GAS TARIFF
OF
COLUMBIA GAS OF VIRGINIA, INC.
CONTAINING
RATE SCHEDULES
AND
(
·,
\.
'
GENERAL TERMS AND CONDITIONS
SEVENTH REVISED VOLUME NO. 1
Communications Covering Rates Should be Addressed to:
President
Columbia Gas of Virginia, Inc.
1809 Coyote ·Drive
Chester, Virginia 23836
(
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 1
TABLE OF CONTENTS
SHEET NO.
PRELIMINARY
~
Preliminary Statement
Rates
2
3
RATE SCHEDULES
,.
l
RS
RTS
MPS
PDS
SGT$1 /SGTS2/SGTS3
SGS1/SGS2/SGS3
ACS
ACTS
UGLS
UGLTS
LGS1/LGS2
SS
TS1/TS2
BBS
LVTS
EDS
DES
CSPS
AS
DPS
DGTS
Residential Service
Residential Transportation Service
Metered Propane Service
Propane Delivery Service
Small General Transportation Service 1, 2 and 3
Small General Service 1, 2 and 3
Air Conditioning Service
Air Conditioning Transportation Service
Unmetered Gas Light Service
Unmetered Gas Light Transportation Service
Large General Service 1 and 2
Standby Service
Transportation Service 1 and 2
Banking and Balancing Service
Large Volume Transportation Service
Economic Development Service
Distributor Exchange Service
Competitive Service Provider Service
Aggregation Service
Demand Polling Service
Daily Gas Transfer Service
100
101
103
104
s
"•
ii
I
I
~
105
107
109
111
113
114
117
121
123
127
134
138
140
142
154
161
163
i
.
I
I"
I!
~
"~
r
I'
~
FORM OF SERVICE AGREEMENTS
300
~
GENERAL TERMS AND CONDITIONS
400
I
t
{
J
(
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 2
PRELIMINARY STATEMENT
Columbia Gas of Virginia, Inc. (hereinafter called the "Company") is a public utility company
engaged in the business of distributing natural gas.
The Company's service area Includes all or a portion of the Counties of Albemarle, Alleghany, Amelia,
Amherst, Appomattox, Augusta, Bedford, Botetourt, Brunswick, Buckingham, Campbell, Caroline, Charlotte,
Chesterfield, Clarke, Culpepper, Cumberland, Dinwiddie, Fairfax, Fauquier, Fluvanna, Giles, Goochland,
Greene, Greensville, Halifax, Isle of Wight, King George, Loudoun, Louisa, Lunenburg, Madison, Mecklenburg,
Nelson, Nottoway, Orange, Page, Pittsylvania, Powhatan, Prince Edward, Prince George, Prince William,
Rappahannock, Rockbridge, Rockingham, Shenandoah, Southampton, Spotsylvania, Stafford, Surry, Sussex
and Warre'n; Cities of Buena Vista, Chesapeake, Clifton Forge, Colonial Heights, Covington, Fredericksburg,
Harrisonburg, Hopewell, Lexington, Manassas, Manassas Park, Lynchburg, Petersburg, Portsmouth, Staunton,
Suffolk, and Waynesboro, and the Towns of Altavista, Bridgewater, Broadway, Brookneal, Chase City,
Chatham, Claremont, Culpepper, Dayton, Dendron, Dumfries, Glasgow, Gordonsville, Haymarket, Herndon,
Hurt, Lawrenceville, Narrows, Pearisburg, Quantico, Rich Creek, Scottsville, Smithfield, South Boston, South
Hill, Stanardsville, Surry, Tlmberv!lle, and Warrenton.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE~2014·00020
ACCEPTED FOR FILING
JANUARY 21, 2016
111VISION OF ENERGY REGULATION-sec
Columbia Gas of Virginia, Inc.
Gas Tariff
Seventh Revised Volume No. 1
Twelfth Revised Sheet No. 3
Superseding Eleventh Sheet No. 3
Base Gas
1112912016
Base
Non-Gas
12/3012016
Base Rate
1213012016
PGA
1112912016
Refunds
11/29/2016
[1)
[2)
[3=1+2)
[4)
[5)
ACA
1112912016
[6]
ll
21
($0.324)
$0.138
TCRC
211/2016
CPA
12130/2016
RNA
1/31/2017
Billing
Rate
1/31/2017
[7]
[8)
[9)
[IO=sum 3 to 9)
II
21
Residential Sales Service (RS) & Metered Propane Service {MPS)
All Gas Consumed I Rate per Dth
$6.464
$4.911
Customer Charge
Infrastructure Reliabilitv & Replacement Adjustment
$11.375
$17.00
($0.04)
$17.00
($0.04)
$4.246
$9.936
$25.00
($0.04)
$25.00
($0.04)
$0.071
($0.021)
$0.000
$0.050
$0.252
$11.403
$17.00
($0.04)
$11.865
$17.00
($0.04)
Small General Service 1 (SGS-1) 0 - 208.9 Dth
All Gas Consumed I Rate per Dth
$5.690
Customer Charge
Infrastructure Reliabilitv & Renlacement Adiustment
$0.068
($0.021)
($0.780)
$0.146
$0.000
$0.015
($0.144)
$9.074
$25.00
($0.04)
$10.000
$25.00
($0.04)
Small General Service 2 (SGS-2) 209.0 - 626.6 Dth
All Gas Consumed I Rate per Dth
$5.690
Customer Charge
Infrastructure Reliability & Replacement Adjustment
$2.465
$8.155
$27.00
($0.11)
$27.00
($0.11)
$2.265
$7.955
$45.00
($0.33)
$45.00
($0.33)
$0.068
($0.021)
($0.780)
$0.146
$0.000
$0.015
$0.282
$7.719
$8.645
$27.00
($0.11)
$27.00
($0.11)
$7.222
$8.148
$45.00
($0.33)
$45.00
($0.33)
Small General Service 3 (SGS-3) > 626.6 Dth
All Gas Consumed I Rate per Dth
$5.690
Customer Charge
Infrastructure Reliabilitv & Replacement Adjustment
$0.068
($0.021)
($0.780)
$0.146
$0.000
$0.000
$0.000
Air Conditioning Service (ACS)
All Volumes Above Base Load
$1.4246
$3.4340
$4.8586
$0.044
$0.000
($0.021)
$0.000
NIA
NIA
$0.000
0.000
NIA
NIA
NIA
NIA
$4.882
(Applicable RS or SGS Customer Charge)
(Applicable RS or SGS lRRA)
Customer Charge
Infrastructure Reliabilitv & Renlacement Adiustment
Unmetered Gas Light Service (UGLS)
First Standard Burner
Each Additional Burner
11.949
11.949
$8.917
8.917
20.866
20.866
$0.143
0.143
($0.044)
(0.044)
($1.638)
(1.638)
$0.307
$0.307
$19.327
$19.327
$21.272
$21.272
With the exception of Column 2, the above rates are effective with meter readings on and after the stated dates.
The above volumetric rates are reflected in Dekatherm C'Dth 11 ). Therm (11 Thm 11 ) rates can be derived by dividing the Dekatherm rates by 10.
II For customers that were fiQ1 on Transportation Service in the last 12 months.
21 For customers that were on Transportation Service in the last 12 months.
INTERIM RATES, SUBJECT TO REFUND
ACCEPTED FOR FILING
PUBLIC UTILITY REGULATION
STATE CORPORATION COMMISSION
JAN 20 2017
Columbia Gas of Virginia. Inc.
Gas Tariff
Seventh Revised Volume No. 1
Twelfth Revised Sheet No. 3A
Superseding Eleventh Sheet No. 3A
Base Gas
Base
Non-Gas
Base Rate
1112912016
1213012016
[1]
[2]
Billing
1213012016
PGA
1112912016
Refunds
11/29/2016
[3=1+2]
[4]
[5]
ACA
11/2912016
[6]
11
21
$0.138
($0.324)
TCRC
2/1/2016
CPA
12/3012016
RNA
Rate
1/31/2017
1/31/2017
[7]
[8]
[9]
[lO~sum
3 to 9]
!/
21
$7.699
$7.237
$17.00
($0.04)
$17.00
($0.04)
$6.611
$5.685
$25.00
($0.04)
$25.00
($0.04)
$5.256
$4.330
$27.00
($0.11)
$27.00
($0.11)
$4.759
$3.833
$45.00
($0.33)
$45.00
($0.33)
Residential Transportation Service {RTS)
All Gas Consumed I Rate per Dth
$2.359
Customer Charge
Infrastructure Reliabilitv & Replacement Adjustment
$4.911
$7.270
$17.00
($0.04)
$17.00
($0.04)
$4.246
$6.605
$25.00
($0.04)
$25.00
($0.04)
$2.465
$4.824
$27.00
($0.11)
$27.00
($0.11)
$2.265
$4.624
$45.00
($0.33)
$45.00
($0.33)
$0.QIO
($0.021)
$0.000
$0.050
$0.252
Small General Transportation Service 1 (SGS-1) 0 - 208.9 Dth
All Gas Consumed I Rate per Dth
$2.359
Customer Charge
Infrastructure Reliability & Replacement Adjustment
$0.010
($0.021)
$0.146
($0.780)
$0.000
$0.015
($0.144)
Small General Transportation Service 2 (SGS-2) 209.0 - 626.6 Dth
All Gas Consumed I Rate per Dth
$2.359
Customer Charge
Infrastructure Reliability & Replacement Adjustment
$0.QIO
($0.021)
$0.146
($0.780)
$0.000
$0.015
$0.282
Small General Transportation Service 3 (SGS-3) > 626.6 Dth
All Gas Consumed I Rate per Dth
$2.359
Customer Charge
Infrastructure Reliabilitv & Replacement Adiustment
$0.QIO
($0.021)
$0.146
($0.780)
$0.000
$0.000
$0.000
Air Conditioning Transportation Service (ACTS)
All Volumes Above Base Load
$2.359
Customer Charge
Infrastructure Reliabilitv & Replacement Adjustment
$1.4246
$3.7836
$0.010
($0.021)
$0.000
$0.000
NIA
NIA
$0.000
0.000
NIA
NIA
NIA
NIA
$3.773
(Applicable RTS or SGTS Customer Charge)
(Aoolicable RS or SGS IRRA)
$4.954
4.954
$8.917
8.917
$13.871
13.871
$0.021
0.021
($0.044)
(0.044)
$0.307
0.307
($1.638)
($1.638)
$14.155
$14.155
$12.210
$12.210
With the exception of Column 2, the above rates are effective with meter readings on and after the stated dates.
The above volumetric rates are reflected in Dekatherm ("Dth"). Therm ("Thrn") rates can be derived by dividing the Dekathenn rates by 10.
II For customers that were IlQ1 on Sales Service in the last 12 months.
21 For customers that were on Sales Service in the last 12 months.
INTERIM RATES, SUBJECT TO REFUND
ACCEPTED FOR FILING
PUBLIC UTILITY REGULATION
STATE CORPORATION COMMISSION
JAN 20 2017
Columbia Gas of Virginia, Inc.
Gas Tariff
Seventh Revised Volume No. 1
Lar~e
General Senrice ~GS-1)
Firm Option:
Monthly Demand Charge
Sixth Revised Sheet No. 4
Superseding Fifth Sheet No. 4
Base Gas
11/29/2016
Base
Non-Gas
12/30/2016
Base
Rate
12/30/2016
PGA
11/29/2016
Refunds
ACA
11/29/2016
Billing
Rate
12/30/2016
[l]
[2]
[3=1+2]
[4]
[5]
[6]
[7=3+4+5+6]
$9.95
$0.00
$9.95
$0.00
$0.00
Firm Option:
First 1,000 Dth
Next 4,000 Dth
Over 5,000 Dth
$3.8850
3.8850
3.8850
$1.4246
0.8078
0.3776
$5.3096
4.6928
4.2626
$0.0440
0.0440
0.0440
$0.0000
0.0000
0.0000
($0.3940)
(0.3940)
(0.3940)
$4.9596
$4.3428
$3.9126
Interruptible Ontion:
First 1,000 Dth
Next 4,000 Dth
Over 5,000 Dth
$3.4340
3.4340
3.4340
$1.4246
0.8078
0.3776
$4.8586
4.2418
3.8116
$0.0440
0.0440
0.0440
$0.0000
0.0000
0.0000
($0.4130)
(0.4130)
(0.4130)
$4.4896
$3.8728
$3.4426
$550.00
($3.44)
$550.00
($3.44)
Customer Charge
Infrastructure Reliability & Replacement Adjustment
$0.00
$9.95
$550.00
($3.44)
Standbv Senrice CSSl)
$9.95
Standbv Option: 11
First 1,000 Dth
Next 4,000 Dth
Over 5,000 Dth
$1.4246
0.8078
0.3776
$1.4246
0.8078
0.3776
$1.4246
$0.8078
$0.3776
Transportation Senrice {TSl)
First 1,000 Dth
Next 4,000 Dth
Over 5,000 Dth
$1.4246
0.8078
0.3776
$1.4246
0.8078
0.3776
$1.4246
0.8078
0.3776
Customer Charge
Infrastructure Reliability & Replacement Adjustment
$550.00
($3.44)
$550.00
($3.44)
$550.00
($3.44)
$9.95
$0.00
$0.00
$0.00
Monthly Demand Charge
$0.00
$9.95
With the exception of Column 2, the above rates are effective with meter readings on and after the stated dates.
11 The Standby Service gas cost commodity charge for Rate Schedule TS-I I TS-2 is the first-of-month mid-point Transco, Zone 6 non-N.Y. index price, as published in Gas
Daily pursuant to Tariff Sheet No. 122 in Case No. PUE-2014-00020.
INTERIM RATES, SUBJECT TO REFUND
ACCEPTED FOR FILING
PUBLIC UTILITY REGULATION
STATE CORPORATION COMMISSION
DEC 28 2016
Columbia Gas of Virginia~ Inc.
Gas Tariff
Seventh Revised Volume No. 1
La:a:;:e General
S~rvice
{LGSw2)
Finn Option:
Monthly Demand Charge
Sixth Revised Sheet No. 4A
Superseding Fifth Sheet No. 4A
Base Gas
11/29/2016
Base
NonwGas
12/30/2016
Base
Rate
12/30/2016
PGA
11/29/2016
Refunds
ACA
11/29/2016
Billing
Rate
12/30/2016
[1)
[2)
[3=1+2)
[4)
[SJ
[6]
[7=3+4+5+6]
DEC 28 2016
$9.95
$0.00
$9.95
$0.00
$0.00
Firm Option:
First 20.000 Dtb
Next 80,000 Dth
Over 100,000 Dth
$3.8850
3.8850
3.8850
$0.4598
$0.2558
$0,2262
$4.3448
4.1408
4.1112
$0.0440
0.0440
0.0440
$0.0000
0.0000
0.0000
($0.3940)
(0.3940)
(0.3940)
$3.9948
3.7908
3.7612
Interruptible Option:
First 20,000 Dth
Next 80,000 Dth
Over 100, 000 Dth
$3.4340
3.4340
3.4340
$0.4598
$0.2558
$0.2262
$3.8938
3.6898
3.6602
$0.0440
0.0440
0.0440
$0.0000
0.0000
0.0000
($0.4130)
(0.4130)
(0.4130)
$3.5248
3.3208
3.2912
$2,700.00
($18.12)
$2,700.00
($18.12)
Customer Charge
Infrastructure Reliability & Replacement Adjustment
$0.00
$9.95
$2,700.00
($18.12)
Standby Service {SS2)
Monthly Demand Charge
$9,95
$0.00
$9.95
Standby Option: 1/
First 20,000 Dth
Next 80,000 Dth
Over 100,000 Dth
$0.4598
$0.2558
$0,2262
$0.4598
0.2558
0.2262
$0.4598
0.2558
0.2262
Transportation Service {TS2)
First 20,000 Dth
Next 80,000 Dth
Over 100,000 Dth
$0.4598
$0.2558
$0.2262
$0.4598
$0.2558
$0.2262
$0.4598
$0.2558
$0.2262
$2,700.00
($18.12)
$2,700.00
($18.12)
$2,700.00
($18.12)
Customer Charge
Infrastructure Reliability & Replacement Adjustment
$0.00
$0.00
$0.00
$9.95
With the exception of Column 2, the above rates are effective with meter readings on and after the stated dates.
1/ The Standby Service gas cost commodity charge for Rate Schedule TS-I I TS-2 is the first-of-month mid-point Transco, Zone 6 non-N. Y. index price, as published in Gas
Daily pursuant to Tariff Sheet No. 122 in Case No. PUE-2014-00020.
INTERIM RATES, SUBJECT TO REFUND
ACCEPTED FOR FILING
PUBLIC UTILITY REGULATION
STATE CORPORATION COMMISSION
Columbia Gas of Virginia, Inc.
Gas Tariff
Seventh Revised Volume No. 1
Fourth Revised Sheet No. 5
Superseding Third Sheet No. 5
Base Gas
11/29/2016
Base
Non-Gas
Base Rate
11/29/2016
PGA
11/29/2016
Refunds
ACA
Billing
Rate
11/29/2016
[3=1+2]
[4]
[5]
[6]
[7=3+4+5+6]
[1]
[2]
5.0%
4.0%
3.0%
2.0%
1.0%
0.5%
$0.0204
0.0176
0.0148
0.0120
0.0093
0.0079
$0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
$0.0204
0.0176
0.0148
0.0120
0.0093
0,0079
$0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
$0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
$0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
$0.0204
0.0176
0.0148
0.0120
0.0093
0.0079
5.0%
4.0%
3.0%
2.0%
1.0%
0.5%
$0.0276
0.0234
0.0191
0.0149
0.0107
0.0086
$0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
$0.0276
0.0234
0.0191
0.0149
0.0107
0.0086
$0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
$0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
$0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
$0.0276
0.0234
0.0191
0.0149
0.0107
0.0086
$6.0160
$0.0000
$6.0160
$0.0000
$0.0000
$0.0000
$6.0160
Bankin2: and Balancin2 Service
Transportation Service (TS1/TS2/LVTS/LVEDTS)
Non-firm
Tolerance Level:
Firm
Volumetric Rate
Tolerance Level:
Demand Rate
ACCEPTED FOR FILING
PUBLIC UTILITY REGULATION
STATE CORPORATION COMMISSION
DEC 28 2016
:1~
ft~=
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
Original Sheet Nos. 6 through 99 of this Tariff are reserved for future use.
(
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 100
SUPERSEDING
ORIGINAL SHEET NO. 100
RATE SCHEDULE RS
RESIDENTIAL SERVICE
ACCEPTED FOR FILING
DIVISIOf'.J OF ENERGY REGULATION
STATE CORPORATION COMMISSION
MAR 2 4 2016
1. APPLICABILITY
Applicable throughout the entire service area of the Company.
2.
AVAILABILITY AND CHARACTER OF SERVICE
Available for all residential uses in any individual residence or multiple family building used for residential
purposes where there is separate metering for each residential unit. Multifamily residences of four units or
less existing on or before September 1, 1990 may continue with single point metering. Service under this
Rate Schedule is subject to the Company's distribution facilities having sufficient capacity and the Company
having adequate gas supply to provide the quantities of gas requested by the Customer.
3. RATE PER MONTH
The rates for service under this Rate Schedule are set forth in the currently effective Rate Sheets of this
Tariff and are incorporated herein. In addition, customers taking service under this Rate Schedule may be
subject to the MAIN Rider, as set forth in Section 21 of the General Terms and Conditions.
4. MINIMUM MONTHLY CHARGE
The minimum monthly charge shall be the Customer Charge.
5,
PURCHASE GAS ADJUSTMENT PROVISION
The rates per Dth prescribed above are subject to adjustment for changes in the Company's cost of gas as
set forth in Section 17 of the General Terms and Conditions.
6.
RECONNECTION CHARGE
Cllstomers who request discontinuance of service and who subsequently request that service be resumed
at the same address will be assessed a reconnection charge equal to: (1) the number of months during
which service is disconnected times the Customer Charge effective for such months and (2) other applicable
special service charges set forth in Section 19 of the General Terms and Conditions. The referenced
Customer Charges shall only be applied when reconnection Is requested within 365 days of disconnection.
7. UNMETERED GAS LIGHTS
Where the Customer receiving service under this Rate Schedule has an unmetered gas light or lights at the
residence, an additional 2.1 Dth per burner per month shall be added to the usage of gas subject to the
monthly per Dth charge set forth in the currently effective Rate Sheets of this Tariff.
8.
GENERAL TERMS AND CONDITIONS
Service under this Rate Schedule Is subject to the currently effective General Terms and Conditions, as
contained in this Tariff, as well as all applicable Rules and Regulations of the Virginia State Corporation
Commission, as may be amended from time to time.
Effective Date: June 1, 2016
Per February 19, 2016 Final Order In Case No. PUE-2015-00056
FIRST REVISED SHEET NO. 101
SUPERSEDING
ORIGINAL SHEET NO, 10·1
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
RATE SCHEDULE RTS
RESIDENTIAL TRANSPORTATION SERVICE
A.CCEPiTD FOF< FILING
D~VISIO!~ OF ENEHGY REGULATION
SltUE CORPORATION COMM/SS/OM
MAR 2 4 2016
1. APPLICABILITY
Applicable throughout the entire service territory of the Company.
2.
AVAILABIL11Y AND CHARACTER OF SERVICE
Available to any residential customer who:
a. Has an account balance that is current; and
b. Selected a Competitive Service Provider ("CSP") and is part of that CSP's Customer Group, which must
consist of at least 100 customers or at least 10,000 0th of annual throughput;
As a condition of receiving service under this Rate Schedule, the Customer's CSP must remain In
compllance with the provisions of Rate Schedule CSPS, the Company's General Terms and Conditions of
Service, and applicable Rules and Regulations of the Virginia State Corporation Commission ("SCC"),
including but not limited to the SCC's Rules Governing Retail Access to Competitive Energy Services 20 VAC
5-312-10 et seq, as may be amended from time to time. The failure of the Customer's CSP to comply with
those requirements may result in the termination of service to Customer under the provisions of this Rate
Schedule, in which event the Customer would revert to sales service under Rate Schedule RS.
Service under this Rate Schedule is subject to the Company's distribution facilities having sufficient capacity
to transport the quantities of gas requested by the Customer.
3, RATE PER MONTH
The rates for service under this Rate Schedule are set forth In the currently effective Rate Sheets of this Tariff
and are Incorporated herein. In addition, customers taking service under this Rate Schedule may be subject
to the MAIN Rider, as set forth In Section 21 of the General Terms and Conditions.
4.
MINIMUM MONTHLY CHARGE
The minimum monthly charge shall be the Customer Charge.
5.
UNMETERED GAS LIGHTS
Where the Customer receiving service under this Rate Schedule has an unmetered gas light or llghts at the
residence, an additional 2.1 Dth per burner per month shall be added to the usage of gas that is subject to
the monthly per Dth charge set forth In the currently effective Rate Sheets of this Tariff.
6.
GENERAL TERMS AND CONDITIONS
Service under this Rate Schedule is subject to the currently effective General Terms and Conditions, as
contained In this Tariff, as well as all applicable Rules and Regulations of the sec, Including but not limited to
the Rules Governing Retail Access to Competitive Energy Services 20 VAC 5-312-10 et seq., as may be
amended from time to time.
7,
ENROLLMENT AND SWITCHING
Enrollment and switching shall be subject to the provisions of Section 5 - Customer Sign-up and Removal
Procedures, of Rate Schedule CSPS. In the event Customer is removed by a CSP and Customer is not
enrolled by another CSP, then such Customer shall revert to sales service from the Company under Rate
Schedule RS.
Effectlve Date: June 1, 2016
Per February 19, 2016 Final Order In Case No. PUE-2015-00056
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 102
RATE SCHEDULE RTS
RESIDENTIAL TRANSPORTATION SERVICE
{continued)
8.
RECONNECTION CHARGE
Customers who request discontinuance of service and who subsequently request that service be
resumed at the same address will be assessed a reconnection charge equal to: (1) the number of months
during which service is disconnected times the Customer Charge effective for such months and (2) other
applicable special service charges set forth In Section 19 of the General Terms and Conditions. The
referenced Customer Charges shall only be applled when reconnection Is requested within 365 days of
disconnection.
At the time service is resumed, Customers will Initially receive sales service from the Company. Customers
will be informed of their right to choose a CSP to provide natural gas commodity service.
Effective Date: February 1, 2016
Per Auaust 21, 2015 Final Order in Case No. PUEH2014'00020
ACCEPTEIJ FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
·/,
~~~
~s
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 103
RATE SCHEDULE MPS
METERED PROPANE SERVICE
(This rate schedule Is no longer available for the installation of new propane tank farms.)
1. APPLICABILITY
Applicable throughout the. entire service area of the Company.
2.
AVAILABILITY
This rate is only available to any residential or commercial Customers pursuant to the following paragraph.
Pursuant to the Orders of the State Corporation Commission Issued in case Nos. PUE-1997-00455 and
PUE-1998-00287, this Rate Schedule Is only available (1) for the addition of new cust9mers to existing
systems or the fulfillment by the Company of Its commitments, existing as of December 21, 1995 to
additional facilities to existing MPS systems; or (2) upon approval by the State Corporation Commission of a
request by the company for a waiver to add new customers not covered under (1) above.
3.
RATE PER MONTH
The rates for service under this Rate Schedule are set forth in the currently effective Rate Sheets of this
Tariff and are Incorporated herein. The applicable metered propane volumes shall be converted by
multiplying those volumes by a factor of 2.5 to achieve a natural gas equivalent quantity for billing purposes.
4. MINIMUM MONTHLY CHARGE
The minimum monthly charge will be the applicable Customer Charge.
5.
RECONNECTION CHARGE
Customers who request discontinuance of service and who subsequently request that service be resumed
at the same address will be assessed a reconnection charge equal to: (1) the number of months during
which service is disconnected times the Customer Charge effective for such months and (2) other applicable
special service charges set forth tn Section 19 of the General Terms and Conditions. Such charges shall
only be applied when reconnection is requested within 365 days of disconnection. For this purpose, any
sixteen days of a month shall be considered a full month.
6. GENERAL TERMS AND CONDITIONS
Service under this Rate Schedule is subject to the currently effectlve General Terms and Conditions, as
contained in this Tariff, as well as all applicable Rules and Regulations of the Virginia State Corporation
Commission, as may be amended from time to time.
Effective Date: February 1j 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 104
RATE SCHEDULE FOR PDS
PROPANE DELIVERY SERVICE
1. APPLICABILITY
Applicable throughout the entire service area of the Company.
2. AVAILABILITY
This rate Is available to any residential or commercial Customer for any usual purpose, Including space
heating, within the Company's service area when natural gas and the facilities to provide such service are
not currently available, but are planned and approved by the Company \o become available within twenty~
four months.
3. RATE PER MONTH
The rates for service under this Rate Schedule are set forth in the currently effective Rate Sheets or this
Tariff and are incorporated herein.
