Northern Natural Gas Company
P.O. Box 3330
Omaha, NE 68103-0330
402 398-7200
February 1, 2016
Ms. Kimberly D. Bose, Secretary
Federal Energy Regulatory Commission
888 First Street, N.E.
Washington, D.C. 20426
Re:
Northern Natural Gas Company
Docket No. RP16-___-000
Periodic Rate Adjustments for Fuel
Dear Ms. Bose:
Northern Natural Gas Company (“Northern”) submits herewith for filing as part of its
F.E.R.C. Gas Tariff, Sixth Revised Volume No. 1 (Tariff), the following tariff sheets to
be effective April 1, 2016:
SIXTH REVISED VOLUME NO. 1
Tenth Revised Sheet No. 50
Eleventh Revised Sheet No. 51
Tenth Revised Sheet No. 52
Ninth Revised Sheet No. 53
Thirteenth Revised Sheet No. 54
Eighth Revised Sheet No. 60
Eighth Revised Sheet No. 60A
Sixth Revised Sheet No. 61
Twelfth Revised Sheet No. 62
Reason for Filing
The revised tariff sheets are being filed in accordance with Sections 53A and 53B of the
General Terms and Conditions of Northern’s Tariff, as further discussed herein. This
filing establishes the Field Area and Storage fuel percentages to be in effect for the
April 1, 2016 through March 31, 2017 annual period, based on actual data for the
twelve-month period January 1, 2015 through December 31, 2015. This filing also
Kimberly D. Bose, Secretary
February 1, 2016
Page 2 of 6
establishes the Market Area fuel percentage to be in effect for the Summer Season of
April 1, 2016 through October 31, 2016.
In addition, the filing establishes the unaccounted for (UAF) percentage to be in effect for
both the Market Area and Field Area for the annual period of April 1, 2016 through
March 31, 2017, based on actual data for the twelve-month period January 1, 2015
through December 31, 2015. True-up adjustments for all fuel and UAF percentages are
also included. Pursuant to Section 53B of the General Terms and Conditions, the filing
establishes the Market Area Electric Compression charge to be in effect for the
April 1, 2016 through March 31, 2017 annual period, based on actual data for the twelvemonth period January 1, 2015 through December 31, 2015.
Although the proposed effective date of the tariff sheets is April 1, 2016, Northern
respectfully requests that the Federal Energy Regulatory Commission (FERC or
Commission) issue an order by March 18, 2016. A number of shippers will be making
supply arrangements for the entire summer season of April through October. Knowing
the fuel retention percentages as far in advance of April 1 as possible will assist in their
planning and contracting processes.
Fuel and UAF Percentages Effective April 1, 2016 – Summary of Changes
A summary of the proposed changes from the 2015 PRA filing in Mainline Fuel, Storage
Fuel and UAF percentages, with true-ups reflected, is as follows:
Section 1 (Permian Area)
Section 2 (Mid-Continent Area)
Storage
UAF
Section 3 (Market Area)
April 1, 2015
0.97%
1.92%
1.76%
-0.09%
April 1, 2016
1.01%
1.29%
1.19%
-0.25%
Summer - 2015
0.62%
Summer - 2016
0.70%
Section 1 (Permian)
The changes in the base and true-up components of the Permian fuel percentage are
shown in the following table.
Base fuel percentage
True-up percentage
Total
April 1, 2015
1.10%
-0.13%
0.97%
April 1, 2016
1.08%
-0.07%
1.01%
Change
-0.02%
0.06%
0.04%
Kimberly D. Bose, Secretary
February 1, 2016
Page 3 of 6
Section 2 (Mid-Continent)
The changes in the base and true-up components of the Mid-Continent fuel percentage
are shown in the following table.
Base fuel percentage
True-up percentage
Total
April 1, 2015
1.51%
0.41%
1.92%
April 1, 2016
1.27%
0.02%
1.29%
Change
-0.24%
-0.39%
-0.63%
Section 3 (Market Area)
The changes in the base and true-up components of the Market Area fuel percentages for
April – October, 2016, are shown in the following table.
Base fuel percentage
True-up percentage
Total
April 1, 2015
0.75%
-0.13%
0.62%
April 1, 2016
0.72%
-0.02%
0.70%
Change
-0.03%
0.11%
0.08%
Storage
The changes in the base and true-up components of the Storage fuel percentages are
shown in the following table.
Base fuel percentage
True-up percentage
Total
April 1, 2015
1.66%
0.10%
1.76%
April 1, 2016
1.43%
-0.24%
1.19%
Change
-0.23%
-0.34%
-0.57%
Kimberly D. Bose, Secretary
February 1, 2016
Page 4 of 6
UAF
The changes in the base and true-up components of the UAF percentage are shown in the
following table.
Base UAF percentage
True-up percentage
Total
April 1, 2015
0.07%
-0.16%
-0.09%
April 1, 2016
-0.01%
-0.24%
-0.25%
Change
-0.08%
-0.08%
-0.16%
Since the UAF percentage is a negative number, Northern will continue to utilize the
accounting mechanism described in footnote 4 of the currently effective Tariff Sheet
No. 54. For deliveries subject only to UAF, the UAF rate will be zero; however,
Northern will issue a volume credit on the shipper’s monthly imbalance statement
equivalent to the associated -0.25% UAF for April, 2016 through March, 2017. Such
quantities will be resolved in accordance with the provisions for resolution of imbalances
found in Section 32 of the General Terms and Conditions of Northern’s FERC Gas
Tariff. The base UAF percentage reflects an adjustment shown in Schedule 7 attached to
this filing. The adjustment reverses a one-time correction booked in June, 2015 for
unreported measured volumes by a third party for a prior period. If the correcting entry
had not been reversed out in the base UAF computation, it would distort the UAF
percentage going forward beginning April 1, 2016. However, the correction for the
unreported measured volumes remains in the true-up percentage in order to pay back
customers for the gas.
Market Area Electric Compression Charge
The Market Area Electric Compression (ECM) commodity surcharge decreased from
$0.0010 to $0.0006.
Supporting Schedules
Supporting information for the proposed changes is attached in Schedule Nos. 1 - 9.
Waiver
Northern respectfully requests that the Commission grant any and all waivers of its
Regulations that it deems necessary to allow the tariff sheets to become effective
April 1, 2016, but, as noted above, Northern respectfully requests that the Commission
issue an order by March 18, 2016.
Posting
Northern has served an electronic copy of this filing upon its customers and interested
state regulatory commissions.
Kimberly D. Bose, Secretary
February 1, 2016
Page 5 of 6
Marked Version
In accordance with Section 154.201 of the Commission's Regulations, Northern has
submitted a marked version of the proposed tariff changes highlighting new additions and
showing deletions by strikeout.
Motion
In accordance with Sections 154.7(a)(9) and 154.206(c) of the Commission's
Regulations, Northern hereby moves to place the tariff sheets referenced herein in effect
as of the end of any suspension period ordered by the Commission.
Data Processing Requirements
Northern is submitting this filing through FERC’s electronic tariff filing process in a
FERC-approved format.
Kimberly D. Bose, Secretary
February 1, 2016
Page 6 of 6
Communication
It is requested that all correspondence and communications concerning this filing be
served upon each of the following:
Laura Demman
Vice President, Regulatory and Government Affairs
Northern Natural Gas Company
1111 South 103rd Street
Omaha, NE 68124-1000
(402) 398-7278
e-mail: Laura.demman@nngco.com
Thomas E. Knight
Steve Stojic
Jennifer Brough
Locke Lord LLP
701 8th Street N.W., Suite 700
Washington, D.C. 20001
(202) 220-6922
tknight@lockelord.com
steve.stojic@lockelord.com
jbrough@lockelord.com
Respectfully submitted,
/s/ Laura Demman
Laura Demman
Vice President, Regulatory and Government Affairs
Attachments
J. Gregory Porter
Vice President, General Counsel
& Chief Compliance Officer
Dari Dornan
Senior Counsel
Northern Natural Gas Company
1111 South 103rd Street
Omaha, NE 68124-1000
(402) 398-7077
greg.porter@nngco.com
dari.dornan@nngco.com
NORTHERN NATURAL GAS COMPANY
PERIODIC RATE ADJUSTMENTS FOR FUEL
SUMMARY OF SCHEDULES
Schedule No. 1
This Schedule reports the fuel consumed at each facility on a month to
month basis sorted by Section 1, 2, 3 and Storage. This Schedule also
shows fuel consumed by MID. The source of the total fuel consumed is
Northern’s Measurement System (FloCal).
Schedule No. 2
This Schedule provides the Annual Throughput described on a Section by
Section basis. The source of this Annual Throughput is Northern’s
Accounting System.
Schedule No. 3
This Schedule calculates the Mainline Fuel Percentages for each Section
by dividing the Fuel Consumed from Schedule No. 1 by the Annual
Throughput as defined in Schedule No. 2. This Schedule reflects the point
exceptions listed on Schedule No. 2.
Schedule No. 4
This Schedule reports total Mainline Fuel Retained by Section.
Schedule No. 5
This Schedule calculates the Mainline True-up adjustment by Section for
the period January 2015 through December 2015 (April-October, 2015 for
Section 3 summer fuel). This Schedule reflects the point exceptions listed
on Schedule No. 2.
Schedule No. 6
This Schedule is a matrix of the Actual Mainline Fuel Percentages
adjusted by the True-up Mainline Fuel Percentages to arrive at the
Mainline fuel rate percentages to be effective April 1, 2016.
Schedule No. 7
This Schedule is a summary of gas by source and disposition used to
calculate the unaccounted for percentages. It includes the calculation of
the True-up for UAF to be effective April 1, 2016.
Schedule No. 8
This Schedule calculates the Storage Fuel Rate for the current period, the
Storage Fuel Rate True-up, and the Total Storage Fuel Percentage to be
effective April 1, 2016.
Schedule No. 9
This Schedule calculates the Market Area Electric Compression charge,
including true-up, to be effective April 1, 2016.
NORTHERN NATURAL GAS COMPANY
PERIODIC RATE ADJUSTMENTS FOR FUEL
FUEL CONSUMED DATA - MAINLINE AND STORAGE
JANUARY, 2015 - DECEMBER, 2015
MID
Sec Zone
/1
Mainline
Storage
S1 MID 2
ML
S1 MID 2
ML
S1 MID 3
ML
S1 MID 3
ML
S1 MID 3
ML
S1 MID 3
ML
S1 MID 3
ML
S1 MID 3
ML
S1 MID 3
ML
S1 MID 6
ML
S1 MID 6
ML
S1 MID 6
ML
S1 MID 6
ML
S1 MID 6
ML
S1 MID 7
ML
S1 MID 7
ML
S1 MID 7
ML
S1 Total
S2 MID 10 ML
S2 MID 10 ML
S2 MID 10 ML
S2 MID 10 ML
S2 MID 11 ML
S2 MID 11 ML
S2 MID 11 ML
S2 MID 11 ML
S2 MID 11 ML
S2 MID 11 ML
S2 MID 11 ML
S2 MID 11 ML
S2 MID 11 ML
S2 MID 11 ML
S2 MID 13 ML
S2 MID 13 ML
S2 MID 13 ML
S2 MID 13 ML
S2 MID 13 ML
S2 MID 13 ML
S2 MID 13 ML
S2 MID 13 ML
S2 MID 13 ML
S2 MID 13 ML
S2 MID 13 ML
S2 MID 13 ML
S2 MID 13 ML
S2 MID 13 ML
S2 MID 14 ML
S2 MID 14 ML
S2 MID 14 ML
S2 MID 15 ML
S2 MID 15 ML
S2 MID 15 ML
S2 MID 15 ML
S2 MID 16 AML
S2 MID 16 AML
S2 MID 16 AML
S2 MID 16 AML
S2 MID 16 AML
S2 MID 16 AML
S2 MID 16 AML
S2 MID 16 AML
Station
Number
Station Name
990003
990031
961341
961342
961601
990004
990006
990022
990034
961421
961451
962145
990005
990008
961401
961431
990028
PLYMOUTH SPRABERRY UNMETERED
PLYMOUTH BLOW AND PURGE
SPRABERRY COMPRESSOR TRANS
SPRAYBERRY RECOMP STA TRANS
SPRAYBERRY OFFICE FUEL
SPRA AND HOBBS PLAINS UNMETERED
COYANOSA TO KERMIT 30 BLOW PURGE
MITCHELL TO PLY TM BLOW AND PURGE
SPRABERRY BLOW AND PURGE
SEMINOLE COMP STA.TRAN.
BROWNFIELD COMP.STA.-TRANS.
PLAINS COMPRESSOR FUEL
BROWN TO PLAIN UNMETERED
PLAINS MEAS STA 26 BLOW PURGE
PLAINVIEW COMP.STA.-TRANS.
CLAUDE TURBINE FUEL
CLAUDE UNMETERED
961201
990019
990030
990038
960448
960449
960450
960466
961020
961022
961049
961519
961520
990012
961115
961116
961117
961119
961120
961122
961123
961125
961126
961317
961512
990002
990010
990023
961580
961581
990009
901523
961072
961114
990035
961040
961042
961043
961044
961107
961108
961109
961110
SUNRAY FUEL(COMP AUX BLDG)
SUNRAY C LINE UNMETERED
SUNRAY UNMETERED
C LINE UNMETERED
BEAVER WAREHOUSE #3
BEAVER EMPLOYEE BLDG.
