42 PGC Rate E-Factor Total Rate Currently effective Rate Increase (Decrease) in Rate 0.

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1 Line No. Exhibit 1-A Schedule 1 Sheet 1 of 2 COMPUTATION OF CHANGE IN RATE PURSUANT TO SECTION 1307(f) APPLICATION PERIOD: OCTOBER, 2016 THROUGH SEPTEMBER, 2017 Description Amount (1) 1 Purchased Gas Commodity Cost $ 2 Commodity Cost of Gas (Exhibit 1-B, Schedule 1) 88,167,627 3 Projected tariff sales for the twelve billing periods of 4 October, 2016 through September, ,208,343 Therms 5 PGCC prior to Off System Sales Credit (Line 2 / Line 4) Commodity (Over)/Under Collection 7 Commodity E-Factor 8 (Exhibit No. 1-E) 348,516 9 Projected sales for the twelve billing periods of 10 October, 2016 through September, ,862,619 Therms 11 Commodity E-Factor (Line 8/ Line 10) Purchased Gas Demand Cost 13 Demand cost of gas (Exhibit 1-B, Schedule 1) 63,350, Less: Purchased Gas Demand recovered under Rate SS 15 (Exhibit 1-A, Schedule 2, Sheet 2) 611, Less: Purchased Gas Demand Cost allocated to Rates LTS, STS, 17 SGS-TS and MLS (Exh 1-A, Sch 2, Sheet 3) 0 18 Subtotal (Line 13 - Line 15 - Line 17) 62,738, Projected sales for the twelve billing periods of 20 October, 2016 through September, _/ 472,136,847 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) 2,681, Projected sales for the twelve billing periods of 28 October, 2016 through September, _/ 472,136,847 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 ( ) 36 Net (Over) Under Collection 37 Commodity E-Factor (Line 11) 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 131,928,504 Therm Transportation Volumes 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, 2016 THROUGH SEPTEMBER, 2017 Line No. Description Detail Total (1) (2) $ 1 Total estimated demand charges for the period 2 October, 2016 through September, ,350,022 3 Estimated demand volumes (Therms) 1_/ 82,934,160 4 Daily purchased gas demand rate (Line 2 / line 3) $ per Therm 5 Daily purchased gas demand (Therms) 800,400 Therms 6 Daily purchased gas demand rate per Therm $ Total rate SS daily demand cost 8 recovered (Line 5 x Line 6) $ 611,394 1_/ Monthly Demand Billing Determinants x 12 82,934,160 Therms

3 Schedule 2 Sheet 1 of 4 SUMMARY OF PROJECTED SALES VOLUMES AND REVENUES FOR THE PERIOD SALES AT PGCC AND PGDC RATES OCTOBER, 2016 THROUGH SEPTEMBER, 2017 Sales Sales Purchased Line Subject PGCC PGCC Subject PGDC PGDC Gas Cost No. Month To PGCC Rate* Revenue To PGDC Rate * Revenue Revenue (1) (2) (3=1x2) (4) (5) (6=4x5) (7=3+6) Therms $/Therm $ Therms $/Therm $ $ 1 October ,818, ,285,431 12,982, ,725,135 4,010,566 2 November 22,687, ,879,800 32,159, ,273,334 10,153,134 3 December 46,356, ,013,665 63,935, ,495,698 20,509,363 4 January ,716, ,030,963 89,880, ,943,286 28,974,249 5 February 64,434, ,698,827 88,156, ,714,245 28,413,072 6 March 55,068, ,271,556 75,396, ,018,741 24,290,297 7 April 33,978, ,805,931 47,209, ,273,181 15,079,112 8 May 17,892, ,637,018 25,270, ,357,947 7,994,965 9 June 8,846, ,292,706 12,741, ,693,148 3,985, July 5,728, ,484,484 8,377, ,113,148 2,597, August 5,098, ,321,392 7,702, ,023,556 2,344, September 5,581, ,446,620 8,324, ,106,124 2,552, Total 340,208,343 88,168, ,136,847 62,737, ,905,937 *Note: Excludes refunds and experienced over/undercollections

4 Schedule 2 Sheet 2 of 4 SUMMARY OF PROJECTED SALES VOLUMES AND REVENUES FOR THE PERIOD SALES AT STANDBY RATE OCTOBER, 2016 THROUGH SEPTEMBER, 2017 Daily Purchased Daily Daily Line Gas Demand Gas Demand Purchased Gas No. Month Volumes Rate Demand Revenue (1) (2) (3=1x2) Therms $/Therm $ 1 October , ,949 2 November 66, ,949 3 December 66, ,949 4 January , ,949 5 February 66, ,949 6 March 66, ,949 7 April 66, ,949 8 May 66, ,949 9 June 66, , July 66, , August 66, , September 66, , Total 800, ,394

