PUBLIC UTILITY REGULATION STATE CORPORATION COMMISSION

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1 Gas Tariff Seventh Revised Volume No. 1 Twenty Ninth Revised Sheet No. 3 Superseding Twenty Eighth Sheet No. 3 Residential Sales Service (RS) & Metered Propane Service (MPS) 9/28/2017 TCRC 2/1/2016 CPA 12/30/2016 RNA RI [2] [3=4+2] [4] 151 [6] [7] [8] I91 [10=sum 3 to 9] 1/ 2/ 1/ 2/ All Gas Consumed / per Dth $6.191 $4.848 $ $0.057 ($0.012) ($0.250) $0.077 $0.000 $0.050 $0.016 $ $ Small General Service 1 (SGS-1) th All Gas Consumed / per Dth $5.401 $3.866 $9.267 $0.054 ($0.012) ($0326) $0.091 $0.000 $0.015 $0.201 $8.799 $9.616 Small General Service 2 (SGS-2) th All Gas Consumed / per Dth $5.401 $2.354 $7.755 $0.054 ($0.012) ($0326) $0.091 $0.000 $0.015 $0.074 $7.160 $7.977 Infrastructure Reliability JSz Replacement Adjustment Small General Service 3 (SGS-3) >626.6 Dth All Gas Consumed / per Dth $5.401 $2.161 $7562 $0.054 ($0.012) ($0.726) $0.091 $0000 $0.000 $0.000 $6.878 $7.695 Air Conditioning Service (ACS) All Volumes Above Load $ $ $ $0.036 ($0.012) $0.000 $0.000 $4.622 (Applicable RS or SGS ) (Applicable RS or SGS 1RRA) Unmetered Gas Light Service (UGLS) First Standard Burner Each Additional Burner $ $ ($0.025) (0,025) ($1.525) (1.525) $0.191 $0.191 $ $ $ $ $ With the exception of Column 2, the above rates are effective with meter readings on and after the stated dates. The above volumetric rates are reflected in Dekatherm ("Dth"). Therm ('Thin') rates can be derived by dividing the Dekatherm rates by 10. 1/ For customers that were ngt on Transportation Service in the last 12 months. ACCEPTED FOR FILING 2/ For customers that were on Transportation Service in the last 12 months. PUBLIC UTILITY REGULATION Per March 17, 2017 Final Order in Case No. PUE NOV

2 Gas Tariff Seventh Revised Volume No. 1 Residential Transportation Service (RTS) 9/28/2017 TCRC 2/1/2016 CPA 12/30/2016 Twenty Ninth Revised Sheet No. 3A Superseding Twenty Eighth Sheet No. 3A RNA [I.] 121 [3=1+2] [4] [5] [6] [71 [8] [9] [10=sum 3 to 9] I/ 2/ 1/ 2/ All Gas Consumed / per Dth $2.274 $4.848 $7.122 $0.007 ($0.012) $0.077 ($0.250) $0.000 $0.050 $0.016 $7.260 $6.933 Small General Transportation Service 1 (SGS-1) Dth All Gas Consumed / per Dth $2.274 $3.866 $ $0.007 ($0.012) $0.091 ($0.726) $0.000 $0.015 $0.201 $6.442 $5.625 Small General Transportation Service 2 (SGS-2) Dth All Gas Consumed / per Dth $2.274 $2.354 $4.628 $0.007 ($0.012) $0.091 ($0.726) $0.000 $0.015 $0.074 $4.803 $3.986 Small General Transportation Service 3 (SGS-3) >626.6 Dth All Gas Consumed / per Dth $2.274 $2.161 $4.435 $0.007 ($0.012) $0.091 ($0.726) $0.000 $0.000 $0.000 $4.521 $3.704 Air Conditioning Transportation Service (ACTS) All Volumes Above Load $2.274 $13686 $ $0.007 ($0.012) $0.000 $0.000 $3.638 Unmetered Gas Light Transportation Service (UGLTS) (Applicable RTS or SGTS ) (Applicable RS or SOS IRRA) I First Standard Burner Each Additional Bumer $ $ $ $ ($0.025) (0.025) $0.191 ($1.525) ($1.525) $ ,000 $ $ $ $ With the exception of Column 2, the above rates are effective with meter readings on and after the stated dates. The above volumetric rates are reflected in Dekatherm ("Dth"). Therm ("Thm") rates can be derived by dividing the Dekatherm rates by 10. 1/ For customers that were not on Sales Service in the last 12 months. ACCEPTED FOR FILING 2/ For customers that were on Sales Service in the last 12 months. PUBLIC UTILITY REGULATION Per March 17,2017 Final Order in Case No. PUE NOV