BEAVER OFFICE/TECH
BEAVER PLANT BOILER FUEL
BEAVER PLANT BLDG 1 ENGINES 14-18
BEAVER PLANT BLDG 2
BEAVER PLANT AUX BU GEN FUEL
BEAVER PLANT BUILDING 1 HEATER FUEL
BEAVER PLANT BUILDING 2 HEATER FUEL
BEAVER PLANT UNMETERED
PLAINS TBS HEATER FUEL
FOWLER TBS HEATER FUEL
CUT STATION HEATER
MULLINVILLE PLANT HEATER FUEL
MULLINVILLE DOMESTIC FUEL
MULL#2 MEAS STA-#2 STA FU
MULL#3-AUX&BOILER FUEL
MULL#5-#26 UNIT FUEL
DODGE CITY TBS HEATER FUEL
CORNELSON DEHY FUEL
ASHLAND OFFICE WHSE FUEL
MULLINVILLE FLASH VAP GAS
MULLINVILLE UNMETERED
MULLINVILLE TRANS PURGE VENT
SUBLETTE COMP NNG START GAS
SUBLETTE COMP NNG ENGINE FUEL
SUBLETTE UNMETERED
GARDEN CITY KS 1C HEATER FUEL
HOLCOMB DOMESTIC FUEL
COPELAND TBS HEATER FUEL
HOLCOMB PLANT TRANS LINE EAST
BUSHTON AUX FUEL #2 3 4 & 5
BUSHTON ENGINE ROOM 2 ENG 23 24 25
BUSHTON COMP#3 FUEL STATION
BUSHTON 4 FUEL COMPRESSOR STATION
MACKSVILLE UNIT 1 STA FUEL
MACKSVILLE UNIT 2 STA FUEL
MACKSVILLE UNIT 3 STA FUEL
MACHSVILLE UNIT 4 STA FUEL
Source: Measurement Data warehouse
Jan-15
Feb-15
Mar-15
Apr-15
May-15
Jun-15
SCHEDULE 1
Jul-15
Aug-15
Sep-15
Oct-15
6
5
5,925
8,614
86
437
6
5
6,316
12,830
69
1,090
6
5
5,367
12,306
46
828
6
6
11,385
20,972
24
820
6
5
12,617
22,016
6
5
9,646
20,341
4
5
3,968
24,076
4
5
4,409
21,776
4
5
4,449
22,584
188
961
367
15
277
48
96
31,858
40,646
17,301
956
43
10,287
7,459
650
124,417
38,495
68
461
48
152
4,180
40,838
13,829
1,041
104
20,166
16,125
632
117,431
48,506
48
106
54,949
17,215
18,429
1,456
102
11,287
11
252
122,413
68,673
48
579
59,435
2,456
15,582
1,440
101
1,027
13
276
114,170
32,519
48
75
62,384
1,188
15,511
360
79
3
48
99
66,955
41,112
2,426
1,726
92
1,360
49
106
63,749
37,766
1,977
2,323
104
633
42
75
61,441
32,190
2,156
2,451
93
2,284
251
114,731
26,474
48
606
57,678
1,412
10,519
1,330
202
1,090
321
400
104,565
19,480
256
142,494
25,168
257
133,173
23,822
255
128,306
23,523
4
5
5,141
22,994
2
15
1,578
48
374
69,266
45,992
5,522
1,473
92
74
1,937
384
154,901
38,736
474
46
44
199
340
132
19,992
56,024
1,326
46
42
131
627
354
14,061
61,952
469
46
32
66
80
9
2,751
26,700
466
46
26
40
470
-6,023
2
2
491
1603
452
45
2
4
473
46
6
6
513
46
12
52
5,112
22,640
117
7,394
15,145
134
10,459
12,333
13,597
15,321
5,643
23,169
12
15,334
10,573
25
660
347
-191,103
52
38
50
14
134
38,261
5,927
48,241
726
62
604
298
4,200
24
20
36
26
80
44,217
4,487
78,421
573
36
42
132
6,374
6
8
28,092
9
6,745
12
44
16
20,622
3,346
2,926
501
6
28
14
25,011
3,644
6
6,113
2,335
416
6,030
109
852
110
880
111
0
580
0
569
0
767
0
680
1,949
105
1
0
31,897
111
65
348
1
7,054
23,476
45,285
103
14,159
19,631
18,915
140
58
334
1
18,940
65,634
68
54
323
1
11,439
45,497
202
86
14
285
1
2,927
27,318
224
1
9,869
17,769
213
1
11,436
7,843
96
36,228
44,904
43,133
32,244
43,187
37,216
4
1,934
3,076
66
46
52
234
415
168
12,490
32,677
18
737
374
256,355
54
44
48
20
150
24,529
-114
31,345
853
78
85
106
1,789
106
Page 1 of 5
5,958
Nov-15
Dec-15
4
5
8,183
19,461
58
193
4
2
7,530
16,926
82
354
46
95
62,421
27,036
4,807
1,678
58
24
1,679
645
126,393
35,531
1,928
96
65,304
7,079
1,162
2,251
45
981
22
249
104,015
27,104
464
45
66
162
56
206
45
63
306
419
15
9,059
6,344
2,731
24,970
288
390
193
2,026
968
404
5,738
76
63
63
4,637
2,893
2,990
19,605
3,839
46
185
6
26,019
3,052
2,222
198
16
23,811
3,827
213
4
18,943
3,557
2
253
265
14
2
72
13,448
5,674
9
533
707
101
748
110
750
101
1,294
109
661
116
968
648
1,411
118
0
7,384
0
636
0
577
361
613
761
581
220
8
311
601
72
167
604
618
388
129
214
1
2,691
24,449
213
1
16,147
39,182
99
1
16,108
54,909
147
1
14,347
41,227
816
100
1
3,376
40,083
502
4
3
3
1,327
15
46
204
219
1
10,273
16,193
5
5
154
14,187
9,832
7
858
109
Annual
60
58
84,936
224,896
367
5,545
1,578
2,449
2,459
659,620
294,930
109,221
18,485
1,115
49,216
27,567
4,507
1,487,009
408,031
68
6,265
-4,009
347
1,202
1,937
690
118,623
307,848
582
3,401
1,765
134,905
212
165
223
134
652
274,766
49,406
163,219
5,574
291
85
106
18,039
1,844
1
2,037
45,503
680
925
177
2,719
12
124,607
403,580
46,101
2,032
84,650
110,898
99,476
NORTHERN NATURAL GAS COMPANY
PERIODIC RATE ADJUSTMENTS FOR FUEL
FUEL CONSUMED DATA - MAINLINE AND STORAGE
JANUARY, 2015 - DECEMBER, 2015
MID
Sec Zone
/1
Mainline
Storage
S2 MID 16 AML
S2 MID 16 AML
S2 MID 16 AML
S2 MID 16 AML
S2 MID 16 AML
S2 MID 16 AML
S2 MID 16 AML
S2 MID 16 AML
S2 MID 16 AML
S2 MID 16 AML
S2 MID 16 AML
S2 MID 16 AML
S2 MID 8
ML
S2 MID 8
ML
S2 MID 8
ML
S2 MID 9
ML
S2 MID 9
ML
S2 MID 9
ML
S2 MID 9
ML
S2 Total
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
S3 MID 17 ML
Station
Number
Station Name
961112
961222
961224
961966
962072
962392
990014
990025
990027
990040
991002
991003
658054
961441
990029
960457
990013
990015
990016
MACKSVILLE UNIT 5 STA FUEL
TESCOTT #2 COMP.STA.TRANS
TESCOTT PLANT DOMESTIC FUEL
MACKSVILLE TBS HEATER FUEL
JETMORE TBS (HEATER FUEL)
BUSHTON TREATER PLT. FUEL
BUSHTON BLOWDOWN PURGE COMPRESSOR
TESCOTT DIST TRANS OP
MACKSVILLE UNMETERED PLT PURGE VENT
MACKSVILLE FLASH VAPOR GAS
MACKSVILLE FLARE FROM CONDENSATE TANK
MACKSVILLE FUEL GAS HEATER
CARGRAY COMPRESSOR FUEL
PAMPA TURBINE (KB) FUEL
PAMPA TURBINE
ROGER MILLS 1
N02 06 UNMETERED
ROGER MILLS CO TRANSMISSION 4130
HEMPHILL CO 3 TRANSMISSION UNS
940391
950901
950902
950903
950904
951901
960479
960480
960481
961012
961016
961017
961018
961023
961051
961054
961056
961057
961059
961060
961061
961062
961133
961134
961135
961136
961137
961138
961139
961141
961142
961143
961152
961153
961154
961156
961158
961159
961160
961161
961162
FT. BUFORD/BEARPAW FUEL METER
Wrenshall VAPORIZER FUEL-FUEL GAS
Wrenshall A TURBINE FUEL GAS
Wrenshall B TURBINE FUEL GAS
VAPORIZER & BUILDING HEAT
GARNER LNG
ALBERT LEA COMPRESSOR STATION FUEL
ALBERT LEA COMPRESSOR BUILDING HEAT
ALBERT LEA COMP FUEL GAS METER
BEATRICE # 2 UNITS 19-25 PLANT
BEATRICE 3 27TURB FUEL
BEATRICE PLANT #1&#2 BOILER FUEL
BEATRICE PLANT DOMESTIC GAS
SOUTH OMAHA HEATER FUEL
CLIFTON COMP FUEL UNIT 27
CLIFTON DOMESTIC FUEL
CLIFTON TURB.BOILER
CLIFTON BOILER BLDG. #3 (RC 4031)
CLIFTON COMP FUEL UNIT 28
CLIFTON COMP FUEL UNIT 29
CLIFTON COMP FUEL UNIT 30
CLIFTON COMP FUEL UNIT 31
OAKLAND COMP #3 ENGINE FUEL
OAKLAND COMP STA AUX FUEL
OAKLAND #1 DOMESTIC FUEL
OAKLAND #2 PIPELINE FUEL
OAKLAND #3 DOMESTIC FUEL
GUTHRIE CENTER COMP FUEL
OAKLAND UNIT #20 BLDG 4
OGDEN AUXILIARY FUEL
OGDEN PLANT #2 FUEL
OGDEN PLANT #3 FUEL
PALMYRA COMPRESSOR BLDG Unit 18
PALMYRA COMPRESSOR BLDG Unit 19
PALMYRA COMPRESSOR BLDG Unit 20
PALMYRA #1 BOILER FUEL
PALMYRA OFFICE FUEL
PALMYRA WAREHOUSE FUEL
PALMYRA FUEL - WORKSHOP BLDG.
PAULLINA COMP.STA.-TRANS
PALMYRA FUEL - WELDING SHOP
Source: Measurement Data warehouse
Jan-15
Feb-15
Mar-15
Apr-15
63
21,269
1,532
58
44
3,170
5,954
71
5,226
457
265
12,294
1,463
893
553
99
256
1
585,033
10,752
1,202
20,114
20,450
64
4,324
59,681
11,949
3,483
51,089
15,890
4,901
156
437
93
997
1,409
567
283
19,741
54,858
24,431
4
102
267
2,684
15,105
23,446
3,239
34,504
46,613
4,583
5,320
7,548
2,303
26
164
6
8,083
46
May-15
Jun-15
78,335
1,817
56
34
4,044
5,232
40
2,985
13
33,533
743
28
32
2,547
3,934
35
2,961
32,836
5
331
20
30
5,536
23
114
8
6
2,406
4
2,021
2,308
22
1,704
217
422
10,146
12
530
452
59
303
1
350,027
9,847
10,225
23,509
23,694
137
9,651
74,461
10,662
4,262
83,349
77,074
4,498
159
423
4,891
86
889
1,261
5,809
6,728
55,532
82,975
59,732
3
98
300
2,294
36,242
72,275
3,048
41,742
44,373
5,655
6,278
10,079
2,006
22
138
26
12,360
48
227
319
12,771
24
529
408
59
302
1
510,458
10,407
5,117
26,091
25,628
107
8,867
25,136
9,587
1,138
67,538
35,698
3,933
78
201
726
50
548
1,098
1,003
2,902
34,395
63,313
44,691
8
76
162
2,062
28,236
34,234
1,854
20,024
49,435
3,174
5,618
8,362
1,801
10
71
6
2,546
28
170
15
-46,844
566
72
32
630
1
126,412
11,629
1,138
24,844
24,618
144
4,846
5
11,949
SCHEDULE 1
Jul-15
Aug-15
Sep-15
39
99
2
4
114
17
38
2
2
1,991
28
1,066
1,840
615
1,238
2,355
36
1,146
183
130
272
15
335
15
372
5
2,140
453
4,546
3,169
159
18
531
87
59
352
1
185,229
14,275
3
531
2
45
341
1
84,082
13,008
531
2
46
362
1
112,109
14,294
9
530
6
536
59
438
1
115,936
16,196
59
414
1
176,006
10,209
50,734
2,877
30
72
1
27
298
2
2
5,268
42,698
21,969
4
18
87
1,405
13,689
7,695
1,221
24,579
33,934
3,132
5,564
6,598
673
6
48
10
1,345
14
Page 2 of 5
12,289
12,169
69
3
9
50
1
1
2
9
60
1
31,359
23,326
30
28,865
17,720
12
10
40,011
36
41,098
17
Oct-15
Nov-15
1,482
4
82
2,650
15
1,523
26
582
22
28
1,099
4,809
7
3,261
1,272
8,764
1766
48
38
13,624
9,010
39
3,548
640
5
430
15
966
30
3
531
24
59
355
1
176,631
14,116
239
18
534
2
59
431
1
157,724
16,409
4
329
348
89
2,123
4,114
60
18
46,281
21
1,025
63
129
42
519
498
59
318
1
163,390
16,469
2,833
17,255
16,998
186
5,629
38,308
192
383
47,994
1,171
6,803
127
323
40
444
829
62
712
667
7,830
11,995
11
70
165
1,622
11,999
10,674
4
110
273
3,296
6,915
2,264
29,919
36,041
1,940
3,003
3,225
1,367
14
68
10
65
26
2,825
18,944
41,791
3,788
3,430
1,494
2,564
24
143
18
456
48
75
479
51,848
105
3
9
27
3
244
21
3
6
9
13
6
11,783
1,352
2
24
45
830
7,746
3
45
22,015
35,096
9,469
7,412
3
9
8
2,742
4
12
3
8
25,528
39,968
461
2,501
4,925
7
4
6
6,318
39,622
2,211
5,271
4,276
19
13
1,557
2,427
6
2
9
1,848
5,354
7
4
12
2,379
5,918
715
2
37,634
43,640
6,358
3,944
6,645
33,740
35,778
5,149
6,159
6,941
2
2
10
6
30
11
435
170
2
8
6
2
Dec-15
4
12
3,911
10,166
27,208
2
26
66
365
25,358
7,482
835
43,018
42,156
1,398
2,027
4,239
4
12
14
22
12
Annual
59,075
142,096
7,067
242
218
24,489
44,629
1,365
31,225
3,169
4,428
1,231
-11,633
1,598
6,761
2,100
694
4,502
12
2,743,037
157,611
20,758
124,431
123,905
873
35,933
201,766
44,399
9,284
563,492
130,042
24,040
631
1,681
5,875
375
3,590
5,565
7,844
10,106
118,847
279,770
209,833
58
538
1,404
14,561
153,587
145,850
15,341
337,965
488,447
37,849
58,584
71,744
10,714
108
646
106
24,899
228
NORTHERN NATURAL GAS COMPANY
PERIODIC RATE ADJUSTMENTS FOR FUEL
FUEL CONSUMED DATA - MAINLINE AND STORAGE
JANUARY, 2015 - DECEMBER, 2015
MID
Sec Zone
/1
Mainline
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
S3
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
MLSTO1
ML
ML
ML
ML
ML
ML
ML
ML
ML
MLSTO1
MLSTO1
MLSTO1
MLSTO1
MLSTO1
ML
MLSTO1
MLSTO1
ML
ML
MLSTO1
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
MID 17
Storage
Station
Number
961163
961165
961166
961167
961168
961169
961170
961171
961172
961175
961176
961177
961178
961181
961230
961231
961232
961233
961234
961235
961236
961237
961243
961246
961248
961251
961261
961268
961306
961381
961382
961461
961471
961561
961562
961565
961961
962434
964003
964004
964096
964097
964101
969044
990000
990011
990017
990018
990021
990024
990032
990037
990046
990052
990053
990054
990055
990056
990057
990058
990059
Station Name
PALMYRA FUEL - EQUIPMENT BLDG.
PALMYRA COMPRESSOR BLDG Unit 21
PALMYRA COMPRESSOR BLDG Unit 22
PALMYRA COMPRESSOR BLDG Unit 23
PALMYRA COMPRESSOR BLDG Unit 24
PALMYRA COMPRESSOR BLDG Unit 25
PALMYRA COMPRESSOR BLDG Unit 26
PALMYRA COMPRESSOR BLDG Unit 27
PALMYRA COMPRESSOR BLDG Unit 28
PALMYRA COMPRESSOR BLDG Unit 29
HOMER COMPRESSOR STATION FUEL
FREMONT COMPRESSOR STATION FUEL
WILLOW LAKE COMPRESSOR STATION
SO SIOUX CITY COMP STA-TRANS
VENTURA DOMESTIC FUEL
VENTURA COMPRESSOR STA TRANS 11
VENTURA COMPRESSOR STA TRANS 12
VENTURA COMPRESSOR STA TRANS 13
VENTURA COMPRESSOR STA TRANS 14
VENTURA COMPRESSOR STA TRANS 15
VENTURA COMPRESSOR STA TRANS BF 16
VENTURA A LINE HEATER FUEL
WATERLOO COMPRESSOR FUEL
EARLVILLE CSO STATION-EAST LEG
FARIBAULT MN COMPRESSOR STATION
FARMINGTON COMP FUEL UNITS 1-7
WATERLOO COMP.STA.-TRANS.