This rate will recover the cost of propane purchased to provide this service.
4.
MINIMUM MONTHLY CHARGE
The minimum monthly charge will be the applicable Customer Charge.
5.
I\
RECONNECTION CHARGE
Customers who request discontinuance of service and who subsequently request that service be resumed
at the same address will be assessed a reconnection charge equal to: (1) the number of months during
which service is disconnected times the Customer Charge effective for such months and (2) other applicable
special service charges set forth in Section 19 of the General Terms and Conditions. The referenced
Customer Charges shall only be applied when reconnection Is requested within 365 days of disconnection.
6. GENERAL TERMS AND CONDITIONS
Service under this Rate Schedule Is subject to the currently effective General Ter.ms and Conditions, as
contained in this Tariff, as well as all applicable Rules and Regulations of the Virginia State Corporation
Commission, as may be amended from time to time.
(
"
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTEl:YFOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
FIRST REVISED SHEET NO. 105
SUPERSEDING
ORIGINAL SHEET N0.105
COLUMBIA GAS OF VIRGINfA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
RATE SCHEDULE SGTS1, SGTS2 and SGTS3
SMALL GENERAL TRANSPORTATION SERVICE
1.
t\CCl::fl I UJ HJf\ l·ILING
DIVISION OF ENrnGY REGULATIO~,l
STf\TE CORPOHATION COMMISSION
MAR 211 2016
APPLICABILITY
Applicable throughout the entire service area of the Company.
2.
AVAILABILITY AND CHARACTER OF SERVICE
a.
Available to any non-residential customer who:
i.
Has an account balance that Is current;
and
ii.
b.
c
d.
3.
Selected a Competitive Service Provider ("CSP") and Is part of that CSP's Customer Group, which
must consist of at least 100 customers or at least 10,000 Dth of annual throughput.
As a condition of receiving service under this Rate Schedule, the Customer's CSP must remain In
compliance with the provisions of Rate Schedule CSPS, the Company's General Terms and Conditions
of Service, and applicable Rules and Regulations of the Virginia State Corporation Commission ("SCC"),
including but not limited to the SCC's Rules Governing Retail Access to Competitive Energy Services 20
VAC 5-312-10 et seq., as may be amended from time to time. The failure of the Customer's CSP to
comply with those requirements may result in the termination of service to Customer under the provisions
of this Rate Schedule, In which event the Customer would revert to sales service under Rate Schedule
SGS1/SGS2/SGS3 unless the customer immediately requests service under Rate Schedule
LGS1/LGS2.
Rate Schedule SGTS1 is designed for Customers with an annual throughput of up to 208.9 Dlh. Rate
Schedule SGTS2 is designed for Customers with an annual throughput greater than 208.9 Dth and less
than or equal to 626.6 Dth. Rate Schedule SGTS3 is designed for Customers with an annual throughput
of greater than 626.6 Dth. For new customers added after September 29, 2014 with less than twelve
months of billing history at the PSID, the election of Rate Schedule SGTS1, SGTS2 or SGTS3 shall be
solely within the discretion of the Customer with assistance from Company personnel. For new
customers added after September 29, 2014 with twelve months of billing history at the PSID a
determination of the proper Rate Schedule SGTS series will be made by the Company based on the
weather normalized billing quantities for the previous twelve months, For Customers existing at
September 29, 2014 with twelve months of billing history a determination of the proper Rate Schedule
SGTS series wlll be made by the Company based on the weather normalized billing quantities for the
previous twelve months, For Customers existing at September 29, 2014 with less than twelve months of
bllllng history a determination of the proper Rate Schedule SGTS series will be made by the Company
based on an annuallzation of actual billed consumptlon or estimation based on the customers installed
natural gas equipment to determine the annualized weather normalized billing quantities, The Company
may periodically review customer consumption to determine if Customers are being billed under the
proper series of the SGTS Rate Schedule.
Service under this Rate Schedule is subject to the Company's distribution facilities havlng sufficient
capacity to transport the quantities of gas requested by the Customer.
RATE PER MONTH
The rates for service under this Rate Schedule are set forth In the currently effective Rate Sheets of this
Tariff and are Incorporated herein. In addition, customers taking service under Rate Schedules SGTS1 and
SGTS2 may be subject to the MAIN Rider, as set forth in Section 21 of the General Terms and Conditions.
Effective Date: June 1, 2016
Per February 19, 2016 Final Qrdar In Case No. PUE"2015·00056
Ii
I
I
I
I
I!
I
I
\
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 106
RATE SCHEDULE SGTS1, SGTS2 AND SGTS3
SMALL GENERAL TRANSPORTATION SERVICE
(continued)
4.
MINIMUM MONTHLY CHARGE
The minimum monthly charge shall be the Customer Charge.
5.
UNMETERED GAS LIGHTS
Where the Customer receiving service under this Rate Schedule has an unrnetered gas light or lights at the
service address, an additional 2.1 Dth per burner per month shall be added to the usage of gas that is
subject to the monthly per Dth charge set forth In the currently effective Rate Sheets of this Tariff.
6. GENERAL TERMS AND CONDITIONS
Service under this Rate Schedule Is subject to the currently effective General Terms and Conditions, as
contained In this Tariff, as well as all applicable Rules and Regulations of the sec Including, but not limited
to, the Rules Governing Retail Access to Competitive Energy Services 20 VAC 5-312-10 et seq., as may be
amended from time to time.
·
1.
ENROLLMENT AND SWITCHING
Enrollment and switching shall be subject to the provisions of Section 6 - Customer Sign-up and Removal
Procedures, of Rate Schedule CSPS. In the event Customer is removed by a CSP and Customer Is not
enrolled by another CSP, then such Customer shall revert to sales service from the Company under Rate
Schedule SGS, unless the customer immediately requests service under Rate Schedule LGS1/LGS2.
{
'
8.
RECONNECTION CHARGE
Custpmers who request discontinuance of service and who subsequently re·quest that service be resumed
at the same address will be assessed a reconnection charge equal to: (1) the number of months during
which service is disconnected times the Customer Charge effective for such months and (2) other applicable
special service charges as set forth in Section 19 of the General Terms and Conditions. The referenced
Customer Charges shall only be applied when reconnection is requested within 366 days of disconnection.
. At the time service is resumed, Customers will initially receive sales service from the Company. Customers
w!ll be informed of their right to choose a CSP to provide natural gas commodity service.
/
\
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
FIRST REVISED SHEET NO. 107
SUPERSEDING
ORIGINAL SHEET NO. 107
COLUMBIA GAS OF VIRGJNIA, INC,
GAS TARIFF
SEVENTH REVlSED VOLUME NO. 1
f\C~GEPTUJ
RATE SCHEDULE SGS1, SGS2 AND SGS3
SMALL GENERAL SERVICE
1.
FOR. nwm
DIVISION OF EMERGY REGULAflON
STATE GORPOPJ\TION COMMISSION
MAR 2 Li 2016
APPLICABILITY
Applicable throughout the entire service area of the Company.
2.
AVAILABILITY AND CHARACTER OF SERVICE
Available to any non-residential Customer on a firm basis provided that:
a.
The Company's existing distribution facilities have sufficient capacity and the Company has adequate
gas supply to provide the quantities of gas requested by the Customer;
and
b.
Service under this Rate Schedule shall not be available as standby, peaking service, or as a substitute
for service under any other Rate Schedule of this Tariff. Service under this Rate Schedule shall be
separately metered;
and
c.
Rate Schedule SGS 1 is designed for Customers with an annusl throughput of up to 208.9 Dth. Rate
Schedule SGS2 Is designed for Customers with an annual throughput greater than 208.9 Dth and
less than or equal to 626.6 Dth. Rate Schedule SGS3 is designed for Customers with an annual
throughput of greater than 626.6 Dth. For new customers added after September 29, 2014 with less
than twelve months of billing history at the PSID, the election of Rate Schedule SGS1, SGS2 or
SGS3 shall be solely within the discretion of the Customer with assistance from Company personnel.
For new customers added after September 29, 2014 with twelve months of billing history at the PSID
a determination of the proper .Rate Schedule SGS series will be made by the Company based on the
weather normalized billing quantities for the previous twelve months, For Customers existing at
September 29, 2014 with twelve months of bllllng history a determination of the proper Rate Schedule
SGS series will be made by the Company based on the weather normalized billing quantities for the
previous twelve months, For Customers existing at September 29, 2014 with less than twelve months
of billing history a determination of the proper Rate Schedule SGTS series will be made by the
Company based on an annualizatlon of actual billed consumption or estimation based on the
customers installed natural gas equipment to determine the annualized weather normalized billing
quantities, The Company may periodically review customer consumption to determine if Customers
are being billed under the proper series of the SGS Rate Schedule.
and
d.
3.
Customers with maximum Daily Requirements in excess of 50 Dth per day may be required to execute
a Service Agreement specifying Customer's service requirements.
RATE PER MONTH
The rates for service under this Rate Schedule are set forth In the currently effective Rate Sheets of this
Tariff and are Incorporated herein. In addition, customers taking service under Rate Schedules SGS1 and
SGS2 may be subject to the MAIN Rider, as set forth in Section 21 of the General Terms and Conditions.
Effective Date: June 1, 2016
Per February 19, 2016 Final Order In Case No. PUE·2015·00056
COLUMBIA GAS OF VIRGINIA, INC.
GASTAF{IFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 108
RATE SCHEDULE SGS1, SGS2 AND SGS3
SMALL GENERAL SERVICE
(continued)
4.
MINIMUM MONTHLY CHARGE
The minimum monthly charge shall be the Customer Charge.
5. PURCHASE GAS ADJUSTMENT PROVISION
The rates per Dth as prescribed above are subject to adjustment for changes in the Company's cost of gas
as set forth in Section 17 of the General Terms and Conditions.
6.
RECONNECTION CHARGE
Customers who request discontinuance of service and who subsequently request that service be resumed
at the same address will be assessed a reconnection charge equal to: (1) the number of months during
which service is disconnected times the Customer Charge effective for such months and (2) other applicable
special service charges set forth in Section 19 of the· General Terms and Conditions. The referenced
Customer Charges shall only be applied when reconnection is requested within 365 days of disconnection.
7. GENERAL TERMS AND CONDITIONS
{
\.
Service under this Rate Schedule ls subject to the currently effective General Terms and Conditions, as
contained in this Tariff, as well as all applicable Rules and Regulations of the Virginia State Corporation
Commission, as may be amended from time to time.
Effective Date: February 1, 2016
Per Auaust 21 2015 Final Order in Case No. PUE~2014-00020
ACCEPTED'""FOR FIL1NG
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME N0.1
FIRST REVISED SHEET NO. 109
SUPERSEDING
ORIGINAL SHEET NO. 109
RATE SCHEDULE ACS
AIR CONDITIONING SERVICE
r.ccc:1~·1 r.::D f:OI\ FtLl~JG
O:\/;SJON OF ENERGY REGULATION
STAIE COl~PORATION COMMISSION
MAR 2 4 2016
1. APPLICABILITY
Throughout the entire service area of the Company.
2.
AVAILABILITY AND CHARACTER OF SERVICE
Available to any existing or potential residential, commercial or Industrial customer, requiring gas service for
the operation of air conditioning equipment during the summer months of May through September each
year, provided the Customer's premises are air conditioned by the Lltilization of gas as the principal energy
supply.
Service under this Rate Schedule is subject to the Company's distribution facllltles having sufficient capacity
and the Company having adequate gas supply to provide the quantities of gas requested by the Customer.
3.
RATES
The rates for service under this Rate Schedule are set forth in the currently effective Rate Sheets of this
Tariff and are incorporated herein. In addition, customers taking service under this Rate Schedule may be
subject to the MAIN Rider, as set forth In Section 21 of the General Terms and Conditions.
4.
SPECIAL PROVlSIONS
For non-residential customers, service under this rate schedule shall be determined and billed on the basis
of gas used in excess of the estimated usage of appliances for purposes other than summer air
conditioning. For residential customers, service under this rate schedule shall be determined and billed on
the basis of gas used in excess of 2.1 Dth per month. The Company reserves the right to determine
residential usage in excess of summer air conditioning In. the same manner as it does for non-residential
customers.
All gas used, other than that billed at the summer air conditioning rate, shall be billed at the effective rates of
the other tariffs under which the customer is served.
5.
PURCHASE GAS ADJUSTMENT PROVISION
The rates per Dth prescribed above are subject to adjustment for changes In the Company's cost of gas as
set forth in Section 17 of the General Terms and Conditions.
6.
RECONNECTION CHARGE
Customers who request discontinuance of service and who subsequently request that service be resumed
at the same address will be assessed a reconnection charge equal to: (1) the number of months during
which service is disconnected times the Customer Charge effective for such months and (2) other applicable
special service charges set forth in Section 19 of the General Terms and Conditions. The referenced
Customer Charges shall only be applied when reconnection Is requested within 365 days of disconnection.
Effective Date: June 1, 2016
Per February 19, 2016 Final Order In Case No. PUE-2015-00056
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET N0.110
RATE SCHEDULE ACS
AIR CONDITIONING SERVICE
(continued)
7.
GENERAL TERMS AND CONDITIONS
Service under this Rate Schedule is subject to the currently effective General Terms and Conditions, as
contained ln this Tariff, as well as all applicable Rules and Regulations of the Virginia State Corporation
Commission, as may be amended from time to time.
(
(
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
FIRST REVISED SHEET NO. 111
SUPERSEDING
ORIGINAL SHEET NO. 111
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
/\CC::PTED FOR
RATE SCHEDULE ACTS
AIR CONDITIONING TRANSPORTATION SERVICE
FIUl~G
DIVISION or: ENEl1GV REGULATION
STATE COr<POR/\TION COMMISSION
1. APPLICABILITY
Throughout the entire service area of the Company.
2.
AVAILABILITY AND CHARACTER OF SERVICE
a. Available to any existing or potential residential, commercial or industrial customer, requiring gas
transportation service for the operation of air conditioning equipment during the summer months of May
through September each year, provided the Customer's premises are air conditioned by the utilization of
gas as the principal energy supply who:
i.
Has an account balance that Is current;
and
Ii.
Selected a Competitive Service Provider ("CSP") and is part of that CSP's Customer Group, which
must consist of at least 100 Customers or at least 10,000 Dth of annual throughput served by that
CSP.
b. As a condition of receiving service under this Rate Schedule, the Customer's CSP must remain in
compliance with the provisions of Rate Schedule CSPS, the Company's General Terms and
Conditions of Service, and applicable Rules and Regulations of the Virginia sec, Including but not
limited to the SCC's Rules Governing Retail Access to Competitive Energy Services, as may be
amended from time to time. The failure of the Customer's CSP to comply with those requirements
may result in the termlnatlon of service to Customer under the provisions of this Rate Schedule, In
which event: (i) a residential Customer would revert to sales service under Rate Schedules RS and ACS;
and (II) a non-residential Customer would revert to sales service under Rate Schedules SGS and ACS.
c. Service under this Rate Schedule ls subject to the Company's distribution facllities having sufficient
capacity to transport the quantities of gas requested by the Customer.
3. RATE PER MONTH
The rates for service under this Rate Schedule are set forth In the currently effective Rate Sheets of this
Tariff and are Incorporated herein. In addition, customers taking service under this Rate Schedule may be
subject to the MAIN Rider, as set forth in Section 21 of the General Terms and Conditions.
4.
SPECIAL PROVISIONS
For non-residential Customers, service under this Rate Schedule shall be determined and billed on the
basis of gas used in excess of the estimated usage of appliances for purposes other than summer air
conditioning. For residential Customers, service under this Rate Schedule shall be determined and billed on
the basis of gas used in excess of 2.1 Dth per month. The Company reserves the right to determine
residential usage In excess of summer air conditioning in the same manner as it does for non-residential
Customers.
All gas used, other than that billed at the summer air conditioning rate, shall be bllled at the effective rates of
the other rate schedules under which the Customer Is served.
Effective Date: June 1, 2016
Per February 19, 2016 Final Order in Case No. PUE-2015-00056
COLUMBIA GAS OF VlRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 112
RATE SCHEDULE ACTS
AIR CONDITIONING TRANSPORTATION SERVICE
(continued)
5.
GENERAL TERMS AND CONDITIONS
Service under this Rate Schedule Is subject to the currently effective General Terms and Conditions, as
contained In this Tariff, as well as all applicable Rules and Regulations of the Virginia SCC Including, but not
limited to, the Rules Governing Retail Access to Competitive Energy Services, as may be amended from time
to time.
6. ENROLLMENT AND SWITCHING
Enrollment and switching shall be subject to the provisions of Section 5 - Customer Sign-up and Removal
Procedures, of Rate Schedule CSPS. ln the event Customer Is removed by a CSP and Customer is not
enrolled by another CSP, then a residential Customer shall revert to sales service from the Company under
Rate Schedules RS and ACS, and a non-residential Customer shall revert to sales service from the Company ·
under Rate Schedules SGS and ACS.
7. RECONNECTION CHARGE
{
\
Customers who request discontinuance of service and who subsequently request that service be resumed at
the same address will be assessed a reconnection charge equal to: (1) the number of months during which
service is disconnected times the Customer Charge effective for such months and {2) other applicable
special service charges set forth in Section 19 of the Genera! Terms and Conditions. The referenced
Customer Charges shall only be applied when reconnection is requested within 365 days of disconnection.
At the time service is resumed, Customers will Initially receive sales service from the Company. Customers
will be Informed of their right to choose a CSP to provide natural gas commodity service.
(
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 113
RATE SCHEDULE UGLS
UNMETERED GAS LIGHT SERVICE
1. APPLICABILITY
Applicability throughout the entire service area of the Company.
2. AVAILABILITY AND CHARACTER OF SERVICE
a. Gas Service under this schedule is available to any non-residential Customer within Company's service
area for use In unmetered gas lighting equipment.
b. Service under this Rate Schedule ls subject to the Company's distribution facilities having sufficient
capacity and the Company having adequate gas supply to provide the quantities of gas requested by
the Customer.
3. RATE! PER MONTH
The rates for service under this Rate Schedule are set forth in the currently effective Rate Sheets of this
Tariff and are incorporated herein.
·4,
SPECIAL CONDITIONS
a. Gas service under this schedule !s for use exclusively In unmetered gas lighting equipment;
and
(
b. The minimum standard consumption rate for gas under this Rate Schedule shall be 2.1 Dth per burner
per month. However, in the event the gas usage specifications for the Customer's gas light equipment
is greater than the minimum standard consumption rate, the Customer's consumption rate for billing
purposes shall be established according to the specifications of the Customer's equipment.
5.
PURCHASED GAS ADJUSTMENT
The rates prescribed above are subject to an adjustment for any change In the Company's cost of gas as
set forth In Section 17 of the General Terms and Conditions.
6.
GENERAL TERMS AND CONDITIONS
Service under this Rate Schedule is subject to the currently effective General Terms and Conditions, as
contained In this Tariff, as well as all applicable Rules and Regulations of the Virginia State Corporation
Commission, as may be amended from time to time.
(
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
OIVISION OF ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 114
.RATE SCHEDULE UGLTS
UNMETERED GAS LIGHT TRANSPORTATION SERVICE
1. APPLICABILITY
Applicability throughout the entire service area of the Company.
2. AVAILABILITY AND CHARACTER OF SERVICE
a. Available to any nonresidential customer who:
(i) has an account balance that Is current;
and
(ii) selected a Competitive Service Provider ("CSP") and Is part of that CSP's Customer Group, which
must consist of at least 100 customers or at least 10,000 Dth of annual throughput.
b. As a condition of receiving service under this Rate Schedule, the Customer's CSP must remain in
compl!ance with the provisions of Rate Schedule CSPS, the Company's General Terms and Conditions
of Service, and applicable Rules and Regulations of the Virginia State Corporation Commission {"SCC")
Including, but not limited to, the SCC's Rules Governing Retail Access to Competitive Energy Services
20 VAC 5-312-10 et seq., as may be amended from time to time. The failure of the Customer's CSP to
comply with those requirements may result in the termination of service to Customer under the provisions
of this Rate Schedule, In which event the Customer would revert to sales service under Rate Schedule
UGLS.
c. Service under this Rate Schedule is subject to the Company's distribution facilities having sufficient
capacity to transport the quantities of gas requested by the Customer.
3.
RATE PER MONTH
The rates for service under this Rate Schedule are set forth in the currently effective Rate Sheets of this
Tariff and are Incorporated herein.
4.
SPECIAL CONDITIONS
a. Gas transportation service under this Rate Schedule is for use exclusively in unmetered gas Ughtlng
equipment. Service wlll not be rendered for resale, use off of the Customer's premises, or any other
use.
b. The minimum standard consumption rate for gas under this Rate Schedule shall be 2.1 Dth per burner
per month. However, in the event the gas usage specifications for the Customer's gas light equipment
is greater than the minimum standard consumption rate, the Customer's consumption rate for billing
purposes shall be established according to the specifications of the Customer's equipment.
5. GENERAL TERMS AND CONDITIONS
Service under this Rate Schedule is subject to the currently effective General Terms and Conditions, as
contained In this Tariff, as well as all applicable Rules and Regulations of the sec including, but not limited
to, the Rules Governing Retail Access to Competitive Energy Services 20 VAC 5-312-10 et seq., as may be
amended from time to time.
(
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET N0.115
RATE SCHEDULE UGLTS
UN METERED GAS LIGHT TRANSPORTATION SERVICE
(continued)
6.
ENROLLMENT AND SWITCHING
Enrollment and switching shall be subject to the provisions of Section 5 - Customer Sign-up and Removal
Procedures, of Rate Schedule CSPS. In the event Customer Is removed by a CSP and Customer is not
enrolled by another CSP, then such Customer shall revert to sales service from the Company under Rate
Schedule UGLS.
(
{
'\.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014·00020
ACCEPTEIJFOR FILING
JANUARY 21, ;1016
nl\/1810N OF ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 116
SUPERSEDING
ORIGINAL SHEET NO. 116
RATE SCHEDULE LGS1 and LGS2
LARGE GENERAL SERVICE
1.
APPLICABILITY
Applicable throughout the entire service area of the Company.
2.
3.
AVAILABILITY
a.
This Rate Schedule is available to any non-residential Customer, except as otherwise stated herein.
Firm sales service and interruptible sales service will be provided under this Rate Schedule.
b.
Rate Schedule LGS 1 is designed for Customers with monthly throughput less than 20,888 Dth. Rate
Schedule LGS 2 is designed for customers with monthly throughput greater than 20,888 Dth. The
election of Rate Schedule LGS1 or LGS2 shall be solely within the discretion of the Customer and
shall be binding on the Customer for the 12-month period commencing with such election. A notice of
a change in the election between Rate Schedules LGS1 and LGS2 must be provided to Company at
least 30 days prior to the anniversary date of the Service Agreement and such change will be
effective only on such annual anniversary date.
c.
The Customer will be required to sign a service agreement setting forth all terms and conditions of
service.
d.
Service under this Rate Schedule is subject to the Company's distribution facilities having sufficient
capacity and the Company having adequate gas supply to provide the quantities of gas requested by
the Customer.
e.
The .Company's daily delivery quantity in excess of a Customer's contracted Daily Firm Quantity is
subject to complete or partial interruption at the Company's discretion. In such event, the Customer will
be notified of its Authorized Daily Quantity.
CHARACTER OF SERVICE
a.
Firm Quantities
The Daily Firm Quantity of the Customer shall be contracted for by the Company from its supplier(s) and
represent a firm service obligation for the Company and no interruption of the Customer's Daily Firm
Quantity is planned in the course of the Company's normal operations. However, the Company
reserves the right to completely or partially curtail LGS1 and LGS2 Firm Sales Service pursuant to its
General Terms and Conditions.
b.
Interruptible Quantities
Interruptible quantities contracted by the Customer will be subject, at the Company's discretion, to
complete or partial interruption at any time and of any duration.
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
FIRST REVISED SHEET NO. 117
SUPERSEDING
ORIGINAL SHEET NO. 117
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
RATE SCHEDULE LGS1 and LGS2
LARGE GENERAL SERVICE
(continued)
4.
SERVICE TERMS AND CONDITIONS
a.
Customer may contract for a Daily Firm Quantity in Dth up to its Maximum Daily Quantity;
and
b.
The Customer also may contract for an Interruptible Quantity that shall, in total, be the difference, if any,
between the Maximum Daily Quantity and the specified Daily Firm Quantity;
and
c.
The Customer is responsible for providing and maintaining alternative fuel storage and combustion
facilities, for having available at all times sufficient alternate fuel to maintain desired levels of plant
operations during periods of interruption of non-firm sales quantities, and for the lack of alternative fuel
storage and combustion facilities. In the event Customer does not purchase Firm Service under this
Rate Schedule, the Company will in no way be obligated to provide uninterrupted sales service to
Customer;
and
d.
Service under this Rate Schedule shall not be available as a standby or back up gas supply for service
under any other'Rate Schedule of this Tariff;
and
e.
On an annual basis, a Customer's "Maximum Daily Quantity" will be automatically adjusted to the
Customer's actual Maximum Daily Quantity based on the Customer's highest daily consumption
experienced during the preceding twenty-four (24) month period ending with March billings. The
Company shall have the discretion to further adjust a Customer's Maximum Daily Quantity for good
cause shown. Notwithstanding the foregoing, in no event shall such an adjustment reduce the
Customer's Maximum Daily Quantity below its contracted Daily Firm Quantity;
and
f.
The Company's ability to accommodate requests for increases or decreases in Daily Firm Quantity is
subject to availability of gas supply capacity and the impact on the Company's other Customers.
Accordingly, the Company will make a good faith effort to accommodate such requests, but cannot
assure accommodation. Any such requests should be received by the Company at least one (1) year
before the proposed effective date in order to provide sufficient time for the processing of such requests.
5. RATE
a.
Rates applicable to this Rate Schedule are set forth in that portion of the currently effective Rate Sheets
of this Tariff and are hereby incorporated into this Rate Schedule; and
b.
Monthly charges for service under this Rate Schedule will be:
i.
Applicable Customer Charge;
ii.
Firm Demand Charge (Firm Demand Rate times contracted Daily Firm Quantity);
Effective Date: September 28, 2016
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Division of Energy Regulation
Accepted for Filing
September 14, 2016
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 118
SUPERSEDING
ORIGINAL SHEET N0.118
RATE SCHEDULE LGS1 and LGS2
LARGE GENERAL SERVICE
(continued)
6.
iii.
Firm Commodity Charge (Firm Commodity Rate times Firm Commodity Quantities delivered);
iv.
Interruptible Commodity Charge (Interruptible Commodity Rate times Interruptible Commodity
Quantities delivered).
MINIMUM MONTHLY CHARGE
The minimum monthly charge shall be the Customer Charge referenced in Section 5(b)(i) above, plus the
Demand Charge set forth in Section 5b(ii) above. However, if the Daily Firm Quantity supply of gas is
interrupted during any billing month, pursuant to Sections 5 or 10 of the General Terms and Conditions, the
demand charge shall be pro-rated on the number of days service was provided.
