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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 Page 2 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 Page 3 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 Page 4
* 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.
Ms. Kimberly D. Bose, Secretary February 26, 2021 Page 5
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
NEXUS GAS TRANSMISSION, LLC
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
NEXUS GAS TRANSMISSION, LLC
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
NEXUS GAS TRANSMISSION, LLC
TOTAL VOLUMES FOR PERIOD ENDED DECEMBER 31, 2020 1/
APPENDIX C
Appendix C Description Page 1 of 2
NEXUS GAS TRANSMISSION, LLC
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
Deferred Amounts 68,593.71$
Carrying Charges 1,084.30$
Ending Balance 429,584.84$
3 March 2020
Deferred Amounts 189,666.47$
Carrying Charges 1,389.22$
Ending Balance 241,307.59$
4 April 2020
Deferred Amounts 262,259.89$
Carrying Charges 726.99$
Ending Balance 20,225.31$
5 May 2020
Deferred Amounts 131,139.27$
Carrying Charges 65.40$
Ending Balance 151,429.98$
6 June 2020
Deferred Amounts 17,763.91$
Carrying Charges 458.80$
Ending Balance 169,652.69$
Acount No. 182/254
Current Subaccount
NEXUS GAS TRANSMISSION, LLC
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
NEXUS GAS TRANSMISSION, LLC
Applicable Shrinkage Deferred Account Summary
Period: January 2020 - December 2020
7 July 2020
Deferred Amounts 475,549.27$
Carrying Charges 380.06$
Ending Balance 645,582.02$
8 August 2020
Deferred Amounts 872,835.96$
Carrying Charges 1,445.15$
Ending Balance 1,519,863.13$
9 September 2020
Deferred Amounts 486,362.55$
Carrying Charges 3,282.32$
Ending Balance 1,036,782.90$
10 October 2020
Deferred Amounts 1,116,558.07$
Carrying Charges 2,242.54$
Ending Balance 2,155,583.51$
11 November 2020
Deferred Amounts 1,101,677.44$
Carrying Charges 4,489.91$
Ending Balance 3,261,750.86$
12 December 2020
Deferred Amounts 320,194.57$
Carrying Charges 7,036.25$
Ending Balance 3,588,981.68$
Appendix C
Schedule No. 1
3 of 3
Line
No.
Acount No. 182/254
Current Subaccount
NEXUS GAS TRANSMISSION, LLC
Applicable Shrinkage Deferred Account Summary
Period: January 2020 - December 2020
13 January 2021
Deferred Amounts
Carrying Charges 7,762.90$
Ending Balance 3,596,744.58$
14 February 2021
Deferred Amounts
Carrying Charges 6,926.74$
Ending Balance 3,603,671.32$
Appendix C
Schedule No. 2
Page 1 of 1
NEXUS GAS TRANSMISSION, LLC
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)
NEXUS GAS TRANSMISSION, LLC
January 2020 Production
Appendix C
Schedule No. 3
2 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 - 188,350$ [1]
7 Debit (Credit) to ASA [Line 5+Line 6] 188,350$
8 Net Pipeline's Gas Use
9 Total Gas Used
10 Market Fuel Area 1 (Greenfield) (380,301) (652,520)$ 1.7158 [2]
11 Supply Fuel Area (TEAL) (163,483) (256,358)$ 1.5681 [2]
12 Market Fuel Area 2 (DTE) (211,729) (363,962)$ 1.7190 [3]
13 Market Fuel Area 3 (Vector) (25,717) (44,287)$ 1.7221 [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)$
17 TOTAL DEBIT / (CREDIT) TO ASA (Line 7 + 16) 68,594$
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 (89,313) (153,243)$ 1.7158 [2]