GARNER CONTROLLER GAS
CUNNINGHAM UGS LIQ.PLT FUEL
NO.BRANCH COMP.STA.-TRANS
HUGO COMP FUEL
CARLTON COMP ENGINE FUEL 1&2
OWATONNA COMP STA TRANS
GALENA COMPRESSOR STATION
GALENA COMP. AUXILIARY
BELLVILLE COMPRESSOR PLANT
CARLTON WHSE FUEL *
CLARK S.D. WAREHOUSE
MACKS 1-CUNN STO SER
MACKS 5-CUNN STO SER
CUNN STORAGE COMP.UNIT #8 FUEL
CUNN STORAGE COMP.UNIT #9 FUEL
CUNNINGHAM UGS - PLANT
OGDEN REDFIELD FUEL TRANS UNIT 7
CUNNINGHAM UGS FIELD SEPERATORS
CUNNINGHAM UNMETERED GATH
HUBBARD COMPRESSOR UNMETERED
EARLVILLE COMPRESSOR UNMETERED
CUNN UNMETERED TRANS
CLIFTON DIST TRANSMISSION
GARNER LNG
CLIFTON DISTRICT TRANS SOUTH
ALBERT LEA COMPRESSOR UNM GAS LOSS
CARLTON GAS UNMETERED
WRENSHALL UNMETERE 504
OWATONNA UNMETERED VENT 504
FARIBAULT COMPRESSOR UNS
SOUTH OMAHA UNMETERED T
OAKLAND UNMETERED GAS
SO SIOUX CITY UNMETERED
VENTURA SOUTH UNMETERED
Source: Measurement Data warehouse
Jan-15
Feb-15
Mar-15
Apr-15
38
4,176
6,654
6,109
4,093
7,903
38,956
8,808
12
4,698
6,813
5,230
7,201
7,775
33,190
20,968
5,651
328
32
4,882
3,914
8,758
10,357
6,823
77,756
608
7,765
18,247
3,966
746
8,634
23,218
435
91
8,078
27,714
1,037
34
236
366
1,381
1,950
3,910
10,032
17,295
4,185
826
50,363
15,919
94,390
25,337
888
328
299
25,085
19,996
10,788
46,724
24,881
327
1,550
257
44
142
386
4,488
5,782
6,260
23,968
26,290
4,036
649
63,375
24,244
86,629
26,103
156
280
278
17,554
19,609
17,261
56,757
23,285
278
2,684
319
30
117
203
2,674
2,883
4,763
20,209
21,025
3,047
691
37,252
7,599
90,679
27,861
126
376
279
24,998
22,132
16,097
32,538
21,186
296
10,657
64
18
56
140
1,761
1,244
1,830
6,519
14,081
1,580
749
33,118
21
57,048
20,661
96
272
246
17,974
8,178
6,002
5,433
24,565
75
22,866
232
8
5,088
4,864
2,419
5,436
19
131
516
1,445
197
62
341
2,344
4
4,411
740
8,155
46
2,713
4,499
2,349
1,267
1,530
2,957
3,454
2,443
5,704
11
138
497
480
273
69
148
3,289
313
3,937
298
6,848
52
2,542
3,840
1,480
1,022
1,404
690
922
2,314
2,524
20
267
445
721
157
68
183
3,968
197
5,046
421
8,193
51
2,505
4,305
2,424
1,261
May-15
6
3,513
3,214
4,160
5,102
8,136
8,978
3,933
3,729
1,982
4,837
14
1,170
3,836
202
69
172
2,829
91
2,330
261
5,078
166
1,279
3,376
956
1,040
Page 3 of 5
Jun-15
SCHEDULE 1
Jul-15
Aug-15
4
4,891
2,111
1,252
2,101
3,699
736
1
7,838
28,056
864
25
2,461
5,127
25,818
114
5
1,335
15,156
297
12
46
6
6
4
8
143
2
2,420
2,461
450
1,014
537
305
6
104
22,248
44,354
897
74,040
13,592
11,243
23,150
12
275
246
11,806
11,132
54
312
221
10,359
23,309
42
304
242
6,958
2
2,273
1,914
1,625
4,924
4
175
56
93
165
66
105
3,082
4
1,884
316
6,333
53
1,148
3,346
680
735
156
236
1,234
305
1,879
29,724
6
6
2
6
4
8
48
1,607
6,845
48
21,403
152
8
Sep-15
24
3
9
7,308
54
21,096
4
28
14,302
36
20,478
22,469
1,228
19,994
42
296
222
4,588
486
22,304
27
23,125
3,907
2,510
1,611
3,170
2,142
113
1,830
1,895
27,698
527
1
Oct-15
4
1,619
5,390
5,263
3,573
6,681
26,096
8,382
1
27,971
6
315
16
54
4
6
14
15
34
56
56
3
75
346
2,896
787
28,135
1,163
299
28,549
6
232
237
6,315
1
37
117
12,703
18
26,839
16
38,356
2,266
1,460
26,103
30
240
267
15,068
48
2
11,203
1,198
6
23,978
200
2
1,991
1,565
1,080
3,329
3
475
57
127
142
66
357
1,287
265
1,843
408
2,744
50
1,481
1,960
712
507
6,158
6,337
609
3,327
449
4,761
5,146
357
0
155
57
470
301
69
74
5,638
2
2,778
563
2,765
52
1,450
2,249
689
582
1
157
55
28
166
66
372
1,235
4
2,153
182
10,166
117
1,521
2,325
669
605
45
2,196
3,258
1,337
276
104
158
4
80
326
66
365
1,557
136
2,258
276
2,776
240
4,180
2,505
681
628
1,647
1,271
680
878
3
340
14
316
364
64
78
2,360
4
2,302
269
4,668
334
2,365
3,109
2,536
850
Nov-15
Dec-15
18
2,831
4,393
1,534
1,019
3,372
50,524
1,129
7,564
13,921
28
39
39
90
223
115
194
692
806
2,293
2,249
511
23,423
32
4,693
3,240
4,627
2,002
223
28,504
7,590
1,276
22,714
801
93
410
123
254
1,841
959
1,790
9,174
12,343
3,422
692
26,882
31,174
17,920
126
232
279
8,011
3,625
9,130
13,970
23,449
177
4,808
84
2
79,214
16,909
180
296
312
7,888
6,579
15,988
18,723
32,399
318
1,809
24
2
690
306
1,182
1,114
10
291
37
133
95
63
78
2,549
4
2,465
304
5,240
125
2,315
3,562
-289
889
1,487
1,901
3,637
9
481
245
530
259
64
893
3,029
269
2,543
284
7,124
182
2,457
3,660
2,067
1,057
Annual
148
39,887
44,635
40,964
37,836
45,614
264,117
30,809
49,513
281,205
13,732
1,368
764
808
1,698
12,274
13,031
19,410
71,110
96,608
19,315
4,222
360,110
180,849
442,121
267,028
1,758
3,443
3,128
156,604
80,170
75,308
187,595
214,425
1,660
181,293
1,352
114
3,372
5,579
34,933
32,746
18,604
28,850
94
3,938
1,983
8,259
2,647
792
3,166
33,167
1,293
33,950
4,322
70,090
1,468
25,956
38,736
14,954
10,443
NORTHERN NATURAL GAS COMPANY
PERIODIC RATE ADJUSTMENTS FOR FUEL
FUEL CONSUMED DATA - MAINLINE AND STORAGE
JANUARY, 2015 - DECEMBER, 2015
MID
Sec Zone
/1
Mainline
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 MID 17
S3 Total
ST MID 17
ST MID 17
ST MID 17
ST MID 17
ST MID 17
ST MID 17
ST MID 17
ST MID 17
ST MID 17
ST MID 17
ST MID 17
ST MID 17
ST MID 17
ST MID 17
ST MID 17
ST MID 17
ST MID 17
ST MID 17
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
ML
990060
990061
990062
990063
990064
990065
990066
990067
990068
990069
990070
990071
990072
990073
990074
990075
990076
990077
990078
990079
990080
990081
990082
990083
990084
990085
990086
990087
990088
990089
990090
990091
990092
990093
990095
990097
990098
990099
990100
990101
990103
990104
NEGUANEE UNMETERED HTR AUX FUEL 5
WATERLOO DOWNSTREAM HEATER FUEL
FARMINGTON UNMETERED VENT RC 4008
NORTH BRANCH HEAT AUX FUEL RC 4004
NORTH BRANCH UNMETERED VENT RC4004
NORTH BRANCH UNMETERE HEAT AUX RC40
POPPLE CREEK UNMETERED
VENTURA NORTH UNMETERED
PLATTEVILLE UNMETERED TBS HEATERS
CLARK SD UNMETERED 547
VENTURA ANALYZER PURGE GAS
OGDEN GAS UNMETERED 504 RC4010
OGDEN UNMETERED DETAIL 547 RC4010
WATERLOO DOWNSTREAM PIPELINE GAS LO
LACROSSE BRANCHLINE COMPRESSOR
SPRING GREEN COMPRESSOR UNMETERED
HUGO MN COMP BLOW DOWN
BEATRICE UNMETERED
OAKLAND UNMETERED GAS USES
WATERLOO COMPRESSOR UNMETERED
WELCOME NORTH UNMETERED GAS VENTED
NORTH BRANCH UNMETERED VENTED RC400
WILLMAR UNMETERED VENTED RC4290
PAULLINA UNMETERED VENTED GAS RC 42
PALMYRA UNMETERED PIPELINE RC4024
OGDEN UNMETERED VENTED RC4012
HARRISBURG UNMETERED
PLATTEVILLE UNMETERED VENTED RC4415
PALMYRA UNMETERED PIPELINE RC4029
WELCOME MEAS STA 1 NB INTER UNS
LACROSSE SYSTEM ZONE 5
MAINLINE HOOPER SOUTH
WATERLOO UPSTREAM HEATER FUEL
WELCOME SOUTH UNS SECTION 3 SEG 2
BOTTLE TRUCK SOUTH SIOUX CITY
PIERZ COMPRESSOR UNMETERED
ALEXANDRIA COMPRESSOR UNMETERED
ST CLOUD PIPELINE UNMETERED
OGDEN UNMETERED TBS HEATERS RC4012
WATERLOO UPSTREAM PIPELINE UNS
HOMER COMPRESSOR STATION USN
FREMONT COMPRESSOR STATION UNS
MLSTO1
STO
STO
MLSTO1
MLSTO1
STO
STO
STO
STO
STO
STO
MLSTO1
MLSTO1
MLSTO1
STO
STO
MLSTO1
MLSTO1
961306
964001
964002
964003
964004
964005
964006
964013
964014
964042
964051
964096
964097
964101
969042
969043
990000
990011
CUNNINGHAM UGS LIQ.PLT FUEL
REDFIELD LAGOON SEPARATOR EAST VENT
REDFIELD LAGOON SEPARATOR WEST VENT
MACKS 1-CUNN STO SER
MACKS 5-CUNN STO SER
CRASE 1 GAS LIFT
MAHER 5 GAS LIFT
REDFIELD #1 COMP. FUEL WEST RUN
REDFIELD DEHY FUEL
REDFIELD H2S TREATER FUEL
REDFIELD DOMESTIC FUEL
CUNN STORAGE COMP.UNIT #8 FUEL
CUNN STORAGE COMP.UNIT #9 FUEL
CUNNINGHAM UGS - PLANT
REDFIELD FUEL UNIT 5
REDFIELD FUEL UNIT 6
CUNNINGHAM UGS FIELD SEPERATORS
CUNNINGHAM UNMETERED GATH
Storage
Station
Number
Station Name
Source: Measurement Data warehouse
Jan-15
Feb-15
Mar-15
Apr-15
May-15
4,716
1,524
15,839
578
1,234
34,697
12
5,186
2,965
1,104
7,659
1,761
15,029
1,205
1,136
39,736
65
7,040
3,012
1,059
4,868
1,229
11,161
477
1,275
27,250
110
4,026
2,180
822
3,157
1,348
7,454
211
1,241
13,494
10
3,240
1,448
597
3,084
702
4,718
119
1,171
8,774
5
3,154
1,074
538
3,153
117
1,193
201
110
4,485
1,225
1,128
508
5,582
392
9,039
2,344
868
2,176
7,096
3,132
2,291
32
2,357
918
3,371
3,632
3,366
111
3,116
143
109
4,316
1,253
1,239
642
5,534
385
9,029
2,649
1,877
2,055
5,933
3,140
1,453
32
2,371
925
3,578
3,520
3,167
73
2,115
124
109
3,173
1,282
939
551
4,039
392
6,796
1,841
869
22,854
5,100
2,904
2,073
32
1,757
647
2,853
2,826
3,514
43
2,661
83
1,209
604
740
3,468
3,055
416
5,564
1,853
752
9,570
3,556
3,134
2,950
32
1,216
176
2,236
2,003
3,420
21
1,186
95
18
29
1,370
664
776
2,347
609
4,052
1,582
586
2,077
3,314
3,301
2,257
32
983
175
2,201
1,781
8
18
3,148
875
221
8
18
2,671
2,113
222
720,555
306
4,714
15
49
4
9
9
14
6,344
6,256
4,873
5,919
5,437
5,875
219
220
220
253
76
80
1,096,081 1,535,113 1,143,251
373
347
347
3,069
3,054
2,283
7,826
2,302
4,391
1,752
394
376
38,086
9,229
2,636
718
861
1,150
2,885
39,640
25
333
558
710
28,034
6,538
2,337
944
6,345
6,067
3,018
24,453
4,294
23
163
Jun-15
SCHEDULE 1
Jul-15
3,024
621
3,436
63
1,579
6,363
70
2,599
943
474
Aug-15
Sep-15
1,923
2,025
2,892
8,007
58
1,500
6,467
5
2,571
953
451
3,856
9,195
1,150
7,494
5
2,583
957
444
3,509
80
1208
6,994
5
2,541
934
487
Oct-15
4,287
902
7,826
246
1,151
10,232
65
6,690
1,375
590
3,513
3,703
3,313
3,247
2,783
1,981
104
2,176
94
1,904
83
3,293
91
134
783
589
566
2,217
19,655
3,394
1,511
442
2,073
2,282
6,992
1,082
32
902
178
2,634
1,595
495
595
3,435
699
2,691
400
3,495
970
718
2,083
723
2,964
4,215
32
872
178
2,035
1,789
263
815
591
1,014
2,555
411
4,074
1,608
410
4,086
747
3,066
3,754
32
860
172
1,986
2,132
28
18
1,491
538
223
433,987
307
46
18
1,489
584
224
102
41
373,875
275
26
691
1,924
1,794
2,342
11,623
3,613
1,761
427
2,075
1,282
4,102
2,310
32
880
171
1,878
1,697
3
3
41
1,877
528
1,147
2,258
145
110
494
998
697
1,153
3,010
521
5,313
1,606
466
2,336
3,474
3,114
3,374
32
1,121
169
2,254
5,794
304,750
302
20
387,876
277
20
394,481
296
17
930
1,448
4,150
559
56
2,738
19,023
15
239
135
5,938
6,418
445
32,796
22,493
38
153
30
4,063
1,668
344
33,805
79
1,909
199
256
17,804
4,931
2,335
730
3,688
4,308
3,047
2
645
5,086
3,018
1,818
198
4,906
4,650
2,473
1,771
1,427
175
2,835
2,388
2,026
2,099
1,343
118
2,484
1,951
1,347
5,671
14
173
4,381
17
1,459
3,771
4
219
3,439
3
592
Page 4 of 5
16
18
1,571
592
1,152
49
23
2,787
1,163
221
25
Nov-15
5,645
1,116
8,300
510
1,158
19,838
4,125
1,828
789
6
2,653
90
1,342
116
110
1,542
1027
860
795
3,462
409
6,048
1,672
820
2,017
4,889
3,310
2,499
32
1,322
901
2,502
2,654
548,436
332
9
3,862
4,276
1,132
24
19
528,826
348
21,175
402
563
88
2,055
1,586
848
36,733
1,589
4
423
16,164
6,147
1,198
262
861
382
1,474
28,731
2,061
12
363
Dec-15
5,886
1,365
10,232
550
1363
27,185
8
4,325
2,201
1,031
2,612
128
1,357
179
109
1,236
1226
1,050
1,153
4,547
411
7,746
2,018
823
2,014
7,528
3,842
2049
32
1,632
1,179
2,784
3,465
4
9
6,649
3,739
1,145
95
714,320
389
4,078
11,356
286
6
1,194
1,237
143
7,680
7,903
759
660
3,506
1
193
1
196
197
23,889
9,068
2,740
516
1,855
2,372
4,537
35,694
12
600
Annual
49,166
10,568
99,367
13,292
15,166
208,524
360
48,080
19,870
8,386
6
38,444
583
24,582
1,458
675
17,402
11,869
13,856
13,119
41,381
35,624
68,163
21,415
9,058
55,416
45,924
43,001
30,307
384
16,273
5,789
30,312
32,888
3
230
204
43,018
31,639
6,346
499
256
8,181,551
3,899
12,484
32,984
4,206
6,958
1,153
2,273
191,760
44,450
18,026
4,057
43,571
40,843
23,203
232,512
28,791
116
4,911
NORTHERN NATURAL GAS COMPANY
PERIODIC RATE ADJUSTMENTS FOR FUEL
FUEL CONSUMED DATA - MAINLINE AND STORAGE
JANUARY, 2015 - DECEMBER, 2015
MID
Sec Zone
/1
Mainline
ST MID 17
ST MID 17
ST MID 17
ST MID 17
ST MID 17
ST MID 17
ST Total
Grand Total
STO
MLSTO1
STO
STO
STO
STO
Foot
notes
1/
Storage
Station
Number
990020
990021
990047
990048
990049
990050
Station Name
Source: Measurement Data warehouse
Jan-15
Feb-15
Mar-15
Apr-15
May-15
Jun-15
SCHEDULE 1
Jul-15
Aug-15
Sep-15
Oct-15
Nov-15
Dec-15
Annual
LYONS UNMETERED
CUNN UNMETERED TRANS
REDFIELD ST PETER PLANT UNMETERED
REDFIELD MT SIMON PLANT UNMETERED
REDFIELD MT SIMON UNMETERED
REDFIELD ST PETER UNMETERED
20
13
10
195
246
340
253
509
501
512
510
1,286
1,134
741
740
16,519
6,090
5,576
3,101
11,417
6,400
6,184
5,977
139,279
103,578
65,452
44,264
1,944,810 2,106,149 1,841,574 1,005,401
205
515
740
677
1,801
19,164
753,111
8
178
513
793
540
1,949
18,562
581,084
456
375
750
751
1,250
1,980
30,594
589,947
11
207
509
1369
122
379
72789
709774
1001
407
492
1829
148
155
69992
768785
1085
453
491
1326
36
171
69360
949328
1,092
118
489
1,310
2,987
4,279
68,278
881,221
1,818
5,514
323
3,300
493
6,284
745
12,764
23,062
60,108
14,087
54,779
137,634
838,946
1,119,359 13,250,543
Total Mainline Fuel
Total Storage Fuel
Total Fuel
1,805,531 2,002,571 1,776,122
961,137
139,279
103,578
65,452
44,264
1,944,810 2,106,149 1,841,574 1,005,401
733,947
19,164
753,111
562,522
18,562
581,084
559,353
30,594
589,947
636,985
72,789
709,774
698,793
69,992
768,785
879,968
69,360
949,328
812,943
68,278
881,221
981,725 12,411,597
137,634
838,946
1,119,359 13,250,543
S1 = Section 1 Mainline Facility Fuel.
