NEXUS GAS TRANSMISSION, LLC

NEXUS GAS TRANSMISSION, LLC 5400 Westheimer Court Houston, TX 77056

February 26, 2021

Ms. Kimberly D. Bose, Secretary Federal Energy Regulatory Commission 888 First Street, NE Washington, D.C. 20426 Re: NEXUS Gas Transmission, LLC 2021 ASA Filing Docket No. RP21-_____-000 Dear Ms. Bose:

In accordance with Section 21.2 of the General Terms and Conditions (“GT&C”) of its FERC NGA Gas Tariff, Original Volume No. 1 (“Tariff”), NEXUS Gas Transmission, LLC (“NEXUS”) submits herewith for filing with the Federal Energy Regulatory Commission (“FERC” or “Commission”) its Applicable Shrinkage Adjustment (“ASA”) annual filing. The ASA annual filing includes revisions to the ASA Percentages as shown on the following Tariff record proposed to be effective on April 1, 2021:

• Version 2.0.0 of Section 4, Percentages for Applicable Shrinkage, of Part 5, Rate

Schedules.

As further described below, NEXUS submits this filing to redetermine the Applicable Shrinkage Percentages (“ASA Percentages”) to be in effect for the twelve (12)-month period beginning on April 1, 2021, and to establish the Applicable Shrinkage Deferred Account (“ASA Deferred Account”) refund or surcharge pursuant to GT&C Section 21.2, as appropriate, for the actual period, twelve (12) months ending December 31, 2020. The net balance of the ASA Deferred Account is a credit, resulting in a refund to NEXUS’ shippers. Pursuant to GT&C Section 21.2, this refund shall be due to NEXUS’ shippers within sixty (60) days after the Commission’s acceptance of this filing.

STATEMENT OF NATURE, REASONS AND BASIS

Pursuant to GT&C Section 21.2(C) of the its Tariff, NEXUS is required to re-calculate the ASA Percentages, to be effective on the first April 1 after one complete year of operation and each April thereafter, by dividing NEXUS’ projection of fuel and Company Use Gas and any lost and unaccounted for Gas for NEXUS’ facilities for the next twelve (12) months beginning on April 1,

Ms. Kimberly D. Bose, Secretary February 26, 2021 by NEXUS’ projection of applicable deliveries for the account of NEXUS customers taking service under the ASA Rate Schedules1 for the next twelve (12) months beginning on April 1.

The projected ASA Percentage for Market Fuel Area 1 (Greenfield) for the upcoming

twelve (12)-month period beginning April 1, 2021, as calculated in Appendix A hereto, is 1.02%, which reflects a decrease of 0.24% from the currently effective ASA Percentage for Market Fuel Area 1 (Greenfield). The projected ASA Percentages for all of the paths that include Market Fuel Area 1 (Greenfield) for the upcoming twelve (12)-month period beginning April 1, 2021, similarly reflect a decrease from the currently effective respective ASA Percentages. The projected ASA Percentages for these paths are inclusive of fuel on fuel calculations caused by the underlying lease contracts/agreements. There is no change beginning April 1, 2021, to the underlying DTE and Vector lease contracts/agreements ASA Percentages. There is a change to the underlying TEAL lease contracts/agreement ASA Percentages, which is adjusted to 1.06%, up from 0.6%, for movements within the Supply Fuel Area, with related revisions to the ASA Percentages for the other Supply Fuel Area transportation paths.2 In addition, pursuant to GT&C Section 21.2(E), NEXUS maintains an ASA Deferred Account to determine the ASA balance, which includes the net monetary value of (i) all transactions involving Gas differences as a result of the operation in accordance with GT&C Section 21, (ii) the imbalance resolution procedures in accordance with GT&C Section 19, and Sections 7.5, 7.6, and 8.1 of Rate Schedule PAL, (iii) carrying charges calculated pursuant to GT&C Section 21.2(E)(2), and (iv) any other requirements for the purchase or sale of gas due to unanticipated events which threaten the operational integrity of NEXUS’ system. Pursuant to GT&C Section 21.2(E)(1), the ASA Deferred Account is required to be accumulated in twelve (12)-month accumulation periods (January 1 through December 31).

For the instant filing, the actual balance in the ASA Deferred Account is a net credit balance

of $3,603,671.32 (“ASA Refund”). Pursuant to GT&C Section 21.2(E)(3), this ASA Refund will be paid within sixty (60) days after the Commission’s acceptance of this filing. Appendix B attached hereto provides an allocation of the ASA Refund to the shippers based upon each shipper’s actual throughput during the accumulation period, exclusive of Backhauls. Appendix C attached hereto provides workpapers supporting the ASA Deferred Account balance.

1 The ASA Rate Schedules consist of Rate Schedules FT-1, LFT-1, and IT-1. 2 See Texas Eastern Transmission, LP Annual ASA and Revenue Reconciliation Report Filing Effective December 1, 2020, Attachment XVI, Schedule A (Calculation of Texas Eastern Appalachian Lease Project Total Fuel for the Period, Including LAUF)(Docket RP21-170-000) (filed Oct. 30, 2020).

Ms. Kimberly D. Bose, Secretary February 26, 2021 PROPOSED EFFECTIVE DATE The proposed effective date of the Tariff record filed herewith is April 1, 2021. NEXUS respectfully requests that the Commission grant any waivers that may be required for the Commission to accept the Tariff record filed herein to become effective on April 1, 2021. IMPLEMENTATION Pursuant to Section 154.7(a)(9) of the Commission’s regulations, 18 C.F.R. § 154.7(a)(9), NEXUS files this motion to place the revised Tariff record into effect at the expiration of any suspension period set by the Commission, provided that the Tariff record is approved as filed and without condition. In the event that the Tariff record filed herewith is not approved as filed and without condition, NEXUS reserves the right to file a later motion to place such Tariff record into effect. COMPLIANCE WITH REGULATIONS In compliance with Section 154.4(c) of the Commission’s regulations, 18 C.F.R. § 154.4(c), all contents of this filing are being submitted as part of an XML filing package in conformance with the Secretary of the Commission’s instructions.