3 Gas Tariff Fifteenth Revised Sheet No. 4 Seventh Revised Volume No. 1 Superseding Fourteenth Sheet No. 4 9/28/2017 Large General Service CLGS-11 [1] [2] [3=1+2] [4] l51 [6] [7= ] Firm Option: Monthly Demand Charge $9.91 $0.00 $9.91 $0.00 $0.00 $0.00 $9.91 Firm Option: First 1,000 Dth $13686 $ $ ( ) Next 4,000 Dth (0.4790) Over 5,000 Dth (0.4790) Interruptible Option: First 1,000 Dth ( ) Next 4,000 Dth (0.3410) Over 5,000 Dth (03410) $ $ $ $ $ $ $ Standby Service (SS1) Monthly Demand Charge $9.91 $0.00 $9.91 $0.00 $0.00 $0.00 $9.91 Standby Option: 1/ First 1,000 Dth Next 4,000 Dth Over 5,000 Dth $03629 Transportation Service (TS1) First 1,000 Dth $ $ $ Next 4,000 Dth Over 5,000 Dth $ $ $ $ $ $ With the exception of Column 2, the above rates are effective with meter readings on and after the stated dates. 1/ The Standby Service gas cost commodity charge for Schedule TS-1 / TS-2 is the highest of (i) the Index price as published for the first of the month by PLATTS Inside FERC's Gas Market Report, under the heading "Market Center Spot Gas Prices" for Transco, Zone 6 non-ny or (ii) the Index price as published for the first of the month by PLATTS Inside FERC's Gas Market Report, under the heading "Market Center Spot Gas Prices" for Transco, Zone 5 delivered, pursuant to Tariff Sheet No. 122 in Case No. PUE Per March 17, 2017 Final Order in Case No. PUE ACCEPTED FOR FILING PU:LIC UTILITY REGULATION Nov

4 Gas Tariff Seventh Revised Volume No. 1 Fifteenth Revised Sheet No. 4A Superseding Fourteenth Sheet No. 4A 9/28/2017 Large General Service (LGS-2) [11 [2] [3=1+2] [4] [51 [6] [7= ] Firm Option: Monthly Demand Charge $9.91 $0.00 $9.91 $0.00 $0.00 $0.00 $9.91 Firm Option: First 20,000 0th $ $ $ ( ) $ Next 80,000 0th (0.4790) Over 100,000 0th (0.4790) Interruptible Option: First 20,000 0th $ $ $ ( ) Next 80,000 0th $ (0.3410) Over 100,000 0th $ (0.3410) $2, $2, $2, $ $ $ Standby Service (SS21 Monthly Demand Charge $9.91 $0.00 $9.91 $0.00 $0.00 $0.00 $9.91 Standby Option: 1/ First 20,000 Dth $ $ $04250 Next 80,000 0th Over 100,000 0th $ Transportation Service (TS2) First 20,000 0th $ Next 80,000 0th $ $ $ Over 100,000 0th $ $2, $2, $2, $ $ $ With the exception of Column 2, the above rates are effective with meter readings on and after the stated dates. 1/ The Standby Service gas cost commodity charge for Schedule TS-1 / TS-2 is the highest of (i) the Index price as published for the first of the month by PLATT'S Inside FERC's Gas Market Report, under the heading "Market Center Spot Gas Prices" for Transco, Zone 6 non-ny or (ii) the Index price as published for the first of the month by PLATTS Inside FERC's Gas Market Report, under the heading "Market Center Spot Gas Prices" for Transco, Zone 5 delivered, pursuant to Tariff Sheet No. 122 in Case No. PUE ACCEPTED FOR FILING PUBLIC UTILITY REGULATION NOV Per March 17, 2017 Final Order in Case No. PUE