S2 = Section 2 Mainline Facility Fuel.
S3 = Section 3 Mainline Facility Fuel.
ST = Storage Fuel.
Page 5 of 5
Northern Natural Gas Company
Periodic Rate Adjustments for Fuel
Summary of Annual MID 1-17 Mainline Throughput Mid to Mid
Schedule No. 2
Annual Transactions from January, 2015 - December, 2015 for Mainline Fuel
Page 1 of 2
Receipt
MID
D1
D2
D3
D4
D5
D6
D7
D7B
D8
D9
D10
D11
SECTION 1 - SECTION 1
R01
R02
R03
R04
R05
R06
R07
R7b
-
-
-
-
32,492,596
640,653
241,362
40,792,545
-
1,639,534
429,105
545,426
-
92,792
354,251
-
D12
D13
D14
D15
1,787,491
8,390,893
2,091,127
3,995,372
112,998
2,360
906,773
9,683,335
33,239
2,498,761
-
-
-
-
-
SECTION 2 - SECTION 1
-
-
-
-
-
14,424
26,539
381,288
79,197
74,644
47,878
-
52,998
40,000
17,999
229,254
7,500
7,499
9,140
10,044
MID 8-16A
Rec=MID 16B
2,413,658
185,903
901,033
59,998
4,391,758
167,238
-
452,305
98,269
12,121
-
47,981
162,134
14,694
-
86,200
3,409,266
193,507
44,528
-
SECTION 3 - SECTION 1
R17
-
-
-
-
-
50,378
901,967
-
-
-
33,334
180,803
110,284
2,385,525
4,013,660
-
-
SECTION 1 SECTION 3
-
-
-
74,668,604
Source: Northern's Accounting System.
2,736,587
558,040
6,781,137
1,652,230
4,453,114
13,453,102
26,339,583
-
-
-
-
-
-
-
-
16,643,678
16,682,700
-
562,695
224,809
3,733,501
952,345
-
6,723,606
-
-
43,700,323
20,796,216
6,818,842
61,639,457
112,998
2,360
-
SECTION 2 SECTION 3
-
-
-
543
126,204
355,366
135,121
1,587
105,014
404,240
96,813
15,870,118
44,621,879
69,730,730
9,304,936
28,707,660
6,366,566
759,219
MID 7B-16A
Rec=MID 16B
13,421,844
175,361,108
-
-
-
217,584,844
217,584,844
19,229,065
44,703,899
74,056,200
10,537,509
33,276,658
10,612,160
759,219
217,752,082
SECTION 3 SECTION 3
-
Total
MID 8-16A
MID 16B
SECTION 3 - SECTION 2
-
Annual
Total
D17
SECTION 2 - SECTION 2
R7b
-
D16b
SECTION 1 - SECTION 2
106,730,613
R08
R09
R10
R11
R12
R13
R14
R15
R16a
R16b
D16a
617,234
607,654
201,700,691
676,288,687
676,288,687
676,288,687
893,873,531
1,220,285,675
Northern Natural Gas Company
Periodic Rate Adjustments for Fuel
Summary of Annual MID 1-17 Mainline Throughput Mid to Mid
Schedule No. 2
Annual Transactions from January, 2015 - December, 2015 for Mainline Fuel
Page 2 of 2
Point Exceptions: Throughput from these receipt points to MIDs 1-7
are excluded from Section 2 fuel derivation on Schedule 3 (Tariff Sheet No. 54A).
150
MID 16 A
NNG/Williams Barton
475 & 62997 MID 8
Westar/NNG Carson
179 & 78287 MID 13
ANR/NNG Greensburg
60667 & 78284 MID 8
NNG/TW Gray ITE
17,488
61491
MID 9
NNG/Warren Canadian
71214 & 78292 MID 16 A
NNG/KN Tescott Pony Express
71363
MID 9
NNG/Bingham Hemphill
71394
MID 9
NNG/Crescendo Hemphill
34,039
71432
MID 16 A
MCMC/NNG Rice County ITE
78441 & 78883 MID 13
Cheyenne Plains Interconnect
499,987
78643 & 78902 MID 8
Enbridge-Pampa Interconnect
2,767,490
3,319,004
Source: Northern's Accounting System.
Point Exceptions: Throughput from MIDs 1-7 to these delivery points
are excluded from Section 2 fuel derivation on Schedule 3.
Delivery
475
MID 8
Westar/NNG Carson
4891
MID 8
WTG-Lark Farm Tap
60667
MID 8
NNG/TW Gray ITE
35402
MID 8
Damson/Crawford
35706
MID 8
Phillips/NNG Carson
55610
MID 8
North Texas Gas/NNG Farm Tap
56111
MID 8
Cabot/NNG Bryan Carson
0
Northern Natural Gas Company
Periodic Rate Adjustments for Fuel
Calculation of Base Mainline Fuel Percentages
Schedule No. 3
Annual Transactions from January, 2015 - December, 2015 for Mainline Fuel
Mainline Fuel
(A)
Section 1 (1-7)
Section 2 (8-16a)
Section 2 (16b)
Section 3 (17)
Total
(B)
Section 1 (1-7)
106,730,613
4,391,758
167,238
111,289,609
Section 1
Section 2
Section 3, Apr-Oct
Total
Fuel Consumed
1,487,009
2,743,037
3,163,960
7,394,006
(C )
Section 2 (8-16a)
13,421,844
13,421,844
2/
3/
4/
Throughput
137,629,192
216,195,289
438,498,426
792,322,907
Backup:
1
Section 1-1
Section 2-1
Section 2(16b)-1
Section 3-1
Section 1-2
Section 1-2(16b)
Section 1-3
2
Section 2-1
Section 2(16b)-1
Section 3-1
Section 1-2
Section 2-2
Section 2(16b)-2
Section 3-2
Section 1-2(16b)
Section 2-2(16b)
less exempt POIs
Section 1-3
Section 2-3
3
Section 1-3
Section 2-3
Section 2(16b)-3
Section 3-3
1/
2/
3/
4/
5/
6/
7/
8/
Throughput
106,730,613
4,391,758
167,238
26,339,583
137,629,192
Section 1 (1-7)
Section 2 (8-16a)
Section 2 (16b)
Section 3 (17)
Total
5/
6/
7/
(E)
Section 3 (17)
217,584,844
676,288,687
893,873,531
(F)
Total
133,070,196
193,174,710
217,752,082
676,288,687
1,220,285,675 1/
Percentage
1.08%
1.27%
0.72%
Matrices linked to numbers in Column B
Section 1 (1-7b) Section 2 (8-16a)
Section 2 (16b)
Section 3 (17)
106,730,613
26,339,583
4,391,758
167,238
111,289,609
-
26,339,583
-
Total
133,070,196
4,391,758
167,238
137,629,192
5/
5/
Throughput
4,391,758
Section 1 (1-7b)
Section 2 (8-16a)
less exempt POIs
13,421,844
Section 2 (16b)
Section 3 (17)
Total
26,339,583
175,361,108
(3,319,004) 8/
216,195,289 6/
Throughput
217,584,844
676,288,687
893,873,531
(D)
Section 2 (16b)
26,339,583
175,361,108
201,700,691
Section 1 (1-7b) Section 2 (8-16a)
4,391,758
13,421,844
4,391,758
13,421,844
Apr-Oct
Section 3 (17)
Section 1 (1-7b)
Section 2 (8-16a)
Section 2 (16b)
Section (17)
Total
See Schedule No. 2.
See Schedule No. 1, subtotal S1 for MIDs 1-7.
See Schedule No. 1, subtotal S2 for MIDs 8-16B.
See Schedule No. 1, subtotal S3 for MID 17, April-October.
Section 1 Throughput.
Section 2 Throughput.
Section 3 April - October Throughput.
See Point Exceptions on page 2 of Schedule No. 2.
91,837,382
346,661,044
438,498,426
Section 2 (16b)
26,339,583
175,361,108
(3,319,004)
198,381,687
Nov-Mar (not used)
Section 3 (17)
125,747,462
329,627,643
455,375,105
Section 3 (17)
-
-
Total
Section 3 (17)
217,584,844
676,288,687
893,873,531
Total
26,339,583
193,174,710
(3,319,004)
216,195,289 /6
/7
Northern Natural Gas Company
Periodic Rate Adjustments for Fuel
Allocate Retained Fuel by Section
Schedule 4
Annual Transactions from January, 2015 - December, 2015 for Mainline Fuel
Apr-Oct
Fuel %
Charged:
Rec
Del
Fuel Retained
W/ Summer(April-October) Market fuel rate
Section 1
Section 1
688,025
Section 1
Section 2
Section 1
Section 2 (16b)
202,282
Section 2
Section 1
30,388
Section 2
Section 2
149,584
Section 2
Section 2 (16b)
1,657,049
Section 2 (16b) Section 1
Section 2 (16b) Section 2
Section 2 (16b) Section 2 (16b) /2
14,158
Section 2 (16b) Section 3
569,182
Section 3
Section 1
Section 3
Section 2
Section 3
Section 2 (16b)
Section 3
Section 3
2,142,694
Total
Summer
0.0097
0.0289
0.0289
0.0289
0.0192
0.0192
0.0097
0.0192
0.0192
0.0062
0.0097
0.0192
0.0192
0.0062
0.0097
0.0192
Section 1 Section 2
0.0097
0.0097
0.0097
0.0097
0.0062
Market
0.0192
0.0192
0.0192
0.0192
0.0192
0.0097
0.0192
0.0192
0.0062
0.0097
0.0192
0.0192
0.0062
5,453,362
W/Jan-Mar & Nov-Dec Market Fuel rates
Section 1
Section 1
Section 1
Section 2
Section 1
Section 2 (16b)
Section 2
Section 1
Section 2
Section 2
Section 2
Section 2 (16b)
Section 2 (16b) Section 1
Section 2 (16b) Section 2
Section 2 (16b) Section 2 (16b) /2
Section 2 (16b) Section 3
Section 3
Section 1
Section 3
Section 2
Section 3
Section 2 (16b)
Section 3
Section 3
Reverse fuel from Sec 2 exceptions
Move fuel to Section 1
/3
Total
Winter
Annual Total
Fuel%
422,927
545,400
34,857
91,306
1,340,260
1,624
1,624
1,648,055
4,237,527
-34,293
34,293
8,323,580
0.0097
0.0289
0.0289
0.0289
0.0192
0.0192
0.0097
0.0192
0.0192
0.0062
0.0097
0.0192
0.0192
0.0062
0.0289
0.0097
0.0097
0.0097
0.0097
0.0097
0.0192
0.0192
0.0192
0.0192
0.0192
0.0097
0.0192
0.0192
0.0062
0.0097
0.0000
0.0192
0.0192
0.0097
0.0097
0.0192
0.0062
13,776,942
1/ Section 3 fuel retained is calculated seasonally. Winter fuel retained is not used at this time.
2/ Reflects fuel retained on out-of-balance deliveries to 16B and from 7B to 16B.
3/ Only Section 1 fuel is retained for Section 1-2 or Section 2-1 paths described on page 2 of Schedule 2.
MID 1-7
MID 8-16
MID 17 /1
Total
Section 1
Section 2
Market
Retained
688,025
0
67,894
10,199
0
0
0
0
0
0
0
0
0
0
0
0
134,388
20,189
149,584
1,657,049
0
0
14,158
0
0
0
0
0
0
0
0
0
0
0
0
0
0
569,182
0
0
0
2,142,694
688,025
0
202,282
30,388
149,584
1,657,049
0
0
14,158
569,182
0
0
0
2,142,694
766,118
1,975,368
2,711,876
5,453,362
422,927
0
183,058
11,699
0
0
1,624
0
0
0
0
0
0
0
-11,510
34,293
642,091
0
0
362,342
23,158
91,306
1,340,260
0
0
1,624
0
0
0
0
0
-22,783
0
1,795,907
0
0
0
0
0
0
0
0
0
1,648,055
0
0
0
4,237,527
0
0
5,885,582
422,927
0
545,400
34,857
91,306
1,340,260
1,624
0
1,624
1,648,055
0
0
0
4,237,527
-34,293
34,293
8,323,580
1,408,210
3,771,274
8,597,458
13,776,942
Northern Natural Gas Company
Periodic Rate Adjustments for Fuel
Mainline Fuel True-up
Schedule No. 5
Annual Transactions from January, 2015 - December, 2015 for Mainline Fuel
Mainline Fuel
Section 1
Section 2
Apr-Oct
Section 3
Total
Actual Mainline Fuel Consumed 1/
1,487,009
2,743,037
3,163,960
7,394,006
Actual Mainline Fuel Retained 2/
less True-up Under(Over) Recovered 3/
1,408,210
(173,538)
3,771,274
1,064,765
2,711,876
(520,855)
7,891,360
370,372
Actual Mainline Fuel Retained Related to Consumed
1,581,748
2,706,509
3,232,731
7,520,988
Under(Over) Recovered
Total Throughput Applicable to Mainline Fuel 4/
True-up Adjustment Due (Shipper)Northern
(94,739)
137,629,192
-0.07%
36,528
216,195,289
0.02%
(68,771)
438,498,426
-0.02%
1/ See Schedule No. 1.
2/ See Schedule No. 4.
3/ 2014 Mainline Fuel True-up as stated on Schedule No. 5 of Northern's January 29, 2015 fuel filing in
Docket No. RP15-389-000.
4/ See Schedule No. 3.
(126,982)
Northern Natural Gas Company
Periodic Rate Adjustments for Fuel
Mainline Fuel
Effective April 1, 2016
Schedule No. 6
Base Mainline Fuel Percent 1/
Section 1
Section 1
1.08%
Section 2
2.35%
Apr-Oct
Section 3
3.07%
Section 1
1.08%
Section 2
2.35% 4/
1.27%
1.99%
Section 2
1.27%
Section 3
1.08%
1.27%
0.72%
Section 3
0.72%
True-up Mainline Fuel Percent 2/
Section 1
Section 1
-0.07%
Section 2
-0.05%
Apr-Oct
Section 3
-0.07%
Section 1
-0.07%
Section 2
-0.05%
0.02%
0.00%
Section 2
0.02%
Section 3
-0.07%
0.02%
-0.02%
Section 3
-0.02%
Section 1
1.01%
Total Mainline Fuel Percent 3/ 4/
Section 1
Section 1
1.01%
Section 2
2.30%
Apr-Oct
Section 3
3.00%
Section 2
2.30%
1.29%
1.99%
Section 2
1.29%
Section 3
1.01%
1.29%
0.70%
Section 3
0.70%
1/
2/
3/
4/
See Schedule No. 3.
See Schedule No. 5.
Base Mainline Fuel Percent plus True-up Mainline Fuel Percent.
Fuel percent from MID 16B or Exempt Section 2 Points to Section 1 equals the
Section 1 percentage. Exempt Section 1 and 2 points are listed on Schedule 2.
Northern Natural Gas Company
Periodic Rate Adjustment for Fuel
Derivation of Lost and Unaccounted For Percentage for 2016
Schedule 7
Jan-15
(c)
Feb-15
(d)
Mar-15
(e)
Apr-15
(f)
1,138,632
3,505,089
2,070,455
1,335,091
249,705
104,756,838
110,750,219
110,156,963
99,256,255
78,536,330
1,865,479
99,510
1,938,661
102,801
1,939,922
94,231
1,680,613
75,523
107,860,459
116,296,770
114,261,571
102,347,482
79,522,700
70,294,635
72,788,256
76,502,760
76,231,022
77,286,767
85,030,376
82,627,000
1,061,049,798
246,862
341,377
165,903
3,015,356
1,199,298
5,055,433
142,890
2,023
2,374
13,333
51,209
99,985
10,336,043
104,613,608
110,439,146
110,138,651
99,160,690
78,635,143
69,514,169
72,239,530
76,060,397
75,485,775
75,678,574
83,876,424
81,371,968
1,037,214,075
11 Gas Losses/Workorder
12 Fuel Used
13 Condensate
1,086
1,647,663
47
1,753,818
125
2,302,381
420
1,844,283
104
(615)
1,008,124
8,518
27,109
728,318
1
232
610,223
-
592,475
837
709,774
1,356
768,785
2,749
1,786
947,227
1,241
882,246
(372)
29,598
13,795,317
15,026
14 Storage INJ (WD)
1,017,897
3,619,835
2,275,344
(2,142,348)
(1,094,167)
(4,284,675)
(72,250)
(200,252)
(226,518)
1,002,270
478,916
71,394
445,446
107,527,163
116,154,301
114,882,699
79,756,301
71,040,355
77,465,711
85,356,803
82,425,221
1,061,835,505
333,296
142,469
(a)
1 SOURCE
2 Purchase
(b)
3 Transport
4 Fuel Retained
5 Storage Retained
6 UAF Retained
7 Net Receipts/Sources
8 DISPOSITION
9 Operational Sales
10 Transport, IT FT
15 NET DELIVERIES/DISPOSITION
16 ACCOUNTING UAF
(621,128)
101,878,085
469,397
May-15
(g)
806,806
(70,141)
(233,601)
Jun 15 /1
(h)
69,608,734
749,088
(63,187)
(745,720)
Jul-15
(i)
Aug-15
(j)
124,000
7,287
71,901,904
75,639,070
656,145
172,751
(66,544)
72,920,625
(132,369)
722,907
204,071
(70,575)
Sep-15
(k)
75,298,463
775,017
226,794
(69,252)
76,455,480
75,972,761
47,280
258,261
1/ The UAF gain for June, 2015 includes a one-time adjustment of 693,859 Dth reflecting a correction for third party unreported volumes from a prior period.