7.
PENALTY CHARGE FOR FAILURE TO INTERRUPT OR CURTAIL
If on any day, after the Company has provided notice to interrupt or curtail pursuant to this Rate Schedule or
the General Terms and Conditions, the Customer fails to limit its use of gas hereunder to the applicable
Authorized Daily Quantity, Authorized Partial Day Quantity or Authorized Monthly Quantity, the Customer
shall be billed penalties and charges as defined in Section 10.6 of the General Terms and Conditions, in
addition to all other applicable charges under this Rate Schedule.
8.
UNAUTHORIZED OVERRUNS OF MAXIMUM DAILY QUANTITIES
If on any day that an interruption or curtailment has not been issued, the Customer utilizes gas in excess of
its Maximum Daily Quantity without the prior approval of the Company, such excess usage will be billed at
the 100% load factor LGS base non-gas demand rate, plus the applicable LGS1 or LGS2 base non-gas
quantity rate, plus 120% of the Transco, zone 6 non-N.Y." citygate price as published in Gas Daily for that
day.
9.
AUTHORIZED OVERRUNS OF MAXIMUM DAILY QUANTITIES
If the Customer has obtained prior approval from the Company, in writing or by electronic mail, to use
quantities in excess of the Maximum Daily Quantity, such excess usage will be billed at the 100% load
factor LGS base non-gas demand rate, plus the applicable LGS1 or LGS2 base non-gas quantity rate, plus
the midpoint Transco, zone 6 non-N.Y. citygate prices as published in Gas Daily for that day.
10. PURCHASED GAS ADJUSTMENT PROVISION
The Demand Charges and Commodity Charges shall be adjusted to reflect changes in the demand charges
of upstream suppliers from which the Company purchases contract demand service and commodity
charges from its gas suppliers, pursuant to Section 17 of the General Terms and Conditions.
11. TERM OF CONTRACT
The term of contract for service under this Rate Schedule shall be as set forth in the Service Agreement, but
shall not be less than one year.
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET N0.119
SUPERSEDING
ORIGINAL SHEET N0.119
RATE SCHEDULE LGS1 and LGS2
LARGE GENERAL SERVICE
(continued)
12. OPTIONAL ALTERNATE FUEL DISPLACEMENT SERVICE
For those Customers purchasing interruptible sales service under this Rate Schedule, the Company may
flex its commodity charges so as to meet the Customer's alternate energy cost. Gas service provided under
this option will be on a best efforts basis and quantities made available to any Customer shall not exceed
the Customer's alternate fuel buying capability.
A rate per Dth shall be established by the Company in excess of the monthly Dth equivalent of the weighted
average commodity cost of gas. Provided, however, a lower floor may be established, subject to
Commission approval, if the company demonstrates that in the absence of the lower floor rate sales will be
lost and the lower floor results in no harm to the Company's other sales Customers. The cost of gas
underlying the lower floor rate shall not be less than the highest average cost of gas being purchased for
general system supply. The floor price shall be the equivalent gas cost, plus ten cents ($0.10) per Dth, plus
allowance for applicable taxes.
The ceiling price shall be at a rate no greater than the 100% load factor firm rate under this Rate Schedule.
Customer shall submit a monthly affidavit to the Company on or before the fifteenth (151h) day of the
month providing the following information:
a.
b.
Prior billing period usage of displacement service; and
Projected price of the applicable alternate fuel and estimated usage for current billing period.
The Company shall determine the rate for the following month by the twentieth (201h) day of the month, and
the customer shall commit in writing to the Company its intent on how much gas it will use the following
month. The Company may enter into a supply contract to cover the needs of the Customer.
By receiving any service under this provision, the Customer shall be deemed to have installed operable
capability for long-term use of alternate fuel, and the Company shall be entitled to rely upon such
representations without further investigation. The Company may, but is not obligated to also inquire through
existing independent sources about current local pricing of alternate fuel, and may utilize, but is not limited
to, one or more of the following publications to assist it in determining the monthly rate:
a.
b.
c.
d.
e.
Platt's Oilgram;
Energy User News;
Oil Daily;
Platt's Bunkerwire; or
Natural Gas Intelligence.
13. DAILY DEMAND MEASUREMENT
a.
A daily demand meter with an electronic measurement (EM) or automatic meter reading (AMR)
device and associated telemetering equipment must be installed at the service location of each
Customer electing service under this Rate Schedule, consistent with specifications established by the
Company. The daily demand meter and associated telemetering equipment shall be and remain the
property of the Company. The Customer or its designee shall have the right to obtain the once daily
update of Customer's actual consumption information, for the prior gas day ending at 10:00 a.m.
Eastern, via a web based process made available by Company, at no cost to the Customer.
Additionally, the Customer may have the ability to use the Company's optional Demand Polling
Service, subject to availability and the terms and conditions of Rate Schedule DPS, to access
metering data at any time within a day at the Customer's discretion.
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 120
RATE SCHEDULE LGS1 and LGS2
LARGE GENERAL SERVICE
(continued)
b. The Customer shall own and maintain a dedicated telephone source and the AC power, if necessary,
to operate all daily demand measurement equipment. The Customer will pay for the initial installation
of such dedicated telephone line or alternative telecommunications technology. The Customer shall
use its best efforts to ensure that the telephone source and AC power are operational at all times.
Failure to comply with this requirement shall not serve as the basis for a waiver of penalties or
charges that are assessed as a consequence of Customer's failure to comply with operational
requirements under this Rate Schedule or the General Terms and Conditions. In the event that
Company notifies Customer that the telephone source is inoperable, Customer shall restore the
operablllty of its telephone source within 10 days. If the Company Is unable to read the Customer's
meter remotely due to the Customer's failure to maintain the telephone source, the Customer shall
pay the Company $84 for each instance that the Company is required to manually read the meter.
14. GENERAL TERMS AND CONDITIONS
Service under thls Rate Schedule Is subject to the currently effective General Terms and Conditions, as
contained in this Tariff, as well as all applicable Rules and Regulations of the Virginia State Corporation
Commission, as may be amended from time to time.
15. RECONNECTION CHARGE
Customers who request discontinuance of service and who subsequently request that service be resumed
at the same address will be assessed a reconnection charge equal to: (1) the number of months during
which service ls disconnected times the Customer Charge effective for such months and (2) other applicable
special service charges set .forth in Section 19 of the General Terms and Conditions. The referenced
Customer Charges shall only be applied when reconnection is requested within 365 days of disconnection.
Effective Date: February 1, 2016
Per A@ust 21I2015 Final Order in Case No. PUEM2014-00020
ACCEPTE[)FOR FIL NG
JANUARY 21, 2016
nl\/IRlnN ()F FNFR(W RFr:\l 11 ATION-sr.c
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 121
SUPERSEDING
ORIGINAL SHEET NO. 121
RATE SCHEDULE SS
STANDBY SERVICE
1.
APPLICABILITY
Applicable throughout the entire service area of the Company.
2.
AVAILABILITY
Available to any Customer taking service under Rate Schedule TS1fTS2 or LVTS, which is located on the
Company's distribution system. Service is available under this Rate Schedule, provided that:
a.
The service can be rendered within the limits of the Company's operating conditions and facilities;
and
b.
The Standby Service contracted under this Rate Schedule does not exceed the Customer's Maximum
Daily Quantity under the applicable rate schedules;
and
c.
The Customer executes a Service Agreement or an Addendum to its Service Agreement providing for
the purchase of a specified level of standby quantity;
and
d.
The Company's distribution facilities have sufficient capacity and the Company has adequate gas
supply to provide the quantities of gas requested by the Customer;
and
e.
3.
The Company's ability to accommodate requests for increases or decreases in Standby Service is
subject to the availability of adequate gas supply and capacity and the impact on the Company's other
Customers. Accordingly, the Company will make a good faith effort to accommodate such requests, but
cannot assure accommodation. Any such requests should be received by the Company at least one (1)
year before the proposed effective date in order to provide sufficient time for the processing of such
requests.
CHARACTER OF SERVICE
The Customer's contracted Standby Service quantities are available for use by subscribing Customers on a
daily basis to satisfy any daily requirements not served by flowing supply quantities scheduled by or on
behalf a subscribing Customer and/or by a subscribing Customer's available and Company authorized
banked supply quantities. The Standby Service requirements of the Customer will represent a firm service
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 122
SUPERSEDING
ORIGINAL SHEET N0.122
RATE SCHEDULE SS
STANDBY SERVICE
(continued)
obligation for the Company and no interruption of standby quantities is planned in the course of the
Company's normal operations. However, the Company reserves the right to completely or partially curtail
Standby Service pursuant to its General Terms and Conditions.
4.
RATE
The demand component of the rates applicable to this Rate Schedule are set forth in the currently effective
Rate Sheets of this Tariff and are hereby incorporated into this Rate Schedule.
Monthly charges for service under this Rate Schedule will be:
5.
a.
Demand Charge - Demand Rate times the contracted Standby Demand Quantity.
b.
Commodity Charge - The first-of-month mid-point Transco, zone 6 non-N.Y. index price, as published in
Gas Daily, times the standby quantities delivered for the month.
c.
Delivery Charge - Applicable Rate Schedule TS-1/TS-2 rate block(s) quantity transportation rate
multiplied by the standby quantities delivered.
MINIMUM MONTHLY CHARGE
The minimum monthly charge shall be the Demand Charge referenced in 4a. above.
6.
PURCHASED GAS ADJUSTMENT PROVISION
The Demand Charge shall be adjusted to reflect changes in the demand charges of upstream suppliers
from which the Company purchases contract demand service pursuant to Section 17 of the General Terms
and Conditions.
7.
TERM OF CONTRACT
Service under this Rate Schedule shall be effective for a minimum primary term of twelve (12) months
ending on October 31 of a designated year, and year to year thereafter, unless or until cancelled by either
Customer or Company by giving written notice no later than April 1 to be effective on November 1 of such
year.
8.
GENERAL TERMS AND CONDITIONS
Service under this Rate Schedule is subject to the currently effective General Terms and Conditions, as
contained in this Tariff, as well as all applicable Rules and Regulations of the Virginia State Corporation
Commission, as may be amended from time to time.
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 123
RATE SCHEDULE TS1 AND TS2
TRANSPORTATION SERVICE 1AND2
1. APPLICABILITY
Applicable throughout the entire service area of the Company.
2. AVAILAl31LITY AND CHARACTER OF SERVICE
a. Transportation Service under th!s Rate Schedule is an interruptible service available to any
nonresidential pustomer located on the Company's distribution system for the transportation and
delivery of natural gas through the Company's distribution facllltles, Including a Customer that is part of
an Aggregation Nomination Group (ANG) as defined in Rate Schedule AS"Aggregatlon Service.
b. Customer agrees to discontinue Its takes under this Rate Schedule for the periods and to the extent
requested by Company pursuant to the provisions of this Rate Schedule and the General Terms and
Conditions. Except as otherwise provided with respect to "emergencies" as contemplated in Section 10
of the Company's General Terms and Conditions and applicable rules, regulations, and orders of the
State Corporation Commission, interruption of de!iveries by the Company of end-user's dally scheduled
and confirmed supply quantities delivered to the Company at the PSP behind which Customer's
facilities are located shall be due to the Company's system delivery capacity limitations only,
'/
c.
(
Rate Schedule TS1 Is designed for Customers whose anticipated monthly throughput is less than
20,888 Dth. Rate Schedule TS2 Is designed for Customers whose anticipated monthly throughput is
greater than 20,888 Dth. The election of Rate Schedule TS1 or TS2 shall be solely within the
discretion of the Customer and shall be binding on the Customer for the· 12-month period
commencing with such election. A notice of a change in the election between Rate Schedules TS1
and TS2 must be provided to Company at least 30 days prior to the anniversary date of the Service
Agreement and such change will be effective only on such annual anniversary date.
d. Gas service under this Rate Schedule will be available when the Company has executed a Service
Agreement with the Customer under which the Company agrees to transport and deliver quantities of
gas for the Customer as contempiated in this Rate Schedule.
e. Service under this Rate Schedule ls subject to the Company's distribution facilities having sufficient
capacity to transport the quantities of gas requested by the Customer.
f.
The Company will not be required to deliver on any day more than the lesser of: (i} a quantity of gas
equ!valen,t to Customer's Maximum Dally Quantity specified in its Service Agreement; (ii) the quaritity
of gas scheduled and confirmed to be delivered Into the Company's distribution facilities on behalf of
the Customer on that day plus applicable Standby Sales and available Firm Banking and Balanclng
Service quantities; or (iii} the Customer's Authorized Daily Quantity.
g. On an annual basis, a Customer's "Maximum Daily Quantity" and "Annual lransportation Quantity"
will be automatically adjusted to the Customer's actual Maximum Daily Quantity and actual Annual
Transportation Quantity based on the Customer's highest daily and annual consumption experienced
during the preceding two consecutive 12~month periods ending with March billings. Upon a
Customer's request, the Company shall have the discretion to further adjust a Customer's Maximum
Dally Quantity and Annual Transportation Quantity for good cause shown.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
OIVISION OF ENERGY REGULATION-SCC
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 124
RATE SCHEDULE T51 AND TS2
TRANSPORIATION SERVICE 1AND2
{continued)
h. The Company will furnish information to, and receive information from, its Customers by means of the
Company's designated Internet based Website ("Website"). The Customer or Its designee must be
capable of utilizing, and agrees to utilize, the Website for communications specified in this Rate
Schedule,. including all nominations and confirmations for service under this Rate Schedule, as well
as receipt of interruption notices and Balancing Service Restrictions ("BSRs") as contemplated in this
Rate Schedule, Rate Schedule BBS or the Company's General Terms and Conditions. The Customer
and/or its designee shall complete all Website training and testing processes as may reasonably be
required by Company, both prior to and during any time the Customer is taking service under this
Rate Schedule, to ensure appropriate use of and access to the Website. Alternative means of
communication may be used for BSR and interruption notices, In lleu of the Website, such as
facsimile, telephone or email, as may be deemed appropriate by the Company under the
circumstances.
i.
3.
CUSTOMER OBLIGATIONS AS A MEMBER OF AN AGGREGATION NOMINATION GROUP
a.
I
.,
\
)
The Customer shall provide notice to the Company, in writing, of the name and address of any agent or
marketer ("Agent") delivering gas supplies to the Company's city gate for the Customer's account at
least thirty (30) days prior to the commencement of the month in which deliveries are to commence.
The Customer shall advise the Company, In writing, of any change In status with respect to any Agent
delivering gas supplies to the Company for the Customer's account. All such written notices shall be In
the form of an Addendum to the Service Agreement. However, the Company w!ll endeavor to work with
the Customer and Its designated agent to authorize dellveries by a third party supplier on less than 30
days notice where such notice ls Impracticable.
Each Customer to be included In an ANG, as defined in Rate Schedule AS - Aggregation Service, shall
execute an Appointment of Agent and Acknowledgement of Service Form before becoming a
participant in an ANG. In the event that the Customer's Agent providing service pursuant' to Rate
Schedule AS terminates service to Customer and Customer fails to otherwise arrange for alternative
service from an Agent under the provisions of Schedule AS, the Customer will immediately revert to
non~aggregated ~ervice under this Rate Schedule.
b. Each Customer that becomes part of an Agent's ANG, as defined in Rate Schedule AS, will retain
ultimate responsibility for any and all charges, fees and penalties applicable under the terms and
conditions of Rate Schedule AS, Rate Schedule BBS and the Company's General Terms and
Conditions in the event that the Agent falls to pay within the time prescribed in the Company's Tariffs
and/or General Terms and Conditions, notwithstanding the fact that the Company will bill the Agent
for such charges, fees and penalties. Any such unpaid charges, fees and penalties will be assessed
to Customers within each ANG on a pro rata basis based on the ratio of each Customer's gas usage
to the usage of all Customers participating in that ANG during the month for which the charge, fee
and/or penalty Is applied. The charges, fees and penalties to which this provision is applicable
Include, but are not limited to, excess bank tolerance charges, BSR penalties and charges,
commodity charges associated with excess consumption (except with regard to customer specific
Interruptions of transportation service), daily gas transfer fees, late payment charges and charges for
an Agent's access to its Customers' daily demand measurement information.
"'
Per Auaust
21~
Effective Date: February 1, 2016
2015 Final Order in Case No. PUE-2014-00020
ACCEPTEIJ"FOR Fll1NG
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 125
RATE SCHEDULE TS1 AND TS2
TRANSPORTATION SERVICE 1AND2
(continued)
4.
CASH.OUT OPTION
Customers who choose not to subscribe to Banking and Balancing Service under Rate Schedule BBS will
be cashed-out on a daily basis by the Company as follows: On days when gas consumed by a Customer
exceeds the quantities of gas delivered Into the Company's system on the Customer's behalf plus
contracted Standby Service quantities, Customer will purchase such excess quantities from Company at
120% of the mid-point Transco, zone 6 non-N.Y. citygate price as published in Gas Daily for the day on
which such Excess Quantities were delivered to Customer. On days when gas delivered into the
Company's system on a Customer's behalf exceeds the quantities consumed· by the Customer, Company
will purchase those excess delivered quantities from the Customer at 1;30% of the mid-point Transco, zone
6 non-N.Y. citygate price as published in Gas Daily for the day on which such excess delivered quantities
were received. by Company. The Company's ability to accommodate daily Imbalances between
Customer-owned supply and demand is provided on an interruptible basis. On those days when the
Company has invoked a BSR pursuant to the provisions of Rate Schedule BBS, this ability shall be
completely or partially interrupted. ln such event, the Customer will be notified of the applicable
Interruption in the same manner as, and simultaneous with, notices to Customers subscribing to Rate
Schedule BBS, which notice shall correspondingly serve as the basis of the Cash-Out Customer's
Authorized Dally Quantity or Authorized Daily Supply. On those days when the Company has invoked
such an Interruption and on those days when the Company has requested a subscribing Customer to
curtail or interrupt, the Customer wlH be subject to the additional charges identified In Section 10.6 of the
General Terms and Conditions for failure to comply with such Authorized Daily Quantity or Authorized
Daily Supply. The purchased gas coi:its associated with any commodity purchases and sales pursuant to
this Section shall be flowed through the Company's PGA mechanism (including the Actual Cost
Adjustment).
,..
\
5.
DAILY DEMAND MEASUREMENT
a. A dally demand meter with an electronic: measurement (EM) or automatic meter reading (AMR)
device and associated telemetering equipment must be Installed at the service location of each
Customer electing service under this Rate Schedule, consistent with specifications established by the
Company. The dai\y demand meter and associated telemetering equipment shall be and remain the
property of the Company. The Customer or Its deslgnee shall have the right to obtain the once daily
update of Customer's actual consumption information, for the prior gas day ending at 10;00 a.m.
Eastern, via a web based process made available by Company, at no cost to the Customer.
Additionally, the Customer or its deslgnee may have the ability to use the Company's optional
Demand Polling Service, subject to availability and the terms and conditions of Rate Schedule DPS,
to access metering data at any time within a day at the Customer's or Its deslgnee's discretion.
(
b. The Customer shall own and maintain a dedicated telephone source and the AC power, if necessary,
to operate all dally demand measurement equipment. The Customer will pay for the initial installation
of such dedicated telephone line or alternatlve telecommunications technology. The Customer shall
use Its best efforts to ensure that the telephone source and AC power are operational at all times.
Failure to comply with this requirement shall not serve as the basis for a waiver of penalties or
charges that are assessed as a consequence of Customer's failure to comply with operational
requirements under this Rate Schedule or the General Terms and Conditions. In the event that
Company notifies Customer that the telephone source is inoperable, Customer shall restore the
operability of its telephone source within 10 days. If the Company is unable to read the Customer's
meter remotely due to the Customer's failure to maintain the telephone source, the Customer shall
pay the Company $84 for each instance that the Company is required to manually read the meter.
Effective Date: February 1, 2016
Per Auaust 21, 2015 Final Order in Case No. PUE·2014·00020
ACCEPTEIJ'FOR FllJNG
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 126
RATE SCHEDULE TS1 AND TS2
TRANSPORTATION SERVICE 1AND2
(continued)
6.
RATES
a. The rates for Transportation Service under this Rate Schedule are set forth In the currently effective
Rate Sheets of this Tariff and are incorporated herein.
b. When a Customer can demonstrate to the Company that a lower rate Is necessary to meet competition
from an alternate energy supplier, the Company may transport gas at a rate lower than the Rate Sheets
of this Tariff. The Company may also, after receiving prior approval from the Virginia State Corporation
Commission, transport gas at a lower rate than the currently effective Rate Sheets of this Tariff when
the Customer has demonstrated that its only alternative would be a shutdown or relocation of facilities.
7.
MINIMUM MONTHLY CHARGE
The minimum monthly charge shall be the Customer Charge.
8. DETERMINATION OF DELIVERIES
The quantity of gas transported pursuant to this Rate Schedule shall be the quantities delivered to the
Company by the Customer or on the Customer's behalf, less 1.0% of the total quantities so delivered, as
retainage for Company use and unaccounted for gas on the Company's distribution system.
(
9.
BACK-UP SERVICE
The Customer ,is responsible for providing and maintaining alternate fuel storage and combustion facilities
and for having available at all times sufficient alternate fuel to maintain desired levels of plant operation
during periods of interruption or curtailment, including any period when a BSR has been issued by
Company. In the event a Customer purchasing transportation services under this Rate Schedule does not
purchase Standby Service as backup for such transportation service, the Company will in no way be
obligated to provide backup sales service to Customer.
10. PENALTY CHARGE FOR FAILURE TO INTERRUPT OR CURTAIL
If on any day, after the Company has provided notice to interrupt or curtail pursuant to this Rate Schedule
or the General Terms and Conditions, the Customer falls to curtail or interrupt its use of gas hereunder to
the Customer's applicable Authorized Dally Quantity, Authorized Partial Day Quantity or Authorized
Monthly Quantity, the Customer shall be billed penalties and charges as defined in Section 10.6 of the
General Terms and Conditions, in addition to all other applicable charges under this Rate Schedule.
11. GENERAL TERMS AND CONDITIONS
Service under this Rate Schedule is subject to the currently effective General Terms and Conditions, as
contained In this Tariff, as well as all applicable Rules and Regulations of the Virginia State Corporation
Commission, as may be amended from time to time.
( ··.
\
...
Effective Date: February 1, 2016
Per AuQust 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTErJFOR FllJNG
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 127
RATE SCHEDULE BBS
BANKING AND BALANCING SERVICE
1. APPLICABILITY
Applicable throughout the entire service area of the Company.
2. AVAILABILITY AND CHARACTER OF SERVICE
a. Banking and Balancing Service ls an optional service that is available, on either a firm or non-firm
basis, to Customers subscribing to transportation service under Rate Schedule TS1/TS2 or LVTS,
including a Customer that Is part of an Aggregation Nomination Group under Rate Schedule AS.
b. A Customer may subscribe to Banking and Balancing Service to account for the Company's
balancing of daily differences between gas delivered into the Company's system on the Customer's
behalf and quantities consumed by the Customer.
c.
(
Customer's gas quantities received by the Company but not delivered to the Customer at its facf!ltles
on any given day shall be referred to as "banked quantities" or a "Quantity Bank." A Customer shaU
be permitted to add supply quantities to its Quantity Bank or draw supply quantities from its Quantity
Sank subject to the provlsions of this Rate Schedule.
d. The Company's provision of Firm Banking and Balancing Service Is conditioned upon the Company's
ability to secure the assets necessary to provide the service and wlll be provided on a first-come firstserved basis. If sufficient assets are not available to provide Firm Banking and Balancing Service,
Customers will have the option of subscribing to Non-Firm Banking and Balancing Service under this
Rate Schedule or the Cash-Out Option available under the transportation Rate Schedule applicable
to the Customer.
e.
Banking and Balancing Service will be available when the Customer has executed a Service Agreement
or an Addendum to its transportation Service Agreement with the Company, under which the Company
agrees to provide Banking and Balancing Service to Customer.
f.
The ability of a Customer to access or build a Quantity Bank will be subject to restriction, in whole or In
part, when directed by the Company pursuant to the provisions of this Rate Schedule. Customers agree
to comply wfth such restrictions for the duration(s} and to the extent directed by Company.
furnl~h information to, and receive Information from, its Customers by means of the
Company's designated Internet based Website ("Website"). The Customer or Its deslgnee must be
capable of utilizing, and agrees to utilize, the Website for communications specified In this Rate
Schedule, Including receipt of interruption notices and Balancing Service Restrictions ("BSRs") as
contemplated in this Rate Schedule and the Company's General Terms and Conditions. The
Customer and/or its designee shall complete all Website training and testing processes as may
reasonably be required by Company, both prior to and during any time the Customer is taking service
under this Rate Schedule, to ensure appropriate use of and access to the Website. Alternative
means of communication may be used for BSR and Interruption notices, in lieu of the Website, such
as facsimile, telephone or email, as may be deemed appropriate by the Company under the
circumstances.
g. The Company will
(
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 128
RATE SCHEDULE BBS
BANKING AND BALANCING SERVICE
{continued)
h. The Bank Tolerance fees and Firm Banking and Balancing Service fees derived from this service
shall flow through the Company's PGA mechanism (including the Actual Cost Adjusfment).
3.
AVAILABLE SERVICE OPTIONS
a. Non-Firm Banking and Balancing Service
A Customer subscribing to Non-Firm Banking and Balancing Service wlll have the ability to maintain a
bank from day to day on the Company's system and to access banked gas, or build Quantity Banks, on a
non-firm basis. On days when the Company has Issued a BSR restricting under-deliveries of customerowned gas, Customer access to banked quantities may be limited completely or In part. On days when
the Company has issued a BSR restricting over-deliveries of Customer-owned gas, a Customer's ability
to build a Quantity Bank may be limited completely or in part. The monthly Bank Tolerance levels that are
available under this Rate Schedule are 5%, 4%, 3%, 2%, 1% or W/o of a Customer's Annual
Transportation Quantity.
b. Firm Banking and Balancing Service
A Customer subscribing to Non-Firm Banking and Balancing Service may also subscribe to Firm Banking
and Balancing Service. A Customer subscribing to Firm Banking and Balancing Service will have the
ability to maintain a bank on the Company's system and to access banked quantities, or build a Quantity
Bank, on a firm basis on any day, including days on which a BSR'has been implemented by the Company
under the conditions set forth below. On days when the Company has issued a BSR restricting underdeliveries of customer-owned gas, the Company will deliver up to ten percent (10%) of a Customer's
effective Maximum Dally Quantity on a firm basis. In such instances, Customer access to Firm Banking
and Balancing Service quaniities Is conditioned upon the Customer having adequate supplies In its bank
to support the Company's delivery of the Customer's Firm Banking and Balancing Service quantities. On
days when the Company has implemented a BSR that restricts over-deliveries of Customer-owned gas,
the Customer will be entitled to dellver to the Company up to one hundred five percent (105%) of the
maximum prescribed delivery authorized by the Company.