In compliance with Section 154.201(a) of the Commission’s regulations, 18 C.F.R. § 154.201(a), a marked version of the proposed Tariff record with changes showing additions to and deletions from the currently effective Tariff is attached. SERVICE AND POSTING Copies of this filing are being posted in accordance with Section 154.207 of the Commission’s regulations, 18 C.F.R. § 154.207. In accordance with Section 154.208 of the Commission’s regulations, 18 C.F.R. § 154.208, copies of this filing are being served electronically to NEXUS’ customers and interested state commissions. A paper copy of this filing may only be served if a customer or state commission has been granted a waiver of electronic service pursuant to Section 390 of the Commission’s regulations, 18 C.F.R. § 390. CORRESPONDENCE AND COMMUNICATION

All correspondence and communications regarding this filing should be addressed to the following:

Ms. Kimberly D. Bose, Secretary February 26, 2021

* Berk Donaldson, Director, Rates & CertificatesBrian Kim, Manager, Rates & CertificatesNEXUS Gas Transmission, LLCP. O. Box 1642Houston, TX 77251-1642Phone: (713) 627-4488Email: [email protected]: [email protected]

and

* Grace O’MalleySenior CounselNEXUS Gas Transmission, LLCP. O. Box 1642Houston, TX 77251-1642Phone: (713) 627-5233Email: [email protected]

and

* D. Kirk Morgan II*George D. Fatula

Bracewell LLP2001 M Street NW, Suite 900Washington, DC 20036Phone: (202) 828-5854Email: [email protected]: [email protected]

*Parties to be designated on the Commission’s Official Service List.

mailto:[email protected]




Ms. Kimberly D. Bose, Secretary February 26, 2021

Should you have any questions regarding this filing, please contact Brian Kim, Manager, Rates and Certificates, at (713) 627-4059, or the undersigned at (713) 627-4488.

Sincerely,

NEXUS Gas Transmission, LLC By: Spectra Energy NEXUS Management, LLC, in its capacity as operator

/s/ Berk Donaldson Berk Donaldson Director, Rates & Certificates

Enclosures

TARIFF RECORD (CLEAN)

NEXUS Gas Transmission, LLC Part 5 - Rate Schedules

FERC Gas Tariff 4. Percentages for Applicable Shrinkage

Original Volume No. 1 Version 2.0.0

Page 1 of 1

Issued on: February 26, 2021

Effective on: April 1, 2021

Currently Effective Percentages

For Applicable Shrinkage

For ASA Rate Schedules

Rate Schedules FT-1, LFT-1 and IT-1: *

To Fuel Area

Supply Market 1 Market 2 Market 3

(TEAL) (Greenfield) (DTE) (Vector)

(%) (%) (%) (%)

From Supply Fuel Area (TEAL) 1.0600 2.0692 3.0485 3.4363

From Market Fuel Area 1 (Greenfield) n/a 1.0200 2.0098 2.4018

From Market Fuel Area 2 (DTE) n/a n/a 1.0000 1.3960

From Market Fuel Area 3 (Vector) n/a n/a 1.3960 0.4000

* The rates are inclusive of fuel on fuel calculations caused by underlying lease

contracts/agreements.

Rate Schedules TABS and PAL:

To Fuel Area

Supply Market 1 Market 2 Market 3

(TEAL) (Greenfield) (DTE) (Vector)

(%) (%) (%) (%)

From Supply Fuel Area (TEAL) n/a n/a n/a n/a

From Market Fuel Area 1 (Greenfield) n/a 0.0000 n/a n/a

From Market Fuel Area 2 (DTE) n/a n/a n/a n/a

From Market Fuel Area 3 (Vector) n/a n/a n/a n/a

TARIFF RECORD (REDLINE)

4. Percentages for Applicable Shrinkage Version 1.0.0 2.0.0 Page 1 of 1

Issued on: February 26, 2021 Effective on: April 1, 2021

Currently Effective Percentages For Applicable Shrinkage For ASA Rate Schedules

Rate Schedules FT-1, LFT-1 and IT-1: *

To Fuel Area Supply Market 1 Market 2 Market 3 (TEAL) (Greenfield) (DTE) (Vector)

(%) (%) (%) (%)

From Supply Fuel Area (TEAL) 1.0600 2.0692 3.0485 3.4363 0.6000 1.8524 2.8339 3.2226 From Market Fuel Area 1 (Greenfield) n/a 1.0200 2.0098 2.4018 1.2600 2.2474 2.6384 From Market Fuel Area 2 (DTE) n/a n/a 1.0000 1.3960 From Market Fuel Area 3 (Vector) n/a n/a 1.3960 0.4000

* The rates are inclusive of fuel on fuel calculations caused by underlying lease contracts/agreements.

