/o.:f.G:. 1.%-1--:- 1.%-Uh 1. Oo/o.:f.G:. 1.o/o~ % % Q% % Q% % %.%-:- O.O%M 1. O%.:f.G:. 1.%-1--:- 1.%-Uh 1.%.:f.G:. 1. /o~ G% % G% -% Q.% % %.%-:- O.O%M 1. /o.:f.g:- 1.%4-:- 1.%-Uh 1. o/o.:f.g:. 1. /o+o-:-g % % % -% Q.% % % (C) Indicates Change Issued : \1 _l_y_ May 31, 2 13

Q.% NATIONAL FUEL GAS Supplement No. 14~4 to DISTRIBUTION CORPORATION Gas - Pa. P. U. C. No. 9 : r t.),':_r:forty Ninth Revised Page No. 37B ::anceling Forty-.~-~~-~:~:.Y~f:J~... t:...l:~.f-i-h-ft and Forty-!:~Li.. ~ _t._~t!bighth Revised Page No. 37B MONTHLY RATE (con' t) (C-). I I I I I I I I I I I I I I I I I ANNUAL INCOME HOUSEHOLD SIZE. 8 9 1 11 12 13 14 I I $ - $999 $1,, - $1,999 2.% 2.%4{h 1.%4{h 1.%-+(h 1.%4{h 1' %-1-G-:- 1.%4-Q.;.Q - ~ Q.% Q.% % Q.% Q.% % 2.% 2.%2-fh 3.%~ 3.%~ 3.%~ 3.%~ 3.%~ ~ ~ Q.% % Q.% G-%... _.... ~--%- $2, - 3.% 3. /o2-fh 3.%~ 3.%~ 3.%~ 3.%~ 3.%~ $2,999 ~ Q.% Q.% % Q.% Q.% % $3, - 4.% 4. /oj{h 4.%W:- 3.%d{h 3.%J{h 3.%J{h 3.%~ $3,999 ~ Q.% Q.% % % Q.% % $4, - 4.% 4.o/o4(h 4.%4-(h 4.%4-Q.;. 4.%4-Q;- 4.%4-(h $4,999 4.%4-(hQ 4(hQ.% Q.% Q.% % Q.% Q.% % $5, - 4.% 4.%4-(h 4.%4-(h 4.%4-Q.;. 4.%4-Q;- 4.%4-(h 4.%4-(hQ $5,999 4(hQ.% Q.% Q.% % % Q.% % 4.% 4. /o4(h 4.%4-(h 4.%4-Q;- 4.%4-Q;- 4.%4-(h 4.%4-(hQ $6, - $6,999 4(hQ.% Q.% Q.% % % Q.% %: $7, - 4.% 4.o/od{h 4.%~ 4.%d{h 4.%dCh 4.%~ 4.%~ $7,999 ~ Q.% Q.% % % Q.% % $8, - 4.% 4. /oj{h 4.%~ 4.%d{h 4.%d{h 4.%~ 4.%~ $8,999 ~ Q.% Q.% % % Q.% % 3.% 4. /oj{h 4.%~ 4.%d{h 4.%J{h 4.%~ $9, - 4.%~ $9,999 ~ Q.% Q.% % % % % $1, - 3.% 3.%J{h 3.%~ 3.%d{h 3.%~ 3.%W:- 3.%~ $1,999 ~ Q.% % % % Q.% % $11, - 3.% 3. /o2-fh 3.%~ 3.%~ 3.%2-fh 3.%~ 3.%~ $11,999 ~ Q.% Q.% % % Q.% % 2,% 3.%~ 3.%~ 3.%~ 3.%~ 3. %2-G-:- $12, - 3.%~ $12,999 ~ Q.% Q.% % Q.% Q.% % - ----- 2.-d% 2.o/o-Uh- 2.'%~ 2.%~- '2~%~- '2.%$.' 2n:ooro~ $13, - $13,999 ~ Q.% Q.% % % Q.% % 2.% 2.%4fh 2.%4{h 2.%4{h 2.%4{h 2.%4{h 2.%~ $14, - $14,999 W:-Q.% Q.% Q.% % G% % % $15, - 1.% 1.o/o~ 1.%4{h 1.%4{h 1.%4{h 1.%4{h $15,999 1.%-1-{hQ ~ Q.% Q.% % Q.% Q.% % $16, - 1.% 1.%~ 1.%4{h 1.%~ 1.%4{h 1.%4{h $16,999 1.%-1-{hQ W:-Q.% Q.% Q.% % G% G% % 1.% 1.%~ 1.%4{h 1.%~ 1.%4{h 1.%4{h $17, - $17,999 1.%-1-{hQ W:-Q.% Q.% Q.% % G% G% % $18, - 1.% 1.%~ 1.%4{h 1.%~ 1.%4{h 1.%4fh $18,999 1.%-1-{hQ W:-Q.% Q.% G% % G% % % 1.% 1.%4fh $19, - 1.%-W-:. 1.%~ 1.%4{h 1.%4:- $19,999 1.%W:-Q ~ Q.% Q.% % G% % % 1.% 1.%~ 1.%4-Q-;. 1. %-1-G-:- 1.%4-Q-;. 1.%4fh $2, - $2,999 1.%W:-Q ~ Q.% G% % % G% % $21, - 1.% 1.%-1-f).;. 1.%4-Q-;. 1.%~ 1.%4-Q-;. 1.%4fh $21,999 1.%W:-Q ~ Q.% Q.% % G% G% % $22, - 1.% 1.%-1-f).;. 1.%4-Q-;. 1.%~ 1.%4fh 1.%4-(h $22,999 1.%W:-Q ~ Q.% Q.% % G% Q.% % $23, - $23,999 1.% 1.%-1-f).;. 1.%~ 1. %-1-G-:- 1.%4-(h 1.%4-(h 1.%W:-Q

~ % Q.% Q.% % Q.% 9k $24, - 1.% 1.%.:1-fh $24,999 1.%.:1-fh 1.%4G:- 1.%4{h 1.%.:1-fh 1. /o..:t-fm) ~ % Q.% Q.% % Q.% 9k $25, - $25,999 ~ % Q.% Q.% % Q.% 9k 1.% 1.%.:1-fh 1.%4fh 1.%-1-<* 1.%4{h 1.%4fh 1. /o..:t-fm} $26, - $26,999 1.% 1.%4-Q.;. 1.%4fh 1.%-1-<* 1.%4().;. 1.%4fh 1. /o-uho 4M% % Q% Q.% % Q.% 9k $27, - $27,999-4-M-% % Q.% Q.% - - -. Q.% Q.% % 1.% 1.%.:1-fh 1.%4fh 1.%-1-<* 1.%4{h 1.%4fh 1.o/o~ $28, - $28,999 1.% 1.%.:1-fh 1.%4fh 1.%-1-<* 1.%4().;. 1.%4().;. 1.%4-M -W-:Q% G% Q.% Q.% % Q.% % $29, - $29,999 -W-:Q% Q.% Q.% Q.% Q.% % 1.% 1.%.:1-fh G% 1.%4fh 1.%-1-<* 1.%4().;. 1.%4fh 1.o/o~ (C) Indicates Change Effective: (<:1'}U3i::Jtli.::re 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Supplement No. 1454 to Gas - Pa. P.U.C. No. 9 Sixty- ' Fourth Revised Page No. 41 :SiKtieth and Sixty- L~ Revised Page No. 41 COMMERCIAL AND PUBLIC AUTHORITY SERVICE RATE SCHEDULE (cont.) APPLICABILITY Applicable in all areas served under this tariff. MONTHLY RATE For "Small" Commercial/Public Authority Customers using not more than 25, cubic feet per year: Basic Service Charge $19.89 per Month Distribution Charges 29.29-.-+8. per 1 cubic feet for the first 5, cubic feet 26.32~ per 1 cubic feet for all over 5, cubic feet (D) (D) Gas Adjustment Charge ( l +.. 1. 8 J. - -3-3 per 1 cubic feet ) (.3-H ) per 1 cubic feet (~_+.. ~..?.. Ll.- - -8- per 1 cubic feet ) Purchased Gas Cost Component (Rider A) Merchant Function Charge (Rider G) Total Gas Adjustment Charge For a period of 12 months starting when gas supply service hereunder is initiated to a former SATC, MMT or DMT customer by the Company, the rates for service under this rate schedule shall exclude the Gas Adjustment Charge. Former SATC, MMT or DMT customers will be charged during this 12 month period the DEDC factor as defined in Rider A to this tariff and as contained in the Distribution charges set forth above, as amended from time to time. Natural Gas Supply Charge 58+. 79J.~ per 1 cubic feet Purchased Gas Cost Component I (Rider A).135± per 1 cubic feet Merchant Function Charge (I) (Rider G) 1.5 per 1 cubic feet Gas Procurement Charge (Rider H) +G+ 59-&.976. -G-4 per 1 cubic feet Total Natural Gas Supply Charge (I) The Natural Gas Supply Charge shall include a Merchant Function Charge (Rider G) to recover uncollectible costs associated with purchase gas costs of.2285% and the Gas Procurement Charge (Rider H) to recover costs of procuring natural gas pursuant to 52 Pa. Code 62.223. +G+ The above rates shall be subject to surcharges in accordance with the provisions of Rider B - State Tax Adjustment Surcharge as set forth in this tariff. (D) Indicates Decrease (I) Indicates Increase Issued: l :/Ma-y 31, 2 13 (C) Indicates Change

NATIONAL FUEL GAS Supplement No. 14~4 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 ',Eighteenth Revised Page No. 41A Canceling ::>ix!>>~'n ;,fourteenth and,;;, ''''(;ntu3eventeenth Revised Page No. 41A COMMERCIAL AND PUBLIC AUTHORITY SERVICE RATE SCHEDULE (Cont'd) For "Small" Commercial/Public Authority Customers using greater than 25, cubic feet but not more than 1,, cubic feet per year: Basic Service Charge $27.53 per Month Distribution Charges 21~.8B3 per 1 cubic feet for the first 2, cubic feet 2.43-+±-9 per 1 cubic feet for all over 2, cubic feet (D) (D) Gas Adjustment Charge (1+.181~ per 1 cubic feet ) ~3+ ) per 1 cubic feet q_+. J~~_. - -9. ) per 1 cubic feet Purchased Gas Cost Component (Rider A) Merchant Function Charge (Rider G) Total Gas Adjustment Charge l I For a period of 12 months starting when gas supply service hereunder is initiated to a former SATC, MMT or DMT customer by the Company, the rates for service under this rate schedule shall exclude the Gas Adjustment Charge. Former SATC, MMT or DMT customers will be charged during this 12 month period the DEDC factor as defined in Rider A to this tariff and as contained in the Distribution charges set forth above, as amended from time to time. Natural Gas Supply Charge 58+.791~ per 1 cubic feet Purchased Gas Cost Component (Rider A). 13~)± per 1 cubic feet Merchant Function Charge (l) (Rider G) 1.5 per 1 cubic feet Gas Procurement Charge (Rider H) +G+ 5 9B. 97 6. -G-4- per 1 cubic feet Total Natural Gas Supply Charge (I) The Natural Gas Supply Charge shall include a Merchant Function Charge (Rider G) to recover uncollectible costs associated with purchase gas costs of.2285% and the Gas Procurement Charge (Rider H) to recover costs of procuring natural gas pursuant to 52 Pa. Code 62.223. +G+ The above rates shall be subject to surcharges in accordance with the provisions of Rider B - State Tax Adjustment Surcharge as set forth in this tariff. (D) Indicates Decrease (I) Indicates Increase Issued: /Ma-y 31, 213 (C) Indicates Change

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling... :)/...,. -~-;.-.. :-. (.. Supplement No. 1454 to Gas - Pa. P.U.C. No. 9 Sixty- :,fourth Revised Page No. 42 cisi1ctieth and Sixty-i:c::... ;,~ Revised Page No. 42 Commercial and Public Authority Service Rate Schedule (Cont'd) For "Large" Commercial/Public Authority Customers: Basic Service Charge $121.1 per Month Distribution Charges 18.67-3-4-+ per 1 cubic 1 6+. 87-±- -5 per 1 cubic 14.69-+1 per 1 cubic feet for feet for feet for the first 3, cubic feet the next 1,7, cubic feet all over 2,, cubic feet (D) (D) (D) Gas Adjustment Charge (.l:.+..:.l?..j.. -3-3 per 1 cubic feet Purchased Gas Cost Component ) (Rider A) (.3H ) per 1 cubic feet Merchant Function Charge ll) (Rider G) (.l-+. 1f3 4 -.G. per 1 cubic feet Total Gas Adjustment Charge (I) ) For a period of 12 months starting when gas supply service hereunder is initiated to a former SATC, MMT or DMT customer by the Company, the rates for service under this rate schedule shall exclude the Gas Adjustment Charge. Former SATC, MMT or DMT customers will be charged during this 12 month period the DEDC factor as defined in Rider A to this tariff and as contained in the Distribution charges set forth above, as amended from time to time. Natural Gas Supply Charge 58+. 79J.-3B per 1 cubic feet Purchased Gas Cost Component (Rider A).13::5± per 1 cubic feet Merchant Function Charge (Rider G) 1.5 per 1 cubic feet Gas Procurement Charge (Rider H) 59-&.976. -G-4 per 1 cubic feet Total Natural Gas Supply Charge The Natural Gas Supply Charge shall include a Merchant Function Charge (Rider G) to recover uncollectible costs associated with purchase gas costs of.2285% and the Gas Procurement Charge (Rider H) to recover costs of procuring natural gas pursuant to 52 Pa. Code 62.223. ill (I) +G+ The above rates shall be subject to surcharges in accordance with the provisions of Rider B - State Tax Adjustment Surcharge as set forth in this tariff. APPLICATION PERIOD The Application Period shall be the twelve months beginning March 1 of each year. RULES AND REGULATIONS The Rules and Regulations set forth in this tariff shall govern, where applicable, the supply of gas service under this rate schedule. (I) Indicates Increase (D) Indicates Decrease (C) Indicates Change

I Issued:'.T<:tLyMa-y 31, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Supplement No. 145~ to Gas - Pa. P.U.C. No. 9 hf-i-f.:t-ft Revised Page No. 48 h~ Revised Page No. 48 1. The purchased gas demand costs applicable to the Residential, Commercial and Public Authority, Small Volume Industrial, Intermediate Volume Industrial, Large Volume Industrial and Large Industrial classes, the "Den, shall be obtained from Rider "An - Section 137(f) Purchased Gas Costs. 2. The number 12 shall be multiplied by the sum of (a) the volume of gas (expressed in Mcf) purchased from the Company by all Residential, Commercial and Public Authority, Small Volume Industrial, Intermediate Volume Industrial, Large Volume Industrial and La~ge Industrial customers, during the Company peak Sales Month and (b) the volume of service (expressed in Mcf) to all customers under the "Monthly Volumen provisions of Rate Schedule SB, during the Company Peak Sales Month. (a) (b) "Company Peak Sales Monthn is defined as the calendar month within which the Company experienced the System-Wide Peak Sales Day, such month being December, January or February preceding the Section 137(f) Application Period for which the determination of the rate per Gas BDU is being made. "System-Wide Peak Sales Dayn is defined as the day of maximum gas purchased by the Company, including all volumes of gas purchased from the Company throughout its entire system in the states of Pennsylvania and New York. 3. The amount determined in Item 1 above shall be divided by the amount determined in Item 2 above to determine the amount included in the rate for recovery of purchased gas costs. 4. The rate per Gas BDU shall be the amount for purchased gas demand costs (Item 3). The current rate per Gas BDU is as follows: Purchased Gas Demand Cost $-±-.8319-9-4-4+/BDU (D) Each time there is a change in the provision for recovery of purchased gas costs pursuant to Rider "An of this tariff, a recomputation shall be made, under Items 1, 2 and 3, above, of the component to be included in the rate for purchased gas demand costs and the rate per Gas BDU shall be changed accordingly. (D) Indicates Decrease Issued: U\pril 3, 213 Effective: ;~ May 1 ' 2 1 3

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Supplement No. 1453 to Gas - Pa. P.U.C. No. 9 Sixty- >,, /;t;c) :1:-r-s-t:- Revised Page No. 5.Fifty Ninth Revised Page No. 5 B. COMMODITY CHARGES FOR SALES AND FOR TRANSPORTATION SERVICE 1. Commodity Charge for Sales Service The monthly Commodity Charge for Sales Service shall be the product of multiplying the rate per Mcf, determined as provided below, by the volume of gas sold to the Customer by the Company during the applicable billing cycle. $_4._3. 7 The rate per Mcf shall be determined as follows and shall be 6~ per Mcf, subject to revision as provided below: (I) The current components of the rate are as follows: Purchased Gas Commodity Costs, set forth in Rider "A" Non Gas Costs a. Determination of Rate per Mcf The rate per Mcf shall be the sum of: $t.13.?:3::5~/mcf - --- $.5566/Mcf (I) 1. The net amount per Mcf for recovery of the commodity component of purchased gas costs and for recovery or refund of "E" factor amounts, the "PGCC", as determined in Rider "A"- Section 137(f) Purchased Gas Costs of this tariff; plus 2. The amount of $.5566 per Mcf for recovery of non-gas costs. Each time there is a change in the provision for recovery of purchased gas costs pursuant to Rider "A" of this tariff, a recomputation shall be made of the commodity component of purchased gas costs (Item 1, above) and the rate per Mcf shall be changed accordingly. The component included in the rate for recovery of non-gas costs shall remain constant until changed in acco~dance with a procedure, other than a proceeding pursuant to Section 137(f) of the Public Utility Code, 66 Pa.C.S. Section 137(f). 2. Commodity Charge for Transportation Service The monthly Commodity Charge for Transportation Service shall be the product of multiplying the rate per Mcf, determined as provided below, by the volume of gas transported by the Company to the Customer's load balancing facilities. The rate per Mcf for transportation of gas under this rate schedule shall be $.81~66 per Mcf, which includes $.5566 for recovery of non-gas costs and $.2~+ for recovery of purchased gas. (D) Indicates Decrease (I) Indicates Increase Issued: -"... 5\April 3, 213 Effective: '\tlj t.ma-y 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Supplement No. 1454 to Gas - Pa. P.U.C. No. 9 ci~ Revised Page No. 53 '<, : > Si:H:tieth Revised Page No. 53 SVIS Small Volume Industrial Service Rate Schedule (Cont'd) MONTHLY RATE Basic Service Charge $65.6 per Month Distribution Charges 23.7~7 per 1 cubic feet (D) Gas Adjustment Charge (.~.-f-. J.~.. ~. -3.3. per 1 cubic feet Purchased Gas Cost Component JJ...!... ) (Rider A) ~Q}H ) per 1 cubic feet Merchant Function Charge...LT./... (_1_-f-. J. B 4 -& -G. per 1 cubic feet (Rider G) Total Gas Adjustment Charge ill ) For a period of 12 months starting when gas supply service hereunder is initiated to a former SATC, MMT or DMT customer by the Company, the rates for service under this rate schedule shall exclude the Gas Adjustment Charge. Former SATC, MMT or DMT customers will be charged during this 12 month period the DEDC factor as defined in Rider A to this tariff and as contained in the Distribution charges set forth above, as amended from time to time. Natural Gas Supply Charge 58-f-.791~ per 1 cubic feet Purchased Gas Cost Component (Rider A).135± per 1 cubic feet Merchant Function Charge (Rider G) 1.5 per 1 cubic feet Gas Procurement Charge (Rider H) 59-8-. 97 6W4 per 1 cubic feet Total Natural Gas Suppiy Charge The Natural Gas Supply Charge shall include a Merchant Function Charge (Rider G) to recover uncollectible costs associated with purchase gas costs of.2285% and the Gas Procurement Charge (Rider H) to recover costs of procuring natural gas pursuant to 52 Pa. Code 62.223. T.L.. LT.!.. (I) +G+ The above rates shall be subject to surcharges in accordance with the provisions of Rider B - State Tax Adjustment Surcharge. APPLICATION PERIOD The Application Period shall be the twelve months beginning March 1 of each year. RULES AND REGULATIONS The Rules and Regulations set forth in this tariff shall govern, where applicable, the supply of gas service under this rate schedule. (D) Indicates Decrease (I) Indicates Increase (C) Indicates Change

I Issued :... : ;/Ma-y 3 1, 2 1 3 E f f e c t i v e : i<.. J1,.~~. J-Hfte 1, 2 1 3

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Supplement No. 1454 to Gas - Pa. P.U.C. No. 9,jf!±-r-s.-:t- Revised Page No. 55 Si/~Y:FirstSixtieth Revised Page No. 55 IVIS INTERMEDIATE VOLUME INDUSTRIAL SERVICE RATE SCHEDULE MONTHLY RATE (Cont'd) Basic Service Charge $21.91 per Month Distribution Charges 1 7-8-. 8 2 6-±-G-6 per 1 cubic feet for the first 1, cubic feet 1 34. '7 4 :;.e-a per 1 cubic feet for the next 1,9, cubic feet 1.551-8--3-±- per 1 cubic feet for all over 2,, cubic feet (D) (D) (D) Gas Adjustment Charge ( 1.+. 1 b _l. -3-3 per 1 cubic feet Purchased Gas Cost Component J..I )_ ) (Rider A) (.3H ) per 1 cubic feet Merchant Function Charge (I) U:. +. 1 s 4. - -8. per 1 cubic feet (Rider G) Total Gas Adjustment Charge ll) ) For a period of 12 months starting when gas supply service hereunder is initiated to a former SATC, MMT or DMT customer by the Company, the rates for service under this rate schedule shall exclude the Gas Adjustment Charge. Former SATC, MMT or DMT customers will be charged during this 12 month period the DEDC factor as defined in Rider A to this tariff and as contained in the Distribution charges set forth above, as amended from time to time. Natural Gas Supply Charge 5U+.79l~ per 1 cubic feet Purchased Gas Cost Component J..l)_ (Rider A).135-l per 1 cubic feet Merchant Function Charge (I) (Rider G) 1.5 per 1 cubic feet Gas Procurement Charge (Rider H) -f-g-1-5 9-8-. 97 6. -94- per 1 cubic feet Total Natural Gas Supply Charge (I) The Natural Gas Supply Charge shall include a Merchant Function Charge (Rider G) to recover uncollectible costs associated with purchase gas costs of.2285% and the Gas Procurement Charge (Rider H) to recover costs of procuring natural gas pursuant to 52 Pa. Code 62.223. -f-g-1- The above rates shall be subject to surcharges in accordance with the provisions of Rider B - State Tax Adjustment Surcharge as set forth in this tariff. APPLICATION PERIOD year. The Application Period shall be the twelve months beginning March 1 of each RULES AND REGULAT1NS The rules and regulations set forth in this tariff shall govern, where applicable, the supply of gas service under this rate schedule.

(I) Indicates Increase (D) Indicates Decrease Issued:~_: _-;_:l;.;ima-y 31, 213 (C) Indicates Change Effective: (\:r:otjtl-r.e 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Supplement No. 145~ to Gas - Pa. P.U.C. No. 9 h~ Revised Page No. 61 : ~ Revised Page No. 61 Industrial and Large Industrial customers, during the Company peak Sales Month defined in Rate Schedule CPA-LBS and (b) the volumes of service (expressed in Mcf) to all customers under the "Monthly Volume" provisions of Rate Schedule SB, during the Company Peak Sales Month defined in Rate Schedule CPA-LBS. 3. The amount determined in Item 1 above shall be divided by the amount determined in Item 2 above to determine the amount included in the rate for recovery of purchased gas costs. 4. The rate per Gas BDU shall be the amount for purchased gas demand costs (Item 3). The current rate per Gas BDU is as follows: Purchased Gas Demand Cost (D) Each time there is a change in the provision for recovery of purchased gas costs pursuant to Rider "A" of this tariff, a recomputation shall be made, under Items 1, 2 and 3, above, of the component to be included in the rate for purchased gas demand costs and the rate per Gas BDU shall be changed accordingly. b. Determination of Customer's Gas BDUs The Customer's Gas BDUs shall be determined as follows: The actual volumes of gas purchased by the Customer from the Company and used by the Customer in the separately-metered load balancing facilities during such Customer's Peak billing Cycle, as defined hereinafter, shall be multiplied by a fraction. The numerator shall be the number 3. The denominator shall be the number of days of service for which such Customer was billed in such Customer's Peak Billing Cycle. The Customer's Peak Billing Cycle shall be the single billing cycle of maximum delivery to the Customer's separately-metered load balancing facilities that ended during one of the months of December, January, February and March during the period beginning with the most recently-completed billing cycle ended in December and ending with the current billing cycle. If the customer used no gas under this rate schedule during the most recently concluded billing cycles ended in December, January, February or March, then the level of Gas BDUs applicable to Customer shall be zero (). (D) Indicates Decrease Issued: U\pril 3, 213 Effective: ~Ma-y 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION 2. Margin Demand Charge Fifty- Canceling Fifty-,:>~\-,ir:......-...-.,... > Supplement No. 14 >.; to Gas - Pa. P.U.C. No. 9 theighth Revised Page No. 62... ~ Revised Page No. 62 a. The rate per Margin BDU shall be $.5122 per Margin BDU. b. Determination of Customer's Margin BDUs The Customer's Margin BDUs shall be determined as follows: The actual deliveries of gas to the Customer by Company, including not only volumes of gas purchased by the Customer from the Company and used by the Customer in the separately-metered load balancing facilities but also volumes of Customerowned gas transported to the Customer's load balancing facilities through the Company's facilities, during such Customer's Peak billing Cycle, as defined hereinafter, shall be multiplied by a fraction. The numerator shall be ;the number 3. The denominator shall be the number of days of service for which such Customer was billed in such Customer's Peak Billing Cycle. The Customer's Peak Billing Cycle shall be the single billing cycle of maximum delivery to the Customer's separately-metered load balancing facilities that ended during one of the months of December, January, February and March during the period beginning with the most recently-completed billing cycle ended in December and ending with the current billing cycle. If the customer used no gas under this rate schedule during the most recently concluded billing cycles ended in December, January, February or March, then the level of Margin BDUs applicable to Customer shall be zero (). B. COMMODITY CHARGES FOR SALES AND FOR TRANSPORTATION SERVICE 1. Commodity Charge for Sales Service The monthly Commodity Charge for Sales Service shall be the product of multiplying the rate per Mcf, determined as provided below, by the volume of gas sold to the Customer by the Company during the applicable billing cycle. The rate per Mcf shall be determined as follows and shall be $_4_.;._ ). ::._._~ per Mcf, subject to revision as provided below: (I) The current components of the rate are as follows: Purchased Gas Commodity Costs, set forth in Rider "A" Non Gas Costs $_4.;. _?}_?.. 2~ I Me f $.388/Mcf (I) a. Determination of Rate 2er Mcf The rate per Mcf shall be the sum of: 1. The net amount per Mcf for recovery of the commodity component of purchased gas costs and for recovery or refund of "E" factor amounts, the "PGCC", as determined in Rider "A"- Section 137(f) Purchased Gas Costs of this tariff; plus (D) Indicates Decrease Issued: )l'rpril 3, 213 Effective: 'tm-a--y 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Supplement No. 1: :;-3-2- to Gas - Pa. P.U.C. No. 9 r,eighteenth Revised Page No. 63 ': hseventeenth... Revised Page No. 63 2. The amount of $.388 per Mcf for recovery of non-gas costs. Each time there is a change in the provision for recovery of purchased gas costs pursuant to Rider "A" of this tariff, a recomputation shall be made of the commodity component of purchased gas costs (Item 1, above) and the rate per Mcf shall be changed accordingly. The component included in the rate for recovery of non-gas costs shall remain constant until changed in accordance with a procedure, other than a proceeding pursuant to Section 137(f) of the Publi~ Utility Code, 66 Pa.C.S. Section 137(f). 2. Commodity Charge for Transportation Service The monthly Commodity Charge for Transportation Service shall be the product of multiplying the rate per Mcf, determined as provided below, by the volume of gas transported by the Company to the Customer's load balancing facilities. The rate per Mcf for transportation of gas under this rate schedule shall be $. 6_1_..8 per Mcf, which includes $. 388 for recovery of non-gas costs (b_)-±-) and $.2~~ for recovery of purchased gas. (Q-I-) V. SURCHARGE The Demand Charges and the Commodity Charge for Sales Service and the Commodity Charge for Transportation Service shall be subject to surcharges in accordance with provisions of Rider B - State Tax Adjustment Surcharge. VI. AMOUNTS TO BE INCLUDED IN OVER/UNDERCOLLECTION OF GAS COSTS Purchased gas cost revenues billed under this rate schedule shall be included as revenues for recovery of gas costs for purposes of computing Factor "E" of Company's 137(f) rate in accordance with procedures set 'forth in Rider "A"- Section 137(f) Purchased Gas Costs. VII. SPECIAL PROVISIONS Monthly metered Special Provisions A through J contained in the Company's Rate Schedule for Transportation Service shall apply to transportation service under this rate schedule. VIII. RULES AND REGULATIONS The rules and regulations set forth in this tariff shall govern, where applicable, the supply of gas service under this rate schedule.. LP..1... Indicates Decrea5:e (I) Indicates Increase Issued: July 31, 21?~ Effective: August 1, 2lj~

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Supplement No. 1454 to Gas - Pa. P.U.C. No. 9 rc!. :i:-f..s.-t.. Revised Page No. 65.. _ rsixtieth Revised Page No. 65 LVIS Large Volume Industrial Service (Cont'd) C. An Industrial Customer, for which the Company estimates that the total volumes of gas purchased from the Company or transported by the Company during the next succeeding twelve months will be not less than 5, Mcf, if the Industrial Customer has used total volumes of gas in at least one billing month of not less than 4,167 Mcf, even if the Customer disagrees with the Company's estimate. D. An Industrial Customer for which the Company estimates that total volumes of gas to be used by the customer during the next succeeding twelve months will not be less than 5, Mcf of gas per year whether the gas is purchased by the Industrial Customer from the Company, delivered by the Company to the Industrial Customer, or obtained by the customer from another source. An Industrial Customer that meets the above criteria under this rate schedule at the beginning of an Application Period is required to continue to be subject to this rate schedule during all months of such Application Period. An Industrial Customer that meets the above criteria under this rate schedule during an Application Period is required to continue to be subject to this rate schedule during all or remaining months of such Application Period. MONTHLY RATE Basic Service Charge $89. per Month Distribution Charges 13.346~ per 1 cubic feet for the first 1, cubic feet (D) 11.52-8-8-8 per 1 cubic feet for the next 1, ~, cubic feet (D) 9.44ti per 1 cubic feet for the next 18,, cubic feet (D) 8.6M8 per 1 cubic feet for all over 2,, cubic feet (D) 1 Gas Adjustment Charge (1,-+. J..?J.~ ) per 1 cubic feet Purchased Gas Cost Component (Rider A) ~Q:}H ) per 1 cubic feet Merchant Function Charge (Rider G) (1-+. Jd4- - -G. ) Per 1 cubic feet Total Gas Adjustment Charge I I ( 1) For a period of 12 months starting when gas supply service hereunder is initiated to a former SATC, MMT or DMT customer by the Company, the rates for service under this rate schedule shall exclude the Gas Adjustment Charge. Former SATC, MMT or DMT customers will be charged during this 12 month period the DEDC factor as defined in Rider A to this tariff and as contained in the Distribution charges set forth above, as amended from time to time. (D) Indicates Decrease.LI.t.. Indicate:::: Increa~:e Issued: y'mfry 31 ' 213 Effective:........:... Jtine 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION ~'Y:I~:I!.~u~u~~}::tNineteenth Supplement No. 14?.4 to Gas - Pa. P.U.C. No. 9 Revised Page No. 66 Canceling SeventeenthFiftcenth and NineteenthEighteenth Revised Page No. 66 LVIS Large Volume Industrial Service (Cont'd) Natural Gas Supply Charge 58-f-.791-3--2--3- per 1 cubic feet Purchased Gas Cost Component -- (Rider A).135-l- per 1 cubic feet Merchant Function Charge (Rider G) 1.5 per 1 cubic feet Gas Procurement Charge (Rider H) 59-&.976..-G-4 per 1 cubic feet Total Natural Gas Supply Charge The Natural Gas Supply Charge shall include a Merchant Function Charge (Rider G) to recover uncollectible costs associated with purchase gas costs of.2285% and the Gas Procurement Charge (Rider H) to recover costs of procuring natural gas pursuant to 52 Pa. Code 62.223... L~J...ilJ fg+ (I) fg+ The above rates shall be subject to surcharges in accordance with provisions of Rider B - State Tax Adjustment Surcharge. RULES AND REGULATIONS The Rules and Regulations set forth in this tariff shall govern, where applicable, the supply of gas service under this rate schedule. APPLICABLE PERIOD year. The Application Period shall be the twelve months beginning March 1 of each (D) Indicates Decrease (I) Indicates Increase Issued:~May 31, 213 (C) Indicates Change Effective: August~ 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Supplement No. 14S~ to Gas - Pa. P.U.C. No. 9 r,f:i:--#fi- Revised Page No. 7 2 ' ~ Revised Page No. 72 Commercial and Public Authority, Small Volume Industrial, Intermediate Volume Industrial, Large Volume Industrial and Large Industrial customers, during the Company Peak Sales Month defined in Rate Schedule CPA-LBS and (b) the volume of service (expressed in Mcf) to all customers under the "Monthly Volume" provisions of Rate Schedule SB, during the Company Peak Sales Month defined in Rate Schedule CPA-LBS. 3. The amount determined in Item 1 above shall be divided by the amount determined in Item 2 above to determine the amount included in the rate for recovery of purchased gas costs. 4. The rate per Gas BDU shall be the amount for purchased gas demand costs (Item 3). The current rate per Gas BDU is as follows: Purchased Gas Demand Cost $.g..b319-8-4-6-+/bdu (D) Each time there is a change in the provision for recovery of purchased gas costs pursuant to Rider "A" of this tariff, a recomputation shall be made, under Items 1, 2 and 3, above, of the component to be included in the rate for purchased gas demand costs and the rate per Gas BDU shall be changed accordingly. b. Determination of Customer's Gas BDUs The Customer's Gas BDUs shall be determined as follows: The actual volumes of gas purchased by the Customer from the Company and used by the Customer in the separately-metered qualifying load balancing facilities during such Customer's Peak billing Cycle, as defined hereinafter, shall be multiplied by a fraction. The numerator shall be the number 3. The denominator shall be the number of days of service for which such Customer was billed in such Customer's Peak Billing Cycle. The Customer's Peak Billing Cycle shall be the single billing cycle of maximum delivery to the Customer's separately-metered qualifying load balancing facilities that ended during on of the months of December, January, February and March during the period beginning with the most recentlycompleted billing cycle and ending with the current billing cycle. If the customer used no gas under this rate schedule during the most recently concluded billing cycles ended in December, January, February or March, then the level of Gas BDUs applicable to Customer shall be zero (). (D) Indicates Decrease Issued: U\p r i 1 3, 2 1 3 Effective: Ma-y 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION 14;-3- to Revised Page No. 73.......<........... ~ Revised Page No. 73 2. Margin Demand Charge a. The rate per Margin BDU shall be $.3182 per Margin BDU. b. Determination of Customer's Margin BDUs The Customer's Margin BDUs shall be determined as follows: The actual deliveries of gas to the Customer by Company, including not only volumes of gas purchased by the Customer from the Company and used by the Customer in the separately-metered load balancing facilities but also volumes of Customerowned gas transported to the Customer's load balancing facilities through the Company's facilities, during such Customer's Peak billing Cycle, as defined hereinafter, shall be multiplied by a fraction. The numerator shall be the number 3. The denominator shall be the number of days of service for which such Customer was billed in such Customer's Peak Billing Cycle. The Customer's Peak Billing Cycle shall be the single billing cycle of maximum delivery to the Customer's separately-metered load balancing facilities that ended during one of the months of December, January, February and March during the period beginning with the most recently-completed billing cycle ended in December and ending with the current billing cycle. If the customer used no gas under this rate schedule during the most recently concluded billing cycles ended in December, January, February or March, then the level of Margin BDUs applicable to Customer shall be zero (). B. COMMODITY CHARGES FOR SALES AND FOR TRANSPORTATION SERVICE 1. Commodity Charge for Sales Service The monthly Commodity Charge for Sales Service shall be the product of multiplying the rate per Mcf, determined as provided below, by the volume of gas sold to the Customer by the Company during the applicable billing cycle. The rate per Mcf shall be determined as follows and shall be $1-3-.4823~ per Mcf, subject to revision as provided below: (I) The current components of the rate are as follows: Purchased Gas Commodity Costs, set forth in Rider "A" Non Gas Costs a. Determination of Rate per Mcf The rate per Mcf shall be the sum of: $4-3-. 23ESCJW-±-6/Mcf - -- $.2473/Mcf (I) 1. The net amount per Mcf for recovery of the commodity component of purchased gas costs and for recovery or refund of "E" factor amounts, the "PGCC", as determined in Rider "A"- Section 137(f) Purchased Gas Costs of this tariff; plus (D) Indicates Decrease (I) Indicates Increase Effective:... tma-y 1, 213

NATIONAL FUEL GAS Supplement No. 1:+.'~~ to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 r,eighteenth Revised Page No. 74 Canceling E: L::;htc'cr, hsixteenth and N nc::t>o::'cnthseventeenth Revised Page No. 74 2. The amount of $.2473 per Mcf for recovery of non-gas costs. Each time there is a change in the provision for recovery of purchased gas costs pursuant to Rider "A" of this tariff, a recomputation shall be made of the commodity component of purchased gas costs (Item 1, above) and the rate per Mcf shall be changed accordingly. The component included in the rate for recovery of non-gas costs shall remain constant until changed in accordance with a procedure, other than a proceeding pursuant to Section 137(f) of the Public Utility Code, 66 Pa.C.S. Section 137(f). 2. Commodity Charge.for Transportation Service The monthly Commodity Charge for Transportation Service shall be the product of multiplying the rate per Mcf, determined as provided below, by the volume of gas transported by the Company to the Customer's load balancing facilities. The rate per Mcf for transportation of gas under this rate schedule shall be $.5Q±73 per Mcf, which includes $.2473 for recovery of non-gas costs (Q±) and $.2 ~ for recovery of purchased gas. (Q±) V. SURCHARGE The Demand Charges and the Commodity Charge for Sales Service and the Commodity Charge for Transportation Service shall be subject to surcharges in accordance with provisions of Rider B - State Tax Adjustment Surcharge as set forth in this tariff. VI. AMOUNTS TO BE INCLUDED IN OVER/UNDERCOLLECTION OF GAS COSTS Purchased gas cost revenues billed under this rate schedule shall be included as revenues for recovery of gas costs for purposes of computing Factor "E" of Company's 137(f) rate in accordance with procedures set forth in Rider "A" -Section 137(f) Purchased Gas Costs. VII. SPECIAL PROVISIONS Monthly metered Special Provisions A through J contained in the Company's Rate Schedule for Transportation Service shall apply to transportat{on service under this rate schedule. VIII. RULES AND REGULATIONS The rules and regulations set forth in this tariff shall govern, where applicable, the supply of gas service under this rate schedule. LP.J.... Indcia tes Decrease (I) Indicates Increase Issued: July 31, 213~ Effective: August 1, 213~

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Supplement No. 1454 to Gas - Pa. P.U.C. No. 9 ' i :i:-f-s-t:. Revised Page No. 7 6..,.. ':... : ;... stsixtieth Revised Page No. 76 LIS Large Industrial Service (Cont'd) C. An Industrial Customer, for which the Company estimates that the total volumes of gas purchased from the Company or transported by the Company during the next succeeding twelve months will be not less than 2, Mcf, if the Industrial Customer has used total volumes of gas in at least one billing month of not less than 17, Mcf, even if the Customer disagrees with the Company's estimate. An Industrial Customer that meets the above criteria under this rate schedule at the beginning of an Application Period is required to continue to be subject to this rate schedule during all months of such Application Period. An Industrial Customer that meets the above criteria under this rate schedule during an Application Period is required to continue to be subject to this rate schedule during all or remaining months of such Application Period. MONTHLY RATE Basic Service Charge $1,29. per Month Distribution Charges 11.37~ per 1 cubic feet 9.23-s-±-7 per 1 cubic feet 7.16448 per 1 cubic feet ::) -G B 1 G-9-G- per 1 cubic feet - -- Gas Adjustment Charge (J.::t-._~.. ~..1. per 1 cubic feet -3 ) ~Q..}H per 1 cubic feet l (l.::f-.184~.g. ) per 1 cubic feet for for for for the first 1, cubic feet the next 1,9, cubic feet the next 18,, cubic feet all over 2,, cubic feet Purchased Gas Cost Component (Rider A) Merchant Function Charge (Rider G) Total Gas Adjustment Charge (D) (D) (D) (D) For a period of 12 months starting when gas supply service hereunder is initiated to a former SATC, MMT or DMT customer by the Company, the rates for service under this rate schedule shall exclude the Gas Adjustment Charge. Former SATC, MMT or DMT customers will be charged during this 12 month period the DEDC factor as defined in Rider A to this tariff and as contained in the Distribution charges set forth above, as amended from time to time. (I) Indicates Increase (D) Indicates Decrease Issued:... yma-y 31, 213 (C) Indicates Change

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling ;;,, Supplement No. 14~4 to Gas - Pa. P.U.C. No. 9 --.>Fourth Page No. 7 6A Page No. 76A LIS Large Industrial Service (Cont'd) Natural Gas Supply Charge SfJ-=t-.791~ per 1 cubic feet Purchased Gas Cost Component (Rider A).135-±- per 1 cubic feet Merchant Function Charge (Rider G) 1.5 per 1 cubic feet Gas Procurement Charge (Rider H) 5 9-8-. 97 6. -G-4- per 1 cubic feet Total Natural Gas Supply Charge The Natural Gas Supply Charge shall include a Merchant Function Charge (Rider G) to recover uncollectible costs associated with purchase gas costs of.2285% and the Gas Procurement Charge (Rider H) to recover costs of procuring natural gas pursuant to 52 Pa. Code 62.223. ( T) ( l) -f-8+ (I) -f-8+ The above rates shall be subject to surcharges in accordance with provisions of Rider B - State Tax Adjustment Surcharge. GAS SHORTAGE CURTAILMENT Service under this schedule to an LIS Industrial Customer is subject to curtailment and excess consumption penalty as set forth in Rule 26 of this tariff. RULES AND REGULATIONS The rules and regulations set forth in this tariff shall govern, where applicable, the supply of gas service under this rate schedule. (D) Indicates Decrease (I) Indicates Increase Issued: ;May 31, 213 (C) Indicates Change