22 Cum. Imbalance Repricing (a) 173,849$
23 Capitalized Gas Loss - -$ 1.7158
24 Line Pack Change 9,463 16,237$ 1.7158 [2]
25 Cum. Line Pack Repricing (a) 31,751$
26 Operational Purchases - -$ 1.7158
27 Operational Sales - -$ 1.7158
28 Sub Total (79,850) 68,594
29 Less: Resolution of Pipeline's Gas Use (79,850) (119,757)$
30 System Inventory Cost for Resolution of Net Cashout - 188,350$
(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)
NEXUS GAS TRANSMISSION, LLC
February 2020 Production
Appendix C
Schedule No. 3
3 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 - 172,169$ [1]
7 Debit (Credit) to ASA [Line 5+Line 6] 172,169$
8 Net Pipeline's Gas Use
9 Total Gas Used
10 Market Fuel Area 1 (Greenfield) (239,996) (376,698)$ 1.5696 [2]
11 Supply Fuel Area (TEAL) (174,645) (235,247)$ 1.3470 [2]
12 Market Fuel Area 2 (DTE) (197,568) (310,518)$ 1.5717 [3]
13 Market Fuel Area 3 (Vector) (30,149) (47,448)$ 1.5738 [2]
14 Total Gas Retained 889,729 1,331,746$ 1.4968 [4]
15 Net Excess (Deficiency) 247,371 361,836$
16 Resolution of Net Pipeline's Gas Use (247,371) (361,836)$
17 TOTAL DEBIT / (CREDIT) TO ASA (Line 7 + 16) (189,666)$
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 (277,817) (436,062)$ 1.5696 [2]
22 Cum. Imbalance Repricing (a) 171,122$
23 Capitalized Gas Loss - -$ 1.5696
24 Line Pack Change 30,446 47,788$ 1.5696 [2]
25 Cum. Line Pack Repricing (a) 27,485$
26 Operational Purchases - -$ 1.5696
27 Operational Sales - -$ 1.5696
28 Sub Total (247,371) (189,666)
29 Less: Resolution of Pipeline's Gas Use (247,371) (361,836)$
30 System Inventory Cost for Resolution of Net Cashout - 172,169$
(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)
NEXUS GAS TRANSMISSION, LLC
March 2020 Production
Appendix C
Schedule No. 3
4 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 - (171,535)$ [1]
7 Debit (Credit) to ASA [Line 5+Line 6] (171,535)$
8 Net Pipeline's Gas Use
9 Total Gas Used
10 Market Fuel Area 1 (Greenfield) (367,327) (612,297)$ 1.6669 [2]
11 Supply Fuel Area (TEAL) (161,989) (227,983)$ 1.4074 [2]
12 Market Fuel Area 2 (DTE) (179,855) (301,311)$ 1.6753 [3]
13 Market Fuel Area 3 (Vector) (26,930) (45,339)$ 1.6836 [2]
14 Total Gas Retained 805,584 1,277,656$ 1.5860 [4]
15 Net Excess (Deficiency) 69,483 90,725$
16 Resolution of Net Pipeline's Gas Use (69,483) (90,725)$
17 TOTAL DEBIT / (CREDIT) TO ASA (Line 7 + 16) (262,260)$
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 (126,222) (210,399)$ 1.6669 [2]
22 Cum. Imbalance Repricing (a) (140,918)$
23 Capitalized Gas Loss - -$ 1.6669
24 Line Pack Change 56,739 94,578$ 1.6669 [2]
25 Cum. Line Pack Repricing (a) (5,521)$
26 Operational Purchases - -$ 1.6669
27 Operational Sales - -$ 1.6669
28 Sub Total (69,483) (262,260)
29 Less: Resolution of Pipeline's Gas Use (69,483) (90,725)$
30 System Inventory Cost for Resolution of Net Cashout - (171,535)$
(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)
NEXUS GAS TRANSMISSION, LLC
April 2020 Production
Appendix C
Schedule No. 3
5 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 - 3,175$ [1]
7 Debit (Credit) to ASA [Line 5+Line 6] 3,175$
8 Net Pipeline's Gas Use
9 Total Gas Used
10 Market Fuel Area 1 (Greenfield) (374,930) (615,298)$ 1.6411 [2]
11 Supply Fuel Area (TEAL) (173,759) (226,947)$ 1.3061 [2]