Rate Schedules TABS and PAL:

To Fuel Area Supply Market 1 Market 2 Market 3 (TEAL) (Greenfield) (DTE) (Vector)

(%) (%) (%) (%)

From Supply Fuel Area (TEAL) n/a n/a n/a n/a From Market Fuel Area 1 (Greenfield) n/a 0.0000 n/a n/a From Market Fuel Area 2 (DTE) n/a n/a n/a n/a From Market Fuel Area 3 (Vector) n/a n/a n/a n/a

APPENDIX A

Appendix A

Page 1 of 1

COMPRESSOR, LOST AND TOTAL

LINE PROJECTED M&R, PLANT & UNACCOUNTED FUEL

NO. MONTH THROUGHPUT OTHER FUEL, ETC. FOR GAS REQUIREMENT

1 April, 2021 35,509,185 351,635 13,706 365,341

2 May 36,692,825 363,357 14,163 377,519

3 June 35,509,185 351,635 13,706 365,341

4 July 36,692,825 363,357 14,163 377,519

5 August 36,692,825 363,357 14,163 377,519

6 September 35,509,185 351,635 13,706 365,341

7 October 36,692,825 363,357 14,163 377,519

8 November 35,509,185 351,635 13,706 365,341

9 December 36,692,825 363,357 14,163 377,519

10 January, 2022 36,692,825 363,357 14,163 377,519

11 February 33,141,906 328,193 12,792 340,985

12 March 36,692,825 363,357 14,163 377,519

13 TOTAL 432,028,418 4,278,230 166,757 4,444,987

14 ASA Percentage (Greenfield) = Projected Fuel and LAUF / ( Projected Throughput + Projected Fuel and LAUF )

15 = 4,444,987 / (432,028,418 + 4,444,987)

16 = 1.02%

17 Leased Capacity Fuel Rates for 2020

18 DTE Gas Lease Fuel Rate 1.00%

19 Vector U.S. Lease Fuel Rate 0.40%

20 Texas Eastern Lease Fuel Rate 1.06%

PROJECTED FUEL REQUIREMENT

NEXUS GAS TRANSMISSION, LLC

DERIVATION OF ASA PERCENTAGES

TO BE EFFECTIVE APRIL 1, 2021

(ALL QUANTITIES IN DTH)

APPENDIX B

Appendix B

1 of 3

ASA BALANCE

QUANTITY DEFERRAL

TOTAL CUSTOMER REFUND / (CHARGE)

LINE VOLUME % OF TOTAL (in dollars)

NO. CUSTOMER (A) 1/, 2/ (B) (C) 3/

1 AEP ENERGY, 591,916 0.134213% 4,836.61

2 AGERA ENERG - 0.000000% -

3 ARCHER ENER 8,164 0.001851% 66.71

4 ARM ENERGY - 0.000000% -

5 BOLT ENERGY 24 0.000005% 0.20

6 BP CAN EN MK 6,416,146 1.454822% 52,427.02

7 BP ENERGY 26,302,645 5.963966% 214,921.74

8 CASTLETON C 5,249,904 1.190384% 42,897.53

9 CNX GAS LLC - 0.000000% -

10 CONOCOPHILPS 15,110,923 3.426311% 123,472.97

11 CONSTELL GAS - 0.000000% -

12 DIRECT EN MK 9,192,369 2.084314% 75,111.83

13 DTE ENERGY 133,379,346 30.242962% 1,089,856.96

14 DTE GAS COM 22,217,097 5.037593% 181,538.29

15 DYNEGY MKLLC 10,699 0.002426% 87.42

16 EAP OHIO 19,322,304 4.381216% 157,884.62

17 ECO-ENERGY - 0.000000% -

18 ECO-ENERGY N 9,273,490 2.102708% 75,774.68

19 ELEVATION E - 0.000000% -

20 ENB GAS INC 17,006,328 3.856082% 138,960.53

21 ENBRIDG GAS 56,087,049 12.717400% 458,293.30

22 ENER PLUS 5,522 0.001252% 45.12

23 EQT ENERGY - 0.000000% -

24 EQUINOR NAT 20,892,452 4.737238% 170,714.47

25 EVERYDAY EN - 0.000000% -

26 EXELON GENER 1,200,332 0.272168% 9,808.04

27 FOSTER EN 7,705 0.001747% 62.96

28 FREEPOINT C 4,279,726 0.970402% 34,970.10

29 GULFPORT EN 620,000 0.140581% 5,066.09

30 IR GAS SUPP 1,740,678 0.394688% 14,223.27

31 J ARON & CO 330,804 0.075008% 2,703.04

32 JUST ENERG S - 0.000000% -

33 MERCURIA CO 3,890,474 0.882142% 31,789.48

34 MERCURIA LLC 15,143,640 3.433729% 123,740.31

35 MRGN STNLY C - 0.000000% -

36 NATIONAL GAS 5 0.000001% 0.04

37 NEXTERA ENER 1,860,211 0.421792% 15,199.98

38 NJR ENER SVC 13,595,403 3.082676% 111,089.50

39 REPSOL ENER - 0.000000% -

ALLOCATION OF APPLICABLE SHRINKAGE DEFERRED ACCOUNT BALANCE

FOR PERIOD ENDED DECEMBER 31, 2020


Appendix B

2 of 3

ASA BALANCE

QUANTITY DEFERRAL

TOTAL CUSTOMER REFUND / (CHARGE)

LINE VOLUME % OF TOTAL (in dollars)