The base UAF percentage to be effective April 1, 2016 excludes the one-time adjustment.
Oct-15
(l)
Nov-15
(m)
Dec-15
(n)
Total
(o)
375,000
235,000
326,068
9,366,327
75,917,240
83,731,773
81,107,163
1,036,660,952
826,006
240,376
(71,855)
(178,944)
954,982
187,637
(79,016)
1,270,288
3,624
(80,143)
(326,427)
201,779
UAF =
Line (16), Total Column
Remove non-recurring adjustment /1
Divided by:
Throughput =
Line (3) + (4) + (6) Total Column
Base UAF
True-up
UAF Retained
Add 2014 Over recovery
UAF Retained
UAF Actual Jan 2015 - Dec 2015
UAF Over (Under) recovered
14,185,914
1,035,253
(198,648)
(785,707)
(785,707)
693,859
(91,848)
1,050,648,218
-0.01%
2015
(198,648)
1,960,118
1,761,470
(785,707)
2,547,177
Divided by:
Throughput =
Line (3) + (4) + (6) Total Column
1,050,648,218
UAF system-wide adjustment
-0.24%
Effective UAF
-0.25%
Northern Natural Gas Company
Periodic Rate Adjustments for Fuel
Storage Fuel
Schedule No. 8
For the Period January, 2015 - December, 2015
Storage Fuel Consumed
1/
838,946
FDD Injections
58,825,739
Storage Fuel Rate
1.43%
True-up
Actual Storage Fuel Consumed
1/
Actual Storage Fuel Retained
Less prior year True-Up Under(Over) Recovered 2/
Actual Storage Fuel Retained Related To Consumed
Under(Over) Recovered
FDD Injections
Storage Fuel Rate True-up
838,946
1,035,253
56,706
978,547
(139,601)
58,825,739
-0.24%
Total Storage Fuel Percentages
Actual Fuel Rate Percent
True Up Percent
Total Storage Fuel Percentage
1.43%
-0.24%
1.19%
1/ Schedule No. 1
2/ In order to recognize retention to recover the prior year's underrecovery,
such amount must be deducted from the total actual retention.
2014 Storage Fuel-True Up as stated on Schedule No. 8 of Northern's January 29, 2015
annual fuel filing in Docket No. RP15-389-000.
Northern Natural Gas Company
Periodic Rate Adjustments for Fuel
Market Area Electric Compression Charge
Schedule No. 9
Page 1 of 2
For the Period January, 2015 - December, 2015
1 Electric Compression Charges
2 Deliveries to Market area (MID 17)
$462,041 /1
885,548,707 /2
3 Electric Compression Charge
$0.0005
4 True-up
5 Actual Electric Compression Commodity Charge Retained
6 Less prior year True-Up Under(Over) Recovered
7 Actual Electric Compression Charge collected vs. costs
$739,806
323,913 /3
$415,893
8 Under(Over) Recovered (Line 1 less Line 7)
$46,148
9 Electric Compression Rate True-up
$0.0001
10 Total Electric Compression Charge
11 Actual Compression Rate
$0.0005
12 True Up
$0.0001
13 Total Electric Compression Charge
$0.0006
1/ Schedule No. 9 Costs for electric compression at facilities listed below:
Popple Creek, added 10/2003. Spencer added 12/2006.
Chatfield incremental added 1/2007. Spring Green added 1/2008.
Elk River added 11/2011.
2/ Schedule 9, page 2.
3/ In order to recognize retention to recover the prior year's underrecovery,
such amount must be deducted from the total actual retention.
See line 8 of Schedule 9, page 1 of 2 of Northern's January 29, 2015
annual fuel filing in Docket RP15-389.
Northern Natural Gas Company
Periodic Rate Adjustments for Fuel
Market Area Electric Compression Charge
Schedule No. 9
Page 2 of 2
For the Period January, 2015 - December, 2015
Charges
(a)
201501
201502
201503
201504
201505
201506
201507
201508
201509
201510
201511
201512
Total
Total Market
Area
Throughput
(b)
Less Fuel
Retained
(c )
Less UAF
Retained
(d)
Total Market
Throughput
assessed Elec
Compr /1
by acct
Elec Compr
Collected
(f)
71,227.69
94,035.94
111,288.39
86,927.58
9,936.11
8,521.17
13,858.25
9,540.32
7,676.93
4,610.41
24,086.48
20,332.02
105,234,695
104,291,798
85,627,320
64,764,473
56,960,902
59,846,029
62,386,735
61,939,767
62,918,249
69,682,271
70,134,954
90,086,338
1,446,647
1,438,855
1,177,657
397,059
353,005
369,145
387,031
383,326
390,118
432,192
799,133
1,023,290
94,131
93,670
77,027
-58,156
-50,837
-53,250
-56,133
-55,270
-56,575
-62,642
-63,410
-81,189
103,693,917
102,759,273
84,372,636
64,425,570
56,658,734
59,530,134
62,055,837
61,611,711
62,584,706
69,312,721
69,399,231
89,144,237
51,535.64
51,803.71
41,276.39
64,975.97
56,445.23
59,805.48
63,353.78
61,251.54
62,816.76
68,601.18
68,491.95
89,448.50
$462,041.29
893,873,531
8,597,458
-272,634
885,548,707
$739,806.13
1/ Mainline Section 3 throughput per Schedule 2 less fuel and UAF retained.
Northern Natural Gas Company
FERC Gas Tariff
Sixth Revised Volume No. 1
Tenth Revised Sheet No. 50
Superseding
Ninth Revised Sheet No. 50
RATE SCHEDULE TF
FIELD-TOFIELD/MARKET
DEMARCATION
MARKET-TO-MARKET
RESERVATION RATES
TF12
TF12 Base Variable
TF5
TFF___
Base Tariff Rates 1/
Summer (Apr-Oct)
Winter (Nov-Mar)
5.683
10.230
5.683
13.866
-015.153
5.473
9.853
______________________________________________________________________________________________________________
COMMODITY RATES 2/
TF12 Base, TF12 Var., TF5 & TFF
Market Area
Field Mileage 5/ Carlton
3/ 6/ Rate per 100 miles Surcharge 4/
Receipt Point
Delivery Point
Maximum
Minimum
Market
Field
Market
Field
Market
Market
Field
Field
0.0365
0.0365
0.0196
0.0196
Maximum
Minimum
0.0122
0.0122
0.0122
0.0040
0.0040
0.0040
Out-of Balance 3/
Maximum
Minimum
Maximum Minimum
0.0175
0.0175
0.0000
0.0000
0.0365
0.0196
0.0276
0.0090
1/ The minimum reservation rate is equal to zero.
2/ The applicable Mileage Indicator Districts (MIDs) billing rate will be added to the TF rates for volumes
received in the Field Area, or received in the Market Area and delivered to the Field Area. The MIDs rates
shown on Sheet Nos. 59-60A represent the maximum Field Area throughput commodity rates for any transaction
involving MIDs. For volumes transported through Northern’s Ft. Buford compressor station, the commodity
rate, fuel and unaccounted for apply only to volumes that are not ultimately confirmed for re-delivery into
Northern’s Market Area.
3/ The Maximum and Minimum rates include the Market Area Electric Compression charge of $0.0006 where
applicable. In addition, Shipper shall pay the ACA unit surcharge as posted on FERC’s website at
http://www.ferc.gov.
4/ Applicable to Market Area shippers as provided for in the Carlton Settlement filed in Docket No. RP96-347
dated October 28, 1996.
5/ Where applicable, the Field Area Electric Compression charge of $0.0000 and the ACA unit surcharge as set
forth on FERC’s website at http://www.ferc.gov will be added to the mileage based rates.
6/ There will be no commodity charge for transportation from the Ventura pooling point (POI 78623) to the
NBPL/NNG Ventura point (POI 192) and from the Ventura pooling point (POI 78623) to the MID 17 pooling point
(POI 71458). In addition, there will be no commodity charge for transportation as set forth in Sheet Nos.
141, 142C and 147.
Issued On: February 1, 2016
Effective On: April 1, 2016
Northern Natural Gas Company
FERC Gas Tariff
Sixth Revised Volume No. 1
Eleventh Revised Sheet No. 51
Superseding
Tenth Revised Sheet No. 51
RATE SCHEDULES TFX and LFT
MARKET-TO-MARKET
RESERVATION RATES
Base Tariff Rates 1/
FIELD-TO-FIELD___
Apr-Oct
Nov-Mar
Apr-Oct
Nov-Mar_
$5.683
$15.153
$5.473
$9.853_
___________________________________________________________________________________________________________
COMMODITY RATES
TFX and LFT
2/
Receipt Point
Delivery Point
Market
Field
Market
Field
Market
Market
Field
Field
Market Area
Field Mileage 5/
3/ 7/ Rate per 100 miles
Maximum
Minimum
0.0365
0.0365
0.0196
0.0196
Maximum
Minimum
0.0122
0.0122
0.0122
0.0040
0.0040
0.0040
Carlton
Surcharge 4/
Maximum Minimum
0.0175
0.0175
0.0000
0.0000
Out-of-Balance 3/
Maximum
Minimum
0.0365
0.0196
0.0276
0.0090
____________________________________________________________________________________________________________
Reservation 1/
GULF COAST
Other Gulf Coast
1/
2/
3/
4/
5/
6/
7/
Commodity 6/
Out-of-Balance 6/
Maximum
Minimum
Maximum
Minimum
Maximum
Minimum
4.8169
0.0000
0.0000
0.0000
0.0000
0.0000
The minimum reservation rate is equal to zero.
The applicable Mileage Indicator Districts (MIDs) billing rate will be added to the TF rates for volumes
received in the Field Area, or received in the Market Area and delivered to the Field Area. The MIDs rates
shown on Sheet Nos. 59-60A represent the maximum Field Area throughput commodity rates for any transaction
involving MIDs. For volumes transported through Northern’s Ft. Buford compressor station, the commodity
rate, fuel and unaccounted for apply only to volumes that are not ultimately confirmed for re-delivery into
Northern’s Market Area.
The Maximum and Minimum rates include the Market Area Electric Compression charge of $0.0006 where
applicable. In addition, Shipper shall pay the ACA unit surcharge as posted on FERC’s website at
http://www.ferc.gov.
Applicable to Market Area shippers as provided for in the Carlton Settlement filed in Docket No. RP96-347
dated October 28, 1996.
Where applicable, the Field Area Compression charge of $0.0000 and the ACA unit surcharge as set forth on
FERC’s website at http://www.ferc.gov will be added to the mileage based rates.
In addition to the Maximum and Minimum rates, Shipper shall pay the ACA unit surcharge as posted on FERC’s
website at http://www.ferc.gov.
There will be no commodity charge for transportation from the Ventura pooling point (POI 78623) to the
NBPL/NNG Ventura point (POI 192) and from the Ventura pooling point (POI 78623) to the MID 17 pooling point
(POI 71458). In addition, there will be no commodity charge for transportation as set forth in Sheet Nos.
141, 142C and 147.
Issued On: February 1, 2016
Effective On: April 1, 2016
Northern Natural Gas Company
FERC Gas Tariff
Sixth Revised Volume No. 1
Tenth Revised Sheet No. 52
Superseding
Ninth Revised Sheet No. 52
RATE SCHEDULE TI
COMMODITY RATES
Receipt Point
1/
Delivery Point
NOVEMBER - MARCH
Market
Market
Field
Market
Market
Field
Field
Field
APRIL - OCTOBER
Market
Market
Field
Market
Market
Field
Field
Field
Market Area
Maximum
0.6087
0.6087
0.2508
0.2508
2/ 6/
Minimum
0.0196
0.0196
0.0196
0.0196
Field Mileage
Rate per 100 miles 3/
Maximum
Minimum
0.1588
0.1588
0.1588
0.0040
0.0040
0.0040
0.0893
0.0893
0.0893
0.0040
0.0040
0.0040
Carlton
Surcharge
4/
Out-of-Balance 2/
Maximum
Minimum
Maximum
Minimum
0.0175
0.0175
0.0000
0.0000
0.6091
0.0200
0.3589
0.0090
0.2508
0.0196
0.2018
0.0090
0.0000
0.0000
0.0000
0.0000
___________________________________________________________________________________________________________
Commodity
GULF COAST
Other Gulf Coast
1/
2/
3/
4/
5/
6/
5/
Out-of-Balance
5/
Maximum
Minimum
Maximum
Minimum
0.1584
0.0000
0.1584
0.0000
The applicable Mileage Indicator Districts (MIDs) billing rate will be added to the TI rates for volumes
received in the Field Area, or received in the Market Area and delivered to the Field Area. The MIDs rates
shown on Sheet Nos. 59-60A represent the maximum Field Area throughput commodity rates for any transaction
involving MIDs.
The Maximum and Minimum rates include the Market Area Electric Compression charge of $0.0006 where
applicable. In addition, Shipper shall pay the ACA unit surcharge as posted on FERC’s website at
http://www.ferc.gov.
Where applicable, Field Area Compression charge of $0.0000 and ACA unit surcharge as set forth on FERC’s
website at http://www.ferc.gov will be added to the mileage based rates.
Applicable to Market Area Shippers as provided for in the Carlton Settlement filed in Docket No. RP96-347
dated October 28, 1996.
In addition to the Maximum and Minimum rates, Shipper shall pay the ACA unit surcharge as posted on FERC’s
website at http://www.ferc.gov.
There will be no commodity charge for transportation from the Ventura pooling point (POI 78623) to the
NBPL/NNG Ventura point (POI 192) and from the Ventura pooling point (POI 78623) to the MID 17 pooling point
(POI 71458). In addition, there will be no commodity charge for transportation as set forth in Sheet Nos.
141, 142C and 147.
Issued On: February 1, 2016
Effective On: April 1, 2016
Northern Natural Gas Company
FERC Gas Tariff
Sixth Revised Volume No. 1
Ninth Revised Sheet No. 53
Superseding
Eighth Revised Sheet No. 53
Commodity
Charges
Nov-Oct
GS-T COMMODITY THROUGHPUT RATE
Market Area
Field to Demarcation
Field-to-Market
0.7030
0.6396
1.2587
1/
6/
8/
1/
6/
0.2600
0.0106
1/ 2/ 6/
1/ 2/ 6/
STAND ALONE COMPRESSION
Ft. Buford
Maximum
Minimum
RATE SCHEDULE CS-1
Compression Fee (Exhibit A Volumes)
Maximum
Minimum
0.0401
0.0054
Compression Fee (Additional Volumes)
Maximum
Minimum
0.0401
0.0054
BEAVER COMPRESSION FEE
Incidental Jurisdictional Compression Fee
0.0400
WATERVILLE STORAGE
The Market Area transportation rate, fuel and unaccounted for is charged for delivery to
Waterville storage point (POI 922), or other similarly situated third party storage points in
the Market Area. If redelivery from Waterville, or other similarly situated third party
storage points, is to a Market Area point, there are no additional transportation, fuel or
unaccounted for charges. If the redelivery is to a Field Area delivery point, the Field Area
mileage/MID transportation rate and fuel is charged.
CAPACITY RELEASE FEE (Rate per transaction)
Marketing
DAILY DELIVERY VARIANCE CHARGE:
Positive DDVC
Positive/Critical DDVC
-First 2%
-Next 3%
Negative DDVC
Punitive DDVC
Punitive/Critical DDVC
-Level I
-Level II
AUTHORIZED OVERRUN
TF, TFX, LFT, TI and GS-T Rate Schedules
1/
2/
3/
4/
5/
6/
7/
8/
Negotiated
3/
1.0000
7/
15.0000
22.0000
0.4000
4/
7/
7/
56.5000
113.0000
5/
In addition, Shipper shall pay the ACA unit surcharge as posted on FERC’s website at
http://www.ferc.gov.
