TRANSCO IS INDIRECTLY OWNED BY THE WILLIAMS COMPANIES, INC.
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Schedule Page: 217 Line No.: 31 Column: c
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VOLUME RETAINED UNDER A SEPARATELY STATED FUEL RATE 2.586 DTH
ALL BASE GAS IN ACCOUNT 117.1 IS CONSIDERED NON-CURRENT.
ALL GAS IN ACCOUNT 117.2 IS CONSIDERED CURRENT.
ALL GAS STORED IN THE LNG FACILITY (ACCOUNT 164.2) IS CONSIDERED CURRENT.
TRANSCO USES THE INVENTORY METHOD TO REPORT STORAGE.
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CTD DESCRIPTION
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DEFERRED TAX ACCOUNT
|
12/31/2025 Balance
|
|
|
|
|
|
|
|
PROPERTY, PLANT, & EQUIPMENT
|
190
|
228,897,088
|
|
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REGULATORY LIABILITIES
|
190
|
111,106,213
|
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OTHER ACCRUED LIABILITIES
|
190
|
186,963,386
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190 TOTAL
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526,966,687
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Use tax is distributed to various accounts based on the accounts coded on the originating invoice.
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CTD DESCRIPTION
|
DEFERRED TAX ACCOUNT
|
12/31/2025 Balance
|
|
|
|
|
|
|
|
|
|
|
PROPERTY, PLANT, & EQUIPMENT
|
282
|
1,617,545,133
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282 TOTAL
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|
1,617,545,133
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|
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|
|
|
|
|
|
|
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CTD DESCRIPTION
|
DEFERRED TAX ACCOUNT
|
12/31/2025 Balance
|
|
|
|
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PROPERTY, PLANT, & EQUIPMENT
|
283
|
24,460,149
|
|
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REGULATORY ASSETS
|
283
|
105,513,561
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|
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DEFERRED CHARGES & OTHER ASSETS
|
283
|
(4,354,992)
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|
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283 TOTAL
|
|
125,618,718
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DOCKET NO. CP 08-31-001, DOCKET NO. CP 08-31-002
FERC GAS TARIFF GENERAL TERMS AND CONDITIONS SECTION 54
FERC GAS TARIFF GENERAL TERMS AND CONDITIONS SECTION 54
FERC GAS TARIFF GENERAL TERMS AND CONDITIONS SECTION 54
DOCKET NO. RP 24-1035, DEFERRED BALANCE (6 YEARS)
Docket No. RP24-1035, protected excess deferred income taxes (16.78 years & 26.34 years)
Docket No. RP24-1035, unprotected excess deferred income taxes (6 years)
FERC GAS TARIFF GENERAL TERMS AND CONDITIONS SECTION 41.5
FERC GAS TARIFF GENERAL TERMS AND CONDITIONS SECTION 15
DOCKET NO. RP 24 - 1035, DEFERRED BALANCE (6 YEARS)
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Zone of Delivery,
Rate Schedule
(a)
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Revenues for Transition Costs and Take-or-Pay Amount for Current Year
(b)
|
Revenues for Transition Costs and Take-or-Pay Amount for Previous Year
(c)
|
Revenues for GRI and ACA Amount for Current Year
(d)
|
Revenues for GRI and ACA Amount for Previous Year
(e)
|
Other Revenues Amount for Current Year
(f)
|
Other Revenues Amount for Previous Year
(g)
|
Total Operating Revenues Amount for Current Year
(h)
|
Total Operating Revenues Amount for Previous Year
(i)
|
Dekatherm of Natural Gas Amount for Current Year
(j)
|
Dekatherm of Natural Gas Amount for Previous Year
(k)
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|
Subtotal Zone 1
|
—
|
—
|
161,957
|
104,009
|
48,712,487
|
41,444,713
|
48,874,444
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41,548,722
|
239,181,351
|
165,642,071
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|
Subtotal Zone 2
|
—
|
—
|
599,119
|
568,330
|
73,582,981
|
71,260,873
|
74,182,100
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71,829,203
|
472,038,624
|
459,281,748
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|
Subtotal Zone 3
|
—
|
—
|
124,437
|
125,002
|
118,723,078
|
98,633,367
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118,847,515
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98,758,369
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583,919,114
|
426,460,777
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|
Subtotal Zone 4
|
—
|
—
|
948,414
|
930,695
|
586,740,079
|
557,961,358
|
587,688,493
|
558,892,053
|
1,529,668,443
|
1,451,601,908
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|
Subtotal Zone 4A
|
—
|
—
|
368,922
|
375,984
|
115,837,632
|
107,075,169
|
116,206,554
|
107,451,153
|
259,789,036
|
280,491,376
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Subtotal Zone 4B
|
—
|
—
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—
|
7,425
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9,659,797
|
6,318,466
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9,659,797
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6,325,891
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118,748,684
|
95,267,296