4.
SERVICE PROVISIONS
a. Customers subscribing to Banking and Balancing Service under this Rate Schedule wlll be subject to
the service obligattons set forth In this Rate Schedule as well as the service obligations set forth In the
Customer's applicable transportation Rate Schedule, any applicable Service Agreement, and the
General Terms and Conditions.
b.
(
Customers subscribing to Banking and Balancing Service under this Rate Schedule will be allowed to
maintain a bank balance, accounted for at the conclusion of each billing month, no greater than the
designated Bank Tolerance. All quantities residing In a Customer's Quantity Bani< at the conclusion
of a billing month in excess of the designated Bank Tolerance shall be subject to an excess bank
tolerance fee of thirty~two cents ($.32) per Dth. In addition, in the event Customer's Quantity Bank
exceeds Its Bank Tolerance level and the Company incurs a storage-overrun penalty imposed by an
upstream pipe!ine(s), the Customer shall be assessed its proportionate share of such penalties.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF.ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 129
RATE SCHEDULE BBS
BANKING AND BALANCING SERVICE
(continued)
If in any billing month in which the Company issues a BSR to restrict access to previously banked
supp{y quantities pursuant to Paragraph 7 of this Rate Schedule or invokes an interruption of
transportation service pursuant to the provisions of Rate Schedule TS1/TS2 or LVTS, a Customer
develops a Quantity Bank in excess of its subscribed Bank Tolerance, then the aforementioned
charge for an excess Bani< Tolerance shall be waived by the Company, on a non-discriminatory
basis, for that billing month. Notwithstanding the foregoing, the penalty shall not be waived: (i) to the
extent that the applicable BSR or Interruption permitted access to a portion of the Customers banked
quantities; and (ii) to the extent that the Customer had a reasonable opportunity, following the
issuance of the BSR or interruption of transportation service, to bring Its Quantity Bani< within Its
designated tolerance.
c.
(
For any billing month when the Company's deliveries to the Customer at Its facilities exceed
Customer's deliveries to Company plus the Customer's contracted daily Standby Service quantities,
available banked quantities, and Daily Gas Transfer Service Quantities, the Customer wiH be bllled for
any such excess consumption ("Excess Quantities") at the average of the midMpoint Transco, zone 6
Non-N.Y. cltygate prices for deliveries as published in Gas Daily for the month In which such Excess
Quantities are delivered. The foregoing charges are in addition to any penalties, fees and charges to
the Customer pursuant to this Rate Schedule.
d. A Customer may elect to change its Bank Tolerance no more than one time in any calendar year. A
Customer may elect Firm Banking and Balancing Service once each calendar year. Notification of
such changes and/or elections must be provided to the Company in writing by submitting an
Addendum to the Service Agreement by April 1, to become effective on the following November 1.
In such instance, Firm Banking and Balancing Service quantities will be granted on a first-come f!rstserved basis in accordance with the provisions of Firm Banking and Balancing Service.
e. A Customer's ability to utilize _banked quantities may be limited, completely or In part, during any
period In which a curtailment or interruptl.on, including a BSR, has been imposed pursuant to the
Customer's applicable transportation Rate Schedule or the General Terms and Conditions.
f.
Banking and Balancing Service Is based on current policies, practices, and procedures of the
Company's Interstate pipe!lne supp!ler(s). Should any of the Company's interstate pipeline suppliers
modify its policies, practices or procedures in a manner which makes it Impracticable for the
Company to continue to offer such balancing services pursuant to the provisions set forth herein,
Company shall have the right to modify the provisions of Its Banking and Balancing Service to the
extent Company deems necessary, subject to appropriate regulatory approval. The Company shall
provide notice to Customers served under this Rate Schedule in the event such right Is exercised.
Nothing In this provision shall limit the Company's future ability to modify this provision or this Rate
Schedule.
(
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE~2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 130
RATE SCHEDULE BBS
BANKING AND BALANCING SERVICE
(continued)
g. Monthly Bank Transfers
Monthly bank transfers will be permitted between one Customer/Agent ("transferor") and another
Customer/Agent {"transferee") located behind the same PSP and having confirmed deliveries on the
same transmission pipeline. Transfers may also be permitted, solely at the discretion of the
Company, between a transferor and a transferee located behind different PSPs and having confirmed
deliveries on the same transmission pipeline. Ali such transfers may only be requested once a month
to be effective for the upcoming billing cycle and must be requested within three (3) business days after
the conclusion of the Customers' monthly billing cycle. A charge of $15.00 per monthly bank transfer
transaction will be b!lfed to the transferor.
h. Disposition of banked quantities upon termination of service:
(1) In the event service under this Rate Schedule is terminated by a Customer that is not a
participant In an Aggregation Nomination Group (ANG), the customer will be entitled to (i) take
delivery of any quantities residing In a Customer's Quantity Bank at the date of termination during
the next billing month pursuant to the terms and conditions of this Rate Schedule, or (ii) transfer
such quantities pursuant to the provisions of sub-section (g), above. Should any quantities reside
in a Customer's Quantity Bank at the conclusion of this next billlng month, the Company will
purchase the remaining bank quantities from the Customer. The purchase price paid by the
Company will be 80% of the mid-point Transco, .zone 6 non-N.Y. citygate price as publlshed In
Gas Daify for the last day that the Customer was ellgible to utilize its banl<ed quantities pursuant
to this provision.
(ii) In the event service under this Rate Schedule is terminated by a Customer that is a participant in
an ANG, no portion of the associated ANG's Quantity Bank wllf be assigned to or accessible for
use by the Customer.
(HI) In the event a Customer taking service under this Rate Schedule elects to move to another ANG,
no portion of the ANG's Quantity Bank wiH be assigned to the Customer or accessible for use by
the Customer or the new ANG.
5. RATES
a. The Firm and Non-Firm rates for Banking and Balancing Service under this Rate Schedule are set forth
in the currently effective Rate Sheets of this Tariff and are incorporated herein. The effective rates under
this Rate Schedule shall be applied to the quantities delivered by the Company to the Customer at its
facility.
{\.
b. When a Customer can demonstrate to the Company that a lower rate is necessary to meet competition
from an alternate energy supplier, the Company may provide Banking and Balancing Service at a rate
lower than the Rate Sheets of this Tariff. The Company may also, after receiving prior approval from
the Virginia State Corporation Commission, provide Banking and Balancing Service at a lower rate than
th\3 currently effective Rate Sheets of this Tariff when the Customer has demonstrated that its only
alternative would be a shutdown or relocation offacilitles.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FJLING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 131
RATE SCHEDULE BBS
BANKING AND BALANCING SERVICE
(continued)
6.
MINIMUM MONTHLY CHARGE
There is no minimum monthly charge for Non-Firm Banking and Balancing Service. The minimum monthly
charge for Firm Banking and Balancing Service shall be the demand charge.
7.
BALANCING SERVICE RESTRICTIONS {BSR)
a. Definition
A BSR is a demand for specific action by, or on behalf of a Customer. A BSR will direct Customer(s)
to adjust their consumption or their daily scheduled deliveries such that the Customer's deliveries to
the Company's system wlll, as closely as practicable, match Its daily consumption or a specified
portion thereof. All Customers are subject to the Company's Issuance of BSRs. The issuance of a
BSR may result In a partial or complete restriction of Banking and Balancing Service as contemplated
In this Rate Schedule. A BSR may be Issued on a system-wide basis, by PSP, market or operating
area (depending on the designation by a pipeline or the Company for purposes of its operations), by
such other geographic area as appropriate under the circumstances, or by individual customer.
b. Criteria
The Company has the authority to issue a BSR whenever the Company has a reasonable basis for
concluding, based on information available tci it at the time, that the sum total of the capacity and
supply that it has call upon on a firm basis, exclusive of the Company's dedicated non-storage
peaking supplies, will be insufficient to simultaneously satisfy the Company's firm service obllgatlons
and the non-firm banking and balancing requirements of its interruptible transportation Customers.
For purposes of this section, peaking supplies shall mean those firm supp/!es having a limited number
of day's availability and that are available to the Company only during the winter operating period
(November through March) Inclusive of propane and liquefied natural gas.
The following operating conditions shall be considered by the Company when evaluating the need to
issue BSRs:
1. actual and forecasted temperatures;
2. actual and estimated demand on the Company's system;
3. non-peaking capacity and supply that the Company has call upon on a firm basis; and
4. actual and estimated storage activity and storage inventory compared to the Company's
seasonal operating parameters for storage and to the operating standards of its upstream
service providers.
The need for BSRs will typically be determined the day prior to the actual applicabfe gas day. The
actual BSR level called for will generally be based on the Company's estimate of its balancing
capabilities for a given day(s). The Company shall terminate a BSR as soon as its operating
conditions permit.
l
\
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY21, 2016
DIVISION OF ENERGY REGULATION-sec
FIRST REVISED SHEET NO. 132
SUPERSEDING
ORIGINAL SHEET NO. 132
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
RATE SCHEDULE BBS
BANKING AND BALANCING SERVICE
(continued)
c.
Types of BSRs
(i} BSRs Restricting Under-Deliveries - The Company shall have the authority to direct
Customers to adjust their daily consumption or daily scheduled deliveries, completely or in part,
such that the Customer's actual consumption is no greater than the Customer's Authorized Daily
Quantity. In such event, a Customer will be entitled to use gas quantities that are: 1) scheduled
and delivered on that day; 2) contracted for under the Rate Schedule SS - Standby Service; 3)
available pursuant to the Company's Firm Banking and Balancing Service option; 4) additional
banked quantities that may be made available to the Customer by the Company at its discretion
on a best-efforts basis; and 5) available pursuant to a transfer under the Company's Daily Gas
Transfer Service. The sum total of the resultant Company-determined supply entitlement for use
by a Customer shall be the Customer's Authorized Daily Quantity.
(ii) BSRs Restricting Over-Deliveries - The Company shall have the authority to direct Customers
to adjust their daily scheduled deliveries to an amount no greater than the Customer's daily
consumption. In such event, the Company shall specify the limitation placed upon the deliveries
in excess of a Customer's actual daily consumption. Such limitations will recognize and include
Firm Banking and Balancing Service quantities for subscribing Customers. The sum total of the
resultant Company-determined supply to be received by the Company on behalf of a Customer
shall be the Customer's Authorized Daily Supply. Under circumstances as determined by the
Company, the Company may provide an alternative delivery point to which a Customer may
choose to deliver quantities of natural gas in excess of the above referenced limitation.
d. Operational Alert (OA)
An Operational Alert (OA) may be issued by the Company when actual or projected variances between
Customer delivered supplies and Customer demand are likely to adversely impact the Company's
storage operations and/or the Company's ability to operate within the contract limitations applicable
under the Company's service provider contracts. An OA is a request for voluntary action on the part of
a Customer. An OA may be issued in an effort to avoid a BSR but shall not be required as a condition
to the issuance of a BSR.
e.
Transmittal and Content of BSR Notices and Operational Alerts
(i) The Company will communicate the issuance of BSRs and Operational Alerts to Customers
through its Website. The Company will also communicate the issuance of BSRs via email to the
individual(s} designated by the Customer to receive such communications, contemporaneously
with their issuance. The Customer will be responsible for providing CGV with a current email
addresses and for changing and updating the address as needed. However, the official mode of
communication shall be the Website and the failure of a Customer or its designee to receive an
email notification of a BSR shall not serve as the basis of a failure to comply with a BSR. The
Company will update Customers regarding BSRs and OAs in the event of significant changes in
conditions affecting the issuance of a BSR or OA by communicating in the same manner as
described immediately above.
Effective Date: September 28, 2016
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Division of Energy Regulation
Accepted for Filing
September 14, 2016
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 133
SUPERSEDING
ORIGINAL SHEET NO. 133
RATE SCHEDULE BBS
BANKING AND BALANCING SERVICE
(continued)
(ii) The notice of BSRs and OAs, as well as the updates regarding significant changes in conditions
referenced in subparagraph (i), above, will be communicated to the SCC's Division of Energy
Regulation contemporaneously with their issuance via email.
(iii) The timing, level and duration of a BSR will be based on the Company's analysis described in
subparagraph (b) above.
8.
PENALTY CHARGE FOR FAILURE TO COMPLY WITH A BSR
If on any day, after the Company has provided notice of a BSR pursuant to this Rate Schedule, the
Customer fails to comply with the BSR such that the Customer's actual use or confirmed delivery of gas
hereunder is in excess of the Customer's applicable Authorized Daily Quantity or Authorized Daily Supply,
the Customer shall be billed penalties and charges as defined in Section 10.6 of the General Terms and
Conditions, in addition to all other applicable charges under this Rate Schedule.
9.
TERM OF CONTRACT
The term of contract for service under this Rate Schedule shall be for a minimum of one (1) year, such that
the applicable Service Agreement or Addendum to Service Agreement expires on the same date as the
Customer's Service Agreement for transportation service. The applicable Service Agreement or Addendum
to Service Agreement shall continue year to year thereafter until terminated by either the Customer or the
Company,
10. PURCHASE GAS ADJUSTMENT PROVISION
The rates for Banking and Balancing Service under this Rate Schedule are subject to adjustment for
changes in pipeline supplier rates as set forth in Section 17 of the General Terms and Conditions.
11. GENERAL TERMS AND CONDITIONS
Service under this Rate Schedule is subject to the currently effective General Terms and Conditions, as
contained in this Tariff, as well as all applicable Rules and Regulations of the Virginia State Corporation
Commission, as may be amended from time to time.
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 134
RATE SCHEDULE LVTS
LARGE VOLUME TRANSPORTATION SERVICE
1. APPLICABILITY
Applicable throughout the entire service area of the Company.
2.
CHARACTER AND AVAILABILITY OF SERVICE
This interruptible Rate Schedule is available to any Customer located on the Company's distribution system
that contracts for a Maximum Daily Quantity of 20,888 Dth per day or greater for the transportation and
delivery of natural gas, not owned by the Company, through the Company's distribution facilities, subject to
the following conditions;
a. Gas service under this Rate Schedule will be available when the Company has executed a Service
Agreement with the Customer under which the Company agrees to transport and deliver quantities of
gas for the Customer as contemplated in this Rate Schedule.
b. The Company wm not be required to dellver on any day more than the lesser of: (i} a quantity of gas
equivalent to Customer's Maximum Dally Quantity specified In Its Service Agreement; (ii) the quantity
of gas scheduled and confirmed to be delivered into the Company's distribution facilities on behalf of
the Customer on that day plus Standby Service and available Firm Banl<lng and Balancing Service
quantities, should either of these services apply; or (ili) the Customer's Authorized Daily Quantity.
c. The Customer must operate facilities capable of consuming at least 20,888 Dth per day on one or
more gas days each calendar year that the Service Agreement under this Rate Schedule Is in effect
to be ellg!ble for services, rates and conditions under this Rate Schedule. The failure to satisfy this
requirement may result in the termination of service under this Rate Schedule.
d. Service under this Rate Schedule is subject to the Company's distribution facilities having sufficient
capacity to transport the quantities of gas requested by the Customer, except as otherwise contracted
between Company and Customer.
e. Service under this Rate Schedule will be subject to curtailment or Interruption whenever requested by
the Company pursuant to this Rate Schedule or the Company's General Terms and Conditions, except
as specified to the contrary with regard to interruptions In the Customer's Service Agreement under this
Rate Schedule. Customer agrees to discontinue its takes under this Rate Schedule for the periods and
to the extent requested by Company. Notwithstanding the foregoing, except as otherwise provided with
respect to "emergencies" as contemplated in Section 10 of the Company's General Terms and
Conditions and applicable rules, regulations, and orders of the State Corporation Commission,
interruption of deliveries by the Company of end-user's dally scheduled and confirmed supply quantities
dellvered to the Company at the PSP behind which Customer's facilities are located shall be due to the
Company's system delivery capacity !Imitations only.
(
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-Sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
ORIGINAL SHEET NO. 135
SEVENTH REVISED VOLUME NO. 1
RATESCHEDULELVTS
LARGE VOLUME TRANSPORTATION SERVICE(contlnued)
f.
l....
The Company will furnish information to, and receive information from, its Customers by means of the
Company's designated Internet based Website ("Website"). The Customer or its designee must be
capable of utilizlng, and agrees to utUlze, the Website for communications specified In this Rate
Schedule, incfudlng all nominations and confirmations for service under this Rate Schedule, as well
as receipt of Interruption notices, and Balancing Service Restrictions ("BSRs") as contemplated in
Rate Schedule BBS and Company's General Terms and Conditions. The Customer and/or its
designee shall complete all Website training and testing processes as may reasonably be required by
Company, both prior to and during any time the Customer is taking service under this Rate Schedule,
to ensure appropriate use of and access to the Website. Alternative means of communication may
be used for interruption notices, In lieu of the Website, such as facsimile, telephone or email, as may
be deemed appropriate by the Company under the circumstances.
g. The Customer shall provide notice to the Company, in writing, of the name and address of any agent or
marketer ("Agent") delivering gas supplies to the Company's city gate for the Customer's account at
least thirty (30) days prior to the month in which such deliveries are to commence. The Customer shall
advise the Company, in writing, of any change In status with respect to any Agent delivering gas
supplies to the Company for the Customer's account. All such written notices shall be In the form of an
Addendum to the Service Agreement. However, the Company will endeavor to work with the Customer
and its designated agent to authorize deliveries by a third party supplier on less than 30 days notice
where such notice Is Impracticable.
';
h. On an annual basis, a Customer's Maximum Daily Quantity and Annual Transportation Quantity will be
automatically adjusted to the Customer's actual Maximum Daily Quantity and actual Annual
Transportation Quantity based on the Customer's highest daily and annual consumption experienced
during the preceding two consecutive 12-month periods ending with March billings. Upon a
Customer's request, the Company shall have the discretion to further adjust a Customer's Maximum
Daily Quantity and Annual Transportation Quantity for good cause shown:
When a Customer executes a Service Agreement under this Rate Schedule for the transportation of
natural gas that will ultimately be consumed by, and at a facility owned by, Customer's corporate
affiliate, for purposes of this Rate Schedule, including the application of the Terms and Conditions of
Company's Tariff, the term "Customer" shall be construed to include Customer's corporate affiliate that
is the ultimate consumer of the natural gas transported by Company.
3. MONTHLY CHARGE
The rate(s) for transportation service to a Customer under this Rate Schedule shall be established by
Company and Customer In the Service Agreement with such Customer. At a minimum, the rate(s) for such
service shall be designed at a level sufficient to recover the annual cost of providing such service to a
Customer (Including the cost of any Incremental additional facilities required).
4. MINIMUM MONTHLY CHARGE
The minimum monthly charge shall be established by Company and Customer In the Service Agreement
with such Customer.
{
'
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
JllVISION OF ENERGY REGULATION-sec
FIRST REVISED SHEET NO. 136
SUPERSEDING
ORIGINAL SHEET N0.136
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
RATE SCHEDULE LVTS
LARGE VOLUME TRANSPORTATION SERVICE
(continued)
5.
DETERMINATION OF DELIVERIES
The quantities of gas transported for a Customer pursuant to this Rate Schedule shall be the quantities
delivered to Company by Customer, less a percentage of the total quantities so delivered as retainage for
Company use and unaccounted for gas on Company's distribution system, which shall be established by
Company and Customer in the Service Agreement with such Customer.
6.
TERM
The term of contract for service to a Customer under this Rate Schedule shall be as set forth in the Service
Agreement with such Customer.
7.
BACK-UP SERVICE
The Customer is responsible for providing and maintaining alternate fuel storage and combustion facilities
and for having available at all times sufficient alternate fuel to maintain desired levels of plant operation
during periods of interruption or curtailment, including any period when a BSR has been issued by
Company. In the event a Customer purchasing transportation services under this Rate Schedule does not
purchase Standby Service as backup for such transportation service, the Company will in no way be
obligated to provide backup sales service to Customer.
8.
BANKING AND BALANCING
To the extent· that the Company ·is capable of provic;;ling panking Clnd balancing. service and in the event
Customer elects such service, provisions for banking and/or balancing of a Customer's quantities shall
either be provided pursuant to Rate Schedule BBS or shall be established by the Company and Customer in
the Customer's Service Agreement. If the Customer does not elect to take service under BBS and did not
establish banking and balancing service in their Service Agreement, the Customer does not have banking
and balancing service.
9.
PENALTY FOR FAILURE TO INTERRUPT OR CURTAIL
If on any day, after the Company has provided notice to interrupt or curtail pursuant to this Rate
Schedule, the General Terms and Conditions, or the Customer's Service Agreement, the Customer fails
to limit its use of gas hereunder to the Customer's Authorized Daily Quantity, the Customer shall be billed
penalties and charges as defined in Section 10.6 of the General Terms and Conditions, in addition to all
. other applicable charges under this Rate Schedule and the Service Agreement.
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 137
RATE SCHEDULE l...VTS
.
LARGE VOLUME TRANSPORTATION SERVICE
(continued)
10. DAILY DEMAND MEASUREMENT
a. A dally demand meter with an electronic measurement (EM) or automatic meter reading (AMR)
device and a~soclated telemetering equipment must be installed at the service location of each
Customer electing service under this Rate Schedule, consistent with specifications established by the
Company. The daily demand meter and associated telemetering equipment shall be and remain the
property of the Company. The Customer or its designee shall have the right to obtain the once daily
update of Customer's actual consumption Information, for the prior gas day ending at 10:00 a.m.
Eastern, via a web based process made available by Company, at no cost to the Customer.
Additionally, the Customer or its designee may have the ability to use the Company's optional
demand~polling service, subject to availability and the terms and conditions of Rate Schedule DPS, to
access metering data at any time within a day at the Customer's or its deslgnee's discretion.
(
b. The Customer shall own and maintain a dedicated telephone source and the AC power, if necessary,
to operate all daily demand measurement equipment. The Customer will pay for the initial Installation
of such dedicated telephone line or alternative telecommunications technology. The Customer shall
use Its best efforts' to ensure that the telephone source and AC power are operational at all times.
Failure to comply with this requirement shall not serve as the basis for a waiver of penalties or
charges that are assessed as a consequence of Customer's failure to comply with operational
requirements under this Rate Schedule or the General Terms and Conditions. In the event that
Company notifies Customer that the telephone source Is Inoperable, Customer shall restore the
operability of Its telephone source within 10 days. If the Company is unable to read the Customer's
meter remotely due to the Customer's failure to maintain the telephone source, the Customer shall
pay the Company $84 for each instance that the Company is required to manually read the meter.
11. GENERAL TERMS AND CONDITIONS
Service under this Rate Schedule ls subject to the currently effective General Terms and Conditions
contained In this Tariff as well as all applicable Rules and Regulations of the Virginia State Corporation
Commission, as may be amended from time to time.
{
\'-c- -
Effective Data: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE~2014·00020
ACCEPTED FOR FILING
JANUARY 21, 2016
nl\/ISION OF FNERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO, 1
ORIGINAL SHEET NO. 138
RATE SCHEDULE EDS
ECONOMIC DEVELOPMENT SERVICE
1. APPLICABILITY
Applicable throughout the entire service area of the Company.
2. AVAILABILITY
This Rate Schedule is available to any new or existing commercial or industrial Customer with maximum
new load requirements of not less than 52.2 Dth per day provided that:
a. The Company's distribution facilities have sufficient capacity and/or the Company has adequate gas
supply to provide the quantities of gas requested by the Customer;
and
b. The Customer executes a Service Agreement in the form contained in this tariff;
and
c. The Customer gives the Company satisfactory proof that the gas service constitutes new manufacturing
or distribution operations In Company's markets, and that In the absence of service under this Rate
Schedule the facilltles will not be constructed in the Company's operating territory;
(
'
and
d. The Customer Is otherwise eligible for service under the Company's applicable Sales or Transportation
Rate Schedules.
3.
CHARACTER OF SERVICE
This Rate Schedule provides for reduced charges for new gas loads related to the economic development
projects within the Company's service area. Service under this Rate Sched).lfe will commence upon
acceptance by the Company and receipt of any necessary regulatory approvals, and continue for a period
not to exceed three (3) years.
4.
RATE
The rate and other charges of the normally applicable Sales or Transportation Rate Schedules are hereby
incorporated into this Rate Schedule.
The monthly charges for service under this Rate Schedule will be computed based on a declining three year
reduction (15% first year-10%-second year-5% third year) In the base non-gas quantity rate of the normally
applicable Sales or Transportation Rate Schedules. The Customer/or Minimum Bill Charges and any
flexible rates under each Rate Schedule are not subject to reduction.
Effective Date: February 1,·2015
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
nl\/ISION OF FNFRC::Y RFC::lll ATION-SGC
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH RJ::VISED VOLUME NO. 1
ORIGINAL SHEET NO. 139
RATE SCHEDULE EDS
ECONOMIC DEVELOPMENT SERVICE
{continued)
5. GENERAL TERMS AND CONDITIONS
Service under this Rate Schedule Is subject to the currently effective General Terms and Conditions, as
contained In this Tariff, as well as all applicable Rules and Regulations of the Virginia State Corporation
Commission, as may be amended from time to time.
I
\
Effectl.ve Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY21, 2016
nIVISION OF ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL. SHEET NO. 140
RATE SCHEDULE DES
DISTRIBUTOR EXCHANGE SERVICE
1.
APPLICABILITY
Applicable throughout the entire service area of the Company.
2.
AVAILABILITY
This Rate Schedule Is available for service to any natural gas distributor authorized as a public service
company by the Virginia State Corporation Commission to provide retail natural gas distribution service for
which it has obtained the requisite certificate of public convenience and necessity pursuant to the Virginia
Utilities Facilities Act ("Distribution Customer"). The Company will agree to sefl, transport and/or exchange.
quantities of gas, subject to the following condittons:
a. The Company shall not be required to deliver on any day more than a quantlty of gas to be mutually
agreed upon by the Company and the Distribution Customer;
and
b. Any service, whether sales, transportation, exchange, or any combination thereof, rendered to a
Distribution Customer pursuant to any statute, order or ruling by a court or administrative agency having
lawful jurisdiction to do so shall be deemed to be provided pursuant to this Rate Schedule;
and
c. The Company and the Distribution Customer have entered Into a written Service Agreement:
and
· d. Service 'under this Rate Schedule is subject to the Company's distribution facilities having sufficient
capacity and/or the Company having adequate gas supply to provide the quantities of gas requested by
the Distribution Customer.
3.
CHARACTER OF SERVICE
This Rate Schedule provides for sales, transportation, or exchange service, or any combination thereof,
within the Company's service area to or for a Distribution Customer.
4. RATE
Rates for specific service to a Distribution Customer shall be established by the Company and Distribution
Customer In the DES Service Agreement in accordance with the following provisions.