Rate only applies to interruptible volumes transported through Ft. Buford that are not
ultimately confirmed for redelivery into Northern's Market Area system.
Northern will assess fee only in those instances outlined in Sheet No. 288.
Charge equal to five (5) times the SMS monthly reservation fee.
The Authorized Overrun Rate shall be equal to the TI rate for the applicable MID path shown
in Sheet Nos. 59-60A.
Reflects Market Area Electric Compression Surcharge of $0.0006 and Field Area Electric
Compression charge of $0.0000 where applicable.
On non-SOL/SUL/Critical Days the rate will be the maximum November-March Market Area TI Rate
during the November-March period, and the maximum April-October Market Area TI Rate during
the April-October period.
There will be no commodity charge for transportation from the Ventura pooling point
(POI 78623) to the NBPL/NNG Ventura point (POI 192) and from the Ventura pooling point (POI
78623) to the MID 17 pooling point (POI 71458). In addition, there will be no commodity
charge for transportation as set forth in Sheet Nos. 141, 142C and 147.
Issued On: February 1, 2016
Effective On: April 1, 2016
Northern Natural Gas Company
FERC Gas Tariff
Sixth Revised Volume No. 1
Thirteenth Revised Sheet No. 54
Superseding
Twelfth Revised Sheet No. 54
RATE SCHEDULES TF, TFX, LFT, GST, TI, & FDD
Fuel Percentages/Electric Compression Rates
Percentages
FUEL PERCENTAGES:
1/
7/
Market Area (including Out-of-Balance)
0.70%
Field Area
2/
UNACCOUNTED FOR PERCENTAGE (including Out-of-Balance)
FDD Storage Fuel
3/
-0.25%
5/
4/
6/
5/
7/
1.19%
Electric Compression
COMMODITY RATES:
1/
7/
Market Area
$0.0006
Field Area
$0.0000
1/
Northern will adjust its Fuel percentages and electric compression commodity rates in
accordance with Sections 53A and 53B, respectively, of the General Terms and Conditions of this
Tariff.
2/
Fuel shall be determined by Mileage Indicator Districts (MIDS) for the Field Area.
3/
Fuel charged in the Field and Market Areas for a pooling transaction or for processing
plant transactions will not exceed the fuel charged on a unified Field-to-Market transaction
having the same initial Field receipt point and ultimate Market delivery point, i.e., the total
fuel collected for transactions that go into and out of pooling points or processing plants in
either the Field Area or the Market Area will be no greater than the fuel collected on the total
path between the original receipt point and the ultimate delivery point, subject to the
shipper(s) providing Northern the requisite information.
4/
The Unaccounted For percentage utilizes the most recent twelve-month period ending
December 31, 2015. For deliveries subject only to UAF, the UAF rate is zero; provided, however
Northern will issue a volume credit on the Shipper’s monthly imbalance statement equivalent to
the Unaccounted For Percentage listed above for the period April 2016 through March 2017 for such
deliveries.
5/
Sheet No. 54A identifies the specific transportation transactions exempt from fuel and
unaccounted-for retention charges.
6/
The Out-of-Balance Fuel Percentage for deliveries in MIDS 1-7 shall be the applicable
Section 1 Mainline Fuel percentage, and for deliveries in MIDS 8-16B shall be the applicable
Section 2 Mainline Fuel percentage.
7/
There will be no fuel, electric compression or UAF charges for transportation from the
Ventura pooling point (POI 78623) to the NBPL/NNG Ventura point (POI 192) and from the Ventura
pooling point (POI 78623) to the MID 17 pooling point (POI 71458). In addition, there will be no
fuel, electric compression or UAF charges for transportation as set forth in Sheet Nos. 141,142C
and 147.
In the event facilities have been abandoned, Northern shall have the right to file to reduce the
applicable MID fuel percentage(s) on a common basis for all transactions affected by the
abandonment to reflect the reduction in use for the remainder of the PRA period. In the event
such abandoned facilities (gas compressors) have been replaced with electric compressors
installed after October 1, 1998, and Northern reduces the applicable MID fuel percentages,
Northern has the right to file to increase the applicable electric compression commodity rate.
Issued On: February 1, 2016
Effective On: April 1, 2016
Northern Natural Gas Company
FERC Gas Tariff
Sixth Revised Volume No. 1
Eighth Revised Sheet No. 60
Superseding
Seventh Revised Sheet No. 60
MILEAGE INDICATOR DISTRICTS (dollars per MMBtu)
DELIVERY DISTRICT
RECEIPT DISTRICT
10
11
12
13
14
15
16A
16B
17
1
TI Apr-Oct
TI Nov-Mar
TF
0.5474
0.9734
0.0748
0.4420
0.7861
0.0604
0.4965
0.8829
0.0678
0.5394
0.9592
0.0737
0.6162
1.0957
0.0842
0.6564
1.1672
0.0897
0.6126
1.0894
0.0837
0.6876
1.2228
0.0939
0.9384
1.8315
0.1304
2
TI Apr-Oct
TI Nov-Mar
TF
0.4751
0.8448
0.0649
0.3929
0.6987
0.0537
0.4385
0.7797
0.0599
0.4769
0.8480
0.0651
0.5546
0.9861
0.0758
0.6555
1.1656
0.0895
0.5572
0.9909
0.0761
0.6197
1.1021
0.0847
0.8705
1.7108
0.1212
3
TI Apr-Oct
TI Nov-Mar
TF
0.4903
0.8718
0.0670
0.4197
0.7464
0.0573
0.4644
0.8258
0.0634
0.5037
0.8956
0.0688
0.6010
1.0687
0.0821
0.6814
1.2116
0.0931
0.5108
0.9083
0.0698
0.6260
1.1132
0.0855
0.8768
1.7219
0.1220
4
TI Apr-Oct
TI Nov-Mar
TF
0.4260
0.7575
0.0582
0.3724
0.6622
0.0509
0.4179
0.7432
0.0571
0.4563
0.8115
0.0623
0.5385
0.9576
0.0736
0.6349
1.1291
0.0867
0.5251
0.9337
0.0717
0.6144
1.0925
0.0839
0.8652
1.7012
0.1204
5
TI Apr-Oct
TI Nov-Mar
TF
0.4492
0.7988
0.0614
0.3492
0.6209
0.0477
0.3947
0.7019
0.0539
0.4331
0.7702
0.0592
0.4751
0.8448
0.0649
0.5983
1.0640
0.0817
0.5340
0.9496
0.0730
0.5867
1.0433
0.0802
0.8375
1.6520
0.1167
6
TI Apr-Oct
TI Nov-Mar
TF
0.4081
0.7257
0.0558
0.3152
0.5606
0.0431
0.3617
0.6431
0.0494
0.4001
0.7114
0.0547
0.4795
0.8528
0.0655
0.5912
1.0513
0.0808
0.4751
0.8448
0.0649
0.5688
1.0116
0.0777
0.8196
1.6203
0.1142
7
TI Apr-Oct
TI Nov-Mar
TF
0.2670
0.4748
0.0365
0.1715
0.3049
0.0234
0.2161
0.3843
0.0295
0.2554
0.4542
0.0349
0.3367
0.5987
0.0460
0.5206
0.9258
0.0711
0.3331
0.5923
0.0455
0.4135
0.7352
0.0565
0.6643
1.3439
0.0930
7B
TI Apr-Oct
TI Nov-Mar
TF
0.2670
0.4748
0.0365
0.1715
0.3049
0.0234
0.2161
0.3843
0.0295
0.2554
0.4542
0.0349
0.3367
0.5987
0.0460
0.5206
0.9258
0.0711
0.3331
0.5923
0.0455
0.4135
0.7352
0.0565
0.6643
1.3439
0.0930
8
TI Apr-Oct
TI Nov-Mar
TF
0.1947
0.3462
0.0266
0.1161
0.2064
0.0159
0.1482
0.2636
0.0203
0.1875
0.3335
0.0256
0.2625
0.4669
0.0359
0.3965
0.7051
0.0542
0.2500
0.4446
0.0342
0.3313
0.5891
0.0453
0.5821
1.1978
0.0818
9
TI Apr-Oct
TI Nov-Mar
TF
0.1509
0.2684
0.0206
0.0679
0.1207
0.0093
0.1473
0.2620
0.0201
0.1500
0.2668
0.0205
0.2366
0.4208
0.0323
0.3626
0.6447
0.0495
0.2652
0.4716
0.0362
0.3268
0.5812
0.0447
0.5776
1.1899
0.0812
NOTE:MID 16A represents the 14 county area south of the Market/Field demarcation point.
MID 16B represents the Field/Market demarcation point.
MID 17 represents the Market area.
NOTE:The MID rates include: (1) the appropriate Market Area Commodity rate for
deliveries to MID 17; (2) the applicable Market Area Electric Compression
surcharge as set forth on Sheet Nos. 50 through 52 for deliveries to MID 17;
and (3) the applicable Field Area Electric Compression surcharge as set forth
on Sheet Nos. 50 through 52 for deliveries to MIDs 1 - 16A.
In addition, where applicable, Shipper shall pay the ACA unit surcharge as posted on
FERC’s website at http://www.ferc.gov and the Carlton surcharge.
Issued On: February 1, 2016
Effective On: April 1, 2016
Northern Natural Gas Company
FERC Gas Tariff
Sixth Revised Volume No. 1
Eighth Revised Sheet No. 60A
Superseding
Seventh Revised Sheet No. 60A
MILEAGE INDICATOR DISTRICTS (dollars per MMBtu)
DELIVERY DISTRICT
RECEIPT DISTRICT
10
11
12
13
14
15
16A
16B
17
10
TI Apr-Oct
TI Nov-Mar
TF
0.0107
0.0191
0.0015
0.0438
0.0778
0.0060
0.1313
0.2334
0.0179
0.1679
0.2985
0.0229
0.2483
0.4415
0.0339
0.3447
0.6130
0.0471
0.2045
0.3637
0.0279
0.3251
0.5780
0.0444
0.5759
1.1867
0.0809
11
TI Apr-Oct
TI Nov-Mar
TF
0.0956
0.1699
0.0131
0.0214
0.0381
0.0029
0.0393
0.0699
0.0054
0.1098
0.1953
0.0150
0.1875
0.3335
0.0256
0.3045
0.5415
0.0416
0.1590
0.2827
0.0217
0.2438
0.4335
0.0333
0.4946
1.0422
0.0698
12
TI Apr-Oct
TI Nov-Mar
TF
0.1491
0.2652
0.0204
0.0732
0.1302
0.0100
0.0893
0.1588
0.0122
0.1366
0.2430
0.0187
0.2259
0.4018
0.0309
0.3233
0.5749
0.0442
0.2170
0.3859
0.0296
0.3045
0.5415
0.0416
0.5553
1.1502
0.0781
13
TI Apr-Oct
TI Nov-Mar
TF
0.1956
0.3478
0.0267
0.0759
0.1350
0.0104
0.1116
0.1985
0.0153
0.0500
0.0889
0.0068
0.1107
0.1969
0.0151
0.2384
0.4240
0.0326
0.0902
0.1604
0.0123
0.1759
0.3128
0.0240
0.4267
0.9215
0.0605
14
TI Apr-Oct
TI Nov-Mar
TF
0.1723
0.3065
0.0235
0.1938
0.3446
0.0265
0.2420
0.4303
0.0331
0.0759
0.1350
0.0104
0.0214
0.0381
0.0029
0.3054
0.5431
0.0417
0.1715
0.3049
0.0234
0.2616
0.4653
0.0357
0.5124
1.0740
0.0722
15
TI Apr-Oct
TI Nov-Mar
TF
0.3902
0.6940
0.0533
0.3134
0.5574
0.0428
0.3643
0.6479
0.0498
0.2313
0.4113
0.0316
0.3170
0.5637
0.0433
0.0223
0.0397
0.0031
0.1527
0.2715
0.0209
0.2340
0.4161
0.0320
0.4848
1.0248
0.0685
16A
TI Apr-Oct
TI Nov-Mar
TF
0.2956
0.5256
0.0404
0.1706
0.3033
0.0233
0.2197
0.3906
0.0300
0.0902
0.1604
0.0123
0.1750
0.3112
0.0239
0.1465
0.2604
0.0200
0.0152
0.0270
0.0021
0.0839
0.1493
0.0115
0.3347
0.7580
0.0480
16B
TI Apr-Oct
TI Nov-Mar
TF
0.3251
0.5780
0.0444
0.2438
0.4335
0.0333
0.3045
0.5415
0.0416
0.1759
0.3128
0.0240
0.2616
0.4653
0.0357
0.2340
0.4161
0.0320
0.0839
0.1493
0.0115
0.0000
0.0000
0.0000
0.2508
0.6087
0.0365
17
TI Apr-Oct
TI Nov-Mar
TF
0.6564
1.1672
0.0897
0.5608
0.9973
0.0766
0.6108
1.0862
0.0834
0.4635
0.8242
0.0633
0.3304
0.5876
0.0451
0.3402
0.6050
0.0465
0.2608
0.4637
0.0356
0.3751
0.6670
0.0512
0.2508
0.6087
0.0365
NOTE:MID 16A represents the 14 county area south of the Market/Field demarcation point.
MID 16B represents the Field/Market demarcation point.
MID 17 represents the Market area.
NOTE:The MID rates include: (1) the appropriate Market Area Commodity rate for
deliveries to MID 17; (2) the applicable Market Area Electric Compression
surcharge as set forth on Sheet Nos. 50 through 52 for deliveries to MID 17;
and (3) the applicable Field Area Electric Compression surcharge as set forth
on Sheet Nos. 50 through 52 for deliveries to MIDs 1 - 16A.
In addition, where applicable, Shipper shall pay the ACA unit surcharge as posted on
FERC’s website at http://www.ferc.gov and the Carlton surcharge.
Issued On: February 1, 2016
Effective On: April 1, 2016
Northern Natural Gas Company
FERC Gas Tariff
Sixth Revised Volume No. 1
Sixth Revised Sheet No. 61
Superseding
Fifth Revised Sheet No. 61
MILEAGE INDICATOR DISTRICTS FUEL PERCENTAGES
DELIVERY DISTRICT
RECEIPT DISTRICT
1
2
3
4
5
6
7
7B
8
1
ML Fuel
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
1.01%
2.05%
2
ML Fuel
0.00%
0.00%
0.76%
0.76%
0.00%
0.00%
0.76%
1.01%
2.05%
3
ML Fuel
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
1.01%
2.05%
4
ML Fuel
0.76%
0.76%
0.76%
0.76%
0.00%
0.76%
0.76%
1.01%
2.05%
5
ML Fuel
0.76%
0.76%
0.76%
0.76%
0.00%
0.76%
0.76%
1.01%
2.05%
6
ML Fuel
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
1.01%
2.05%
7
ML Fuel
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
1.01%
2.05%
7B
ML Fuel
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
0.00%
1.04%
8
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
1.29%
1.04%
9
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
1.29%
1.04%
10
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
1.29%
1.04%
11
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
1.29%
1.04%
12
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
1.29%
1.04%
13
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
1.29%
1.04%
14
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
1.29%
1.04%
15
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
1.29%
1.04%
16A
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
1.29%
1.04%
16B
ML Fuel
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
0.00%
1.04%
17
ML Fuel
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
0.00%
1.04%
Note:ML Fuel percentages include the unaccounted-for percent as set forth on Sheet No. 54.
Northern will adjust its fuel percentages in accordance with Section 53
of the General Terms and Conditions of this Tariff.
In recognition of all to-and-through transactions where gas is nominated and
scheduled for delivery first to the Bushton inlet at POI 1708 in MID 16A and
then subsequently delivered to other delivery points on Northern's system, the
UAF percent will be zero on deliveries to the Bushton inlet (POI 1708); and the
fuel will be zero from the Bushton outlet (POI 1707) to MID 16B.