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|
Subtotal Zone 5
|
—
|
—
|
2,502,721
|
2,220,560
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651,010,074
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537,508,365
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653,512,795
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539,728,925
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2,103,086,599
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2,012,493,292
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|
Subtotal Zone 6
|
—
|
—
|
2,053,102
|
1,863,020
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1,429,407,855
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1,208,356,881
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1,431,460,957
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1,210,219,901
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1,647,452,409
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1,552,797,384
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Subtotal Other
|
—
|
—
|
—
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—
|
1,056,487
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963,506
|
1,056,487
|
963,506
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—
|
—
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Total
|
—
|
—
|
6,758,672
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6,195,025
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3,034,730,470
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2,629,522,698
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3,041,489,142
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2,635,717,723
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6,953,884,260
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6,444,035,852
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GAS USED FOR COMPRESSOR STATION FUEL - ACCOUNTS CHARGED
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ACCOUNTS
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DT'S
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|
|
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|
|
85400
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39,911,955
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GAS USED FOR COMPRESSOR STATION
|
|
81900
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2,447,021
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STORAGE COMPRESSOR FUEL
|
|
85400
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(44,615,246)
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COMPRESSOR STATION FUEL REIMBURSEMENTS
|
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(2,256,270)
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GAS USED FOR COMPRESSOR STATION FUEL - ACCOUNTS CHARGED
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|
|
|
|
|
|
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ACCOUNTS
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DOLLARS
|
|
|
|
|
|
85400
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115,132,953
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GAS USED FOR COMPRESSOR STATION
|
|
81900
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7,074,562
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STORAGE COMPRESSOR FUEL
|
|
85400
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(133,946,448)
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COMPRESSOR STATION FUEL REIMBURSEMENTS
|
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(11,738,933)
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PURGING - ACCOUNTS CHARGED
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|
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ACCOUNTS
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DT'S
|
|
|
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|
|
10700
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67,503
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|
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85600
|
13,453
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|
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80,956
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PURGING - ACCOUNTS CHARGED
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|
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|
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ACCOUNTS
|
DOLLARS
|
|
|
|
|
|
10700
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$
|
188,791
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|
|
|
85600
|
66,679
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|
|
|
$
|
255,470
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|
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PRODUCTION AND GATHERING OFFSHORE
DEPRECIATION 1.82% (RP24-1035)
ALL PRODUCTION AND GATHERING OFFSHORE PLANT DEPRECIATION WAS PRIMARILY COMPUTED ON DEPRECIABLE PLANT IN SERVICE BASED ON THE BALANCE AT THE END OF THE PRECEDING MONTH.
PRODUCTION AND GATHERING OFFSHORE
DEPRECIATION 1.82% (RP24-1035)
ALL PRODUCTION AND GATHERING OFFSHORE PLANT DEPRECIATION WAS PRIMARILY COMPUTED ON DEPRECIABLE PLANT IN SERVICE BASED ON THE BALANCE AT THE END OF THE PRECEDING MONTH.