NO. CUSTOMER (A) 1/, 2/ (B) (C) 3/

ALLOCATION OF APPLICABLE SHRINKAGE DEFERRED ACCOUNT BALANCE

FOR PERIOD ENDED DECEMBER 31, 2020


40 SANTANNA NAT 239,648 0.054339% 1,958.19

41 SEQ ENER MGM - 0.000000% -

42 SFE OHIO 17,772 0.004030% 145.22

43 SNYDER BRO - 0.000000% -

44 SOSTAR ENER 127,179 0.028837% 1,039.19

45 SPARK ENERG 169 0.000038% 1.38

46 SPIRE MARKE 4,390,649 0.995553% 35,876.46

47 STATEWISE E 14,551 0.003299% 118.90

48 TENASKA MKTG 13,174,557 2.987251% 107,650.72

49 TIDAL ENERG 19,999 0.004535% 163.41

50 TOMORROW EN 3,160 0.000717% 25.82

51 TWIN EAGLE 22,568,383 5.117245% 184,408.68

52 U.S. GAS - 0.000000% -

53 UNITED EN TR 54,920 0.012453% 448.76

54 VOLUNTEER E 1,336,745 0.303099% 10,922.69

55 XTO ENERGY 8,178,894 1.854515% 66,830.62

56 SPOTLIGHT E 744,000 0.168698% 6,079.30

57 VITOL INC. 3,065,080 0.694988% 25,045.10

58 CITADEL ENE 2,745,000 0.622412% 22,429.69

59 GUNVOR USA 610,000 0.138314% 4,984.38

60 TOTALS 441,026,062 100.0000% 3,603,671.32

1/ See Appendix B, Page 3

2/ Volumes exclusive of backhaul

3/ See Appendix C, Schedule No. 1

Appendix B

3 of 3

Jan-20 Feb-20 Mar-20 Apr-20 May-20 Jun-20 Jul-20 Aug-20 Sep-20 Oct-20 Nov-20 Dec-20

LINE CUSTOMER FT-1, LFT-1, & IT-1 FT-1, LFT-1, & IT-1 FT-1, LFT-1, & IT-1 FT-1, LFT-1, & IT-1 FT-1, LFT-1, & IT-1 FT-1, LFT-1, & IT-1 FT-1, LFT-1, & IT-1 FT-1, LFT-1, & IT-1 FT-1, LFT-1, & IT-1 FT-1, LFT-1, & IT-1 FT-1, LFT-1, & IT-1 FT-1, LFT-1, & IT-1 TOTAL

NO. DTH DTH DTH DTH DTH DTH DTH DTH DTH DTH DTH DTH DTH

1 AEP ENERGY, 71,145 2,295 - 70,680 73,036 - 73,219 76,074 71,859 - 74,775 78,833 591,916

2 AGERA ENERG - - - - - - - - - - - - -

3 ARCHER ENER 1,519 1,421 465 - - - - - - 1,470 1,770 1,519 8,164

4 ARM ENERGY - - - - - - - - - - - - -

5 BOLT ENERGY 24 - - - - - - - - - - - 24

6 BP CAN EN MK 1,239,100 1,009,686 1,240,000 - - - - - - - 1,496,929 1,430,431 6,416,146

7 BP ENERGY 1,650,655 745,700 2,784,155 2,937,327 3,078,887 2,999,787 2,950,393 3,120,000 2,906,119 3,129,622 - - 26,302,645

8 CASTLETON C 1,740,089 1,624,819 1,884,996 - - - - - - - - - 5,249,904

9 CNX GAS LLC - - - - - - - - - - - - -

10 CONOCOPHILPS 1,560,148 1,449,177 1,550,000 1,492,794 1,544,337 1,497,561 1,501,834 1,549,801 1,416,469 1,548,802 - - 15,110,923

11 CONSTELL GAS - - - - - - - - - - - - -

12 DIRECT EN MK 1,124,476 1,239,779 1,325,963 243,960 145,134 241,920 125,530 714,192 233,341 251,627 1,745,254 1,801,193 9,192,369

13 DTE ENERGY 11,699,914 10,065,450 10,805,476 11,670,348 12,629,915 11,341,616 10,855,422 11,551,575 9,879,721 11,666,188 10,829,346 10,384,375 133,379,346

14 DTE GAS COM 2,324,008 365,516 543,089 3,353,190 1,774,471 2,248,930 2,256,211 2,324,535 2,111,645 2,322,396 1,124,760 1,468,346 22,217,097

15 DYNEGY MKLLC 7,614 545 - 2,540 - - - - - - - - 10,699

16 EAP OHIO 520,000 10,000 20,000 2,426,449 1,530,132 1,667,731 2,622,597 1,064,525 2,015,133 3,098,268 2,960,105 1,387,364 19,322,304

17 ECO-ENERGY - - - - - - - - - - - - -

18 ECO-ENERGY N 165,000 677,000 589,000 731,397 1,145,995 790,784 966,926 775,000 615,872 773,682 1,169,451 873,383 9,273,490

19 ELEVATION E - - - - - - - - - - - - -

20 ENB GAS INC 1,704,907 1,594,913 903,092 670,450 899,915 1,650,000 1,624,773 1,705,000 1,604,365 1,704,938 1,447,388 1,496,587 17,006,328

21 ENBRIDG GAS 4,649,996 4,350,000 4,650,000 4,500,000 4,647,773 4,500,000 4,476,580 4,649,870 4,337,919 4,649,969 5,249,970 5,424,972 56,087,049

22 ENER PLUS - 590 - 3,112 - - - - - - - 1,820 5,522

23 EQT ENERGY - - - - - - - - - - - - -

24 EQUINOR NAT 3,712,476 4,204,836 2,944,100 449,517 457,165 1,050,000 1,008,309 1,085,000 949,570 1,084,941 1,948,190 1,998,348 20,892,452