Issued On: February 1, 2016
Effective On: April 1, 2016
Northern Natural Gas Company
FERC Gas Tariff
Sixth Revised Volume No. 1
Twelfth Revised Sheet No. 62
Superseding
Eleventh Revised Sheet No. 62
MILEAGE INDICATOR DISTRICTS FUEL PERCENTAGES
DELIVERY DISTRICT
RECEIPT DISTRICT
9
10
11
12
13
14
15
16A
16B
17
1
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.30%
2.75%
2
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.30%
2.75%
3
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.30%
2.75%
4
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.30%
2.75%
5
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.30%
2.75%
6
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.30%
2.75%
7
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.30%
2.75%
7B
ML Fuel
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.29%
1.74%
8
ML Fuel
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.29%
1.74%
9
ML Fuel
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.29%
1.74%
10
ML Fuel
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.29%
1.74%
11
ML Fuel
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.29%
1.74%
12
ML Fuel
1.04%
1.04%
1.04%
0.00%
1.04%
0.00%
1.04%
1.04%
1.29%
1.74%
13
ML Fuel
1.04%
1.04%
1.04%
0.00%
1.04%
0.00%
1.04%
1.04%
1.29%
1.74%
14
ML Fuel
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.29%
1.74%
15
ML Fuel
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.29%
1.74%
16A
ML Fuel
1.04%
1.04%
1.04%
0.00%
0.00%
0.00%
0.00%
0.00%
1.29%
1.74%
16B
ML Fuel
1.04%
1.04%
1.04%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
0.45%
17
ML Fuel
1.04%
1.04%
1.04%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
0.45%
Note:ML Fuel percentages include the unaccounted-for percent as set forth on Sheet No. 54.
Northern will adjust its fuel percentages in accordance with Section 53
of the General Terms and Conditions of this Tariff.
In recognition of all to-and-through transactions where gas is nominated and
scheduled for delivery first to the Bushton inlet at POI 1708 in MID 16A and
then subsequently delivered to other delivery points on Northern's system, the
UAF percent will be zero on deliveries to the Bushton inlet (POI 1708); and the
fuel will be zero from the Bushton outlet (POI 1707) to MID 16B.
Issued On: February 1, 2016
Effective On: April 1, 2016
Northern Natural Gas Company
FERC Gas Tariff
Sixth Revised Volume No. 1
Tenth Revised Sheet No. 50
Superseding
Ninth Revised Sheet No. 50
RATE SCHEDULE TF
FIELD-TOFIELD/MARKET
DEMARCATION
MARKET-TO-MARKET
RESERVATION RATES
TF12
TF12 Base Variable
TF5
TFF___
Base Tariff Rates 1/
Summer (Apr-Oct)
Winter (Nov-Mar)
5.683
10.230
5.683
13.866
-015.153
5.473
9.853
______________________________________________________________________________________________________________
COMMODITY RATES 2/
TF12 Base, TF12 Var., TF5 & TFF
Market Area
Field Mileage 5/ Carlton
3/ 6/ Rate per 100 miles Surcharge 4/
Receipt Point
Delivery Point
Maximum
Market
0.0200196
Field
Market
Field
Market
0.03695
0.0200196
0.0175
0.0000
Market
Field
Field
0.03695
0.0200196
0.0122
0.0040
0.0122
0.0040
0.0122
0.0040
0.0175
0.0000
Minimum
Maximum
Minimum
Maximum
Out-of Balance 3/
Minimum
Maximum Minimum
0.03695
0.0276
0.0090
1/ The minimum reservation rate is equal to zero.
2/ The applicable Mileage Indicator Districts (MIDs) billing rate will be added to the TF rates for volumes
received in the Field Area, or received in the Market Area and delivered to the Field Area. The MIDs rates
shown on Sheet Nos. 59-60A represent the maximum Field Area throughput commodity rates for any transaction
involving MIDs. For volumes transported through Northern’s Ft. Buford compressor station, the commodity
rate, fuel and unaccounted for apply only to volumes that are not ultimately confirmed for re-delivery into
Northern’s Market Area.
3/ The Maximum and Minimum rates include the Market Area Electric Compression charge of $0.00100006 where
applicable. In addition, Shipper shall pay the ACA unit surcharge as posted on FERC’s website at
http://www.ferc.gov.
4/ Applicable to Market Area shippers as provided for in the Carlton Settlement filed in Docket No. RP96-347
dated October 28, 1996.
5/ Where applicable, the Field Area Electric Compression charge of $0.0000 and the ACA unit surcharge as set
forth on FERC’s website at http://www.ferc.gov will be added to the mileage based rates.
6/ There will be no commodity charge for transportation from the Ventura pooling point (POI 78623) to the
NBPL/NNG Ventura point (POI 192) and from the Ventura pooling point (POI 78623) to the MID 17 pooling point
(POI 71458). In addition, there will be no commodity charge for transportation as set forth in Sheet Nos.
141, 142C and 147.
Issued On: February 1, 2016
Effective On: April 1, 2016
Northern Natural Gas Company
FERC Gas Tariff
Sixth Revised Volume No. 1
Eleventh Revised Sheet No. 51
Superseding
Tenth Revised Sheet No. 51
RATE SCHEDULES TFX and LFT
MARKET-TO-MARKET
RESERVATION RATES
Base Tariff Rates 1/
FIELD-TO-FIELD___
Apr-Oct
Nov-Mar
Apr-Oct
Nov-Mar_
$5.683
$15.153
$5.473
$9.853_
___________________________________________________________________________________________________________
COMMODITY RATES
TFX and LFT
2/
Market Area
Maximum
Field Mileage 5/
3/ 7/ Rate per 100 miles
Minimum
Maximum
Minimum
Carlton
Surcharge 4/
Out-of-Balance 3/
Receipt Point
Delivery Point
Maximum Minimum
Maximum
Market
0.0200196
Field
Market
Field
Market
0.03695
0.0200196
0.0175
0.0000
Market
Field
Field
0.03695
0.0200196
0.0122
0.0040
0.0122
0.0040
0.0122
0.0040
0.0175
0.0000
Minimum
0.03695
0.0276
0.0090
____________________________________________________________________________________________________________
Reservation 1/
GULF COAST
Other Gulf Coast
1/
2/
3/
4/
5/
6/
7/
Commodity 6/
Out-of-Balance 6/
Maximum
Minimum
Maximum
Minimum
Maximum
Minimum
4.8169
0.0000
0.0000
0.0000
0.0000
0.0000
The minimum reservation rate is equal to zero.
The applicable Mileage Indicator Districts (MIDs) billing rate will be added to the TF rates for volumes
received in the Field Area, or received in the Market Area and delivered to the Field Area. The MIDs rates
shown on Sheet Nos. 59-60A represent the maximum Field Area throughput commodity rates for any transaction
involving MIDs. For volumes transported through Northern’s Ft. Buford compressor station, the commodity
rate, fuel and unaccounted for apply only to volumes that are not ultimately confirmed for re-delivery into
Northern’s Market Area.
The Maximum and Minimum rates include the Market Area Electric Compression charge of $0.00100006 where
applicable. In addition, Shipper shall pay the ACA unit surcharge as posted on FERC’s website at
http://www.ferc.gov.
Applicable to Market Area shippers as provided for in the Carlton Settlement filed in Docket No. RP96-347
dated October 28, 1996.
Where applicable, the Field Area Compression charge of $0.0000 and the ACA unit surcharge as set forth on
FERC’s website at http://www.ferc.gov will be added to the mileage based rates.
In addition to the Maximum and Minimum rates, Shipper shall pay the ACA unit surcharge as posted on FERC’s
website at http://www.ferc.gov.
There will be no commodity charge for transportation from the Ventura pooling point (POI 78623) to the
NBPL/NNG Ventura point (POI 192) and from the Ventura pooling point (POI 78623) to the MID 17 pooling point
(POI 71458). In addition, there will be no commodity charge for transportation as set forth in Sheet Nos.
141, 142C and 147.
Issued On: February 1, 2016
Effective On: April 1, 2016
Northern Natural Gas Company
FERC Gas Tariff
Sixth Revised Volume No. 1
Tenth Revised Sheet No. 52
Superseding
Ninth Revised Sheet No. 52
RATE SCHEDULE TI
COMMODITY RATES
Receipt Point
1/
Delivery Point
NOVEMBER - MARCH
Market
Market
0.0200
Field
Market
Market
Field
Field
Field
APRIL - OCTOBER
Market
0.0200196
Field
Market
Field
Market Area
Maximum
Field Mileage
Rate per 100 miles 3/
2/ 6/
Minimum
Maximum
Minimum
Carlton
Surcharge
Maximum
4/
Out-of-Balance 2/
Minimum
Maximum
0.609187
0.0200196
0.0175
0.0000
0.609187
0.0200196
0.1588
0.0040
0.1588
0.0040
0.1588
0.0040
0.0175
0.0000
0.251208
0.0200196
0.0000
0.0000
Market
Field
Field
0.251208
0.0200196
0.0000
0.0000
0.0893
0.0040
0.0893
0.0040
0.0893
0.0040
0.6091
0.3589
Market
Minimum
0.0090
0.251208
0.2018
0.0090
___________________________________________________________________________________________________________
Commodity
GULF COAST
Other Gulf Coast
1/
2/
3/
4/
5/
6/
5/
Out-of-Balance
5/
Maximum
Minimum
Maximum
Minimum
0.1584
0.0000
0.1584
0.0000
The applicable Mileage Indicator Districts (MIDs) billing rate will be added to the TI rates for volumes
received in the Field Area, or received in the Market Area and delivered to the Field Area. The MIDs rates
shown on Sheet Nos. 59-60A represent the maximum Field Area throughput commodity rates for any transaction
involving MIDs.
The Maximum and Minimum rates include the Market Area Electric Compression charge of $0.001006 where
applicable. In addition, Shipper shall pay the ACA unit surcharge as posted on FERC’s website at
http://www.ferc.gov.
Where applicable, Field Area Compression charge of $0.0000 and ACA unit surcharge as set forth on FERC’s
website at http://www.ferc.gov will be added to the mileage based rates.
Applicable to Market Area Shippers as provided for in the Carlton Settlement filed in Docket No. RP96-347
dated October 28, 1996.
In addition to the Maximum and Minimum rates, Shipper shall pay the ACA unit surcharge as posted on FERC’s
website at http://www.ferc.gov.
There will be no commodity charge for transportation from the Ventura pooling point (POI 78623) to the
NBPL/NNG Ventura point (POI 192) and from the Ventura pooling point (POI 78623) to the MID 17 pooling point
(POI 71458). In addition, there will be no commodity charge for transportation as set forth in Sheet Nos.
141, 142C and 147.
Issued On: February 1, 2016
Effective On: April 1, 2016
Northern Natural Gas Company
FERC Gas Tariff
Sixth Revised Volume No. 1
Ninth Revised Sheet No. 53
Superseding
Eighth Revised Sheet No. 53
Commodity
Charges
Nov-Oct
GS-T COMMODITY THROUGHPUT RATE
Market Area
Field to Demarcation
Field-to-Market
0.70340
0.6396
1.259187
1/
0.26040
0.011006
1/ 2/ 6/
1/ 2/ 6/
1/
6/
8/
6/
STAND ALONE COMPRESSION
Ft. Buford
Maximum
Minimum
RATE SCHEDULE CS-1
Compression Fee (Exhibit A Volumes)
Maximum
Minimum
0.0401
0.0054
Compression Fee (Additional Volumes)
Maximum
Minimum
0.0401
0.0054
BEAVER COMPRESSION FEE
Incidental Jurisdictional Compression Fee
0.0400
WATERVILLE STORAGE
The Market Area transportation rate, fuel and unaccounted for is charged for delivery to
Waterville storage point (POI 922), or other similarly situated third party storage points in
the Market Area. If redelivery from Waterville, or other similarly situated third party
storage points, is to a Market Area point, there are no additional transportation, fuel or
unaccounted for charges. If the redelivery is to a Field Area delivery point, the Field Area
mileage/MID transportation rate and fuel is charged.
CAPACITY RELEASE FEE (Rate per transaction)
Marketing
DAILY DELIVERY VARIANCE CHARGE:
Positive DDVC
Positive/Critical DDVC
-First 2%
-Next 3%
Negative DDVC
Punitive DDVC
Punitive/Critical DDVC
-Level I
-Level II
AUTHORIZED OVERRUN
TF, TFX, LFT, TI and GS-T Rate Schedules
1/
2/
3/
4/
5/
6/
7/
8/
Negotiated
3/
1.0000
7/
15.0000
22.0000
0.4000
4/
7/
7/
56.5000
113.0000
5/
In addition, Shipper shall pay the ACA unit surcharge as posted on FERC’s website at
http://www.ferc.gov.
Rate only applies to interruptible volumes transported through Ft. Buford that are not
ultimately confirmed for redelivery into Northern's Market Area system.
Northern will assess fee only in those instances outlined in Sheet No. 288.
Charge equal to five (5) times the SMS monthly reservation fee.
The Authorized Overrun Rate shall be equal to the TI rate for the applicable MID path shown
in Sheet Nos. 59-60A.
Reflects Market Area Electric Compression Surcharge of $0.001006 and Field Area Electric
Compression charge of $0.0000 where applicable.
On non-SOL/SUL/Critical Days the rate will be the maximum November-March Market Area TI Rate
during the November-March period, and the maximum April-October Market Area TI Rate during
the April-October period.
There will be no commodity charge for transportation from the Ventura pooling point
(POI 78623) to the NBPL/NNG Ventura point (POI 192) and from the Ventura pooling point (POI
78623) to the MID 17 pooling point (POI 71458). In addition, there will be no commodity
charge for transportation as set forth in Sheet Nos. 141, 142C and 147.
Issued On: February 1, 2016
Effective On: April 1, 2016
Northern Natural Gas Company
FERC Gas Tariff
Sixth Revised Volume No. 1
Thirteenth Revised Sheet No. 54
Superseding
Twelfth Revised Sheet No. 54
RATE SCHEDULES TF, TFX, LFT, GST, TI, & FDD
Fuel Percentages/Electric Compression Rates
Percentages
FUEL PERCENTAGES:
1/
7/
Market Area (including Out-of-Balance)
1.140.70%
Field Area
2/
UNACCOUNTED FOR PERCENTAGE (including Out-of-Balance)
FDD Storage Fuel
3/
-0.0925%
5/
6/
4/
5/
7/
1.7619%
Electric Compression
COMMODITY RATES:
1/
7/
Market Area
$0.001006
Field Area
$0.0000
1/
Northern will adjust its Fuel percentages and electric compression commodity rates in
accordance with Sections 53A and 53B, respectively, of the General Terms and Conditions of this
Tariff.
2/
Fuel shall be determined by Mileage Indicator Districts (MIDS) for the Field Area.
3/
Fuel charged in the Field and Market Areas for a pooling transaction or for processing
plant transactions will not exceed the fuel charged on a unified Field-to-Market transaction
having the same initial Field receipt point and ultimate Market delivery point, i.e., the total
fuel collected for transactions that go into and out of pooling points or processing plants in
either the Field Area or the Market Area will be no greater than the fuel collected on the total
path between the original receipt point and the ultimate delivery point, subject to the
shipper(s) providing Northern the requisite information.
4/
The Unaccounted For percentage utilizes the most recent twelve-month period ending
December 31, 20145. For deliveries subject only to UAF, the UAF rate is zero; provided, however
Northern will issue a volume credit on the Shipper’s monthly imbalance statement equivalent to
-0.09% the Unaccounted For Percentage listed above for the period April 20156 through March 20167
for such deliveries.
5/
Sheet No. 54A identifies the specific transportation transactions exempt from fuel and
unaccounted-for retention charges.
6/
The Out-of-Balance Fuel Percentage for deliveries in MIDS 1-7 shall be the applicable
Section 1 Mainline Fuel percentage, and for deliveries in MIDS 8-16B shall be the applicable
Section 2 Mainline Fuel percentage.
7/
There will be no fuel, electric compression or UAF charges for transportation from the
Ventura pooling point (POI 78623) to the NBPL/NNG Ventura point (POI 192) and from the Ventura
pooling point (POI 78623) to the MID 17 pooling point (POI 71458). In addition, there will be no
fuel, electric compression or UAF charges for transportation as set forth in Sheet Nos. 141,142C
and 147.
In the event facilities have been abandoned, Northern shall have the right to file to reduce the
applicable MID fuel percentage(s) on a common basis for all transactions affected by the
abandonment to reflect the reduction in use for the remainder of the PRA period. In the event
such abandoned facilities (gas compressors) have been replaced with electric compressors
installed after October 1, 1998, and Northern reduces the applicable MID fuel percentages,
Northern has the right to file to increase the applicable electric compression commodity rate.