NATIONAL FUEL GAS Supplement No. 14S3 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Fifty<~,' J,-F-:i:-f..t.fi Revised Page No. 7 9 Canceling Fifty-r ':> "., ;. '~" ch~ Revised Page No. 7 9 LBS and (b) volume of service (expressed in Mcf) to all customers under the "Monthly Volume" provisions of Rate Schedule SB, during the Company Peak Sales Month defined in Rate Schedule CPA-LBS. 3. The amount determined in Item 1 above shall be divided by the amount determined in Item 2 above to determine the amount included in the rate for recovery of purchased gas costs. 4. The rate per Gas BDU shall be the amount for purchased gas qemand costs (Item 3). The current rate per Gas BDU is as follows: Purchased Gas Demand Cost (D) Each time there is a change in the provision for recovery of purchased gas costs pursuant to Rider "A" of this tariff, a recomputation shall be made, under Items 1, 2 and 3, above, of the component to be included in the rate for purchased gas demand costs and the rate per Gas BDU shall be changed accordingly. b. Determination of Customer's Gas BDUs The Customer's Gas BDUs shall be determined as follows: The actual volumes of gas purchased by the Customer from the Company and used by the Customer in the separately-metered load balancing facilities during such Customer's Peak billing Cycle, as defined hereinafter, shall be multiplied by a fraction. The numerator shall be the number 3. The denominator shall be the number of days of service for which such Customer was billed in such Customer's Peak Billing Cycle. The Customer's Peak Billing Cycle shall be the single billing cycle of maximum delivery to the Customer's separately-metered load balancing facilities that ended during one of the months of December, January, Feb~uary and March during the period beginning with the most recently-completed ti~lling I cycle ended in December and ending with the current billing cycle. If the customer used no gas under this rate schedule during the most recently concluded billing cycles ended in December, January, February or March, then the level of Gas BDUs applicable to Customer shall be zero (). (I) Indicates Increase Issued: ~" :}\p r i 1 3, 2 1 3 Effective: '~M-ay 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Fifty-. Revised Page No. 8 : ~ Revised Page No. 8 2. Margin Demand Charge a. The rate per Margin BDU shall be $.2517 per Margin BDU. b. Determination of Customer's Margin BDUs The Customer's Margin BDUs shall be determined as follows: The actual deliveries of gas to the Customer by Company, including not only volumes of gas purchased by the Customer from the Company and used by the Customer in the separately-metered load balancing facilities but also volumes of Customerowned gas transported to the Customer's load balancing facilities through the Company's facilities, during such Customer's Peak billing Cycle, as defined hereinafter, shall be multiplied by a fraction. The numerator shall be the number 3. The denominator shall be the number of days of service for which such Customer was billed in such Customer's Peak Billing Cycle. The Customer's Peak Billing Cycle shall be the single billing cycle of maximum delivery to the Customer's separately-metered load balancing facilities that ended during one of the months of December, January, February and March during the period beginning with the most recently-completed billing cycle ended in December and ending with the current billing cycle. If the customer used no gas under this rate schedule during the most recently concluded billing cycles ended in December, January, February or March, then the level of Margin BDUs applicable to Customer shall be zero (). B. COMMODITY CHARGES FOR SALES AND FOR TRANSPORTATION SERVICE 1. Commodity Charge for Sales Service The monthly Commodity Charge for Sales Service shall be the product of multiplying the rate per Mcf, determined as provided below, by the volume of gas sold to the Customer by the Company during the applicable billing cycle. The rate per Mcf shall be determined as follows and shall be $2~.4274~ per Mcf, subject to revision as provided below: (I) The current components of the rate are as follows: Purchased Gas Commodity Costs, set forth in Rider "A" Non Gas Costs a. Determination of Rate per Mcf The rate per Mcf shall be the sum of: $.1_~.235G-ti-6/Mcf $.1924/Mcf (I) (I) Indicates Increase Issued: ::\pril 3, 213 Effective: tma-y 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Supplement No. 1f-3-'>-2- to Gas - Pa. P.U.C. No. 9 '.heighteenth Revised Page No. 81...,:... ' : :Si}{teenth and Lr->< ':~ ;;;r< [,seventeenth Revised Page No. 81 1. The net amount per Mcf for recovery of the commodity component of purchased gas costs and for recovery or refund of "E" factor amounts, the "PGCC", as determined in Rider "A"- Section 137(f) Purchased Gas Costs of this tariff; plus 2. The amount of $.1924 per Mcf for recovery of non-gas costs. Each time there is a change in the provision for recovery of purchased gas costs pursuant to Rider "A" of this tariff, a recomputation shall be made of the commodity component of purchased gas costs (Item 1, above) and the rate per Mcf shall be changed accordingly. The component included in the rate for recovery of non-gas costs shall remain constant until changed in accordance with a procedure, other than a proceeding pursuant to Section 137(f) of the Public Utility Code, 66 Pa.C.S. Section 137(f). 2. Commodity Charge for Transportation Service The monthly Commodity Charge for Transportation Service shall be the product of multiplying the rate per Mcf, determined as provided below, by the volume of gas transported by the Company to the Customer's load balancing facilities. The rate per Mcf for transportation of gas under this rate schedule shall be $.42~24 per Mcf, which includes $.1924 for recovery of non-gas costs (Q~) and $. 2.+ for recovery of purchased gas. (J2~) V. SURCHARGE The Demand Charges and the Commodity Charge for Sales Service and the Commodity Charge for Transportation Service shall be subject to surcharges in accordance with provisions of Rider B - State Tax Adjustment Surcharge as set forth in this tariff. VI. AMOUNTS TO BE INCLUDED IN OVER/UNDERCOLLECTION OF GAS COSTS Purchased gas cost revenues billed under this rate schedule shall be included as revenues for recovery of gas costs for purposes of computing Factor "E" of Company's 137(f) rate in accordance with procedures set forth in Rider "A"- Section 137(f) Purchased Gas Costs. VII. SPECIAL PROVISIONS Monthly metered Special Provisions A through J contained in the Company's Rate Schedule for Transportation Service shall apply to transportation service under this rate schedule. VIII. RULES AND REGULATIONS The rules and regulations set forth in this tariff shall govern, where applicable, the supply of gas service under this rate schedule..\..ij... TT. 1.S~.) :.S=..~.t.. E?.:.~:... P.. ~.~~=..E~.9..'?.~ (I) Indicates Increase Issued: July 31, 213-2- Effective: August 1, 2L)-2-

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Fifty- Fifty- Supplement No. 14~3 to Gas - Pa. P.U.C. No. 9 '~ Revised Page No. 82 hfourth Revised Page No. 82 RATE SCHEDULE - NGV NATURAL GAS VEHICLE SERVICE I. APPLICABILITY Throughout the territory served under this tariff. II. AVAILABILITY Sales Service under this rate schedule is available for use of natural gas by a customer directly in a natural gas motor vehicle ("NGV"). III. NATURE OF SERVICE Service provided in this rate schedule shall be firm service subject to the curtailment priorities of Rule 26. For curtailment purposes, service under this rate schedule shall be defined as curtailment priority number (6), firm large noncritical commercial and industrial requirements other than requirement for boiler fuel use. IV. RATE Rates per 1 cu. Ft. shall be established by the Company on the first day of each calendar month for each of the categories set forth below to compete with alternative vehicle fuels. The rates shall not be less than the 1% load factor base cost of gas, plus the take-or-pay surcharge, plus the surcharge for Transition Cost, plus the incremental operating cost incurred by the Company for operating Company owned NGV compression equipment on a per Ccf basis, if any, plus $.1 per cu. ft., plus the state tax adjustment surcharge, and not more than the tailblock rate of the Commercial and Public Authority Service Rate Schedule, including all applicable surcharges, plus the incremental operating cost incurred by the Company for operating Company owned NGV compression equipment on a per Ccf basis, if any. The 1% load factor base cost of gas shall be $..?...9 ~>... 2-4-8-6-8-3 per 1 cu. (I) ft. (as calculated by adding the purchase gas components of the Load Balancing Service Rates). Purchased Gas 1% Load Factor Demand Cost plus Purchased Gas Commodity Cost Equals 1% Load Factor Base Cost of Gas $. -~~.?..?}}.~/Ccf $.4235~/Ccf $.56694-G-6-8-3/Ccf (D) (I) (I) The incremental operating cost for compression shall be $.13436/Ccf. (D) Indicates Decrease (I) Indicates Increase Issued: lprpril 3, 213 Effective: 'May 1, 213

NATIONAL FUEL GAS Supplement No. 14S4 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Seventy-,,_, :--,~ Revised Page No. 83 Canceling Seventy-.~...;_-:Second and Seventy-S h~ Revised Page No. 83 Natural gas vehicle customers are classified into the following categories: NGV(1) All natural gas vehicle customers utilizing Company owned filling facilities. A uniform rate shall be established each month within the parameters set forth above, for customers utilizing Company-owned filling facilities. The minimum NGV(1) rate shall be: r The current components of the minimum NGV(1) rate are as follows: 1% load factor base cost of gas: $ o. ~) o 6 6 9-4-G--6-8-3 ICc f l_ll Incremental operating cost of Company owned NGV compression equipment: Transition Cost Surcharge State Tax Adjustment Surcharge Minimum allowable Non-Gas cost The maximum NGV(1) rate shall be: The current components of the maximum NGV(1) rate are as follows: $.134361Ccf $.1Ccf ($. 1?_4_-±-G-) ICcf I $.11Ccf Tailblock rate of the Commercial and Public Authority Service Rate schedule: Incremental operating cost of Company owned NGV compression equipment: State Tax Adjustment Surcharge $.73483~1Ccf $.134361Ccf ($.1 _>. -9.) ICcf (I) (I) NGV(2) Natural gas vehicle customers utilizing customer owned filling facilities. A uniform rate will be established each month within the parameters set forth above, to customers utilizing customer owned filling facilities. The minimum NGV(2) rate shall be: The current components of the minimum NGV(2) rate are as follows: $.51571-4-±-6-G-8-ICcf (I) 1% load factor base cost of gas: Transition Cost Surcharge State Tax Adjustment Surcharge Minimum allowable Non-Gas cost $.5669-4-G--&8-31Ccf (I) $.1Ccf ( $. ~..?.-8-3) ICc f I $.11Ccf The maximum NGV(2) rate shall be: $.73343~1Ccf (I) (I) Indicates Increase (D) Indicates Decrease Issued: yma-y 31 1 2 13 Effective: J.\::rfie 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Seventy- S::.?..r.?:9:~ Supplement No. 1454 to Gas - Pa. P.U.C. No. 9 Revised Page No. 84 Canceling Sixty-Nin.tbSeventh and Seventy-FirstSeventieth Revised Page No. 84 The current components of the maximum NGV(2) rate are as follows: V. SURCHARGE Tailblock rate of the Commercial and Public Authority Service Rate schedule: State Tax Adjustment Surcharge $.. ~...?.J.. ~-?.. ~.~5 ICc f ( $. 1!Q_-3--2-) ICc f (I) (!?_±) All charges under this rate schedule will be subject to surcharges in accordance with provisions of Rider B - State Tax Adjustment Surcharge as set forth in this tariff. VI. AMOUNTS TO BE INCLUDED IN OVERIUNDERCOLLECTION OF GAS COSTS Purchased gas cost revenues billed under this rate schedule shall be included as revenues for recovery of gas costs for purposes of computing Factor "E" of Company's 137( ) rate in accordance with procedures set forth in Rider "A" - section 137(f) Purchased Gas Costs. Purchased gas cost revenues recovered under this rate schedule shall be the 1% load factor base cost of gas as defined above. VII. RULES AND REGULATIONS The rules and regulations set forth in this tariff shall govern, where applicable, the supply of gas service under this rate schedule. (I) Indicates Increase (D) Indicates Decrease Issued: ~~!ymay 31, 213 Effective: 1:\'::1.9\l.f?.!.:Jun e 1, 2 13

NATIONAL FUEL GAS DISTRIBUTION CORPORATION nceling Supplement No. 14S3 to Gas - Pa. P.U.C. No. 9 Revised Page No. 93 Revised Page No. 93 ~Thirtieth RATE SCHEDULE PSB APPLICABILITY PRIORITY STANDBY SERVICE Throughout the territory served under this tariff. AVAILABILITY OF SERVICE Service under this rate schedule is available to all customers under the Residential, Commercial and Public Authority, and SVIS Rate Schedules which enter into a contract for service under this Rate Schedule. A customer will be permitted to enter into a contract, prepared by the Company, for service under this rate schedule, however, only if the Company projects that sufficient volumes of gas will be available to the Company during the period of the customer's contract for Priority Standby Service. Service under this rate schedule is mandatory for all customers categorized as Priority 1 under the curtailment priorities of Rule 26 who enter into contracts with the Company to receive Transportation Service and who do not have dual or alternate fuel equipment on site which is installed and operable with sufficient amounts of alternate fuel available on site during each winter period of each year commencing on December 1 and ending on March 31 of the following year. Service under this rate schedule is voluntary for all other customers. NATURE OF SERVICE Priority standby service shall permit the customer to purchase gas on a firm basis subject to curtailment priorities of Rule 26. The Company will take all reasonable steps to obtain or to maintain gas supplies sufficient to enable the Company to provide reasonably continuous service to each Customer receiving Priority Standby Service. MONTHLY RATE The monthly rate shall be $.!:_B-.):)._)./+-±-+± per Mcf, which shall be applied to the total monthly volumes transported by the customer during the month. (TH) The rate shall equal the PGDC portion of the commodity rate applicable to the corresponding sales rate classification. (~_B) Indicates InBecrease Issued: Lhpril 3, 213 Effective: '.May 1' 213

NATIONAL FUEL GAS Supplement No. 14S~ to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 MONTHLY RATE ' ' : ; '-: Thirtieth Revised Page No. 95 Canceling Twenty-~ ~~Eighth Revised Page No. 95 The monthly rate shall be $.5249~ per Mcf, which shall be applied to the Monthly Volume, as defined below. (l8) MONTHLY VOLUME The Mcf volume of gas to which the Monthly Rate set forth above shall be applied, shall be determined for each billing cycle, as set forth below; 1. The volume of gas specified in the Service Agreement under this rate schedule shall be adjusted for each billing cycle by, multiplying such volume, expressed in Mcf, by a fraction. The numerator of the fraction shall be the number of days in the billing cycle applicable to the customer and the denominator shall be thirty (3). 2. If the volume determined under item 1, above, is greater than the sum of the Mcf volume of gas purchased by the customer under rate schedules other than load balancing rate schedules during the billing cycle, the Monthly Rate shall be applied to the difference between: (a) the volume determined under item 1, above, and (b) the Mcf volume of gas purchased by the customer under the rate schedules other than load balancing rate schedules during such billing cycle. 3. If the volume determined under item 1, above, is equal to or less than the Mcf volume of gas purchased by the customer under rate schedules other than load balancing rate schedules during the billing cycle, then the Monthly Volume shall be zero () Mcf. (~_8) Indicates In-8-ecrease Issued: LApril 3, 213 Effective: 'Miry 1, 213

NATIONAL FUEL GAS Supplement No. 14?.4 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Twenty-~_tg)~.. thseventh Revised Page No. 1 Canceling Twenty-SixthFourth and Twenty-Seventh~ Revised Page No. 1 RATE SCHEDULE FOR MONTHLY METERED TRANSPORTATION SCHEDULE (cont'd) (C) MONTHLY RATES Commodity Rates The commodity rates set forth below contain a component, presently $.2 _.:t- per Mcf, for recovery of purchased gas costs. For transportation of gas to Residential Customers, the monthly rate for transportation of gas both within and outside the Commonwealth of Pennsylvania shall be: $3. ~_498 Mcf (D) For transportation of gas to Commercial and Public Authority Customers, the monthly rate for transportation of gas produced within the Commonwealth of Pennsylvania shall be: $2.~9~72 per Mcf for Small Commercial/Public Authority using not more (D) than 25 Mcf per year $2.2l441 per Mcf for Small Commercial/Public Authority using greater (D) than 25 Mcf but not more than 1, Mcf per year $1.74_5 62 per Mcf for Large Commercial/Public Authority (D) For transportation of gas to Commercial and Public Authority Customers, the monthly rate for transportation of gas produced outside the Commonwealth of Pennsylvania shall be: $2?._9 72 per Mcf for Small Commercial/Public Authority using not more (D) than 25 Mcf per year $2.2}_441 per Mcf for Small Commercial/Public Authority using greater (D) than 25 Mcf but not more than 1, Mcf per year $1.7_4_-5-62 per Mcf for Large Commercial/Public Authority (D) For transportation of gas to Small Volume Industrial Customers, the monthly rate for transportation of gas produced within the Commonwealth of Pennsylvania shall be: $2. 5.9._-l-97 per Mcf for SVIS Customers (D) For transportation of gas to Small Volume Industrial Customers, the monthly rate for transportation of gas produced outside the Commonwealth of Pennsylvania shall be: $2.5.9._~97 per Mcf for SVIS Customers (D) (I) Indicates Increase (D) Indicates Decrease Issued: JulYMay 31, 213 (C) Indicates Change Effective: AugustJ:tt:H.e 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Twenty- L Supplement No. 1454 to Gas - Pa. P.U.C. No. 9 Twenty-:::,~Y_<~. ;~ Revised Page No. 11 ::;~ and Twenty-::;i zthfourth Revised Page No. 11 RATE SCHEDULE FOR MONTHLY METERED TRANSPORTATION SCHEDULE (cont'd) +8+ For transportation of gas to Intermediate Volume Industrial Customers, the monthly rate for transportation of gas produced within the Commonwealth of Pennsylvania shall be: $1. 3. _-+6 per Mcf for IVIS Customers (D) For transportation of gas to Intermediate Volume Industrial Customers, the monthly rate for transportation of gas produced outside the Commonwealth of Pennsylvania shall be: $1.3 -+6 per Mcf for IVIS Customers (D) For transportation of gas to Large Volume Industrial Customers and any entity that is not a Gas Service Customer, the monthly rate for transportation of gas produced within the Commonwealth of Pennsylvania shall be: $1.1Q±29 per Mcf (D) For transportation of gas to Large Volume Industrial Customers and any entity that is not a Gas Service Customer, the monthly rate for transportation of gas produced outside the Commonwealth of Pennsylvania shall be: $1.1Q±29 per Mcf (D) For transportation of gas to Large Industrial Customers, the monthly rate for transportation of gas produced within the Commonwealth of Pennsylvania shall be: $. 7!?,-69 per Mcf (D) For transportation of gas to Large Industrial Customers, the monthly rate for transportation of gas produced outside the Commonwealth of Pennsylvania shall be: $.7~~9 per Mcf Provided, however, that the Company, in its sole discretion, may reduce by contract the portion of the above rates applicable to the Customer that are for recovery of gas or the portion of the rate for recovery of non-gas costs of service if it is reasonably necessary to do so to meet competition from another supplier of energy including gas from another supplier of gas that has constructed, or could construct, facilities to deliver supplies of gas to a MMT Customer of the Company without use of the Company's facilities or another transportation of gas. The Company may also reduce or eliminate the compensation for line losses provided for in Special Provisions paragraph B of this rate schedule in order to meet the competitive circumstances for alternate fuels or bypass situations cited above excluding competition from other Pennsylvania local distribution companies. The Company will reduce the applicable rate only if: (a) Either (1) the MMT Customer has facilities in place and operable to use an alternative fuel or obtain gas from an alternative supplier or (2) in the Company's judgment, such facilities would be constructed; (I) Indicates Increase (C) Indicates Change (D) Indicates Decrease (D)

I Issued:... ;'May 31 ' 2 1 3 Effective: '.J-tlfte 1, 213

NATIONAL FUEL GAS Supplement No. 14c3 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Sixty-<.>,,-..1-F:i-r-s-t:- Revised Page No. 16 Canceling, ;Fifty Ninth Revised Page No. 16 E. In the event of interruption or curtailment of transportation service, pursuant to items C and D, above, and during such period of interruption or curtailment, the MMT Customer must sell to the Company all or a portion of the MMT Customer's supply of gas at the higher of (1) the Transportation Service Customer's cost of purchased gas at the point of delivery to the Company or (2) the Company's average cost of purchased gas per Mcf, as determined based upon the Company's Section 137(f) Rate, which is $ 6.1_-8-4 59+±. (I) F. If for any reason (including the default of an MMNGS Supplier), the MMNGS Supplier fails to provide sufficient daily deliveries of natural gas supplies to meet the MMT Customers DDQ pursuant to the terms of MMNGS supply service, and/or MMT Customer's MMNGS Supplier does not provide complete compensation to the Company for services provided under Rate Schedule MMNGS, Special Provision.3, the Company shall charge the MMT Customer for the deficient daily deliveries under the applicable gas sales rate schedule plus applicable surcharge as set forth in Rate Schedule SB Special Provisions. (I) Indicates Increase Issued: >]1\pril 3, 213 Effective: tma-y 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Supplement No. 1 ;-1-G- to Gas - Pa. P.U.C. No. 9 S''' th~ Page No. 116 Canceling Page No. 116 BILLING Monthly charges, for transportation service pursuant to this rate schedule, are subject to the Late Payment Charges set forth in Section 16 of the Rules and Regulations of this Tariff. SPECIAL PROVISIONS A. The volume of gas delivered into the Company's distribution system, on any day in behalf of Transportation Service Customers for transportation service pursuant to this Rate Schedule, shall be determined by meters and as provided in B, below, at the delivery points specified in the service Agreement or to another point or points acceptable to the Company. If any such point of delivery is also a point at which the Company buys or exchanges gas for the Company's own account through the same meter, the volume of gas delivered into the Company's distribution system, in behalf of Transportation Service Customers for transportation service, shall be deemed to be the volume scheduled by the Company and such Customers to be delivered in behalf of such Customers, at such point on such day, determined after the adjustment provided in B, below, but shall not be more than the total amount actually delivered, determined after the adjustment provided in B below, through such meter into the Company's distribution system at such point on such day. B. To compensate for line losses, the volume of gas delivered into the Company's distribution system, shall be determined for purposes of this Rate Schedule, effective August 1, 21 ~.g. to be equal to 99. c54% of the amount (:,-±-) indicated by a meter at the point of delivery into the Company's distribution system; provided however, that, where the only Company facilities involved in transporting gas to the Gas Service Customer are meters, meter installations, house regulators, house regulator installations and industrial measuring and regulating station equipment, no amount shall be deducted as compensation for line losses. C. Service under this Rate Schedule may be interrupted during periods of supply shortages but only based upon the schedule of priority of curtailment set forth in section 26 of the Rules and Regulations of this tariff. D. Transportation service under this Rate Schedule may be interrupted or curtailed whenever, in the event of a sudden and unforeseen supply deficiency, the Company invokes emergency curtailment provisions under Tariff Rule 26. (D±-) Indicates efficrease Issued: July 3~G, 21~-G- Effective: August 1, 21~G

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Fifty-NJ Supplement No. 14S3 to Gas - Pa. P.U.C. No. 9 ; Si1ctieth Revised Page No. 117 (~: ';Eighth Revised Page No. 117 E. In the event of interruption or curtailment of transportation service, pursuant to items C and D, above, and during such period of interruption or curtailment, the DMT Service Customer must sell to the Company all or a portion of the DMT Service Customer's supply of gas at the higher of (1) the Transportation Service Customer's cost of purchased gas at the point of delivery to the Company or (2) the Company's average cost of purchased gas per Mcf, as determined based upon the Company's Section 137(f) Rate, which is $ 6 1 -G-4 5 9-=t-±-. ( I ) F. If a Gas Service Customer receiving gas transported by the Company uses less than the amount of gas delivered into the Company's system for transportation to such Customer ("excess deliveries"), the Gas Service Customer receiving gas transported by the Company may use such gas during the banking/balancing period defined below, following which the Company shall have the right, but not the obligation, to purchase remaining excess deliveries of gas from the DMT service Customer at a rate equal to the lowest of (1) the cost at which it was acquired by the DMT Service Customer, including pipeline transportation charges, or (2) the Company's average commodity delivered cost of gas to National Fuel Gas Supply Corporation, or (3) the Company's average commodity cost of locally produced gas during the month when excess deliveries were received by the Company. The cost at which the DMT Service Customer acquired the gas will be determined from such Customer's contract with the supplier or by a sworn affidavit setting forth the Customer's cost of gas, including cost of delivery of such gas to the Company's system. Upon request by the Company, the DMT Service Customer will be required to furnish to the Company the DMT service Customer's choice of (1) a copy of this contract or (2) an affidavit. The banking/balancing period shall be the three billing months after the billing month in which the Company received excess deliveries in behalf of the Customer. G. "Underdeliveries" are volumes of gas taken from the Company by a Gas Service Customer in excess of the sum of (1) any excess deliveries of the customer at the beginning of the day and (2) the volume of gas delivered to the Company for the customer's account, after adjustment for line losses less volumes of volumes of gas determined to be sales by the Company to the customer. Cumulative underdeliveries, as determined each day, in excess of two percent of the volume of gas delivered by the Company to the customer that day, shall be a sale of gas by the Company to the customer under the applicable rate schedule plus applicable surcharges as set forth in Rate Schedule SB Special Provisions and shall not be recharacterized as transportation service under any circumstances. Cumulative underdeliveries of not more than two percent of the volume of gas delivered to a customer by the Company on any day may be offset by volumes of gas delivered to the Company for the customer's account, after adjustment for line losses, in excess of the volume of gas taken by the customer from the Company on subsequent days within the same billing month. (I) Indicates Increase Issued:.' April 3, 213 Effective: ~May 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Supplement No. 1 ;~ to Gas - Pa. P.U.C. No. 9 ' Eleventh Revised Page No. 118B, (i.!f-e.n-:t-fl. Revised Page No. 118 B RATE SCHEDULE MMNGS MONTHLY METERED NATURAL GAS SUPPLIER SERVICE (Cont.) The Company shall provide the Supplier receiving standard Billing Service with meter reading information and other reports in the Company's standard electronic format on a basis corresponding to the MMT Customer's billing cycles. The Supplier shall provide the Company with all required Supplier billing and rate information necessary for customer billing as determined by the Company. The Supplier shall provide such billing information in the Company's required format. The Supplier shall provide its billing information no later than three business days before the last day of the month. The Company will bill the MMT Customer for gas supplies sold by the Supplier to the Customer subject to the Supplier entering into a billing service contract with the Company. Payments made by the MMT Customer under the billing service will be applied first to amounts to past service due under an amortization agreement with the Company, next to current bills due to the Company, next to gas supply charges owed to the Supplier, next to charges for other non-regulated service charges, and lastly to any "neighbor for neighbor" contribution. The terms and charges for the Supplier billing services other than Standard Billing Services may be negotiated between the Company and the Supplier. The Company shall be under no obligation to provide the Supplier billing services other than Standard billing Services if mutually agreeable terms and charges cannot be negotiated. SPECIAL PROVISIONS A. Gas Quality Gas delivered by the Supplier must satisfy the quality specifications included in the Rules for Transportation Service section of this tariff. For deliveries to the Company, such deliveries must be made at an appropriate Company facility located within the Territory, as described in this tariff, or at another point or points acceptable to the Company. B. Allocation Priority If any such point of delivery is also a point at which the Company buys or exchanges gas for the Company' s own account though the same meter, the volume of gas delivered into the Company's distribution system, in behalf of MMT customers, shall be deemed in behalf of such MMT Customers, at such point on such day, determined after the adjustment provided in C, below, but shall not be more than the total amount actually delivered, determined after the adjustment provided in C below, through such meter into the Company's distribution system at such point on such day. C. Allowance for Losses As allowance for losses incurred in the process of delivery except as provided in Special Provision B under the MMT Rate schedule, Leaf No. 15, the Supplier shall provide the Company with a volume of gas equal to.15-3-1-% of the amount delivered to the Company. (D) (D) Indicates Decrease Issued: July 31, 21J~ Effective: August 1, 21i~

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Supplement No. 1453 to Gas - Pa. P.U.C. No. 9 Revised Page No. 119A... :... Tvvelfth Revised Page No. 119A ~Fourteenth RATES AND CHARGES RATE SCHEDULE SATC SMALL AGGREGATION TRANSPORTATION CUSTOMER SERVICE (Cont'd) A. Customer Transportation Service Rates The Company will provide transportation services to deliver gas supplies to the SATC Customer(s). The Customer shall be billed the charges for the transportation services rendered for it at the appropriate charges provided herein for which service the SATC Customer qualifies. The SATC Customer shall pay the following transportation charges for the transportation of gas. The commodity rates set forth below contain a component, presently $.238~ per Ccf, for the recovery of purchased gas (D) demand costs and shall be adjusted pursuant to Rider A of the tariff. Such purchased gas costs collected though these rates shall be included as revenues for the recovery of purchased gas costs as specified in Rider A of this tariff. (D) Indicates Decrease Issued: >I'xpril 3, 213 Effective: Ma-y----1-, 2 13

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Sixty-:f.S?.~l.:J?!:l.?.~ Supplement No. 14?.4 to Gas - Pa. P.U.C. No. 9 Revised Page No. 12 Canceling Sixty-FirstFi.fty Ninth and Sixty-ThirdSecond Revised Page No. 12 RATE SCHEDULE SATC SMALL AGGREGATION TRANSPORTATION CUSTOMER SERVICE (Cont.) 1. Residential Transportation Rates SATC Customers that meet the qualifications under the Residential Service Rate Schedule classification: Rates per Residential SATC Customer per Month: $12. $. 3 5 -~ _L6-5 1 $.25Ql~3 Basic Service Charge per 1 cubic feet for the first 5, cubic feet per 1 cubic feet for all over 5, cubic feet (D) (D) 2. Commercia~ and Public Authority Transportation Rates SATC Customers that meet the qualifications under the Commercial and Public Authority Service Rate Schedule classification: a. Rates per Commercial/Public Authority customer per month for "Small" Commercial/Public Customers using not more than 25, cubic feet per year: $19.89 $. 2 9.?... ~:5 7 $.26Q3-±-2 Basic Service Charge per 1 cubic feet for the first 5, cubic feet per 1 cubic feet for all over 5, cubic feet (D) (D) b. Rates per Commercial/Public Authority customer per month for "Small" Commercial/Public Customers using greater than 25, cubic feet but not more than 1,,~ cubic feet per year: $27.53 $. 21:_-2- _-&3 $. 211_-=7-1-9 Basic Service Charge per 1 cubic feet for the first 2, cubic feet per 1 cubic feet for all over 2, cubic feet (D) (D) c. Rates per Commercial/Public Authority customer per month for "Large" Commercial/Public Customers: $121.1 Basic Service Charge $.18Q. _347 per 1 cubic feet for the first 3, cubic feet $. 1.?.~ 7-1 5 5 per 1 cubic feet for the next 1,7, cubic feet $.14 _9+1 per 1 cubic feet for all over 2,, cubic feet (D) (D) (D) (D) Indicates Decrease Issued: T\:l~YMay 31, 2 13 Effective:!?:\:!9L.l.?.!: J-\:l-R-e 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Supplement No. 14S4 to Gas - Pa. P.U.C. No. 9 Sixty- ' r ~ Revised Page No. 121.Fifty Ninth and Sixty- :;:: ;,.:Second Revised Page No. 121 RATE SCHEDULE SATC SMALL AGGREGATION TRANSPORTATION CUSTOMER SERVICE (Cont.) 3. Small Volume Industrial Service Transportation Rates SATC Customers that meet the qualifications under the Small Volume Industrial Service Rate Schedule classification: Rates per Small Volume Industrial Service SATC Customer per Month: $65.6 Basic Service Charge $.237-9-&7 per 1 cubic feet (D) 4. Intermediate Volume Industrial Service Transportation Rates SATC Customers that meet the qualifications under the Intermediate Volume Industrial Service Rate Schedule classification: Month: Rates per Intermediate Volume Industrial Service SATC Customer per $21.91 Basic Service Charge $.1782±-86 per 1 cubic feet for the first 1, cubic feet (D) $. )::.}..:?±4 W-5 per 1 cubic feet for the next 1,9, cubic feet (D) $.155-8-:3-1 per 1 cubic feet for all over 2,, cubic feet (D) B. Miscellaneous Customer Surcharges 1. Gas Adjustment Charges For a period of 12 months starting when service hereunder is rendered to the SATC Customer by the SATS Suppliers, the rates for transportation services under this service classification shall include an amount per 1 cubic feet equal to the sum of the Gas Adjustment Charge included in the currently applicable Purchased Gas rate as specified in Rider A plus the applicable Merchant Function Charge ("MFC") as specified in Rider G, both of this tariff and as adjusted from time to time. 2. Transition costs associated with FERC Order No. 636. The rates for service rendered pursuant to the service classification shall be subject to a monthly transition cost surcharge as described in Rider D to this tariff. 3. Residential rates shall be subject to surcharges in accordance with Rider F - LIRA Discount Charge as set forth in this tariff. 4. The above SATC rates shall be subject to surcharges in accordance with provisions of Rider B - State Tax Adjustment Surcharge. (D) Indicates Decrease Issued: :. ::/May 31 1 2 13 Effective: -~.. Jtrfte 1, 2 13

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Supplement No. 1 ';~ to Gas - Pa. P.U.C. No. 9 : ::Fourth Revised Page No. 125A r:!f-h-:i::-r.el Revised Page No. 125A RATE SCHEDULE SATS SMALL AGGREGATION TRANSPORTATION SUPPLIER SERVICE (Cont.) SPECIAL PROVISION A. Gas Quality Gas delivered by the Supplier must satisfy the quality specification of the pipelines used to transport Supplier's gas. For deliveries to the Company, such deliveries must be made at an appropriate Company facility located within the Territory, as described in this tariff, or at another point or points acceptable to the Company. B. Allowance for Losses As allowance for losses incurred in the process of delivery, the Supplier shall provide the Company with a volume of gas equal to.j..?..-3-±-% of (D) the amount delivered to the Company. In addition, for deliveries into Company capacity retained pursuant to Sections C.3. and C.S., Suppliers shall provide incremental quantities of gas equal to the amount of retainage required to transport gas from the receipt point into such Company retained capacity to the entry point to the Company's system ("City Gate"). (D) Indicates Decrease -------------------------------------------------------------------------------------------- Issued: July 31, 21~~ Effective: August 1, 21~~

NATIONAL FUEL GAS Supplement No. 1453-2 to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 Twenty-~}_i~~-~~hFo-t:H:'-t-h Revised Page No. 126 Canceling Twenty-FourthSecond and Twenty-Fifth'-f!.hird Revised Page No. 126 RATE SCHEDULE SATS SMALL AGGREGATION TRANSPORTATION SUPPLIER SERVICE (Cont.) c. Total Upstream Capacity Requirements for SATS Suppliers SATS Suppliers shall be required to provide sufficient firm pipeline transportation and storage capacity to meet the estimated extreme day requirements of their SATC Customer groups as further described below. The SATS Suppliers' estimated extreme day requirements of their SATC Customer Group used for Supplier capacity allocations and requirements shall be based on a sixty-two (62) degree day extreme peak day calculation. The Company shall utilize peaking and temperature swing storage capacity retained by the Company and recovered through SATC rates to provide for any variances between actual and forecasted usage and for any peak delivery requirements for days colder than sixty-two (62) degree days. Such sufficient pipeline transportation and storage capacity shall be provided through the following means: 1. Released ESS Storage Capacity and Associated EFT Capacity a. Requirements To Be Met Through ESS Storage 6±% of extreme peak day requirements shall be provided through the Company's ESS storage and associated EFT transportation capacity on NFGSC. Such NFGSC Storage and transmission capacity shall be released to SATS Suppliers at the maximum rate under the pipeline's FERC gas tariff. (D) b. Initial Assignment of ESS Storage Capacity In a month a SATS Supplier begins to serve SATC customers, it shall be provided with an initial assignment of storage capacity, based on the percentage set forth at C.l.a. above, to meet the Supplier's requirements for the upcoming winter period. Approximately fifteen days prior to the close of nominations for the month, the Company will calculate the quantity of storage capacity released to match the SATS Supplier's winter requirements based on the number of SATC Customers aggregated by the Supplier. If the initial assignment takes place in a month other than April, the Company will transfer storage gas to the Supplier pursuant to C.l.c below. The SATS Supplier shall be responsible for all taxes and pipeline fees associated with moving or transferring the storage gas to the Company. (D) Indicates Decrease (I) Indicates Increase Issued: July 31, 213* Effective: August 1, 213~

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Twenty-U}. ~.: Eighth.. Supplement No. 1 <-3-8- to Gas - Pa. P.U.C. No. 9 ;T,enty Ninth Revised Page No. 127 Revised Page No. 127 RATE SCHEDULE SATS SMALL AGGREGATION TRANSPORTATION SUPPLIER SERVICE (Cont.) c. Additional Assignments of ESS Storage Capacity Approximately fifteen days prior to the close of nominations for each month, the Company will recalculate the quantity of storage capacity released to match the SATS Supplier's revised winter requirements based on the number of SATC Customers aggregated by the Supplier. If additional SATC Customers join a SATS Supplier's SATC Customer Group, the Company will release additional capacity as required, based on the percentage set forth at C.1.a. above. In addition, the SATS Supplier will be required to pay the Company for storage gas transferred and all taxes and pipeline fees associated with moving or transferring the storage gas to the Supplier. The storage gas transfer rate shall be the sum of (1) the higher of the Company's average cost of gas based upon the Company's Section 137f rate, or the DMI for the first day of month in which gas is transferred plus all transportation costs to the Company's City Gate, plus (2) the demand Transfer Recovery Rate ("DTR Rate"). The DTR rate shall equal the per Mcf System Average Unrecovered Demand Charge revenue beginning in the month of April through the initial month that storage capacity is released to the Supplier. The System Average Unrecovered demand Charge Revenue shall equal the sum of the differences between the average demand charge revenues and the average fixed demand costs beginning the month of April through the initial month that storage capacity is released to the Supplier. The DTR by month shall be as follows: Capacity Transfer Month DTR $/Mcf April $. May $. June $. July $. August $. September $. October $. November $.1_- -7 December $..4.?.-8-8- January $.29+±- February $.1~ March $. D (D) ( _Q-±-) (_Q-±-) Indicates De-I-ncrease Issued: ;-:;:yjanuary 31, 213 Effective: cfebruary 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Twenty-Se Twenty-'\ Supplement No. 14~~ to Gas ~ Pa. P.U.C. No. 9!:Eighth Revised Page No. 131 Revised Page No. 131 RATE SCHEDULE SATS SMALL AGGREGATION TRANSPORTATION SUPPLIER SERVICE (Cont.) 2. Released Transmission Capacity Not Included in SATC Transportation Rates 4~% of extreme peak day requirements is to be provided.by the release of pipeline capacity upstream of NFGSC and the release of associated EFT transportation capacity on NFGSC which is not included in transportation rates. All such capacity shall be released to SATS Suppliers, and SATS Suppliers shall take such released capacity, at the maximum rate under the pipeline's FERC gas tariff. The actual pipeline capacity path upstream of NFGSC to be released to the Supplier by the Company shall be designated by the Company from its available capacity. The Company will attempt to accommodate a Supplier's request for particular capacity on a first-come first-serve basis. As an alternative to the above, the Company may designate an alternative capacity path(s) from its available capacity. The capacity release rate for the pipeline capacity path released to the Supplier shall be $1}4.8762~/Dth which equals the weighted average demand cost of upstream capacity, however, capacity released on NFGSC will be released at the maximum rate under NFGSC's FERC gas tariff. The Company will post a listing of the alternative capacity path(s) designated, including the associated quantity of capacity, on its web site. (D) For capacity termination notices, prior to the termination notice date of any capacity contract in this Section C.2., the Company will issue a request for proposals to qualified Suppliers under this tariff to determine if the Company should terminate, renew, or replace such contract, in whole or in part. The Company will terminate a proportionate share of the capacity contract if: (1) Suppliers demonstrate that they will provide comparable firm capacity to serve the Company's core customers, (2) the Suppliers agree to assign such comparable capacity at the contracted price to the Company upon Company request if such capacity is required to meet supply requirements of SATC Customers due to the termination of the SATS Supplier pursuant to Section H.1. or if the Supplier has reduced the level of delivery requirements from the previous periods requirements, and 3) the Commission approves such comparable capacity. Comparable capacity must have firm rights for at least the seven (7) winter months, and such capacity must have primary delivery rights into available primary receipt rights on NFGSC held by the Company. Comparable capacity must have firm capacity rights sufficient in volume and duration (with renewal rights) to serve the customers to be served by the SATS Supplier. The Company will post a listing of capacity contracts, including the associated quantity of capacity, that it determines to be of critical status on its web site. (D) Indicates Decrease Effective: ;May 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Twenty-D~ Supplement No. 14~3 to Gas - Pa. P.U.C. No. 9 Revised Page No. 146G Revised Page No. 146G ~ Thirtieth E. In the event of interruption or curtailment of transportation service, pursuant to items C and D, above, and during such period of interruption or curtailment, the DMLMT Service customer must sell to the Company all or a portion of the DMLMT Service Customer's supply of gas at the higher of (1) the Transportation Service Customer's cost of purchased gas at the point of delivery to the Company or (2) the Company's average cost of purchased gas per Mcf, as determined based upon the Company's Section 137(f) Rate which is $6. JG-4?... 2.-=7-±-. (I) F. If a Gas Service Customer receiving gas transported by the Company uses less than the amount of gas delivered into the Company's system for transportation to such Customer ("excess deliveries"), the Gas Service Customer receiving gas transported by the Company may use such gas during the banking/balancing period defined below, following which the Company shall have the right, but not the obligation, to purchase remaining excess deliveries of gas from the DMLMT Service Customer at a rate equal to the lowest of (1) the cost at which it was acquired by the DMLMT Service Customer, including pipeline transportation charges, or (2) the Company's average commodity delivered cost of gas to National Fuel Gas Supply Corporation, or (3) the Company's average commodity cost of locally-produced gas during the month when excess deliveries were received by the Company. The cost at which the DMLMT Service Customer acquired the gas will be determined from such Customer's contract with the supplier or by a sworn affidavit setting forth the Customer's cost of gas, including cost of delivery of such gas to the Company's system. Upon request by the Company, the DMLMT service Customer will be required to furnish to the Company the DMLMT Service Customer's choice of (1) a copy of this contract or (2) an affidavit. The banking/balancing period shall be the three billing months after the billing month in which the Company received excess deliveries in behalf of the Customer. G. "Underdeliveries" are volumes of gas taken from the Company by a Gas Service Customer in excess of the sum of (1) any excess deliveries of the customer at the beginning of the day and (2) the volume of gas delive~ed to the Company for the customer's account, after adjustment for line losses less volumes of gas determined to be sales by the Company to the customer. Cumulative underdeliveries, as determined each day, in excess of two percent of the volume of gas delivered by the Company to the customer that day, shall be a sale of gas by the Company to the customer under the applicable rate schedule plus applicable surcharges as set forth in Rate Schedule SB Special Provisions and shall not be recharacterized as transportation service under any circumstances. Cumulative underdeliveries of not more than two percent of the volume of gas delivered to a customer by the Company on any day may be offset by volumes of gas delivered to the Company for the customer's account, after adjustment for line losses, in excess of the volume of gas taken by the customer from the Company on subsequent days within the same billing month. (I) Indicates Increase I Issued:,,, }}\pril 3, 213 Effective: May 11 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Supplement No. 14 r,~ to Gas - Pa. P.U.C. No. 9 Revised Page No. 147 Revised Page No. 147 ~seventh RIDER A SECTION 137(F) PURCHASED GAS COSTS PROVISION FOR RECOVERY OF PURCHASED GAS COSTS Rates for each Mcf (1, cubic feet) of gas supplied under Residential, Low Income Residential Assistance Service, Commercial and Public Authority, Commercial and Public Authority Load Balancing Service ("LBS"), Small Volume Industrial, Intermediate Volume Industrial, Intermediate Volume Industrial LBS, Large Industrial, Large Industrial LBS, Large Volume Industrial, Large Volume Industrial LBS and Natural Gas Vehicle Service rate schedules of this tar iff, shall include $ _1-3. -G-2]_5_-±-6- per Mcf for recovery of purchased gas (I) commodity costs, calculated in the manner set forth below, pursuant to Section 137(f) of the Public Utility Code. Rates for each Mcf (1, cubic feet) of gas supplied under Residential, Commercial and Public Authority, Small Volume Industrial Service, Intermediate Volume Industrial, Large Volume Industrial Service, Large Industrial Service and Standby Service rate schedules of this tariff, shall include $1. -~..?..5?..Q.%-+4 per Mcf for recovery of purchased gas demand costs, calculated in the manner set forth below, pursuant to Section 137(f) of the Public Utility Code. Rates for each Mcf (1, cubic feet) of gas transported under the Small Aggregation Transportation Customer Rate Schedule shall include $. 2~..?..-6-6- per Mcf for the recovery of purchased gas demand costs. (D) (D) Such rates for gas service shall be increased or decreased, from time to time, as provided by Section 137(f) of the Public Utility Code and the Commission's regulations, to reflect changes in the level of purchased gas costs. The amounts per Mcf for recovery of purchased gas costs (commodity and demand) included in rates under each rate schedule of the tariff are as follows: Residential Low Income Residential Assistance Service Commercial/Public Authority Small Volume Idustrial Intermediate Volume Industrial Large Volume Industrial Large Industrial Distribution Total Charges $5. -~--:-~.. ~>.-2- $. 238-G 4-. -GO Fifty- $5.999-2- 4-. $5.999-2- 4-. $5.. ~J... '!.}-2-4-. $5 2-~_2-2- 4-. $5.999-2- 4-. $ 5. :~--~--~--2-4-. $.238-6- -GO $.238-G -GO $.238-G -GO $.238-6- -6- $.238-G -6- $. 2}~.-6- -6- Gas Adjustment Charge ( $. 1}.?.. ~ +.-3-.3) ( $. J... t?.. ~.+ --3-3) ( $. )....J:...?.J:.+.-3--3) ($.1181+.-3-.3) ( $. JJ..?... ~.+ --3-3) Natural Gas Supply Charge $5.8791~ $5._ 7.~J~ $5.8791~ $5.?3791~ $5. 87_~..1.~ Standby $..?...?... 4...~. (_~B) ~ Priority Standby $.J..:_-G-. 1 (_!_B) 2 -=t-±-=7-± Small Aggregation Transportation (I) (I) (I) (I) (I) (I) (I)