5 Gas Tariff Eighth Revised Sheet No. 5 Seventh Revised Volume No. 1 Superseding Seventh Sheet No. 5 [1.] [2] [3=1+2] [4] [5] [61 [7= ] Banking and Balancing Service Transportation Service (TS1/TS2/LVTS/LVEDTS) Non-firm Tolerance Level: 5.0% $ $ $ % % % % % Firm Volumetric Tolerance Level: 5.0% $ % % % % % Demand $ $ ACCEPTED FOR FILING PUBLIC UTILITY REGULATION NOV

6 COLUMBIA GAS OF VIRGINIA, INC. SECOND REVISED SHEET NO. 445 GAS TARIFF SUPERSEDING SEVENTH REVISED VOLUME NO. 1 FIRST REVISED SHEET NO TERMS AND CONDITIONS 17.1 Adjustment GENERAL TERMS AND CONDITIONS ALL RATE SCHEDULES (continued) (a) Application The rates for all gas sales services and Schedules RTS, SGTS1, SGTS2, SGTS3, UGLTS, ACTS and BBS, other than Optional Alternate Fuel Displacement sales under Schedule LGS1/LGS2 and Schedule PDS, shall be increased or decreased by an amount hereinafter described as the Purchased Gas Adjustment Factor (). (b) Definition of "Purchased Gas" The term "purchased gas" as used in determination of the shall include, but not be limited to, the following sources of gas, including related transportation, storage, handling costs required for delivery to the Company's facilities, and all costs associated with the purchase and sales of gas price hedging futures contracts applicable to: 30% of the Company's forecasted non-storage normal winter demand (December through February), commencing with the Winter Season and continuing through the Winter Season, of its Customers that pay the /, as determined at the outset of each hedging purchase period, pursuant to the Company's Gas Price Hedging Plan: (i) (ii) (iii) (iv) Natural and substitute natural gas (SNG) and liquefied natural gas (LNG) from pipeline and other suppliers including exchange gas; LNG from other than pipeline sources; Liquefied petroleum gas (LPG); and Other hydrocarbons used as feedstock for production of SNG and spot or emergency purchases Computation of Firm The, calculated to the nearest $0.001 per Dth, shall be computed each quarter for firm sales Customers under Schedules RS, SGS1, SGS2, SGS3, UGLS and MPS and to the nearest $ per Dth for firm customers under Schedule LGS1/LGS2 in the following manner: (a) Cost Firm Schedules The base cost of purchased gas applicable to each of the Company's firm sales rate schedules is as follows: Schedule Demand (per Dth) Commodity (per Dth) Total Cost Of Gas (per Dth) RS, MPS $ $ $ SGS1/SGS2/SGS3, UGLS $ $ $ LGS1/LGS2 $ $ $ SS1/SS2 $ $ $ Effective Date: November 29, 2017