PRODUCTION AND GATHERING ONSHORE
PRODUCTION AND GATHERING ONSHORE PLANT IS BASED ON AN ASSET RETIREMENT OBLIGATION.
PRODUCTION AND GATHERING ONSHORE
PRODUCTION AND GATHERING ONSHORE PLANT IS BASED ON AN ASSET RETIREMENT OBLIGATION.
UNDERGROUND STORAGE
DEPRECIATION 2.52% (RP24-1035)
ALL UNDERGROUND STORAGE PLANT DEPRECIATION WAS COMPUTED ON DEPRECIABLE PLANT IN SERVICE BASED ON THE BALANCE AT THE END OF THE PRECEDING MONTH.
UNDERGROUND STORAGE
DEPRECIATION 2.52% (RP24-1035)
ALL UNDERGROUND STORAGE PLANT DEPRECIATION WAS COMPUTED ON DEPRECIABLE PLANT IN SERVICE BASED ON THE BALANCE AT THE END OF THE PRECEDING MONTH.
TRANSMISSION OFFSHORE
DEPRECIATION 2.23% (RP24-1035)
ALL TRANSMISSION OFFSHORE PLANT DEPRECIATION WAS COMPUTED ON DEPRECIABLE PLANT IN SERVICE BASED ON THE BALANCE AT THE END OF THE PRECEDING MONTH.
TRANSMISSION OFFSHORE
DEPRECIATION 2.23% (RP24-1035)
ALL TRANSMISSION OFFSHORE PLANT DEPRECIATION WAS COMPUTED ON DEPRECIABLE PLANT IN SERVICE BASED ON THE BALANCE AT THE END OF THE PRECEDING MONTH.
TRANSMISSION ONSHORE
TRANSMISSION ONSHORE RATES RANGE FROM 2.55% TO 6.93% (RP24-1035))
ALL TRANSMISSION PLANT DEPRECIATION WAS COMPUTED ON DEPRECIABLE PLANT IN SERVICE BASED ON THE BALANCE AT THE END OF THE PRECEDING MONTH.
TRANSMISSION ONSHORE
TRANSMISSION ONSHORE RATES RANGE FROM 2.55% TO 6.93% (RP24-1035)
ALL TRANSMISSION PLANT DEPRECIATION WAS COMPUTED ON DEPRECIABLE PLANT IN SERVICE BASED ON THE BALANCE AT THE END OF THE PRECEDING MONTH.
GENERAL PLANT
GENERAL PLANT DEPRECIATION RATES RANGE FROM 4.00% TO 20.00% (RP24-1035) BASED ON THE EXPECTED SERVICE LIFE. GENERAL PLANT DEPRECIATION WAS PRIMARILY COMPUTED ON DEPRECIABLE PLANT IN SERVICE BASED ON THE BALANCE AT THE END OF THE PRECEDING MONTH.
GENERAL PLANT
GENERAL PLANT DEPRECIATION RATES RANGE FROM 4.00% TO 20.00% (RP24-1035) BASED ON THE EXPECTED SERVICE LIFE. GENERAL PLANT DEPRECIATION WAS PRIMARILY COMPUTED ON DEPRECIABLE PLANT IN SERVICE BASED ON THE BALANCE AT THE END OF THE PRECEDING MONTH.
OTHER STORAGE
DEPRECIATION 2.73% (RP24-1035
ALL OTHER STORAGE PLANT DEPRECIATION WAS COMPUTED ON DEPRECIABLE PLANT IN SERVICE BASED ON THE BALANCE AT THE END OF THE PRECEDING MONTH.
OTHER STORAGE
DEPRECIATION 2.73% (RP24-1035)
ALL OTHER STORAGE PLANT DEPRECIATION WAS COMPUTED ON DEPRECIABLE PLANT IN SERVICE BASED ON THE BALANCE AT THE END OF THE PRECEDING MONTH.
