(f) Annual Filing. Exhibit 1-A Schedule 1 Sheet 1 of 2

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1 COMPUTATION OF CHANGE IN RATE PURSUANT TO SECTION 1307(f) APPLICATION PERIOD: OCTOBER, 2017 THROUGH SEPTEMBER, 2018 Schedule 1 Sheet 1 of 2 Line No. Description Amount (1) 1 Purchased Gas Commodity Cost $ 2 Commodity Cost of Gas (Exhibit 1-B, Schedule 1) 109,323,648 3 Projected tariff sales for the twelve billing periods of 4 October, 2017 through September, ,885,537 Therms 5 PGCC (Line 2/Line 4) Commodity (Over)/Under Collection 7 Commodity E-Factor 8 (Exhibit No. 1-E) (622,505) 9 Projected sales for the twelve billing periods of 10 October, 2017 through September, ,885,537 Therms 11 Commodity E-Factor (Line 8/ Line 10) ( ) 12 Purchased Gas Demand Cost 13 Demand cost of gas (Exhibit 1-B, Schedule 1) 62,965, Less: Purchased Gas Demand recovered under Rate SS 15 (, Schedule 2, Sheet 2) 539, Less: Purchased Gas Demand Cost allocated to Rates LTS, STS, 17 SGS-TS and MLS (Exh 1-A, Sch 2, Page 3) 0 18 Subtotal (Line 13 - Line 15 - Line 17) 62,426, Projected sales for the twelve billing periods of 20 October, 2017 through September, _/ 465,221,593 Therms 21 PGDC Rate prior to Capacity Release Credit (Line 18 / Line 20) Off System Sales and Capacity Release Credit ( ) 23 PGDC Rate Demand (Over)/Under Collection 25 Demand E- Factor 26 (Exhibit No. 1-E) 1,592, Projected sales for the twelve billing periods of 28 October, 2017 through September, _/ 465,221,593 Therms 29 Demand E-Factor (Line 26 / Line 28) Total Purchased Gas Cost 31 PGCC Rate (Line 5) PGDC Rate (Line 23) PGC Rate Currently effective PGC Increase (Decrease) in PGC Net (Over) Under Collection 37 Commodity E-Factor (Line 11) ( ) 38 Demand E-Factor (Line 29) E-Factor Currently effective E-Factor ( ) 41 Increase (Decrease) in E-Factor PGC Rate E-Factor Total Rate Currently effective Rate Increase (Decrease) in Rate _/ Includes 129,336,056 Therm Transportation Quantities for the Company's Choice Program

2 Schedule 1 Sheet 2 of 2 PURCHASED GAS COST RECOVERED UNDER RATES SS AND COMPUTATION OF DAILY PURCHASED GAS DEMAND APPLICATION PERIOD: OCTOBER, 2017 THROUGH SEPTEMBER, 2018 Line No. Description Detail Total (1) (2) 1 Total estimated demand charges for the period 2 October, 2017 through September, ,965,433 3 Estimated Demand Quantity (Therms) 1_/ 82,334,160 4 Daily purchased gas demand rate (Line 2 / line 3) $ per Therm 5 Daily purchased gas demand (Therms) 705,360 Therms 6 Daily purchased gas demand rate per Therm $ Total rate SS Daily Demand Cost to be 8 Recovered (Line 5 x Line 6) $539,424 1_/ Monthly Demand Billing Determinants x 12

3 SUMMARY OF PROJECTED SALES QUANTITIES AND REVENUES FOR THE PERIOD SALES AT PGCC AND PGDC RATES OCTOBER, 2017 THROUGH SEPTEMBER, 2018 Schedule 2 Sheet 1 of 4 Sales Sales Purchased Line Subject PGCC PGCC Subject PGDC PGDC Gas Cost No. Month To PGCC Rate 1_/ Revenue To PGDC Rate 1_/ Revenue Revenue (1) (2) (3=1x2) (4) (5) (6=4x5) (7=3+6) Therms $/Therm $ Therms $/Therm $ $ 1 October ,143, ,650,573 12,230, ,641,155 4,291,728 2 November 21,886, ,123,504 31,062, ,168,290 11,291,794 3 December 45,063, ,667,122 62,235, ,351,323 23,018,445 4 January ,860, ,761,847 90,875, ,194,634 33,956,481 5 February 66,168, ,536,482 89,650, ,030,187 33,566,669 6 March 54,420, ,712,796 74,033, ,934,498 27,647,294 7 April 35,520, ,561,077 49,053, ,582,532 18,143,609 8 May 15,718, ,116,192 22,491, ,018,146 8,134,338 9 June 7,926, ,580,010 11,718, ,572,556 4,152, July 4,885, ,590,025 7,445, ,111 2,589, August 4,445, ,446,902 6,947, ,221 2,379, September 4,846, ,577,494 7,477, ,003,433 2,580, Total 335,885, ,324, ,221,593 62,428, ,752,110 1_/ Excludes refunds and experienced over/undercollections