I Customer Rate Schedule $.23E-6-6 $.23f3-6 -6 (B) (I) Indicates Increase (D) Indicates Decrease Issued: _.,. / :.: ~]\pril 3, 213 Ef feet i ve:!\lj');~ s ::Ma-y 1, 2 13

NATIONAL FUEL GAS Supplement No. i-9-5 to DISTRIBUTION CORPORATION Gas - Pa. P. U. C. No. 9 h8eeond Revised Page No. 148 Canceling ;:;(>,>:JtciOriginal and '!'hi. c::l-f-i-r-s-t Revised Page No. 14 8 COMPUTATION OF PURCHASED GAS COMMODITY COSTS PER MCF INCLUDED IN NATURAL GAS SUPPLY CHARGES Purchased gas commodity costs, per Mcf, shall be computed to the nearest one-hundredth cent (.1 ) in accordance with the formula set forth below: PGCC = cc ) (S) Purchased gas commodity costs, so computed, shall be included in Natural Gas Supply Charge rates charged to customers for gas service under the Residential, Commercial and Public Authority, Commercial and Public Authority Load Balancing Service ("LBS"), Small Volume Industrial, Intermediate Volume Industrial, Intermediate Volume Industrial LBS, Large Industrial, Large, Industrial LBS, Large Volume Industrial and Large Volume Industrial LBS Service rate schedules for an initial period determined by the Commission and for consecutive twelve month periods beginning August 1 of each year thereafter, unless such period is revised by the Commission. The amount of purchased gas commodity costs, per Mcf, will vary, if appropriate, based upon annual filings, by the Company, pursuant to Section 137(f) of the Public Utility Code and such supplemental filings as may be required or be appropriate under Section 137(f) or the Commission's regulations adopted pursuant thereto. In computing purchased gas commodity costs, per Mcf, pursuant to the formula, above, the following definitions shall apply: "PGCC" - purchased gas commodity costs determined to the nearest onehundredth cent (.1 ) to be included in rates for each Mcf of gas supplied under Residential, Low Income Residential Assistance Service, Commercial and Public Authority, Commercial and Public Authority Load Balancing Service ("LBS"), Small Volume Industrial, Intermediate Volume Industrial, Intermediate Volume Industrial LBS, Large Industrial, Large Industrial LBS, Large Volume Industrial, Large Volume Industrial LBS and Natural Gas Vehicle Service rate schedules of this tariff. "CC" - the estimated current commodity cost of gas including all associated hedging costs and deferrals, shall be determined as follows: (a) for all type of purchased gas, project the commodity cost for each purchase (adjusted for net current gas stored) for the projected period when rates will be in effect plus (b) the arithmetical sum of (1) the projected book value of noncurrent gas at the beginning of the computation year minus (2) the projected book value of noncurrent gas at the end of the computation year. This factor shall include no amount for purchased gas demand or winter requirement charges of an interstate pipeline company. (C) Indicates Change Issued: July 31, 2 ;{f-9 Effective: August 1, 2; ;-G-9

Supplement No. ';f:r!- to Gas - Pa. P.U.C. No. 9 NATIONAL FUEL GAS 'hsecond Revised Page No. 149 DISTRIBUTION CORPORATIONCanceling ~>:: >:~n:ioriginal and t.:lf±-r-5-t:- Revised Page No. 14 9 "S" - projected Mcf of gas to be billed to customers under the commodity charges of the Residential, Commercial and Public Authority, Commercial and Public Authority Load Balancing Service ("LBS"), Small Volume Industrial, Intermediate Volume Industrial, Intermediate Volume Industrial LBS, Large Industrial, Large Industrial LBS, Large Volume Industrial and Large Volume Industrial LBS Service rate schedules of this tariff during the period when rates will be in effect. COMPUTATION OF PURCHASED GAS DEMAND COSTS PER MCF OF GAS INCLUDED IN NATURAL GAS SUPPLY CHARGES UNDER THE RESIDENTIAL, COMMERCIAL AND PUBLIC AUTHORITY, SMALL VOLUME INDUSTRIAL, INTERMEDIATE VOLUME INDUSTRIAL, LARGE VOLUME INDUSTRIAL, LARGE INDUSTRIAL AND STANDBY SERVICE RATE SCHEDULES Purchased gas demand costs, per Mcf, to be included in Natural Gas Supply Charge rates under Residential, Commercial and Public Authority, Small Volume Industrial, Intermediate Volume Industrial, Large Volume Industrial, Large Industrial and Standby rate schedules shall be computed to the nearest onehundredth cent (.1c), in accordance with the formula set forth below: PGDC = ( (DC) ) ( ( S - ( SBS) ) Purchased gas demand costs, so computed, shall be included in the rates charged to customers for gas service, pursuant to the Residential, Commercial and Public Authority, Small Volume Industrial Service, Intermediate Volume Industrial Service, Large Volume Industrial Service, Large Industrial Service and Standby Service rate schedules, for an initial period determined by the Commission and for consecutive twelve-month periods beginning August 1 of each year thereafter unless such period is revised by the Commission. The amount of purchased gas demand costs, per Mcf, will vary, if appropriate, based upon annual filings, by the Company, pursuant to Section 137(f) of the Public Utility Code and such supplemental filings as may be required or be appropriate under Section 137(f) or the Commission's regulations adopted pursuant thereto. In computing purchased gas demand costs, per Mcf, pursuant to the formula, above, the following definitions shall apply: "PGDC" - purchased gas demand costs determined to the nearest onehundredth cent (.1c) to be included in rates for each Mcf of gas supplied under Residential, Commercial and Public Authority, Small Volume Industrial Service, Intermediate Volume Industrial Service, Large Volume Industrial Service, Large Industrial Service and Standby Service rate schedules of this tariff. "DC" - the estimated current demand cost of gas, determined by projecting, for all types of purchased gas, the total demand and winterrequirement charges from any interstate pipeline company or any other source of gas supply purchased by the Company for the projected period when rates will be in effect less projected current purchased gas demand cost revenue recovered through Distribution charges. I Issued: :.':' y...:...'.. L...,,... ~December 29, 26 Effective: ''--' :t.. '' }L}January 1, 27

NATIONAL FUEL GAS DISTRIBUTION CORPORATIONCanceling ",-- Supplement No. 1 '>3~ to Gas - Pa. P.U.C. No. 9,,, :Fourth revised Page No. 15 '~i:second and _;-;~ Revised Page No. 15 "S" - projected Mcf to be billed to customers during the projected period under the Residential, Commercial and Public Authority, Small Volume Industrial, Intermediate Volume Industrial, Large Industrial and Large Volume Industrial Service rate schedules. "SBS" - projected Mcf volume to be billed to customers during the projected period under the Standby Service rate schedule. COMPUTATION OF PURCHASED GAS DEMAND COSTS PER MCF OF GAS INCLUDED IN THE DISTRIBUTION CHARGES UNDER THE SALES RATE SCHEDULES AND THE RATE SCHEDULE SMALL AGGREGATION TRANSPORTATION CUSTOMER SERVICE Purchased gas demand costs transportation, per Mcf, to be included in Distribution Charges under the Residential, Commercial and Public Authority, Small Volume Industrial, Intermediate Volume Industrial, Large Industrial and Large Volume Industrial Service rate schedules and the Rate Schedule Small Aggregation Transportation Customer Service shall be computed to the nearest one-hundredth cent (.1c), in accordance with the formula set forth below: PGDCT (OCT + DEDC) (S + SATCV) - (SBS) "PGDCTu - Purchased gas demand costs transportation, per Mcf, to be included in Distribution Charges under the Residential, Commercial and Public Authority, Small Volume Industrial, Intermediate Volume Industrial, Large Industrial and Large Volume Industrial Service rate schedules and the Rate Schedule Small Aggregation Transportation Customer Service. "OCT" - the estimated current demand cost of gas, determined by projecting, for all types of demand purchased gas capacity costs included in the Distribution Charges for Sales Service Rate Schedules and the Small Aggregation Transportation Customer Service Rates, the total usage, demand and winter-requirement charges from any interstate pipeline company or any other source of gas supply purchased by the Company for the projected period when rates will be in effect. "DEDC" - experienced net overcollection or undercollection of purchased gas demand costs included in the Distribution Charges. Such experienced net overcollection or undercollection shall be determined for the most recent period permitted under law which shall begin with the month following the last month which was included in the previous over-under collection calculation reflected in rates. The annual filing date shall be the date specified by the Company's Section 137(f) tariff filing and not the date established by the Commission for prefiling of certain information pursuant to 52 Pa. Code Sections 53.64(b) (1) and 53.65. Supplier demand refunds received for capacity associated with the SATS capacity release provisions will be included in the calculation of the "DEDC" with interest added at the annual rate of six percent (6%) calculated from the month received to the effective month such refund is refunded. All other Supplier demand refunds received will be included in the calculation of the "DEn with interest added at the annual rate of six percent (6%) calculated from the month received to the effective month such refund is refunded. I Issued: July 31, 213~ Effective: August 1, 213~

Supplement No. ',-6+ to Gas - Pa. P.U.C. No. 9 NATIONAL FUEL GAS ~hseeond Revised Page No. 152 DISTRIBUTION CORPORATIONCanceling ~:;e >.~ndoriginal and c ~5-Fi-r-s-.:t::- Revised Page No. 152 The annual filing date shall be the date specified by the Company's Section 137(f) tariff filing and not the date established by the Commission for pre-filing of certain information pursuant to 52 Pa. Code Sections 53. 6 4 (b) ( 1) and 53. 6 5. Supplier commodity refunds received will be included in the calculation of "CE" with interest added at the annual rate of six percent (6%) calculated from the month received to the effective month such refund is refunded. Supplier conm~dity refunds will be included in the next quarterly filing after red~nds are received pursuant to Case R-213-2341534. C "DE" - experienced net overcollection or undercollection of purchased gas demand costs. For the initial filing, pursuant to 137(f) of the Public Utility Code, in order to achieve an orderly transition from Gas Cost Rate procedures to Section 137(f) procedures, such experienced net overcollection or undercollection, to be reflected in rates effective September 1, 1985, shall be the net overcollection or undercollection arising under the Gas Cost Rate procedure. The amount of such net overcollection or undercollection shall include the historic net amount as of March 31, 1985 together with the projected net overcollection or undercollection for the five-month period ending August 31, 1985. After the transition from the Gas Cost Rate procedures, established pursuant to the Commission's order of October 1, 1978 at M-78555, (52 Pa P.U.C. 217) as amended, to procedures established pursuant to Section 137(f) of the Public Utility Code, such experienced net overcollection or undercollection shall be determined for the most recent period permitted under law which shall begin with the month following the last month which was included in the previous over-under collection calculation reflected in rates. The annual filing date shall be the date specified by the Company's Section 137(f) tariff filing and not the date established by the Commission for pre-filing of certain information pursuant to 52 Pa. Code Sections 53.64(b)(1) and 53.65. Supplier demand refunds received will be included in the calculation of "DE" with interest added at the annual rate of six percent (6%) calculated from the month received to the effective month such refund is refunded. Suoplier demand refunds will be included in the next quarterly filing after refunds are received pursuant to Case R-213-2341534. "Sl" - projected Mcf of gas to be billed to customers under the natural gas supply charges of the Residential, Commercial and Public Authority, Commercial and Public Authority Load Balancing Service ("LBS"), Small Volume Industrial, Intermediate Volume Industrial, Intermediate Volume Industrial LBS, Large Industrial, Large Industrial LBS, Large Volume Industrial and Large Volume Industrial LBS Service rate schedules of this tariff during the period when rates will be in effect. For a period of twelve months sales volumes associated with former SATC customers returning to sales service shall be excluded from the projected Mcf used in this calculation. "SATCVl" - Projected customer volume to be transported for the first twelve months of transportation service to former sales customers during the projected period under the Small Aggregation Transportation Rate Schedule. (C) Indicates Change Issued: ~.!..~-~~--- -~----... -~ 1,?J 1 3Deeember 29, 26 Effective: vl3january 1, 27

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Supplement No. : -9- - to Gas - Pa. P.U.C. No. 9 ': :Seventh Revised Page No. 155 ;)'>''<'.'ntt:f-:i:4-t-fi and --.-.ul >,&:i:-:x-t-fi Revised Page No. 155 (9) An amount determined by multiplying volumes billed under the Small Aggregation Transportation Service rate schedule times the PGDCT charge recovered through rates under rate schedule Small Aggregation Transportation Customer Service. (1) An amount equal to the revenues from Daily Metered Transportation customers produced by charges for overdeliveries of transportation gas to such customers. (11) An amount equal to 75% of the revenues generated from the release of pipeline transmission and storage capacity other than releases for SATS customers. The Company shall retain the remaining 25%. (12) An amount equal to 75% of the savings from gas storage fill contracts as established in Case R-16789. The Company shall retain the remaining 25%. (13) An amount equal to 75% of asset management arrangements under FERC Order 712 for capacity releases associated with identified capacity contracts. The Company shall retain the remaining 25%. Interest shall be computed monthly at the appropriate rate provided for in Section 137(f) (5) of the Public Utility Code from the month that the over or under-collection occurs to the effective month such over-undercollection is refunded or recouped as appropriate. QUARTERLY UPDATES The Company's rates for recovery of purchased gas costs will be subject to quarterly adjustments under procedures set forth in the Commission's regulations at 52.Pa. Code 53.64(i) (5). Such updates will reflect, in addition to data specified in the regulation, changes in the projected commodity cost of purchased gas based upon the NYMEX source of data and method used in projecting the commodity cost of purchased gas approved by the Commission in the Company's most recent annual proceeding for recovery of purchased gas costs under Section 137(f) of the Public Utility Code. In a~iition, the Company will calculate rates in the November, February and May quarterly filings using remaining monthly sales volumes to detennine the purchased gas cost rates. The projected remaining monthly sales volwnes used in the February quarterly filinq will also be used in the May quarterly filing. rrhe rat(; ch.anqc: v.;ill be no more than 2:) -; 'or JJ1e _I'a_te usinq t:he prior rr~thodoloqy of twelve months of sales volumes as allowed at Docket R-213-234l~l34. T l (C) Indicates Change Issued: July 31, 2.~G--9- Effective: August 1, 2 <G--9-

NATIONAL FUEL GAS Supplement No. 14'~-3- to DISTRIBUTION CORPORATION Gas - Pa. P.U.C. No. 9 _5~Fortieth Revised Page No. 157 Canceling Thirty-NinthEighth and fort h Revised Page No. 157 RIDER B STATE TAX ADJUSTMENT SURCHARGE In addition to the charges provided in this tariff, a surcharge of (..1:... ~~%) will apply to all charges for service rendered on or after!\.t:.1.9_1.. l...::.>:t:}4a-y (I) 1, 213. The above surcharge will be recomputed using the same elements prescribed by the Commission. a. Whenever any of the tax rates used in calculation of the surcharge are changed; b. Whenever the utility makes effective any increased or decreased rates, and c. On March 31, 1971, and each year thereafter. The above recalculation will be submitted to the Commission within ten (1) days after the occurrence of the event or date which occasions such recomputation; and, if the recomputed surcharge is less than the one in effect, the Company will, and if the recomputed surcharge is more than the one then in effect, the Company may submit with such recomputation a tariff or supplement to reflect such recomputed surcharge, the effective date of which shall be ten (1) days after filing. (I) Indicates Increase Issued:.. ).. _}JAp r i 1 3, 2 13 Effective: ;.::,'L~!:.. u _t:~may 1, 213 2

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Sixty- Sixty- Supplement No. 1454 to Gas - Pa. P.U.C. No. 9 hseventh Revised Page No. 164 Revised Page No. 164 RIDER F LIRA DISCOUNT CHARGE CURRENT LIRA RATE DISCOUNT Effective April 1, 22, a charge will be included in the rates subject to this Rider to provide for recovery of costs of the projected LIRA rate discounts for the upcoming 12 months. Such charge shall be updated quarterly and effective each February 1, May 1, August 1, and November 1 of the year. The charge will also be updated whenever there is a change to the Residential Sales Service Rate Customer Charge, Distribution Charge, Natural Gas Supply Charge, or Gas Adjustment Charge. APPLICABILITY In addition to the charges provided in this tariff, a charge calculated in the manner explained below shall be added to the otherwise applicable charge for each Mcf of sales and transportation volumes delivered by the Company to customers receiving service under the Residential Sales Service Rate Schedule and the Residential rates of the SATC, MMT, and DMT transportation rate schedules. CALCULATION OF RATE The charge will be recalculated as specified above. The charge shall be equal to the total annual projected discounts for LIRA customers for the upcoming 12 month period divided by the annual normalized throughput volumes of the qualified rate classes. The total annual projected discounts for the LIRA customers for the upcoming 12 month period shall equal the sum of the individual monthly total projected discounts for LIRA customers for the upcoming 12 months. The total monthly projected discounts for LIRA customers shall equal the residential bill for the average LIRA customer consumption for the month multiplied by the average discount percentage for LIRA service multiplied by the projected number of LIRA customers for the month. The currently effective charge for the current LIRA Rate Discount to be included in rates is $. 32..?_/Mcf. (I) (I) Indicates Increase Issued: yma-y 31, 213 Effective: J.tme 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Supplement No. 1454 to Gas - Pa. P.U.C. No. 9 Thirty-,:><> '"'-1~ Revised Page No. 167 rs' Revised Page No. 167 RIDER F LIRA DISCOUNT CHARGE CAP FUNDING RECONCILIATION CHARGE (can't) CALCULATION OF RECONCILATION COMPONENT OF RATE (can't) The charge associated with the incremental customer credit will contain the following calculation: Effective February 1, 29 and thereafter, an annual credit of $35 per customer will be provided associated with the LIRA incremental customers. The credit will be based on the average number of LIRA customers billed during the previous fiscal period (October- September) less 11,411. The annual credit will continue until new base rates become effective as a result of a general rate proceeding. If the average number of LIRA customers billed during the previous fiscal period is 11,411 or less, the credit will be $. The CAP Funding Reconciliation Charge will be the summation of the charges calculated above divided by the projected February 1 through January 31 volumes. CAP Funding Reconciliation Charge Calculation LIRA Rate Discount $(296,63) + LIRA Program Costs $54,292 + LIRA Forgiven Pre-Program Arrear ages $(363,369) + LIRA Incremental Customer Credit $(14,875) Equals Total $(62,555) Divided by Projected Feb - Jan Volumes 16l591l55 Me Cap Funding Reconciliation Charge I Me $(.374)/ Mcf ADJUSTMENT FOR OVER / UNDER RECOVERY OF PRIOR PERIOD CHARGE The filing to be effective February 1, 21 and every February 1 thereafter shall include a levelized rate for over/under collections for the prior (12) month period by comparing projected revenues under this Rider to actual revenue amounts experienced. The annual reconciliation shall be based upon actual revenues through December 31 and estimated revenues for January. Estimates for January shall be included in the following reconciliation period. The rate will be designed to recover or refund the applicable under or over recovery over the twelve (12) month period beginning February. RIDER F LIRA Discount Charge Component $/Mcf Current LIRA Rate Discount $.838-G-9- Cap Funding Reconciliation Charge $(.374) Adjustment for Over/Under Recovery of Prior Period Charge $(.135) Total RIDER F $.329 The currently effective charge to be included in rates is $.329~/Mcf. (I) (I) (I) (D) Indicates Decrease (I) Indicates Increase Issued:.:'.J:yMay 31, 213 Effective: ",;;u:;.j-th:te 1, 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling Supplement No. 145~ to Gas - Pa. P.U.C. No. 9 ''Sixteenth Revised Page No. 168 Revised Page No. 168 Rider G Merchant Function Charge (MFC) Rider Applicability: The Merchant Function Charge (MFC) shall be added to the Natural Gas Supply Charge and Gas Adjustment Charge of Residential, LIRAS, Commercial and Public Authority, SVIS, IVIS, LVIS and LIS rate schedules. Such charges shall be updated quarterly and effective each February 1, May 1, August 1, and November 1 of the year. The charge will also be updated whenever there is a change to the Sales Service Rate Customer Charge, Distribution Charge, Natural Gas Supply Charge or Gas Adjustment Charge. Calculation of Rate: For customers receiving service in the Residential classification, the MFC shall equal 2.231% times the Natural Gas Supply Charge and the Gas Adjustment Clause as calculated for Rider A. The current Residential MFC Charge is: Natural Gas Supply Charge per Mcf Gas Adjustment clause (E-Factor) per Mcf Total Residential MFC per Mcf $.1278 ($.168) $.111 (I) (D) (I) For customers receiving service in the Non-Residential classifications, the MFC shall equal.2285% times the Natural Gas Supply Charge and Gas Adjustment Clause as calculated for Rider A. The current Non-Residential MFC Charge is: Natural Gas Supply Charge per Mcf Gas Adjustment clause (E-Factor) per Mcf Total Non-Residential MFC per Mcf $.131 ($.17) $.114 (I) (I) (I) Indicates Increase (D) Indicates Decrease Issued: Effective: May 11 213

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Canceling First and Supplement No. 1454 to Gas - Pa. P.U.C. No. 9!;~ Revised Page No. 169 iseeond Revised Page No. 169 Rider H Gas Procurement Charge (GPC) APPLICABILITY Effective June 1, 213, the Gas Procurement Charge will be included in the Natural Gas Supply Charge of Residential, LIRAS, Commercial and Public Authority, SVIS, IVIS, LVIS and LIS rate schedules. The charge is designed to recover the costs of procuring natural gas pursuant to 52 Pa. Code 62.223. The natural gas procurement costs included in the GPC charge will only be updated in a base rate case. The GPC to be included in the Natural Gas Supply Charge shall be $.15 I Mcf and is not reconcilable. Price To Compare Component Natural Gas Supply Charge Purchased Gas Cost Component (Rider A) Merchant Function Charge associated with Natural Gas Supply Charge(Rider G) Gas Procurement Charge (Rider H) Subtotal Natural Gas Supply Charge Gas Adjustment Charge Purchased Gas Cost Component (Rider A) Merchant Function Charge associated with Gas Adjustment Charge (Rider G) Subtotal Gas Adjustment Charge Total Price To Compare Residential ( per 1 cubic feet) 58-=t-.791-3-2--3 1.311~ 1.5 61. -9.. 1-652-l- Non Residential ( per 1 cubic feet) 58-=t-. 791-3-ti (.2-l-6-8-) ( 1.-=t- ~ -=t- 2-±-) _2 9-±- 9 4 5-8-.135-l- 1.5 5 9-8-. 9 7 6. -8.4- (.3H) (1:_-=t-. 184. - -8-) _2 f.}._.g. 7...2.?... -&4- (I) (D) Indicates Decrease (I) Indicates Increase Issued:, )ym-ay 31, 213 Effective: (C) Indicates Change

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Summary of Cost of Gas by Gas Supplier and Transmission of Gas by Local Producers Twelve Months Ended November 212 Supplier Projected Quantity Purchased Mcf Commodity. Demand Cost Demand Cost Cost Natural Gas Supply Distribution Charge $ $ $ Total Projected Cost $ Upstream Purchases Storage Transportation Transportation Credit Local Production T. W. Phillips Exchange Gas Off-System Sales 16,925,958 55,768,855 199,982 63,463 3,254,8 11,429,769 342,458 22,459,176 6,113,447 (1 '72,54) 3,288,655. 9,588,784 1,188 17,948 1,416 (44, 15) (3,223,872) (8,55,279) 55,968,837 14,683,849 28,915,81 (1,72,54} 9,588,784 17,948 (44, 15) (8,55,279) Off-System Sales Refund (521,889) (5g1,_ 8_ID Subtotal Credit Line Hits Total 17,596,88 59,9,86 32,368,872 6,113,447 98,383,126 (13,852) 98,369,274 ccncn-u -o :::T (") G) g.m~o ~=~~ "- <D :::T ~g <D... r\) ~ u:>

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Summary of Cost of Gas by Gas Supplier Twelve Months Ended November 212 Projected Total Quantity Commodity Demand Projected Sugglier Purchased Cost Cost Cost Mcf $ $ $ Upstream December 211 1,595,13 6,495,626 42,959 6,538,585 January 212 2,628,244 9,346,216 42,995 9,389,211 - February 1,939,83 6,669,282 42,63 6,711,912 March 1,15,568 3,781,897 39,48 3,821,377 April 1,88,173 4,335,37 4,335,37 May 1,176,415 2,97,425 2,97,425 June 1,125,15 3,9,811 3,9,811 July 489,959 1,953,925 1,953,925 August 98,96 3,18,312 3,18,312 September 1,56,958 4,755,357 4,755,357 October 1,6,335 3,437,335 3,437,335 November 1,59,425 5,752,362 - :31_!9j f!_ 5,784,28 Total 16,925,958 55,768,855 199,982 59.966,63]_ CCJ>CJ>IJ "' ::T G) ~m~o... ~... c.. m!1? N x c... CD::T c... o= :J ;::;: CD... N ~ c.j

--=-----'l'l====-=.i""'-~--==- ------"'~tt-.,..~==,=---~ -~ -u=======-:r~-- - ----~~--~==-~:..::-===-'-'"-_,j_==~-=====-~='o"""""':;,:::::::-=~~~-~"'-"==.::-..:.~::.=::::..,.. - = =--== = -= "============ NATIONAL FUEL GAS DISTRIBUTION CORPORATION Penn~ylvania Division Summary of Cost of Gas by Gas Supplier Twelve Months Ended November 212 Total Total Quantity Commodity Projected Supplier Purchased Cost Cost Local Production Mcf $ $ December 211 298,767 1,72,547 1,72,547 January 212 298,369 985,916 985,916 February 275,81 773,13 773,13 March 298,66 77,719 77,719 April 291,526 665,679 665,679 May 27,451 584,184 584,184 June 22,985 565,444 565,444 July 332,451 94,588 94,588 Augus_t 325,873 1,3,265 1,3,265 September 95,365 25,356 25,356 October 288,225 897,175 897,175 ccncn-u "O:::TOG) November 292,182 1,52,88 1,52,88 ~~~ Total 3,288,655 9,588,784 9,588,784 ~~~~ '- Cll:::T c:...&.: ::J ;:::;: Cll... I\) ~ w

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Summarv of Transportation Credits Twelve Months Ended November 212 211 December 212 Januarv f_!3br~arv_ Me1rch_ April Mav June Julv August September October November Total MMTVolume Rate$/Mcf Transportation Credit - $ 941,842 1,65,572 913,142 653,666 559,941 311,14 278,173 283,757 352,243 388,989 529,65 834,269 7,112,384.23.23.23.23.23.23.23.23.27.27.27.27 (216,624) (245,82) (21,23) (15,343) (128.786) (71,562) (63,98) (65.264) (95,16) (15,27) (143,6) (225,253) (1,72,54) C(I)(I)"U -c::tog)!i}ali5o ~:;~~ c... (1) ::T ~ ~g 1\) s (..)

... --. - - --------... - """==-.. =-= == ~ =-~==r--,.---,..,.,.,_...,...,.,,t-.... -... --..._,~ -~--, - ---~-,-~-~---------- --- - NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Summary of Credit Due to Line Hits Twelve Months Ended November 212 211 December January February 212 March April May June July AUQUSt September October November Total Line Hits (Credit) Amount - $ 7,537 873 8 19 589 673 224 1,18. 1.421 165 5 735 13,852 ccncn-o "O :::T n (j) g-~~,...-+a.m ~1 x c_ <D ::::T -'-!2: <D... 1\) ~ w

-- -~= -""' =- =--=--=== ---.1.. - ~ - -.. - - - -- - -... - -- -- -.!... _., --.. - """"'.''- ' '... - ~--- -- - - -~. - ----~---- --.. -~ - - c.- -z -- -- "...,. NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Summary of Exchanqe Gas Twelve Months Ended November 212 211 December January February 212 March April May June July AUQUSt September October November Total Exchange Gas - Mcf 12,7 9,126 13,585 1,285 149,46) 8.421 7,26 (5,397) 1512) (2,656) (L299) _ J161l 1A16 Commodity - $ 4,68 45,61 1,947 41,76 (183,29) (93,3) 65,637 (9,262) (962) 38,71 (24,65) 23,988 (44,15) ccncn-o "O::J'"OG) g.m~o ~~~!Jl C- CD ::::r ~ ~g 1\:) ~ (,)

Pennsylvania Division Summary of Off-System Safes Twelve Months Ended November 212 211 December January February March 212 April May June July AUQUSt September October November Total Off-System Safes Mcf (53,523) (1,185.489) (837,546) (419,15) (251,164) (3,223,872) Off-System Safes (Gas Cost) $ (1,654,169) (3,49,58) (2,72,282) (853,493) (875,827) (8,55,279) CCilCil<J "' :::; C) G) g.m~o... o.m ~-...l x c... <D :::; ~ -Lg 1\) ~ (.)

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Summary of Off-System Sales Refund Twelve Months Ended November 212 211 December January Februarv 212 March April May June July Auoust September October November Total Oft-System Sales MarQin - $ (113,416) (282,498) (157,655) (95,8) (47,274) (695,851) Oft-System Sales Refund (75%)- $ Prior Period Adjustment Net Off-System Sales Refund - $ (85,62) (211,874) (118,241) (71,256) (35,456) (521,889) (85,62} (211,874) (118,241) (71,256) (35,456} (521,889} ccncnij " :::T () (j) g-~~ --a.m ~CXl x c._ CD :::T ~ _.g 1\) ~ w

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Details of Upstream Purchases Twelve Months Ended November 212 211 December January February 212 March Aim! Mgy June JyJy Auaust September October November Total Purchase Volume: Mcf Spot Contracted Shrinkage Total (Met) 81,591 1,158,319 875,99 482,912 1,853,452 1,27,479 1,147,85 667,85 1,1,122 1,586,333 1,27,424 1,252,277 13,61,69 838,628 1,524,794 1,17,547 65,336 (66) 28,374 4,41,73 (45,26) (54,869) (4~._734) (27,68)_ (44,673) (31,64) (21,98) (177,126) (2,162) (25,375) (21,89) (23,226) (536, 184) 1,_595,913 -- 2,~8.~4 1J}39,83 1,"1 5,568 1,88,173 u 76,415 1,125,15 489,959 98,96 1,56,958 1,6,335 1,59,425 16,925,958 Demand Costs - $ Spot Contracted 42,959 42,995 42,63 39,48 31,918 199,982 Total Demand Costs-$ 42,959 42,995 42,63 39,48 31,918 199,982 Commodity Costs - $ Spot Contracted Total Commodity Costs-$ 2,845,636 3,425,855 2,484.731 1,155.392 4,335,37 2,97,425 3,9,811 1,953,925 3,18,312 4, 755,357 3,437,335 4,876,722 38,511,88 3,649,99 5,92,361 4,184,551 2,626,55 875,64 17,257.47 6,495,626 9,346,216 6,669,282 3, 781,897 4,335,37 2.97,425 3,9,811 1,953,925 3,18,312 4, 755,357 3,437,335 5,752,362 55,768,855 Total Cost-$ 6,538,585 9,389,211 6. 711,912 3,821,377 4,335,37 2,97,425 3,9.811 1.953.925 3.18.312 4, 755,357 3,437,335 5, 784,28 55,968,837 ccncn-u " :::r (') G) g-~aro ~= :~ c_ CD :::r ~ 1\)g 1\) ~ c.u

--=~=~=,~~~ L===.-======,c =c ~~ - ===' ~o~===== -~= -~,==~ == "-'=c o.,~=--== = = - ' '=== - =c. == = ="ti'"'=== ~~=~= ~ ==''-'' " - = =="=.-.-.c= = =~-="~'=' ''="'='''= ~ - ~ _..,,ic~~- d.c.'="cc.c========== NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Details of Storaqe Twelve Months Ended November 212 Rental Demand-$ Commodity - $ Total 211 December Januarv Februarv 212 March 8.rm! M y June ~ August September October November Total 84,645 84,278 839,487 838,87 839,641 837,649 967,43 899,499 898,52 896,845 894,949 892,511 1,485,792 7,289 22,472 27,982 24,279 16,3_18-11.461 _43,?34_ ~5.2_64_ 2~.638 39,241 53,389 25,449 332,16 847,934 862,75 867,469 863,86 855,959 849,11 1,1,664 934,763 923,69 936,86 948,338 917,96 1,817,88 Gas Costs Injection - Mcf Withdrawal - Mcf Net (lnjection)/withdrawal (89, 123) (17,339) (12,988) (151,242) (84,98) (731,262) (838,677) (847,91) (81,266) (956,71) (641,862) (73,354) (5,975,632) 1,378,757 1,695,925 1,486,412 749,387 14,219 41,42 1.341 7,488 42,446 26,715 237.928 798,435 6,579,95 1.289.634 1,678,586 1,473,424 598.145 (7.689) (69,22) (828,336) (84.422) (767,82) (929,986) (43,934) 725,81 63,463 Demand-$ Commodity - $ Total Storage Costs Demand-$ Commodity - $ 2,878,85 3,771,116 3,31,192 1,343,793 (1,62,551) (1,596,343) (1,915,776) (1,954,569) (1,785,719) (2,147,712) (831,13) 1,491,79 943,977 6,127.696 6,12.836 5,986,37 2.43,23 (4.991,893) (2,388,441) (2,866.374) (2,717,374) (2, 727.66) (3,468,248) (1,781,47) 3,197,825 2,922,64 9.6.546 9.891,952 9.296.562 3, 773,996 (6,612,444) (3,984, 784) (4, 782,15) (4,671,943) (4,512, 785) (5,615,96) (2,612,484) 4,689,534 3,866,4 3, 719,495 4,611,394 4,149,679 2,182,6 (78,91 ) (758,694) (948,346) (1,55,7) (887,667) (1,25,867) 63,936 2,384,22 11,429, 769 6,134,985 6,143,38 6,14,352 2,454,482 (4,975,575) (2,376,98) (2,823, 14) (2.682,11 ) (2, 71,428) (3,429,6) (1,728,81) 3,223,274 3,254,8 9,854,48 1,754,72 1,164,31 4,637,82 (5,756,485) (3,135,674) (3,771,486) (3,737,18) (3,589,96) (4,679,874) (1,664,145) 5,67,493 14,683,849 C(J)(J)IJ -o::::>og) ~~~ ~... c.m ~rv x c... < ::r rv!;!. CD.- I'V ~ (..)

-~-,.! ~- - --~--- -------- - -- -- -- -- ~- -- -------=~:c~---._.,_."''"" -~.---------.----..,------ -"- " --.. _ -- -- ----- ~ -r--,.,,,_.,.,, ""_!,.,,,, r -~ NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Detail of Costs Related tot. W. Phillips Twelve Months Ended November 212 211 December January February 212 March April May June ~ August September October November Total Mcf 279 294 261 83 9 2 3 23 153 1,188 Amount-$ 2,467 3,347 2,752 1,376 1,43 743 749 73 73 73 931 1,963 17,948 cw-u "COG) firi5o %~J;r c_cd::t w : CD... 1\) ~ (,.)

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Transportation Charges Twelve Months Ended November 212 Pennsylvania Division 211 December Januarv Februarv 212 March 8Q.d!.Mgy June J!!!Y August September October November Total Demand - Distribution Charge - $ Demand - Natural Gas Supply - $ Total Demand-$ Commodity - $ Total Costs - $ 521,144 521,8 521,669 521,669 467,148 53,87 53,697 53,697 512,384 512,384 512,384 512,384 6,113,447 1,47,996 1,897,782 1,925,551 1,919,648 1,981,658 1,752,12 2,48,34 1,94,733 1,89,675 1,837,853 1,897,182 1,932,746 22,459,176 1,992,14 2,418,862 2,447,22 2,441,317 2,448,86 2,255,819 2,552,37 2,48,43 2,43,59 2,35,237 2,49,566 2,445,13 28,572,623 48,831 72,959 29,693 24,886 29.342 17,893 1,692 6,988 11,392 17,344 19,629 52,89 342,458 2,4,971 2,491,821 2,476,913 2,466,23 2,478,148 2,273,712 2,562,729 2,415,418 2,414,451 2,367,581 2,429,195 2,497,939 28,915,81 C(f)""'' "'COG) g-$o ~~~ c_cd::::r ~2: CD,... 1\) VJ

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Temperature Swing/ Peaking Capacity Costs Twelve Months Ended November 212 211 212 December January Februarv March 8mil Mgy June J!!!y August September October November Total NFGSC EFT Capacity (Dth} 59,26 59,26 59,26 59,26 59,26 59,26 59,26 Rate ($/Dth} 3.5545 3.5534 3.5534 3.5534 3.5534 3.9617 3.9617 Amount($} 21,448 21,383 21,383 21,383 21,383 234,556 234,556 59,26 62,228 62,228 62,228 3.9617 3.9617 3.9617 3.9617 234,556 246,529 246,529 246,529 62,228 3.9617 246,529 2,741,764 NFGSC ESS Delivery (Dth} 3,381 3,381 3,381 3,381 3,381 3,381 3,381 Rate ($/Dth} 2.1345 2.1345 2.1345 2.1345 2.1345 2.5959 2.5959 Amount($) 64,848 64,848 64,848 64,848 64,848 78,866 78,866 3,381 51,562 51,562 51,562 2.5959 2.5959 2.5959 2.5959 78,866 133,85 133,85 133,85 51,562 2.5959 133,85 1,96,238 NFGSC ESS Capacity (Dth} 1,427,97 1,427,97 1,427,97 1,427,97 1,427,97 1,427,97 1,427,97 Rate ($/Dth}.432.432.432.432.432.44.44 Amount($} 61,686 61,686 61,686 61,686 61,686 57,687 57,687 1,427,97 2,423.414 2,423,414 2,423,414.44.44.44.44 57,687 97,96 97,96 97,96 2,423,414.44 97,96 873,115 NFGSC FSS Capacity (Dth} 1,666 1,666 1,666 1,666 1,666 1,666 1,666 Rate ($/Dth} 2.1556 2.1556 2.1556 2.1556 2.1556 2.4826 2.4826 Amount($} 22,992 22,992 22,992 22,992 22,992 26,479 26,479 1,666 1,666 1,666 1,666 2.4826 2.4826 2.4826 2.4826 26,479 26,479 26,479 26,479 1,666 2.4826 26,479 3,313 NFGSC FSS Capacity (Dth} 2, 2, 2, 2, 2, 2, 2, Rate ($/Dth}.432.432.432.432.432.381.381 Amount($) 8,64 8,64 8,64 8,64 8,64 7,62 7,62 2, 2. 2, 2,.381.381.381.381 7,62 7,62 7,62 7,62 2,.381 7,62 96,54 Columbia Full Peak FSS (Dth} Demand 18,417 18,417 18,417 18,417 18,417 18,417 18,417 Rate ($/Dth) 1.55 1.55 1.59 1.59 1.59 1.59 1.59 Amount($) 27,718 27,718 27,791 27,791 27,791 27,791 27,791 18,417 1.59... 27,791. 222,182 Columbia Full Peak FSS (Dth} Capacity 564,31 564,31 564,31 564,31 564,31 564,31 564,31 Rate ($/Dth).289.289.289.289.289.289.289 Amount($) 16,3 16,3 16,3 16,3 16,3 16,3 16,3 564,31.289... 16,3. 13,4 Columbia Full Peak SST (Dth} Capacity 18,417 : 18,417 18,417 18,417 9,29 9,29 9,29 Rate ($/Dth} 5.892 ; 5.892 5.92 5.92 5.919 5.919 5.97 Amount($) 18,513 18,513 19,29 19,29 54,58 54,58 54,398 9,29 18,417 5.97... 54,398 18,417. 652,896 Grand Total Cost- Distribution Charge($) 521,144 521,8 521,669 521,669 467,148 53,87 53,697 53,697 512,384 512,384 512,384 512,384 6,113,448 C(f)""U "COG)!ir~O ~~~ c...<ll:::j" C112: (1) - "' ~ (,)

====--==-~ -~.,_=,...::= '' '===::.=:::::l~--- ----~-~ -~ -- o: -~ - - ~---- -~~--'~:.:...: ::..~:.o.::... :.J- - - ~--.-========= NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Summary of Cost of Gas by Gas Supplier and Transmission of Gas by Local Producers Eight Months Ended July 213 Projected Demand Cost Demand Cost Total Quantity Commodity Natural Gas Distribution Projected Supplier Purchased Cost Supply Charge Cost Mcf $ $ $ $ Upstream Purchases 11,496,84 52,814,75 2,168,756 512,415 55,495,876 Storage 9,857,82 11,495,47 21,352,867 Transportation 291,245 12,442,485 3,586,874 16,32,64 Transportation Credit (1,615,319) (1,615,319) Capacity Release (395,21 ) (395,21 ) Local Production 1,964,343 7,731,216 7,731,216 Exchange Gas 19,423 128,885 128,885 T. W. Phillips 78 11,349 11,349 Off-System Sales (1,767,833) (5,893,42} (5,893,42) Off-System Sales Refund (355,368) (355,368) Subtotal 11,713,445 64,586,449 24,95,759 4,99,289 92,781,497 Credit- Line Hits (6,952) Total 92,774,545 ccncn-u "O::::l"OG) ~ffi[o ~~s.!j' _.g c._ CD :::J" c :J CD ~ w ~

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Summary of Cost of Gas by Gas Supplier Eight Months Ended July 213 Projected Demand Cost Demand Cost Total Quantity Commodity Natural Gas Distribution Projected Supplier Purchased Cost Supply Charge Cost Mcf $ $ $ $ Upstrean1 December 212 1,792,273 6,96,35 32,752 6,939,12 January ~~13 2,37,42 7,635,436 32,268 7,667,74 February 1,432,715 5,268,379 31,412 5,299,791 March 1,74,95 7,13,82 32,644 7,46,464 April 1,66,38 7,489,139 (4) 7,489,134 May 1,412,974 6,215,46 6,215,46 June 1,86,27 4,843,735 (221) 4,843,514 July 37,182 7,442,386 2,39,96 512,415 9,994,77 Total 11,496,84 52,814,75 2,168,756 See Exhibit 23, Schedule 1 512,415 55,495,876 C(I)(I)"'U " ::T C"l G) ~mffio fir~~~ C... CD ::T ~g CD 1\) 1\) ~ Ul

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Summary of Cost of Gas by Gas Supplier Eight Months Ended July 213 Projected Total Quantity Commodity Projected Supplier Purchased Cost Cost Mcf $ $ Local Production December 212 287,395 1 '176,74 1 '176,74 January 213 293,411 1,42,981 1,42,981 February 268,996 915,38 915,38 March 294,56 1,79,567 1,79,567 April 263,13 1 '12,554 1,12,554 May 291,365 1,235,799 1,235,799 June 254,724 1 '118,767 1 '118,767 July 1,816 41,536 41,536 Total 1,964,343 7,731,216 7,731,216 See Exhibit 23, Schedule 2 ccncn-u " :::J" C'l Q g-~~ --a.m ~ w!:..x ~ CD :::J" c ~cr :::J ;:::;: CD I\) I\) (.,)

- - ~ -._,.,- --- ---- -d--.. - - - ~ - - -,o - oj - ~-,,_,-,,_=. -"O"'" --t--.. --.,. NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Summary of Transportation Credits Eight Months Ended July 213 212 December 213 January February March April.M y June ~ Total MMTVolume Rate $/Mcf Transportation Credit-$ 955,126.27 (257,884) 1,151,795 1,91,71 1,16,551 653,591.27.27.27.27 (31,985) (294,762) (274,469) (176,47) 457,517.27 (123,53) 336,993.27 (9,988) 319,381.27 (86,233) 5,982,664 (1,615,319) C(I)(I)'"U ""C :::; (") G) g-m~o r-+r-+a.m ~ ~.X C... CD :::; ~ _.g 1\) 1\) ~ "'

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Summary of Credit Due to Line Hits Eight Months Ended July 213 212 December 213 January February March April ~ June JlliY Total Line Hits (Credit) Amount - $ 1,142 192 575 1,862 22 227 1,716 1,18 6,952 F:\RARA\Common\V A _DATA\ 137f13\Update\Compliance 8.13\EXH2_12.XLS C(f)(f)"U -o :::r (j) g-m~o ~~ ~ c... CD :::r c -"'cr :J ;::;: CD 1\) 1\) ~ (..)