Maximum and Minimum Rates
For the purposes of transactions under this rate schedule, the maximum price shall be the LGS1/LGS2 Firm
Rate or the Ts1rrs2 rate, as applicable, plus the cost of any required facilities. The minimum charge shall
not be less than the cost of providing the service.
Gas sold under this Rate Schedule will be priced at a 100% load factor rate (excluding Actual Cost
Adjustment and refunds) developed from the Company's LGS1/LGS2 Firm Rate Schedule.
•I'·
'
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE"2014·00020
ACCEPTED FOR FILING
JANUARY 21, 2016
.
nt\/LC:lnl\I nr: FNFR~Y RFC'.ll II ATION-.SCC
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 141
RATE SCHEDULE DES
DISTRIBUTOR EXCHANGE SERVICE
(continued)
Exchange of Gas
Gas exchanged on the basis of equivalent quantities under this rate schedule will not be subject to any
charges except those which may be required under "Other Charges" below, and applicable charges
contained in the General Terms and Conditions of this tariff.
Other Charges
In the event incremental facilities are required, additional charges will include, but not be limited to, an
amount sufficient to recover the cost of the following:
a. Operation and Maintenance Expenses;
b.
c.
d.
e.
5.
(
Depreciation Expense based on current rates;
Property taxes and any effective tax levied by governing bodies;
Return based on most recently approved sec allowance for the Company; and
Federal and State Income tax at current rates.
·
TER~
The term of contract for service to a Distribution Customer under this Rate Schedule shall be as set forth in
the Service Agreement with such Distributor Customer.
6,
LATE PAYMENT CHARGE
All bills not paid by the next billing date will be subject to a late payment charge as set forth in Section 7 of
the General Terms and Conditions.
7.
GENERAL TERMS AND CONDITIONS
Service under this Rate Schedule is subject to the currently effective General Terms and Conditions, as
contained in this Tariff In the same manner as if Distribution Customer were a "Customer'' (to the extent
not inconsistent with this Rate Schedule), as well as all applicable Rules and Regulations of the Virginia
State Corporation Commission, as may be amended from time to time.
(
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE~2014~00020
ACCEPTED FOR FILING
JANUARY 21, 2016
nl\/li:<Inl\I
rn= l=NFRC::V Rl=(H ll
ATION-sr.r.
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET N0.142
SUPERSEDING
ORIGINAL SHEET NO. 142
RATE SCHEDULE CSPS
COMPETITIVE SERVICE PROVIDER SERVICE
1.
APPLICABILITY
This Rate Schedule is applicable throughout the entire service area of the Company.
2.
AVAILABILITY
For purposes of this Rate Schedule a "licensed Competitive Service Provider" is any entity that holds a
valid license issued by the Virginia State Corporation Commission ("SCC") pursuant to the Rules
Governing Retail Access to Competitive Energy Services at 20 VAC 5-312-40, as may be amended by
the sec.
This service is available to any licensed Competitive Service Provider (CSP), who is delivering gas on
behalf of Customers receiving Transportation Service from the Company under Rate Schedules RTS,
SGTS1, SGTS2, SGTS3, UGLTS and ACTS ("Applicable Rate Schedules"). Service under this Rate
Schedule allows a CSP to deliver to the Company, on an aggregated basis, natural gas supplies sufficient to
satisfy the requirements of the CSP's Customers.
To receive service under this Rate Schedule, CSP must comply with the Company's registration
requirements (including financial assurance), must execute and comply with a Competitive Service Provider
Service Agreement ("CSP Service Agreement") in the form approved by the SCC, and must meet all
eligibility and performance requirements of any applicable Tariff provisions, including this Rate Schedule,
the Company's Gas Supply Operations Plan, and the Company's General Terms and Conditions, as
amended from time to time. A CSP also must comply with the SCC's Rules Governing Retail Access to
Competitive Energy Services, 20 VAC 5-312-10 et seq., ("SCC Retail Access Rules") on an on-going basis.
Any material breach of any provision of this Rate Schedule or the SCC Retail Access Rules shall be a basis
for termination of service by the Company pursuant to Section 16, Remedies, in this Rate Schedule.
Open enrollment for CSPs to solicit and sign up Customers will commence with the effective date of the Rate
Schedule.
The CSP shall enroll and remove Customers via the Company's designated Internet based Website
("Website"), as further described in Section 5 of this Rate Schedule. The Company will also furnish
information to, and receive information from, the CSP by means of the Website, which information
includes but is not limited to all nominations and confirmations for service under this Rate Schedule. The
CSP or its designee must be capable of, and agrees to, utilize the Website for communications specified
in this Rate Schedule. The CSP and/or its designee shall complete all Website training and testing
processes as may reasonably be required by Company, both prior to and during any time the CSP is
taking service under this Rate Schedule, to ensure appropriate use of and access to the Website.
Service under this Rate Schedule is subject to the Company's distribution facilities having sufficient capacity
to provide the quantities of gas requested by the Customer and the Company having adequate gas supply
resources to satisfy the requirements of the CSP's participating customers.
3.
CUSTOMER GROUPS/NOMINATION GROUPS
A CSP's customers will be combined to form that CSP's Customer Group for purposes of this Rate Schedule.
The CSP's Customer Group will be segmented into Nomination Groups that correspond to each of the
Pipeline Scheduling Points ("PSPs") behind which that CSP's customers receive service. The scheduling,
nominations and other operational requirements imposed on a CSP under this Rate Schedule (including daily
delivery obligations, operational flow orders, reconciliations, and the application of penalties for a failure to
comply with any operational requirement) shall be applied individually for each Nomination Group.
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
.r-L
t
'
-
.--~
COLUMBIA GAS OF' VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 143
RATE SCHEDULE CSPS
COMPETITIVE SERVICE PROVIDER SERVICE
(continued)
4. REQUIREMENTS FOR PARTICIPATION
a.
Credit Worthiness
In addition to holding a valid license as a CSP as described in Section (4)(d) herein, a CSP desiring to
provide service under this Rate Schedule must be credit worthy, as determined by the Company in its
reasonable judgment. CSP will be required to provide the following information as part of the credit
evaluation process:
(I)
,.
\.,
Proof of license from the SCC, pursuant to 20 VAC 5-312-40, to conduct business as a
competitive service provider for residential ahd small commercial customers within the
Company's certificated service territory;
(ii)
A copy of tile most recent application for such license;
(iii) Most recent annual report, 1OK, or 1OQ and current financial statements prepared since tile last
audited reports; ·
(Iv) List of parent company and other affiliates;
(v) Names, addresses, and telephone numbers of 3 trade references;
(vi) Names, addresses, and telephone numbers of one or more banking institution contacts;
(vii) List of unbundl!ng programs in which that CSP is participating;
(viii) Confirmation that the CSP is not operating under any bankruptcy or insolvency law;
(ix) Confirmation that no significant lawsuits or Judgments are outstanding;
(x) Confirmation that the CSP Is not aware of any adverse condition that could cause a material
change in financial eonditlon; and
(xi) Any additional financial related information as determined by the Company.
The establishment of acceptable credit levels will be based on standard credit factors such as previous
customer history, Dun & Bradstreet financial and credit ratings, trade references, bank information, unused
lfne(s) of credit, and financial information. The Company shall have sole discretion to determine, on a non"
discriminatory basis, the level of a CSP's credit worthiness based on tile above criteria but will not deny
credit worthiness without reasonable cause.
A fee of $280.00 wHI be assessed for each evaluation. This fee is for the cost the Company Incurs to obtain
credit reports ($40.00) and the cost the Company Incurs to activate a CSP ($240.00). CSPs participating In
the Company's pilot program as of September 30, 2002, will not be charged these fees. The Company
reserves the right to conduct additional evaluations at any time during the course of the program. No
additional credit report fee will be charged to the CSP.
b. Financial Assurance
CSP shall, at the time of execution of a CSP Service Agreement, provide the Company with financial
assurance in the form of a cash deposit, letter of credit or other financial Instrument acceptable to the
Company. The amount of the financial assurance shall be that amount which the Company believes Is
reasonably required to protect It from adverse financial impacts due to CSP's nonperformance, taking Into
account the level of risk assumed by the Company. The consideration of the level of risk assumed may
include, but not be limited to, the level and type of services contracted for by the CSP from the Company; the
quantities of gas· supply to be used by CSP's customers; CSP's over-all creditworthiness; and its past
payment
(
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE"2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
nl\/ISION OF FNFRGY RFGULATION-SCC
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 144
RATE SCHEDULE CSPS
COMPETITIVE SERVICE PROVIDER SERVICE
(continued)
history with the Company; and any costs payable to a third party for which the Company Is liable should the
CSP fall to pay such third party. Said deposit shall be available to the Company to satisfy any of the CSP's
obligations of this Rate Schedule and to satisfy any outstanding claims that the Company may have against
the CSP. The amount of financial assurance shall be periodically reviewed and updated by the Company
taking into account changes ln the CSP's risk profile, including the number of Customers served by the CSP,
the CSP's payment history and its performance history under this Rate Schedule.
A CSP shall notify the Company Immediately upon any material change to any of the financial data provided
to the Company and shall provide the Company with updates of all affected financial information within five
(5) days of notice to the Company. In the event a CSP elects, or is forced, to terminate service under this
Rate Schedule In accordance with the terms and conditions hereof, it shall continue to maintaln its financial
security instruments/arrangements until It has satisfied all of !ts outstanding debts to and claims of the
Company.
c.
Other Requirements for Participation
CSP shall:
{
(i)
Where applicable, satisfy all requirements of Virginia Code Section 56-235.8; the SCC's
applicable Retail Access Rules; other applicable federal, state, and local laws, orders and
regulations; and Company's Tariff;
·
(II)
Obtain and maintain a license, from the SCC, pursuant to 20 VAC 5-312-40, to conduct
business as a CSP for customers eligible for service under the Applicable Rate Schedules
within the Company's certificated service territory, as well as obtain and maintain any licenses,
permits or other authorizations, from any other federal, state or local agencies, required for
participation In the Virginia gas supply market;
(Iii)
Verify that there are no actions at law, suits in equity, proceedings or claims pending against
CSP before any federal, state, foreign or local court, tribunal or government agency or authority
that could materially delay, prevent or hinder the performance of Its obligations under this Rate
Schedule or CSP's Service Agreement;
(Iv)
Execute all applications and agreements required for participation in the Virginia gas supply
market;
(v)
Cooperate to ensure the provision of gas supply service to Customers In CSP's Customer
Group. To this end, CSP shall supply to Company, in a thorough and timely manner, all data,
materials or other information specified in this Rate Schedule or CSP's Service Agreement or
that may otherwise be reasonably required by Company In connection with the obligations
under this Rate Schedule or the CSP's Service Agreement;
(vi)
lmmed!ately notify Company via facsimile or email (with the original transmitted via overnight
mail or courier service), if CSP learns that any of its representations, warranties, or covenants
pursuant to this Rate Schedule or CSP's Service Agreement has been violated; and
(vii)
Resolve disputes In accordance with the dispute resolution procedures on file with and
approved by the SCC as well as the SCC's Rules of Practice and Procedure.
\_.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE:-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
nl\/l!':lnl\t OF FNFRf.lY R!=Cllll ATION-SCC
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 145
RATE SCHEDULE CSPS
COMPETITIVE SERVICE PROVIDER SERVICE
(continued)
5.
CUSTOMERSIGN~UP
AND REMOVAL PROCEDURES
(a) Initial Enrollment: CSPs shall enroll Customers through the Website. The Website Is a web-based
application accessible via computer with Internet access. Access to the Website w!ll be granted after a
·Competitive Service Provider Service Agreement Is executed between the CSP and the Company. The
CSP shall enter the Customers' Company account number through the Website. The CSP Is
responsible for verifying the eligibility of each Customer.
Customers submitted on or before the 15th calendar day of the month commence service from the CSP
effective with bills rendered on and after the next month's normal meter reading date unless rejected
based upon program parameters. For example, customers submitted on or before January 15 would be
billed at the CSP's rates beginning with the b!lling month of February. Customers submitted after the
15th calendar day of the month commence service from the CSP effective with bills rendered on and
after the second succeeding month's normal meter reading date. For example, customers submitted
after January 15 would be billed at the CSP's rates beginning with the billing month of March. If the
15th calendar day falls on a non-business day, the deadline for submission is the prior business day.
(b) Enrollment Verification: The Company will verify the account numbers submitted for enrollment by a
(
CSP, then provide the CSP a normalized monthly quantity profile for the CSP's Customer Group as well
as an exceptions report. In the event that a Customer attempts to enroll with more than one CSP in the
same enrollment cycle, the enrollment first received by the Company wm be used to determine which
Customer Group the Customer wlll be assigned. Duplicates received on the same day wlll be returned
to the CSPs for resolution with the Customer. Any Incomplete submittal will be returned to the CSP for
completion.
(c) Removal from Enrollment CSPs shall submit removals of Customers through the Website. Removals
submitted by the 15th calendar day of the month cease service from the CSP effective with bills
rendered on and after the next month's normal meter reading date. Removals submitted after the 15th
calendar day of the month cease service from the CSP effective with bills rendered on and after the
second month's normal meter reading date. If the 15th calendar day falls on a non-business day, the
deadline for submission is the prior business day.
(d) Commencement of Natural Gas Supply Service by CSP; For Customers submitted for enrollment by
the 15th calendar day of the month, the CSP's daily delivery obligation, as defined In this Rate
Schedule, shall be adjusted effective the 1st day of the following calendar month to cover those
Customers. For Customers submitted for enrollment after the 15th calendar day of the month, the
CSP's dally delivery obligation shall be adjusted effective the first day of the second succeeding
calendar month to cover said Customers.
(e) Customer Lists: The Company wlll, upon request from a licensed CSP, distribute information relating lo
Customers eligible for inclusion in a Customer Group under this Rate Schedule, consistent with the
provisions of 20 VAC 5-312-60. A CSP may request a customized Customer Information list from the
Company. Subject to a determination by the Company that It has the necessary resources to provide
the requested service, CSP and Company may negotiate a mutually agreeable service contract for
customized Customer information. Other than as specified above, Company will not provide
Customer-specific Information without the Customer's written· consent.
t
' -Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
nl\/1.C:lrll\I rn: i::l\lt=Rf.W RFl-:111 ATION-8C:r.
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOl..UME NO. 1
ORIGINAL SHEET NO. 146
RATE SCHEDULE CSPS
COMPETITIVE SERVICE PROVIDER SERVICE
(continued)
(f) Privacy of Information: Information shall not be released for those otherwise eligible Customers that opt
out of having their Information released, as provided in the sec Retail Access Rules. To comply with
the "opt-out" requirement, the Company shall, on a semi-annual basis, send all Customers a bill Insert
that will allow a Customer to opt out of information release or to reverse a prior opt-out decision. The
Company may, In Its discretion, elect an alternative means to satisfy the opt-out requirement in lieu of
the bill Insert. In accordance with 20 VAC 5-312-60(A), CSP shall hold In strict confidence all
Customer-specific information supplied by Company, unless CSP has Customer's authorization to do
otherwise.
AH Company information made available to CSP pursuant to this Rate Schedule Including, without
limitation, information regarding Company's computer or communication systems, shall not be
disclosed to third parties without Company's express written consent.
6.
Bill.ING OPTIONS
CSPs may choose from two billing options in rendering a bill to a participating Customer. The CSP may opt
to: (1) have the Company issue the total bUI; or (2) bill its portion of the blfl with the Company continuing to
bill the non-gas cost portion of the bill.
(
a. Billlng Option 1: Company Billing Services ~ Company shaH provide an electing CSP with billing
services. The bill rendered to CSP's Customers under this option shall include CSP's supply charges
and applicable Company dellvery charges. CSP's supply charges, which will be shown as a separate
line Item on the bill sent to Customers, shall be billed as a fixed dollar amount times quantities
consumed.
(i) Information Exchange/Requirements; The· Company shall provide the CSP with meter reading
information and other reports In the Company's electronic format or standard printed format on a
monthly basis corresponding to the Company's billing cycle. The CSP shall provide the Company
with all required billing information as indicated on the Company's "CSP Supplier Rate Statement,"
which will require jnformation necessary to bill the CSP's Customers, and such other information as
may be reasonably necessary for Customer bllling as determined by the Company In its sole
discretion. The CSP shall provide billing determinants In the electronic format or standard printed
format specified by the Company. Such information shall be provided no later than the 20th day of
the month prior to the effective Billing Cycle by supply!ng an electronic Rate submission file or a
new CSP Supplier Rate Statement.
'
(ii) Optional Customized Billing and Collection Services: If CSP desires the Company to bill multiple or
variable supply charges (e.g., variable index prices), or desires other customized b!ll components or
structures, or collection services, it may request a customized service from the Company. Subject
to a determination by the Company that it has the necessary resources to provide the requested
service, the CSP and Company may negotiate a mutually agreeable service contract for billing
and/or collection services. A contract covering such mutually agreed upon customized billing and/or
collection services shall be an Appendix to the executed CSP Service Agreement. Negotiated
services provided pursuant to this section shall be made available on a non-discriminatory basis to
similarly situated CSPs.
b. Billing Option 2: CSP Billing - A CSP electing this option shall be responsible for billing its charges to its
Customers. Company will separately bill Its own service charges. CSP b!llings shall be In compliance
with applicable SCC Retail Access Rules.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order In Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
OIVISION OF ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
.
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO, 147
RATE SCHEDULE CSPS
COMPETITIVE SERVICE PROVIDER SERVICE
(continued)
c.
Under all billing options, the CSP shall be fully responsible for any nonpayment of the CSP's portion of
the Customer's bill. Provided, however, if CSP elects to enter Into a negotiated col!ectfon service
contract with the Company, as provided in this Rate Schedule, CSP's responsibility for nonpayment
shall be subject to said service contract.
d.
Billing Option Selection: CSP shall specify its initial Biiiing Option Selection in Its CSP Service
Agreement. Thereafter, CSP may change Its billing selection no more than once during each calendar
year by submitting a request In writing to the Company requesting the change. The change shall
become effective as set forth In an amendment to CSP's Service Agreement that reflects the newly
selected billing option.
The optional services set forth in this Section shall be offered by the Company on a nondiscriminatory basis
to similarly situated Customers.
7.
MANDATORY CAPACITY ASSIGNMENT
Capacity assignment under this Tariff is mandatory. The Company will assign each Participating CSP
upstream interstate pipeline firm transportation service ("FTS") capacity as set forth ln the Gas Supply
Operations Plan.
8. RE-ASSIGNMENT AND RETURN OF CAPACITY
CSPs may reassign capacity subject to recall by the Company in its sole discretion, as may be required to
meet operational and/or contractual obligations. The assignment shall be subject to all operational flow
orders that may be Invoked by upstream pipeline service providers or the Company and to recall provisions
invoked by the Company. The CSP shall continue to be responsible to the Company for payment of all
upstream pipeline charges associated with the assigned capacity, Including, but not limited to demand and
commodity charges, retention, GRI charges, cash-outs, transition costs, pipeline overrun, Actual Cost
Adjustments and all other applicable charges.
In the event that a CSP elects to terminate service under this Rate Schedule, or Is suspended or terminated
from further participation under this Rate Schedule for any reason, the Company shall have the right, but not
the obligation, to recall any capacity assigned to the CSP.
The CSP shall remain responsible for the difference between the market value of any recalled capacity and
the full demand charges for the remaining term of the current assignment. The Company shall Invoice the
CSP for such difference and CSP shall be obligated to pay such amount. In the event CSP fails to timely
pay any amount owed, .the Company shall have the right to collect any such unpaid amount from the CSP's
financial assurance.
9.
OPERATIONAL REQUIREMENTS
a.
Daily Delivery Obligation, Tolerance and Scheduling
(i) A CSP receiving service under this Rate Schedule shall be required to deliver, on a· dally basis,
(
)
supplies for each individual Nomination Group pursuant to a daily delivery obHgation ("Dally Delivery
Obligation" or "ODO"} provided by the Company, as described in the Gas Supply Operations Plan.
CSPs will be provided with nominations requirements by the 2oth calendar day of the month
preceding delivery. If the 20\h calendar day of the month falls on a non-business day, the
nominations requirements are due the prior business day.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE·2014·00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
. COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET N0.148
SUPERSEDING
ORIGINAL SHEET NO. 148
RATE SCHEDULE CSPS
COMPETITIVE SERVICE PROVIDER SERVICE
(continued)
(ii) CSP shall be responsible for arranging and nominating delivery of DDO quantities in accordance
with the Gas Supply Operations Plan.
(iii) At temperatures colder than the design peak day temperature the Company will arrange for the
required incremental supply and bill the CSPs at the highest commodity rate paid by the Company
for the day(s) of such delivery.
(iv) For purposes of this Rate Schedule, "First of Month Index Price" shall mean the first-of-month midpoint Transco, zone 6 non-N.Y. index price as published in Gas Daily for the month during which
the applicable delivery, underdelivery or overdelivery occurred. For purposes of this Rate Schedule,
"Daily Index Price" shall mean the mid-point Transco, zone 6 non-N.Y. index price as published in
Gas Daily for the day during which the applicable delivery, underdelivery or overdelivery occurred.
In the event that either of these indices is unavailable, Company will designate a new applicable
Index price.
b.
Operational Flow Order
The Company may, in its discretion, issue an Operational Flow Order (OFO), directing and obligating
the CSP to deliver gas supply in quantities that may differ from or be equal to its DDO requirements. In
the event of an OFO that restricts gas supply delivery quantities at the city gate to less than a CSP's
DDO, the Company may, at its discretion, provide an alternative delivery point to which a CSP may
choose to deliver quantities of natural gas, in order to meet the delivery requirements under its DDO.
For purposes of this Rate Schedule, an OFO may be issued by the Company on any day when it
determines that adjustments to or maintenance of daily or seasonal delivery quantities are warranted to
meet or maintain system operational requirements. Notice of an OFO shall be posted on the Website
and, to the extent practicable, will generally be posted no less than one day in advance of
implementation of the OFO.
So long as CSP delivers the DDO specified by the Company pursuant to this Section, it is deemed to be
in balance for purposes of this Rate Schedule.
An OFO-directed DDO is the quantity that will be used for billing purposes for that month.
c.
Failure to Deliver DDO
Failure to deliver the DDO referenced in Section 9(a), as may be modified by Section 9(b), shall subject
the CSP to the following charges:
(i)
Non-OFO Days:
1.
Under Deliveries
CSP shall purchase gas from the Company at the higher of 120% of the Daily Index Price for
the day that the under delivery occurred or 120% of the First of the Month Index Price, plus all
applicable upstream penalty costs.
2.
Over Deliveries
Company shall purchase gas from the CSP at the lower of 80% of the Daily Index Price for the
day that the over delivery occurred or 80% of the First of the Month Index Price.
(ii) OFO Days:
1 . Under Deliveries
CSP shall purchase gas from the Company at the higher of 120% the Daily Index Price or
120% of the First of the Month Index Price, plus ten dollars ($10.00) per Dth for all underdelivered quantities, plus all applicable upstream penalty costs.
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
C-
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 149
RATE SCHEDULE CSPS
COMPETITIVE SERVICE PROVIDER SERVICE
(continued)
2. Over Deliveries
The Company shall purchase gas from the CSP at the lower of 80% of the Daily Index Price or
80% of the First of the Month Index Price. In addition, the CSP shall pay ten dollars ($10.00)
per Dth for all over-delivered quantities plus all applicable upstream penalty costs
Charges under this section of this Rate Schedule shall be assessed on the difference between the ODO
quantity and quantities actually delivered by the CSP.
d. Chronic Delivery Imbalances
In the event that a CSP over or under delivers Its ODO on ten (10) or more days during any six month
period, It shall be deemed to have a chronic delivery imbalance.
Notwithstanding any other provision of this Rate Schedule, a chronic delivery imbalance is a default
condition and the Company reserves the right to remove any CSP from this Rate Schedule for chronic
delivery Imbalance.
10. SERVICE CHARGES
{
(a)
Other Charges applicable to a CSP under this Rate Schedule shall be as provided
under various provisions of this Rate Schedule and the General Terms and Conditions.
The cost to rectify CSP billing errors, as well as other incidental services provided to
CSPs, shall be billed as "Other Special Services."
(b)
Retroactive Period Adjustments - Adjustments that necessitate a credit or debit to the
CSP's Nomination Group shall be performed In accordance with the provisions of
Section 7.6 of the General Terms and Conditions contained In this Tariff.
·~
'
11. MEASUREMENT OF DELIVERED QUANTITIES
Monthly quantities billed to participating Customers shall be considered actual quantities delivered, whether
the meter reading is actual or calculated.
12. ANNUAL RECONCILIATION
On March 31 of each year, the Company shall reconcile the imbalance between quantities transported
under this Rate Schedule and consumption by each CSP's participating customers. The imbalance Is equal
to (a) the CSP's quantities transported under this Rate Schedule for the 12-month period ending March 31,
minus (b) the sum of the consumption billed by the Company to the CSP's participating customers during
the same 12-month period plus the estimated March unbilled quantity.
As of March 31 each year, If the imbalance Is negative, the CSP must purchase the deficient quantity from
the Company at the average of the First of the Month Indices for each of the prior twelve months. Likewise,
if the Imbalance is positive, the Company will purchase the excess quantity from the CSP at the same index
mentioned above. in the event this posting Is unavailable, Company wlll designate a new First of the Month
Index Price.
(
Effective Date: February 1, 2016
Per Au1:1ust 21, 2015 Final Order in Case No. PUE-2014·00020
ACCEPTEIJ"FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET N0.150
RATE SCHEDULE CSPS
COMPETITIVE SERVICE PROVIDER SERVICE
(continued)
Provided, however, the Company may elect to reconcile design and actual deliveries during the year, on a
year-to-date or monthly basis, if any of the fol\owlng conditions occur:
(a) Degree days, as measured by the Company based on actual data calculated by the National Oceanic
and Atmospheric Administration, are more than 20% colder than normal in any month from November
through February;
(b) The number of customers served by a CSP increases or decreases by more than 10% in any month
during the year;
(c) A CSP's financial status is downgraded as a result of a credit worthiness review as provided In this Rate
Schedule; or
(d) A CSP's Service under this Rate Schedule is suspended or terminated for any reason or is subject to a
non~emergency related restriction or disqualification.
The Company will provide affected CSPs at least 15 calendar days advance written notice when a year-todate or monthly reconciliation Is Imposed.
Except for the term for which the reconcillatlon is done, a yearAo-date or monthly reconciliation shall be
done in the same manner as the annual reconciliation.
(
13. DETERMINATION OF DELIVERIES
The quantity of gas transported pursuant to thls Rate Schedule shall be the quantity delivered to the
Company by the CSP less 2.5% of the total quantity delivered, as retalnage for Company use and
unaccounted for gas on the Company's distribution system.