25 EVERYDAY EN - - - - - - - - - - - - -

26 EXELON GENER 5,974 63 - 78,949 189,844 12,209 176,017 190,464 180,053 - 184,200 182,559 1,200,332

27 FOSTER EN 2,505 2,378 - 573 - - - - - - - 2,249 7,705

28 FREEPOINT C 775,000 725,000 665,000 - 597,530 - - - - - 742,196 775,000 4,279,726

29 GULFPORT EN 620,000 - - - - - - - - - - - 620,000

30 IR GAS SUPP 185,907 173,420 185,070 133,830 137,051 131,820 131,836 135,780 127,337 132,456 130,980 135,191 1,740,678

31 J ARON & CO - - - - 325,959 4,845 - - - - - - 330,804

32 JUST ENERG S - - - - - - - - - - - - -

33 MERCURIA CO 619,957 580,000 620,000 194,505 572,888 600,000 280,000 180,000 - 243,124 - - 3,890,474

34 MERCURIA LLC - 594,500 620,000 1,697,717 1,545,179 1,494,999 1,501,982 1,550,000 1,452,083 1,649,242 1,488,370 1,549,568 15,143,640

35 MRGN STNLY C - - - - - - - - - - - - -

36 NATIONAL GAS - 5 - - - - - - - - - - 5

37 NEXTERA ENER 301,227 282,315 301,041 117,773 127,691 120,720 112,672 127,751 120,617 - 123,660 124,744 1,860,211

38 NJR ENER SVC 2,325,000 2,119,414 2,325,000 750,000 775,000 750,000 745,840 775,000 730,149 775,000 750,000 775,000 13,595,403

39 REPSOL ENER - - - - - - - - - - - - -

40 SANTANNA NAT 23,032 22,185 20,016 21,790 24,335 14,730 17,015 16,771 15,525 19,395 21,108 23,746 239,648

41 SEQ ENER MGM - - - - - - - - - - - - -

42 SFE OHIO 3,596 3,422 3,050 630 - - - - - - 3,302 3,772 17,772

43 SNYDER BRO - - - - - - - - - - - - -

44 SOSTAR ENER 13,671 13,079 14,260 12,960 13,392 12,660 12,315 12,183 11,409 - 11,250 - 127,179

45 SPARK ENERG - 26 - 143 - - - - - - - - 169

46 SPIRE MARKE 132,112 126,156 75,634 449,195 451,036 449,999 449,099 465,000 422,981 464,508 440,030 464,899 4,390,649

47 STATEWISE E 3,379 3,132 2,700 528 - - - - - - 2,244 2,568 14,551

48 TENASKA MKTG 1,080,603 1,274,996 885,000 1,009,373 1,549,866 1,500,110 1,484,367 1,520,078 995,224 1,025,000 444,940 405,000 13,174,557

49 TIDAL ENERG - - - - 19,999 - - - - - - - 19,999

50 TOMORROW EN 1,101 1,015 - 238 - - - - - - - 806 3,160

51 TWIN EAGLE 809,823 729,985 782,533 2,352,828 2,485,059 2,407,318 2,400,809 2,485,310 2,342,048 2,487,736 1,425,089 1,859,845 22,568,383

52 U.S. GAS - - - - - - - - - - - - -

53 UNITED EN TR - - - - - - - - 393 16,852 34,251 3,424 54,920

54 VOLUNTEER E 182,435 170,665 182,435 - - 94,230 94,222 118,668 143,497 - 168,034 182,559 1,336,745

55 XTO ENERGY - - 310,000 294,139 890,089 1,050,000 1,026,248 1,085,000 926,425 1,081,397 743,146 772,450 8,178,894

56 SPOTLIGHT E - - - - 2,500 - - - - - 729,000 12,500 744,000

57 VITOL INC. - - - - - - - - - - 1,502,948 1,562,132 3,065,080

58 CITADEL ENE - - - - - - - - - - 1,350,000 1,395,000 2,745,000

59 GUNVOR USA - - - - - - - - - - 300,000 310,000 610,000

60 TOTALS 39,256,393 34,163,483 36,232,075 35,666,935 37,634,178 36,631,969 36,894,216 37,277,577 33,609,754 38,126,613 38,642,686 36,890,183 441,026,062

1/ Volumes exclusive of backhaul


TOTAL VOLUMES FOR PERIOD ENDED DECEMBER 31, 2020 1/

APPENDIX C

Appendix C Description Page 1 of 2


Applicable Shrinkage Deferred Account Description of Account Entries

Pursuant to Section 21.2(E) of the General Terms and Conditions (“GT&C”) of NEXUS’

FERC NGA Gas Tariff, Original Volume No. 1, NEXUS maintains an Applicable Shrinkage Deferred Account (“ASA Deferred Account”), which is credited and/or debited each month for the resolution of fuel reimbursement differences as well as the net cashout activity.

Appendix C, Schedule No. 1 summarizes the monthly ASA Deferred Account activity from January 2020 through December 2020.

Appendix C, Schedule No. 2 reflects the calculation of the monthly carrying charges through February 28, 2021.

Appendix C, Schedule No. 3 reflects the sources and disposition of gas utilized to balance the fuel reimbursement differences and net cashout activity each month.

Appendix C, Schedule No. 4 reflects the average monthly ASA Index Price and the

average monthly cashout index price. Additional descriptions for the items in Appendix C, Schedule No. 3 are provided below:

“Net Cashout Activity” reflects the net activity of cashout purchases and sales under NEXUS’

transportation rate schedules and OBA contracts. It represents the aggregate of the individual purchases and sales cashed out during the month at each transaction’s applicable cashout price.

“Resolution of Net Cashout Based On System Inventory Cost” reflects either the disposition of a

net cashout purchase of gas for the month, or the sourcing of gas quantities used from system inventory to balance a net cashout sale of gas for the month. Since NEXUS does not buy and sell gas specifically to resolve these cashout quantity differences, the cost of system inventory is used in the resolution of the net cashout.

“Net Pipeline’s Gas Use” reflects the net excess or deficiency quantities resulting from the

month’s actual quantities of gas used or lost compared to the actual quantities of gas retained from Shippers as reimbursement.