4 Schedule 2 Sheet 2 of 4 SUMMARY OF PROJECTED SALES QUANTITIES AND REVENUES FOR THE PERIOD SALES AT STANDBY RATE OCTOBER, 2017 THROUGH SEPTEMBER, 2018 Daily Purchased Daily Daily Line Gas Demand Gas Demand Purchased Gas No. Month Quantity Rate Demand Revenue (1) (2) (3=1x2) Therms $/Therm $ 1 October , ,952 2 November 58, ,952 3 December 58, ,952 4 January , ,952 5 February 58, ,952 6 March 58, ,952 7 April 58, ,952 8 May 58, ,952 9 June 58, , July 58, , August 58, , September 58, , Total 705, ,424

5 Schedule 2 Sheet 3 of 4 SUMMARY OF PROJECTED SALES QUANTITIES AND REVENUES FOR THE PERIOD SALES AT BANKING AND BALANCING RATES OCTOBER, 2017 THROUGH SEPTEMBER, 2018 Lg. Quantity Sm. Quantity Total Line GDS GDS Trans. No. Month Deliveries Rate Revenue Deliveries Rate Revenue Revenue (1) (2) (3=1x2) (4) (5) (6=4x5) (7=3+6) Therms $/Therm $ Therms $/Therm $ $ 1 October November December January February March April May June July August September Total

6 Schedule 2 Sheet 4 of 4 SUMMARY OF PROJECTED TOTAL OVER/UNDERCOLLECTION FOR THE (f) PERIOD OCTOBER, 2017 THROUGH SEPTEMBER, 2018 Commodity Total Demand Total Line Recoveries Commodity Commodity Over/ Recoveries Demand Demand Over/ Total Over/ No. Month PGCC Revenue Cost of Gas 1_/ Undercollection PGDC Revenue Cost of Gas 1_/ Undercollection Undercollection (1) (2) (3=1-2) (4) (5) (6=4-5) (7=3+6) $ $ $ $ $ $ $ 1 October ,650,573 4,653,820 (2,003,247) 1,686,107 5,916,879 (4,230,772) (6,234,018) 2 November 7,123,504 11,167,759 (4,044,255) 4,213,242 5,984,974 (1,771,732) (5,815,987) 3 December 14,667,122 19,934,585 (5,267,463) 8,396,275 6,034,924 2,361,351 (2,906,111) 4 January ,761,847 24,426,013 (2,664,166) 12,239,586 6,034,924 6,204,662 3,540,496 5 February 21,536,482 21,009, ,458 12,075,139 6,034,924 6,040,215 6,567,673 6 March 17,712,796 15,690,919 2,021,878 9,979,450 6,034,924 3,944,526 5,966,404 7 April 11,561,077 6,469,089 5,091,989 6,627,484 4,487,314 2,140,170 7,232,159 8 May 5,116,192 2,582,104 2,534,088 3,063,098 4,487,314 (1,424,216) 1,109,872 9 June 2,580, ,507 1,617,503 1,617,508 4,487,314 (2,869,806) (1,252,303) 10 July 1,590, , ,753 1,044,063 4,487,314 (3,443,251) (2,713,498) 11 August 1,446, , , ,173 4,487,314 (3,510,141) (2,671,213) 12 September 1,577, , ,911 1,048,385 4,487,314 (3,438,929) (2,821,018) 13 Total 109,324, ,323, ,967,510 62,965,433 2,077 2,453 1_/ Refer to Exhibit 1-B, Schedule No. 1.