INTANGIBLE PLANT
DEPRECIATION 1.58% (RP24-1035)
ALL INTANGIBLE PLANT DEPRECIATION WAS COMPUTED ON DEPRECIABLE PLANT IN SERVICE BASED ON THE BALANCE AT THE END OF THE PRECEEDING MONTH.
INTANGIBLE PLANT
DEPRECIATION 1.58% (RP24-1035)
ALL INTANGIBLE PLANT DEPRECIATION WAS COMPUTED ON DEPRECIABLE PLANT IN SERVICE BASED ON THE BALANCE AT THE END OF THE PRECEEDING MONTH.
LETTER OF CREDIT FEES INCURRED BY WILLIAMS ARE CHARGED TO ITS SUBSIDIARIES, INCLUDING TRANSCO, BASED ON A THREE-FACTOR FORMULA, WHICH CONSIDERS REVENUES; PROPERTY, PLANT AND EQUIPMENT; AND PAYROLL.
Enterprise shared service costs are allocated to franchises via specific or general methods. Specific allocations are based on metrics that bear a reasonable correlation to the delivery of services, for instance some human resource services costs are allocated based on employee headcount. General allocations are based on "Modified Massachusetts" formula (MMF) which is determined by the proportion of three components: net revenues; gross property, plant and equipment; and gross payroll.
Enterprise shared service costs for fleet leasing and other fleet costs are allocated to franchises via specific allocations based on labor costs assigned to capital work orders.
Payroll and non-payroll charges for the benefit of the operating area that are not specific to a franchise are allocated to franchises in the operating area via specific or general methods. Specific allocations are based on metrics that bear a reasonable correlation to the delivery of services, for instance some human resource services costs are allocated based on employee headcount. General allocations are based on "Modified Massachusetts" formula (MMF) which is determined by the proportion of three components: net revenues; gross property, plant and equipment; and gross payroll.
Storage facilities charges recorded to a specific work order for the benefit of the storage facilities within Transmission, Power & Gulf Operating Area that are not specific to a franchise are allocated to franchises included in the operating area via specific allocations primarily based on labor costs.
Salt Lake City, Utah building rent is allocated based on employee labor hours.
Houston, Texas Williams tower building rent is allocated based on employee labor hours.
Employees' direct assignment payroll and non-payroll charges recorded to a specific work order for the benefit of the Transmission, Power & Gulf Operating Area that are not specific to a franchise are allocated to franchises included in the operating area via general allocations based on "Modified Massachusetts" formula (MMF).
Houston, Texas Williams tower building rent is allocated based on employee labor hours.
Common systems hardware and software costs are allocated via general allocations using "Modified Massachusetts" formula (MMF).
Houston, Texas Williams tower building rent is allocated based on employee labor hours
Houston, Texas Williams tower building rent is allocated based on employee labor hours.
Common systems hardware and software costs are allocated via general allocations using "Modified Massachusetts" formula (MMF).
Houston, Texas Williams tower building rent is allocated based on employee labor hours.
Common systems hardware and software costs are allocated via general allocations using "Modified Massachusetts" formula (MMF).
LEIDY COMPRESSOR STATION IS OWNED BY TRANSCO, TEXAS EASTERN TRANSMISSION CORPORATION, AND DOMINION TRANSMISSION. THE PLANT REPORTED REPRESENTS TRANSCO'S 25% INTEREST IN SUCH STATION.
WHARTON COMPRESSOR STATION IS OWNED BY TRANSCO, NATIONAL FUEL, AND CENTRAL PENN GAS. THE PLANT REPORTED REPRESENTS TRANSCO'S 80% INTEREST IN SUCH STATION.
STORAGE FLEX VOLUME ACTIVITY FOR ALL STORAGE FACILITIES IS REPORTED IN COLUMN B.
CUSTOMERS’ STORAGE VOLUME FOR ALL STORAGE FACILITIES IS REPORTED IN COLUMN C.