14. DEFAULT AND TERMINATION
Default under this Rate Schedule shall occur lf CSP:
(a) is the subject of a bankruptcy, Insolvency or similar proceeding;
(b) makes an assignment for the benefit of its creditors without written consent;
(c) applies for, seeks consent to, or acquiesces in the appointment of a receiver, custodian, trustee,
liquidator or similar official to manage all or a substantial portion of Its assets;
(d) falls to pay Company when payment Is due;
(e) fails to perform, to a material extent, any of the obligations Imposed under the SCC's Retail Access
Rules, this Rate Schedule or Company's Tariff, Including, but not limited to, the v!olatlon of any
material federal, state or local code, regulation or statute; or
(f) over or under delivers Its Daily Delivery Obligation for ten (10) or more days during any six-month
period, as contemplated In Section 9.
(
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET N0.151
RATE SCHEDULE CSPS
COMPETITlVE SERVICE PROVIDER SERVICE
(continued)
15. REMEDIES
{
\
(a) In addition to other rights to terminate or cancel service under this Rate Schedule, tf CSP defaults, then
Company may, at its option, terminate or cancel the CSP's service under this Rate Schedule by causing
written notice thereof to be served on the CSP in default. Such notice shall state speciflcally the cause
for terminating or canceling service under this Rate Schedule, any Impending restriction or
disqualification, and the actions, if any, that the CSP In default may take to avoid the Impending
restriction or disqualification. Such notice shall also declare it to be the Company's intention to
terminate service under this Rate Schedule. Any such notice shall be sent to the CSP in default via
overnight mall or facsimile. Company also shall forward a copy of any such notlce to the SCC's
Division of Energy Regulation and Division of Economics and Finance via the same methods. ln the
event CSP receives notice of termination or cancellatlon made pursuant to this sub-section, the CSP In
default shall have five (5) days after the service of the aforesaid notice In which to remedy or remove
the cause or causes stated in the notice for terminating or canceling service, and if, within said period of
five (5) days, the CSP In default does so remedy or remove said causes, then such notice shall be
deemed to have been withdrawn and service under this Rate Schedule shall continue in full force and
effect. If the CSP in default does not so remedy or remove the cause or causes within said period of
five (5) days, then, at the Company's option, service under this Rate Schedule shall terminate or cancel
as of the expiration of said 5-day period.
.
Notwithstanding the foregoing, in the event of default by a CSP, Company may pursue any and all
available legal and equitable remedies, Including recourse by Company to the sec on less than five
(5) days notice to obtain a non-emergency related restriction or disqualification of the CSP in order to
protect the assets of the Company, ensure the operational Integrity of the Company's system, avoid
the imposition of unnecessary costs or charges on the Company or its Customers, or to otherwise
protect the public interest.
{b) The obligations, termination rights, and other remedies outlined In this Rate Schedule and in the
Company's General Terms and Conditions for non-performance herein shall be the Company's and
CSP's respective sole and exclusive remedies for such non-performance. ln no event shall either party
be liable for special, incidental, exemplary, punitive, indirect or consequential damages Including, but
not limited to, loss of profit or revenue, cost of capital, cost of substitute products, downtime costs, or
claims for damages by third parties upon Company or CSP except as specifically contemplated in the
applicable Tariff. This applies whether claims are based upon contract, warranty, tort, (Including
negligence and strict liability), or other theories of liability.
(c) If, at any time during the course of a CSP's receipt of service under this Rate Schedule, a CSP's
SCC-issued license, or any other license, permit or authorization required by any other federal, state
or local agency, shall expire or be revoked, suspended, or terminated, or should the renewal of such
license, permit or authorization be refused, or should such license, permit or authorization be
withdrawn, then the CSP's Service Agreement shall terminate automatically as of the effective date of
expiration, revocation, suspension, termination, non-renewal, or withdrawal of such license. This
subsection does not restrict Company's ability to Impose emergency restrictions or to disqualify a
CSP or terminate a CSP's Service Agreement on an emergency basis for other reasons as permitted
by law and as necessary to protect Company, its system, and/or its Customers.
(
\.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION.sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 152
RATE SCHEDULE CSPS
COMPETITIVE SERVICE PROVIDER SERVICE
(continued)
(d) Upon termination of a CS P's Service Agreement, service under this Rate Schedule shall
automatically terminate and CSP shall no longer be authorized to provide gas supply service to
Customers on Company's system, provided, however, that termination of such Service Agreement for
any reason shall not relieve CSP of any obligation accruing prior to such termination.
16. INCORPORATION OF TARIFF PROVISIONS
Service under this Rate Schedule expressly incorporates by reference all of the terms and conditions
governing the Company's Applicable Rate Schedules, Its General Terms and Conditions of Service, the
SCC's Retail Access Rules and such other rules, regulations, and Tariff provisions as may be applicable to
CSPs served under this Rate Schedule, as may be amended from time to time. In all events, the terms and
conditions of Company's applicable rate schedule(s) shall be controlling to the extent inconsistent with the
Company's Genera! Terms and Conditions.
17. LIMITATION OF LIABILITY
The Company shall not have any duties or liabilities other than those specifically set forth In the
applicable rate schedules, Company's General Terms and Conditions, and the CSP's Service Agreement
signed pursuant to this Rate Schedule.
18. LIMITATION OF THIRD PARTY RIGHTS
Except as otherwise contemplated herein, service is provided under this Rate Schedule solely for·the
benefit of Company and CSP and is not intended and should not be deemed to vest any rights, privileges,
or interests of any kind or nature to any other party.
19. FORCE MAJEURE
Neither Company nor CSP shall be liable in damages to the other for any act, omission, or circumsta·nce
occasioned by or in consequence of any acts of God, strikes, lockouts, and other labor disputes, acts of
the public enemy, wars, blockades, insurrections, riots, epidemics, landslides, lightning, earthqual<e, fires,
storms, floods, washouts, arrests and restraints of rules and people, civil disturbances, explosions,
breakage, or accident to machinery or lines of pipe, the binding order of any court or governmental
authority which has been resisted In good faith by all reasonable legal means, and any other cause,
whether of the kind herein enumerated or otherwise, not reasonably within the control of Company or
CSP claiming suspension and which by the exercise of 'due dlllgence such Company or CSP is unable to
prevent or overcome. Failure to prevent or settle any strike or strikes shall not be considered to be a
matter within the control of the one claim Ing suspension.
Such causes or contingencies affecting the performance hereunder by either the Company or CSP,
however, shall not relieve either of llablllty In the event of Its concurring negligence or in the event of Its
failure to use due diligence to remedy the situation and to remove the cause In an adequate manner and
with all reasonable dispatch, nor shall such causes or contingencies affecting. such performance relieve
CSP from Its obligations to mal<e payments of amounts due hereunder.
(
Effective Date: February 1, 2016
Per August21, 2015 Final Order in Case No. PUEw2014·00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET N0.153
RATE SCHEDULE CSPS
COMPETITIVE SERVICE PROVIDER SERVICE
{continued)
20. TITLE TO GAS
The CSP warrants that it or its Customer(s) has good title to all natural gas delivered to the Company on
behalf of Customers in CSP's Customer Group and that such gas w!ll be free and clear of all liens,
encumbrances and claims, and the CSP will Indemnify the Company and save it harmless from all suits,
actions, debts, accounts, damages, costs, losses and expenses arising from or out of a breach of this
warranty.
21. NO PREJUDICE OF RIGHTS
No term or condition of this Rate Schedule shall be deemed to have been waived and no breach excused
unless such waiver or consent to excuse is provided in writing and signed by the party claimed to have
waived or consented to excuse. The failure of either party to Insist in any one or more instances upon
strict performance of any provisions of this Rate Schedule, or to take advantage of any of its rights
hereunder, shall not be construed as a waiver of any such provisions or the relinquishment of any such
right or any other right hereunder, which shall remain in full force and effect.
22 LATE PAYMENT CHARGE
All bills not paid by the next bllllng date wlll be subject to a late payment charge as set forth in Section 7 of
the General Terms and Conditions.
23. GENERAL TERMS AND CONDITIONS
Service under th!s Rate Schedule is subject to the currently effective General Terms and Conditions, as
contained In this Tariff in the same manner as If CSP were a "Customer" (to the extent not inconsistent
with this Rate Schedule), as well as all applicable Rules and Regulations of the Virginia State Corporation
Commission, as may be amended from time to time.
(
\
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE"2014·00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
OLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 154
RATE SCHEDULE AS
AGGREGATION SERVICE
1. APPLICABILITY
Appllcable throughout the entire service area of the Company.
2. AVAILABILITY AND CHARACTER OF SERVICE
a. Aggregation Nomination Groups ("ANGs") may be formed by an agent or marketer ("Agent") with whom
Customers taking service under Rate Schedule rs1rrs2 or LVTS have contracted to deliver natural gas
in aggregate to the Company's city gates on behalf of such Customers for delivery by the Company to
such Customers. The purpose of an ANG Is to enable Agents to perform certain gas transportation
function$ on an aggregate basis for all Customers participating in an ANG, including scheduling and
nominating gas consistent with the requirements of Rate Schedule BBS - Banking and Balancing
Service and complying with Balancing Service Restrictions ("BSRs"), which may be implemented
pursuant to the provisions of Rate Schedule BBS, which Rate Schedule Is incorporated herein by
reference. All Customers participating in a common ANG must: (1) have their gas transported on a
common interstate natural gas pipeline; {2) be located behind the same PSP ; and (3) subscribe to
Banking and Balancing Service under Rate Schedule BBS.
b. Agents will be allowed to establish one or more ANGs. However, multiple ANGs may not be
aggregated to satisfy any requirement Imposed under this Rate Schedule under any circumstance.
l
!
\.
c. As a condition of supplying natural gas to an ANG, each Agent serving the ANG must comply with the
Company's regislratfon requirements, and each Agent must execute and comply with an Aggregation
Service Agreement ("Service Agreement") In the form approved by the Virginia State Corporation
Commission ("SCC"), and comply with any applicable tariff provisions, including this Rate Schedule, and .
the Company's General Terms and Conditions, as may be amended from time to. time. The failur!3 of
the Agent to comply with this condition will ren'der the Agent lnellglble to deliver gas supplies to the
Company for Customers' accounts and any subsequent failure of an Agent to comply may result in the
termination of service to Agent under this Rate Schedule.
d. The Company will furnish Information to, and receive information from, the Agent by means of the
Company's designated Internet based Website (''Website"). The Agent must be capable of utlllzfng, and
agrees to utilize the Website for communications specified in this and other specified Rate Schedules
and the Company's General Terms and Conditions. The Agent shall complete all Website training and
testing processes as may reasonably be required by Company, both prior to and during any time the
Agent Is taking service under this Rate Schedule, to ensure appropriate use of and access to the
Website.
(
\
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
FIRST REVISED SHEET NO. 155
SUPERSEDING
ORIGINAL SHEET N0.155
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
RATE SCHEDULE AS
AGGREGATION SERVICE
(continued)
3.
SERVICE AGREEMENT
An ANG shall be formed upon: (i) the execution of an "Appointment of Agent and Acknowledgement of
Service" form by two or more Customers taking service under Rate Schedule TS1rrs2 or LVTS; and (ii) the
execution of an Aggregation Service Agreement by the Company and an Agent authorized to provide
aggregation services to such Customers. The Service Agreement shall be in the form filed with the sec.
The Service Agreement will require, for each ANG, a list of all Customers included in the ANG and each
Customer's account number. No agreement for service may be assigned or transferred without the written
consent of or approval of the Company.
4.
SERVICE PROVISIONS
a.
Agents subscribing to this Rate Schedule will be responsible, on an aggregated basis, for nominating,
scheduling and managing gas supplies within the aggregate entitlement levels of an ANG, as applicable,
and pursuant to Rate Schedule BBS. Agents will be required to aggregate all quantities of Customers
participating in each individual ANG. The sum total of the cumulative Firm Banking and Balancing
Service, Standby Service and monthly Bank Tolerance levels of the Customers within an ANG shall
represent the aggregate quantities available to that ANG, but only for purposes of operating in
compliance with the requirements of Rate Schedule BBS. Standby Service quantities are attributable to
the individual subscribing Customer and will not be available for use by an ANG on those days when a
Customer specific operating limitation has been imposed on the Customer subscribing to Standby
Service.
b.
Each ANG will have a single Aggregation Quantity Bank managed by the Agent. When a Customer is
added to an ANG, the Customer's existing. Quantity Bank will become the Quantity Bank of the ANG.
Any terms, conditions and compensation associated with such a transfer of a Quantity Bank shall be
within the exclusive discretion of the Customer and the Agent. As each Customer is added to or
· removed from an ANG, the service entitlement levels paid for by such Customer shall be credited or
debited to the existing aggregated service entitlements and made available to the ANG. Should a
Customer choose to terminate service under its respective transportation Rate Schedule and begin
taking sales gas service from the Company, or terminate service as part of an Agent's ANG and return to
transportation service as a stand alone transportation Customer, or move to another ANG, no portion of
the Aggregation Quantity Bank will be assigned to the Customer or transferred to the new ANG.
c.
Agents will be responsible for an ANG's adherence to the operating requirements and the payment of all
associated fees and penalties as described in Sections 4(b) - (e) of Rate Schedule BBS. Agents shall
also be responsible for receiving and responding to BSR notices, as referenced in Rate Schedule BBS,
and for the payment of all applicable charges for failure of an ANG to comply with a BSR pursuant to
Rate Schedule BBS and Section 10.6 of the General Terms and Conditions. Except in the instance of a
customer-specific interruption of transportation service, any determination of a failure to comply with any
applicable operating requirements, including the requirements of a BSR, shall be made on an aggregate
basis with respect to all Customers in a common ANG. Those penalties, charges and fees applicable in
accordance with the Company's tariffs against Customers participating in a common ANG for a failure to
comply with such operating requirements, shall be aggregated and billed to the Agent, except as
provided in Section 15 of this Rate Schedule. Notwithstanding the foregoing, in the instance of a
customer-specific interruption of transportation service, any failure to comply with such interruption shall
be determined on a customer-specific basis and any applicable charges or penalties shall be assessed
directly to the non-complying Customer.
Effective Date: September 28, 2016
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Division of Energy Regulation
Accepted for Filing
September 14, 2016
OLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 156
RATE SCHEDULE AS
AGGREGATION SERVICE
(continued)
d.
In the event service under this Rate Schedule is terminated by an Agent, the Agent shall be entitled to
transfer any quantities residing in the Quantity Bank of an ANG managed by the Agent to another
Customer's account or another ANG within 90 days after service Is terminated. If the Agent fails to
transfer such Banked Quantities within 90 days, the gas will be purchased by the Company. The
purchase price paid by the Company for such gas will be 80% of the mid-point Transco, zone 6 nonN.Y. cltygate price as published in Gas Dally for (I) the date of termination of Agent's service under this
Rate Schedule, or (ii) the goth day following the date of termination, whichever Is lower.
5. ENROLLMENT AND TERMINATION
Agents may enroll Customers in an ANG under this Rate Schedule by written notice to the Company at least
thirty (30) days prior to the commencement of the month in which the enrollment is to be effective. The written
notice shall Include a copy of the Acknowledgement of Service form that Is attached the Service Agreement
for this Rate Schedule. A Customer may remove itself from an ANG by written notice of withdrawal to the
Company and, if applicable, the Agent at least thirty (30) days prior to the commencement of the month in
which the withdrawal is to become effective. Agents may remove any Customer from an ANG by written
notice of removal to the Company and the Customer at least ninety (90) days prior to the commencement of
the month in which the removal is to be effective. The written notice of removal must include the ANG
number, Customer name, facility address, and the Customers PCID #and PSID #.
l
\,
6. OTHER REQUIREMENTS FOR PARTICIPATION
Agent shall:
a) Satisfy the requirements of applicable federal, state, and local laws, orders and regulations, and
Company's tariffs;
b) Verify that there are no actions at law, suits !n equity, proceedings or claims pending against Agent
before any federal, state, foreign or local court, tribunal or government agency or authority that could
materially delay, prevent or hinder the performance of its obligations under this Rate Schedule or
Agent's Service Agreement;
c) Execute all applications and agreements required for participation under this Rate Schedule;
d) Cooperate to ensure the provision of gas supply service to customers. To this end, Agent shall
supply to Company, in a thorough and timely manner, all data, materials or other Information
specified In this Rate Schedule or Agent's Service Agreement or that may otherwise be reasonably
required by Company In connection with the obligations under this Rate Schedule or the Agent's
Service Agreement; and
e) Immediately notify Company via facsimile or emall (with the orjginal transmitted via overnight mall or
courier service), If Agent learns that any of its representations, warranties, or covenants pursuant to
this Rate Schedule or its Service Agreement has been violated.
(
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
OLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 157
RATE SCHEDULE AS
AGGREGATION SERVICE
{continued)
7. DEFAULT AND TERMINATION
a) Default under this Rate Schedule shall occur if Agent:
(i) is the subject of a bankruptcy, insolvency or similar proceeding;
(ii) makes an assignment for the benefit of its creditors without written consent; or
(Iii) applies for, seeks consent to, or acquiesces In the appointment of a receiver, custodian, trustee,
liquidator or similar official to manage all or a substantial portion of Its assets;
b) Default under this Rate Schedule shall occur if Agent:
([) falls to pay Company when payment is due; or
(ii) fails to perform, to a material extent, any of the obligations Imposed under any applicable rules
and regulations of the State Corporation Commission, this Rate Schedule or Company's tariffs,
lncludlng, but not limited to, the v!olat!on of any material federal, state or local code, regulation or
statute.
{
\.
8.
REMEDIES
a. In addition to other rights to terminate or cancel service under this Rate Schedule, if Agent defaults,
then Company may, at its option, terminate or cancel the Agent's service under this Rate Schedule by
causing written notice thereof to be served on the Agent in default. Such notice shall state
speciflcally the cause for terminating or canceling service under this Rate Schedule, any impending
restriction or disqualification, and the actions, if any, that the Agent In default may take to avoid the
impending restriction or disquallfication. Such notice shall also declare It to be the Company's
intention to terminate service under this Rate Schedule. Any such notice shall be sent to the Agent
In default via overnight mail or facsimile. Company also shall forward a copy of any such notice to
the State Corporation Commission's Division of Energy Regulation and Division of Economics and
Finance via the same methods. In the event Agent receives notice of termination or cancellation
made pursuant to this sub-section, the Agent In default shall have ten (10) business days after the
service of the aforesaid notice in which to remedy or remove the cause or causes stated in the notice
for terminating or canceling service, and if, within said period of ten business (10) days, the Agent in
default does so remedy or remove said causes, then such notice shall be deemed to have been
withdrawn and service under this Rate Schedule shall continue in full force and effect. If the Agent In
default does not so remedy or remove the cause or causes within said period of ten (10) business
days, then, at the Company's option, service under this Rate Schedule shall terminate or cancel as of
the expiration of said 10-day period.
Notwithstanding the foregoing, in the event of default by an Agent, Company may pursue any and
all available legal and equitable remedies at any time, Including recourse by Company to the sec
on less than ten (10) business days notice to obtain a restriction or disqualification of the Agent In
order to protect the assets of the Company, ensure the operational integrity of the Company's
system, avoid the imposition of unnecessary costs or charges on the Company or its customers, or
to otherwise protect the public interest.
(
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-SCC
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 158
RATE SCHEDULE AS
AGGREGATION SERVICE
(continued)
b) The obligations, termination rights, and other remedies outlined In this Rate Schedule and in the
Company's General Terms and Conditions for non-performance herein shall be the Company's and
Agent's respective sale and exclusive remedies for such non-performance. In no event shall either
party be liable for special, Incidental, exemplary, punitive, indirect or consequential damages Including,
but not limited to, loss of profit or revenue, cost of capital, cost of substitute products, downtime costs, or
claims for damages by third parties upon Company or Agent except as specifically contemplated in the
applicable tariffs. This applies whether claims are based upon contract, warranty, tort (Including
negligence and strict liability), or other theories of liability.
c) Upon termination of an Agent's Service Agreement, service under this Rate Schedule shall
automatically terminate and Agent shall no longer be authorized to provide gas supply service to
customers on Company's system, provided, however, that termination of such Service Agreement for
any reason shall not relieve Agent of any obligation accruing pr!or to such termination.
9.
CONFIDENTIALITY OF INFORMATION
a) Customer information. Agent shall hold in strict confidence all customer~speclflc Information supplied
by Company, unless Agent has customer's authorization to do otherwise.
·(
'
b) Company Information. All Company information made available to Agent pursuant to this Rate
Schedule Including, without limitation, information regarding Company's computer or communication
systems, shall not be disclosed to third parties without Company's express written consent.
10. LIMITATION OF LIABILITY
The Company shall not have any duties or liabilities other than those specifically set forth in applicable
Rate Schedules, Company's General Terms and Conditions, and the Agent's Service Agreement
executed pursuant to this Rate Schedule.
11. LIMITATION OF THIRD PARTY RIGHTS
Except as otherwise contemplated herein, service is provided under this Rate Schedule solely for the
benefit of Company and Agent and Is not intended and should not be deemed to vest any rights,
privileges, or interests of any kind or nature to any other party.
12. FORCE MAJEURE
(
Neither Company nor Agent shall be liable in damages to the other, for any act, om1ss1on, or
circumstance occasioned by or in consequence of any acts of God, strikes, lockouts, and other labor
disputes, acts of the public enemy, wars, blockades, insurrections, riots, epidemics, landslides, lightning,
earthquake, fires, storms, floods, washouts, arrests and restraints of rules and people, civil disturbances,
explosions, breakage, or accident to machinery or lines of pipe, the binding order of any court or
governmental authority which has been resisted in good faith by all reasonable legal means, and any
other cause, whether of the kind herein enumerated or otherwise, not reasonably within the control of
Company or Agent claiming suspension and which by the exercise of due diligence such Company or
Agent is unable to prevent or overcome. Failure to prevent or settle any strike or strikes shall not be
considered to be a matter within the control of the one claiming suspension.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE·2014·00020
ACCEPTED FOR FILING
JANUARY 21, 2016
nl\11810N OF FNFRGY REGULATION-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 159
RATE SCHEDULE AS
AGGREGATION SERVICE
(continued)
Such causes or contingencies affecting the performance hereunder by either the Company or Agent,
however, shall not relieve either of llabillty in the event of its concurring negligence or In the event of its
failure to use due diligence to remedy the situation and to remove the cause in an adequate manner and
with all reasonable dispatch, nor shall such caUSEIS or contingencies affecting such performance relieve
Agent from its obligations to make payments of amounts due hereunder.
13. TITLE TO GAS
. The Agent warrants that it or its Customer(s) has good title to all natural gas delivered to the Company on
behalf of Customers participating In an ANG and that such gas wlll be free and clear qf all liens,
encumbrances and claims, and the Agent will indemnify the Company and save it harmless from all suits,
actions, debts, accounts, damages, costs, losses and expenses arising from or out of a breach of this
warranty.
14. DAILY DEMAND MEASUREMENT
The Agent shall be permitted to obtain the once dally update of actual consumption Information for each
of Its Customers for the prior gas day ending at 10 a.m. Eastern, via an lnternet based process made
available by Company, at no cost to the Customer or to the Agent, as permitted in the Acknowledgement
of Service Form executed by the Customer In order to subscribe to Aggregation Service pursuant to this
Rate Schedule. Additionally, the Agent will have the ability to use the Company's Rate Schedule DPS ~
Demand Polling Service to access metering data for such Customers, based on the terms and conditions
of Rate Schedule DPS.
15. CUSTOMER OBLIGATIONS
Notwithstanding the fact that the Company will bill the Agent for the charges, fees and penalties
applicable under the terms and conditions of this Rate Schedule, Rate Schedule BBS and the General
Terms and Conditions, the Customers within each ANG are ultimately responsible for any such charges,
fees and penalties that the Agent fails to pay within the time prescribed in the Company's tariffs and/or
General Terms and Conditions. Any such unpaid charges, fees and penalties will be assessed to
Customers within each ANG on a pro rata basis based on the ratio of each Customer's gas usage to the
usage of all Customers participating In that ANG during the month for which the charge, fee and/or
penalty is applied. The charges, fees and penalties to which this provision is applicable Include, but are
not Hmlted to, excess bank tolerance charges, BSR penalties and charges, commodity charges
associated with excess consumption (except with regard to customer specific Interruptions of
transportation service), daily gas transfer fees, late payment charges, and charges for an Agent's access
to Its Customers' dally demand measurement information.
16. LATE PAYMENT CHARGE
All bills not paid by the next billing date will be subject to a late payment charge as se1: forth in Section 7 of
the General Terms and Conditions.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
nl\/l!::l()l\I m: FNt=Rf.\Y Rbf.\l 11 ATION-Rr.C:
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET N0.160
RATE SCHEDULE AS
AGGREGATION SERVICE
(continued)
17. GENERAL TERMS AND CONDITIONS
Service under this Rate Schedule Is subject to the currently effective General Terms and Conditions, as
contained In this Tariff In the same manner as If Agent were a "Customer" (to the extent not inconsistent
with this Rate Schedule), as well as all applicable Rules and Regulations of the Virginia State Corporation
Commission, as may be amended from time to time.
(
'
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
nl\/IRinN ni:: !=Nf'R!-lV RFf.ll ll ATION-RC:C:
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME N0.1
ORIGINAL SHEET N0.161
RATE SCHEDULE DPS
DEMAND POLLING SERVICE
1. APPLICABILITY
Applicable throughout the entire service area of the Company.
2. AVAILABILITY
This service Is available to Customers (or their deslgnee) taking service under Rate Schedules
LGS1/LGS2, TS1/TS2, LVTS and AS.
3. CHARACTER OF SERVICE
a. This service provides Customer or its deslgnee electronic access to metering data at any time within
a day at the Customer or its designee's discretion.
and
b. To use thls service, the Customer or its designee must obtain an ID and Password from the Company
in order to access the Demand Polling feature via the Company's Web Interface.
and
c. The Customer must have a meter equipped with an electronic measurement or automatic meter
reading device and associated telemetering equipment, including a dedicated phone line.
4.
RATES AND CHARGES
a. The initial set up charge f~r Demand Polling service will be $35.00 per meter.
b. This charge will be billed as a separate llne Item on the customer's monthly bill from the company.
5.
ELECTION OF SERVICE
Customers desiring Demand Polllng Service must designate their service election In writing thirty days
prior to the 1st day of the effective month. The enrollment request must be in the written form required by
the Company.
6, TERMINATION OF SERVICE
Customers electing to terminate service under this Rate Schedule must provide the termination notice to
the Company in writing at least thirty days prior to the 1st day of the month In which service is to be
terminated.
7.
(
LATE PAYMENT CHARGE
All bills not paid by the next billing date will be subject to a late payment charge as set forth In Section 7 of
the General Terms and Conditions.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
nl\llC::l(")M rn:: i=t-.n=RrW Ri=r:;111 ATlnN.sr.r.