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Summary of Exchange Gas Eight Months Ended July 213 212 December 213 January February March April Mm: June 4!d!Y Total Exchange Gas- Mcf 727 (99) 6,711 2,54 3,35 4,37 3,849 19,423 Commodity - $ 36,589 (1,433) 17,768 1,85 2,522 12,23 (75,596) 128,885 CCI) (I)-a "' ::T () (j) ar~i6o Cii-c.m.. > X c... CD ::T ~ -..g: 1\) 1\) ~ w

--- = - ~---- --- - ----.. '"~"'-'-'-~=c- - - -1 -- - :=~..=:oo...:::...::===.::~=o.- J.:.:..:.::::c~'-O.:.:.:L:::.._"'::::=_~...::.:. ;_-.: ~ "'""'j~.. ~.-, a- t: -- -- - -- - ~ :.:. -- -. - - ::_ - - ---~::_ :...:..i:..:.~::=:. - ~.:..:_;:::...c:..:. :_:...::::...:...~~.";""'"' NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Summary of Off-System Sales Eight Months Ended July 213 212 December January Februarv March 213 April ~ June 4!d!Y Total Off-System Sales- Met Off-System Sales (Gas Cost) - $ (458,52) (1,485,463) (594,278) (1,93,56) (435,977) (1,428,697) (279,58) (1,49, 186) (1,767,833) (5,893,42) C(I)(I)""O -o ::J () G) g-m~o ~~~~ '- (!) ::J -Lg (!) 1\) 1\) ~ (...)

- -- NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Summary of Off-System Sales Refund Eight Months Ended July 213 212 December 213 January Februarv March April M. y June ~ Total Off-System Sales Margin-$ (138,953) (168,466) (94,462) (71,943) (473,824) Off-System Sales Refund {75%)- $ Prior Period Adjustment Net Off-System Sales Refund - $ (14,215) (126,35) (7,847) (53,957) (355,368) (1 4,215) (126,35) (7,841) 1 3,957)_ - - - -- - - - - Q_ - (355,368) ccncn-o "'C ::::r (') G)... ~tm~o c.m ~CD x c._ CD ::::r _,.~ <1> I\) I\) w

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Details of Upstream Purchases {Including Transportation) 1 Eight Months Ended July 213 212 December 213 Januarv Februarv March April MM June J!!lY Total Purchase Volume - Dth Storage Volume - Dth Total Volume- Dth 2,32,616 2,32,616 {1,635,41) (1,635,41) 397,575 397,575 Conversion Factor 1.74 1.74 1.74 1.74 1.74 1.74 1.74 1.74 Total Volume- Mcf 37,182 37,182 Net Purchases - Mcf 37,182 37,182 Demand - Natural Gas Supply - $ Demand - Distribution Charge - $ Total Demand - $ 2,39,96 512,415 2,552,321 2,39,96 512,415 2,552,321 Commodity - $ - PA 7,442,386 7,442,386 Net Commodity-$ 7,442,386 7,442,386 Total Cost - $ 9,994,77 9,994,77 1 See Exhibit 23, Schedule 1 CCJ)CJ)"U "O::TOG) &r~ffio ~=S:~ c_ CD ::; ~ ~g ~ ~ w

====-==--~~==~-=--...=~-=--"'-=-~t='=:o'"==-==--=~-=-"-=~"'==.::::.:.::_-:=.-:_:~~= :_-,_":!"="'-'==~-~c::~~:-.:"; ;:-:-:''' ::~-C:~-:- ~-...c :: -= _.:_! - ;""::"~ 7"!...-'' NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Details of Upstream Purchases Eight Months Ended July 213 212 213 December Januarv Februarv March April May June July Total Purchase Volume - Mcf Spot 1,356,68 1,484,37 1,31,175 1,461,95 1,66,58 1,28,65 922,314 9,196,459 Contracted 46,245 594,562 439,423 276,22 21,728 155,468 184,523 2,131,971 ShrinkaQe (24,4) (41,467) (37,883) (33,22) (22,27) (22,55~- _(~._ 6?) (21,88) Total (Met) 1,792,273 2,37,42 1,432,715 1,74,95 1,66,38 1,412,974 1,86,27 11,126,622 Demand Costs - $ Spot Contracted 32,752 32,268 31,412 32,644 (4) (221) 128,85 Total Demand Costs - $ 32,752 32,268 31,412 32,644 (4) (221) 128,85 Commodity Costs - $ Spot 5,24,92 5,474,797 3,78,465 6,2,413 7,395,319 5,531,92 4,11,3 37,328,9 Contracted 1,71,43 2,16,639 1,559,914 1,11,47 93,82 684,368 832,732 8,44,31 Total Commodity Costs - $ 6,96,35 7,635,436 5,268,379 7,13,82 7,489,139 6,215,46 4,843,735 45,372,319 Total Cost - $ 6,939,12 7,667,74 5,299,791 7,46,464 7,489,134 6,215,46 4,843,514 45,51,169 * This schedule does not include Transportation Charges. See PGC Exhibit 2, Schedule 6, for all updated Transportation Charges. CWW"U " ::r (") G) ~l&~o.-+.-+c.m ~ "' x c... CD::r c: :::l "'' ;::;: CD 1\) w 1\)

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Details of Storage Eight Months Ended July 213 Rental Cost* Demand Commodity 212 December 891,723 39,69 213 January Februarv March April 885,573 883,13 88,284 877,754 42,179 75,662 86,768 62,988.Mgy June JWy 871,126 868,441 961,72 38,24 47,991 66,26 Total 7,119,75 458,888 Transportation Cost Demand Commodity 51,184 2,126 51,184 2,126 Gas Cost Demand Commodity 1,771,41 3,796,638 3,959,384 4,179,223 2,851,355 (1,58,735) 7,133,3 7,849,82 5,355,69 252,222 (2,267,374) (2,26,759) (3,83,347) (4,683,688) (4, 186,652) (6, 12,226) 4,324,788 9,396,86 TOTAL COSTS Demand Commodity TOTAL 2,662,764 3,835,77 6,498,471 4,844,956 5,62,326 3,731,639 (18,981) 7, 175,182 7,925,482 5,442,458 315,21 12,2,138 12,987,88 9,174,97 134,229 (1,396,248) (1,158,318) (2,71,91) {4,645,484) (4, 138,661) {6,52,74) (6,41, 733) (5,296,979) (8, 123, 165) 11,495,47 9,857,82 21,352,867 See Exhibit 23, Schedule 1 C(J)(J)-o "C::rOG) g.mffio <ii... o..m.. W x c... <D ::r 1\.)2: <D... 1\.) 1\.) ~ w

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Detail of Costs Related tot. W. Phillips Eight Months Ended July 213 212 December January February 213 March April May June July Total Mcf 165 173 169 163 37 78 Amount-$ 2,68 2,123 1,995 1,958 1,9 73 736 73 11,349 C(J)"U "OOG) fi}~o ~~!Jl c._<d::t wg <D 1\) 1\) ~ (..)

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Detail of Capacity Release Eight Months Ended July 213 212 December 213 January February March 8m:i! ~ June ill!!y Total PA. Capacity Release 84,961 84,961 PA Customer Wide Choice Capacity Release 31,249 31,249 PA Capacity Release-$ 395,21 395,21 C(I)IJ -oog) ~afo ~~~ c.._<d::t """g <D I\) I\) ~ (J.)

::.:.:...~ -~:o..-====:!..:::::::=:-=r..:.~~~:<..:::=?~.,...,...,,..,~ NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Temperature Swing/ Peaking Capacity Costs Eight Months Ended July 213 212 213 December January February March April Mgy June 41!lY Total NFGSC EFT Capacity (Dth) 62,228 62,228 62,228 62,228 62,228 Rate ($/Dth) 3.9617 3.9622 3.9622 3.9622 3.9622 Amount($) 246,529 246,56 246,56 246,56 246,56 62,228 62,228 3.9622 3.9622 246,56 246,56 62,228 3.9622 246,56 1,972,449 NFGSC ESS Delivery (Dth) 51,562 51,562 51,562 51,562 51,562 Rate ($/Dth) 2.5959 2.5959 2.5959 2.5959 2.5959 Amount($) 133,85 133,85 133,85 133,85 133,85 51,562 51,562 2.5959 2.5959 133,85 133,85 51,562 1 2.5959 133,85 1,7,8 NFGSC ESS Capacity (Dth) 2,423,414 2,423,414 2,423,414 2,423,414 2,423,414 Rate ($/Dth).44.44.44.44.44 Amount($) 97,96 97,96 97,96 97,96 97,96 2,423,414 2,423,414.44.44 97,96 97,96 2,423,414.44 97,96 783,248 NFGSC FSS Capacity (Dth) 1,666 1,666 1,666 1,666 1,666 Rate ($/Dth) 2.4826 2.4826 2.4826 2.4826 2.4826 Amount($) 26,479 26,479 26,479 26,479 26,479 1,666 1,666 2.4826 2.4826 26,479 26,479 1,666 2.4826 26,479 211,832 NFGSC FSS Capacity (Dth) 2, 2, 2, 2, 2, Rate ($/Dth).381.381.381.381.381 Amount($) 7,62 7,62 7,62 7,62 7,62 2, 2,.381.381 7,62 7,62 2,.381 7,62 6,96 Grand Total Cost- Distribution Charge($) 512,384 512,415 512,415 512,415 512,415 512,415 512,415 512,415 4,99,289 ccn-o -cog) g.~o ~~~ c...cl>::t (112: C1> -!\)!\) ~ Vl

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Transportation Charges Eight Months Ended July 213 Demand - Distribution Charge - $ Demand - Natural Gas Supply - $ 212 213 December January February March April 512,384 512,415 512,415 512,415 512,415 1,841,686 1,787,39 1,822,878 1,844,671 1,81,223 Mgy: I June J!d!y 512,415 512,415 1,69,772 1,726,217 Total 3,586,874 12,442,485 Total Demand - $. 2,354,7 2,299,454 2,335,293 2,357,86 2,322,638 I 2, 122,181 2,238,632 16,29,359 Commodity - $ 44,~3 -- Z_1.~2 63,155 57,234 29,96 13,75~ 11,433 291,245 Total Costs - $ 2,398,533 2,37,756 2,398,448 2,414,32 2,352,544 I 2,135,93a 2,25,65 16,32,64 C(I)"U "OOG) &}~o ~~~ c_cd:::r m : CD,.. 1\) 1\) ~ w

l.l.l::!.:===---""==~--~::= ====~~:,~-- ~ - ~ " ~ --;-.. -~.~-- ~ -r=c>-.l""=---"-"==!:::::::;~-:.==c --k- - - -... -... -- ~- - -=-~"=-=============~=-=========- NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Summary of Cost of Gas by Gas Supplier and Transmission of Gas by Local Producers Twelve Months Ended July 214 Supplier Projected Quantity Purchased Mcf Commodity Cost $ Demand Cost Natural Gas Supply Demand Cost Distribution Charge Total Projected Cost $ $ $ Upstream Purchases 18,317,325 76,966,767 25,15,236 5,424,893 17,46,896 Storage (214,671) 12,532,882 12,318,211 Transportation Credit (2, 177, 135) (2, 177, 135) Capacity Release Credit 1 (4,575,653) (4,575,653) Local Production 127,354 56,642 56,642 T. W. Phillips 1 '188 17,949 17,949 Subtotal 18,445,867 77,276,687 3,795,33 5,424,893 113,496,91 Credit - Line Hits (13,851) Total Includes portion of ESS Storage Capacity Term release of $33,963 per Settlement (See Sch4) 113,483,59 C(I)(I)"U "O:::TOG) g.~~() ~= ~ '- CD :::T ~ -Lg 1\) (..) s> (..)

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Summary of Cost of Gas by Gas Supplier Twelve Months Ended July 214 Projected Demand Cost Demand Cost Total Quantity Commodity Natural Gas Distribution Projected SuQQiier Purchased Cost fumq!y Charge Cost Mcf $ $ $ $ Upstream August 213 377,493 5,812,593 2,94,152 452,74 8,358,819 September 575,259 6,84,26 2,12,33 452,74 9,358,583 October 1,99,827 5,325,964 2,94,152 452,74 7,872,19 November 1,776,276 6,21,72 2,97,721 452,74 8,75,867 December 2,733,95 7,353,827 2,91,925 452,74 9,897,826 January 214 3,23,621 6,37,927 2,91,925 452,74 8,914,926 February 2,877,829 5,989,22 2,89,362 452,74 8,53,458 March 2,527,751 4,879,666 2,91,924 452,75 7,423,665 April 1,524,245 7,246,149 2,65,443 452,75 9,763,667 May 816,88 7,88,88 2,65,443 452,75 1,326,326 June 49,49 7,564,8 2,65,443 452,75 1,82,318 July 368,559 5,69,733 2,65,443 452,75 8,127,251 Total 18,317,325 76,966,767 25,15,236 5,424,893 1 7,46,896 See Exhibit 23, Schedule 1 COOOO"U "' ::J"C'l Ci) g-mie"o... c.m ~ 1\)!:_x c... CD::J" c ::s... cr ;:::;: CD U) 1\) ~ U)

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Summary of Cost of Gas by Gas Supplier Twelve Months Ended July 214 Projected Total Quantity Commodity Projected Sugglier Purchased Cost Cost Local Production Mcf $ $ August 213 1,816 4,765 4,765 September 1,468 39,439 39,439 October 1,816 4,917 4,917 November 1,468 4,434 4,434 December 1,816 43,711 43,711 January 214 1,816 44,61 44,61 February 9,77 4,314 4,314 March 1,816 44,236 44,236 April 1,468 41,916 41,916 May 1,816 43,5 43,5 June 1,468 42,482 42,482 July 1,816 44,318 44,318 Total 127,354 56,642 56,642 See Exhibit 23, Schedule 2 C(I)(I)IJ "O::YOG) &r~~o <-a.m.. C.U X '- CD::J c ~c= :::l ;::;: CD (,..) 1\) ~ (,..)

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Summary of Transportation Credits Twelve Months Ended July 214 213 August Segtember October 214 November December January February March ~ ~ June,!illy: Total MMTVolume Rate $/Mcf Transportation Credit-$ Exhibit 24, Appendix 1 327,165.26 (85,63) 393,91 566,168.26.26 (12,414) (147,24) 82,66 1,19,117 1,289,133 1,124,648.26.26.26.26 (213,358) (288,37) (335,175) (292,48) 99,447 661,215 438,436 335,87.26.26.26.26 (257,516) (171,916) (113,993) (87,123) 317,675.26 (82,596) 8,373,598 (2,177,135) C(I)(I)IJ "O::::TOG) &r~~o --a.m ~ ~ x C... CD ::::T c: ~cr ~ ~ 1\) c.v

=...: "" -- --- ------ ~ =o-- ---- ~-----.o..;:: :::=====::_:::-: =--,~ - -..-.-----===:z.. :.::::d- - ~"- "-... -:..~=,!:::...:.,:I=-:..:::_,:_:.:.:...:...J..:...::..:_~:.:::.:;.; NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Summary of Credit Due to Line Hits Twelve Months Ended July 214 213 August September October 214 November December January February March till.ri! Mgy June Jilly Total Line Hits (Credit) Amount - $ 7,537 873 8 19 589 673 224 1,18 1,421 165 5 735 13,851 ccncn-u -o ::::; G) &rmffio ~~~!:r c... co ::::;... g: co - 1'\) (,) ~ (,)

----------==------- ~ - == ~---- ::: -=L - -- ~ - -- - - -!~ -- - -- --._... - '":::=!. ::.::::.===:=== - --- -- - =:-=:=.::. _oc_:.c~=.::.. ;':;;.:.:_::.:c..=..=-:.::.:::...:-:...:..:.:...:::::c... NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Details of Upstream Purchases (Including Transportation) ' Twelve Months Ended July 214 213 August Segtember 214 October November December Januarv Februarv March 8Qrl! f'.@y June J..yjy Total Purchase Volume - Dth Storage Volume - Dth Total Volume- Dth 1,616,557 {1,211 '129) 45,428 1,892,465 (1,274,637) 617,828 1,478,113 1,644,221 1,859,556 1,571,551 1,483,836 1,221,344 (296,899) 263,499 1,75,788 1,898,136 1,66,952 1,493,461 1,181,214 1,97,72 2,935,344 3,469,687 3,9,788 2,714,85 1,884,496 2,32,41 1,953,44 (247,457) {1 '155,81) (1,513,648) 1,637,39 877,329 439,792 1,447,446 (1,51,614) 395,832 2,85,436 (412,629) 19,672,87 Conversion Factor 1.74 1.74 1.74 1.74 1.74 1.74 1.74 1.74 1.74 1.74 1.74 1.74 Total Volume- Mcf 377,493 575,259 1,99,827 1,776,276 2,733,95 3,23,621 2,877,829 2,527,751 1,524,245 816,88 49,49 368,559 18,317,325 Net Purchases - Met 377,493 575,259 1,99,827 1,776,276 2,733,95 3,23,621 2,877,829 2,527,751 1,524,245 816,88 49,49 368,559 18,317,325 Demand - Natural Gas Supply - $ Demand - Distribution Charge - $ Total Demand - $ 2,94,152 452,74 2,546,226 2,12,33 452,74 2,554,377 2,94,152 2,97,721 2,91,925 2,91,925 2,89,362 2,91,924 452,74 452,74 452,74 452,74 452,74 452,75 2,546,226 2,549,795 2,543,999 2,543,999 2,541,436 2,543,999 2,65,443 2,65,443 2,65,443 452,75 452,75 452,75 2,517,518 2,517,518 2,517,518 2,65,443 452,75 2,517,518 25,15,236 5,424,893 3,44,129 Commodity- $ - PA 5,812,593 6,84,26 5,325,964 6,21,72 7,353,827 6,37,927 5,989,22 4,879,666 7,246,149 7,88,88 7,564,8 5,69,733 76,966,767 Net Commodity - $ 5,812,593 6,84,26 5,325,964 6,21,72 7,353,827 6,37,927 5,989,22 4,879,666 7,246,149 7,88,88 7,564,8 5,69,733 76,966,767 Total Cost- $ 8,358,819 9,358,583 7,872,19 8,75,867 9,897,826 8,914,926 8,53,458 7,423,665 9,763,667 1,326,326 1,82,318 8,127,251 17,46,896 ' See Exhibit 23, Schedule 1 ccncn-o -o :::r (") G) ar~~o ~=~~ r_ CD :::r "' : CD -(..) "' ~ (..)

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Details of Storage Twelve Months Ended July 214 213 214 August September October November December Januarv Februarv March 6o!:l! ~ June J!!!y Total Rental Cost Demand Commodity Transportation Cost Demand Commodity Gas Cost Demand Commodity TOTAL COSTS Demand Commodity TOTAL 961,72 961,72 961,72 961,72 961,72 961,72 961,72 961,72 961,72 961,72 961,72 961,72 11,532,864 51,61 52,393 17,163 6,468 45,616 8,51 68,211 61,811 22,73 45,976 61,311 41,697 554,38 51,184 51,184 12,362 12,362 12,362 12,362 12,362 12,362 51,184 51,184 51,184 51,184 921,276 1,275 744 3,74 666 1,438 959 1,918 531 2,126 2,126 2,126 16,983 (2,298,975) (2,419,356) (642,752) 584,949 2,386,783 4,211,32 3,565,237 3,313,561 (531,814) (2,511,797) (3,291,623) (2,286, 773) 78,742 (4,563,33) (4,82,252) (1 '149,555) 1,46,175 4,268,738 7,531,874 6,376,394 5,926,272 (951,145) (4,492,325) (5,887,35) (4,89,872) (786,34) (1,286,719) (1,47,1) 42,682 1,648,383 3,45,217 5,274,736 4,628,671 4,376,995 48,442 (1,499,541) (2,279,367) (1,274,517) 12,532,882 (4,511,693) (4,748,584) (1,131,648) 1,55,717 4,315,2 7,613,363 6,445,564 5,99,1 (928,541) (4,444,223) (5,823,598) (4,46,49) (214,671) (5, 798,412) (6, 155,684) (71,966) 2, 74,1 7, 765,237 12,888,99 11,74,235 1,366,996 (448,99) (5,943, 764) (8, 12,965) (5,32,566) 12,318,211 See Exhibit 23, Schedule 1 C(J)(J)"U "' ::TO (j) &rmaro ~~~~ r_ (!) :::T 1\)g: (!)... 1\) c.:> ~ c.:>

---- - '">~~- -c~-~~.<'~'- h -, -!~ -~ u - o '"'-.!---l.:'-.;:j:;::=_.;:: - ''- - ~--=:..:.~~ ==-,..j- w-..,-., '""~ -------~- -- - -----~--- -.:::::t=::.:.:.--::--.-::.:.::::.-...:..:.::.:~::::::::..:.:::====~::=-.:::_ - "~ 1... ~-~--....-_~" NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Detail of Costs Related tot. W. Phillips Twelve Months Ended.July 214 213 August September October 214 November December January February March ~ ~ June ill!jy Total Mcf 23 153 279 294 261 83 9 2 3 1,188 Amount-$ 73 73 931 1,963 2,467 3,347 2,752 1,376 1,43 743 749 73 17,949 ccn-o -cog) g.~o ~~~ c:_cd::t w : CD - 1\) c..:> c..:>

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Detail of Capacity Release Credits Twelve Months Ended July 214 213 214 August September October November December January February March 6Qri! ~ June,!!!bl Total PA Capacity Release 99,137 14,433 72,733 79,474 73,12 79,822 83,17 84,961 86,99 73,879 74,471 65,56 976,598 PA Customer Wide Choice Capacity Release 297,91 297,91 297,91 297,91 297,91 297,91 297,91 297,91 297,91 297,91 297,91 297,91 3,565,92 ESS Storage Capacity Term Release per Sttlmt 4 2 245 4,245 4 2 245 4 2 245 4,245 4 2 245 4,245 4,246 33,963 Capacity Release Credit - $ 4,473 45,769 374,69 38,81 374,348 381,158 384,353 386,298 383,19 37,97 371,562 362,651 4,575,653 C(I)LJ "'OC">G) g-~o aia.m.. X c..._cd:::t -""2: CD.-+ 1\) U) ~ U)

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Temperature Swing/ Peaking Capacity Costs Twelve Months Ended July 214 213 August September October November December January February March 214 6Qtl! ~ June JQ!y Total NFGSC EFT Capacity (Dth) 55,93 55,93 55,93 55,93 55,93 55,93 55,93 55,93 Rate ($/Dth) 3.9622 3.9622 3.9622 3.9622 3.9622 3.9622 3.9622 3.9622 Amount($) 218,289 218,289 218,289 218,289 218,289 218,289 218,289 218,289 55,93 55,93 55,93 3.9622 3.9622 3.9622 218,289 218,289 218,289 55,93 3.9622 218,289 2,619,468 NFGSC ESS Delivery (Dth) 44,427 44,427 44,427 44,427 44,427 44,427 44,427 44,427 Rate ($/Dth) 2.5959 2.5959 2.5959 2.5959 2.5959 2.5959 2.5959 2.5959 Amount($) 115,328 115,328 115,328 115,328 115,328 115,328 115,328 115,328 44,427 44,427 44,427 2.5959 2.5959 2.5959 115,328 115,328 115,328 44,427 2.5959 115,328 1,383,936 NFGSC ESS Capacity (Dth) 2,88,69 2,88,69 2,88,69 2,88,69 2,88,69 2,88,69 2,88,69 2,88,69 Rate ($/Dth).44.44.44.44.44.44.44.44 Amount($) 84,358 84,358 84,358 84,358 84,358 84,358 84,358 84,358 2,88,69 2,88,69 2,88,69.44.44.44 84,358 84,358 84,358 2,88,69.44 84,358 1,12,296 NFGSC FSS Delivery (Dth) 1,666 1,666 1,666 1,666 1,666 1,666 1,666 1,666 Rate ($/Dth) 2.4826 2.4826 2.4826 2.4826 2.4826 2.4826 2.4826 2.4826 Amount($) 26,479 26,479 26,479 26,479 26,479 26,479 26,479 26,48 1,666 1,666 1,666 2.4826 2.4826 2.4826 26,48 26,48 26,48 1,666 2.4826 26,48 317,753 NFGSC FSS Capacity (Dth) 2, 2, 2, 2, 2, 2, 2, 2, Rate {$/Dth).381.381.381.381.381.381.381.381 Amount($) 7,62 7,62 7,62 7,62 7,62 7,62 7,62 7,62 2, 2, 2,.381.381.381 7,62 7,62 7,62 2,.381 7,62 91,44 Grand Total Cost- Distribution Charge($) 452,74 452_,_7~ - '!5~74_ - 4 2,~74 45~,74-45?,7_4 452,74 452,75 452,75 452,75 452,75 452,75 5,424,893 C(I)IJ ""COG) &ti5o ~~~ c.._cd::::t C11g CD 1\) ~ w W

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Computation of Purchased Gas Commodity Cost Per Mcf On and After August 1, 213 PGC Exhibit 21 Schedule 1 Sheet 1 COMMODITY Update: June 213 Computation Year: Twelve Months Ended July 214 Line No. Description Purchased Gas Commodity Costs (CC - E) + S 2 3 4 5 6 7 8 9 1 11 12 CC = Commodity Cost of Gas (Exhibit 3) S = Projected Sales for the Computation Year (See Exhibit 22) Unit Commodity Cost (Line 2/ Line 3) Storage Interest (Exhibit 218, Sheet 2) Total Commodity Cost (Line 4 +Line 5) E =Experienced Net Undercollection to be Recovered (See Schedule 5 - COMMODITY) S = Projected Sales for the Computation Year (See Exhibit 22) Projected SATC Volumes for Computation Year Total Volumes for Recovery of Commodity E- Factor (Line 8 + Line 9) Unit Commodity E-Factor Rate (Line 7/ Line 1) Projected Sales Commodity Cost per Mcf (Line 6- Line 11) 77,262,836 18,335,882 4.2138 (.5) 4.288 (481 '132) 18,335,882 18,335,882 (.262) 4.235

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Computation of Purchased Gas Demand Cost Per Mcf On and After August 1, 213 PGC Exhibit 21 Schedule 1 Sheet2 DEMAND-NGS Update: June 213 Computation Year: Twelve Months Ended July 214 Line No. Description Purchased Gas Demand Costs DC+ S 2 3 4 3 4 DC = Demand Cost of Gas - Natural Gas Supply (Exhibit 3) ESS Storage Capacity Reduction per Settlement (April 214-July 214 ($42,281/mth) Adjusted DC = Demand Cost of Gas - Natural Gas Supply Projected Sales for Computation Year (Exhibit 22) Unit Demand Cost (Line 2/ Line 3) 3,795,33 (169,124) 3,626,26 18,335,882 1.673 5 6 7 8 9 1 E = Experienced Net Overcollection to be Refunded (See Schedule 2 - DEMAND - NGS) ESS Storage Capacity Term Release per Settlement (July 213 $4,245/mth) Adjusted E = Experienced Net Overcollection to be Refunded S = Projected Sales for the Computation Year (Exhibit 22) Unit Demand E-Factor Rate (Line 5/ Line 6) Projected Sales Demand Cost per Mcf (Line 4- Line 7) 2,649,217 (4,245) 2,644,972 18,335,882.1443 1.526

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Computation of Purchased Gas Demand Cost Per Mcf On and After August 1, 213 PGC Exhibit 21 Schedule 1 Sheet 3 DEMAND- DC Update: June 213 Computation Year: Twelve Months Ended July 214 Line No. Description Purchased Gas Demand Costs DC S 2 3 4 5 6 DC = Demand Cost of Gas - Distribution Charge (Exhibit 3) Projected Sales for Computation Year (Exhibit 22) Projected SATC Volumes for Computation Year Total Volumes for Recovery of Demand Costs- Distribution Charge Unit Demand Cost (Line 2/ Line 5) 5,424,893 18,335,882 2,385,52 2,721,42.2618 7 8 9 1 E = Experienced Net Overcollection to be Refunded (See Schedule 2 - DEMAND - DC) Total Volumes for Recovery of Demand Costs- Distribution Charge Unit Demand E-Factor Rate Projected Sales Demand Cost per Mcf (Line 6 - Line 9) 493,943 2,721,42.238.238

PGC Exhibit 21 Schedule 2 DEMAND-NGS Update: June 213 NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Statement Showing the Development of Experienced Net Over or (Under) Collections Line No. Description Amount $ 1 Estimated Overcollection of gas cost for the twelve month period 2 August 212 through July 213 to be Refunded (Schedule 3) 3 Reconciliation of estimated Undercollection of gas cost for the 4 twelve month period August 211 through July 212 (Schedule 7) 5 Reconciliation of Undercollection of gas cost balances for the 6 twelve month period August 21 through July 211 7 (Schedule 8, Sheet 1) 8 Estimated Undercollection of gas cost for the 9 twelve month period August 211 through July 212 1 to be Refunded for the twelve months ended July 213 (Schedule 8, Sheet 2) 11 Reconciliation of refund balances for the twelve month period 12 August 211 - July 212 ( Schedule 9, Sheet 1) 13 Estimated balance of refunds/surcharges for the twelve month period 14 August 212 - July 213 (Schedule 9, Sheet 2) 15 Refunds Received and included in PGC 213 (Schedule 4, Sheet 1) 16 Total Amount to be Refunded 2,45,435 259,649 (6,867) 2,649,217

PGC Exhibit 21 Schedule 2 DEMAND-DC Update: June 213 NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Statement Showing the Development of Experienced Net Over or (Under) Collections Line No. Description Amount $ Estimated Overcollection of gas cost for the twelve month period 2 August 212 through July 213 to be Refunded (Schedule 3) 3 Reconciliation of estimated Undercollection of gas cost for the 4 twelve month period August 211 through July 212 (Schedule 7) 5 Reconciliation of estimated Overcollection of gas cost balances for the 6 twelve month period August 21 through July 211 7 for the twelve months ended July 212 ( Schedule 8, Sheet 1) 8 Estimated Undercollection of gas cost for the 9 twelve month period August 211 through July 212 1 to be Refunded for the twelve months ended July 213 (Schedule 8, Sheet 2) 11 Reconciliation of refund balances for the twelve month period 12 August 211 - July 212 ( Schedule 9, Sheet 1) 13 Estimated balance of refunds/surcharges for the twelve month period 14 August 212 - July 213 (Schedule 9, Sheet 2) 15 Refunds Received and included in PGC 213 (Schedule 4, Sheet 2) 16 Total Amount to be Refunded 35,144 29,36 (45,829) 25,322 493,943

... == """=...! ~- -~..,=... _,_...,. ~ ~ -... -- -~.- - --~ - ~ -- -~ - - -M- -,.,... -~.,.,.-... ------ NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 213 PGC PGC Cost of Over(Under) Interest Interest Interest Sales Rate Revenue Fuel Collections Rate Weight Amount Mcf $/Mcf $ $ $ % $ (1) (2) (3=1x2) (4) (5=3-4) (6) (7) (8=5x6x7) 212 August 166,86 1.6891 281,752 148,617 1.6656 247,536 Standby/Priority 21,514 Standby Overruns 574 LBS- Demand 267.9461 253 Overdelivery/Upstream Cap. Surcharge 38,4 315,423 589,633 97,92 (318,269) 8.% 18 I 12 (38, 192) September 373,499 1.6656 622,1 Standby/Priority 25,789 Standby Overruns 164 LBS- Demand 267.924 246 Overdelivery/Upstream Cap. Surcharge 35,55 373,499 683,354 481,959 21,395 8.% 17 I 12 22,825 October 764,384 1.6656 1,273,158 Standby/Priority 46,772 Standby Overruns 13 LBS- Demand 267.924 246 Overdelivery/Upstream Cap. Surcharge 32,145 764,384 1,352,424 1,818,112 (465,688) 8.% 16 I 12 (49,673) November 792,66 1.6656 1,32,165 - ~-~~--- 644,528 1.732 1,97,76 Standby/Priority 73,652 COCilCil""' -om:::::rog) Standby Overruns 151 &}s:~ffio... )>... c..m LBS- Demand 267.924 246 ~Z... x c...o <l>::::t Overdelivery/Upstream Cap. Surcharge 32,948 c wcr ~ ;::;: 1,437,134 2,524,922 4,123,631 (1,598, 79) 8.% 15 I 12 (159,871) mz 1\)Gl ~(/) (.o.) ~

==~====-= ===-.. -,... --...... ==== o=.o.l===='="'""""" i --- --"" "- ---- - - - ~=- =., = =- = -~ =...,.~=-= = ======== NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 213 PGC PGC Cost of Over(Under) Interest Interest Interest Sales Rate Revenue Fuel Collections Rate Weight Amount Mcf $/Mcf $ $ $ % $ (1) (2) (3=1X2) (4) (5=3-4) (6) (7) (8=5x6x7) December 6,824 1.6656 11,366 2,38,229 1.732 3,931,376 Standby/Priority 85,297 Standby Overruns 74 LBS- Demand 267.9386 251 Overdelivery/Upstream Cap. Surcharge 45,279 2,315,53 4,74,39 4,279,318 (25,9) 8.% 14 I 12 (19, 134) 213 January 3,71,43 1.732 5,23,6 Standby/Priority 18,95 Standby Overruns 155 LBS- Demand.9386 Overdelivery/Upstream Cap. Surcharge 48,265 3,71,43 5,387,115 6,353,278 (966,163) 8.% 13 I 12 (83,734) February 1,657,526 1.732 2,823,98 1,651,821 1.7162 2,834,855 Standby/Priority 15,98 Standby Overruns 3,243 LBS- Demand.9386 Overdelivery/Upstream Cap. Surcharge 44,38 3,39,347 5,81,674 6,621,854 (811 '18) 8.% 12 I 12 (64,894) March 3,122,576 1.7162 5,358,965. Standby/Priority 11,838 Standby Overruns 379 LBS- Demand.9446 CO(I)(I)-.:J -om::tng) Overdelivery/Upstream Cap. Surcharge 37,887 a.5:m~o ~J>-a.m ~ZN x 3,122,576 5,499,69 5,334,485 164,584 8.% 11 I 12 12,69 c...o CD::T. c.jo' ;::;: coz I\) G) ~ ~(/) VJ

NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 213 PGC PGC Cost of Over(Under) Interest Interest Interest Sales Rate Revenue Fuel Collections Rate Weight Amount Mcf $/Mcf $ $ $ % $ (1) (2) (3=1X2) (4) (5=3-4) (6} (7) (8=5x6x7) April 2,489, 1.7162 4,271,622 Standby/Priority 71,293 Standby Overruns 878 LBS- Demand 93.9446 88 Overdelivery/Upstream Cap. Surcharge 35,79 2,489, 4,379,671 1,452,768 2,926,93 8.% 1 I 12 195,127 May 572,664 1.7162 982,86 469,523 1.6914 794,151 Standby/Priority 39,29 Standby Overruns 266 LBS- Demand 93.9446 88 Overdelivery/Upstream Cap. Surcharge 39,43 572,664 1,856,4 89,993 1,766,11 8.% 9 I 12 15,961 June 62,59 1.6914 1,48,768 Standby/Priority 26,593 Standby Overruns 416 LBS- Demand 93.935 87 Overdelivery/Upstream Cap. Surcharge 38,499 62,59 1 '114,363 476,69 637,673 8.% 8 I 12 34,9 July 328,132 1.6914 555,2 Standby/Priority 15,97 Standby Overruns 37 LBS- Demand.935 Overdelivery/Upstream Cap. Surcharge 28,844 CO(J)(J)""U "m:::rng) 328,132 599,853 (512,628) 1,112,481 8.% 7 I 12 51,916 o.~mffio ~)>-o.m Total 18,718,314 33,871,391 31,427,363 2,444,28 6,47 ~ZC.V x c;_q co:::r c: ' c.vg ~z I\) G) ~ ~(/) c.v

====~========,"-"'="====== = -===~ -... - -- _,_ - - -- -... -- -- - NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 213 PGC PGC Cost of Over(Under) Interest Interest Interest Sales Rate Revenue Fuel Collections Rate Weight Amount Mcf $/Mcf $ $ $ % $ (1) (2) (3=1x2) (4) (5=3-4) (6) (7) (8=5x6x7) 212 August 166,86.2896 48,37 148,617.2892 42,98 SATC 2,81.2896 6,24 SATC 18,615.2892 5,383 354,839 12,694 512,384 (49,69) 6.% 18 I 12 (36,872) September 373,499.2892 18,16 SATC 47,719.2892 13,8 421,218 121,816 512,384 (39,568) 6.% 17 I 12 (33,198) October 764,384.2892 221,6 SATC 99,72.2892 28,839 864,14 249,899 512,384 (262,485) 6.% 16 I 12 (2,999) November 792,66.2892 229,222 644,528.292 187,42 SATC 14,91.2892 3,34 SATC 81,799.292 23,738 1,623,843 47,342 512,384 (42,42) 6.% 15 I 12 (3, 153) December 6,824.2892 1,974 2,38,229.292 669,848 175,77.2892 5,833 SATC 138,1.292 4,51 2,628,833 762,76 512,384 25,322 8.% 14 I 12 23,363 cocncn-u -om=-nq g-s::)g~o -)>-a.m ~z~s.x c...o CD::T 213 January 3,71,43.292 891,217 c:: ' SATC 465,677.292 135,139 WeT ;::;: ~ 3,536,72 1,26,356 512,415 513,941 8.% 13 I 12 44,542 1\) ~ ~ w

NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 213 PGC PGC Cost of Over(Under) Interest Interest Interest Sales Rate Revenue Fuel Collections Rate Weight Amount Mcf $1Mcf $ $ $ % $ (1) (2) (3=1 x2) (4) (5=3-4) (6) (7) (8=5x6x7) February 1,657,526.292 481,14 1,651,821.291 479,193 SATC 264,31.292 76,73 SATC 261,178.291 75,768 3,834,835 1 '112,678 512,415 6,263 8.% 12 I 12 48,21 March 3,122,576.291 95,859. SATC 514,35.291 149,213 SATC. 3,636,926 1,55,72 512,415 542,657 8.% 11 I 12 39,795 April 2,489,.291 722,59 SATC 419,836.291 121,794 2,98,836 843,853 512,415 331,438 8.% 1 I 12 22,96 May 572,664.291 166,13 469,523.285 133,814 11,57.291 29,317 SATC 83,68.285 23,849 1,226,924 353,11 512,415 (159,35) 8.% 9 I 12 (9,558) June 62,59.285 176,717 SATC 113,837.285 32,444 733,896 29,161 512,415 (33,254) 8.% 8 I 12 (16,174) July 328,132.285 93,518 SATC 48,441.285 13,86 376,573 17,324 512,415 (45,91) 8.% 7 I 12 (18,94) CO(J)(J)-o -om ::r n G) g-s::~~o Total 22,147,547 6,415,11 6,148,825 266,186 38,958 ~~~ ~ ~o ro::r c: ' wo: ;:::;: ifio t\) ~ ~ v.>

-~ --- ~-=-~-------~. =.:r--'""'-'-""=~=t:..c.lc.::~-=---- ~ -~ -;:,-~ -:::"'o~::ll'-'-~'==-=~=-::~:::::::-~; -===::...-:=::.:.:=='--:::_-l.!." NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Refunds From and Payments to Gas Suppliers Refund From Date Received Refund Amount $ Rate INTEREST Weight Amount $ Total Refund Plus Interest $ A. 6.% o I 12 ---- TOTAL CO(I)(I)"U -cm:::tng) ~s:~ffio -)>-a.m ~Z... x L. (1) :::T ' ~ g: roz - NG) ~ ~(I) (,.)

- -- ------ - -..,.,.. <-.:.."'-:...-.L:.-:..=.:.=...::...~~1'""" - - -- -- t.::====!::=-o.o==..:::::.==_:.:.::=~.=::.=::..:..:d.:. ::.:.:.-;:.=-.:.:.:_ -'..:...:.:~..::.:.::;:_'--"'~~- :-- - ----~- -~ - -- - - ---.-- ~- 1 --- ---... -- - ::- ::~==- - -~ - ----'" ---:= - ----.:::,,_!._._,... - ---- oo :: ~...:...:...:o~-- NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Refunds From and Payments to Gas Suppliers Refund From Date Received Refund Amount $ INTEREST Rate Weight Amount $ Total Refund Plus Interest $ A. Columbia Gas 3/11/13 194,618 6.% 11 I 12 1,74 25,322 TOTAL 194,618 1,74 25,322 cocncn""' -om::jog) c..s:m~o ~~-c..m ~ZI\:l!:.x C- CD:!. '.j:>. Q': coo ~ 1\) ~ ~ (.,.)

PGC Exhibit 21 Schedule 5 COMMODITY Update: June 213 NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Statement Showing the Development of Experienced Net Over or (Under) Collections Line No. Description Amount $ 1 Estimated Overcollection of gas cost for the twelve month period 2 August 212 through July 213 to be Refunded (Schedule 6) 3 Reconciliation of estimated Overcollection of gas cost for the 4 twelve month period August 211 through July 212 (Schedule 7) 5 Reconciliation of Overcollection of gas cost for the 6 twelve month period August 21 through July 211 7 (Schedule 8, Sheet 1) 8 Reconciliation of estimated Overcollection of gas cost for the 9 twelve month period August 211 through July 212 1 to be RecoveredJor the twelve months ended July 213 (Schedule 8, Sheet 2) 11 Reconciliation of refunds for the twelve month period 12 August 211 -July 212 (Schedule 9, Sheet 1) 13 Estimated balance of refunds for the twelve month period 14 August 212 -July 213 (Schedule 9, Sheet 2) 15 Refunds Received and included in PGC 213 (Schedule 1 ) 16 Reconciliation of C-Factor Storage Interest Expense/(lncome) orginating in 17 PGC 211 for the twelve months ended July 212 (Schedule 11, Sheet 1) 18 Actual C-Factor Storage Interest Expense/(lncome) orginating in 19 PGC 212 for the twelve months ended July 213 (Schedule 11, Sheet 2) 954,5 (1,519,464) (8,736) 952 2 Reconcilation of Storage Interest refund balance for the period August 211 -July 212 21 (recovered)/passed back August 212 - July 213 (Schedule 11, Sheet 3) 27,159 22 Estimated C-Factor interest expense/(income) originating in PGC 212 23 for the 12 month period ended July 213 (Schedule 11, Sheet 4) 64,97 24 Total Amount to be Recovered (481, 132)

- -- - ~-- -- "'-:::- :: _l.=..:r..>::=!.::.._ -~===--=="""---'==-=- ~ - ---=:'=:o=-~'7'--= --,~- - '" --...,_,:::: =;:--..:.:C;. :l.=<.:.=~.~~c:::.::::...:.:c::...:=::-;,;.t:::'-'-l.:.=-: - --.. -- - -- ~:.::::.-::~!:.::.:L-::.-.:: :-'-1-:.:=.::_:.!_::._.::.:.~::.:::-=:::-.::.=.-.:.:::.c==,.,_:J::::.:: NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 213 Sales Mcf (1) PGC Rate $/Mcf (2) PGC Revenue $ (3=1X2) Cost of Fuel $ (4) Over(Under) Collections $ (5=3-4) Interest Rate % (6) Interest Weight (7) Interest Amount $ (8=5x6x7) 212 August 166,86 Storage Inventory Recovery Reimbursement of NFGSC Transfer Fee Market Rate Differential City Gate Imbalance Sales Cashout NGV LBS - Commodity 148,617 112 1,213 316,748 3.1213 52,652 4.54 62,493 91,55 19 3,147 133 4.674 456 3.1213 3,786 1,222,236 1,518,888 (296,652) 8.% 18 12 (35,598) September 373,499 Storage Inventory Recovery Reimbursement of NFGSC Transfer Fee Market Rate Differential City Gate Imbalance Sales Cashout NGV LBS - Commodity 99 1,216 374,814 4.54 1,514,165 138,1 12 54,63 4.9744 492 4.54 4,93 1,712,239 1,633,317 78,922 8.% 17 12 8,945 October Storage Inventory Recovery Reimbursement of NFGSC Transfer Fee Market Rate Differential City Gate Imbalance Sales Cashout NGV LBS - Commodity 764,384 524 1,884 766,792 4.54 3,98,813 96,39 12 6,168 4.9744 2,67 4.54 7,638 3,211,628 2,62,424 69,24 8.% 16 12 64,982 November 792,66 644,528 Storage Inventory Recovery Reimbursement of NFGSC Transfer Fee Market Rate Differential City Gate Imbalance Sales Cashout NGV 427 LBS - Commodity 77 1,438,331 4.54 4.435 3,213,225 2,855,581 44,447 12 293 26,65 4.9744 2,124 4.54 3,122 6,541,454 9,195,185 (2,653,731) 8.% 15 12 (265,373) C()(J)(J)""O ""CQ::TOG) g.s:~~o ~~=~~ C... CD :!. :::j (j)g: <1>-< 1\) 1\)... ~ (..)

NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 213 Sales Mcf (1) PGC Rate $/Mcf (2) PGC Revenue $ (3=1X2) Cost of Fuel $ (4) Over(Under) Collections $ (5=3-4} Interest Rate % (6} Interest Weight (7) Interest Amount $ (8=5x6x7) December 6,824 2,38,229 Storage Inventory Recovery Reimbursement of NFGSC Transfer Fee Market Rate Differential City Gate Imbalance Sales Cashout NGV LBS - Commodity 467 2,315,52 4.54 27,664 4.435 1,226,69 188,642 19 27,213 5.3691 2,57 4.435 1,652,654 1,411,61 241,593 8.% 14 12 22,549 213 January 3,71,43 Storage Inventory Recovery Reimbursement of NFGSC Transfer Fee Market Rate Differential City Gate Imbalance Sales Cashout NGV LBS- Commodity 484 3,71,527 4.435 13,66,256 96,714 19 2,223 53,163 5.3691 2,599 4.435 13,76,974 13,868,994 (18,2} 8.% 13 12 (9,362} February 1,657,526 1,651,821 Storage Inventory Recovery Reimbursement of NFGSC Transfer Fee Market Rate Differential City Gate Imbalance Sales Cashout NGV LBS - Commodity 357 3,39,74 4.435 7,343,669 3.73 6,161,292 52,236 23 1,692 167,774 5.3691 1,917 4.435 13,728,63 12,691,969 1,36,635 8.% 12 12 82,931 March 3,122,576 Storage Inventory Recovery Reimbursement of NFGSC Transfer Fee Market Rate Differential City Gate Imbalance Sales Cashout NGV 386 LBS - Commodity 3.122,962 3.73. 11,647,28 2,537 23,732 4.6746 1,84. 11,855,281 12,5,837 (645,556} 8.% 11 12 (47,341} C()(f)(f)"U "OQ::TDG) fits:~~() cos:-c..m.. o"' x E CD::!. ::::l::j mg: CD-< 1\:l "' ~ ~ (...)

-~ -- ~~~~... '~4 - --- -- -.. ~ l ovu.- - ==:::.===:l.::.::::~;:;::;;:;.:';i"!= ====l=- - --..-~-=~:---- -_,. NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 213 PGC PGC Cost of Over(Under) Interest Interest Interest Sales Rate Revenue Fuel Collections Rate Weight Amount Mcf $1Mcf $ $ $ % $ (1) (2) (3=1X2) (4) (5=3-4) (6) (7) (8=5x6x7) April 2,489, 3.73 9,283,97. Storage Inventory Recovery Reimbursement of NFGSC Transfer Fee Market Rate Differential 3 City Gate Imbalance Sales Cashout 312,739 NGV 347 4.6746 1,622 LBS- Commodity 96 3.73 358 2,489,443 9,598,692 8,976,12 622,572 8.% 1 I 12 41,55 May 572,664 3.73 2,136,37 469,523 4.77 1,911,287 Storage Inventory Recovery 23,874 Reimbursement of NFGSC Transfer Fee 15 Market Rate Differential 33 City Gate Imbalance Sales Cashout 11,444 NGV 368 4.6746 1,72 LBS - Commodity 357 3.73 1,332 1,42,912 4,175,742 2,94,259 1,235,483 8.% 9 I 12 74,129 June 62,59 4.77 2,524,74 Storage Inventory Recovery 41,743 Reimbursement of NFGSC Transfer Fee 12 Market Rate Differential 49 City Gate Imbalance 54 Sales Cashout 135,792 NGV 474 5.12 2,371 LBS - Commodity 168 4.77 684 62,71 2,74,779 1,758,698 946,81 8.% 8 I 12 5,458 July 328,132 4.77 1,335,727 NGV 5.12 cocncn-u "OQ::TC>G) LBS - Commodity 4.77 g.s::m~o 328,132 1,335,727 1,431,56 (95,833) 8.% 7 I 12 (4,472) ~~;~~ f=o m;:r. ::::l:::::j O>Q: Total 19,197,586 8,5,9 79,529,31 97,699 (16,649) (1)-< ~ 1\)... ~ cu

PGC Exhibit 21 Schedule 7 Sheet 1 COMMODITY Update: June 213 NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Reconciliation of Interest on Over(Under) Collections Twelve Months Ended July 212 Amount $ Estimated Overcollection of gas cost for the twelve month period August 211 through July 212 calculated in PGC 211 (Schedule 7, Pages 2-4} Net Interest Expense (Income) to be refunded (Schedule 7, Pages 2-4} 17,11,259 1,325,489 Total Estimate For the Twelve Months Ended July 212 18,426,748 Actual Overcollection of gas cost for the twelve month period August 211 through July 212 (Schedule 7, Pages 5-7) 17,11,259 Net Interest Expense (Income) to be refunded (Schedule 7, Pages 5-7) 1,325,489 Total Actual For the Twelve Months Ended July 212 18,426,748

NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 212 (ESTIMATE) PGC PGC Cost of Over(Under) Interest Interest Interest Sales Rate Revenue Fuel Collections Rate Weight Amount Mcf $1Mcf $ $ $ % $ (1) (2) {3=1x2) (4) (5=3-4) (6) (7) (8=5x6x7) 211 August 168,974 5.1438 869,168 16,582 5.2854 848,74 Storage Inventory Recovery 162,669 Reimbursement of NFGSC Transfer Fee 15 Market Rate Differential City Gate Imbalance NGV 6 5.9322 356 LBS - Commodity 1,12 5.1438 5,26 33,628 1,886,154 2,72,384 {186,23) 8.% 18 I 12 (22,348) September. 398,454 5.2854 2,15,989 Storage Inventory Recovery 289,994 Reimbursement of NFGSC Transfer Fee 15 Market Rate Differential City Gate Imbalance 261 NGV 198 6.2578 1,239 LBS - Commodity 2,56 5.2854 1,867 4,78 2,48,365 {4, 169, 153) 6,577,518 8.% 17 I 12 745,452 October 661,444 5.2854 3,495,996 Storage Inventory Recovery 39,91 Reimbursement of NFGSC Transfer Fee 23 Market Rate Differential City Gate Imbalance 23 NGV 64 6.2578 3,78 LBS - Commodity 2,731 5.2854 14,434 664,779 3,553,347 4,961,842 (1,48,495) 8.% 16 I 12 (15,239) November 771,799 5.2854 4,79,266 622,795 4.5184 2,814,37 Storage Inventory Recovery 37,435 Reimbursement of NFGSC Transfer Fee 23 Market Rate Differential City Gate Imbalance 4,522 cocncn"u NGV 47 6.2578 2,547 'OQ:TO(j) g.:s::m~o LBS - Commodity 1,135 5.2854 5,999 -:s::-o.m ~on x 1,396,136 6,943,829 7,22,286 (258,457) 8.% 15 I 12 (25,846) c...o ro:::. =i ~g Cl>-< 1\) 1\)... s (..)

=====~--., ------... --.... ------ - -- - -- -----...... -----...... _ - _.... - -- - --- ~ --~ ----,_.,.....,.,_., - NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 212 (ESTIMATE) PGC PGC Cost of Over(Under) Interest Interest Interest Sales Rate Revenue Fuel Collections Rate Weight Amount Mcf $1Mcf $ $ $ % $ (1) (2) (3=1 x2) (4) (5=3-4) (6) (7) (8=5x6x7) December 3,866 5.2854 2,433 2,216,714 4.5184 1,16,1 Storage Inventory Recovery 63,658 Reimbursement of NFGSC Transfer Fee 19 Market Rate Differential City Gate Imbalance 28 NGV 51 5.4137 2,761 LBS - Commodity 628 4.5184 2,838 2,221,718 1,15,918 12,47,756 (1,941,838) 8.% 14 I 12 (181,238) 212 January 3,126,35 4.5184 14,124,677 Storage Inventory Recovery 36,143 Reimbursement of NFGSC Transfer Fee 4 Market Rate Differential City Gate Imbalance 22 NGV 448 5.4137 2,425 LBS -Commodity 4.5184 3,126,483 14,163,271 13,335,92 828,179 8.% 13 I 12 71,776 February 1,473,19 4.5184 6,656,462 1,523,289 3.6215 5,516,591 Storage Inventory Recovery 5,47 Reimbursement of NFGSC Transfer Fee 4 Market Rate Differential City Gate Imbalance NGV 582 5.4137 3,151 LBS - Commodity 4.5184 2,997,61 12,181,678 11,39,597 872,81 8.% 12 I 12 69,766 March 2,371,74 3.6215 8,589,256 Storage Inventory Recovery 19 Reimbursement of NFGSC Transfer Fee 4 Market Rate Differential City Gate Imbalance * NGV 664 4.5158 2,998 -R 8 ~ 3- g ~ Z; - m.. Q -X 2,372,44 8,592,277 6,15,28 2,442,69 8.% 11 I 12 179,85 E-o ~ g; -u :J=i ;::::;: CD-< 1\J 1\J _.. ~ (,.)

NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 212 (ESTIMATE) Sales Mcf (1) PGC Rate $1Mcf (2) PGC Revenue $ (3=1x2) Cost of Fuel $ (4) Over(Under) Collections $ (5=3-4) Interest Rate % (6) Interest Weight (7) Interest Amount $ (8=5x6x7) April 1,715,596 3.6215 6,213,31 Storage Inventory Recovery Reimbursement of NFGSC Transfer Fee Market Rate Differential City Gate Imbalance NGV 69 4.5158 3,116 LBS - Commodity --~27:...:6:._ 3.6215 1, 1,716,562 6,217,147 (127,615) 6,344,762 8.% 1 I 12 422,984 May 626,645 3.6215 439,89 3.1213 Storage Inventory Recovery Reimbursement of NFGSC Transfer Fee Market Rate Differential City Gate Imbalance 2,269,395 1,373,29 7,217 19 NGV 666 4.5158 3,8 LBS - Commodity :_,:16::..;,7_ 3.6215 65 1,67,368 3,653,273 1,12,292 2,55,981 8.% 9 I 12 153,59 June 436,89 3.1213 1,361 '165 Storage Inventory Recovery Reimbursement of NFGSC Transfer Fee Market Rate Differential City Gate Imbalance 35,72 15 3 NGV 584 4.674 2,375 LBS - Commodity.:_41.:...:5::_ 3.1213 1,295 437,88 1,4,87 99,969 49,91 8.% 8 I 12 26,181 July 33,794 3.1213 948,232 Storage Inventory Recovery Reimbursement of NFGSC Transfer Fee Market Rate Differential City Gate Imbalance Sales Cashout NGV 278 4.674 4,499 27 626 6,89 1,131 LBS- Commodity..:...96.:.,_9_ 3.1213 3,25 35,41 999,629 29,841 789,788 Total 17,35,976 72,15,758 55,4,499 17,11,259 8.% 7 I 12 36,857 1,325,489 cocncn"'' " :::T G) &r~m~o -~-c..m ~o~s.x ~ <D::!. ::l:::::j -.~g <D-< 1\:) 1\:) ~ s (,)

- - ~ --- - ~ -~ -1-...- - --~--~- ::='=.=::.==..,-e.:-f".-- - --- ---- -- -----!... '=""" ------- - - ------ --... -, ------- - ----------- ----- =-=--=-- = --= =---=--============= NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 212 (ACTUAL) PGC PGC Cost of Over(Under) Interest Interest Interest Sales Rate Revenue Fuel Collections Rate Weight Amount Mcf $/Mcf $ $ $ % $ (1) (2) (3=1X2) (4) (5=3-4) (6) (7) (8=5x6x7) 211 August 168,974 5.1438 869,168 16,582 5.2854 848,74 Storage Inventory Recovery 162,669 Reimbursement of NFGSC Transfer Fee 15 Market Rate Differential City Gate Imbalance NGV 6 5.9322 356 LBS - Commodity 1,12 5.1438 5,26 33,628 1,886,154 2,72,384 {186,23) 8.% 18 I 12 (22,348) September. 398,454 5.2854 2,15,989 Storage Inventory Recovery 289,994 Reimbursement of NFGSC Transfer Fee 15 Market Rate Differential City Gate Imbalance 261 NGV 198 6.2578 1,239 LBS - Commodity 2,56 5.2854 1,867 4,78 2,48,365 (4, 169, 153) 6,577,518 8.% 17 I 12 745,452 October 661,444 5.2854 3,495,996 Storage Inventory Recovery 39,91 Reimbursement of NFGSC Transfer Fee 23 Market Rate Differential City Gate Imbalance 23 NGV 64 6.2578 3,78 LBS - Commodity 2,731 5.2854 14,434 664,779 3,553,347 4,961,842 (1,48,495) 8.% 16 I 12 (15,239) November 771,799 5.2854 4,79,266 622,795 4.5184 2,814,37 Storage Inventory Recovery 37,435 Reimbursement of NFGSC Transfer Fee 23 Market Rate Differential City Gate Imbalance 4,522 NGV 47 6.2578 2,547 LBS - Commodity 1,135 5.2854 5,999 CO(I)Cf)-o -oo::rng) 1,396,136 6,943,829 7,22,286 (258,457) 8.% 15 I 12 (25,846) ~~~~() ~5z;;~~ c...o ro:!. c_ -...JC" ::J-1 ;::;:: <1>-< N N... ~ c.v

NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 212 (ACTUAL) PGC PGC Cost of Over(Under) Interest Interest Interest Sales Rate Revenue Fuel Collections Rate Weight Amount Mcf $1Mcf $ $ $ % $ (1) (2) (3=1x2) (4) (5=3-4) {6) (7) (8=5x6x7) December 3,866 5.2854 2,433 2,216,714 4.5184 1,16,1 Storage Inventory Recovery 63,658 Reimbursement of NFGSC Transfer Fee 19 Market Rate Differential City Gate Imbalance 28 NGV 51 5.4137 2,761 LBS - Commodity 628 4.5184 2,838 2,221,718 1,15,918 12,47,756 (1,941,838) 8.% 14 I 12 (181,238) 212 January 3,126,35 4.5184 14,124,677 Storage Inventory Recovery 36,143 Reimbursement of NFGSC Transfer Fee 4 Market Rate Differential City Gate Imbalance 22 NGV 448 5.4137 2,425 LBS - Commodity 4.5184 3,126,483 14,163,271 13,335,92 828,179 8.% 13 I 12 71,776 February 1,473,19 4.5184 6,656,462 1,523,289 3.6215 5,516,591 Storage Inventory Recovery 5,47 Reimbursement of NFGSC Transfer Fee 4 Market Rate Differential City Gate Imbalance 1\!GV 582 5.4137 3,151 LBS - Commodity 4.5184 2,997,61 12,181,678 11,39,597 872,81 8.% 12 I 12 69,766 March 2,371,74 3.6215 8,589,256 Storage Inventory Recovery 19 Reimbursement of NFGSC Transfer Fee 4 Market Rate Differential City Gate Imbalance NGV 664 4.5158 2,998 cocncn-o LBS - Commodity 3.6215 2,372,44 8,592,277 6,15,28 2,442,69 8.% 11 I 12 179,85 "CQ::::TOG) fj"s:m~o -s:-c.m ~om x c:.. <1> :::!: =i -..lg: <1>-< 1\) 1\)... ~ w

NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 212 (ACTUAL) Sales Mcf (1) PGC Rate $/Mcf (2) PGC Revenue $ (3=1x2) Cost of Fuel $ (4) Over(Under) Collections $ (5=3-4) Interest Rate % (6) Interest Weight (7) Interest Amount $ (8=5x6x7) April 1,715,596 3.6215 6,213,31 Storage Inventory Recovery Reimbursement of NFGSC Transfer Fee Market Rate Differential City Gate Imbalance NGV 69 4.5158 3,116 LBS - Commodity 276 3.6215 1, 1,716,562 6,217,147 (127,615) 6,344,762 8.% 1 I 12 422,984 May 626,645 439,89 Storage Inventory Recovery Reimbursement of NFGSC Transfer Fee Market Rate Differential City Gate Imbalance NGV 666 LBS - Commodity 167 1,67,368 3.6215 2,269,395 3.1213 1,373,29 7,217 19 4.5158 3,8 3.6215 65 3,653,273 1,12,292 2,55,981 8.% 9 I 12 153,59 June 436,89 Storage Inventory Recovery Reimbursement of NFGSC Transfer Fee Market Rate Differential City Gate Imbalance NGV 584 LBS - Commodity 415 437,88 3.1213 1,361,165 35,72 15 3 4.674 2,375 3.1213 1,295 1,4,87 99,969 49,91 8.% 8 I 12 26,181 July 33,794 3.1213 948,232 Storage Inventory Recovery Reimbursement of NFGSC Transfer Fee Market Rate Differential City Gate Imbalance Sales cashout NGV 278 4.674 4,499 27 626 6,89 1,131 LBS - Commodity :_96~9:.._ 3.1213 3,25 35,41 999,629 29,841 789,788 Total 17,35,976 72,15,758 55,4,499 17,11,259 8.% 7 I 12 36,857 1,325,489 C(f)(f)<J "OQ:::TC">G) g-~~~ co~-c.m.. o"""-~ x E CD~ ::J::::j """-~g CD-< 1\) ~ ~ (,.)

PGC Exhibit 21 Schedule 7 Sheet 1 DEMAND- NGS Update: June 213 NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Reconciliation of Interest on Over(Under) Collections Twelve Months Ended July 212 Amount $ Estimated Undercollection of gas cost for the twelve month period August 211 through July 212 calculated in PGC-212 (Schedule 7, Pages 2-4) Net Interest Income to be collected (Schedule 7, Pages 2-4} (4,676, 738) (53,626) Total Estimate For the Twelve Months Ended July 212 (5,27,364) Actual Undercollection of gas cost for the twelve month period August 211 through July 212 (Schedule 7, Pages 5-7) (4,676, 738) Net Interest Income to be collected (Schedule 7, Pages 5-7) Total Actual For the Twelve Months Ended July 212 (53,626) (5,27,364)

,_. ~.. ~ "" ---~- --- -". ~--- --- -- ~ - ~ --! --~. "-~- '"... j -" ---- ' --- -- -------- ~ ~ --...,.. ---- ------- --- ----~... ~-~---... -..- NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 212 (ESTIMATE) PGC PGC Cost of Sales Rate Revenue Fuel Mcf $/Mcf $ $ (1) (2) (3=1x2) (4) 211 August 168,974 1.437 241,751 16,582 1.7711 284,47 Standby/Priority 25,191 Standby Overruns 358 LBS- Demand.7884 Overdelivery/Upstream Cap. Surcharge 32,782 329,556 584,489 1,922,751 September - - 398,454 1.7711 75,72 Standby/Priority 3,359 Standby Overruns 88 LBS- Demand.9724 Overdelivery/Upstream Cap. Surcharge 27,994 398,454 764,143 1,46,731 October 661,444 1.7711 1 '171,483 Standby/Priority 54,918 Standby Overruns (21 ) LBS - Demand.9724 Overdelivery/Upstream Cap. Surcharge 31,61 661,444 1,257,81 1,969,17 November 771,799 1.7711 1,366,933 622,795 1.682 1,1,579 Standby/Priority 65,787 Standby Overruns 49 LBS- Demand.9724 Overdeiivery/Upstream Cap. Surcharge 35,233 1,394,594 2,469,581 3,563,47 Over(Under) Interest Interest Collections Rate Weight $ % (5=3-4) (6) (7) (1,338,262) 8.% 18 I 12 (282,588) 8.% 17 I 12 (711,36) 8.% 16 I 12 (1,93,889) 8.% 15 I 12 Interest Amount $ (8=5x6x7) (16,591) (32,27) (75,873) (19,389) cocncn-o -om::tog) ar5:reafo -)>-c..m ~ZN x.. < ::T ~~ ~g 1\)G) ~ sen U)

NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 212 (ESTIMATE) PGC PGC Cost of Sales Rate Revenue Fuel Mcf $/Mcf $ $ (1) (2) (3=1x2) (4) December 3,866 1.7711 6,847 2,216,714 1.682 3,564,919 Standby/Priority 87,514 Standby Overruns 2,397 LBS- Demand.8953 Overdelivery/Upstream Cap. Surcharge 44,739 2,22,58 3,76,416 5,16,826 212 January 3,126,35 1.682 5,27,289 Standby/Priority 13,529 Standby Overruns 64 LBS- Demand.8953 Overdelivery/Upstream Cap. Surcharge 43,714 3,126,35 5,175,136 6,37,89 February 1,473,19 1.682 2,369,184 1,523,289 1.5993 2,436,196 Standby/Priority 93,768 Standby Overruns 5,378 LBS- Demand.8953 OverdeHvery/Upstream Cap. Surcharge 43,119 2,996,479 4,947,645 5,97,837 March 2,371,74 1.5993 3,793,124 Standby/Priority 67,878 Standby Overruns 1,281 LBS- Demand.8943 Overdelivery/Upstream Cap. Surcharge 51,247 2,371,74 3,913,53 3,991,385 Over(Under) Interest Interest Collections Rate Weight $ % (5=3-4) (6) (7) (1,31,41) 8.% 14 I 12 (1,131,953) 8.% 13 I 12 (96, 192) 8.% 12 I 12 (77,855) 8.% 11 I 12 Interest Amount $ (8=5x6x7) (122,35) (98, 1 3) (76,815) (5,79) CO(I)(I)"U -om ::r o G) ars=~ifio Ci)l>-o.m ZW x c.._ CD ::r ~~ --Jg 1\)G) ~ ~(/) w

NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 212 (ESTIMATE) PGC PGC Cost of Over(Under) Interest Interest Interest Sales Rate Revenue Fuel Collections Rate Weight Amount Mcf $/Mcf $ $ $ % $ (1) (2) (3=1x2) (4) (5=3-4) (6) (7) (8=5x6x7) April 1,715,596 1.5993 2,743,753 Standby/Priority 63,6 Standby Overruns 5 LBS- Demand 267.8943 239 Overdelivery/Upstream Cap. Surcharge 51,223 1,715,596 2,858,865 1,71,962 1,786,93 8.% 1 I 12 119,127 May 626,645 1.5993 1,2,193 439,89 1.6891 743,18 Standby/Priority 35,125 Standby Overruns 12 LBS- Demand 267.8943 239 Overdelivery/Upstream Cap. Surcharge 39,346 1,66,535 1,819,933 921,756 898,177 8.% 9 I 12 53,891 June 436,89 1.6891 736,598 Standby/Priority 24,411 Standby Overruns 11 LBS- Demand.9461 OverdeHvery/Upstream Cap. Surcharge 37,774 436,89 798,794 1,36,14 (237,22) 8.% 8 I 12 (12,652) July 33,794 1.6891 513,138 Standby/Priority 2,216 Standby Overruns 15 LBS- Demand 267.9461 253 Overdelivery/Upstream Cap. Surcharge 32,633 33,794 566,255 784,399 (218, 144) 8.% 7 I 12 (1, 18) Total 17,2,896 28,862,588 33,539,325 (4,676,738) (53,626) cocncn"' -om:jog) o.s::m~o!!l.)>-c.m ~Z.f:>. x c:..o CD:J c: ' --!' ~z ;:::;: 1\){j) ~ ~en (.,)

NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 212 (ACTUAL) PGC PGC Cost of Over(Under) Interest Interest Interest Sales Rate Revenue Fuel Collections Rate Weight Amount Mcf $/Mcf $ $ $ % $ (1) (2) (3=1x2) (4) (5=3-4) (6) (7) (8=5x6x7) 211 August 168,974 1.437 241,751 16,582 1.7711 284,47 Standby/Priority 25,191 Standby Overruns 358 LBS- Demand.7884 Overdelivery/Upstream Cap. Surcharge 32,782 329,556 584,489 1,922,751 (1,338,262) 8.% 18 I 12 (16,591) September - 398,454 1.7711 75,72 Standby/Priority 3,359 Standby Overruns 88 LBS- Demand.9724 Overdelivery/Upstream Cap. Surcharge 27,994 398,454 764,143 1,46,731 (282,588) 8.% 17 I 12 (32,27) October 661,444 1.7711 1,171,483 Standby/Priority 54,918 Standby Overruns (21 ) LBS- Demand.9724 Overdelivery/Upstream Cap. Surcharge 31,61 661,444 1,257,81 1,969,16 (711,35) 8.% 16 I 12 (75,873) November 771,799 1.7711 1,366,933 622,795 1.682 1,1,579 Standby/Priority 65,787 Standby Overruns 49 LBS- Demand.9724 Overdelivery/Upstream Cap. Surcharge 35,233 1,394,594 2,469,581 3,563,47 (1,93,889) 8.% 15 I 12 (19,389) CO(J)(J)""U -om::tog) &rs:mi5o -)>-o.m ~ZUl!:.x c...o CD::T c:, -.JC' ;::;: ~z I'\) G) ~ ~(/) c.v

----- --- - -- - --c=.:::. =...:..::l.== -- -.. ~----.-~~==-=-----~ - -~ - - - --,... ' ~ -~ -- - ~--- - - -""""- - '------- -------- ~-- -- --- - ---~-- ~ - - ---- --- - :~1-::~c::=.-: - - - ------... -- -.- "' -. -- - ~ ""'-- ~--- ---- -.. -,_ ~ NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 212 (ACTUAL) PGC PGC Cost of Over(Under) Interest Interest Interest Sales Rate Revenue Fuel Collections Rate Weight Amount Mcf $/Mcf $ $ $ % $ (1) (2) (3=1x2) (4) (5=3-4) (6) (7) (8=5x6x7) December 3,866 1.7711 6,847 2,216,714 1.682 3,564,919 Standby/Priority 87,514 Standby Overruns 2,397 LBS- Demand.8953 Overdelivery/Upstream Cap. Surcharge 44,739 2,22,58 3,76,416 5,16,827 (1,31,411) 8.% 14 I 12 (122,35) 212 January 3,126,35 1.682 5,27,289 Standby/Priority 13,529 Standby Overruns 64 LBS- Demand.8953 Overdelivery/Upstream Cap. Surcharge 43,714 3,126,35 5,175,136 6,37,9 (1 '131,954) 8.% 13 I 12 (98,13) February 1,473,19 1.682 2,369,184 1,523,289 1.5993 2,436,196 Standby/Priority 93,768 Standby Overruns 5,378 LBS- Demand.8953 Overdelivery/Upstream Cap. Surcharge 43,119 2,996,479 4,947,645 5,97,837 (96, 192) 8.% 12 I 12 (76,815) March 2,371,74 1.5993 3,793,124 Standby/Priority 67,878 Standby Overruns 1,281 LBS- Demand.8943 Overdelivery/Upstream Cap. Surcharge 51,247 2,371,74 3,913,53 3,991,385 (77,855) 8.% 11 I 12 (5,79) cocncn-u -cm:tog) g-~~~!lr~q;~~ LO <ll:t c: ' "': :::+ ffiz rvcv ~ sen (.o)

NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 212 (ACTUAL) PGC PGC Cost of Over(Under) Interest Interest Interest Sales Rate Revenue Fuel Collections Rate Weight Amount Met $/Met $ $ $ % $ (1) (2) (3=1x2) (4) (5=3-4) (6} (7) (8=5x6x7) April 1,715,596 1.5993 2,743,753 Standby/Priority 63,6 Standby Overruns 5 LBS- Demand 267.8943 239 Overdelivery/Upstream Cap. Surcharge 51,223 1,715,596 2,858,865 1,71,962 1,786,93 8.% 1 I 12 119,127 May 626,645 1.5993 1,2,193 439,89 1.6891 743,18 Standby/Priority 35,125 Standby Overruns 12 LBS- Demand 267.8943 239 Overdelivery/Upstream Cap. Surcharge 39,346 1,66,535 1,819,933 921,756 898,177 8.% 9 I 12 53,891 June 436,89 1.6891 736,598 Standby/Priority 24,411 Standby Overruns 11 LBS- Demand.9461 Overdelivery/Upstream Cap. Surcharge 37,774 436,89 798,794 1,36,14 (237,22) 8.% 8 I 12 (12,652) July 33,794 1.6891 513,138 Standby/Priority 2,216 Standby Overruns 15 LBS- Demand 267.9461 253 Overdelivery/Upstream Cap. Surcharge 32,633 33,794 566,255 784,399 (218, 144} 8.% 7 I 12 (1, 18) Total 17,2,896 28,862,588 33,539,325 (4,676,738) (53,626} CO(I)(I)"'O -cm::rog) a.s:m15o ~J>-o.m ~Z-..J x c...o <D::T c ' -..JC' ;::o: ffiz I'\) G) ~ ~(/) w

PGC Exhibit 21 Schedule 7 Sheet 1 DEMAND-DC Update: June 213 NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Reconciliation of Interest on Over(Under) Collections Twelve Months Ended July 212 Amount $ Estimated Undercollection of gas cost for the twelve month period August 211 through July 212 calculated in PGC 212 (Schedule 7, Pages 2-3) (966,49) Net Interest Expense to be refunded (Schedule 7, Pages 2-3) (64,648) Total Estimate For the Twelve Months Ended July 212 (1,31 '138) Actual Overcollection of gas cost for the twelve month period August 211 through July 212 (Schedule 7, Pages 4-5) (966,49) Net Interest Expense to be refunded (Schedule 7, Pages 4-5) (64,648) Total Actual For the Twelve Months Ended July 212 (1,31 '138) Amount to be Refunded

~-~~~===~~===~= ------- --. ---- - -------- ------- - - -- ------- -.- ---- --- --- - -----"" ------------- - - -------- --.,... ---- - A~-~-~ ~~~~-~-~~-~~-- ~----- ~- -- --~---- "' -- ----.. ------ ----- --- ---- -~ ~ --- NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 212 (ESTIMATE) PGC PGC Cost of Over(Under) Interest Interest Interest Sales Rate Revenue Fuel Collections Rate Weight Amount Mcf $1Mcf $ $ $ % $ (1) (2) (3=1 x2) (4) (5=3-4) (6) (7) (8=5x6x7) 211 August 168,974.2276 38,458 16,582.2627 42,185 -~ATC 17,739.2276 4,37 '~ SATC 15,982.2627 4,198 363,277 88,878 466,888 (378,1) 6.% 18 I 12 (34,21) September.2276 398,454.2627 14,674 SATC.2276 SATC 39,19.2627 1,274 437,563 114,948 466,888 (351,94) 6.% 17 I 12 (29,915) October 661,444.2627 173,761 SATC 72,218.2627 18,972 733,662 192,733 521,142 (328,49) 6.% 16 I 12 (26,273) November 771,799.2627 22,752 622,795.2643 164,65 SATC 86,124.2627 22,625 SATC 67,957.2643 17,961 1,548,675 47,943 521,142 (113, 199) 6.% 15 I 12 (8,49) December 3,866.2627 1,16 2,216,714.2643 585,878 SATC 41.2627 15 SATC 245,331.2643 64,841 2,466,312 651,84 521 '144 13,696 6.% 14 I 12 9,149 212 January 3,126,35.2643 826,211 SATC 348,2.2643 92,29 3,474,235 918,24 521,8 397,16 6.% 13 I 12 25,815 CQ(/)(/)"" -om:::tog) ars:mffio -)>-a.m ~ZI' x c...o <D:::T c: ' -.~g: ~ 1\) ~ (..)

------ ------ ----~- -- NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 212 (ESTIMATE) PGC PGC Cost of Over(Under) Interest Interest Interest Sales Rate Revenue Fuel Collections Rate Weight Amount Mcf $/Mcf $ $ $ % $ (1) (2) (3=1X2) (4) (5=3-4) (6) (7) (8=5x6x7) February 1,473,19.2643 389,364 1,523,289.2711 412,964 SATC 165,774.2643 43,814 SATC 17,475.2711 46,216 3,332,728 892,358 521,669 37,689 6.% 12 I 12 22,241 March 2,371,74.2711 642,979 SATC 266,741.2711 72,313 2,638,481 715,292 521,669 193,623 6.% 11 I 12 1,649 April 1,715,596.2711 465,98 SATC 196,598.2711 53,298 1,912,194 518,396 467,148 51,248 6.% 1 I 12 2,562 May 626,645.2711 169,883 439,89.2896 127,392 SATC 74,321.2711 2,148 SATC 51,84.2896 15,13 1,192,696 332,436 53,87 (171,371) 6.% 9 I 12 (7,712) June 436,89.2896 126,291 SATC 52,738.2896 15,273 488,827 141,564 53,697 (362,133) 6.% 8 I 12 (14,485) July 33,794.2896 87,979 SATC 37,549.2896 1,874 341,343 98,853 53,697 (44,844) 6.% 7 I 12 (14,17) CO(f)(f)IJ Total 18,929,993 5,73,481 6,39,971 (966,49) (64,648) -om::::rog) g-~~~ -)>-c..m ~zc.> x c...o <::::1" c, -...~g ~ 1\) ~ ~ c.>

- =..~~==~=~~...=b._, -r - -- ------ "'"'""'"" :! -~- ~ - -.,.. -~ -~- - ~ -.. - -.., ~--! NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 212 (ACTUAL) PGC PGC Cost of Over(Under) Interest Interest Interest Sales Rate Revenue Fuel Collections Rate Weight Amount Mcf $/Met $ $ $ % $ (1) (2) (3=1 x2) (4) (5=3-4) (6) (7) (8=5x6x7) 211 August 168,974.2276 38,458 16,582.2627 42,185 SATC 17,739.2276 4,37 SATC 15,982.2627 4,198 363,277 88,878 466,888 (378,1) 6.% 18 I 12 (34,21) September.2276 398,454.2627 14,674 SATC.2276 SATC 39,19.2627 1,274 437,563 114,948 466,888 (351,94) 6.% 17 I 12 (29,915) October 661,444.2627 173,761 SATC 72,218.2627 18,972 733,662 192,733 521 '142 (328,49) 6.% 16 I 12 (26,273) November 771,799.2627 22,752 622,795.2643 164,65 SATC 86,124.2627 22,625 SATC 67,957.2643 17,961 1,548,675 47,943 521 '142 (113,199) 6.% 15 I 12 (8,49) December 3,866.2627 1,16 2,216,714.2643 585,878 SATC 41.2627 15 SATC 245,331.2643 64,841 2,466,312 651,84 521,144 13,696 6.% 14 I 12 9,149 CO(f)(f)""'' -om:::jng) g-s:m~o 212 January 3,126,35.2643 826,211 ~~:; ~ c...o CD:::J" c ---.~a= SATC 348,2.2643 92,29 ;:::;: 15o 3,474,235 918,24 521,8 397,16 6.% 13 I 12 25,815 1\) ~ ~ (.V

NATIONAL FUEL GAS DISTRIBUTION CORPORATION PENNSYLVANIA DIVISION STATEMENT OF TOTAL OVER(UNDER) COLLECTIONS TWELVE MONTHS ENDED JULY 212 (ACTUAL) PGC PGC Cost of Over(Under) Interest Interest Interest Sales Rate Revenue Fuel Collections Rate Weight Amount Mcf $1Mcf $ $ $ % $ (1) (2) (3=1x2) (4) (5=3-4) (6) (7) (8=5x6x7) February 1,473,19.2643 389,364 1,523,289.2711 412,964 SATC 165,774.2643 43,814 SATC 17,475.2711 46,216 3,332,728 892,358 521,669 37,689 6.% 12 I 12 22,241 March 2,371,74.2711 642,979 SATC 266,741.2711 72,313 2,638,481 715,292 521,669 193,623 6.% 11 I 12 1,649 April 1,715,596.2711 465,98 SATC 196,598.2711 53,298 1,912,194 518,396 467,148 51,248 6.% 1 I 12 2,562 May 626,645.2711 169,883 439,89.2896 127,392 74,321.2711 2,148 SATC 51,84.2896 15,13 1,192,696 332,436 53,87 (171,371) 6.% 9 I 12 (7,712) June 436,89.2896 126,291 SATC 52,738.2896 15,273 488,827 141,564 53,697 (362, 133) 6.% 8 I 12 (14,485) July 33,794.2896 87,979 SATC 37,549.2896 1,874 341,343 98,853 53,697 (44,844) 6.% 7 I 12 (14,17) Total 18,929,993 5,73,481 6,39,971 (966,49) (64,648) c:ocncn-o -om::::tng) ~$:~~() 1ir~;;;~!Jl (l)::::t -Jg c O c:::, ~ I'Q() ~ ~ w

PGC Exhibit 21 Schedule a Sheet 1 COMMODITY Update: June 213 NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Calculation of Over(Under) Collection Balances Included in the PGC 213 Description Reconciliation of over/(under)collection of gas cost for the twelve month period August 21 through July 211 originating in PGC 11 Amount $ Amount $ Estimated amount refunded/(recovered) during the period August 211 through July 212 2,938,814 Actual amount refunded/(recovered) during the period August 211 through July 212 SALES Rate Mcf RefundL{Surcharge) August 211.4678 361,992 169,34 September 211.855 436,397 37,312 October 211.855 727,65 62,214 November 211.1214 1,51,558 182,289 December 211.1658 2,349,839 389,63 January -July 212.1659 12,435,151 2,62,992 17,812,587 2,93,75 MIGRATION August 211.4847 5,747 2,785 September 211.855 9,433 87 October 211.855 9,982 853 November 211.125 19,979 2,47 December 211.1648 29,37 4,83 January- July 212.1659 14,937 23,381 215,384 35,64 2,938,814

PGC Exhibit 21 Schedule 8 Sheet 2 COMMODITY Update: June 213 NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Calculation of Over(Under) Collection Balances Included in the PGC 213 Description Amount $ Estimated balance of over/(under)collection of gas cost for the twelve month period August 211 through July 212 originating in PGC 12 Amount $ Estimated over/(under)collections of gas cost for the twelve month period August 212 through July 213 Estimated amount refunded/(recovered) during the period August 212 through July 213 SALES Rate Mcf RefundL(Surcharge} August 212.553 327,267 18,979 September 212.998 386,718 383,16 October 212.998 789,217 781,956 November 212 1.92 1,478,217 1,491,817 December 212 1.316 2,392,187 2,467,78 January - July 213 1.317 14,713,767 15,18,193 2,87,373 2,485,885 MIGRATION August 212.587 4,556 2,317 September 212.998 5,222 5,174 October 212.998 7,383 7,315 November 212 1.66 13,35 13,121 December 212 1.39 23,943 24,683 January- July 213 1.317 122,659 126,547 176,797 179,157 Amount to be Recovered in PGC 213 19,145,578 2,665,42 {1,519,464}

PGC Exhibit 21 Schedule 8 Sheet 1 DEMAND,NGS Update: June 213 NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Calculation of Over(Under) Collection Balances Included in the PGC 213 Description Reconciliation of over/(under)collection of gas cost for the twelve month period August 21 through July 211 originating in PGC 11 Amount $ Amount $ Estimated amount refunded/(recovered) during the period August 211 through July 212 (436,58) Actual amount refunded/(surcharged) during the period August 211 through July 212 SALES Rate Mcf RefundL(Surcharge} August 211 (.186) 36,92 (6,713) September 211.611 434,143 26,526 October 211.611 724,315 44,256 November 211.181 1,5,16 27,15 December 211 (.352) 2,348,71 (82,674) January - July 212 (.354) 12,429,412 {44,1} 17,797,57 (431,456) LBS&NGV August 21 (.446) 6 (3) September - November 21.293 1,29 35 December 21 - July 211 (.169) 5,223 {88} 6,492 (56) MIGRATION August21 (.221) 5,747 (127) September 21.611 9,433 576 October 21.611 9,982 61 November 21.192 19,979 384 December 21 (.341) 29,37 (999) January- July 211 (.354) 14,937 {4,989} 215,384 (4,546) {436,58}

PGC Exhibit 21 Schedule 8 Sheet 2 DEMAND-NGS Update: June 213 NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Calculation of Over(Under) Collection Balances Included in the PGC 213 Description Amount $ Estimated balance of over/(under)collection of gas cost for the twelve month period August 211 through July 212 originating in PGC 12 Amount $ Estimated over/(under)collection of gas cost for the twelve month period August 212 through July 213 (5,551,418) Estimated amount refunded/(recovered) during the period August 212 through July 213 SALES Rate Mcf Refund August 212 (.1456) 325,942 (47,457) September 212 (.272) 385,43 (1 4, 136) October 212 (.272) 786,89 (212,596) November 212 (.2832) 1,477,2 (418,292) December 212 (.2991) 2,391,72 (715,364) January - July 213 (.2992) 14,241,27 {4,26,969} 19,68,11 (5,758,814) LBS& NGV August 212 (.169) 379 (6) September- November 212 (.1271) 1,851 (235) December 212- July 213 (.148) 3,429 {483} 5,659 (724) MIGRATION August 212 (.1329) 4,556 (65) September 212 (.272) 5,222 (1,411) October 212 (.272) 7,383 (1,995) November 212 (.2813) 13,35 (3,667) December 212 (.2987) 23,943 (7, 152) January -July 213 (.2992) 122,659 {36,7} 176,797 (51,529) Amount to be Refunded in PGC 213 {5,811,67} 259,649

PGC Exhibit 21 Schedule 8 Sheet 1 DEMAND-DC Update: June 213 NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Calculation of Over(Under) Collection Balances Included in the PGC 213 Description Reconciliation of over/(undercollection) of gas cost for the twelve month period August 21 through July 211 originating in PGC 11 Amount $ Amount $ Estimated amount refunded/(recovered) during the period August 211 through July 212 232,558 Actual amount refunded/(recovered) during the period August 211 through July 212 SALES Rate Mcf Refu ndl(s u rcharge) August 211 (.3) 363,277 (1,9) September- October 211.18 1 '171,225 12,649 November 211.117 1,548,674 18,12 December 211 - July 212.128 15,846,818 22,839 18,929,994 232,519 LBS&NGV August 211 (.76) 6 () September- November 211.51 1,29 6 December 211 - July 212.62 5,223 32 6,492 39 232,558

PGC Exhibit 21 Schedule 8 Sheet 2 DEMAND-DC Update: June 213 NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Calculation of Over(Under) Collection Balances Included in the PGC 213 Description Estimated balance of over/(under)collection of gas cost for the twelve month period August 211 through July 212 originating in PGC 12 Estimated over/{under)collections of gas cost for the twelve month period August 212 through July 213 Amount $ Amount $ (1,3,98) Estimated amount refunded(recovered) during the period August 212 through July 213 SALES Rate Mcf RefundL(Surcharge) August 212 (.152) 354,839 {5,394) September 212 (.468) 421,218 (19,713) October 212 (.468) 864,14 (4,44) November 212 (.47) 1,623,843 (76,321) December 212 (.472) 2,628,833 (124,81) January 213- July 213 (.472) 16,254,71 {767,222} 22,147,547 (1,33,171) LBS& NGV August 212.62 379 2 September- November 212 (.221) 1,851 (41) December 212 -July 213 (.223) 3,429 {76} 5,659 (115) Amount to be Refunded in PGC 213 (1,33,286) 29,36