THE PHYSICAL STORAGE VOLUME ACTIVITY FOR ALL STORAGE FACILITIES IS REPORTED IN COLUMN D.
SUMMARY OF JOINTLY OWNED TRANSMISSION LINES OPERATED BY TRANSCO-PENNSYLVANIA ONSHORE AND STATE WATERS
i.
187.7 MILES - TRANSCO 61.09%, MEADE PIPELINE CO 38.91%
SUMMARY OF JOINTLY OWNED TRANSMISSION LINES NOT OPERATED BY TRANSCO-ALABAMA ONSHORE AND STATE WATERS
i.
18.7 MILES - TRANSCO 79.35%, FLORIDA GAS TRANSMISSION COMPANY 20.65%
SUMMARY OF JOINTLY OWNED TRANSMISSION LINES NOT OPERATED BY TRANSCO-FEDERAL WATERS
i.
60.1 MILES - TRANSCO 21.56%,GULF SOUTH 35.52%, TC OFFSHORE 25.15%, ENTERPRISE 12.00%, TEXAS GAS TRANSMISSION 5.7%
THOSE TRANSACTIONS THAT FLOW ON RATE SCHEDULES OTHER THAN FT, IT, OR BUNDLED STORAGE ARE CATEGORIZED AS OTHER.
THOSE TRANSACTIONS THAT FLOW ON RATE SCHEDULES OTHER THAN FT, IT, OR BUNDLED STORAGE CARE CATEGORIZED AS OTHER.
From Docket CP75-118, the certificated deliverability is 400 MMscfd. Send out is limited to 365 MMscfd due to the possibility of the lateral pressure used for delivery being at pressures as low as 400 psig. 400 MMscfd is possible if the pressures are over 800 psig in the lateral.
Total Maximum Daily Delivery Capacity for Caverns 5, 6, and 7 is 1,200 MMscfd. Normal maximum daily delivery capacity for Dehys 2-6 is 1,250 MMscfd. Cavern 6 is currently out of service for a repair, limiting the total withdrawal capacity to only 800 MMscfd, which is the combined maximum rates of Caverns 5 and 7.
Total Maximum Daily Delivery Capacity for the field is 1,224 MMscfd. Transco's share of the deliverability is 306 MMscfd. BHE provides conversion to Dth annually.
Total Maximum Daily Delivery Capacity for the field is 300 MMscfd. Transco's share (per the 1996 Operating Agreement) is 250 MMscfd.
FOOTNOTE TO INSTRUCTION 8:
ALL VOLUMES FOR GAS PURCHASES ARE RECORDED TO ACCOUNT 803.
LINE 3, COLUMN C INCLUDES THE FOLLOWING VOLUMES:
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|
|
|
|
|
|
|
|
|
|
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CASH-OUT PURCHASES
|
42,497,614
|
|
|
DTs
|
|
SYSTEM MANAGEMENT GAS PURCHASES
|
—
|
|
|
DTs
|
|
42,497,614
|
|
|
DTs
|
FOOTNOTE TO INSTRUCTION 8:
ALL VOLUMES FOR GAS PURCHASES ARE RECORDED TO ACCOUNT 803.