Issued On: February 1, 2016
Effective On: April 1, 2016
Northern Natural Gas Company
FERC Gas Tariff
Sixth Revised Volume No. 1
Eighth Revised Sheet No. 60
Superseding
Seventh Revised Sheet No. 60
MILEAGE INDICATOR DISTRICTS (dollars per MMBtu)
DELIVERY DISTRICT
RECEIPT DISTRICT
10
11
12
13
14
15
16A
16B
17
1
TI Apr-Oct
TI Nov-Mar
TF
0.5474
0.9734
0.0748
0.4420
0.7861
0.0604
0.4965
0.8829
0.0678
0.5394
0.9592
0.0737
0.6162
1.0957
0.0842
0.6564
1.1672
0.0897
0.6126
1.0894
0.0837
0.6876
1.2228
0.0939
0.93884
1.83195
0.13084
2
TI Apr-Oct
TI Nov-Mar
TF
0.4751
0.8448
0.0649
0.3929
0.6987
0.0537
0.4385
0.7797
0.0599
0.4769
0.8480
0.0651
0.5546
0.9861
0.0758
0.6555
1.1656
0.0895
0.5572
0.9909
0.0761
0.6197
1.1021
0.0847
0.87095
1.711208
0.12162
3
TI Apr-Oct
TI Nov-Mar
TF
0.4903
0.8718
0.0670
0.4197
0.7464
0.0573
0.4644
0.8258
0.0634
0.5037
0.8956
0.0688
0.6010
1.0687
0.0821
0.6814
1.2116
0.0931
0.5108
0.9083
0.0698
0.6260
1.1132
0.0855
0.877268
1.722319
0.12240
4
TI Apr-Oct
TI Nov-Mar
TF
0.4260
0.7575
0.0582
0.3724
0.6622
0.0509
0.4179
0.7432
0.0571
0.4563
0.8115
0.0623
0.5385
0.9576
0.0736
0.6349
1.1291
0.0867
0.5251
0.9337
0.0717
0.6144
1.0925
0.0839
0.86562
1.70162
0.12084
5
TI Apr-Oct
TI Nov-Mar
TF
0.4492
0.7988
0.0614
0.3492
0.6209
0.0477
0.3947
0.7019
0.0539
0.4331
0.7702
0.0592
0.4751
0.8448
0.0649
0.5983
1.0640
0.0817
0.5340
0.9496
0.0730
0.5867
1.0433
0.0802
0.83795
1.65240
0.117167
6
TI Apr-Oct
TI Nov-Mar
TF
0.4081
0.7257
0.0558
0.3152
0.5606
0.0431
0.3617
0.6431
0.0494
0.4001
0.7114
0.0547
0.4795
0.8528
0.0655
0.5912
1.0513
0.0808
0.4751
0.8448
0.0649
0.5688
1.0116
0.0777
0.82008196
1.62073
0.11462
7
TI Apr-Oct
TI Nov-Mar
TF
0.2670
0.4748
0.0365
0.1715
0.3049
0.0234
0.2161
0.3843
0.0295
0.2554
0.4542
0.0349
0.3367
0.5987
0.0460
0.5206
0.9258
0.0711
0.3331
0.5923
0.0455
0.4135
0.7352
0.0565
0.66473
1.344339
0.09340
7B
TI Apr-Oct
TI Nov-Mar
TF
0.2670
0.4748
0.0365
0.1715
0.3049
0.0234
0.2161
0.3843
0.0295
0.2554
0.4542
0.0349
0.3367
0.5987
0.0460
0.5206
0.9258
0.0711
0.3331
0.5923
0.0455
0.4135
0.7352
0.0565
0.66473
1.344339
0.09340
8
TI Apr-Oct
TI Nov-Mar
TF
0.1947
0.3462
0.0266
0.1161
0.2064
0.0159
0.1482
0.2636
0.0203
0.1875
0.3335
0.0256
0.2625
0.4669
0.0359
0.3965
0.7051
0.0542
0.2500
0.4446
0.0342
0.3313
0.5891
0.0453
0.58251
1.198278
0.082218
9
TI Apr-Oct
TI Nov-Mar
TF
0.1509
0.2684
0.0206
0.0679
0.1207
0.0093
0.1473
0.2620
0.0201
0.1500
0.2668
0.0205
0.2366
0.4208
0.0323
0.3626
0.6447
0.0495
0.2652
0.4716
0.0362
0.3268
0.5812
0.0447
0.578076
1.1903899
0.08162
NOTE:MID 16A represents the 14 county area south of the Market/Field demarcation point.
MID 16B represents the Field/Market demarcation point.
MID 17 represents the Market area.
NOTE:The MID rates include: (1) the appropriate Market Area Commodity rate for
deliveries to MID 17; (2) the applicable Market Area Electric Compression
surcharge as set forth on Sheet Nos. 50 through 52 for deliveries to MID 17;
and (3) the applicable Field Area Electric Compression surcharge as set forth
on Sheet Nos. 50 through 52 for deliveries to MIDs 1 - 16A.
In addition, where applicable, Shipper shall pay the ACA unit surcharge as posted on
FERC’s website at http://www.ferc.gov and the Carlton surcharge.
Issued On: February 1, 2016
Effective On: April 1, 2016
Northern Natural Gas Company
FERC Gas Tariff
Sixth Revised Volume No. 1
Eighth Revised Sheet No. 60A
Superseding
Seventh Revised Sheet No. 60A
MILEAGE INDICATOR DISTRICTS (dollars per MMBtu)
DELIVERY DISTRICT
RECEIPT DISTRICT
10
11
12
13
14
15
16A
16B
17
10
TI Apr-Oct
TI Nov-Mar
TF
0.0107
0.0191
0.0015
0.0438
0.0778
0.0060
0.1313
0.2334
0.0179
0.1679
0.2985
0.0229
0.2483
0.4415
0.0339
0.3447
0.6130
0.0471
0.2045
0.3637
0.0279
0.3251
0.5780
0.0444
0.576359
1.187167
0.081309
11
TI Apr-Oct
TI Nov-Mar
TF
0.0956
0.1699
0.0131
0.0214
0.0381
0.0029
0.0393
0.0699
0.0054
0.1098
0.1953
0.0150
0.1875
0.3335
0.0256
0.3045
0.5415
0.0416
0.1590
0.2827
0.0217
0.2438
0.4335
0.0333
0.495046
1.04262
0.0702698
12
TI Apr-Oct
TI Nov-Mar
TF
0.1491
0.2652
0.0204
0.0732
0.1302
0.0100
0.0893
0.1588
0.0122
0.1366
0.2430
0.0187
0.2259
0.4018
0.0309
0.3233
0.5749
0.0442
0.2170
0.3859
0.0296
0.3045
0.5415
0.0416
0.55573
1.15062
0.07851
13
TI Apr-Oct
TI Nov-Mar
TF
0.1956
0.3478
0.0267
0.0759
0.1350
0.0104
0.1116
0.1985
0.0153
0.0500
0.0889
0.0068
0.1107
0.1969
0.0151
0.2384
0.4240
0.0326
0.0902
0.1604
0.0123
0.1759
0.3128
0.0240
0.427167
0.92195
0.06095
14
TI Apr-Oct
TI Nov-Mar
TF
0.1723
0.3065
0.0235
0.1938
0.3446
0.0265
0.2420
0.4303
0.0331
0.0759
0.1350
0.0104
0.0214
0.0381
0.0029
0.3054
0.5431
0.0417
0.1715
0.3049
0.0234
0.2616
0.4653
0.0357
0.51284
1.07440
0.07262
15
TI Apr-Oct
TI Nov-Mar
TF
0.3902
0.6940
0.0533
0.3134
0.5574
0.0428
0.3643
0.6479
0.0498
0.2313
0.4113
0.0316
0.3170
0.5637
0.0433
0.0223
0.0397
0.0031
0.1527
0.2715
0.0209
0.2340
0.4161
0.0320
0.485248
1.025248
0.06895
16A
TI Apr-Oct
TI Nov-Mar
TF
0.2956
0.5256
0.0404
0.1706
0.3033
0.0233
0.2197
0.3906
0.0300
0.0902
0.1604
0.0123
0.1750
0.3112
0.0239
0.1465
0.2604
0.0200
0.0152
0.0270
0.0021
0.0839
0.1493
0.0115
0.335147
0.75840
0.04840
16B
TI Apr-Oct
TI Nov-Mar
TF
0.3251
0.5780
0.0444
0.2438
0.4335
0.0333
0.3045
0.5415
0.0416
0.1759
0.3128
0.0240
0.2616
0.4653
0.0357
0.2340
0.4161
0.0320
0.0839
0.1493
0.0115
0.0000
0.0000
0.0000
0.251208
0.609187
0.03695
17
TI Apr-Oct
TI Nov-Mar
TF
0.6564
1.1672
0.0897
0.5608
0.9973
0.0766
0.6108
1.0862
0.0834
0.4635
0.8242
0.0633
0.3304
0.5876
0.0451
0.3402
0.6050
0.0465
0.2608
0.4637
0.0356
0.3751
0.6670
0.0512
0.251208
0.609187
0.03695
NOTE:MID 16A represents the 14 county area south of the Market/Field demarcation point.
MID 16B represents the Field/Market demarcation point.
MID 17 represents the Market area.
NOTE:The MID rates include: (1) the appropriate Market Area Commodity rate for
deliveries to MID 17; (2) the applicable Market Area Electric Compression
surcharge as set forth on Sheet Nos. 50 through 52 for deliveries to MID 17;
and (3) the applicable Field Area Electric Compression surcharge as set forth
on Sheet Nos. 50 through 52 for deliveries to MIDs 1 - 16A.
In addition, where applicable, Shipper shall pay the ACA unit surcharge as posted on
FERC’s website at http://www.ferc.gov and the Carlton surcharge.
Issued On: February 1, 2016
Effective On: April 1, 2016
Northern Natural Gas Company
FERC Gas Tariff
Sixth Revised Volume No. 1
Sixth Revised Sheet No. 61
Superseding
Fifth Revised Sheet No. 61
MILEAGE INDICATOR DISTRICTS FUEL PERCENTAGES
DELIVERY DISTRICT
RECEIPT DISTRICT
1
2
3
4
5
6
7
7B
8
1
ML Fuel
0.88%
0.88%
0.88%
0.88%
0.88%
0.88%
0.88%
0.97%
2.80%
2
ML Fuel
0.00%
0.00%
0.88%
0.88%
0.00%
0.00%
0.88%
0.97%
2.80%
3
ML Fuel
0.88%
0.88%
0.88%
0.88%
0.88%
0.88%
0.88%
0.97%
2.80%
4
ML Fuel
0.88%
0.88%
0.88%
0.88%
0.00%
0.88%
0.88%
0.97%
2.80%
5
ML Fuel
0.88%
0.88%
0.88%
0.88%
0.00%
0.88%
0.88%
0.97%
2.80%
6
ML Fuel
0.88%
0.88%
0.88%
0.88%
0.88%
0.88%
0.88%
0.97%
2.80%
7
ML Fuel
0.88%
0.88%
0.88%
0.88%
0.88%
0.88%
0.88%
0.97%
2.80%
7B
ML Fuel
0.88%
0.88%
0.88%
0.88%
0.88%
0.88%
0.88%
0.00%
1.83%
8
ML Fuel
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
1.92%
1.83%
9
ML Fuel
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
1.92%
1.83%
10
ML Fuel
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
1.92%
1.83%
11
ML Fuel
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
1.92%
1.83%
12
ML Fuel
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
1.92%
1.83%
13
ML Fuel
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
1.92%
1.83%
14
ML Fuel
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
1.92%
1.83%
15
ML Fuel
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
1.92%
1.83%
16A
ML Fuel
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
1.92%
1.83%
16B
ML Fuel
0.88%
0.88%
0.88%
0.88%
0.88%
0.88%
0.88%
0.00%
1.83%
17
ML Fuel
0.88%
0.88%
0.88%
0.88%
0.88%
0.88%
0.88%
0.00%
1.83%
1
ML Fuel
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
1.01%
2.05%
2
ML Fuel
0.00%
0.00%
0.76%
0.76%
0.00%
0.00%
0.76%
1.01%
2.05%
3
ML Fuel
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
1.01%
2.05%
4
ML Fuel
0.76%
0.76%
0.76%
0.76%
0.00%
0.76%
0.76%
1.01%
2.05%
5
ML Fuel
0.76%
0.76%
0.76%
0.76%
0.00%
0.76%
0.76%
1.01%
2.05%
6
ML Fuel
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
1.01%
2.05%
7
ML Fuel
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
1.01%
2.05%
7B
ML Fuel
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
0.00%
1.04%
8
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
1.29%
1.04%
9
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
1.29%
1.04%
10
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
1.29%
1.04%
11
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
1.29%
1.04%
12
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
1.29%
1.04%
Issued On: February 1, 2016
Effective On: April 1, 2016
Northern Natural Gas Company
FERC Gas Tariff
Sixth Revised Volume No. 1
Sixth Revised Sheet No. 61
Superseding
Fifth Revised Sheet No. 61
13
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
1.29%
1.04%
14
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
1.29%
1.04%
15
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
1.29%
1.04%
16A
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
1.29%
1.04%
16B
ML Fuel
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
0.00%
1.04%
17
ML Fuel
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
0.76%
0.00%
1.04%
Note:ML Fuel percentages include the unaccounted-for percent as set forth on Sheet No. 54.
Northern will adjust its fuel percentages in accordance with Section 53
of the General Terms and Conditions of this Tariff.
In recognition of all to-and-through transactions where gas is nominated and
scheduled for delivery first to the Bushton inlet at POI 1708 in MID 16A and
then subsequently delivered to other delivery points on Northern's system, the
UAF percent will be zero on deliveries to the Bushton inlet (POI 1708); and the
fuel will be zero from the Bushton outlet (POI 1707) to MID 16B.
Issued On: February 1, 2016
Effective On: April 1, 2016
Northern Natural Gas Company
FERC Gas Tariff
Sixth Revised Volume No. 1
Twelfth Revised Sheet No. 62
Superseding
Eleventh Revised Sheet No. 62
MILEAGE INDICATOR DISTRICTS FUEL PERCENTAGES
DELIVERY DISTRICT
RECEIPT DISTRICT
9
10
11
12
13
14
15
16A
16B
17
1
ML Fuel
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.89%
3.94%
2
ML Fuel
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.89%
3.94%
3
ML Fuel
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.89%
3.94%
4
ML Fuel
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.89%
3.94%
5
ML Fuel
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.89%
3.94%
6
ML Fuel
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.89%
3.94%
7
ML Fuel
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.80%
2.89%
3.94%
7B
ML Fuel
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.92%
2.97%
8
ML Fuel
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.92%
2.97%
9
ML Fuel
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.92%
2.97%
10
ML Fuel
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.92%
2.97%
11
ML Fuel
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.92%
2.97%
12
ML Fuel
1.83%
1.83%
1.83%
0.00%
1.83%
0.00%
1.83%
1.83%
1.92%
2.97%
13
ML Fuel
1.83%
1.83%
1.83%
0.00%
1.83%
0.00%
1.83%
1.83%
1.92%
2.97%
14
ML Fuel
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.92%
2.97%
15
ML Fuel
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.83%
1.92%
2.97%
16A
ML Fuel
1.83%
1.83%
1.83%
0.00%
0.00%
0.00%
0.00%
0.00%
1.92%
2.97%
16B
ML Fuel
1.83%
1.83%
1.83%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
1.05%
17
ML Fuel
1.83%
1.83%
1.83%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
1.05%
1
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.30%
2.75%
2
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.30%
2.75%
3
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.30%
2.75%
4
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.30%
2.75%
5
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.30%
2.75%
6
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.30%
2.75%
7
ML Fuel
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.05%
2.30%
2.75%
7B
ML Fuel
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.29%
1.74%
8
ML Fuel
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.29%
1.74%
9
ML Fuel
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.29%
1.74%
10
ML Fuel
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.29%
1.74%
11
ML Fuel
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.29%
1.74%
12
ML Fuel
1.04%
1.04%
1.04%
0.00%
1.04%
0.00%
1.04%
1.04%
1.29%
1.74%
Issued On: February 1, 2016
Effective On: April 1, 2016
Northern Natural Gas Company
FERC Gas Tariff
Sixth Revised Volume No. 1
Twelfth Revised Sheet No. 62
Superseding
Eleventh Revised Sheet No. 62
13
ML Fuel
1.04%
1.04%
1.04%
0.00%
1.04%
0.00%
1.04%
1.04%
1.29%
1.74%
14
ML Fuel
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.29%
1.74%
15
ML Fuel
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.04%
1.29%
1.74%
16A
ML Fuel
1.04%
1.04%
1.04%
0.00%
0.00%
0.00%
0.00%
0.00%
1.29%
1.74%
16B
ML Fuel
1.04%
1.04%
1.04%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
0.45%
17
ML Fuel
1.04%
1.04%
1.04%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
0.45%
Note:ML Fuel percentages include the unaccounted-for percent as set forth on Sheet No. 54.
Northern will adjust its fuel percentages in accordance with Section 53
of the General Terms and Conditions of this Tariff.
In recognition of all to-and-through transactions where gas is nominated and
scheduled for delivery first to the Bushton inlet at POI 1708 in MID 16A and
then subsequently delivered to other delivery points on Northern's system, the
UAF percent will be zero on deliveries to the Bushton inlet (POI 1708); and the
fuel will be zero from the Bushton outlet (POI 1707) to MID 16B.
Issued On: February 1, 2016
Effective On: April 1, 2016