“Resolution of Net Pipeline’s Gas Use” reflects either the disposition of a net excess quantity of

gas retained for the month, or the sourcing of gas quantities used from system inventory to balance a net deficiency quantity of retention gas for the month. Since NEXUS does not buy and sell gas specifically to resolve these Pipeline’s Gas Use quantity differences,

Appendix C Description Page 2 of 2

gas from system inventory is used in the resolution of the net Pipeline’s Gas Use, priced at the ASA Index Price for the month, as reflected on Appendix C, Schedule No. 4, herein.

“System Inventory for Resolution of Net Cashout and Gas Use” reflects the cost or revenue

experienced in sourcing or disposing of net cashout gas in the following ways: (1) In-kind Imbalance Monthly Activity; (2) Cumulative In-kind Imbalance Repricing; (3) Capitalized Gas Loss; (4) Line Pack Changes; (5) Operational Purchases; (6) Operational Sales. The Resolution of Net Pipeline’s Gas Use is deducted to obtain the cost attributable to the Net Cashout.

“In-kind Imbalance Monthly Activity” reflects the month’s activity with respect to imbalances

incurred at interconnects which are not cashed out. These in-kind imbalances are valued pursuant to the Commission-prescribed Mid-LA pricing methodology. See Mid Louisiana Gas Co., 34 FERC ¶ 61,051 (1986) (“Mid-LA”). In accordance with Mid-LA, the current month activity is priced at the current month’s cashout price.

“Cumulative In-kind Imbalance Repricing” reflects the cost adjustment due to the impact of

monthly changes in the cashout price on cumulative imbalance quantities available for current month system inventory, in accordance with Mid-LA.

“Capitalized Gas Loss” reflects the value credited to the system at the current month’s cashout

price for gas which is lost from the system and capitalized. “Line Pack Changes” are valued at the current month’s cashout price as reflected in Appendix C,

Schedule No. 4, herein. “Operational Purchases” reflect the cost of operational purchases made by NEXUS from time to

time to manage system imbalances, which are valued at the price negotiated between NEXUS and the seller. NEXUS made no Operational Purchases during the current reporting period.

“Operational Sales” reflect the revenue from operational sales made by NEXUS, which are

valued at the price negotiated between NEXUS and the buyer. NEXUS made no Operational Sales during the current reporting period.

Appendix C

Schedule No. 1

1 of 3

Line

No.

1 January 2020

Deferred Amounts 359,906.83$

Carrying Charges

Ending Balance 359,906.83$

2 February 2020


Carrying Charges 1,084.30$


3 March 2020




4 April 2020


Carrying Charges 726.99$


5 May 2020




6 June 2020




Acount No. 182/254

Current Subaccount


Applicable Shrinkage Deferred Account Summary

Period: January 2020 - December 2020

Appendix C

Schedule No. 1

2 of 3

Line

No.

Acount No. 182/254

Current Subaccount




7 July 2020




8 August 2020



Ending Balance 1,519,863.13$

9 September 2020




10 October 2020

Deferred Amounts 1,116,558.07$



11 November 2020

Deferred Amounts 1,101,677.44$



12 December 2020




Appendix C

Schedule No. 1

3 of 3

Line

No.

Acount No. 182/254

Current Subaccount




13 January 2021

Deferred Amounts



14 February 2021

Deferred Amounts



Appendix C

Schedule No. 2

Page 1 of 1


ASA Deferred Account - Carrying Charge Calculation

Balance Balance

Carrying Excluding State Tax Federal Tax Deferred Net of Monthly Cumulative

Production Current Beginning Charge Carrying (e) = (b) *rate% (f) = [(b) - (e)] * rate% Income Taxes Deferred FERC Carrying Carrying

Month Month Balance Exclusions Charges 2020 2020 Exclusion Taxes Rate 1/ Charge Charge

(a) (b)=PM [(a)+(b)+(j)] (c )=PM[(c )+(j)] (d)=(b)-(c ) 2.2161% 21% (g) = (e) + (f) (h) = (d) - (g)

(i) =(n)/days in yr *

days in mth (j) = (h) * (i) (k) = PM(k) + (j)

Jan-20 359,906.83 - - - - - - - 0.0042 - -

Feb-20 68,593.71 359,906.83 - 359,906.83 7,975.90 73,905.50 81,881.40 278,025.43 0.0039 1,084.30 1,084.30

Mar-20 (189,666.47) 429,584.84 1,084.30 428,500.54 9,520.03 88,213.61 97,733.64 330,766.90 0.0042 1,389.22 2,473.52

Apr-20 (262,259.89) 241,307.59 - 241,307.59 5,347.62 49,551.59 54,899.21 186,408.38 0.0039 726.99 3,200.51

May-20 (131,139.27) (20,225.31) 726.99 (20,952.30) (448.21) (4,153.19) (4,601.40) (16,350.90) 0.0040 (65.40) 3,135.11

Jun-20 (17,763.91) (151,429.98) 661.59 (152,091.57) (3,355.84) (31,095.57) (34,451.41) (117,640.16) 0.0039 (458.80) 2,676.31

Jul-20 (475,549.27) (169,652.69) - (169,652.69) (3,759.67) (34,837.53) (38,597.20) (131,055.49) 0.0029 (380.06) 2,296.25

Aug-20 (872,835.96) (645,582.02) (380.06) (645,201.96) (14,306.74) (132,567.81) (146,874.55) (498,327.41) 0.0029 (1,445.15) 851.10

Sep-20 486,362.55 (1,519,863.13) (1,825.21) (1,518,037.92) (33,681.69) (312,098.10) (345,779.79) (1,172,258.13) 0.0028 (3,282.32) (2,431.22)