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET N0.162
RATE SCHEDULE DPS
DEMAND POLLING SERVICE
(continued)
8.
GENERAL TERMS AND CONDITIONS
Service under this Rate Schedule is subject to the currently effective General Terms and Conditions, as
contained in this Tariff, as well as all applicable Rules and Regulations of the Virginia State Corporation
Commission, as may be amended from time to time. To the extent that s·ervlce under this Rate Schedule is
provided to an Agent, service hereunder is likewise subject to the currently effective General Terms and
Conditions, as contained In this Tariff in the same manner as if Agent were a "Customer" (to the extent not
inconsistent with this Rate Schedule), as well as all applicable Rules and Regulations of the Virginia State
Corporation Commission, as may be amended from time to time.
9.
ACKNOWLEDGEMENT OF NATURE OF SERVICE
a. Customer and its designee utilizing the Company's Demand Polling Service acknowledge and agree
that this service ls provided "AS IS" and that the Company assumes no responsibil!ty for the timeliness,
deletion, mis-delivery, or failure to store any data, communications or Information.
,.
b. Customers and/or its designee utilizing the Company's Demand Polling Service pursuant to this Rate
Schedule will access available information via the Company's Web Interface and agree to the terms
and conditions of access to such Information as set forth on that web site.
(
(
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
nl\/l<>lf"\1\1 ni:: r::l\lr::Pr.lV Rr::r.\111 ATlnl\l.Sr!r!
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME N0.1
ORIGINAL SHEET NO. 163
RATE SCHEDULE DGTS
DAILY GAS TRANSFER SERVICE
1. APPLICABILITY
Applicable throughout the entire service area of the Company.
2. AVAILABILITY
This is an optional service available to each Customer, and/or Its Agent, taking service under Rate
Schedules TS1/TS2, LVTS, or AS that has subscribed to the Company's Banking and Balancing Service
or that uses Columbia's Cash-Out Option. This service provides for the tr.ansfer of gas quantities from one
Customer/Agent ("transferor") account to another Customer/Agent ("transferee") account on any day,
including days when a BSR is in effect, but excluding days when an interruption or curtailment is
applicable to a proposed transferee.
3.
CHARACTER OF SERVICE
(a) Each transfer must occur such that gas is transferred from the transferor to the transferee on the
same Gas Day. Transfer0r must request the transfer In the billing cycle at the end of the current
month, as described In subparagraph (e) below.
(b) Transfers will be permitted between a transferor and a transferee located behind the same PSP and
having confirmed deliveries on the same transmission pipeline. Transfers may also be permitted,
solely at the discretion of the Company, between a transferor and a transferee located behind
different PSPs and having confirmed deliveries on the same transmission pipeline.
(c) Quantities eligible for transfer shall not exceed the transferor's confirmed deliveries for the day of
transfer. The transferor, transferee or both, as applicable, shall be responsible for penalties applicable
as a consequence of gas transfers processed pursuant to this Rate Schedule.
(d) Customer's consumption information will be posted on the Company's designated Internet based
Website, on a best efforts basis, by 5:00 pm eastern time ·on the second business day following the
end of the applicable calendar month.
(e) All gas transfer requests must be accurately completed and executed by both the transferor and the
transferee and submitted to the Company on Its standard Gas Transfer Request Form by the third
business day following the end of the previous calendar month.
(f) Company will not be involved In any arrangement or agreement for compensation for the value of the
gas being transferred, or for any other fees between transferor and transferee. The Company's role
in administering this Rate Schedule is limited to transferring the approved gas quantities from the
transferor's account to the transferee's account with the Company.
4. RATE
The Company will charge the transferor (Customer or Agent) $0.02 per Dth transferred. For transactions
of less than 750 Dth, there will be a minimum charge of $15.00 per transaction.
5.
LATE PAYMENT CHARGE
All bills not paid by the next billing date will be subject to a late payment charge as set forth In Section 7 of
the General Terms and Conditions.
ACCEl?T.ElJ l~Gf1: fltl:ffl.G
IDJU'!61$l!\OJiliil fl)JIF ftiTuiEK-tf~l'f :rue&UJ'Ll\\':TIION
STATE CORl?W1l«AITTIWI~ IOGWIMISSION
JAN 2 1 2016
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 164
RATE SCHEDULE DGTS
DAILY GAS TRANSFER SERVICE
(continued)
6.
GENERAL TERMS AND CONDITIONS
Service under this Rate Schedule is subject to the currently effective General Terms and Conditions, as
contained in this Tariff, as well as all appllcable Rules and Regulations of the Virginia State Corporation
Commission, as may be amended from time to time. To the extent that service under this Rate Schedule
is provided to an Agent, service hereunder is likewise subject to 1he currently effective General Terms and
Conditions, as contained in this Tariff in the same manner as if Agent were a "Customer" (to the extent not'
Inconsistent with this Rate Schedule), as well as all applicable Rules and Regulations of the Virginia State
Corporation Commission, as may be amended from time to time.
{
\
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-sec
L
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
{
\
Or!ginal Sheet Nos. 165 through 299 of this Tariff are reserved for future use.
I\.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
ACCEPTED FOR FILING
JANUARY 21, 2016
DIVISION OF ENERGY REGULATION-SCC
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 300
SUPERSEDING
ORIGINAL SHEET NO. 300
FORM OF SERVICE AGREEMENT FOR
LARGE GENERAL SERVICE
THIS AGREEMENT, dated as of this _ _ day of
, 20_, by and between Columbia Gas of
Virginia, Inc., a Virginia public service corporation (hereinafter called the "Company"), and _ _ _ _ __
(hereinafter called "Customer").
WITNESS ETH:
That in consideration of the mutual covenants herein contained, the parties hereto agree as follows:
Section 1. Gas to Be Sold. The Company hereby agrees to sell and deliver and Customer hereby
agrees to purchase and receive natural gas for use by Customer at the delivery point specified herein and
pursuant to the terms, conditions, and price stated in the Company's Rate Schedule(s)
on file with the
Virginia State Corporation Commission or any effective superseding rate schedule(s). The specific amounts
contracted for herein shall be as follows:
Daily Firm Quantity
Daily Interruptible Quantity
Maximum Daily Quantity (adjusted annually)
Section 2. Delivery Point. The delivery point shall be at _ _ _ _ _ _ _ _ _ _ _ __
Section 3. Incorporation of Tariff Provisions. This Agreement expressly incorporates by this
reference all of the terms and conditions of Rate Schedule LGS1/LGS2 and the Company's General Terms and
Conditions, as may be amended from time to time.
Section 4. Term. This Agre.ement shall become effective on __ and shall continue in effect until
_ _ _ _ and thereafter from year to year unless and until canceled by either Customer or the Company
giving written notice to the other no later than April 1, to become effective on November 1, of such year.
Section 5. Subject to Operating Conditions, Permits, etc. Company's obligation to render service
hereunder may be influenced or limited by such operating conditions as may exist on its system from time to
time, with any such limitations more fully described in Rate Schedule LGS1/LGS2 and the General Terms and
Conditions of the Company's tariff, and by its ability to secure and maintain adequate rights, permits, franchises
and any other necessary authorizations.
Section 6. Cancellation of Previous Agreements. This agreement supersedes and cancels, as of
the effective date hereof, the following agreements between Customer (including any and all predecessors in
interest of Customer) and Company as listed below:
Section 7. Notices. Notices to Company under this agreement shall be addressed to it at 1809
Coyote Drive, Chester, VA 23836, Attention: Sales and Marketing Department, and notices to Customer shall be
addressed to it at
, until changed by
either party by written notice
Section 8. Responsibility for Alternate Fuel Facilities. To the extent that the Customer elects
Interruptible Service under Rate Schedule LGS1/LGS2, the Customer acknowledges that the Customer is
responsible for providing and maintaining alternate fuel storage and combustion facilities and for having
available at all times sufficient alternate fuel to maintain desired levels of plant operation during periods of
interruption or curtailment.
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
FIRST REVISED SHEET NO. 301
SUPERSEDING
ORIGINAL SHEET NO. 301
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FORM OF SERVICE AGREEMENT FOR
LARGE GENERAL SERVICE
(continued)
Section 9. Contract Data. A Customer's emergency contact information, billing address and related
billing information shall be included on Attachment A to the Service Agreement, which information, as may be
modified from time to time, are incorporated herein by reference. The Customer shall be responsible for
updating the information on Attachment A on a timely basis.
Section 10. This agreement shall be binding upon Company only when accepted by its duly authorized
officer and shall not be modified by any promise, agreement or representation of any agent or employee of
Company unless incorporated in writing in this agreement before such acceptance.
IN WITNESS WHEREOF, the parties hereto have caused this agreement to be duly executed.
CUSTOMER._ _ _~-~~~~-~-
COLUMBIA GAS OF VIRGINIA, INC
BY~~~~~~~~~~~~~~
BY_ _ _ _ _ _ _ _ _ _ _ _ _~---
TITLE
TITLE._ _ _ _ _ _ _ _ _ _ _ _ _ __
~-------~----~-
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 301A
FORM OF SERVICE AGREEMENT
FOR LARGE GENERAL SERVICE
(continued)
Attachment A
Large General Service Agreement
CUSTOMER EMERGENCY CONTACT INFORMATION
and INVOICE BILLING ADDRESS
FACILITY A D D R E S S : - - - - - - - - - - - - - - - - - - - - - - - - - - - -
PCID# _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __
Emergency Contact Names
Please list TWO names with work, 24-hr/cellular phone, fax, business phone, and e-mail
address. (No Agent Names)
Contact Name
Home Phone
Business Phone
24-hr/Cellular Phone
Fax Number
E-mail Address
INVOICE BILLING ADDRESS
This section should be filled out using the facility's accounts payable infonnation.
Attention:
Address
Telephone:
Fax:
E-mail:
Customer Signature:
Printed:
Title:
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 302
SUPERSEDING
ORIGINAL SHEET NO. 302
FORM OF SERVICE AGREEMENT
FOR TS1 AND TS2 GAS TRANSPORTATION SERVICE
THIS AGREEMENT, made and entered into as of the _ _day of _ _ _ _ _ _ _ , 20_, by and
between COLUMBIA GAS OF VIRGINIA, INC., a Virginia public service corporation, 1809 Coyote Drive,
Chester Virginia 23836 (hereinafter "Company"), and
(hereinafter
"Customer").
WHEREAS, Customer has secured supplies of natural gas that it desires to transport to its facility listed
in the Contract Data Addendum to this Agreement within the operating parameters established by the Company
and subject to the terms and conditions of the Company's Rate Schedule TS1 or TS2 and other applicable tariff
provisions;
WHEREAS, Company is willing and able, pursuant to the terms of this Agreement, to accept gas
delivered to its city gate receipt points by or on behalf of Customer and to redeliver such gas supplies to
Customer's service location(s) pursuant to the terms and conditions of Rate Schedule TS1 or TS2;
NOW, THEREFORE, in consideration of the mutual covenants contained in this Agreement, Company
agrees to permit Customer to commence service under Rate Schedule TS1 or TS2 and Customer hereby
agrees to take such service in accordance with the following terms and conditions:
Section 1. Transportation Service to be Rendered. In accordance with the provisions of the
Company's transportation Rate Schedule TS1!TS2, on file with the Virginia State Corporation Commission
("SCC") and the terms and conditions herein contained, Company shall receive the quantities of gas requested
by Customer to be transported and shall redeliver said gas to Customer's facilities. The Point(s) of Receipt,
Customer facility location, the applicable Rate Schedule, and the service and levels of said services to be
rendered, shall be .set forth in the Contract Data Addendum to this Agreement, as may be amended from time to
time.
Section 2. Incorporation of Tariff Provisions. This Agreement expressly inco.rporates by this
reference all of the terms and conditions governing Company's transportation service in the applicable Rate
Schedule and the Company's General Terms and Conditions, as may be amended from time to time. In all
events, the terms and conditions of Rate Schedule TS1!TS2 shall be controlling to the extent inconsistent with
the Company's General Terms and Conditions.
Section 3. Term. The term of this Agreement shall commence on the first day of the month after
execution hereof and, subject to Customer's continued compliance with the requirements outlined herein, shall
continue in effect thereafter for a minimum primary term of twelve (12) months, until October 31, 20_, and
thereafter from year to year unless and until canceled by either Customer or Company by giving written notice to
the other no later than April 1, to become effective on November 1 of such year.
Section 4. Subject to Operating Conditions, Permits, etc. Company's obligation to render service
hereunder may be influenced or limited by such operating conditions as may exist on its system from time to
time, with any such limitations more fully described in Rate Schedule TS1!TS2 and the General Terms and
Conditions of the Company's tariff, and by the Company's ability to secure and maintain adequate rights,
permits, franchises and any other necessary authorizations.
Section 5. Cancellation of Prior Agreements This Agreement supersedes and cancels, as of
the effective date hereof, all previous two party transportation agreements and any Commercial or Industrial
Gas Service Agreements between the parties for service to Customer's facilities served hereunder.
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 303
SUPERSEDING
ORIGINAL SHEET NO. 303
FORM OF SERVICE AGREEMENT
FOR TS1 AND TS2 GAS TRANSPORTATION SERVICE
(continued)
Section 6. Notices. Any notices, except those relating to billing, restriction, interruption or curtailment
of service(s), required or permitted to be given hereunder or pursuant to an applicable Rate Schedule or the
Company's General Terms and Conditions, shall be effective only if delivered personally to an officer or
authorized representative of the party being notified, or if mailed by certified mail to the address provided in
accordance with Section 9 of this Agreement.
Section 7. Signature of Officers Required. This Agreement shall be binding upon Company only
when accepted by its duly authorized officer and shall not be modified by any promise, agreement or
representation of any agent or employee of Company unless incorporated in writing in this Agreement before
such acceptance.
Section 8. Responsibility for Alternate
Customer is responsible for providing and
facilities and for having available at all times
plant operation during periods of interruption
issued by Company.
Fuel Facilities. The Customer acknowledges that the
maintaining alternate fuel storage and combustion
sufficient alternate fuel to maintain desired levels of
or curtailment and any period when a BSR has been
Section 9. Contract Data. The Customer specific contract data and service elections are set forth in
the attached Contract Data Addendum to Service Agreement for TS1 and TS2. The Contract Data contained
therein, as may be modified from time to time in accordance with the provisions of this Rate Schedule and Rate
Schedule BBS, are incorporated herein by reference. A Customer's emergency contact information, billing
address and related billing information shall be included on Attachment A to the Service Agreement, which
information, as may be modified from time to time, are incorporated herein by reference. The Customer shall be
responsible for updating the information on Attachment A on a timely b?sis.
Section 10. Appointment of Agent. The Customer may appoint an Agent for purposes of establishing
and administering gas transportation service under this Rate Schedule. The appointment of an Agent shall be in
the form set forth in an Appointment of Agent and Acknowledgement of Service Form, as may be modified from
time to time in accordance with the provisions of this Rate Schedule, which is incorporated herein by reference.
Section 11. Acknowledgement of Service. The Customer shall elect either non-aggregated service
under this Rate Schedule or aggregated service under this Rate Schedule and Rate Schedule AS, which shall
be designated in an Appointment of Agent and Acknowledgement of Service Form, as may be modified from
time to time in accordance with the provisions of this Rate Schedule and Rate Schedule AS, which is
incorporated herein by reference.
IN WITNESS WHEREOF, the parties hereto have accordingly and duly executed this Agreement as of
the date hereinabove first mentioned.
CUSTOMER_ _ _ _ _ _ _ _ _ _ _ __
COLUMBIA GAS OF VIRGINIA, INC
BY~----------------
BY________________
TITLE._ _ _ _ _ _ _ _ _ _ _ _ __
TITLE._ _ _ _ _ _ _ _ _ _ _ _ _ __
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
~
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 304
SUPERSEDING
ORIGINAL SHEET NO. 304
FORM OF SERVICE AGREEMENT
FOR TS1 AND TS2 GAS TRANSPORTATION SERVICE
(continued)
Attachment A
TS1/TS2 Service Agreement
CUSTOMER EMERGENCY CONTACT INFORMATION
and INVOICE BILLING ADDRESS
FACILITY ADDRESS: _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __
PCID# _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _~--~
Emergency Contact Names
Please list TWO names with work, 24-hr/cellular phone, fax, business phone, and e-mail
address. (No Agent Names)
Contact Name
Home Phone
Business Phone
24-hr/Cellular Phone
Fax Number
E-mail Address
INVOICE BILLING ADDRESS
This section should be filled out using the facility's accounts payable information.
Attention:
Address
Telephone:
Fax:
E-mail:
Customer Signature:
Printed:
Title:
MAIL COMPLETED FORM TO:
GAS TRANSPORTATION SERVICES, COLUMBIA GAS OF VIRGINIA, 290 W NATIONWIDE BLVD, COLUMBUS, OH
43215
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 305
SUPERSEDING
ORIGINAL SHEET NO. 305
FORM OF SERVICE AGREEMENT
FOR TS1 AND TS2 GAS TRANSPORTATION SERVICE
{continued)
Effective Billing Month/Year: _ _ __
Addendum to Service Agreement Dated: _ _ __
Contract Data Addendum to Service Agreement For TS1 and TS2
A. Point(s) of Receipt into Columbia Gas of Virginia, Inc. - Point(s) of Receipt with Interstate
Pipelines
1)
Columbia Gas Transmission Corporation (TCO)
2)
Other Point(s) of R e c e i p t : - - - - - - - - - - - - - - -
8. FACILITY ADDRESS: _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __
PCID: _ _ _ _ _ _ _ _ _ _ _ _ PSID: _ _ _ _ _ _ _ _ _ _ _ _ _ _ __
Description of Business:
•Rate
Selection:
D TS1
Alternate Fuel:
Type
D
Alternate Fuel:
Percent
TS2
• Firm Banking
and Balancing
Service
D YES
D NO
• Daily CashOut Option
D YES
D
NO
(Subject to
approval by
Company)
*Monthly
Bank
Tolerance
D y,, %
D 1%
D 2%
D 3%
O 4%
D 5%
*Standby
Service
(Dth)
(Subject to
approval by
Company)
Company
Polling
Service
D YES
D NO
(Must
complete
Enrollment
Form)
otices
Company Name:
Columbia Gas of Virginia, Inc
dba {if applicable):
Attn: Gas Transportation
290 W Nationwide Blvd
Columbus, OH 43215
Address:
City, St, Zip:
Attn:
Telephone #: (
* Demand
Title:
)
Fax#: ( )
E-mail Address:
IN WITNESS WHEREOF, the parties hereto have accordingly and duly executed this Contract Data Addendum as of
the date herein above first mentioned.
CUSTOMER
COLUMBIA GAS OF VIRGINIA, INC.
By: ~--------=,.--~-,---------(Signature)
By:~~-~-~>=-__.,.____,~~--~
(Signature)
Printed:-----------------
Printed:
Title:------------------
Title: - - - - - - - - - - - - - - -
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
!,.L--
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 306
l. -FORM OF SERVICE AGREEMENT
FOR TS1 AND T52 GAS TRANSPORTATION SERVICE
(continued)
I PONOTWRltl't ~ELOW THIS UNl;·For Gb!umbia Per~mnneJ On[y. NOTE AH Max Day &·Annual Tr!J.nspllrtation Quantities Updated Annually
0New
Customer
DNew
Facility
MaKDally
Quantity
(MDQ)
(Dth)
0Amendment
PSID#
Annual
Transportation
Quantity
(ATQ)
(Dth)
Monthly
Bank
Tolerance
EFC
Firm Service
Annual Quantity
(Dth)
Firm Service
Daily
Quant!ty(Dth)
Demand Polling
Service
0Yes
0No
SIC Code
PSP
. Invoice#:
APPROVAL:
Company R e p r e s e n t a t i v e : - - - - - - - - - - - - - - - - - - -
Date:
-----
Comments - - - - - - - - - - - - - - - - - - - - - Effective Date: _ _ _ __
Eff~ctive
Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulatlon-SCC
ORIGINAL SHEET NO. 307
Effective Billing Month/Year: _ __
For Service Agreement Dated: _ __
COLUMBIA GAS OF VIRGINIA, ING.
APPOINTMENT OF AGENT and ACKNOWLEDGEMENT OF SERVICE FORM
For Rate Schedules TS1/TS2 or LVTS
. KNOW ALL MEN BY THESE PRESENTS that
("Customer") does hereby
make, constitute and appoint
("Agent") as its AGENT for the
purpose of establishing and administering a gas transportation program on the Columbia Gas of Virginia, Inc.
("Columbia") system for and on behalf of Customer for the accounts listed below. This appointment authorizes
Agent to establish such gas transportation program on behalf of Customer, including (by way of illustration and
not limitation) the following: request gas transportation service from Columbia; obtain Customer's historic and
current usage data from Columbia; .nominate gas transportation quantities on behalf of Customer; direct
Columbia to send Customer's transportation bill directly to Agent; and obtain from Columbia any information
pertaining to prior or current month gas deliveries to Customer.
Choose type of gas transportation service (CHECK & INITIAL ONE ONLY):
0 Non-Aggregation Service (Stand Alone):
Under Non-Aggregation Service (Stand Alone), Customer agrees to be responsible for all Columbia
charges, fees, and penalties associated with providing gas transportation service,
Customer Initials: _ __
D Aggregation Service (AS}:
ACKNOWLEDGEMENT OF SERVICE UNDER RATE SCHEDULE AS
This Acknowledgement of Service reflects the agreement of the undersigned Customer to service
under Schedule AS.
By executing this Agreement, Customer agrees to be bound by the terms and conditions of Schedule
AS {as well as the Customer's underlying transportation Rate Schedule and associated Service
Agreement) including, but not limited to, Customer Obligations reflected In Section 15 of Rate Schedule
AS, as well as the Service Agreement to which this Acknowledgement is attached:
Each customer that becomes part of an Agent's Aggregation Nomination Group (ANG), as
defined in Rate Schedule AS - Aggregation Service, will retain ultimate responsibility for any and all
charges, fees and penalties applicable under the terms and conditlons of Rate Schedule AS, Rate
Schedule BBS and the Company's General Terms and Conditions in the event that the Agent fails to
pay within the time prescribed in the Company's tariff and/or General Terms and Conditions,
notwithstanding the fact that the Company will bill the Agent for such charges, fees and penalties.
Any suoh unpaid charges, fees and penalties will be assessed to Customers within each ANG on a
pro rata basis based on the ratio of each Customer's gas usage to the usage of all Customers
participating in that ANG during the month for which the charge, fee and/or penalty ls applied. The
charges, fees and penalties to which this provision is applicable include, but are not limited to, excess
bank tolerance charges, BSR penalties and charges, commodity charges associated with excess
consumption (except with regard to customer specific interruptions of transportation service), daily
gas transfer fees, late payment· charges and charges for an Agent's access to its Customers daily
demand measurement information.
Customer also consents to the release of its daily demand measurement information for the
foll owing facility/location to the Agent under the terms and conditions set forth in Rate Schedule AS and
other applicable Rate Schedules.
Customer Initials: _ __
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE~2014·00020
Accepted for Filing
Janauiy 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 306
COLUMBIA GAS OF VIRGINIA, INC.
APPOINTMENT OF AGENT and ACKNOWLEDGEMENT OF SERVICE FORM
For Rate Schedules TS1/TS2 or LVTS
Acct. No.
Acct. No.
Acct. No.
Acct. No.
Acct. No.
Acct. No.
Acct. No.
Acct. No.
Acct. No.
Acct. No.
Acct. No.
Acct. No.
CUSTOMER AUTHORIZED EMPLOYEE INFORMATION:
EXECUTED BY CUSTOMER:--,-~~~~~~~-------~~
(Must be signed by Authorized Employee of Company)
"
'
\
(Please Print Authorized Employee Name)
Title:---------------
Address:------------
Phone No.: -------~-----
Fax N o . : - - - - - - - - - - - -
E·Mail A d d r e s s : - - - - - - - - - - -
Date: _ _ _ _ _ _ _ _ _ _ _ _ __
AGENT AUTHORIZED EMPLOYEE INFORMATION:
EXECUTED BY AGENT: _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __
(Must be signed by Authorized Employee of Agent)
(Please Print Authorized Employee Name)
Title:----...,.-----------
Address:------------
Phone N o . : - - - - - - - - - - - - -
Fax No.: _ _ _ _ _ _ _ _ _ _ __
E-Mail A d d r e s s : - - - - - - - - - - -
Date: _ _ _ _ _ _ _ _ _ _ _ __
EXECUTED BY C O L U M B I A : - - - - - - - - - - - - - - - - - Name: _ _ _ _ _ _ _ _ _ _ _ _ _~
Address:------------
Title: _ _ _ _ _ _ _ _ _ _ _ _ _ __
Date: _ _ _ _ _ _ _ _ _ _ _ __
Effective Date: February 1, 2016
Per August 21, 2015 Final Order In Case No. PUE-2014·00020
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
..
-
\
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
ORIGINAL SHEET NO. 309
-
BANKING AND BALANCING SERVICE AGREEMENT
FOR LVTS CUSTOMERS
THIS AGREEMENT, made and entered into this _ _ day of
, 20_, by and between
COLUMBIA GAS OF VIRGINIA, INC., 1809 Coyote Drive, Chester, VA, 23836, a Virginia public service
corporation (hereinafter "Company"), and
, (hereinafter
"Customer").
WITNESS ETH:
That in consideration of the mutual covenants contained in this Agreement, Company agrees to
provide service to Customer under Rate Schedule BBS - Banking and Balancing Service, and Customer
hereby agrees to take such service In accordance with the followlng terms and conditions:
Section 1. Service Elections and Information. Customer chooses the following service:
<
Monthly Bank Tolerance:
0% %
Firm Banking and Balancing Service:
01%
0 2%
0
03%
Yes
0 4%
0
05%
No
Facility Address: - - - - - - - - - - - - - - - - - - - PCID:
----------~
PSID: - - - - - - - - -
Section 2. Term. This Agreement shall become effective on
, 20_ and shall
continue in effect thereafter for a minimum primary term of twelve (12) months, until October 31, 20_, and
thereafter from year to year unless and until cancelled by either Customer or Company giving written notice
no later than April 1, to become effective on November 1, of such year.
Section 3. Incorporation of Tariff Provisions. This Agreement expressly incorporates by this
reference all of the terms and conditions of Rate Schedule BBS and the General Terms and Conditions of
Company's Tariff, as may be amended from time to time.
Section 4. Notices. Notices to be provided regarding the banking and balancing service provided in
accordance with this Agreement shall be to the following points of contact:
Customer Notices: (Please Print)
Company Name:
Oba {if applicable):
Address:
City, St. Zip:
Attn:
Telephone#: ( )
Fax#: ( )
E-mail Address:
-
-
Company Notices
Columbia Gas of Virginia, Inc.