12 Market Fuel Area 2 (DTE) (200,751) (330,958)$ 1.6486 [3]
13 Market Fuel Area 3 (Vector) (24,796) (41,065)$ 1.6561 [2]
14 Total Gas Retained 878,898 1,348,581$ 1.5344 [4]
15 Net Excess (Deficiency) 104,662 134,314$
16 Resolution of Net Pipeline's Gas Use (104,662) (134,314)$
17 TOTAL DEBIT / (CREDIT) TO ASA (Line 7 + 16) (131,139)$
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 (71,616) (117,529)$ 1.6411 [2]
22 Cum. Imbalance Repricing (a) 40,622$
23 Capitalized Gas Loss - -$ 1.6411
24 Line Pack Change (33,046) (54,232)$ 1.6411 [2]
25 Cum. Line Pack Repricing (a) (1)$
26 Operational Purchases - -$ 1.6411
27 Operational Sales - -$ 1.6411
28 Sub Total (104,662) (131,139)
29 Less: Resolution of Pipeline's Gas Use (104,662) (134,314)$
30 System Inventory Cost for Resolution of Net Cashout - 3,175$
(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)
NEXUS GAS TRANSMISSION, LLC
May 2020 Production
Appendix C
Schedule No. 3
6 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 - 141,113$ [1]
7 Debit (Credit) to ASA [Line 5+Line 6] 141,113$
8 Net Pipeline's Gas Use
9 Total Gas Used
10 Market Fuel Area 1 (Greenfield) (355,456) (550,033)$ 1.5474 [2]
11 Supply Fuel Area (TEAL) (169,552) (226,878)$ 1.3381 [2]
12 Market Fuel Area 2 (DTE) (188,743) (294,968)$ 1.5628 [3]
13 Market Fuel Area 3 (Vector) (19,476) (30,735)$ 1.5781 [2]
14 Total Gas Retained 847,832 1,261,489$ 1.4879 [4]
15 Net Excess (Deficiency) 114,605 158,876$
16 Resolution of Net Pipeline's Gas Use (114,605) (158,876)$
17 TOTAL DEBIT / (CREDIT) TO ASA (Line 7 + 16) (17,764)$
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 1,833 2,836$ 1.5474 [2]
22 Cum. Imbalance Repricing (a) 154,242$
23 Capitalized Gas Loss - -$ 1.5474
24 Line Pack Change (116,438) (180,176)$ 1.5474 [2]
25 Cum. Line Pack Repricing (a) 5,334$
26 Operational Purchases - -$ 1.5474
27 Operational Sales - -$ 1.5474
28 Sub Total (114,605) (17,764)
29 Less: Resolution of Pipeline's Gas Use (114,605) (158,876)$
30 System Inventory Cost for Resolution of Net Cashout - 141,113$
(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)
NEXUS GAS TRANSMISSION, LLC
June 2020 Production
Appendix C
Schedule No. 3
7 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 - (220,130)$ [1]
7 Debit (Credit) to ASA [Line 5+Line 6] (220,130)$
8 Net Pipeline's Gas Use
9 Total Gas Used
10 Market Fuel Area 1 (Greenfield) (293,959) (486,532)$ 1.6551 [2]
11 Supply Fuel Area (TEAL) (167,819) (214,036)$ 1.2754 [2]
12 Market Fuel Area 2 (DTE) (213,373) (356,802)$ 1.6722 [3]
13 Market Fuel Area 3 (Vector) (25,666) (43,358)$ 1.6893 [2]
14 Total Gas Retained 880,615 1,356,147$ 1.5400 [4]
15 Net Excess (Deficiency) 179,798 255,419$
16 Resolution of Net Pipeline's Gas Use (179,798) (255,419)$
17 TOTAL DEBIT / (CREDIT) TO ASA (Line 7 + 16) (475,549)$
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 (187,932) (311,046)$ 1.6551 [2]
22 Cum. Imbalance Repricing (a) (177,090)$
23 Capitalized Gas Loss - -$ 1.6551
24 Line Pack Change 8,134 13,463$ 1.6551 [2]
25 Cum. Line Pack Repricing (a) (876)$
26 Operational Purchases - -$ 1.6551
27 Operational Sales - -$ 1.6551
28 Sub Total (179,798) (475,549)
29 Less: Resolution of Pipeline's Gas Use (179,798) (255,419)$