LINE 3, COLUMN D INCLUDES THE FOLLOWING VOLUMES:
|
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|
|
|
|
|
|
|
|
|
|
|
CASH-OUT PURCHASES
|
14,451,128
|
|
|
DTs
|
|
SYSTEM MANAGEMENT GAS PURCHASES
|
—
|
|
|
DTs
|
|
14,451,128
|
|
|
DTs
|
INCLUDES THE FOLLOWING VOLUMES WITHDRAWN FROM STORAGE:
|
|
|
|
|
|
|
GSS
|
10,014,001
|
|
|
LSS
|
478,982
|
|
|
SS-2
|
(659,255)
|
|
|
S-2
|
(1,108,568)
|
|
|
WSS
|
(8,123,335)
|
|
|
LNG
|
1,237,249
|
|
|
LGS
|
—
|
|
|
EMINENCE
|
7,022,234
|
|
|
LGA
|
(583,935)
|
|
|
TOTAL
|
8,277,373
|
|
INCLUDES THE FOLLOWING VOLUMES WITHDRAWN FROM STORAGE:
|
|
|
|
|
|
|
GSS
|
2,399,037
|
|
|
LSS
|
14,623
|
|
|
SS-2
|
375,408
|
|
|
S-2
|
(448,254)
|
|
|
WSS
|
20,516
|
|
|
LNG
|
580,532
|
|
|
LGS
|
—
|
|
|
EMINENCE
|
723,559
|
|
|
LGA
|
(118,703)
|
|
|
TOTAL
|
3,546,718
|
|
FIRST QUARTER:
14.47% OF THE TOTAL GAS RECEIVED FROM SHIPPERS AS FUEL REIMBURSEMENT WAS CALCULATED TO BE RECEIVED AS LOST AND UNACCOUNTED FOR. THIS PERCENTAGE WAS DERIVED FROM THE DATA UNDERLYING THE 2024 FUEL TRACKER FILING.
SECOND QUARTER
21.24% OF THE TOTAL GAS RECEIVED FROM SHIPPERS AS FUEL REIMBURSEMENT WAS CALCULATED TO BE RECEIVED AS LOST AND UNACCOUNTED FOR. THIS PERCENTAGE WAS DERIVED FROM THE DATA UNDERLYING THE 2025 FUEL TRACKER FILING.
THIRD QUARTER
21.24% OF THE TOTAL GAS RECEIVED FROM SHIPPERS AS FUEL REIMBURSEMENT WAS CALCULATED TO BE RECEIVED AS LOST AND UNACCOUNTED FOR. THIS PERCENTAGE WAS DERIVED FROM THE DATA UNDERLYING THE 2025 FUEL TRACKER FILING.
FOURTH QUARTER
21.24% OF THE TOTAL GAS RECEIVED FROM SHIPPERS AS FUEL REIMBURSEMENT WAS CALCULATED TO BE RECEIVED AS LOST AND UNACCOUNTED FOR. THIS PERCENTAGE WAS DERIVED FROM THE DATA UNDERLYING THE 2025 FUEL TRACKER FILING.
IN THE FOURTH QUARTER, 21.24% OF THE TOTAL GAS RECEIVED FROM SHIPPERS AS FUEL REIMBURSEMENT WAS CALCULATED TO BE RECEIVED AS LOST AND UNACCOUNTED FOR. THIS PERCENTAGE WAS DERIVED FROM THE DATA UNDERLYING THE 2025 FUEL TRACKER FILING.
INCLUDES INCREASE IN LINE PACK OF:
456,275 DTs
INCLUDES DECREASE IN LINE PACK OF:
57,192 DTs
FOOTNOTE TO INSTRUCTION 5:
TRANSCONTINENTAL GAS PIPE LINE COMPANY, LLC DOES NOT BUNDLE SALES AND TRANSPORTATION SERVICES.
FOOTNOTE TO INSTRUCTION 7:
ALL QUANTITIES OF GAS WERE SUBJECT TO COMMISSION REGULATION.
FOOTNOTE TO INSTRUCTION 9 (3):
CONTRACT STORAGE QUANTITIES ARE AS FOLLOWS:
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|
|
|
|
|
|
|
|
|
|
RATE SCHEDULE
|
DTs
|
RATE SCHEDULE
|
DTs
|
|
ESS
|
5,893,643
|
|
S-2
|
8,723,932
|
|
|
GSS
|
49,362,545
|
|
SS-2
|
8,599,098
|
|
|
LGA
|
231,682
|
|
WSS
|
57,131,844
|
|
|
LNG
|
1,833,323
|
|
LSS
|
10,929,369
|
|
|
LGS
|
0
|
|
|
|
FOOTNOTE TO INSTRUCTION 10:
THERE ARE NO VOLUMES OF PIPELINE PRODUCTION FIELD SALES INCLUDED IN THE TOTAL SALES VOLUMES OR THE TOTAL TRANSPORTATION VOLUMES.