Oct-20 (1,116,558.07) (1,036,782.90) - (1,036,782.90) (22,976.15) (212,899.42) (235,875.57) (800,907.33) 0.0028 (2,242.54) (4,673.76)

Nov-20 (1,101,677.44) (2,155,583.51) (2,242.54) (2,153,340.97) (47,769.89) (442,640.86) (490,410.75) (1,662,930.22) 0.0027 (4,489.91) (9,163.67)

Dec-20 (320,194.57) (3,261,750.86) (6,732.45) (3,255,018.41) (72,283.66) (669,788.11) (742,071.77) (2,512,946.64) 0.0028 (7,036.25) (16,199.92)

Jan-21 - (3,588,981.68) - (3,588,981.68) (79,535.42) (736,983.71) (816,519.13) (2,772,462.55) 0.0028 (7,762.90) (23,962.82)

Feb-21 - (3,596,744.58) (7,762.90) (3,588,981.68) (79,707.46) (738,577.80) (818,285.26) (2,770,696.42) 0.0025 (6,926.74) (30,889.56)

- (3,603,671.32) (14,689.64) (3,588,981.68)

Footnotes:

1/ Interest rate is calculated pursuant to Section 154.501(d) of the Commission's regulations and in accordance with GT&C Section 21.2(E).

Calculation of Interest Rate for a month:

Monthly Rate = Quarterly Rate/days per year x days in month

2/ Current month includes cash out billings based on billing production month, billed on a month lag.

3/ Carrying charge is compounded quarterly.

4/ Cumulative carrying charge is calculated through February 28, 2021.

February 28, 2021

Appendix C

Schedule No. 3

1 of 12

Line

No Dth $ $/ Dth

(A) (B) (C)

1 Monthly ASA Deferred Account

2 Net Cashout

3 Net Cash Out Purchases (Sales)

4 OBA Cashouts - -$

5 Total Net Cashout Activity - -$

6 Resolution of Net Cashout Based On System Inventory Cost - 239,790$ [1]

7 Debit (Credit) to ASA [Line 5+Line 6] 239,790$

8 Net Pipeline's Gas Use

9 Total Gas Used

10 Market Fuel Area 1 (Greenfield) (574,752) (1,078,580)$ 1.8766 [2]

11 Supply Fuel Area (TEAL) (176,419) (291,144)$ 1.6503 [2]

12 Market Fuel Area 2 (DTE) (264,052) (498,425)$ 1.8876 [3]

13 Market Fuel Area 3 (Vector) (43,882) (83,319)$ 1.8987 [2]

14 Total Gas Retained 1,012,635 1,831,350$ 1.8085 [4]

15 Net Excess (Deficiency) (46,470) (120,117)$

16 Resolution of Net Pipeline's Gas Use 46,470 120,117$

17 TOTAL DEBIT / (CREDIT) TO ASA (Line 7 + 16) 359,907$

18 Footnote [1]:

19 Derivation of System Inventory Cost for Net Cashout

20 System Inventory for Resolution of Net Cashout and Use:

21 In-kind Imbalance Adjustment 97,789 183,511$ 1.8766 [2]

22 Cum. Imbalance Repricing (a) 242,626$

23 Capitalized Gas Loss - -$ 1.8766

24 Line Pack Change (51,319) (96,305)$ 1.8766 [2]

25 Cum. Line Pack Repricing (a) 30,075$

26 Operational Purchases - -$ 1.8766

27 Operational Sales - -$ 1.8766

28 Sub Total 46,470 359,907

29 Less: Resolution of Pipeline's Gas Use 46,470 120,117$

30 System Inventory Cost for Resolution of Net Cashout - 239,790$

(a) Price adjustment, if applicable, reflecting the impact of monthly changes in the Index Price on cumulative

volumes available for current month system activity.

31 Footnote [2]: Reference Appendix C, Schedule No. 4

32 Footnote [3]: The average of Market Fuel Area 1 (Greenfield) and Market Fuel Area 3 (Vector)

33 Footnote [4]: The average of Supply Fuel Area (TEAL), Market Fuel Area 1 (Greenfield) and Market Fuel Area 3 (Vector)


January 2020 Production

Appendix C

Schedule No. 3

2 of 12

Line

No Dth $ $/ Dth

(A) (B) (C)


2 Net Cashout


4 OBA Cashouts - -$





9 Total Gas Used

10 Market Fuel Area 1 (Greenfield) (380,301) (652,520)$ 1.7158 [2]




14 Total Gas Retained 861,080 1,436,884$ 1.6687 [4]

15 Net Excess (Deficiency) 79,850 119,757$

16 Resolution of Net Pipeline's Gas Use (79,850) (119,757)$


18 Footnote [1]:



21 In-kind Imbalance Adjustment (89,313) (153,243)$ 1.7158 [2]



24 Line Pack Change 9,463 16,237$ 1.7158 [2]




28 Sub Total (79,850) 68,594

29 Less: Resolution of Pipeline's Gas Use (79,850) (119,757)$








February 2020 Production

Appendix C

Schedule No. 3

3 of 12

Line

No Dth $ $/ Dth

(A) (B) (C)


2 Net Cashout


4 OBA Cashouts - -$





9 Total Gas Used








17 TOTAL DEBIT / (CREDIT) TO ASA (Line 7 + 16) (189,666)$

18 Footnote [1]:






24 Line Pack Change 30,446 47,788$ 1.5696 [2]




28 Sub Total (247,371) (189,666)









March 2020 Production

Appendix C

Schedule No. 3

4 of 12

Line

No Dth $ $/ Dth

(A) (B) (C)