7 COLUMBIA GAS OF VIRGINIA, INC. FOURTH REVISED SHEET NO. 446 GAS TARIFF SUPERSEDING SEVENTH REVISED VOLUME NO. 1 THIRD REVISED SHEET NO. 446 GENERAL TERMS AND CONDITIONS ALL RATE SCHEDULES (continued) (b) Cost - Combined Firm Sales Schedules The base cost of purchased gas applicable to the combined total sales for the firm sales rate schedules in 17.2(a) of this section is $ per Dth. This is the sum of the demand cost of $ and the commodity cost of $ The base cost of purchased gas for RTS, SGTS1, SGTS2, SGTS3, UGLTS and ACTS is $ (c) Calculation of Firm Sales The for all firm sales rate schedules shall be determined as follows: (i) (ii) (iii) (iv) (v) For estimated quantities purchased as specified in Section 17.1(b)(I), the annual billing demands and the quarterly commodity purchases for firm sales rate schedules will be priced at the estimated wholesale rates of the Company's suppliers. For the purposes of calculating the firm, Gas Inventory Charges (GIC's) and other similar charges from the Company's pipeline suppliers will be considered as a demand cost of gas. For purposes of the interruptible s, such charges will be considered as a commodity cost of gas. The estimated quantities of all other types of gas or hydrocarbons purchased as specified in Section 17.1 (b)(ii), (iii), and (iv), for firm sales rates schedules during the billing quarter will be priced at the respective prices at which such quantities were charged to expense accounts on the Company's books. These purchases will be included with the commodity charges in Section 17.2(c)(i). The sum of commodity amounts determined in Section 17.2(c)(i) and (ii), carrying costs on gas storage balances, and applicable billing adjustments, will be divided by the projected firm Dth sales, less any sales related to applicable billing adjustments, for the billing quarter to determine the quarterly commodity cost per Dth. Carrying costs on gas storage balances for the Firm -Sales will be based on allocated average storage balances for the billing quarter multiplied by the overall rate of return, as determined in its most recent rate case, including the authorized return on common equity, plus an allowance for income taxes. The sum of demand amounts determined in Section 17.2(c)(i) and (ii), and applicable billing adjustments, less any demand costs directly assigned to rate schedules or Customers, other than those directly assigned the Choice Program, will be divided by the projected firm Dth sales, including quantities transported under rate schedules RTS, SGTS1, SGTS2, SGTS3, UGLTS and ACTS, less any sales related to applicable billing adjustments, for the billing quarter to determine the quarterly demand cost per Dth. The sum of amounts determined in Section 17.2(c)(iii) and (iv) for separately computed demand and commodity amounts will be the current cost per Dth of gas purchased for sales under applicable schedules (Current Cost). Effective Date: November 29, 2017

8 COLUMBIA GAS OF VIRGINIA, INC. SECOND REVISED SHEET NO. 447 GAS TARIFF SUPERSEDING SEVENTH REVISED VOLUME NO. 1 FIRST REVISED SHEET NO. 447 GENERAL TERMS AND CONDITIONS ALL RATE SCHEDULES (continued) (vi) (vii) The Current Cost determined in Section 17.2(c)(v) will be adjusted to provide for the recovery of uncollectible accounts expense by multiplying the Current Cost times one plus the uncollectible accrual rate used to establish base nongas rates in the Company's most recent rate proceeding. The shall be the difference between the base cost set forth in Section 17.2(b) and the current cost determined in Section 17.2(c)(vi). z 0 (d) Calculation of Firm Choice Program 6 c, The for rate schedules RTS, SGTS1, SGTS2, SGTS3, UGLTS and ACTS shall be determined as follows: I.L.. =1 m 0 0 r.-- 0:: ill z cog C.) ce 0 (i) The unit demand cost of firm capacity, as calculated in Section 17.2c(iv), minus c J (ii) The weighted average unit demand cost of capacity offered for assignment in the B 1: 5 g >0 Choice Program, plus CL M CL. i=10 LLI 0 C.) Et = ci :3 0 (iii) Variable storage costs, minus < m ul a. ti (iv) The base cost set forth in Section 17.2(b). 1-- co (e) Annual Roll-In Effective with the December billing month of each year, the base cost of gas shall be revised to reflect the cost of purchased gas as determined in Sections 17.2(c)(v), excluding carrying costs on gas storage balances, and 17.2(d) for the 12 months ended August of that year, which base cost of gas shall be effective through the November billing month of the following year. Concurrently, the rates for monthly consumption set forth in all firm sales rate schedules as well as transportation rate schedules RTS, SGTS1, SGTS2, SGTS3, UGLTS and ACTS shall be revised to reflect an appropriately revised base cost Computation of Interruptible (a) Cost - Interruptible Schedules The base cost of purchased gas applicable to the combined total commodity sales for the interruptible sales rate schedules is $ per Dth. (b) Calculation of Interruptible The for all interruptible sales rate schedules shall be determined as follows: (I) For estimated quantities purchased as specified in Section 17.1(b)(i), the quarterly commodity purchases for interruptible sales rate schedules will be priced at the estimated wholesale rates of the Company's suppliers. Effective Date: November 29, 2017