PGC Exhibit 21 Schedule 9 Sheet 1 COMMODITY Update: June 213 NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Calculation of Refund or (Surcharge) Balances Included in the PGC 213 Description Reconciliation of refund/(surcharge) established in PGC 12 Amount $ Amount $ Estimated amount refunded/(recovered) during the period August 211 through July 212 Actual amount refunded/(recovered) during the period August 211 through July 212 SALES Rate Mcf RefundL(Surcharge) August 211. 361,992 September 211. 436,397 October 211. 727,65 November 211. 1,51,558 December 211. 2,349,839 January-July 212. 12,435,151 17,812,587 MIGRATION August 211. 5,747 September 211. 9,433 October 2 11. 9,982 November 211. 19,979 December 211. 29,37 January- July 212. 14,937 215,384

PGC Exhibit 21 Schedule 9 Sheet 2 COMMODITY Update: June 213 NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylv.ania Division Calculation of Refund or (Surcharge) Balances Included in the PGC 213 Description Amount $ Amount $ Reconciliation of refund/(surcharge) established in PGC 12 Estimated amount refunded/(recovered) during the period August 212 through July 213 91,689 Estimated amount refunded/(recovered) during the period August 211 through July 212 SALES Rate Mcf Refu ndl(surcharge} August 212.23 327,267 753 September 212.5 386,718 1,934 October 21 2.5 789,217 3,946 November 212.5 1,478,217 7,391 December 212.5 2,392,187 11,961 January- July 213.5 14,713,767 73,569 2,87,373 99,554 MIGRATION August 212.21 4,556 1 September 212.5 5,222 26 October 212.5 7,383 37 November 212.5 13,35 65 December 212.5 23,943 12 January- July 213.5 122,659 613 176,797 871 1,425 Amount to be Recovered (8,736)

PGC Exhibit 21 Schedule 9 Sheet 1 DEMAND-NGS Update: June 213 NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Calculation of Refund or Surcharge Balances Included in the PGC 213 Descrigtion Reconciliation of refund or (surcharge) established in PGC 11 Estimated amount refunded/(recovered) during the period August 211 through July 212 Actual amount refunded/(recovered) during the period August 211 through July 212 Amount $ Amount $ 2,656,57 SALES Rate Met RefundL(Surcharge) August 211.114 36,92 36,597 September 211.1483 434,143 64,383 October 211.1483 724,315 17,416 November 211.1483 1,5,16 222,452 December 211.1484 2,348,71 348,547 January - July 212.1484 12,429,412 1,844,525 17,797,57 2,623,921 LBS& NGV August 211.272 6 2 September - November 211.71 1,29 86 December 211 - July 212.71 5,223 371 6,492 458 MIGRATION August 211.994 5,747 571 September 211.1483 9,433 1,399 October 211.1483 9,982 1,48 November 211.1483 19,979 2,963 December 211.1484 29,37 4,349 January - July 212.1484 14,937 2,915 215,384 31,678 2,656,57

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division PGC Exhibit 21 Schedule 9 Sheet 2 DEMAND-NGS Update: June 213 Calculation of Refund or Surcharge Balances Included in the PGC 213 Descrigtion Reconciliation of refund or (surcharge) established in PGC 12 Estimated amount refunded/(recovered) during the period August 212 through July 213 Estimated amount refunded/(recovered) during the period August 212 through July 213 Amount $ Amount $ 616,55 SALES Rate Mcf RefundL(Surcharge} August212.943 325,942 3,736 September 212.331 385,43 12,757 October 212.331 786,89 26,43 November 212.331 1,477,2 48,889 December 212.332 2,391,72 79,45 January - July 213.332 14,241,27 472,88 19,68,11 67,639 LBS&NGV August212.71 379 27 September - November 212.156 1,851 29 December 211 - July 213.156 3,429 53 5,659 19 MIGRATION August 212.15 4,556 458 September 212.331 5,222 173 October 212.331 7,383 244 November 212.331 13,35 431 December 212.332 23,943 795 January -July 213.332 122,659 4,72 176,797 6,174 Amount to be Recovered 676,922 (6,867}

PGC Exhibit 21 Schedule 9 Sheet 1 DEMAND-DC Update: June 213 NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Calculation of Refund or Surcharge Balances Included in the PGC 213 Descrigtion Reconciliation of refund or (surcharge) established in PGC 12 Amount $ Amount $ Estimated amount refunded/(recovered) during the period August 211 through July 212 Actual amount refunded/(recovered) during the period August 211 through July 212 SALES Rate Mcf RefundL(Surcharge} August 211. 363,277 September - October 211. 1,171,225 November 211. 1,548,674 December - July 212. 15,846,818 18,929,994 LBS&NGV August 211. 6 September - November 211. 1,29 December 211 - July 212. 5,223 6,492

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division PGC Exhibit 21 Schedule 9 Sheet 2 DEMAND- DC Update: June 213 Calculation of Refund or Surcharge Balances Included in the PGC 213 DescriRtion Reconciliation of refund or (surcharge) established in PGC 12 Estimated amount refunded/(recovered) during the period August 212 through July 2123 Estimated amount refunded/(recovered) during the period August 212 through July 213 Amount $ Amount $ 1,48,49 SALES Rate Mcf RefundL{Surcharge} August212.311 354,839 11,35 September 212.662 421,218 27,885 October 212.662 864,14 57,24 November 212.662 1,623,843 17,498 December 212.662 2,628,833 174,29 January - July 213.662 16,254,71 1,76,62 22,147,547 1,453,713 LBS&NGV August212. 379 September- November 212.313 1,851 58 December 211 - July 213.313 3,429 17 5,659 165 Amount to be Recovered in PGC 213 1,453,878 {45,829}

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Refunds From and Payments to Gas Suppliers Refuncl From Date Received Refund Amount $ Rate INTEREST Weight Amount Total Refund Plus Interest A. TOTAL 6.% o I 12 ---- cocn-u "'OQO(i) ~$:~ m$:o.m.. o x 2-om::r. :J::::jog (!)-< 1\) 1\) ~ c.:>

PGC Exhibit 21 Schedule 11 Sheet 1 COMMODITY- STORAGE Update: June 213 NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Calculation of Reconciliation of Interest on Storage Injections/Withdrawals Description Reconciliation of interest expense/(income) due to/(from) customers for the twelve month period August 211 through July 212 originating in PGC 12 (PGC 21 - Rec. E-factor) Estimated amount passed back/(recovered) during the period August 211 through July 212 in E Factor Amount $ (77,939) Actual amount passed back/(recovered) during the period August 211 through July 212 in E-Factor SALES Rate Mcf RefundL(Surcharge} August 211 (.29) 361,992 (1,5) September 211 (.6) 436,397 (2,618) October 211 (.6) 727,65 (4,366) November 211 (.52) 1,51,558 (7,88) December 211 (.42) 2,349,839 (9,869) January - July 212 (.42) 12,435,151 {52,228~ 17,812,587 (77,939) MIGRATION August 211 (.28) 5,747 (16) September 211 (.6) 9,433 (57) October 211 (.6) 9,982 (6) November 211 (.52) 19,979 (14) December 211 (.42) 29,37 (123) January- July 212 (.42) 14,937 {592~ 215,384 (951) (78,891) Amount to be Refunded in PGC 213 952

PGC Exhibit 21 Schedule 11 Sheet 2 COMMODITY - STORAGE Update: June 213 NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Calculation of Reconciliation of Interest on Storage Injections/Withdrawals Description Estimated interest expense/{income) due to/{from) customers for the twelve month period August 211 through July 212 in C-Factor (PGC 211 - C Factor) Amount $ 259,253 Actual amount passed back/{recovered) during the period August 211 through July 212 in C Factor SALES Rate Mcf RefundL(Surcharge) August 211.12 33,628 3,372 September 211.187 4,78 7,493 October 211.187 664,779 12,431 November 211.213 1,396,136 29,738 December 211.245 2,221,718 54,432 January 212.245 3,126,483 76,599 February 212.158 2,997,61 47,354 March 212.74 2,372,44 17,556 April 212.74 1,716,562 12,73 May 212.19 1,67,368 2,28 June - July 212 (.6) 742,129 {4,453~ 17,35,976 259,253 259,253 Amount to be Refunded in PGC 213

PGC Exhibit 21 Schedule 11 Sheet 3 COMMODITY - STORAGE Update: June 213 NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Calculation of Reconciliation of Interest on Storage Injections/Withdrawals Description Estimated balance of interest expense/(income) due to/(from) customer for the twelve month period August 211 through July 212 originating in PGC 12 (PGC 211- Rec. E-factor) Amount $ Estimated interest expense/(income) due to/(from) customers for the twelve month period August 211 through July 212 in C/E Factor (323,832) Estimated amount passed back/(recovered) during the period August 212 through July 213 in E Factor SALES Rate Mcf RefundL(Surcharge} August212 (.16) 327,267 (3,469) September 212 (.177) 386,718 (6,845) October 212 (.177) 789,217 (13,969) November 212 (.176) 1,478,217 (26,17) December 212 (.174) 2,392,187 (41,624) January- July 213 (.174) 14,713,767 {256,2} 2,87,373 (347,943) MIGRATION August 212 (.98) 4,556 (45} September 212 (.177) 5,222 (92) October 212 (.177) 7,383 (131) November 212 (.176) 13,35 (229) December 212 (.174) 23,943 (417) January - July 213 (.174) 122,659 {2, 134} 176,797 (3,48) (35,991) Amount to be Refunded in PGC 213 27,159

PGC Exhibit 21 Schedule 11 Sheet 4 COMMODITY- STORAGE Update: June 213 NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Calculation of Reconciliation of Interest on Storage Injections/Withdrawals Description Estimated interest expense/(income) due to/(from) customers for the twelve month period August 212 through July 213 in C-Factor (PGC 212 - C factor) Amount $ 486,291 Estimated amount passed back/(recovered) during the period August 212 through July 213 in C Factor SALES Rate Mcf RefundL(Surcharge} August 212.22 316,748 697 September 212.114 374,814 4,273 October 212.114 766,792 8,741 November 212.169 1,438,331 24,38 December 212.237 2,315,52 54,878 January 213.237 3,71,527 72,795 February 213.23 3,39,74 76,123 March 213.222 3,122,962 69,33 April 213.222 2,489,443 55,266 May 213.256 1,42,912 26,699 June - July 213.298 948,833 28,275 19,197,586 421,384 421,384 Amount to be Refunded in PGC 213 64,97

NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Calculation of Interest on Storage Injections/Withdrawals (C Factor Recovery/(Passback)) Twelve Months Ended July 213 Cost Charged Cost Paid Open/ Through PGC By Distribution Storage Gross Closed Rate But Not Paid But Not Charged (Net Paid) I Interest Interest Storage Interest Month Period Injections Withdrawals Differential B~ Distribution Through PGC Net Charged Weight Rate 1 ExQenseL(Revenue} Mcf Mcf $/Mcf $ $ $ % $ (1) (2) (3) (4=2X3) (5=1X3) (6=4+5) (7) (8) (9=[6x(7x8)] August 212 Closed 81,266 42,446 5.173 212,964 {4,65,348) (3,852,384) 12 I 12 8.% {38, 191) September Closed 956,71 26,715 5.173 134,37 (4,8,56) {4,666,19) 11 I 12 8.% {342, 175) October Closed 641,862 237,927 5.3424 1,271,11 (3,429,84) (2, 157,983) 1 I 12 8.% (143,866) November Closed 73,354 798,436 5.3424 4,265,564 (391,886) 3,873,678 9 I 12 8.% 232,421 December Closed 56,588 917,445 5.3424 4,91,358 {32,316) 4,599,42 8 I 12 8.% 245,282 January 213 Closed 75,758 1,91,76 5.3424 1,28,44 {44,73) 9,83,314 7 I 12 8.% 457,488 February Closed 78,753 2,15,643 5.3424 1,768,371 {42,73) 1,347,641 6 I 12 8.% 413,96 March Closed 82,58 1,43,537 5.3424 7,498,256 {438,387) 7,59,869 5 I 12 8.% 235,329 April Closed 715,743 223,93 5.3424 1,196,179 {3,823,785) {2,627,66) 4 I 12 8.% {7,69) May Closed 1,89,911 36,592 5.3424 195,489 {5,822,741) {5,627,252) 3 I 12 8.% {112,545) June Closed 973,621 32,81 5.3424 171,39 {5,21,473) (5,3,83) 2 I 12 8.% {67,68) July Open 1 522 385 5.3424 _(_8Jj93_,18Zl (8, 133, 187) 1 I 12 8.% (54,221) TOTAL 7,77, 7,645,485 4,822,753 (37,233,723) 3,589,3 486,291 Estimated Storage Interest Expense Due to PGC Customers $ 486,291 1 The storaqe over/(under) interest rate was calculated on a stand-alone basis usinq the TME July as the determination period. COcn"' ' ::::T G') g-~mo!ir~:r;r c...o ~ :::j g <D-< 1\.) 1\.) '... ~en w--i ::D )> G') m CD

~... ~-======="================="~..=.=-"':::==--.-.':::~~::;d-:m - - ~-~ - ~,...,- - ~ '±=-=" -~--~"=- -- -- --.--... - -~ -*,... ~' ~--~- -- - -- _,...,,~ ~- ~ c...::::.::===::=::==::--"...::..--~~-- NATIONAL FUEL GAS DISTRIBUTION CORPORATION Pennsylvania Division Calculation of Interest on Storage Injections/Withdrawals (C Factor Recovery/(Passback)) Twelve Months Ended July 214 Open/ Closed Cost Charged Cost Paid Through PGC By Distribution Storage Rate But Not Paid But Not Charged (Net Paid) I Gross Interest Interest Storage Interest Month Period Injections Withdrawals Differential B~ Distribution Through PGC Net Charged Mcf Mcf $/Mcf $ $ $ (1) (2) (3) (4=2x3) (5=1x3) (6=4+5) Weight Rate 1 ExQenseL(Revenue} % $ (7) (8} (9= [6x(7x8)] August 213 Open 1,127,681 5.3424 (6,24,521) (6,24,521) 12 I 12 6.% (361,471) September Open 1,186,813 5.3424 (6,34,429} (6,34,429} 11 I 12 6.% (348,724) October Open 276,442 5.7733 (1,595,984} (1,595,984} 1 I 12 6.% (79,799} November Open 245,344 5.7733 1,416,442 1,416,442 9 I 12 6.% 63,74 December Open 1,1,665 5.7733 5,782,911 5,782,911 8 I 12 6.% 231,316 January 214 Open 1,767,352 5.7733 1,23,453 1,23,453 7 I 12 6.% 357,121 February Open 1,496,231 5.7733 8,638,19 8,638,19 6 I 12 6.% 259,146 March Open 1,39,56 5.7733 8,28,118 8,28,118 5 I 12 6.% 2,73 April Open 23,47 5.7733 (1,33,28) (1,33,28) 4 I 12 6.% (26,64) May Open 1,75,494 5.7733 (6,29, 152) (6,29, 152) 3 I 12 6.% (93, 137) June Open 1,49,356 5.7733 (8, 136,633} (8, 136,633} 2 I 12 6.% (81,366} July Open 979,156 5.7733 (5,652,964) (5!652!964} 12 6.% (28,265) TOTAL 6,285,349 5,91 '151 34,69,114 (35,289,891) (1,22,777) 92,659 Estimated Storage Interest Expense Due to PGC Customers $ 92,659 Remaining PGC Volumes 18 1 554 1 728 1 The storaqe over/(under) interest rate was calculated on a stand-alone basis usinq the TME July as the determination period. PGC (Passback)/Recovery Rate $/ Mcf $ (.5) co en-a " ::::r (j) ~~mo 1~-m.. 1\:l X ~ ~ (!)-< I\) 1\:l, ~ ~en OJ C..:l-1 JJ )> (j) m

I! National Fuel Gas Distribution Corporation Exhibit23 Pennsylvania Division -137(f) 213 Schedule 1 Upstream Purchase & Delivered Volume Page 1 For the Eight Months Ending July 213 Update: 6/13 Com~an~ Com~onent Dec-12 Jan-13 Feb-13 Mar-13 ~r-13 Ma~-13 Jun-13 Jul-13... Total Columbia Demand (D1) 1,748 1,748 1,748 1,748 1,748 1,748 1,748 1,748 13,984 Demand (D2) Receipt Vol. 86,498 115,33 57,665 115,33 374,823 DeHvered Vol. (83) (93) 85,289 114,127 57,7 114,333 37,643 Texas Eastern Demand(D1) 1, 1, 1, 1, 1, 1, 1, 1, 8, Demand (D2) 775 775 7 775 3,25 Receipt Vol. 97 97 87 97 311,462 321,844 311,462 321,844 1,266,99 Delivered Vol. 92 92 83 92 297,72 37,644 297,72 37,644 1,211,87 Tennessee Demand(D1) 74, 74, 74, 74, 74, 74, 74,. 74, 592, ~.~ ( Demand (D2) Receipt Vol. 1,643,184 1,377,928 1,465,556 1,652,96 1,616,46 1,67,288 1,616,46 1,67,288 12,712,962 Delivered Vol. 1,584,542 1,335,175 1,418,638 1,593,911 1,558,683 1,61,639 1,558,683 1,61,639 12,27,91 Transcanada Demand (D1) Demand(D2) Receipt Vol. DeHvered Vol. Total Upstream Purchase Volumes 1,584,551 1,335,267 1,418,721 1,593,91 1,941,692 2,32,41 1,913,473 2,32,616 13,852,64 Total Storage Volumes 114161625 2,212,61 1,7411566 1,1821327 {27,167} {1,1421937} {1147413} {1,635,41} 213,944 Total for NFGDC PAD 3,11176 3,5471868 31161287 2,7761237 1,6711525 889,473 4391443 397,575 15,8831584 F:\RARA\Common\VA,_DATA\1371311orecast1\I.INKYEAR.xts (Upstream Puroh. Vol.)

~--- ~ - _,_-- - -~- --- - -----~:=.... - ----~:;'.;::.::~;=='.:-- d... ::::====.:c=-=.:::..::.~-"=~"'-:c:..=--::::.. ~:=::::==~J- ===========~==~~=-==--=-=- National Fuel Gas Distribution Corporation Pennsylvania Division -137(f) 213 Upstream Purchase & Delivered Volume For the Twelve Months Ending July 214 Company Columbia Texas Eastern Tennessee Transcanada Total Upstream Purchase Volumes Com~onent Demand(D1) Demand(D2) Receipt Vol. Delivered Vol. Demand(D1) Demand(D2) Receipt Vol. Delivered Vol. Demand(D1) Demand(D2) Receipt Vol. Delivered Vol. Demand(D1) Demand(2) Receipt Vol. Delivered Vol. Aug-13 Se~-13 Oct-13 Nov-13 Dec-13 Jan-14 Feb-14 Mar-14 ~r-14 Max-14 Jun-14 Jul-14 Total 1,748 1,748 1,748 1,748 1,748 1,748 1,748 1,748 1,748 1,748 1,748 1,748 2,976 69,198 4,366 28,833 115,33 115,33 115,33 484,387 (129) 68,488 39,736 (276) (83) 28,93 114,127 114,297 114,333 478,585 1, 1, 1, 1, 1, 1, 1, 1, 1, 1, 1, 1, 12, 75 775 n5 7 n5 3,n5 321,844 36,558 321,844 3,388 298,985 247,184 29o,5n 321,71 311,462 321,844 311,462 321,844 3,675,72 37,644 293,33 37,644 287,135 285,912 236,376 2n,872 37,644 297,72 37,644 297,72 37,644 3,513,988 74, 74, 74, 74, 74, 74, 74, 74, 74, 74, 74, 74, 888, 1,356,917 1,587,585 1,171,647 1,47,311 1,631,935 1,3n,929 1,244,58 946,142 1,616,46 1,67,288 1,598,472 1,62,274 16,671,486 1,39,42 1,53,945 1,13,733 1,357,362 1,573,727 1,335,175 1,25,964 913,7 1,558,683 1,61,639 1,541,423 1,25,469 16,92,862 1,616,~57 1.892.~Q_ 1 478,113 1644221 1 859 556 1 571,551 1483836 1221,344 1J!M.496 2,32,41 1,953,44 1,447.446 2.85.435 Total Storage Volumes Total for NFGDC PAD (1.211,129) (1,274.637) (296,899) 263,499 1,75,788 1,898136 1.66.952 1,493.461 (247,457) (1.155,81) (1,513.648) (1.51,614) (412.629) -' 4 45A28 617828 1181214 19772 2935344 3469687 39788 271_4,85 1~.39 877,329 439,792 395,832 19.672.86 "U c G) "B. en ID ~ ~ "' 1\) 1:: ~ id 1\) "' ~ ih ~ 'g F:\RARA\Ccmmon\VA_DATA\137fD3Vorecast1\RATEYEAR.xls (S1111ge Unit Coat)

National Fuel Gas Distribution Corporation PGC Exhibit 23 Pennsylvania Division -137(f) 213 Schedule 1 Upstream Pipeline Rates ($/Dt) Page3 For the Eight Months Ending July 213 Update: 6/13 Com~an~ Schedule Come!2nent Dec-12 Jan-13 Feb-13 Mar-13 A~r-13 Ma~-13 Jun-13 Jul-13 NFGSC EFT Demand $3.9617 $3.9617 $3.9617 $3.9617 $3.9617 $3.9617 $3.9617 $3.9622 Commodity.166.166.166.166.166.166.166.166 Demand........ FG Demand 23.7426 26.7886 26.7886 25.2656 2.6966 2.6966 2.6966 23.7426 Commodity.166.166.166.166.166.166.166.166 Columbia FTS Demand 6.77 6.77 6.77 6.77 6.77 6.77 6.77 5.728 Commodity.254.254.254.254.254.254.254.19 Columbia SST Demand 5.97 5.97 5.97 5.97 5.97 5.97 5.97 5.558 Commodity.252.252.252.252.252.252.252.188 Transcanada FT Demand........ Commodity........ Texas Eastern FT-1 Demand 12.2132 12.2132 12.2132 12.2132 12.2132 12.2132 12.2132 12.2132 CDS Demand........ STX-M2 Commodity.81.81.81.81.81.81.81.81 ETX-M2 Commodity.743.743.743.743.743.743.743.743 ELA-M2 Commodity.743.743.743.743.743.743.743.743 WLA-M2 Commodity.755.755.755.755.755.755.755.755 M1-M2 Commodity.631.631.631.631.631.631.631.631 Tennessee FTA-4(-4) Demand 18.353 18.353 18.353 18.353 18.353 18.353 18.353 18.353 Commodity.381.381.381.381.381.381.381.355 FTA-4(1-4) Demand 15.626 15.626 15.626 15.626 15.626 15.626 15.626 15.626 Commodity.2619.2619.2619.2619.2619.2619.2619.2597 FTA-4(5-4) Demand 6.88 6.88 6.88 6.88 6.88 6.88 6.88 6.88 Commodity.733.733.733.733.733.733.733.728 F:\RARA\Common\VA_DATA\13713\Iorecast1\I.INKYEAR.llls (Upstream Pun:h. Vol.)

------ -~ - - -- --- -- -... ::;t_.,.,;:;:- -p -~-- "':..::- - --~--.::..:.:...:.l...:::.:c::..;;;~.::-.c:=~-"'='" '--"- - -.. =.. -- ---.::.::..:.~--=~==~--- ------- ------ - - - National Fuel Gas Distnbution Corporation Pennsylvania Division- 137(f) 213 Upstream Pipeline Rates ($/Dt) For the Twelve Months Ending July 214 Com12anl! Schedule ComeQnent Aug-13 Se!:!::13 Oct-13 Nov-13 Dec-13 Jan-14 Feb-14 Mar-14 Aer-14 Max-14 Jun-14 Jul-14 NFGSC EFT Demand $3.9622 $3.9622 $3.9622 $3.9622 $3.9622 $3.9622 $3.9622 $3.9622 $3.9622 $3.9622 $3.9622 $3.9622 Commodity.166.166.166.166.166.166.166.166.166..166.166.166 Demand............ FG Demand 23.7426 25.2656 23.7426 23.7426 22.2196 22.2196 22.2196 22.2196 22.2196 22.2196 22.2196 22.2196 Commodity.166.166.166.166.166.166.166.166.166.166.166.166 Columbia FTS Demand 5.728 5.728 5.728 5.728 5.728 5.728 5.728 5.728 5.728 5.728 5.728 5.728 Commodity.19.19.19.19.19.19.19.19.19.19.19.19 Columbia SST Demand 5.558 5.558 5.558 5.558 5.558 5.558 5.558 5.558 5.558 5.558 5.558 5.558 Commodity.188.188.188.188.188.188.188.188.188 :188.188.188 Transcanada FT Demand............ Commodity............ Texas Eastern FT-1 Demand 11.7577 11.7577 11.7577 9.72 9.72 9.72 9.72 9.72 9.72 9.72 9.72 9.72 CDS Demand............ STX-M2 Commodity.56.56.5.5.5.5.5.5.5.5.5.5 ETX-M2 Commodity.448.448.442.442.442.442.442.442.442.442.442.442 ELA-M2 Commodity.448.448.442.442.442.442.442.442.442.442.442.442 WLA-M2 Commodity.46.46.454.454.454.454.454.454.454.454.454.454 M1-M:2 Commodity.337.337.331.331.331.331.331.331.331.331.331.331 Tennessee FTA-4- (-4) Demand 18.353 18.353 18.353 18.353 18.353 18.353 18.353 18.353 18.353 18.353 18.353 18.353 Commodity.355.355.355.355.355.355.355.355.355.355.355.355 FTA-4 (1-4) Demand 15.626 15.626 15.626 15.626 15.626 15.626 15.626 15.626 15.626 15.626 15.626 15.626 Commodity.2597.2597.2597.2597.2597.2597.2597.2597.2597.2597.2597.2597 FTA-4 (5-4) Demand 6.88 6.88 6.88 6.88 6.88 6.88 6.88 6.88 6.88 6.88 6.88 6.88 Commodity.728.728.728.728.728.728.728.728.728.728.728.728., c: G> (") -o c. en g. m Dl )( ;- -c m ::r Dl c. ) IQ c::: g ;:;:.,.. m id N (,)... (,) F:\RARAICommoniVA_DATA\137131forecui11RATEYEAR.xta (Storage UnH Coat)

National Fuel Gas Distribution Corporation PGC Exhibit 23 Pennsylvania Division- 137(f) 213 Schedule 1 Upstream Purchase and Storage Cost Page5 For the Eight Months Ending July 213 Update: 6/13 Comean~ c~~-~~~-:n! Dec-12 Jan-13 Feb-13 Mar-13 ~w-1_3 ~a~~13 Jun-13 Jul-13 Total Columbia Demand (D1) 1,623 1,623 1,623 1,623 1,623 1,623 1,623 1,13 84,374 Demand (D2) Gas Cost 345,646 469,278 237,61 386,275 1,438,26 Transp. Cost 17 12 76 417 2 115 1,665 Transcanada Demand (D1) Demand (D2) Gas Cost Transp. Cost Tennessee Demand (D1) 1,123,597 1,123,597 1,123,597 1,123,597 1,123,597 1,123,597 1,123,597 1,123,597 8,988,776 Demand (D2) 3,41 3,41 2~.965 29,185 117,97 Gas Cost 5,867,91 4,788,311 4,99,258 5,579,916 6,331,473 6,664,459 6,517,359 5,516,617 46,175,33 Transp. Cost 46,53 321,36 356,287 462,845 452,925 468,23 452,925 464,8 3,438,498 Texas Eastern Demand (D1) 122,132 122,132 122,132 122,132 122,132 122,132 122,132 122,132 977,56 Demand.(D2) 775 775 7 775 3,25 Gas Cost 359 325 281 332 1,241,488 1,36,365 1,277,36 1,48,986 4,875,442 Transp. Cost 6 6 5 6 18,93 19,561 18,93 19,561 77,5 NFGSC Demand (D1) 1,332,865 1,349,168 1,349,168 1,341,16 1,278,59 1,278,59 1,278,59 1,295,39 1,53,26 Demand (D2) 1,54 1,54 1,54 1,54 1,54 1,54 1,54 1,54 12,32 Transp. Cost 49,984 59,59 52,69 46,25 27,895 14,918 7,442 6,752 264,99 Total Purchase Demand $2,6211942 $216381245 $21635.725 $2,628,868 $21536,482 $215361482 $2,536,482 $2,5521321 $2,686,547 Commodity $613781419 $51169161 $51318,44 $6189,469 $81419163 $8,943,21 $8,5111223 $7,442,386 $561271182 PAD Storage Rental and Demand 1,69,861 1,69,861 1,69,861 1,69,861 1,15,47 1,15,47 1,15,47 1,12,256 8,338,11 Transp. Storage Gas Commodity 61,333 95,71 75,242 51,19 25,423 48,123 62,143 68,152 487,136 PAD Storage Gas Demand 2,742,688 4,283,54 3,371,49 2,288,516 (5,968) (2,155,258) (2, 779,826) (3,63,347) 4,166,718 Commodity 5,444,42 8,52,454 6,692,9 4,542,543 (994,387) (4,278,36) (5,517' 76) (6,12,226) 8,27,639 Total NFGDC PAD Demand 6,434,491 7,991,61 7,76,995 5,987,245 3,5,984 1,396,694 772,126 481,23 33,191,375 Commodity 11,883,794 1317671216 12185,691 11683,31 7,45,99 4,713118 3,55,66 1,39,312 65,281857 Total $181318,285 $21,758,826 $19,162;686 $16,671276 $1,51,83 $6,19,82 $31827,732 $1,871,542 $98122,232 F:IRARA\Common1VI\.DATA\137ftl3\lo<ecost1\UNKYEAR.xls (Upstream Pun:h. Vol.)

National Fuel Gas Distribution Corporation Pennsylvania Division -137(f) 213 Upstream Purchase and Storage Cost For the Twelve Months Ending July 214 Company Component Aug-13 Sep-13 Oct-13 Nov-13 Dec-13 Jan-14 Feb-14 Mar-14 Apr-14 May-14 Jun-14 Jul-14 Total Columbia Demand (D1) 1,13 1,13 1,13 1,13 1,13 1,13 1,13 1,13 1,13 1,13 1,13 1,13 12,156 Demand(D2) GasCost o 227,129 133,58 11,53 47,957 411,878 413,723 1,69p,275 Transp. Cost 124 177 39 263 8 498 312 15 115 2,28 Transcanada Demand (D1) Demand(D2) o Gas Cost o Transp. Cost Tennessee Demand(D1) 1,123,597 1,123,597 1,123,597 1,123,597 1,123,597 1,123,597 1,123,597 1,123,597 1,123,597 1,123,597 1,123,597 1,123,597 13,483,164 Demand (D2) o o 21,886 24,166 24,166 21,827 24,166 o 116,211 GasCost 4,396,29 5,137,487 3,814,34 4,786,66 5,812,518 5,115,943 4,616,377 3,451,778 5,564,164 5,776,366 5,582,55 3,769,498 57,823,377 Transp. Cost 371,236 44,571 316,346 387,968 452,717 318,686 287,846 249,534 449,11 464,8 443,797 283,941 4,465,832 TexasEastem Demand(D1) 117,577 117,577 117,577 97,2 97,2 97,2 97,2 97,2 97,2 97,2 97,2 97,2 1,225,911 Demand (D2) 75 775 775 7 775 3,775 GasCost 1,27,744 978,625 1,31,928 985,363 1,3,93 87,656 1,24,81 1,122,864 1,93,637 1,135,24 1,19,21 1,125,585 12,535,26 Transp. Cost 1,447 9,951 1,261 9,577 9,536 7,884 9,268 1,261 9,93 1,261 9,93 1,261 117,567 NFGSC Demand (D1) 1,295,39 1,33,19 1,295,39 1,295,39 1,286,888 1,286,888 1,286,888 1,286,888 1,286,888 1,286,888 1,286,888 1,286,888 15,483,411 Demand (2) o o o 1,49 1,54 1,54 1,391 1,54 o o o 7,51 Transp. Cost 6,752 1,266 19,722 31,835 48,883 57,758 51,45 45,229 27,28 14,592 7,285 6,61 327,662 Total Purchase Demand $2.546.226 $2.554,377 $2.546.226 $2.549 795 $2.543.999 $2.543 999 $2.541.436 $2 543.999 $2.517.518 $2.517.518 $2,517 518 $2 517.518 $3.44.129 Commodity $5,812.593 $6 84 26 $5,325 964 $6 21,72 $7,353,827 $6 37 927 $5,989 22 $4 879,666 $7 246.149 $7 88 88 $7 564 8 $5 69 733 $76 966 767 PAD Storage Rental and Demand 1,12,256 1,12,256 1,63,434 1,63,434 1,63,434 1,63,434 1,63,434 1,63,434 1,12,256 1,12,256 1,12,256 1,12,256 12,454,14 Transp. Storage Gas Commodity 51,61 53,668 17,97 9,542 46,282 81,489 69,17 63,729 22,64 48,12 63,437 43,823 571,363 PADStorageGas Demand (2,298,975) (2,419,356) (642,752) 584,949 2,386,783 4,211,32 3,565,237 3,313,561 (531,814) (2,511,797) (3,291,623) (2,286,773) 78,742 Commodity (4,563,33) (4.82,252) (1,149,555) 1,46,175 4,268,738 7,531,874 6,376,394 5,926,272 (951,145) (4,492,325) (5,887,35) (4,89,872) (786,34) Total NFGDC PAD Demand 1,259,57 1,147,277 2,966,98 4,198,178 5,994,216 7,818,735 7,17,17 6,92,994 2,997,96 1,17,977 238,151 1,243,1 42,97~.11 Commodity 1,3,9 2,55,622 4,194.316 7.256,789 11.668.847 13.98429 12.434.586 1,869,667 6.317.68 3,364,585 1,741.22 1,563.684 76,752,96 Total $2,56.47 $3,22,899 $L161,224 i_11.454967 $1766363 $2183,25 $1964693 $17]9661 _$931556B j_4,~2,562 $1,9_79,353 $2.86,685 $119725.17 "1J c G> " a. (/) (') o m fl ov ~ ~ ~ ~ ~ ~ c.> Ol... (..) F.\RARA\Ccmmon\VA_OATA\13713\~\RATEYEAR.xts (Storage Unit Cost)

PGC Exhibit 23 National Fuel Gas Distribution Corporation Schedule 1 Pennsylvania Division -137(f) 213 Page7 Summary of Storage Volume Update: 6/13 Storage Volume {Dtl Dec-12 Jan-13 Feb-13 Mar-13 A~r-13 Ma:,:-13 Jun-13 Jul-13 Total Coi.-FSS Storage Rental Demand 18,417 18,417 18,417 18,417 18,417 18,417 18,417 18,417 147,336. Capacity 564,31 564,31 564,31 564,31 564,31 564,31 564,31 564,,31 4,51~.248 Injection 64,8 113,66 56,533 113,86 367,465 Withdrawal 39,155 64,65 64,65 64,65 292,97 Storage Transp. Demand 18,417 18,417 18,417 18,417 9,29 9,29 9,29 9,29 11,54 Injection 84,8 113,66 56,533 113,66 367,465 Withdrawal 39,155 84,65 84,65 84,65 292,97 Gas Cost Injection (84,65) (112,86) (56,43) (112,86) (366,62) Withdrawal 39,155 84,65 84,65 84,65 292,97 NFGSC-ESS Storage Rental Demand 196,997 196,997 196,997 196,997 196,997 196,997 196,997 196,997 1,575,976 Capacity 9,195,462 9,195,462 9,195,462 9,195,462 9,195,462 9,195,462 9,195,462 9,195,462 73,563,696 Injection 335,289 1,15,11 1,332,449 1,459,22 4,141,951 Withdrawal 1,36,56 2,14,894 1,635,67 1,112,944 167,744 6,381,245 Gas Cost Injection (335,289) (1,15,11) (1,33~.449) (1,459,22) (4,141,951) Withdrawal 1,36,56 2,14,894 1,635,67 1,112,944 167,744 6,381,245 NFGSC-FSS Storage Rental Demand 1,666 1,666 1,666 1,666 1,666 1,666 1,666 1,666 85,328 Capacity 2, 2, 2, 2, 2, 2, 2, 2, 1,6, Injection 1, 65,793 41,465 117,258 Withdrawal 36, 52, 44,. o 132, Gas Cost Injection (1,) (65,793) (41,465) (117,258) Withdrawal 36, 52, 44, 132, F:\RARA\Cammon\VA_OATA\13713Vore<:aSt1\LINKYEAR.x!s (Upstream Purch. V~.)

National Fuel Gas Distribution Corporation Pennsylvania Division -137(f) 213 Summary of Storage Volume Storage Volume {Dt} Aug-13 Se!!-13 Oct-13 Nov-13 Dec-13 Jan-14 Feb-14 Mar-14 ~r-14 Max-14 Jun-14 Jul-14 Total Col. -FSS Storage Rental Demand 18,417 18,417 18,417 18,417 18,417 18,417 18.417 18,417 18,417 18,417 18,417 18,417 221,4 Capacity 564,31 564,31 564,31 564,31 564,31 564,31 564,31 564,31 564,31 564,31 564,31 564,31 6,768,372 Injection 67,84 39,573 28,267 113,66 113,66 113,66 474,878 Withdrawal 18,817 39,155 84,65 56,43 112,86 473,786 Storage Transp. Demand 9,29 9,29 18,417 18,417 18,417 18,417 18,417 18,417 9,29 9,29 9,29 9,29 165,756 Injection 67,84 39,573 28,267 113,66 113,66 113,66 474,878 Withdrawal 18,817 39,155 84,65 56,43 112,86 473,786 Gas Cost Injection (67,684) (39,483) (28,22) (112,86) (112,86) (112,86) (4?3,787) Withdrawal 18,817 39,155 84,65 56,43 112,86 (I 473,786 NFGSC-ESS Storage Rental Demand 196,997 196,997 196,997 196,997 196,997 196,997 196,997 196,997 196,997 196,997 196,997 196,997 2,363,964 Capacity 9,195,462 9,195,462 9,195,462 9,195,462 9,195,462 9,195,462 9,195,462 9,195,462 9,195,462 9,195,462 9,195,462 9,195,462 11,345,544 Injection 1,23,22 1,171,59 32,27 324,155 969,884 1,353,28 931,621 6,273,579 Withdrawal 65,949 84,693 1,16,314 1,775,89 1,527,931 1,4,581 145,731 6,16,288 Gas Cost Injection (1,23,22) (1,171,59) (32,27) (324,155) (969,884) (1,353,28) (931,621) (6,273,579) Withdrawal 65,949 84,693 1,16,314 1,n5,89 1,527,931 1,4,581 145,731 6,16,288 NFGSC-FSS Storage Rental Demand 1,666 1,666 16,666 1,666 1,666 1,666 1,666 1,666 1,666 1,666 1,666 1,666 127,992 Capacity 2, 2, 2, 2, 2, 2, 2, 2, 2, 2, 2, 2, 2,4, Injection 26,742 36,267 64,511 37,281 164,81 Withdrawal 1,651 34,635 63,714 44, 144, Gas Cost Injection (26,742) (36,267) (64,511) (37,281) (164,81) Withdrawal 1,651 34,635 63,714 44, 144, " c G) () " C/) Q. g. m Ill )( m ::T!ii ~ Q. en cc r:: c= ;::;: :::;; CD id 1'.) (,)... (,) F:\RARA\Ccxnmon\VA _DATAI13713111C8611\RATEYEAR.xls (Stolage Un~ Cool)

National Fuel Gas Distribution Corporation PGC Exhibit 23 Pennsylvania Division- 137(f) 213 Schedule 1 Summary of Storage Unit Cost Page9 Update: 6/13 Storage Unit Cost {$/Dt} Dec-12 Jan-13 Feb-13 Mar-13 ~r-13 Ma~-13 Jun-13 Jul-13 Col. - Fss - Storage 'Rental Demand.. 1:59 1.59..... 1.59' 1.59 1.59 1.59 1.5 1.59 Capacity.289.289.289.289.289.289.289.289 Injection.153.153.153.153.153.153.153.153 Withdrawal.153.153.153.153.153.153.153.153 Storage Transp. Demand 5.97 5.97 5.97 5.97 5.97 5.97 5.97 5.558 Injection.2.52.252.252.252.252.252.252.188 Withdrawal.234.234.234.234.234.234.234.17 Gas Cost Demand 1.911 1.911 1.911 1.911 1.911 1.911 1.911 1.911 Commodity 3.7932 3.7932 3.7932 3.7932 3.7932 3.7932 3.7932 3.7932 NFGSC-ESS Storage Rental Demand 2.5959 2.5959 2.5959 2.5959 2.5959 2.5959 2.5959 2.5959 Capacity.44.44.44.44.44.44.44.44 Injection.429.429.429.429.429.429.429.429 Withdrawal.429.429.429.429.429.429.429.429 Gas Cost Demand 1.911 1.911 1.911 1.911 1.911 1.911 1.911 1.911 Comm.Pd.ity 3.7~32 3.7932 ~.79~~ 3.7932. 3.7932. 3.7932.3.7932... - 3.7932. NFGSC- FSS Storage Rental Demand 2.4826 2.4826 2.4826 2.4826 2.4826 2.4826 2.4826 2.4826 Capacity.381.381.381.381.381.381.381.381 Injection.49.49.49.49.49.49.49.49 Withdrawal.49.49.49.49.49.49.49.49 Gas Cost Demand 1.911 1.911 1.911 1.911 1.911 1.911 1.911 1.911 Commodity 3.7932 3.7932 3.7932 3.7932 3.7932 3.7932 3.7932 3.7932 F:IRARA\Common\VA_OATAI13713Voreoaat1\LINKYEAR.xf11 (Upstream Purch. Vol.)