2 Net Cashout


4 OBA Cashouts - -$


6 Resolution of Net Cashout Based On System Inventory Cost - (171,535)$ [1]

7 Debit (Credit) to ASA [Line 5+Line 6] (171,535)$


9 Total Gas Used









18 Footnote [1]:




22 Cum. Imbalance Repricing (a) (140,918)$


24 Line Pack Change 56,739 94,578$ 1.6669 [2]

25 Cum. Line Pack Repricing (a) (5,521)$



28 Sub Total (69,483) (262,260)


30 System Inventory Cost for Resolution of Net Cashout - (171,535)$







April 2020 Production

Appendix C

Schedule No. 3

5 of 12

Line

No Dth $ $/ Dth

(A) (B) (C)


2 Net Cashout


4 OBA Cashouts - -$





9 Total Gas Used









18 Footnote [1]:






24 Line Pack Change (33,046) (54,232)$ 1.6411 [2]

25 Cum. Line Pack Repricing (a) (1)$



28 Sub Total (104,662) (131,139)









May 2020 Production

Appendix C

Schedule No. 3

6 of 12

Line

No Dth $ $/ Dth

(A) (B) (C)


2 Net Cashout


4 OBA Cashouts - -$





9 Total Gas Used









18 Footnote [1]:



21 In-kind Imbalance Adjustment 1,833 2,836$ 1.5474 [2]



24 Line Pack Change (116,438) (180,176)$ 1.5474 [2]




28 Sub Total (114,605) (17,764)









June 2020 Production

Appendix C

Schedule No. 3

7 of 12

Line

No Dth $ $/ Dth

(A) (B) (C)


2 Net Cashout


4 OBA Cashouts - -$





9 Total Gas Used









18 Footnote [1]:






24 Line Pack Change 8,134 13,463$ 1.6551 [2]




28 Sub Total (179,798) (475,549)









July 2020 Production

Appendix C

Schedule No. 3

8 of 12

Line

No Dth $ $/ Dth

(A) (B) (C)


2 Net Cashout


4 OBA Cashouts - -$





9 Total Gas Used









18 Footnote [1]:






24 Line Pack Change 92,051 183,458$ 1.9930 [2]

25 Cum. Line Pack Repricing (a) (41,018)$



28 Sub Total (106,729) (872,836)









August 2020 Production

Appendix C

Schedule No. 3

9 of 12

Line

No Dth $ $/ Dth

(A) (B) (C)


2 Net Cashout


4 OBA Cashouts - -$





9 Total Gas Used









18 Footnote [1]:






24 Line Pack Change (16,581) (27,569)$ 1.6627 [2]




28 Sub Total (110,950) 486,363









September 2020 Production

Appendix C

Schedule No. 3

10 of 12

Line

No Dth $ $/ Dth

(A) (B) (C)


2 Net Cashout


4 OBA Cashouts - -$





9 Total Gas Used








17 TOTAL DEBIT / (CREDIT) TO ASA (Line 7 + 16) (1,116,558)$

18 Footnote [1]:






24 Line Pack Change (30,915) (62,909)$ 2.0349 [2]

25 Cum. Line Pack Repricing (a) 1$



28 Sub Total (159,957) (1,116,558)









October 2020 Production

Appendix C

Schedule No. 3

11 of 12

Line

No Dth $ $/ Dth

(A) (B) (C)


2 Net Cashout


4 OBA Cashouts - -$





9 Total Gas Used








17 TOTAL DEBIT / (CREDIT) TO ASA (Line 7 + 16) (1,101,677)$

18 Footnote [1]:






24 Line Pack Change (38,801) (91,551)$ 2.3595 [2]




28 Sub Total (156,769) (1,101,677)









November 2020 Production

Appendix C

Schedule No. 3

12 of 12

Line

No Dth $ $/ Dth

(A) (B) (C)


2 Net Cashout


4 OBA Cashouts - -$





9 Total Gas Used









18 Footnote [1]:






24 Line Pack Change (9,582) (22,900)$ 2.3899 [2]




28 Sub Total (103,802) (320,195)









December 2020 Production

Appendix C

Schedule No. 4

Page 1 of 1

Line Market Zone 1 Supply Zone Market Zone 2

No. Year Month Mich Con city gate Texas Eastern, M-2 Receipts Dawn, Ontario

1 2020 January 1.8766 1.6503 1.8987

2 2020 February 1.7158 1.5681 1.7221

3 2020 March 1.5696 1.3470 1.5738

4 2020 April 1.6669 1.4074 1.6836

5 2020 May 1.6411 1.3061 1.6561

6 2020 June 1.5474 1.3381 1.5781

7 2020 July 1.6551 1.2754 1.6893

8 2020 August 1.9930 1.1446 2.0062

9 2020 September 1.6627 0.9142 1.6843

10 2020 October 2.0349 0.8645 2.1091

11 2020 November 2.3595 1.2203 2.3550

12 2020 December 2.3899 2.1132 2.4099

Average Monthly Cashout Index Price


Monthly ASA Index Price

Source: Platts Gas Daily

CERTIFICATE OF SERVICE

I hereby certify that I have electronically served the foregoing document upon customers of

NEXUS Gas Transmission, LLC and interested state commissions that have requested electronic

service. A paper copy of this filing may only be served if a customer or state commission has been

granted a waiver of electronic service pursuant to Section 390 of the Commission’s regulations.

Dated at Houston, Texas, this 26th day of February 2021.

/s/ David Chow David Chow On behalf of

NEXUS Gas Transmission, LLC By: Spectra Energy NEXUS Management, LLC,

in its capacity as operator

NEXUS GAS TRANSMISSION, LLC

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