5 Schedule 2 Sheet 3 of 4 SUMMARY OF PROJECTED SALES VOLUMES AND REVENUES FOR THE PERIOD SALES AT BANKING AND BALANCING RATES OCTOBER, 2016 THROUGH SEPTEMBER, 2017 Large Volume Small Volume 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, 2016 THROUGH SEPTEMBER, 2017 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 ,285,431 3,635,685 (1,350,254) 1,776,085 6,006,300 (4,230,215) (5,580,469) 2 November 5,879,800 9,079,722 (3,199,922) 4,324,283 6,008,748 (1,684,465) (4,884,387) 3 December 12,013,665 15,699,338 (3,685,673) 8,546,648 6,058,038 2,488,610 (1,197,063) 4 January ,030,963 18,970,946 (1,939,983) 11,994,235 6,058,038 5,936,197 3,996,215 5 February 16,698,827 16,508, ,432 11,765,194 6,058,038 5,707,156 5,897,588 6 March 14,271,556 12,417,117 1,854,439 10,069,690 6,058,038 4,011,652 5,866,092 7 April 8,805,931 5,869,452 2,936,479 6,324,130 4,517,137 1,806,993 4,743,473 8 May 4,637,018 2,475,072 2,161,946 3,408,897 4,517,137 (1,108,240) 1,053,706 9 June 2,292, ,783 1,452,923 1,744,098 4,517,137 (2,773,039) (1,320,117) 10 July 1,484, , ,426 1,164,098 4,517,137 (3,353,039) (2,614,614) 11 August 1,321, , ,707 1,074,505 4,517,137 (3,442,632) (2,915,924) 12 September 1,446,620 1,131, ,246 1,157,074 4,517,137 (3,360,063) (3,044,818) 13 Total 88,168,393 88,167, ,348,938 63,350,022 (1,084) (318) 1_/ Refer to Exhibit 1-B, Schedule No. 1.

7 Columbia Gas of Pennsylvania, Inc. Capacity Assignment Factor Assignment of FT Only Exhibit 1-A 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, 2017 $63,350, Demand Costs per 1307(f) Filing (Exhibit 1-B, Schedule 1) (611,394) 1a. Less Purchased Gas Demand Costs Recovered Under Rate SS (Exhibit 1-A, Schedule 1, Sheet 2) 0 1b. Less Purchased Gas Demand Allocated to Rates LTS, STS, SGS-TS, and MLS (Exhibit 1-A, Schedule 2, Sheet 3) 2,681,285 1c. Experienced Demand Net Under/(Over) Collection (Exhibit No. 1-E) $65,419, Total Adjusted Demand Costs per 1307(f) Filing (1) + (1a) + (1b) + (1c) $ per Dth 3. Unit FT Demand Charge Per Mcf of Gulf/TCO capacity the marketer would pay Gulf and TCO. (Exhibit 1-A, Schedule 3, Sheet 2) 47,214 MMDth 4. Projected Sales & Choice Requirements for 12 billing periods of October, 2015 through September, ,544 MMDth 5. Projected Sales & Choice Requirements 12 months ended September 2016, including Unaccounted 0.7% 21,755 MMDth 6. Annual Injections and Withdrawals, Normal Weather 1 Dth 7a. Volume Delivered to the Customer 0.7% 7b. Unaccounted-for & Co. Use Factor Dth 7c. Volume Delivered to the City Gate. (7a)/(1-7b) $ per Dth 8. Unit Demand Charge: (2) / (4) ($0.1567) per Dth 9a. 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. Volume Injected and Withdrawn to Deliver 1 Dth to the Customer: (6) / (4) $ a. Injection $0.0153/Dth $ b. FSS 0.13 percent for gas at $2.6025/Dth $ c. Withdrawal $0.0153/Dth $ d. SST Commodity $0.0192/Dth $ e. SST 1.885% for gas at $2.6025/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) ($0.0472) 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 127,373 43,632 3 Projected Demand Costs 4. Annual Demand Cost 1/ $9,782,244 $2,247,060 4a. Monthly Billing Determinants 127,373 43,632 4b. Annual Demand Charge (4/ 4a) c. Monthly Demand Charge (4b / number of months) $6.400 $4.292 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 $76.80 $52.49 $ Notes: 1/ Projected demand costs for the period 12 months ended September, / Dth/day = / (1-retention) = / ( )

PURCHASED GAS ADJUSTMENT RIDER SCHEDULE

Page 22 GAS SERVICE Effective: October 27, 2005 Filed: August 25, 2005 Supersedes: PGA-2 filed 8/25/05 RIDER SCHEDULE PGA-3 Schedule Consists of: Three Sheets Plus PURCHASED GAS ADJUSTMENT RIDER SCHEDULE