National Fuel Gas Distribution Corporation Pennsylvania Division -137(f) 213 Summary of Storage Unit Cost Storage Unit Cost ~$/Dt} Aug-13 see-13 Oct-13 Nov-13 Dec-13 Jan-14 Feb-14 Mar-14 ~r-14 Ma~-14 Jun-14 Jul-14 Col. -FSS Storage Renftal Demand 1.59 1.59 1.59 1.59 1.59 1.59 1.59 1.59 1.59 1.59 1.59 1.59 Capacity.289.289.289.289.289.289.289.289.289.289.289.289 Injection.153.153.153.153.153.153.153.153.153.153.153.153 Withdrawal.153.153.153.153.153.153.153.153.153.153.153.153 Storage Transp. Demand 5.558 5.558 5.558 5.558 5.558 5.558 5.558 5.558 5.558 5.558 5.558 5.558 Injection.188.188.188.188.188.188.188.188.188.188.188.188 Withdrawal.17.17.17.17.17.17.17.17.17.17.17.17 Gas Cost Demand 1.911 1.911 2.1895 2.1895 2.1895 2.1895 2.1895 2.1895 2.1895 2.1895 2.1895 2.1895 Commodity 3.7932 3.7932 3.9159 3.9159 3.9159 3.9159 3.9159 3.9159 3.9159 3.9159 3.9159 3.9159 NFGSC-ESS Storage Rental Demand 2.5959 2.5959 2.5959 2.5959 2.5959 2.5959 2.5959 2.5959 2.5959 2.5959 2.5959 2.5959 Capacity.44.44.44.44.44.44.44.44.44.44.44.44 Injection.429.429.429.429.429.429.429.429.429.429.429.429 Withdrawal.429.429.429.429.429.429.429.429.429.429.429.429 Gas Cost Demand 1.911 1.911 2.1895 2.1895 2.1895 2.1895 2.1895 2.1895 2.1895 2.1895 2.1895 2.1895 Commodity 3.7932 3.7932 3.9159 3.9159 3.9159 3.9159 3.9159 3.9159 3.9159 3.9159 3.9159 3.9159 NFGSC -FSS Storage Rental Demand 2.4826 2.4826 2.4826 2.4826 2.4826 2.4826 2.4826 2.4826 2.4826 2.4826 2.4826 2.4826 Capacity.381.381.381.381.381.381.381.381.381.381.381.381 Injection.49.49.49.49.49.49.49.49.49.49.49.49 Withdrawal.49.49.49.49.49.49.49.49.49.49.49.49 Gas Cost Demand 1.911 1.911 2.1895 2.1895 2.1895 2.1895 2.1895 2.1895 2.1895 2.1895 2.1895 2.1895 Commodity 3.7932 3.7932 3.9159 3.9159 3.9159 3.9159 3.9159 3.9159 3.9159 3.9159 3.9159 3.9159 ~~.., (j) c: (') ' C/) a.., ::J' m )( ~ Dl CD ::J'.. (Q a. g <II 1:: ~ id 1\) w... w F:IRARAICommoniVA_DATA113713Vorecast11RATEYEARJds (Storage Unft Cost)

National Fuel Gas Distribution Corporation PGC Exhibit 23 Pennsylvania Division -137(f) 213 Schedule 1 Summary of Storage Cost Page 11 Update: 6/13 Storage Cost {$} Dec-12 Jan-13 Feb-13 Mar-13 8er-13 Ma:t-13 Jun-13 Jul-13 Total Col. -FSS Storage Rental Demand 27,791 27,791 27,791 27,791 27,791 27,791 27,791 27,791 222,328 Capacity 16,3' 16,3 16,3 16,3 16,3 16,3 16,3 16,3 13,4 Injection 1,297 1,73 865 1,73 5,622 Withdrawal 599 1,294 1,294 1,294 4,481 Storage Transp. Demand 18,789 18,789 18,789 18,789 54,398 54,398 54,398 51,184 649,534 Injection 2,137 2,849 1,425 2,126 8,537 Withdrawal 916 1,98 1,98 1,98 6,856 Injection Demand (161,68) (215,572) (17,786) (215,572) (7,61) Commodity (32,924) (427,896) (213,948) (427,896) (1,39,664) Withdrawal Demand 74,825 161,68 161,68 161,68 559,865 Commodity 148,523 32,924 32,924 32,924 1,111,295 NFGSC ESS Storage Rental Demand 511';385 511,385 511,385 511,385 511,385 511,385 511,385 511,385 4;9~,8 Capacity 371,497 371,497 371,497 371,497 371,497 371,497 371,497 371,497 2,971,976 Injection 14,384 43,544 57,162 62,6 177,69 Withdrawal 58,346 9,3 7,168 47,745 7,196 273,755 Injection Demand (64,737) (1,939,686) (2,546,31) (2,788,535) (7,915,268) Commodity (1,271,818) (3,85, 14) (5,54,246) (5,535,45) (15, 711,249) Withdrawal Demand 2,599,67 4,22,452 3,125,645 2,126,836 32,559 12,194,559 Commodity 5,158,964 7,984,284 6,24,184 4,221,619 636,287 24,25,338 NFGSC-FSS Storage Rental Demand 26,479 26,479 26,479 26,479 26,479 26,479 26,479 26,479 211,832 Capacity 7,62 7,62 7,62 7,62 7,62 7,62 7,62 7,62 6,96 Injection 49 2,691 1,696 4,796 Withdrawal 1,472 2,127 1,8 5,399 Injection Demand (19, 11) (125,73) (79,24) (224,8) Commodity (37,932) (249,566) (157,285) (444,783) Withdrawal Demand 68,796 99,372 84,84 252,252 Commodity 136,555 197,246 166,91 5,72 Total Cost $9,317,924 $13,951,52 $11,28,521 $7,951,939 {$454,462} ($5 369,71} ($7,219,973} ($8,123,165) $21,262,63 Summary Storage Rental Demand $961,72 $961,72 $961,72 $961,72 $961,72 $961,72 $961,72 $961,72 $7,688,576 Commodity $6,417 $93,721 $73,262 $49,39 $23,286 $45,274 $6,718 $66,26 $471,743 Storage Transp. Demand $18,789 $18,789 $18,789 $18,789 $54,398 $54,398 $54,398 $51,184 $649,534 Commodity $916 $1,98 $1,98 $1,98 $2,137 $2,849 $1,425 $2,126 $15,393 Gas Cost Demand $2,742,688 $4,283,54 $3,371,49 $2,288,516 ($5,968) ($2, 155,258) ($2,779,826) ($3,83,347) $4,166,718 Commodity $5,444,42 $8,52,454 $6,692,9 $4,542,543 ($994,387) ($4,278,36) ($5,517,76) ($6,12,226) $8,27,639 Total Cost $9,317,924 $13,951,52 $11,28,521 $7,951,939 {$454,462} {$5,369,71} {$7,219,973} ($8,123,165l $21,262,63 FWUIAICommon\VA_OATAI1371Q3Vorecast1\LINKYEAR.xls (Upo1ntam Purch. Vol.)

National Fuel Gas Distribution Corporation Pennsylvania Division- 137(f) 213 Summary of Storage Cost Storage Cost {$) Aug-13 See:13 Oct-13 Nov-13 Dec-13 Jan-14 Feb-14 Mar-14 &!r-14 Ma):-14 Jun-14 Jul-14 Total Coi.-FSS Storage Rental Demand 27,791 27,791 27,791 27,791 27,791 27,791 27,791 27,791 27,791 27,791 27,791 27,791 333,492 Capacity 16,3 16,3 16,3 16,3 16,3 16,3 16,3 16,3 16,3 16,3 16,3 16,3 195,6 Injection 1,38 65 432.1,73 1,73 1,73 7,265 Withdrawal 2,767 599 1,294 863 1,726 7,249 Storage Transp. Demand 51,184 51,184 12,362 12,362 12,362 12,362 12,362 12,362 51,184 51,184 51,184 51,184 921.276 Injection 1,275 744 531 2,126 2,126 2,126 8,928 Withdrawal 3,74 666 1,438 959 1,918 8,55 Injection Demand (129,344) (86,448) (61,748) (246,989) (246,989) (246,989) (1,11i,57) Commodity (256,739) (154,611) (11,436) (441,737) (441,737) (441,737) (1,846,997) Withdrawal Demand 395,899 85,73 185,243 123,494 246,989 1,37,355 Commodity 78,61 153,327 331,35 22,869 441,737 1,855,299 NFGSC-ESS Storage Rental Demand 511,385 511,385 511,385 511,385 511,385 511,385 511,385 511,385 511,385 511,385 511,385 511,385 6,136,62 Capacity 371,497 371,497 371,497 371,497 371,497 371,497 371,497 371,497 371,497 371,497 371,497 371,497 4,457,964 Injection 51,61 5,261 13,729 13,96 41,68 58,56 39,967 269,137 Withdrawal 2,829 3,633 43,6 76,151 65,548 6,85 6,252 258,98 Injection Demand (2,298,975) (2,238,98) (7,699) (79,737) (2,123,561) (2,963,7) (2,39,784) (13,74,671) Commodity (4,563,33) (4,444,75) (1,253,194) (1,269,359) (3,797,969) (5,299,39) (3,648,135) (24,27~.344) Withdrawal Demand 144,395 185,435 2,225,22 3,886,557 3,345,45 3,66,572 319,78 13,172,662 Commodity 258,25 331,649 3,979,784 6,951,71 5,983,225 5,484,535 57,668 23,55~.182 NFGSC-FSS Storage Rental Demand 26,479 26,479 26,479 26,479 26,479 26,479 26,479 26,479 26,479 26,479 26,479 26,479 317,748 Capacity 7,62 7,62 7,62Q 7,62 7,62 7,62 7,62 7,62 7,62 7,62 7,62 7,62 91,44 Injection 1,94 1,483 2,638 1,525 6,74 Withdrawal 68 1,417 2,66 1,8 5,891 Injection Demand (51,14) (79,47) (14.1,247) (81,627) (35~,385) Commodity (11,438) (142,18) (252,619) (145,989) (642,64) Withdrawal Demand 3,615 75,833 139,52 96,338 315,288 Commodity 6,465 135,627 249,498 172,3 56~.89 Total Cost (5798,412) (6,155684)!11,966) 2 741 7,765237 12,888,99 1174,235 1366,996 (448,99) ~.943,If!il (8, 12,965) -- (5,32,566) 12,318,211 Summary Storage Rental Demand 961,72 961,72 961,72 961,72 961,72 961,72 961,72 961,72 961,72 961,72 961,72 961,72 11,532,864 Commodity $51,61 $52,393 $17,163 $6,468 $45,616 $8,51 $68,211 $61,811 $22,73 $45,976 $61,311 $41,697 $554,38 Storage Transp. Demand $51,184 $51,184 $12,362 $12,362 $12,362 $12,362 $12,362 $12,362 $51,184 $51,184 $51,184 $51,184 $921,276 Commodity $ $1,275 $744 $3,74 $666 $1,438 $959 $1,918 $531 $2,126 $2,126 $2,126 $16,983 Gas Cost Demand ($2,298,975) ($2,419,356) ($642,752) $584,949 $2,386,783 $4,211,32 $3,565,237 $3,313,561 ($531,814) ($2,511,797) ($3,291,623) ($2,286,773) $78,742 Commodity ($4,563,33) ($4,82,252) ($1,149,555) $1,46,175 $4,268,738 $7,531,874 $6,376,394 $5,926,272 ($951,145) ($4,492,325) ($5,887,35) ($4,89,872) ($786,34) Total Cost {5798412) {6,155684)!11966) 2741 7765237 12 888,99 11,74235 1366,996 {44899) {5943764) {8,12965) {5 32566) 123Hi211 "I] G) ~ en o ~ "I] i ~ : «~ g :a;...a.. CD 1\,) w "'... w F:\RARA\Common\VA_OATA\137f3\forecast1\RATEYEAR.xls (Storage Unit Cost)

------ ---~ - - - --~1--- - -: --- -- - -,.,... - - - ~ -- ~ - - - -- =~-..:.o:..± ~- "::"~ : o----'---- National Fuel Gas Distribution Corporation Pennsylvania Division- 137(f) 2'13 Unit Storage Gas Cost ($/Dt) For the Twelve Months Ending September 213 Unit Storage Demand Gas Cost CS/DI;} Upstream Purchased Gas Cost Appalachian Gas Cost Local Production Gas Cost Storage Rental & Transp. Cost Total Demand Cost Less: Offsystem Sales Purchase Net Demand Cost Oct-12* Nov-12* Dec-12* Jan-13* Feb-13* Mar-13* A~r-13* Ma~-13* Jun-13* Jul-13 Au~t13 See:;13 Total! $2,49,566 $2,477,48 $2,386,822 $2,331,72 $2,366,75 $2,389,73 $2,322,634 $2,122,187 $2,238,412 $2,552,321 $2,546,226 $2,554,3n $28,697,748 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $894,949 $892,511 $891,723 _$885,57~ $88~~ $88,284 san,754 $871,126 $866,441 $1 12 256 1LQ12,~$1,12,2!i6_ $1,982,232 $3,34,515 $3,369,559 $3,278,545 $3,217,293 $3,249,88 $3,27,14 $3,2,388 $2,993,313 $3,16,853 $3,564,5n $3,558,482 $3,566,633 $39,679,98 $ $ $ $ $ $ $ $ $ $ $ $ $ $3,34.515 $3,369,559 $3.278.545 $3.217~$3:249.88 $3,27.14 $3 2 388 $2.993.313 $3 16.853 $3 564.5n $3.558,482 $3,566.633 $39.679.98 Total Receipt Volume (Dt) Less: Total Shrinkage (Dt) Less: Offsystem Sales Purchase Net Volume (Dt) Unit Storage Demand Gas Cost 1,41,996 22,617 1,388,379 1,945,352 2,282,87 2,562,297 1,852,996 2,188,85 2,95,684 1,799,644 1,485,731 2,119,149 1,69,448 1,974,651 23,47,84 24,758 26,76 44,785 4,349 35,559 23,989 23,59 22,443 76,33 62,274 71,776 474,438 268.746 494.743 637,66 468,675 299,987 2.169.811 1,651,848 1,761,268 1,879,852 1,343,972 1,853,259 2,71,695 1,n6,135 1,463,288 2,42,846 1,628,174 1,92,875 2,763,591 I $1.911 I Unit Storage Commodjtv Gas Cost <S/Dtl Upstream Purchased Gas Cost $3,433,831 $5,831,121 $6,989,47 $7,77,429 $5,351,298 $7,83,816 $7,54,576 $6,35,171 $4,78,38 $7,442,386 $5,812,593 $6,84,26 $75,127,25 Appalachian Gas Cost Local Production Gas Cost $891,38 $5,795 $1,45,93 $6,878 $1,168,818 $7,886 $1,34,595 $8,385 $99,26 $6,281 $1,73,26 $6,542 $1,114,44 $6,51 $1,228,35 $7,449 $1,11,617 $8,15 $32,6 $8,936 $31,991 sa,n4 $3,95 $8,489 $9,671,327 -$9,76 Storage Rental & Transp. Cost $53,389 $25,449 $39,69 $42,179 $75,662 $86,768 $62,988 $38,24 $47,991 $68,152 $51,61 $53,668 $645,129 Total Commodity Cost Less: Offsystem Sales Purchase Net Commodity Cost $4,384,395 $6,99,378 $8,25,243 $8,792,588 $6,342,267 $8,25,152 $8,724,118 $7,624,174 $5,947,66 $7,552,74 $5,94,968 $6,897,313 $85,533,737 $ $875 827 $1 485 463 $1 93 56 $1 428 697 $1 49186 $ $ jg_ $ $ $ $6,769.229 $4,384 395 $6 33,551 $6,719 78 $6 862,532 $4,913 57 $7,2 966 $8 724 118 $7 624 174 $5,947 66 $7 552 74 $5,94,968 $6 897 313 $78 764 58 Total Receipt Volume (Dt) Less: Total Shrinkage (Dt) Less: Offsystem Sales Purchase Net Volume (Dt) Unit Storage Commodity Gas Cosl: ($/Dt) 1,41,996 22,617 1,388,379 1,945,352 2,282,87 2,562,297 1,852,996 2,188,85 2,95,684 1,799,644 1,485,731 2,119,149 1,69,448 1,974,651 23,47,84 24,758 26,76 44,785 4,349 35,559 23,989 23,59 22,443 76,33 62,274 71,776 474,438 268,746 494,743 637,66 468,675_ 2!:1~ 2.169.811 1,651,848 1,761,268 1,879,852 1,343,972 1,853,259 2,71,695 1,n6,135 1,463,288 2,42,846 1,6.?_8,174 1,92,875 2,763,591 I $3.7932 I *per Books. c " 'U Gl en o ~ 'U i ~ ~ ci ~ g ~ ~ CD f\l (,o) (,o)... (,o) F:\RARA\C»mmon\VA_DATA\13.Q7f3Vorecast1\LINKYEAR»s {Upstream Purch. Vol.)

National Fuel Gas Distribution Corporation Pennsylvania Division- 137(f) 213, Unit Storage Gas Cost ($/1) For the Twelve Months Ending September 214 Oct-13 Nov-13 Dec-13 Jan-14 Feb-14 Mar-14 Apr-14 Mav-14 Jun-14 Jul-14 Aug-14 SeP-14 Total Unit Storage Demand Gas Cost CS/1) Upstream Purchased Gas Cost $2,546,226 $2,549,795 $2,543,999 $2,543,999 $2,541,436 $2,543,999 $2,517,518 $2,517,518 $2,517,518 $2,517,518 $2,517,518 $2,517,518 $3,374,562 Appalachian Gas Cost $ $ $ $ $ $ $ $ $ $ $ $. $ Local Production Gas Cost $ $ $ $ $ $ $ $ $ $ $ $ $ Storage Rental & Transp. Cost $1,63,434 $1.63 434 $1 63 434 $1 63 434 $1 63 434 $1 63 434 $1 12 256 $1 12 256 $1 12 256 $1 12 256 $1 12 256 $1 12 256 $12 454 14 Total Demand Cost Less: Offsystem Sales Purchase Net Demand Cost $3,69,66 $ $3,69,66 $3,613,229 $ $3,613,229 $3,67,433 $ $3,67,433 $3,67,433 $ $3,67,433 $3,64,87 $ $3,64,87 $3,67,433 $ $3,67,433 $3,529,774 $ $3,529,774 $3,529,774 $ $3,529,774 $3,529,774 $ $3,529,774 $3,529,774 $ $3,529,774 $3,529,774 $ $3,529,774 $3,529,774 $ $3,529,774 $42,828,72 $ $42,828,72 Total Receipt Volume (1) Less: Total Shrinkage (1) Less: Offsystem Sales Purchase Net Volume (1) Unit Storage Demand Gas Cost 1,545,544 1,719,9 1,942,67 1,636,8 1,545,713 1,279,539 1:968,11 2,119,149 2,36,574 1,511,135 1,16,91 1,881,344 2,292,335 56,3 64,92 71,731 54,274 51,813 47,435 72,62 76,51 73,281 53,459 4,35 68,33 73,996 1.489.244 1,654,89 1,87,876 1,582,~26 1.4SJ3,9..._1,23214.. 1 895 391 2 42 639 1963 293 1457 676 1_,!!_~ 1.~.13..41 19,561,339 I $2.1895 I Unit Storage CommoditY Gas Cost ($/Qll Upstream Purchased Gas Cost $5,325,964 $6,21,72 $7,353,827 $6,37,927 $5,989,22 $4,879,666 $7,246,149 $7,88,88 $7,564,8 $5,69,133 $4,11,27 $7,81,818 $75,541,813 Appalachian Gas Cost $32,111 $31,736 $34,319 $35,3 $31,657 $34,734 $32,98 $34,152 $33,355 $34,799 $34,956 $33,855 $43;612 Local Production Gas Cost $8,86 $8,698 $9,392 $9,58 $8,657 $9,52 $9,8 $9,348 $9,127 $9,519 $9,561 $9,259 $11;456 Storage Rental & Transp. cost Total Commodity Cost Less: Offsystem Sales Purchase Net Commodity Cost Total Receipt Volume (1) Less: Total Shrinkage (1) Less: Offsystem Sales Purchase Net Volume (1) Unit Storage Commodity Gas Cost ($/1) $17,97 $9,542 $46,282 $8M89 ~9.17 $6~.72L $~4 _-~ 12 $63,437 $43,823 $28,195 $5,475 $544.755 $5,384,788 $6,251,48 $7,443,82 $6,497,26 $6,98,56 $4,987,631 $7,31,669 $7,9,41 $7,67,719 $5,697,874 $4,182,739 $7,175,47 $76,6,636 $ $ -~ _$ $ - _jq $ $ $ $ $ $ $ $5 384 788 $6 251 48 $7 443 82 $6 497 26 $6 98 56 $4 987 631 $7 31 669 $7 9 41 $7 67 719 $5 697 874 $4 182 739 $7 175 47 $76 6Q:636 1,545,544 1,719,9 1,942,67 1,636,8 1,545,713 1,279,539 1,968,11 2,119,149 2,36,574 1,511,135 1,16,91 1,881,344 2,292;335 56,3 64,92 71,731 54,274 51,813 47,435 72,62 76,51 73,281 53,459 4,35 68,33 73,996 ; 1,489.244 1,654,89 1,87,876 1,582,526 1.4.!:13,9 1,232,19" 1~895 391 2~.639 _..1..963,293 1,457,676 1,66,56 1,813.41 19.561;339 I $3.9159 I '1J c G'l (/) () X! II m ~ ~ i ID g ~ id N c.> ~... c.> F:\R.ARA\Common\VA_OATA\13713\Ib~ClSt1\RATEYEAFbds (Storage Unit Cost)

PGC Exhibit No. 25 Update: 6/13 National Fuel Gas Distribution Corporation 213 137(f) Filing. Wellhead Price Projection Projected NFG NYMEX Receipt Projected Settle/ Average Price Month ($/Dth) ($/Dth) (B) (D) December 212 $ 3.696 $3.696 January 213 $ 3.354 $3.354 February 213 $ 3.226 $3.226 March 213 $ 3.427 $3.427 April 213 $ 3.976 $3.976 May 213 $ 4.49 $4.49 June 213 $ 4.91 $4.91 July 213 $ 3.77 $3.77 August 213 $ 3.641 $3.641 September 213 $ 3.64 $3.64 October 213 $ 3.654 $3.654 November 213 $ 3.728 $3.728 December 213 $ 3.893 $3.893 January 214 $ 3.97 $3.97 February 214 $ 3.972 $3.972 March 214 $ 3.9~8 $3.938 April 214 $ 3.8~9 $3.859 May 214 $ 3.875 $3.875 June 214 $ 3.99 $3.99 July 214 $ 3.945 $3.945 August 214 $ 3.962 $3.962 September 214 $ 3.965 $3.965 October 214 $ 3.985 $3.985 November 214 $ 4.66 $4.66 December 214 $ 4.231 $4.231 Settlement Feb 213 Settlement Feb 213 Settlement Feb 213 Settlement Feb 213 Settlement Feb 213 Settlement Feb 213 Settlement Feb 213 August 213 Filing August 213 Filing August 213 Filing August 213 Filing August 213 Filing August 213 Filing August 213 Filing August 213 Filing August 213 Filing August 213 Filing August 213 Filing August 213 Filing August 213 Filing August 213 Filing August 213 Filing August 213 Filing August 213 Filing August 213 Filing Average $3.83 $3.83 August 213-July 214 $3.835 $3.835 Footnote: 1. NYMEX average as of 7/15/213 for Aug. 213 through Dec. 214

I National Fuel Gas Distribution Corporation Pennsylvania Division Computation of Weighted Average Cost of Capacity for Mandatory Release Capacity Under the Rate Schedule Small Aggregation Transportation Supplier Service On or After August 1, 213 Computation Year: Twelve Months Ended July 214 PGC Exhibit No. 29 Page 1 of 2 Update: 6/13 Total Total Pa. Monthly Applicable Pa Annual Demand Capacity #of Months Capacity Rate Dth in Rate Yr Dth $/Dth (A) (B) (C) (D) Texas Eastern 1, 12 12, $1.2159 $ TGP -4 3, 12 36, $18.353 $ TGP 1-4 3,26 12 362,472 $15.626 $ TGP 5-4 12, 12 144, $ 6.88 $ Columbia- FTS 1,748 12 2,976 $21.7652 $ Columbia FSS Demand $ 1.59 $ Columbia FSS Capacity $.289 $ Columbia SST 18,417 165,756 1/ $ 5.558 $ Total 12,371 1 '173,24 Total Mandatory Release Capacity (Dth) Weighted Average Cost of Capacity ($/Dth) $ Total Demand Cost (E=DxC) 1,225,911 6,66,18 5,663,987 876,672 456,547 333,495 195,66 921,272 16,279,598 1,173,24 13.8762 Footnote: 1 I Columbia SST Annual Capacity it 6 months at 18,417 and 6 months at 929. Oct- Mar 18,417 x 6 mos 11,52 Apr- Sep 9,29 x 6 mos 55,254. 165,756

National Fuel Gas Distribution Corporation Pennsylvania Division Calculation of Demand Transfer Recovery Rate Storage Cycle April 213 - March 214 Total Normal Sales Load Month Pattern (MMcf) 1 Apr 2,11.77 2 May 1,156.61 3 Jun 554.93 4 Jul 328.13 5 Aug 314.51 6 Sep 375.85 7 Oct 684.44 8 Nov 1,36.36 9 Dec 2,46.8 1 Jan 3,24.85 11 Feb 3,147.78 12 Mar 2,792.65 18,418.96 Demand Charge Rate $ 2.25 $ 2.22 $ 2.22 $ 2.22 $ 1.76 $ 1.76 $ 1.76 $ 1.76 $ 1.76 $ 1.76 $ 1.76 $ 1.76 Demand Charge Revenue ($) $ 4,756.2 $ 2,571.61 $ 1,233.83 $ 729.56 $ 554.8 $ 663. $ 1,27.35 $ 2,34.42 $ 4,244.33 $ 5,716.86 $ 5,552.68 $ 4,926.23 $34,46.87 Storage Cumulative Transfer Demand Demand Volumes@ Demand Fixed Cost Cost 6% Cost in Demand (Under) Over (Under) Over of Peak Day Storage Cost Recovery Recovery Requirements Rate ($) ($) ($) (MMcf) $ 2,871.74 $ 1,884.46 $ 1,884.46 825.17 $ 1.76 $ 2,871.74 $ (3.13) $ 1,584.33 1,65.34 $ 1.76 $ 2,871.74 $ (1,637.91) $ (53.58) 2,475.52 $ 1.76 $ 2,871.74 $ (2, 142.17) $ (2, 195. 76) 3,3.69 $ 1.76 $ 2,871.74 $ (2,316.94) $ (4,512.7) 4,125.86 $ 1.76 $ 2,871.74 $ (2,28.74) $ (6,721.44) 4,951.3 $ 1.76 $ 2,871.74 $ (1,664.39) $ (8,385.83) 5,776.21 $ 1.76 $ 2,871.74 $ (567.32) $ (8,953.15) 4,62.96 $ 1.76 $ 2,871.74 $ 1,372.59 $ (7,58.56) 3,465.72 $ 1.76 $ 2,871.74 $ 2,845.12 $ (4,735.44) 2,31.48 $ 1.76 $ 2,871.74 $ 2,68.94 $ (2,54.5) 1 '155.24 $ 1.76 $ 2,871.74 $ 2,54.5 $ - - $ 1.76 $34,46.87 Demand (Under) Cost Over Demand Recovered Recovery of Transfer in Storage Demand Recovery Rate Cost Rate ($) ($) $ 1,455.6 $ 3,34.6 $ - Apr $ 2,911.21 $ 4,495.53 $ - May $ 4,366.81 $ 4,313.23 $ - Jun $ 5,822.42 $ 3,626.66 $ - Jul $ 7,278.2 $ 2,765.32 $ - Aug $ 8,733.62 $ 2,12.18 $ - Sep $1,189.23 $ 1,83.4 $ - Oct $ 8,151.38 $ (81.76) $.17 Nov $ 6,113.54 $ (1,467.2) $.42 Dec $ 4,75.69 $ (659.75) $.29 Jan $ 2,37.85 $ (16.65) $.1 Feb $ - $ - $ - Mar C""O""O ""'S» G) g-~ ()... m ~ N >< >2': ::.:-c- C.UN;::::;: z ~ N CD

National Fuel Gas Distribution Corporation Pennsylvania Division Calculation of PSB Service Rates and SB Service Rates PGC Exhibit No. 35 Page 1 Update: 6/13 Peak Capacity Requirement (52) 6,783 PLUS PAD Shrink @.31 21 MCF (See PGC Exhibit No. 26-B) 6,84 BTU 1.74 Dth 7,37 Upstream Capacity Rate (8/1 /213) $ 13.8762 /Dth Annualized Upstream Capacity Amount $ 1,216,714 EFT Rate $ 3.9622 Annualized EFT Amount $ 347,42 Total Annualized Amount $ 1,564,133 Normalized Annual Priority Standby (PSB) Volumes 1,39,49 Calculated PSB Rate (New Methodolgy) $ 1.554 Current PSB Rate (5/1 /213) $.7171 Difference (New Calculation less Current Rate) $.7883 5% of the Difference $.3941 Proposed PSB Rate with Gradual 5% increase $ 1.1112 Mcf $/Mcf $/Mcf $/Mcf $/Mcf $/Mcf Average Sales Load Factor 47.2386% Standby (SB) Service Rate $.5249 $/Mcf

Workpaper Page 1 Pennsylvania Rate Jurisdiction Summary of Proposed Rate Adjustment F:\RARA\Common\VA_DATA\PatariffNo.9\Supp_145\IPACHANGE- REV.xls]A 8/1/13 1!1!13 8/1/13 8/1/13 6/1/13 8/1/13 Base Transition Bypass RiderE Rider F Total Rate Tail block "Current" Tariff Change Rate Cost Rate Rate Rate Per Tariff Margin e/cct rt/ccf rt/cct ~ ~ iccf ~ rt/ccf rt/cct Residential Basic Service Charqe ($) 12.. 12..... 12. First 5 MCF 35.651 (.28) 35.371....329 35.7 Over 5 MCF 25.293 (.28) 25.13....329 25.342 22.633 Low Income Residential (Same as Tier 2) Basic Service Charqe........ Balance......... Low Income Residential (Tier 1) Basic Service Charqe........ Balance......... Low Income Residential (Tier 2) Basic Service Charqe........ Balance......... Low Income Residential (Tier 3) Basic Service Charqe........ Balance......... Commercial/ Public Authority - Small (LL) Basic Service Charqe ($) 19.89. 19.89.... 19.89 First 5 MCF 295'7 (.28) 29.29.... 29.29 Over5 MCF 26.312 (.28) 26.32.... 26.32 23.652 Commercial/ Public Authority- Small (UL) Basic Service Charqe ($) 27.53. 27.53.... 27.53 First2 MCF 2283 (.28) 21.83.... 21.83 Over 2 MCF 2.'719 (.28) 2.439.... 2.439 18.59 Commercial/ Public Authority- Large Basic Service Charqe ($) 121.1. 121.1.... 121.1 First 3 MCF 18.347 (.28) 18.67.... 18.67 Next 1,7 MCF 17.155 (.28) 16.875.... 16.875 Over 2, MCF 14.971 (.28) 14.691.... 14.691 12.311 C/PALBS Demand Purchased Gas Demand Costs 1.46'1 (2.148) 8.319 8.319 Non-Gas Costs ;?,99Q. ;?,_ggq 5.63 Total Demand 16.97 13.949 13.949 Commodity Purchased Gas Commodity Costs 3.216 12.134 42.35.... 42.35 Non-Gas Costs ;?,59J~. ;?,_QQQ 5.566 Total Commodity 35.782 47.916 47.916 SVIS Basic Service Charqe ($) 65.6. 65.6.... 65.6 All Consumption 23.987 (.28) 23.77.... 23.77 21.327 IV IS Basic Service Charqe ($) 21.91. 21.91.... 21.91 First 1 Met 18.16 (.28) 17.826.... 17.826 Next 1,9 Met 14.25 (.28) 13.745.... 13.745 Over 2, Met 1.831 (.28) 1.551.... 1.551 8.171 IVIS LBS Demand Purchased Gas Demand Costs 1.467 (2.148) 8.319 8.319 Non-Gas Costs 5J2Z. 5J.2.2 5.122 Total Demand 15.589 13.441 13.441 Commodity Purchased Gas Commodity Costs 3.216 12.134 42.35.... 42.35 Non-Gas Costs ~JlO.B.. ;;L6Q6 3.88 Total Commodity 34.24 12.134 46.158 46.158 LVIS Basic Service Charqe ($) 89.. 89..... 89. First 1 MCF 13.626 (.28) 13.346.... 13.346 Next 1,9 MCF 11.88 (.28) 11.528.... 11.528 Next 18, MCF 9.72 (.28) 9.44.... 9.44 Over 2, MCF 8.348 (.28) 8.68.... 8.68 5.688 LVIS LBS Demand Purchased Gas Demand Costs 1.467 (2.148) 8.319 8.319 Non-Gas Costs ~.J.. B.?.. ~J.62 3.182 Total Demand 13.649 11.51 11.51 Commodity Purchased Gas Commodity Costs 3.216 12.134 42.35.... 42.35 Non-Gas Costs 2.An. 2Al9. 2.473

Workpaper Page2 Total Commodity 32.689 12.134 44.823 44.823 LIS/Super L VIS Basic Service CharQe ($) 1,29.. 1,29..... 1,29. First 1 MCF 11.317 (.28) 11.37.... 11.37 Next 1,9 MCF 9.517 (.28) 9.237.... 9.237 Next 18, MCF 7.448 (.28) 7.168.... 7.168 Over 2, MCF 6.9 (.28) 5.81.... 5.81 3.43 LIS LBS Demand Purchased Gas Demand Costs 1.467 (2.148) 8.319 8.319 Non-Gas Costs 2.!?..1?..?,,QJ] 2.517 Total Demand 12.984 (2.148) 1.836 1.836 Commodity Purchased Gas Commodity Costs 3.216 12.134 42.35.... 42.35 Non-Gas Costs L924. 1.924 1.924 Total Commodity 32.14 12.134 44:274 44.274 NGV Purchased Gas 1% Load Factor Demand Cost (includinq Gross Receipts Tax) 1.467 (2.148) 8.319 8.319 Plus Purchased Gas Commodity Cost (includinq Gross Receipts Tax) 3.216 12.134 42.35 42.35 1% Load Factor Base Cost of Gas 4.683 9.986 5.669 5.669 NGV (1) Minimum Rate 1% Load Factor Base Cost of Gas 4.683 9.986 5.669 5.669 Incremental operatinq cost of Company owned NGV compression equipment 13.436. 13.436 13.436 Take-or-Pay SurcharQe.... Bypass Refund....... Transition Costs..... State Tax Adjustment Surcharge (.11) (.14) (.124) (.124) Minimum allowable Non-Gas Cost 1.. 1. 1. Minimum NGV (1) Rate 55.9 9.972 64.981 64.981 Maximum NGV (1) Rate Tailblock rate of the Commercial and Public Authority Service Rate Schedule 65.925 73.483 73.483 Incremental operating cost of Company.. owned NGV compression equipment 13.436. 13.436 13.436 State Tax Adjustment Surcharge (.159) (.6) (.165) (.165) Maximum NGV (1) Rate 79.22 (.6) 86.754 86.754 NGV (2) Minimum Rate 1% Load Factor Base Cost of Gas 4.683 9.986 5.669 5.669 Take-or-Pay Surcharge.... Bypass Refund...... Transition Costs..... State Tax Adjustment Surcharge (.83) (.15) (.98) (.98) Minimum allowable Non-Gas Cost 1.. 1. 1. Minimum NGV (2) Rate 41.6 9.971 51.571 51.571 Maximum Rate Tailblock rate of the Commercial and Public Authority Service Rate Schedule 65.925. 73.483 73.483 State Tax Adjustment Surcharge (.132) (.8) (.14) (.14) Maximum NGV (2) Rate 65.793 7.55 73.343 73.343 GAS ADJUSTMENT CHARGE (7.533) (1.181) NATURAL GAS SUPPLY CHARGE 57.323 58.791 Distribution Charge 2.66 2.38 ST A Percentage -.2% -.19% -.19% GAC with MFC - non res (7.55) (1.184) NGSC with MFC - non res 58.54 59.976

- - --- - I Basic National Fuel Gas Distribution C()rp_oration Pennsylvania Division I I Rate Summa~ S~e11~ l -- =r_ ~ This Rate Summary Does Not In Any Way Supersede The Tariff Current Rate Structure I Natural Gas Supply Charee C.3 Residential Basic Monthly_ Service Charge $12. First 5 Mcf $3.5371 per Mcf II ($.1181)lper Mcf I $5.8791lPer Mcf Over 5 Mcf $2.513 per Mcf I I (SO.I!.. ~.!lt~~--~7~mcf Transition Surcharge $. per Mcf Rider E Surcharge $. permcf Rider F Surcharge $.329 per Mcf "Smallff Commercoai/Pubhc Authority "LLff< 25 Mcf/Year Basic Monthly Service Char)!,e $19.89 First 5 Mcf $2.929 I per Mcf I I ($.118i5TP"er Mcf I $5.8791l;er Mcf Over 5 Mcf $2.632 I per Mcf I I ($.118l)lperMcf I $5.8791 I per Mcf Transition Surcharge $. lpermcf Rider E Surcharge $. I per Mcf "Smallff Commercial/Public Authority "UL"> 25 and< 1, Mcf/Year Basic Monthly Service Charge $27.53 First 2 Mcf $2.183 I per Mcf titso.n8i:)'fper Mcf T $5.8791 Tper Mcf Over2 Mcf $2.439 JperMcf I I ($.118l)lperMcf l $5.8791 jper Mcf Transition Surcharge $. I per Mcf Rider E Surcharl!,e $. I per Mcf ""Large" Commercial/Public Authority > 1, Mcf/Y ear Basic Monthly_ Service Charge $121.1 First 3 Mcf $1.867 I per Mcf II ($.118l)lper Mcf I $5.8791 lper Mcf Next 1, 7 Mcf $1.6875 I per Mcf I I ($.1181)1Per Mcf I $5.8791 I per Mcf Over 2, Mcf $1.4691 permcf ll ($.118i)lperMcf -f.-~_?_91 \per Mcf Transition Surcharge $. per Mcf Rider E Surchar)!,e $. per Mcf Small Volume Industrial< 1, Mcf/Year Basic Monthly Service Charge $65.6 All ConsuiiiJ>Iion $2.377 I per Mcf I T($.1181)lper Mcf $5.8791 I per Mcf Transition Surcharge $. I per Mcf Rider E Surcharl!,e $. I per Mcf I Intermediate Volume Industrial > 1, and < 5, Mcf/Year Basic Monthly Service Charge $21.91 First 1 Mcf $1.7826 lpermcf I I ($.118l)lper Mcf I $5.87911Per Mcf I I ($.1181} I per Mcf I $5.8791 I per Mcf Over 2, Mcf $1.551 I per Mcf I I ($.118Jlil>er Mcf _j_ $5.8791_(per Mcf Transition Surcharge $. I per Mcf Next 1,9 Mcf $1.3745 lpermcf Rider E Surcharge $. I per Mcf Large Volume Industrial> 5, and i< 2, Mcf/Year Monthly Service Charge $89. I First 1 Mcf $1.3346 JperMcf II ($.118D'tPer Mcf I $5.8791 I per Mcf Next 1,9 Mcf $1.1528 lpermcf I I ($.1181)lper Mcf I $5.8791 I per Mcf Next 18, Mcf $.944 I per Mcf l I ($.1181) IJlCr Mcf I $5.8791 JJl"r Mcf I Over 2, Mcf $.868 I per Mcf -+.../.. ($.1181).jFer Mcf $5.8791 4-Pcr Mcf.../.. Transition Surcharge/Mcf $. I per Mcf Lafl!,e Industrial > 2, Mcf/Y ear Basic Monthly Service Charge $1,29. First 1 Mcf $1.137 JperMcf tt ($o.1i8mpermcr I $5.8791 I per Mcf Next 1,9 Mcf $.9237 lpermcf I I ($.1181)lperMcf I $5.8791 JJl..er Mcf Next 18, Mcf $.7168 lper Mcf I I ($.1181)lper Mcf I $5.8791 I per Mcf Over 2, Mcf $.581 lpermcf I I ($.1181)lperMcf I $5.8791 I per Mcf Transition Surcharp;e/Mcf $. per Mcf :~ (JQ ~ '"" (.H-6 ~ "C ~ '"" F:\AARA\Common\VA_DATA\AESTRUCT413 Sept.28\POA 1Ssues\Tar~ffrates3.31 ldmgupda TED3.4.21.xls (Extublt28)

permcf National Fuel Gas Distribution Cc Pennsylvania Division I _I I I I I Rate Summary- Supplement 145 I _I j_ I This Rate Summary Does Not In Any W; _j I I I I I I Distribution Rates with Write-off Rate Removed -1- ::-t Merchant Function Cha!"2e (MFC) Recovery of Write-Off Rate Incremental Merchant Write-Off Associated with Basic Service Charge & I Write-Off PORCosts Function I MFC Gas Adjustment I MFC Natural Gas I Total Merchant Factor Gas Costs Distribution Charges Factor Factor Charge Factor Charge (E-Factor) Supply Charge Function Charge c.s C. 9=C.8x(C.2+ 3 C.!O=C.l J C.ll=C.8 C.l2 C.!! l C.I2=C.llxC.2 l C.!3=C.9-C.l2 l C.l4=C.l2+!3 Residential Basic Monthly Service Charge $12. FirstS Mcf 2.231% $.1285 $3.5371 I per Mcf tt 2.231%t o.ooooo/;t 2.23!%J ($.26~r Mcf J $.13111Per Mcf t $.1285lPer Mcf Over 5 Mcf 2.231% $.1285 $2.513 permcf I 2.231% o.oooo% I 2.231%/ ($.26) /per Mcf I $.1311 /per Mcf I $.1285 /per Mcf Transition Surcharge $. iper Mcf Rider E Surcharge $. lpermcf Ride.r F Surchar_ge $.329 permcf "Small~ Commercial/Public Authonty "LL"< 25 Mcf/Year Basic Monthly Service Charge $19.89 First5Mcf.2285% $.132 $2.929 per Mcf II.2285%/.%_1.2285% J J$o.ooolli"Per Mcf J $.135 }Per Mcf T $.132}per Mcf Over 5 Mcf.2285% $.132 $2.632 per Mcf II.2285%1.%1 o.22ss% I ($.3) I per Mcf I $.135 I per Mcf I $.132 I per Mcf Transition Surcharge $. per Mcf Rider E Surcharge $. per Mcf "Small" Commercial/Public Authority "UL"> 25 and< 1, Mcf/Year Basic Monthly Service Charge $27.53 First 2 Mcf.2285% $.132 $2.183lPer Mcf tt.2285%t o.oooo%1.2285%1 ($o.3)iper Mcf I $.135lper Mcf $.132 I per Mcf Over 2 Mcf.2285% $.132 $2.439 I per Mcf.2285% I.%.2285% ($.3) I per Mcf $.135 I per Mcf J $.132 jper Mcf Transition Surcharge $. I per Mcf Rider E Surcharge $. _jper Mcf "Large" CommerciaUPublic Authority > 1, Mcf/Ycar Basic Monthly Service Char c $121.1 First 3 Mcf.2285% $.132 $1.867 lpermcf I o.2285% I.% o.2285% I JSO.ooo:Jllicr Mcf I $.135 }per Mcf I $.132];er Mcf Next I, 7 Mcf.2285% $.132 $1.6875 I per Mcf.2285%1.%.2285% ($.3) I per Mcf $.135 I per Mcf $.132 I per Mcf Over 2, Mcf.2285% $.132 $1.4691 lpermcf Transition Surcharge $.!per Mcf Rider E Surcharge $. permcf -1.+.2285%_j..%+.2285o/{ (S.3l_fper Mcf -\- $.135 _(_per Mcf + $.132 _jper Mcf Sm;oll Volume Industrial < 1, Mcf/Year Basic Monthly Service Charge $65.6 All Consumption.2285% $.132 $2.377 ]J>er Mcf Transition Surcha!,ge $. I per Mcf -, I o.228so/~ I o.oooo%t o.2285% I ($.3) I per Mcf I $.135 I per Mcf $.132 I per Mcf Rider E Surcharge $. I per Mcf Intermediate Volume Industrial > 1, and< 5, Mcf/Year Basic Monthly Service Charge $21.91 First 1 Mcf.2285% $.132 $1.7826 I per Mcf It -.2285%/ o:oooo%t.2285%l -($.3lJPer Mcf T $.135JPer Mcf T $.1321Per Mcf Next 1,9 Mcf.2285% $.132 $1.3745 I per Mcf I.2285%.%1 o.2285% 1 ($.3) I per Mcf I $.135 I per Mcf $.132 I per Mcf Over 2, Mcf.2285% $.132 $1.551 I per Mcf.2285%_j. O.OOOOo/~ -1.+.2285%+ ($.3/.(Per Mcf + $.135 _jper Mcf $.132 _j.per Mcf -1. 1 Transition Surcha_!ge $. Rider E Surcharge $. 'per Mcf Large Volume Industrial> 5, and < 2, Mc /Year --- Basic Monthly Service Charge $89. First 1 Mcf.2285% $.132 $1.3346 1per Mcf.2285%.%.2285% ($.3} lper Mcf $.135!per Mcf $.132!per Mcf Ne:ct 1,9 Mcf.2285% $.132 $1.1528 er Mcf.2285%.%.2285% ($.3) lpermcf $.135 I per Mcf $.132 I per Mcf Ne:ct 18, Mcf.2285% $.132 $.944 per Mcf.2285%.%.2285% ($.3) I per Mcf $.135 I per Mcf $.132!per Mcf Over 2, Mcf.2285% $.132 $.868 per Mcf.2285%.%.2285% ($.3) I per Mcf $.135 I per Mcf $.132!per Mcf Transition Surcharae/Mcf $. ermcf CICI Luge Industrial > 2, Mcf/Y ear ~ "'r Basic Monthly Service Charge $1,29. ""';J:;" " First 1 Mcf.2285% $.132 $1.137 permcf.2285%.%.2285% ($.3) I per Mcf $.135 I per Mcf $.132 I per Mcf ~ Next 1,9 Mcf.2285% $.!32 $.9237 per Mcf.2285%.%.2285% ($.3) 'per Mcf $.135!per Mcf $.132 'per Mcf "C Next 18, Mcf.2285% $.132 $.7!68 )JCr Mcf.2285%.%.2285% ($.3) I per Mcf $.135 lpermcf $.132 per Mcf ~ Over 2, Mcf.2285% $.132 $.581 permcf.2285%.%.2285% ($.3) I per Mcf $.135 I per Mcf $.132 :per Mcf "'r Transition Surchar_e.c/Mcf $. ermcf ;;p~ o F \AARA\Common\VA_OATA\RESTRUCT413.Sept26\POR 1Ssues\Tarlffrstes3.31.111mgUPOA TE3 4.21.)rjs (Extub1t28)