30 System Inventory Cost for Resolution of Net Cashout - (220,130)$
(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)
NEXUS GAS TRANSMISSION, LLC
July 2020 Production
Appendix C
Schedule No. 3
8 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 - (756,588)$ [1]
7 Debit (Credit) to ASA [Line 5+Line 6] (756,588)$
8 Net Pipeline's Gas Use
9 Total Gas Used
10 Market Fuel Area 1 (Greenfield) (371,707) (740,812)$ 1.9930 [2]
11 Supply Fuel Area (TEAL) (177,499) (203,165)$ 1.1446 [2]
12 Market Fuel Area 2 (DTE) (206,750) (413,417)$ 1.9996 [3]
13 Market Fuel Area 3 (Vector) (18,919) (37,955)$ 2.0062 [2]
14 Total Gas Retained 881,604 1,511,598$ 1.7146 [4]
15 Net Excess (Deficiency) 106,729 116,248$
16 Resolution of Net Pipeline's Gas Use (106,729) (116,248)$
17 TOTAL DEBIT / (CREDIT) TO ASA (Line 7 + 16) (872,836)$
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 (198,780) (396,169)$ 1.9930 [2]
22 Cum. Imbalance Repricing (a) (619,107)$
23 Capitalized Gas Loss - -$ 1.9930
24 Line Pack Change 92,051 183,458$ 1.9930 [2]
25 Cum. Line Pack Repricing (a) (41,018)$
26 Operational Purchases - -$ 1.9930
27 Operational Sales - -$ 1.9930
28 Sub Total (106,729) (872,836)
29 Less: Resolution of Pipeline's Gas Use (106,729) (116,248)$
30 System Inventory Cost for Resolution of Net Cashout - (756,588)$
(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)
NEXUS GAS TRANSMISSION, LLC
August 2020 Production
Appendix C
Schedule No. 3
9 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 - 586,637$ [1]
7 Debit (Credit) to ASA [Line 5+Line 6] 586,637$
8 Net Pipeline's Gas Use
9 Total Gas Used
10 Market Fuel Area 1 (Greenfield) (320,924) (533,600)$ 1.6627 [2]
11 Supply Fuel Area (TEAL) (156,551) (143,119)$ 0.9142 [2]
12 Market Fuel Area 2 (DTE) (208,322) (348,627)$ 1.6735 [3]
13 Market Fuel Area 3 (Vector) (23,033) (38,794)$ 1.6843 [2]
14 Total Gas Retained 819,780 1,164,416$ 1.4204 [4]
15 Net Excess (Deficiency) 110,950 100,275$
16 Resolution of Net Pipeline's Gas Use (110,950) (100,275)$
17 TOTAL DEBIT / (CREDIT) TO ASA (Line 7 + 16) 486,363$
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 (94,369) (156,907)$ 1.6627 [2]
22 Cum. Imbalance Repricing (a) 670,839$
23 Capitalized Gas Loss - -$ 1.6627
24 Line Pack Change (16,581) (27,569)$ 1.6627 [2]
25 Cum. Line Pack Repricing (a) (0)$
26 Operational Purchases - -$ 1.6627
27 Operational Sales - -$ 1.6627
28 Sub Total (110,950) 486,363
29 Less: Resolution of Pipeline's Gas Use (110,950) (100,275)$
30 System Inventory Cost for Resolution of Net Cashout - 586,637$
(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)
NEXUS GAS TRANSMISSION, LLC
September 2020 Production
Appendix C
Schedule No. 3
10 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 - (930,807)$ [1]
7 Debit (Credit) to ASA [Line 5+Line 6] (930,807)$
8 Net Pipeline's Gas Use
9 Total Gas Used
10 Market Fuel Area 1 (Greenfield) (324,590) (660,508)$ 2.0349 [2]
11 Supply Fuel Area (TEAL) (177,090) (153,094)$ 0.8645 [2]
12 Market Fuel Area 2 (DTE) (233,306) (483,410)$ 2.0720 [3]
13 Market Fuel Area 3 (Vector) (25,805) (54,425)$ 2.1091 [2]
14 Total Gas Retained 920,748 1,537,189$ 1.6695 [4]
15 Net Excess (Deficiency) 159,957 185,751$
16 Resolution of Net Pipeline's Gas Use (159,957) (185,751)$