7 Columbia Gas of Pennsylvania, Inc. Capacity Assignment Factor Assignment of FT Only Schedule 3 Sheet 1 of 2 Purchased Gas Demand Charge (PGDC) Paid By the CHOICE Customer Rates Based on Projected Costs For 12 Months Ending September, 2018 $62,965, Projected Demand Costs Oct through Sept (Exh. 1-B, Sch. 1) (539,424) 1a. Less Purchased Gas Demand Costs Recovered Under Rate SS (, Schedule 1, Sheet 2) 0 1b. Less Purchased Gas Demand Allocated to Rates LTS, STS, SGS-TS, and MLS 1,592,168 1c. Experienced Demand Net Under/(Over) Collection (Exhibit No. 1-E) $64,018, Total Adjusted Demand Costs per 1307(f) Filing (1) + (1a) + (1b) + (1c) $ per Dth 3. Unit FT Demand Charge Per Dth of Gulf/TCO capacity the marketer would pay Gulf and TCO. (, Schedule 3, Sheet 2) 46,522 MMDth 4. Projected Sales & Choice Requirements for 12 billing periods of October, 2017 through September, ,039 MMDth 5. Projected Sales & Choice Requirements 12 months ended September 2018, including Unaccounted 1.1% 21,755 MMDth 6. Annual Injections and Withdrawals, Normal Weather 1 Dth 7a. Quantity Delivered to the Customer 1.1% 7b. Unaccounted-for & Co. Use Factor from Volume Balancing System Dth 7c. Quantity Delivered to the City Gate. (7a)/(1-7b) $ per Dth 8. Unit Demand Charge: (2) / (4) ($0.1852) per Dth 9. OSS and Capacity Release Credit Dth 10. Average Daily FT Delivery: (7c) / 365 days $ per Dth 11. Annual Demand Charge for the Assigned FT Capacity payable to the pipeline(s): (3) X (10) $ per Dth 12. Annual Demand Charge for other capacity that CPA retains (8) - (11) Dth 13. Quantity Injected and Withdrawn to Deliver 1 Dth to the Customer: (6) / (4) $ a. Injection $0.0153/Dth $ b. FSS 0.15 percent for gas at $3.0138/Dth $ c. Withdrawal $0.0153/Dth $ d. SST Commodity $0.0192/Dth $ e. SST 1.893% for gas at $3.0138/Dth $ per Dth 14f. Total Annual Variable Storage Costs 15. Credit to Purchased Gas Demand Charge for the CHOICE Customer: $ per Dth 15a. For Demand Cost Paid to Pipelines: = (11) ($0.0522) per Dth 15b. Less Storage Costs: = (14f) $ per Dth 15c. Net Credit: (15a) + (15b) $ per Therm 15d. Per Therm: (15c)/10 - Capacity Assignment Factor $ per Dth 16. Purchased Gas Demand Charge Paid By the CHOICE Customer: (8)+(9) - (15c) $ per Therm 17. Per Therm: (16)/10

8 Schedule 3 Sheet 2 of 2 Columbia Gas of Pennsylvania, Inc. (CPA) CPA Capacity Assignment (PCA): Assignment of FT Capacity Only CPA Capacity on TCO and Gulf. Cost of the Capacity Allocated to Marketers. TCO CGT Total: FT FTS-1 TCO and Capacity Capacity Gulf 1 CPA FT Capacity on TCO and Columbia Gulf 2 CPA Contract: Dth/d 122,373 43,632 3 Projected Demand Costs 4. Annual Demand Cost 1/ $9,439,368 $2,183,340 4a. Monthly Billing Determinants 122,373 43,632 4b. Annual Demand Charge (4/ 4a) $77.14 $ c. Monthly Demand Charge (4b / number of months) $6.428 $4.170 Transportation Pilot: Allocation Capacity and Costs. 5. Capacity Allocation: / 6. Number of Months Unit Annual Cost of City Gate Capacity: (4c) x (5) x (6) $/Dth $77.14 $51.01 $ Notes: 1/ Projected demand costs for the period 12 months ended September, / Dth/day = / (1-retention) = / ( )