per... --" -..:..,.,.,_, ~-.. 1-...,...,. ====-=.,,6= -~ = = ~----~--.~...,...-~., I National Fuel Gas Distribution Cc Pennsylvania Division I I I I I -+-+ + - -1- Rate Summary - Supplement 145 I I I I I I I l:fhis Rate Summary Does Not In Any W: I I L I L I Rate Structure with MFC in "Gas Cost Rates" Rate Structure less Current Rate Structure Gas Adjustment Total Retail with E Total Retail No E- SATC withe- SATC- No E- Total Retail Total Retail No SA l'c with E- SATC- NoE- Charge (E-Factor) w/ Natural Gas Supply Factor w/ MFC in Factor w/ MFC in Factor w/ MFC Factor w/ MFC with E-Factor E-Factor Factor Factor MFC Char~e w/ MFC Gas Costs Gas Costs in Gas Costs in Gas Costs Proposed Proposed Proposed Proposed C.!5=C.l2+2 C.l6=C.l3+3 C.l7=C.l+15+16 C.l8=C.i+16 C.l9=C.l+15 C.2=C.JO C.2J=C.l7-4 C.22=C.J8-5 C.23=C.l9-6 C.24=C.2-7 Residential Basic Monthly Service Charge $12. $12. $12. $12. $. $. $. $. FirstS Mcf ($.127 I per Mcf $6.12 I per Mcf $9.4266 $9.5473 $3.4164 $3.5371 $.1285 $.1311 ($.26) $. Over 5 Mcf ($.127) I per Mcf $6.12 jper Mcf 58.398 $8.5115 $2.386 $2.513 $.1285 $.1311 ($.26) $. Transition Surcharge $. $. $. $. $. $. $. $. Rider E Surchar~:e $. $. $. $. $. $. $. $. Rider F Surcharge $.329 $.329 $.329 $.329 $. $. $. $. "Small" Commercial/Public Authority "LL"< 25 Mcf/Year Basic Monthly Service Charge $19.89 $19.89 $19.89 $19.89 $. $. $. $. First 5 Mcf J$.11841 jper Mcf $5.8926.JlerMcf $8.732 $8.8216 $2.816 $2.929 $.132 $.135 J$.3) $. Over 5 Mcf ($.1184) jper Mcf $5.8926 iper Mcf $8.3774 $8.4958 $2.4848 $2.632 $.132 $.135 ($.3) $. Transition Surcharge so.oooo $. $. $. $. $. $. $. Rider E Surchar~:e $. so.oooo $. $. $. $. $. $. "Small'" Commercial/Public Authority "UL"> 25 and< 1, Mcf/Year Basic Monthly Service Charge $27.53 $27.53 $27.53 $27.53 $. $. $. $. First 2 Mcf ($.1184) ermcf $5.8926 IPer Mcf $7.9545 $8.729 $2.619 $2.183 $.132 $.135 _($.3) $. Over 2 Mcf ($.1184) per Mcf $5.8926 I per Mcf $7.8181 $7.9365 $1.9255 $2.439 $.132 $.135 ($.3) $. Transition Surcharge $. $. $. $. $. $. $. $. Rider E Surcharge $. $. $. $. $. $. $. $. "Large" Commercial/Public Authority > 1, Mcf/Y ear Basic Monthly Service Charge $121.1 $121.1 $121.D! $121.1 $. $. $. $. First 3 Mcf ($.1184 lpermcf $5.8926 (per Mcf $7.589 $7.6993 $1.6883 $1.867 $.132 $.135 ($.3) $. Next I. 7 Mcf ($.1184 lpermcf $5.8926 I per Mcf $7.4617 $7.581 $1.5691 $1.6875 $.132 $.135 ($.3) $. Over 2, Mcf ($.1184.) I per Mcf $5.8926 lpermcf $7.2433 $7.3617 $1.357 $1.4691 $.132 $.135 $.3 $. Transition Surcha!&e $. so.oooo $. $. $. $. $. $. Rider E Surcharge $. $. $. $. $. $. $. $. Small Volume Industrial< 1, Mcf/Year Basic Monthly Service Charge l" 1 1 1 1 $65.61 s6s.6o T s6s.6o T s6s.6o T1 $o.oooot $o.oooot $.1 $. All Consumption ($.1184)lper Mcf I $5.8926 I per Mcf $8.1449 $8.2633 I s2.2523 I $2.377 I $.132 I $o.o135 I ($.3) $. Transition Surcha!&e $. so.oooo I $. so.oooo I $o.oooo I $o.oooo I $. $. Rider E Surcharge _j_ J_ J ). J $. J $. _j_ so.oooo_j_ so.oooo_j_j $._)_ $.j_ $.J $. Intermediate Volume Industrial> 1, and < 5, Mcf/Year Basic Monthly Service Charge $21.91 $21.91 $21.91 $21.91 $. $. $. $. First 1 Mcf ($.1184) lpermcf $5.8926 Mcf $7.5568 $7.6752 $1.6642 $1.7826 $.132 $.135 ($.3) $. Next 1,9 Mcf ($.1184) I per Mcf $5.8926 'permcf $7.1487 $7.2671 $1.2561 $1.3745 $.132 $.135 ($.3) $. Over 2, Mcf ($.1184) loer Mcf $5.8926 per Mcf $6.8293 $6.9477 $.9367 $1.551 $.132 $.135 _($.3) $. Transition Surchar~e $. $. $. $. $. $. $. $. Rider E Surcharge $. $. $. $. $. $. $. $. Large Volume Industrial > 5, and < 2, Mcf/Year Basic Monthly Service Charge $89. $89. $89. $89. $. $. $. $. First 1 Mcf ($.1184) er Mcf $5.8926 er Mcf $7.188 $7.2272 $1.2162 $1.3346 $.132 $.135 ($.3) $. Next 1,9 Mcf ($.1184) jpermcf $5.8926 per Mcf $6.927 $7.454 $1.344 $1.1528 $.132 $.135 _($.3) $. Next 18, Mcf ($.1184) er Mcf $5.8926 ermcf $6.7182 $6.8366 $.8256 $.944 $.132 $.135 ($.3) $. Over 2, Mcf ($.1184) per Mcf $5.8926 permcf $6.581 $6.6994 $.6884 $.868 $.132 $.135 ($.3) $. Transition Surcharge/Mcf $. $. $. $. $. $. $. $. La~e Industrial> 2, Mcf/Year (JQ f'l)., Basic Monthly Service Char~:c $1,29. $1,29. $1,29. $1,29. $. $. $. $. ua~ First 1 Mcf ($.1184 per Mcf $5.8926 lper Mcf $6.8779 $6.9963 $.9853 $1.137 $.132 $.135 ($.3) $. "C Next 1,9 Mcf ($.1184 per Mcf $5.8926 I per Mcf $6.6979 $6.8163 $.853 $.9237 $.132 $.135 ($.3) $. ~ Next 18, Mcf ($.!184 per Mcf $5.8926 ljlermcf $6.491 $6.694 $.5984 $.7168 $.132 $.135 ($.3) $. "C f'l) Over 2. Mcf ($.1184 er Mcf $5.8926 I per Mcf $6.3552 $6.4736 $.4626 $.581 $.132 $.135 ($.3) $.., Transition Surcha!.e.c/Mcf $. $. $. $. $. $. $. $. ;;~ F \AARA\Common\VA_DATA\AESTAUCT413.Sept.28\POA lssues\tanffrates3.31.fihngupoate3.4 21.xls (Extublt2B)

National Fuel Gas Distribution Corporation Pennsylvania Division Rate Summary: Current= Supplement 145 This Rate Summary Does Not In Any Way Supersede The Tariff Rate Structure with MFC in Current Rate Structure Merchant Function Charge (MFC) "Gas Cost Rates" Basic Service Merchant Basic Service Charge & Charge & Function MFCGas Distribution Charges Distribution Gas Adjustment Natural Gas Charge Adjustment Charge MFC Natural Gas Total Merchant Less Gas Cost Write-Off Total Gas Supply Charges Charge (E-Factor) Supply Charge Factor (E-Factor) Supply Charge Function Charge Rate Charges w/ MFC/GPC C.l C.2 C.3 C.4 C.5 = C.4xC.2 C.6 = C.4xC.3 c. 7 = C.5+C.6 C.8 = C.l-C.7 C.9 = (C.2+C.3)+C.7 Residential Basic Monthly Service Charge $12. $12. First 5 Mcf $3.5371 permcf ($.1181) per Mcf $5.8791 per Mcf 2.231% ($.26) per Mcf $.1311 per Mcf $.1285 per Mcf $3.5371 permcf $5.9945 per Mcf Over 5 Mcf $2.513 per Mcf ($.1181) per Mcf $5.8791 per Mcf 2.231% ($.26) per Mcf $.1311 per Mcf $.1285 per Mcf $2.513 per Mcf $5.9945 per Mcf Rider F Surcharge $.329 per Mcf $.329 per Mcf "Small" Commercial/Public Authority "LL"< 25 Mcf/Year Basic Monthly Service Charge $19.89 $19.89 First 5 Mcf $2.929 per Mcf ($.1181) permcf $5.8791 per Mcf.2285% ($.3) per Mcf $.135 per Mcf $.132 per Mcf $2.929 per Mcf $5.8792 per Mcf Over 5 Mcf $2.632 per Mcf ($.1181) permcf $5.8791 per Mcf.2285% ($.3) per Mcf $.135 per Mcf $.132 per Mcf $2.632 per Mcf $5.8792 per Mcf "Small" Commercial/Public Authority "UL"> 25 and< 1, Mcf/Year Basic Monthly Service Charge $27.53 $27.53 First 2 Mcf $2.183 per Mcf ($.1181) per Mcf $5.8791 permcf.2285% ($.3) per Mcf $.135 per Mcf $.132 per Mcf $2.183 per Mcf $5.8792 per Mcf Over 2 Mcf $2.439 per Mcf ($.1181) per Mcf $5.8791 per Mcf.2285% ($.3) per Mcf $.135 per Mcf $.132 per Mcf $2.439 per Mcf $5.8792 per Mcf "Large" Commercial/Public Authority> 1, Mcf/Y ear Basic Monthly Service Charge $121.1 $121.1 First 3 Mcf $1.867 per Mcf ($.1181) per Mcf $5.8791 per Mcf.2285% ($.3) per Mcf $.135 per Mcf $.132 per Mcf $1.867 per Mcf $5.8792 per Mcf Next1,7 Mcf $1.6875 per Mcf ($.1181) per Mcf $5.8791 per Mcf.2285% ($.3) per Mcf $.135 per Mcf $.132 per Mcf $1.6875 per Mcf $5.8792 per Mcf Over 2, Mcf $1.4691 per Mcf ($.1181) per Mcf $5.8791 per Mcf.2285% ($.3) per Mcf $.135 per Mcf $.132 per Mcf $1.4691 per Mcf $5.8792 per Mcf Small Volume Industrial< 1, Mcf/Year Basic Monthly Service Charge $65.6 $65.6 All Consumption $2.377 per Mcf ($.1181) per Mcf $5.8791 per Mcf.2285% ($.3) per Mcf $.135 per Mcf $.132 per Mcf $2.377 per Mcf $5.8792 per Mcf Intermediate Volume Industrial > 1, and< 5, Mcf/Year Basic Monthly Service Charge $21.91 $21.91 First 1 Mcf $1.7826 per Mcf ($.1181) per Mcf $5.8791 per Mcf.2285% ($.3) per Mcf $.135 per Mcf $.132 per Mcf $1.7826 per Mcf $5.8792 per Mcf Next 1,9 Mcf $1.3745 per Mcf ($.1181) per Mcf $5.8791 per Mcf.2285% ($.3) per Mcf $.135 per Mcf $.132 per Mcf $1.3745 per Mcf $5.8792 per Mcf Over 2, Mcf $1.551 per Mcf ($.1181) per Mcf $5.8791 per Mcf.2285% ($.3) per Mcf $.135 per Mcf $.132 per Mcf $1.551 per Mcf $5.8792 per Mcf Large Volume Industrial> 5,, and< 2, Mcf/Year Basic Monthly Service Charge $89. $89. First 1 Mcf $1.3346 per Mcf ($.1181) per Mcf $5.8791 per Mcf.2285% ($.3) per Mcf $.135 per Mcf $.132 per Mcf $1.3346 per Mcf $5.8792 per Mcf Next 1,9 Mcf $1.1528 per Mcf ($.1181) per Mcf $5.8791 per Mcf.2285% ($.3) per Mcf $.135 per Mcf $.132 per Mcf $1.1528 per Mcf $5.8792 per Mcf Next18, Mcf $.944 per Mcf ($.1181) per Mcf $5.8791 per Mcf.2285% ($.3) per Mcf $.135 per Mcf $.132 per Mcf $.944 per Mcf $5.8792 per Mcf Over 2, Mcf $.868 per Mcf ($.1181) per Mcf $5.8791 per Mcf.2285% ($.3) per Mcf $.135 per Mcf $.132 per Mcf $.868 per Mcf $5.8792 per Mcf Large Industrial> 2, Mcf/Year Basic Monthly Service Charge $1,29. $1,29. First 1 Mcf $1.137 per Mcf ($.1181) per Mcf $5.8791 per Mcf.2285% ($.3) per Mcf $.135 per Mcf $.132 per Mcf $1.137 per Mcf $5.8792 per Mcf Next 1,9 Mcf $.9237 per Mcf ($.1181) per Mcf $5.8791 per Mcf.2285% ($.3) per Mcf $.135 per Mcf $.132 per Mcf $.9237 per Mcf $5.8792 per Mcf Next 18, Mcf $.7168 per Mcf ($.1181) per Mcf $5.8791 per Mcf.2285% ($.3) per Mcf $.135 per Mcf $.132 per Mcf $.7168 per Mcf $5.8792 per Mcf Over 2, Mcf $.581 per Mcf ($.1181) per Mcf $5.8791 per Mcf.2285% ($.3) per Mcf $.135 per Mcf $.132 per Mcf $.581 per Mcf $5.8792 per Mcf "'~ ~ ~ o-..s ""' ~ "' ~ "''

National Fuel Gas Distribution Corporation Pennsylvania Division Unbundled sales and Aggregation Rate Schedule August 1, 213 I Sales Rate Components Summary Total Sales Natural Gas Gas Total Storage & Tariff Supply Adjustment Commodity Distribution Capacity Rate Cost Charge Gas Cost Charge Gas Cost (A) (B) (C) (D=B+C) (E) (F) (G=E+F) Residential Basic Service Charge $ 12. First 5 Mcf $ 9.2981 $ 5.8791 $ (.1181) $ 5.761 $.238 $ $.238 Over 5 Mcf $ 8.2623 $ 5.8791 $ (.1181) $ 5.761 $.238 $ $.238 Small Commercial L.L. Basic Service Charge $ 19.89 First 5 Mcf $ 8.69 $ 5.8791 $ (.1181) $ 5.761 $.238 $ $.238 Over 5 Mcf $ 8.3642 $ 58791 $ (.1181) $ 5.761 $.238 $ $.238 Small Commercial U.L. Basic Service Charge $ 27.53 First 2 Mcf $ 7.9413 $ 5.8791 $ (.1181) $ 5.761 $.238 $ $.238 Over 2 Mcf $ 7.849 $ 5.8791 $ (.1181) $ 5.761 $.238 $ $.238 Large Commercial Basic Service Charge $ 121.1 First 3 Mcf $ 7.5677 $ 5.8791 $ (.1181) $ 5.761 $.238 $ $.238 Next 1, 7 Mcf $ 7.4485 $ 5.8791 $ (.1181) $ 5.761 $.238 $ $.238 Over 2, Mcf $ 7.231 $ 5.8791 $ (.1181) $ 5.761 $.238 $ $.238 Small Volume Industrial Basic Service Charge $ 65.6 All Volumes $ 8.1317 $ 5 8791 $ (.1181) $ 5.761 $.238 $ $.238 Intermediate Volume Industrial Basic Service Charge $ 21.91 First 1 Mcf $ 7.5436 $ 5.8791 $ (.1181) $ 5.761 $.238 $ $.238 Next 1,9 Mcf $ 7.1355 $ 5.8791 $ (.1181) $ 5.761 $.238 $ $.238 Over 2, Mcf $ 6.8161 $ 5.8791 $ (.1181) $ 5.761 $.238 $ $.238 Large Volume Industrial Basic Service Charge $ 89. First 1 Mcf $ 7.956 $ 5.8791 $ (.1181) $ 5.761 $.238 $ $.238 Next 1,9 Mcf $ 6.9138 $ 5.8791 $ (.1181) $ 5.761 $.238 $ $.238 Next 18, Mcf $ 6.75 $ 5.8791 $ (.1181) $ 5.761 $.238 $ $.238 Over 2, Mcf $ 6.5678 $ 5.8791 $ (.1181) $ 5.761 $.238 $ $.238 Large Industrial Basic Service Charge $ 1,29. First 1 Mcf $ 6.8647 $ 5.8791 $ (.1181) $ 5.761 $.238 $ $.238 Next 1,9 Mcf $ 6.6847 $ 5.8791 $ (.1181) $ 5.761 $.238 $ $.238 Next 18, Mcf $ 6.4778 $ 5.8791 $ (.1181) $ 5.761 $.238 $ $.238 Over 2, Mcf $ 6.342 $ 5.8791 $ (.1181) $ 5.761 $.238 $ $.238 Total Gas Cost (H=G+D) $ $ 5.999 $ $ 5.999 $ $ $ 5.999 $ $ 5.999 $ $ $ 5.999 $ $ 5.999 $ $ $ 5.999 $ $ 5.999 $ $ 5.999 $ $ $ 5.999 $ $ $ 5.999 $ $ 5.999 $ $ 5.999 $ $ $ 5.999 $ $ 5.999 $ $ 5.999 $ $ 5.999 $ $ $ 5.999 $ $ 5.999 $ $ 5.999 $ $ 5.999 $ GRT (I) Base Rates Non-gas Costs (J=A-H-1) $ 12. $ 3.2991 $ 2.2633 $ 19.89 $ 2.691 $ 2.3652 $ 27.53 $ 1.9423 $ 1.859 $ 121.1 $ 1.5687 $ 1.4495 $ 1.2311 $ 65.6 $ 2.1327 $ 21.91 $ 1.5446 $ 1.1365 $.8171 $ 89. $ 1.966 $.9148 $.76 $.5688 $1,29. $.8657 $.6857 $.4788 $.343 I 7/29/213 1:1 AM ;JJ~... -s (ICI td "'' ~ "C td "''

-======-~==-~-==-~-~ -==-...:c=c_c::~c --~ ==-:::::::-~~=:::.:..:l:!t:"":"_!::::c:== c::...--:=.-:::::""...:o=::::=:-=c!: ~ ~-:::-,::,_~::-=:=:;:..~:;::,::-~~~=± :;: -;:=~.::::= :.::=:=::;:.-~":::::7=~--;=.:::l.::J - -:::-;::1::: _;.. -,.-: _:;.:::===--::::.:_====l:..-::t~±-: '"'- ----..- "-o-.-.-:~--c-=.,..,. ===============~====~ August 1, 213 National Fuel Gas Distribution Corporation Pennsylvania Division Derivation of Unbundled Small Volume Transportation (SATC) Rates SATC Rates for Converting SATC Billing Rates Sales Customers Bill Rate for Billed Bill Rate Proposed Total Base Rates Retained Demand SATC Existing Gas for New SATC Gas SATC Rates Non-gas Capacity Distribution Gas Tariff Transition Bypass Rider E RiderF SATC Adjustment SATC Tariff Adjustment for Converting Costs Cost Charge Cost Rate Cost Credit Credit Rate Customer With/MFC Customer Rate With/MFC Customers (K=J) (L) (M) (N=F) (O=L+M+N) (P=K+O) (O=P) (R=C) (S=O+R) Residential Basic Service Charge $ 12. $ 12. $ 12. $ 12. $ 12. $ 12. FirstS Mcf $ 3.2991 $.238 $.238 $ 3.S371 $ $.329 $ 3.S7 $ (.127) $ 3.4493 $ 3.S371 $ (.127) $ 3.4164 OverS Mcf $ 2.2633 $.238 $.238 $ 2.S13 $ $.329 $ 2.S342 $ (.127) $ 2.413S $ 2.S13 $ (.127) $ 2.386 Small Commercial L.L. Basic Service Charge $ 19.89 $ 19.89 $ 19.89 $ 19.89 $ 19.89 $ 19.89 FirstS Mcf $ 2.691 $.238 $.238 $ 2.929 $ $ $ 2.929 $ (.1184) $ 2.816 $ 2.929 $ (.1184) $ 2.816 OverS Mcf $ 2.36S2 $.238 $.238 $ 2.632 $ $ $ 2.632 $ (.1184) $ 2.4848 $ 2.632 $ (.1184) $ 2.4848 Small Commercial U.L. Basic Service Charge $ 27.S3 $ 27.S3 $ 27.S3 $ 27.S3 $ 27.S3 $ 27.S3 First2 Mcf $ 1.9423 $.238 $.238 $ 2.183 $ $ $ 2.183 $ (.1184) $ 2.619 $ 2.183 $ (.1184) $ 2.619 Over 2 Mcf $ 1.8S9 $.238 $.238 $ 2.439 $ $ $ 2.439 $ (.1184) $ 1.92SS $ 2.439 $ (.1184) $ 1.92SS Large Commercial Basic Service Charge $ 121.1 $ 121.1 $ 121.1 $ 121.Q1 $ 121.1 $ 121.Q1 First 3 Mcf $ 1.S687 $.238 $.238 $ 1.867 $ $ $ 1.867 $ (.1184} $ 1.6883 $ 1.867 $ (.1184} $ 1.6883 Next 1,7 Mcf $ 1.449S $.238 $.238 $ 1.687S $ $ $ 1.687S $ (.1184} $ 1.S691 $ 1.687S $ (.1184} $ 1.S691 Over 2, Mcf $ 1.2311 $.238 $.238 $ 1.4691 $ $ $ 1.4691 $ (.1184) $ 1.3S7 $ 1.4691 $ (.1184) $ 1.3S7 Small Volume Industrial Basic Service Charge $ 6S.6 $ 6S.6 $ 6S.6 $ 6S.6 $ 6S.6 $ 6S.6 All Volumes $ 2.1327 $.238 $.238 $ 2.377 $ $ $ 2.377 $ (.1184) $ 2.2S23 $ 2.377 $ (.1184) $ 2.2S23 Intermediate Volume Industrial Basic Service Charge $ 21.91 $ 21.91 $ 21.91 $ 21.91 $ 21.91 $ 21.91 First 1 Mcf $ 1.S446 $.238 $.238 $ 1.7826 $ $ $ 1.7826 $ (.1184) $ 1.6642 $ 1.7826 $ (.1184) $ 1.6642 Next 1,9 Mcf $ 1.136S $.238 $.238 $ 1.374S $ $ $ 1.374S $ (.1184) $ 1.2S61 $ 1.374S $ (.1184) $ 1.2S61 Over 2, Mcf $.8171 $.238 $.238 $ 1.S51 $ $ $ 1.SS1 $ (.1184) $.9367 $ 1.SS1 $ (.1184) $.9367 Large Volume Industrial Basic Service Charge $ 89. $ 89. $ 89. $ 89. $ 89. $ 89. First 1 Mcf $ 1.966 $.238 $.238 $ 1.3346 $ $ $ 1.3346 $ (.1184) $ 1.2162 $ 1.3346 $ (.1184) $ 1.2162 Next 1,9 Mcf $.9148 $.238 $.238 $ 1.1S28 $ $ $ 1.1528 $ (.1184) $ 1.344 $ 1.1S28 $ (.1184) $ 1.344 Next 18, Mcf $.76 $.238 $.238 $.944 $ $ $.944 $ (.1184} $.82S6 $.944 $ (.1184} $.82S6 Over 2, Mcf $.5688 $.238 $.238 $.868 $ $ $.868 $ (.1184) $.6884 $.868 $ (.1184) $.6884 Large Industrial Basic Service Charge $1,29. $1,29. $ 1,29. $ 1,29. $ 1,29. $ 1,29. First 1 Mcf $.86S7 $.238 $.238 $ 1.137 $ $ $ 1.137 $ (.1184) $.98S3 $ 1.137 $ (.1184) $.98S3 Next 1,9 Mcf $.68S7 $.238 $.238 $.9237 $ $ $.9237 $ (.1184) $.8S3 $.9237 $ (.1184) $.8S3 Next 18, Mcf $.4788 $.238 $.238 $.7168 $ $ $.7168 $ (.1184) $ O.S984 $.7168 $ (.1184) $ O.S984 Over 2, Mcf $.343 $.238 $.238 $ O.S81 $ $ $ O.S81 $ (.1184} $.4626 $ O.S81 $ (.1184} $.4626 ~~ (JC:I td "'l QC~ " Do? " td "'l

National Fuel Gas Distribution Corporation Pennsylvania Division Derivation of Natural Gas Supply Charges To Include in Unbundled ComQanr Sales Tariff Jatural Gas SUQQii:: Charges -NO MFC Base Natural Gas Rate Distribuition Gas Supply Gas Gas Cost Charge Adjustment Charge Adjustment {H) {I) {J) {K=H-1-J) {L=J) Residential Basic Service Charge First 5 Mcf $ 5.999 $.238 $ (.1181) $ 5.8791 $ {.1181) Over 5 Mcf $ 5.999 $.238 $ {.1181) $ 5.8791 $ {.1181) Small Commercial L.L. Basic Service Charge First 5 Mcf $ 5.999 $.238 $ {.1181) $ 5.8791 $ {.1181) Over 5 Mcf $ 5.999 $.238 $ {.1181) $ 5.8791 $ {.1181) Small Commercial U.L. Basic Service Charge First 2 Mcf $ 5.999 $.238 $ {.1181) $ 5.8791 $ {.1181) Over 2 Mel $ 5.999 $.238 $ {.1181) $ 5.8791 $ {.1181) Large Commercial Basic Service Charge First 3 Mcf $ 5.999 $.238 $ {.1181) $ 5.8791 $ (.1181) Next 1,7 Mcf $ 5.999 $.238 $ {.1181) $ 5.8791 $ {.1181) Over 2, Mcf $ 5.999 $.238 $ (.1181) $ 5.8791 $ (.1181) Small Volume Industrial Basic Service Charge All Volumes $ 5.999 $.238 $ {.1181) $ 5.8791 $ {.1181) Intermediate Volume Industrial Basic Service Charge First 1 Mcf $ 5.999 $.238 $ {.1181) $ 5.8791 $ {.1181) Next 1,9 Mcf $ 5.999 $.238 $ {.1181) $ 5.8791 $ {.1181) Over 2, Mel $ 5.999 $.238 $ {.1181) $ 5.8791 $ {.1181) Large Volume Industrial Basic Service Charge First 1 Mcf $ 5.999 $.238 $ {.1181) $ 5.8791 $ {.1181) Next 1,9 Mcf $ 5.999 $.238 $ (.1181) $ 5.8791 $ {.1181) Next 18, Mcf $ 5.999 $.238 $ {.1181) $ 5.8791 $ {.1181) Over 2, Mel $ 5.999 $.238 $ {.1181) $ 5.8791 $ {.1181) Large Industrial Basic Service Charge First 1 Met $ 5.999 $.238 $ (.1181) $ 5.8791 $ (.1181) Next 1,9 Mcf $ 5.999 $.238 $ {.1181) $ 5.8791 $ {.1181) Next 18, Mcf $ 5.999 $.238 $ {.1181) $ 5.8791 $ {.1181) Over 2, Mcf $ 5.999 $.238 $ (.1181) $ 5.8791 $ (.1181) ~~ (J'Q td "": ~.e,.s ~ " td '"l

--~--~- August 1, 213 I Unbundled Rate Components Gas Natural Gas Adjustment Supply Distribution Credit/2 Charge Distribution Charges /1 W\MFC W \ MFC \GPC Charges /1 (A) (B) (C) (A) Residential Basic Service Charge $ 12. $ 12. First 5 Met $ 3.5371 $ (.127) $ 6.1152 $ 3.5371 Over5 Met $ 2.513 $ (.127) $ 6.1152 $ 2.513 Small Commercial L.L. Basic Service Charge $ 19.89 $ 19.89 First 5 Met $ 2.929 $ (.1184) $ 5.9976 $ 2.929 Over 5 Met $ 2.632 $ (.1184) $ 5.9976 $ 2.632 Small Commercial U.L. Basic Service Charge $ 27.53 $ 27.53 First2 Met $ 2.183 $ (.1184) $ 5.9976 $ 2.183 Over2 Met $ 2.439 $ (.1184) $ 5.9976 $ 2.439 Large Commercial Basic Service Charge $ 121.Q1 $ 121.1 First 3 Met $ 1.867 $ (.1184) $ 5.9976 $ 1.867 Next 1, 7 Met $ 1.6875 $ (.1184) $ 5.9976 $ 1.6875 Over 2, Met $ 1.4691 $ (.1184) $ 5.9976 $ 1.4691 Small Volume Industrial Basic Service Charge $ 65.6 $ 65.6 All Volumes $ 2.377 $ (.1184) $ 5.9976 $ 2.377 Intermediate Volume Industrial Basic Service Charge $ 21.91 $ 21.91 First 1 Met $ 1.7826 $ (.1184) $ 5.9976 $ 1.7826 Next 1,9 Met $ 1.3745 $ (.1184) $ 5.9976 $ 1.3745 Over 2, Met $ 1.551 $ (.1184) $ 5.9976 $ 1.551 Large Volume Industrial Basic Service Charge $ 89. $ 89. First 1 Met $ 1.3346 $ (.1184) $ 5.9976 $ 1.3346 Next 1,9 Met $ 1.1528 $ (.1184) $ 5.9976 $ 1.1528 Next 18, Met $.944 $ (.1184) $ 5.9976 $.944 Over 2, Met $.868 $ (.1184) $ 5.9976 $.868 Large Industrial Basic Service Charge $ 1,29. $ 1,29. First 1 Met $ 1.137 $ (.1184) $ 5.9976 $ 1.137 Next 1,9 Met $.9237 $ (.1184) $ 5.9976 $.9237 Next 18, Met $.7168 $ (.1184) $ 5.9976 $.7168 Over 2, Met $.581 $ (.1184) $ 5.9976 $.581 I I National Fuel Gas Distribution Corporation Pennsylvania Division Unbundled Sales and Aggregation rate Schedule Rates Unbundled Rate Components With GRT Gas Natural Gas Sum of Adjustment Supply Unbundled Credit/2 Charge Components W\MFC W\MFC\GPC (B) (C) $ 12. $ (.127) $ 6.1152 $ 9.5316 $ (.127) $ 6.1152 $ 8.4958 $ 19.89 $ (.1184) $ 5.9976 $ 8.882 $ (.1184) $ 5.9976 $ 8.4824 $ 27.53 $ (.1184) $ 5.9976 $ 8.595 $ (.1184) $ 5.9976 $ 7.9231 $ 121.1 $ (.1184) $ 5.9976 $ 7.6859 $ (.1184) $ 5.9976 $ 7.5667 $ (.1184) $ 5.9976 $ 7.3483 $ 65.6 $ (.1184) $ 5.9976 $ 8.2499 $ 21.91 $ (.1184) $ 5.9976 $ 7.6618 $ (.1184) $ 5.9976 $ 7.2537 $ (.1184) $ 5.9976 $ 6.9343 $ 89. $ (.1184) $ 5.9976 $ 7.2138 $ (.1184) $ 5.9976 $ 7.32 $ (.1184) $ 5.9976 $ 6.8232 $ (.1184) $ 5.9976 $ 6.686 $ 1,29. $ (.1184) $ 5.9976 $ 6.9829 $ (.1184) $ 5.9976 $ 6.829 $ (.1184) $ 5.9976 $ 6.596 $ (.1184) $ 5.9976 $ 6.462 I Check that Unbundled Rates Equal Sales Rates Sum of Tariff Sum of Unbundled Sales Unbundled Components Rate/3 Components GRT /4 &GRT (D) (E=A+B+C) (F) (G=E+F) $ 12. $ 12. $ $ 12. $ 9.5316 $ 9.5316 $ $ 9.5316 $ 8.4958 $ 8.4958 $ $ 8.4958 $ 19.89 $ 19.89 $ $ 19.89 $ 8.882 $ 8.882 $ $ 8.882 $ 8.4824 $ 8.4824 $ $ 8.4824 $ 27.53 $ 27.53 $ $ 27.53 $ 8.595 $ 8.595 $ $ 8.595 $ 7.9231 $ 7.9231 $ $ 7.9231 $ 121.Q1 $ 121.1 $ $ 121.1 $ 7.6859 $ 7.6859 $ $ 7.6859 $ 7.5667 $ 7.5667 $ $ 7.5667 $ 7.3483 $ 7.3483 $ $ 7.3483 $ 65.6 $ 65.6 $ $ 65.6 $ 8.2499 $ 8.2499 $ $ 8.2499 $ 21.91 $ 21.91 $ $ 21.91 $ 7.6618 $ 7.6618 $ $ 7.6618 $ 7.2537 $ 7.2537 $ $ 7.2537 $ 6.9343 $ 6.9343 $ $ 6.9343 $ 89. $ 89. $ $ 89. $ 7.2138 $ 7.2138 $ $ 7.2138 $ 7.32 $ 7.32 $ $ 7.32 $ 6.8232 $ 6.8232 $ $ 6.8232 $ 6.686 $ 6.686 $ $ 6.686 $1,29. $ 1,29. $ $ 1,29. $ 6.9829 $ 6.9829 $ $ 6.9829 $ 6.829 $ 6.829 $ $ 6.829 $ 6.596 $ 6.596 $ $ 6.596 $ 6.462 $ 6.462 $ $ 6.462 ~~ (JQ t'd.., -:;!::"' c"c ~ "C t'd..,

National Fuel Gas Distribution Corporation Pennsylvania Division Calculation of Load Balancing Service Gas Cost Rates Workpaper Page 11 A Demand B Commodity 1) 2) Total Gas Cost per Mcf included in base rates: Distribution Charge Total Annual Sales & Sales+ SATC $1.526 $4.235 PGC Exhibit 21, Schedule 1, Page 4 of 4, Columns 1 $.238 18,335,882 PGC Exhibit 22, Page 4 of 4 2,721,42 3) 4) 5) 6) 7) Total Demand Cost: Distribution S+Charge Peak Month Sales Sales = SATC peak Demand Billing Units Distribution Charge Units Load Balancing Demand Costs Rate: Distribution Charge Load Balancing Commodity Cost Rate $27,98,556 Line 1, Column Ax Line 2 Column A 4,931,694 3,24,85 PGC Exhibit 22, Page 4 of 4 3,655,452 38,89,2 Line 4, Column Ax 12 43,865,424 $.7195 Line 3, Column A + Line 5, Column A $.1124 $.8319 $4.235 Line 1, Column B 8) Transition Costs $. Per Tariff 9) Total Load Balancing Commodity Cost Rate $4.235 Line 7 plus Line 8 F:\RARA\Common\VA_DATA\PatariffNo.9\Supp31\PACHANGE- REV.xls (N)

A B c D E F G H 582 TABLE a-average Aug Sep Oct Nov Dec Jan 583 Volume (Mcf) 1.69 2.1 4.5 8.44 12.53 16.58 584 Monthly Distribution 1.65% 1.911% 4.282% 8.19% 11.96% 15.759% 585 Monthly Volumes 1.688 2.1 4.55 8.436 12.525 16.578 586 Actual Deg. Days 1 28 227 491 768 1,22 587 Normal Deg. Days 2 39 29 474 855 1,183 588 Normal Consumption 1.725 2.123 4.284 8.23 13.749 18.911:! 589 59 Blocked Volume 591 1st5 Mcf 5: 1.72 2.12 4.28 5. s.oo S.OO 592 OverS Mcf s 3.2 8.75 13.92 593 Total 1.72 2.12 4.28 8.2 13.7S 18.92 S94 59S 596 Residential Rate 597 Gust Charge $ 12. $ 12. $ 12. $ 12. $ 12. $ 12. $ 598 Distribution Chg 599 1st5 Mcf $ 3.5371 $ 3.5371 $ 3.5371 $ 3.5371 $ 3.5371 $ 3.5371 $ 6 OverS Mcf $ 2.S13 $ 2.513 $ 2.S13 $ 2.513 $ 2.S13 $ 2.513 $ 61 Gas Adjustment Chg $ (.127) $ (.127) $ (.127) $ (.127) $ (.127) $ (.127) $ 62 NGS Charge $ 6.1152 $ 6.11S2 $ 6.1152 $ 6.11S2 $ 6.11S2 $ 6.1152 $ 63 64 Residential Revenue 65 Gust Charge $ 12. $ 12. $ 12. $ 12. $ 12. $ 12. $ 66 Distribution Chg 67 1st5Mcf $ 6.1 $ 7.51 $ 15.15 $ 17.69 $ 17.69 $ 17.69 $ 68 Overs Mcf $ $ $ $ 8.1 $ 21.88 $ 34.81 $ 69 Gas Adjustment Chg $ (.21) $ (.26) $ (O.S2) $ (.99) $ (1.66) $ (2.28) $ 61 NGSCharge $ 1.55 $ 12.98 $ 26.2 $ 5.17 $ 84.7 $ 115.69 $ 611 Total $ 28.44 $ 32.23 $ S2.83 $ 86.87 $ 133.98 $ 177.9 $ 612 613 Avg Discount 12.94% 12.94% 12.94% 12.94% 12.94% 12.94% 614 61S Discount Amount $ 3.68 $ 4.17 $ 6.84 $ 11.25 $ 17.34 $ 23.3 $ 616 617 Lira Customers 1,134 1,215 1,28 1,89 1,164 1,27 618 619 Discount Amount $ 37,36 $ 42,62 $ 69,815 $ 113,456 $ 176,282 $ 236,51 $ 62 621 Sales 233,993 331,823 575,455 1,11,964 2,3,73 2,724,219 622 SATC 28,623 4,837 76,332 148,646 285,31 439,149 623 Res MMT 492 642 1,913 4,818 9,655 13,1 624 Incremental LIRA Volumes (364) (62) (1,221} {1,362) (3,313) (6,S65) 625 Projected Residential Volume 262,744 372,682 652,479 1,254,66 2,294,716 3,169,813 626 627 Rider Variable Rate $.838 $.838 $.838 $.838 $.838 $.838 $ 628 629 Discount Recovery $ 22,28.43 $ 31,245.54 $ 54,73.62 $ 15,14.S7 $ 192,388.33 $ 265,756.3 $ i63 631 Monthly Over/Under Recovery_ $ (15,277.92) $ (11,374.18) $ (1S,111.79) $ (8,315.92} $ 16,16.81 $ 29,246.75 $ 632 633 Prospective Discount o/o Rate Change 1 1 1 1 1 1 634 Discount Amount $ 37,36.35 $ 42,619.72 $ 69,815.41 $ 113,456.49 $ 176,281.52 $ 236,59.55 $ 635 636 Prospective Discount $.838 $.838 $.838 $.838 $.838 $.838 $ 637 Discount Recovery $ 22,28.43 $ 31,245.54 $ S4,73.62 $ 15,14.57 $ 192,388.33 $ 265,7S6.3 $ 638 Monthly Over/Under Recovery $ (15,277.92) $ {11,374.181 $ _{_15,111.79)_ $ (8,31S.92) $ 16,16.81 $ 29,246.75 $ 639 64 641 Monthly Lira Customer Increase 211 81 (7) (119) 75 16 642 Total LIRA 211 292 285 166 241 347 I J Feb Mar 17.57 16.87 16.76% 16.33% 17.575 16.866 1,68 1,16 1,15 988 18.124 16.449 5. s.oo 13.12 11.45 18.12 16.4S 12. $ 12. $ 3.5371 $ 3.5371 $ 2.513 $ 2.513 $ (.127) $ (.127) $ 6.11S2 $ 6.1152 $ 12. $ 12. $ 17.69 $ 17.69 $ 32.83 $ 28.64 $ (2.19} $ (1.99) $ 11.83 $ 1.59 $ 171.15 $ 156.93 $ 12.94% 12.94% 22.16 $ 2.31 $ 1,422 1,535 23,92 $ 214,2 $ 2,621,19 2,355,63 442,477 413,351 14,164 14,8S (9,44) (1,67) 3,68,787 2,772,973.838 $.838 $ 257,286.27 $ 232,485.27 $ 26,383.78 $ 18,483.7 $ 1 1 23,92.5 $ 214,1.58 $.838 $.838 $ 257,286.27 $ 232,485.27 $ 26,383.78 $ 18,483.7 $ 152 113 499 612 K L M N Apr May Jun Jul Total 13.63 5.93 3.69 1.76 15.2 12.959% 5.637% 3.511% 1.674% 1.% 13.632 5.93 3.693 1.761 15.199 797 293 153 9 725 386 153 29 12.557 7.264 3.693 1.725 18.813 5. 5. 3.69 1.72 48.55 7.56 2.26 6.26 12.56 7.26 3.69 1.72 18.81 12. $ 12. $ 12. $ 12. 3.S371 $ 3.5371 $ 3.5371 $ 3.5371 2.513 $ 2.513 $ 2.513 $ 2.513 (.127) $ (.127) $ (.127) $ (.127) 6.1152 $ 6.1152 $ 6.1152 $ 6.11S2 12. $ 12. $ 12. $ 12. $ 144. 17.69 $ 17.69 $ 13.6 $ 6.1 $ 171.72 18.9 $ S.66 $ $ $ 15.74 (1.S2) $ (.88) $ (.4S) $ (.21} $ (13.13) 76.79 $ 44.42 $ 22.58 $ 1.S5 $ 665.41 123.86 $ 78.9 $ 47.2 $ 28.44 $ 1,118.74 12.94% 12.94o/o 12.94% 12.94% 16.3 $ 1.21 $ 6.11 $ 3.68 $ 144.82 1,389 1,741 11,48 11,423 166,566 $ 19,695 $ 67,55 $ 42,52 $ 1,56,71 1,762,587 1,6,99 489,928 238,815 15,444,749 314,888 187,72 94,621 28,749 2,5,676 11,353 4,251 2, S94 76,976 (5,851) (5,942) (4,1S5) (2,587) (51,9) 2,82,977 1,192,11 582,394 265,571 17,971,311.838 $.838 $.838 $.838 $.838 174,636.24 $ 99,946.17 $ 48,827.79 $ 22,265.38 $ 1,56,79.91 8,7.5 $ (9,748.41) $ (18,677.14) $ (19,786.18) $. 1 1 1 1 166,565.73 $ 19,694.S7 $ 67,54.94 $ 42,51.55 $ 1,S6, 79.91.838 $.838 $.838 $.838 174,636.24 $ 99,946.17 $ 48,827.79 $ 22,265.38 $ 1,56, 79.91 8,7.5 $ J9,748.41)_ $ _1_18,677.14)_ $ (19,786.1Bl $. (146) 352 37 375 466 818 1,125 1,5 p Q 15,444,749 2,5,676 76,976 ~~ L -- L_ - -- - - -- -- - ------------------------- -------- ----- - - ------ ~~ ~ tl> ~ -~ N"'C ~ "'C tl> ~ F:\RARA\Common\VA _DATA\PatariffNo.9\Supp _145\LIRA _Discount_8_1_13_table change.xls Rate_Calc