17 TOTAL DEBIT / (CREDIT) TO ASA (Line 7 + 16) (1,116,558)$
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 (129,042) (262,588)$ 2.0349 [2]
22 Cum. Imbalance Repricing (a) (791,062)$
23 Capitalized Gas Loss - -$ 2.0349
24 Line Pack Change (30,915) (62,909)$ 2.0349 [2]
25 Cum. Line Pack Repricing (a) 1$
26 Operational Purchases - -$ 2.0349
27 Operational Sales - -$ 2.0349
28 Sub Total (159,957) (1,116,558)
29 Less: Resolution of Pipeline's Gas Use (159,957) (185,751)$
30 System Inventory Cost for Resolution of Net Cashout - (930,807)$
(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)
NEXUS GAS TRANSMISSION, LLC
October 2020 Production
Appendix C
Schedule No. 3
11 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 - (895,452)$ [1]
7 Debit (Credit) to ASA [Line 5+Line 6] (895,452)$
8 Net Pipeline's Gas Use
9 Total Gas Used
10 Market Fuel Area 1 (Greenfield) (324,550) (765,776)$ 2.3595 [2]
11 Supply Fuel Area (TEAL) (171,717) (209,546)$ 1.2203 [2]
12 Market Fuel Area 2 (DTE) (249,705) (588,605)$ 2.3572 [3]
13 Market Fuel Area 3 (Vector) (41,534) (97,813)$ 2.3550 [2]
14 Total Gas Retained 944,275 1,867,965$ 1.9782 [4]
15 Net Excess (Deficiency) 156,769 206,226$
16 Resolution of Net Pipeline's Gas Use (156,769) (206,226)$
17 TOTAL DEBIT / (CREDIT) TO ASA (Line 7 + 16) (1,101,677)$
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 (117,968) (278,345)$ 2.3595 [2]
22 Cum. Imbalance Repricing (a) (731,782)$
23 Capitalized Gas Loss - -$ 2.3595
24 Line Pack Change (38,801) (91,551)$ 2.3595 [2]
25 Cum. Line Pack Repricing (a) 1$
26 Operational Purchases - -$ 2.3595
27 Operational Sales - -$ 2.3595
28 Sub Total (156,769) (1,101,677)
29 Less: Resolution of Pipeline's Gas Use (156,769) (206,226)$
30 System Inventory Cost for Resolution of Net Cashout - (895,452)$
(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)
NEXUS GAS TRANSMISSION, LLC
November 2020 Production
Appendix C
Schedule No. 3
12 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 - (105,746)$ [1]
7 Debit (Credit) to ASA [Line 5+Line 6] (105,746)$
8 Net Pipeline's Gas Use
9 Total Gas Used
10 Market Fuel Area 1 (Greenfield) (349,738) (835,839)$ 2.3899 [2]
11 Supply Fuel Area (TEAL) (174,026) (367,752)$ 2.1132 [2]
12 Market Fuel Area 2 (DTE) (253,008) (607,194)$ 2.3999 [3]
13 Market Fuel Area 3 (Vector) (36,681) (88,398)$ 2.4099 [2]
14 Total Gas Retained 917,255 2,113,631$ 2.3043 [4]
15 Net Excess (Deficiency) 103,802 214,449$
16 Resolution of Net Pipeline's Gas Use (103,802) (214,449)$
17 TOTAL DEBIT / (CREDIT) TO ASA (Line 7 + 16) (320,195)$
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 (94,220) (225,176)$ 2.3899 [2]
22 Cum. Imbalance Repricing (a) (72,120)$
23 Capitalized Gas Loss - -$ 2.3899
24 Line Pack Change (9,582) (22,900)$ 2.3899 [2]
25 Cum. Line Pack Repricing (a) 2$
26 Operational Purchases - -$ 2.3899
27 Operational Sales - -$ 2.3899
28 Sub Total (103,802) (320,195)
29 Less: Resolution of Pipeline's Gas Use (103,802) (214,449)$
30 System Inventory Cost for Resolution of Net Cashout - (105,746)$
(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)
NEXUS GAS TRANSMISSION, LLC
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
NEXUS GAS TRANSMISSION, LLC
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