INCLUDES THE FOLLOWING VOLUMES INJECTED INTO STORAGE:
|
|
|
|
|
|
|
GSS
|
8,349,655
|
|
|
LSS
|
187,067
|
|
|
SS-2
|
(866,655)
|
|
|
S-2
|
(2,206,683)
|
|
|
WSS
|
(7,742,013)
|
|
|
LGA
|
(777,769)
|
|
|
LGS
|
0
|
|
|
EMINENCE
|
4,829,214
|
|
|
LNG
|
754,459
|
|
|
TOTAL
|
2,527,275
|
|
INCLUDES THE FOLLOWING VOLUMES INJECTED INTO STORAGE:
|
|
|
|
|
|
|
GSS
|
3,754,298
|
|
|
LSS
|
893,121
|
|
|
SS-2
|
653,956
|
|
|
S-2
|
(436,270)
|
|
|
WSS
|
(2,010,511)
|
|
|
LGA
|
(199,753)
|
|
|
LGS
|
0
|
|
|
EMINENCE
|
359,789
|
|
|
LNG
|
753,302
|
|
|
TOTAL
|
3,767,932
|
|
THE FOLLOWING VOLUMES HAVE BEEN DUPLICATED IN LINE 30, PAGE 520, OR ARE NOT SUBJECT TO ACA SURCHARGES:
1.
GAS SALES (ACCOUNT 480-484), LINE 18, PAGE 520, IN THE AMOUNT OF 0 DT’S.
2.
DELIVERIES OF CONTRACT STORAGE GAS (ACCOUNT 489.4) LINE 22, PAGE 520, IN THE AMOUNT OF 131,938,605 DT’S.
3.
OTHER GAS DELIVERED TO STORAGE, LINE 27, PAGE 520, IN THE AMOUNT OF 2,527,275 DT’S.
4.
OTHER DELIVERIES, LINE 29, PAGE 520, IN THE AMOUNT OF 43,274,088 DT’S.
5.
FEEDERS OF 1,498,023,055 DT’S ARE INCLUDED IN LINE 20, PAGE 520.
6.
DELIVERIES TO WASHINGTON STORAGE OF 43,352,249 DT’S ARE INCLUDED IN LINE 20, PAGE 520.
7.
EXCHANGE GAS DELIVERED TO OTHERS OF 13,030,955 DT’S ARE INCLUDED IN LINE 24, PAGE 520.
8.
GAS DELIVERED AS IMBALANCES OF 20,777,577 DT’S ARE INCLUDED IN LINE 25, PAGE 520.
9.
GAS USED FOR COMPRESSOR STATION FUEL OF 42,376,175 DT’S ARE INCLUDED IN LINE 28, PAGE 520.
BASIS FOR VALUATION OF ALL GAS:
GAS IS VALUED MONTHLY AT A NGW INDEX PRICE WHEN THERE IS A NET EXCESS OF SHIPPER SUPPLIED GAS OR AT TRANSCO'S MONTHLY WACOG WHEN THERE IS A DEFICIENCY OF SHIPPER SUPPLIED GAS.
THE FOLLOWING APPLIES TO ALL VOLUMES, FOR ALL MONTHS, IN LINES 11, 18, 26, 34, 40, AND 56:
VOLUMES WERE ALLOCATED PRORATA TO "DISCOUNTED RATE", "NEGOTIATED RATE", AND "RECOURSE RATE" BASED ON THE ACTUAL VOLUMES PRESENTED ON LINE 4.
PAGE 521, LINE 67
TRANSCO IS A BIDIRECTIONAL PIPELINE THEREFORE THE BACKHAUL DESIGNATION IS NOT APPLICABLE.