I Title:
Attn:
Section 5. Signature of Officers Required. This Agreement shall be binding upon Company only
when accepted by Its duly authorized officer and shall not be modified by any promise, agreement or
representation of any agent or employee of Company unless Incorporated In writing in this Agreement before
such acceptance.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
i~··-.
\..
-.
Accepted for Fiiing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, ING.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 310
BANKING AND BALANCING SERVICE AGREEMENT
FOR LVTS CUSTOMERS
(continued)
IN WITNESS WHEREOF, the parties hereto have accordingly and duly executed this Agreement as of
the date hereinabove first mentioned.
CUSTOMER
COLUMBIA GAS OF VIRGINIA, INC.
By~-~~~~~~~-~
(Signature)
By_ _~----~~---
Printed _ _ _ _ _ _ _ _ _ __
Title _ _ _ _ _ _ _ _ _ _ __
(Signature)
Printed-----------
Title_ _ _ _ _ _ _ _ _ _ _ __
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
Accepted for FIUng
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
.
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET N0.·311
STANDBY SERVICE AGREEMENT
FOR LVTS CUSTOMERS
THIS AGREEMENT, made and entered Into this _ _ day of
, 20_, by and between
COLUMBIA GAS OF VIRGINIA, INC., 1809 Coyote Drive, Chester, VA, 23836, a Virginia public service
corporation (hereinafter "Company"), and
, (hereinafter
"Customer").
WITNESS ETH:
That In consideration of the mutual covenants contained In this Agreement, Company agrees to
provide service to Customer under Rate Schedule SS - Standby Service, and Customer hereby agrees to
take such service in accordance with the following terms and conditions:
Section 1. Ser¥ice Election and Information. Customer chooses the following service level:
Standby Service Quantity:
Facility Address: - - - - - - - - - - - - - - - - - - - PSID: - - - - - - - PCID: - - - - - - - - - -
{
Section 2. Term. This Agreement shall become effective on
, 20_ and shall
continue in effect thereafter for a minimum primary term of twelve (12) months, until October 31, 20__, and
thereafter from year to year unless and untn cancelled by either Customer or Company giving written notice
no later than Aprll 1, to become effective on November 1, of such year.
J
\
Section 3. Incorporation of Tariff Provisions. This Agreement expressly Incorporates by this
reference all of the terms and conditions of Rate Schedule BBS and the General Terms and Conditions of
Company's Tariff, as may be amended from time to time.
Section 4. Notices. Notices to be provided regarding the banking and balancing service provided In
accordance with this Agreement shall be to the following points of contact:
Customer Notices: (Please Print)
Company Name:
Oba {If applicable}:
Address:
City, St. Zip:
Attn:
Telephone#: ( )
Fax#: ( )
.
.
Company Notices
Columbia Gas of Virginia, Inc.
I Title:
Attn:
E-mail Address:
Section 5. Signature of Officers Required. This Agreement shall be binding upon Company only
when accepted by its duty authorized officer and shall not be modified by any promise, agreement or
representation of any agent or employee of Company unless incorporated in writing in this Agreement before
such acceptance.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
.r--
1
%- ·--·
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulatfon-SCC
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 312
STANDBY SERVICE AGREEMENT
FOR LVTS CUSTOMERS
(continued)
IN WITNESS WHEREOF, the parties hereto have accordingly and dulY. executed this Agreement as of
the date hereinabove first mentioned.
CUSTOMER
COLUMBIA GAS OF VIRGINIA, INC.
By_ _ _ _ _ _ _ _ _ _ _ _
~
(Signature)
By_ _ _ _ _ _ _ _ _ _ _ _
~
(Signature)
Printed-----------
Title _ _ _ _ _ _ _ _ _ _ __
Title _ _ _ _ _ _ _ _ _ _ __
("
(
\.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
ORIGINAL SHEET NO. 313
COLUMBIA GAS OF VIRGINIA, INC.
COMPETITIVE SERVICE PROVIDER SERVICE AGREEMENT
This Agreement is made and entered into this __ day of
, 20__ , between Columbia Gas of
Virginia, lno., 1809 Coyote Drive, Chester, Virginia 23836, a Virginia public servloe corporation, (hereinafter
"Company"), and
, a(n)
corporation _ _ _ __
(hereinafter 11 CSP 11 ).
WHEREAS, CSP has been duly licensed by the Virginia State Corporation Commission ("SCC").
WHEREAS, CSP has secured firm supplies of natural gas which it intends to supply and sell to gas
Customers located on the Company's system, all within the parameters established by the Company for its
Residential Transportation Service (RTS), Small General Transportation Service (SGTS1, SGTS2 and SGTS3),
Unmetered Gas Light Transportation Service (UGLTS), and Air Conditioning Transportation Service (ACTS)
("Applicable Rate Schedules") Customers; and
WHEREAS, Company is willing and able, pursuant to the terms of this Agreement, to accept gas
delivered into its city gate receipt points designated by the Company, by CSP, and to redeliver such gas
supplies to CSP's Customers, all of whom have eleoted transportation service from the Company under one or
more of its Applicable Rate Schedules;
NOW, THEREFORE, in consideration of the mutual covenants contained in this Agreement, Company
agrees to permit CSP to commence service under Rate Schedule CSPS - Competitive Service Provider Service
and CSP hereby agrees to take such service in accordance with the following terms and conditions:
Section 1.
Service to be Rendered. In accordance with the provisions of Rate Schedule CSPS,
the Applicable Rate Schedules and General Terms and Conditions, on file with the sec, and the terms and
conditions herein contained, Company shall provide· a service that allows CSP to deliver to Company, on an
aggregated basis, tl1ose natural gas supplies that are sufficient to satisfy the requirements of the one or more
transportation customers that comprise the membership of the CSP's Customer Group.
Section 2.
Term. The term of this Agreement shall commence on the first day of the month after
execution hereof and, subject to CSP's continued compliance with the requirements set forth herein for
participation In this program, shall continue in effect thereafter for a primary term of twelve (12) months.
Thereafter, this Agreement shall continue from month-to-month, unless terminated by either party, upon at least
ninety (90) days advance written notice or as otherwise provided in applicable provisions of the Company's
Tariff or the SCC Rules Governing Retail Access to Competitive Energy Services, 20 VAC 5-312-10 et seq.
("SCC Retail Access Rules").
Section 3.
Billing Options. ln aocordanoe with the billing options as provided in Rate Schedule
CSPS, the CSP hereby elects to
__(1)
Have the Company issue the total bill; or
__(2)
Have the Company bill for only the non-gas cost portion of the bill; or
__(3)
Negotiate a customized billing service with the Company.
PLEASE INDICATE SELECTION BY INITIALING BY ONE OF THE NUMBERS LISTED ABOVE.
Section 4.
Mandatory Capacity Assignment. Under the terms of Rate Schedule CSPS,
capacity assignment is mandatory. The Company shall make an assignment of capacity for the CSP's
Customer Group, as set forth in the Gas Supply Operations Plan.
Effective Date: February 1, 2016
Per August 21, 2015 Flnal Order in Case No. PUE-2014-00020
l.r-
1
\. __.
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 314
COLUMBIA GAS OF VIRGINIA, INC.
COMPETITIVE SERVICE PROVIDER SERVICE AGREEMENT
(continued)
Section 5
Succession and Assignment. This Agreement shall Inure to and be binding upon the
successors and assigns, survivors and executors or administrators as the case may be, of the original parties
thereto, respectively, for the full term thereof. However, no Service Agreement may be assigned or transferred
without the written consent of or approval of the Company, which shall not be unreasonably withheld. No
assignment of this Agreement shall relieve the assigning party of any of its obligations under this Agreement
until such obligations have been assumed by the assignee. Notwithstanding the foregoing, Company may
assign any or all of Its rights and obligations u'nder this Agreement, without CSP's consent, to any entity
succeeding to all or substantially all of the transmission and distribution facilities of Company, or any affiliated
entity of Company that acquires the properties of the Company used in rendering service to CSP's
Customers, if such assignee agrees, in writing, to be bound by all of the terms and conditions hereof, and
provided that any necessary regulatory approvals are obtained. Either CSP or Company may assign or pledge
this Agreement between them under the provisions of any mortgage, deed of trust, indenture or similar
Instrument that it has executed or may execute hereafter; provided, however, such mortgage, deed of trust,
indenture or similar instrument shall cover the properties of such party as an entirety unless such party is an
affiliated successor in interest as referenced above. in no event shall any party be relieved of its obligations of
confidentiality Incurred pursuant to this Agreement.
Section 6.
Applicable Law and Regulations. Thts Agreement shall be construed under the laws
of the Commonwealth of Virginia and shall be subject to all valid applicable state, federal and local laws, rules,
orders, and regulations. Nothing herein shall be construed as divesting or attempting to divest any regulatory
body of any of its rights, jurisdiction, powers or authority conferred by law.
Section 7.
Notices and Correspondence. Unless otherwise stated herein; In Rate Schedule
CSPS, or in the Applicable Rate Schedules, all notices, demands or requests required or permitted under this
Agreement shall be In writing and shall be personally delivered or sent by overnight mail or courier service, or
by facsimile or email transmission (with the original transmitted by overnight mail or courier service). Written
notices and correspondence shall be directed to Company as follows:
Columbia Gas of Virginia, Inc.
Address:------------Attention:
Telephone:
Facsimile:
Email:
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 315
COLUMBIA GAS OF VIRGINIA, INC.
COMPETITIVE SERVICE PROVIDER SERVICE AGREEMENT
(continued)
Written notices and correspondence to CSP shall be addressed as follows:
CompanyName:~~~~~~~~~~­
Address:
Attention:
Telephone:
Facsimile:
Email:
Either party may change its address, telephone, facsimile or email Information for receiving notices
effective upon receipt, by written notice to the other party. In addition, CSP, as part of its registration process
with Company, shall provide the above-listed information for CSP's registered agent in Virginia and for
appropriate points of contact to address operational, business coordination and customer account issues, to the
extent those points of contact are different than the above-named recipient of written notices and
corresponds nee.
(
Section 8.
Change in Applicable Legal Authorities. This Agreement is subject to change in the
future to reflect any relevant changes required by the sec or other state agency having jurisdiction, or by virtue
of any federal, state, or local law, order or regulation, and such changes shall be deemed to be binding upon the
parties, except where the right to terminate is exercised In accordance with the terms of this Agreement.
Section 9.
(a)
Indemnification. To the fullest extent permitted by law, CSP shall defend, indemnify, and hold
harmless Company from and against any and all claims and/or liabilities for losses, expenses,
damage to property, injury to or death of any person, including Company's employees or any third
parties, or any other liability Incurred by Company, Including reasonable attorneys' fees, relating
to performance under this Agreement, except to the extent that a court of competent jurisdiction
determines that the losses, expenses or damages were caused wholly or in part by any grossly
negligent or w!llful act or omission of the Company.
(b)
Survival of Indemnification. CSP's obligation to defend, Indemnify and hold harmless shall
survive termination of this Agreement, and shall not be limited in any way by any limitation on the
amount or type of damages, compensation or benefits payable by or for CSP under any statutory
scheme, including any Workers Compensation Acts, Disability Benefit Acts or other Employee
Benefit Acts.
Section 10.
I
i
Indemnification.
Miscellaneous Provisions.
(a)
This Agreement shall not be interpreted or construed to create an association, joint venture, or
partnership between the parties, or to Impose any partnership obligation or liablllty upon either
party. Neither party shall have any right, power, or authority to enter any agreement or
undertaking for, or on behalf of, or to act as or be an agent or representative of, or to otherwise
bind, the other party.
(b)
Cancellation, expiration or early termination of this Agreement shall not relleve the parties of
obligat!ons that by their nature survive such cancellation, expiration or termination, including,
without limitation, payment of any amounts due, warranties, remedies, promises of indemnity and
confidentiality.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
,L:__
l
•;..
__ .
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulatlon-SCC
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 316
COLUMBIA GAS OF VIRGINIA, INC.
COMPETITIVE SERVICE PROVIDER SERVICE AGREEMENT
(continued)
(c)
Should any provision of this Agreement be held invalid or unenforceable, such provision shall
be lnvalld or unenforceable only to the extent of such invalidity or unenforceability without
invalidating or rendering unenforceable any other provision hereof, unless it materially changes
the Agreement of the parties.
(d)
Each of the parties hereto acl<nowledges that it has read this Agreement, Virginia Code Section
56-235.8, and the SCC's Rules Governing Retail Access to Competitive Energy Services (20
VAC 5-312-10 et seq.) and agrees to be bound by their terms. This Agreement is intended by
the parties as a final expression of their agreement and is intended also as a complete and
exclusive statement of the terms of their agreement. All prior written or oral understandings,
offers or other oommunications of every l<lnd pertaining to this Agreement are hereby abrogated
and withdrawn.
IN WITNESS WHEREOF, the parties hereto executed this Agreement on the day and year first above
written.
ATIEST:
COLUMBIA GAS OF VIRGINIA, INC.
BY~~~~~~~~~~~~~~~~-
ATIEST:
CSP
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUEM2014-00020
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 317
COLUMBIA GAS OF VIRGINIA, INC.
AGGREGATION SERVICE AGREEMENT
(ASA)
ANG#_ _ _ _ _ _~
This Agreement Is made and entered Into as of the_ day of ___ , 20_, between Columbia Gas
of Virginia, Inc., 1809 Coyote Drive, Chester, Virginia 23836, a Virginia public service corporation, hereinafter
"Company," and
a(an)
corporation _ _ _ _ _ __
hereinafter "Agent."
WHEREAS, Agent: has secured supplies of natural gas which it intends to supply and sell to gas
customers located on the Company's system, all within the operating parameters established by the Company
and subject to the terms and conditions of the Company's applicable tariffs including Rate Schedule AS and
BBS;
WHEREAS, Company is willing and able, pursuant to the terms of this Agreement, to accept gas
delivered Into its city gate receipt points by an Agent and to redeliver such gas supplies to Agent's customers, all
of whom have elected transportation service from the Company under Rate Schedule BBS;
WHEREAS, an Agreement between Company and Agent is needed for Agent to register with Company
and to engage In the provision of aggregation service to Company's industrial and commercial customers taking
service under Rate Schedule BBS;
NOW, THEREFORE, In consideration of the mutual covenants contained in this Agreement, Company
agrees to permit Agent to commence service under Rate Schedule AS and Agent hereby agrees to tal<e such
service in accordance with the following terms and conditions:
Section 1.
Service to be Rendered. In accordance with the provisions of the Rate Schedule AS
on file with the Virginia State Corporation Commission ("SCC"), and the terms and conditions herein contained,
Agent shall deliver to Company, on an aggregated basis, those natural gas supplies that are needed to satisfy
the requirements of the Rate Schedule BBS Customers that comprise the membership of the Agent's
Aggregation Nomination Group ("ANG").
Section 2.
Incorporation of Tariff Provisions. This Agreement expressly Incorporates by this
reference all of the terms and conditions governing the Company's Rate Schedule AS and Rate Schedule BBS,
the Company's General Terms and Conditions of Service, and such other rules, regulations and Tariff provisions
as may be applicable to Agent's served under Rate Schedule AS, as may be applicable from time to time. In all
events, the terms and conditions of Company's applicable Rate Schedule(s) shall be controlling to the extent
Inconsistent with the Company's General Terms and Conditions.
Section 3.
Term. The term of this Agreement shall commence on the first day of the month after
execution hereof and, subject to Agent's continued compliance with the requirements outlined herein shall
continue in effect thereafter for a primary term of twelve (12) months. Thereafter, this Agreement shall continue
from month-to-month, unless and until terminated by either party, upon at least ninety (90) days advance written
notice.
Section 4.
Subject to Operating Conditions. Company's obligation to render service hereunder
is subject to such operating conditions and service restrictions as may exist on its system from time to time
including, but not limited to, operational requirements, Interruptions and curtailments as described in the
applicable Rate Schedule(s) and General Terms and Conditions.
Section 5.
Requirements for Participation. The standards for participation shall be the
requirements as described In Rate Schedule AS, the Company's General Terms and Conditions, and other
rules, regulations and tariff provisions as may be applicable.
Effective Date: February 1, 2016
Per August 21, 2016 Final Order In Case No. PUE-2014-00020
Accepted for Filing
Janaury 21 , 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, ING.
GAS TARIFF
ORIGINAL SHEET NO. 318
SEVENTH REVISED VOLUME NO. 1
COLUMBIA GAS OF VIRGINIA, INC.
AGGREGATION SERVICE AGREEMENT
(ASA)
(continued)
Section 6,
Change in Applicable Legal Authorities. This Agreement is subject to change in
the future to reflect any relevant changes required by the sec or other state agency having jurisdiction, or by
virtue of any federal, state, or local law, order or regulation, and such changes shall be deemed to be binding
upon the parties, except where the right to terminate is exercised in accordance with the terms of this
Agreement.
Section 7.
Limitation of Third Party Rights. Except as otherwise contemplated herein and in
Rate Schedule AS, this Agreement Is entered Into solely for the benefit of the Company, the Agent, and those
Customers comprising the ANG and is not intended and should not be deemed to vest any rights, privileges or
interests of any kind or nature to any other party.
/
~
Section 8.
Succession and Assignment. This Agreement shall be binding upon and inure to the
benefit of the successors and assigns of the respective parties hereto. However, assignment of this Agreement,
in whole or in part, will not be made without the prior written approval of the non~assigning party. The written
consent to assignment shall not be unreasonably withheld. No assignment of this Agreement shall relieve the
assigning party of any of its obligations under this Agreement until sucn obligations have been assumed by
the assignee. Notwithstanding the foregoing, Company may assign any or all of its rights and obligations
under this Agreement, without Agent's consent, to any entity succeeding to all or substantially all of the
transmission and distribution facilities of Company, or any affiliated entity of Company that acquires the
properties of the Company used in rendering service to Agent's ANG, if such assignee agrees, in writing, to
be bound by all of the terms and conditions hereof, and provided that any necessary regulatory approvals are
obtained. Either Agent or Company may assign or pledge this Agreement between them under the provisions
of any mortgage, deed of trust, indenture or similar instrument that it has executed or may execute hereafter;
provided, however, such mortgage, deed of trust, indenture or similar instrument shall cover the properties of
such ·party as an entirety unless such party is an affiliated successor in Interest as referenced above. In no
event shall any party be relieved of Its obligations of confidentiality incurred pursuant to this Agreement.
Section 9. Applicable Law and Regulations. This Agreement shall be construed under the laws of
the Commonwealth of Virginia and shall be subject to all valid applicable state, federal and local laws, rules,
orders, and regulations. Nothing herein shall be construed as divesting or attempting to divest any regulatory
body of any of its rights, jurisdiction, powers or authority conferred by law.
Section 10.
No Preludice of Rights. No term or condition of this Agreement shall be deemed to
have been waived and no breach excused unless such waiver or consent to excuse Is in writing and signed
by the party claimed to have waived or consented to excuse. The failure of either party to Insist in any one or
more instances upon strict performance of any provisions of this Agreement, or to take advantage of any of its
rights hereunder, shall not be construed as a waiver of any such provisions or the relinquishment of any such
right or any other right hereunder, which shall remain In full force and effect.
Section 11.
(a)
Indemnification.
Indemnification. To the fullest extent permitted by law, Agent shall defend, indemnify, and hold
harmless Company from and against any and all claims and/or iiablllties for losses, expenses,
damage to property, injury to or death of any person, including Company's employees or any
third parties, or any other liability incurred by Company, including reasonable attorneys' fees,
relating to performance under this Agreement, except to the extent that a court of competent
jurisdiction determines that the losses, expenses or damages were caused wholly or in part by
any grossly negligent or willful act or omission of the Company.
Effective Date: February 1, 2016
Per August 21, 2016 Final Order in Case No. PUE~2014-00020
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulatron-SCC
ORIGINAL SHEET NO. 319
COLUMBIA GAS Or VIRGINIA, INC.
AGGREGATION SERVICE AGREEMENT
(ASA)
(b)
Survival of Indemnification. Agent's obligation to defend, indemnify and hold harmless shall
survive termination of this Agreement, and shall not be limited In any way by any limitation on
the amount or type of damages, compensation or benefits payable by or for Agent under any
statutory scheme, Including any Workers Compensation Acts, Disability Benefit Acts or other
Employee Benefit Acts.
·Section 12.
Customer Acknowledgement of Service. Each Customer to be Included In the ANG
to be established pursuant to this Agreement shall execute an Acknowledgement of Service as a participant in
the ANG in the form provided as Attachment 1 to this Agreement. Separate Attachments wlll be required for
multiple service locations.
Section 13.
Notices and Correspondence. Any notices, except those relating to billing, or
restriction, Interruption, or curtailment of service, required or permitted to be given hereunder or pursuant to Rate
Schedule AS, other applicable Rate Schedule, or Company's General Terms and Conditions shall be effective
only If delivered personally to an officer or authorized representative of the party being notified or, if by mail, by
certified mail. Written notices, correspondence and discrepancies shall be directed to the Company as follows:
Columbia Gas of Virginia, Inc.
Address: _ _ _ _ _ _ _ _ _ _ __
Attention:-----------Telephone:-----------Facsimile:-----------Email:
Written notices and correspondence to the Agent shall be addressed as follows:
Company N a m e : - - - - - - - - - Address: _ _ _ _ _ _ _ _ _ _ __
Attention: _ _ _ _ _ _ _ _ _ _ __
Telephone: _ _ _ _ _ _ _ _ _ _ __
Facsimile: _ _ _ _ _ _ _ _ _ _ __
Email:
Either party may, by written notice to the other party, change Its address, telephone or facsim lie or email
information for receiving notices effective upon receipt by the other party. In addition, Agent, as a part of its
registration process with Company, shall provide the name, address, telephone, facsimile, and email address
Information for Agent's registered agent for service of process In Virginia and for appropriate Internal points of
contact to address operational, business coordination and customer account issues, to the extent those points of
contact are different than the above-named redplent of written notices and correspondence.
Section 14.
(a)
Miscellaneous Provisions,
This Agreement shall not be interpreted or construed to create an association, joint venture, or
partnership between the parties, or to Impose any partnership obligation or liability upon either
party. Neither party shall have any right, power, or authority to enter any agreement or
undertaking for, or on behalf of, or to act as or be an agent or representative of, or to otherwise
bind, the other party.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 320
COLUMBIA GAS OF VIRGINIA, INC.
AGGREGATION SERVICE AGREEMENT
(ASA)
(continued)
(b)
Cancellation, expiration or early termination of this Agreement shall not relieve the parties of
obligations that by their nature survive such cancellation, expiration or termination, including,
without limitation, payment of any amounts due, warranties, remedies, promises of indemnity
and confidentiality.
(c)
Should any provision of this Agreement be held Invalid or unenforceable, such provision shall
be invalid or unenforceable only to the extent of such invalidity or unenforceability without
invalidating or rendering unenforceable any other provision hereof, unless it materially changes
the Agreement of the parties.
(d)
Each of the parties hereto acknowledges that it has read this Agreement and agrees to be
bound by its terms.
IN WITNESS WHEREOF, the parties hereto executed this Agreement on the day and year first above
written.
ATIEST:
COLUMBIA GAS OF VIRGINIA, INC.
(Signature)
(Print)
ATIEST:
AGENT/ELIGIBLE CUSTOMER
(Signature)
(Signature)
(Print)
(Print)
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No.
PUE~2014-00020
~.
1
~--
.
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
Original Sheet Nos. 321 through 399 of this Tariff are reserved for future use.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
Accepted for Filing
Janaury 21, 2016
Division of-Energy Regulation-sec
..
~--
~
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 400
"=-- .•
Table of Contents for
General Terms and Conditions
Sheet No.
1. DEFINITIONS .................................................................................................................................................. 405
{
1.1
1.2
1.3
1.4
1.5
1.6
1.7
1.8
1.9
1.1 O
1.11
1.12
1.13
1.14
1.15
1.16
1.17
1.18
1.19
1.20
1.21
1.22
1.23
1.24
1.25
1.26
1.27
1.28
"Annual Transportation Quantity" ...................................................................................................... 405
"Authorized Daily Supply" .................................................................................................................. 405
"Authorized Partial Day Quantity" ...................................................................................................... 405
"Authorized Daily Quantity" ................................................................................................................ 405
"Authorized Monthly Quantity" ........................................................................................................... 405
"Btu" .................................................................................................................................................... 405
"Dekatherm" or "Dth" .......................................................................................................................... 405
"Dekatherm Multiplier" ....................................... :................................................................................ 405
"Billing Month" ..................................................................................................................................... 405
"Company" .......................................................................................................................................... 405
"Customer" .......................................................................................................................................... 405
"Customer Premises" ......................................................................................................................... 405
"Day" ............................................................................................................................:...................... 405
"High Pressure" .................................................................................................................................. 405
"Low Pressure" ................................................................................................................................... 406
"Maximum Daily Quantity" .................................................................................................................. 406
"Mcf" .................................................................................................................................................... 406
"Month" ............................................................................................................................................... 406
"Point of Delivery" ............................................................................................................................... 406
"Point(s) of receipt" .................................................. :.......................................................................... 406
"Daily Firm Quantity" .......................................................................................................................... 406
"Choice Program" .............................................................................................................................. 406
"Customer Group" ..............................................................................................................................406
"Competitive Service Provider (CSP)" ............................................................................................... 406
"Affiliated Competitive Service Provider'' ........................................................................................... 406
"Upstream Pipeline Scheduling Point" or "PSP" ................................................................................ 406
"Main" .................................................................................................................................................. 406
"Service Line" ......._............................................................................................................................... 406
2. MEASUREMENT ..................................................................................................;.......................................... 407
2.1
High
(a)
(b)
(c)
(d}
(e)
(f)
(g)
(h}
(I)
0)
(k)
(I)
J
~.
'
Pressure Accounts ..................................................................................................................... 407
Measurement Base ................. :................................................................................................ 407
Atmospheric Pressure .............................................................................................................. 407
Flowing Temperature ............................................................................................................... 407
Specific Gravity ........................................................................................................................ 407
Super Compressibility ..........................................................................................................__.. 407
Measuring Equlpment .............................................................................................................. 408
Calibration and Test of Meters ................................................................................................. 408
Correction of Metering Errors .................................................................................................. 408
Failure of Measuring Equipment. ............................................................................................. 409
Preservation of Records .......................................................................................................... 409
Delivery Pressure ..................................................................................................................... 409
Dekatherm Adjustment ............................................................................................................ 409
2.2
- Low Pressure Accounts ..................................................................................................................... 41 O
(a) The Quantity of Gas Determined by Meter Reading .............................................................. 410
(b) Dekatherm Adjustment ............................................................................................................ 410
(c)
Monitored Usage ...................................................................................................................... 410
(d) Meter Testing ........................................................................................................................... 411
2.3
Measuring Equipment ........................................................................................................................ 411
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE·2014·00020
Accepted for Fiiing
Janaury 21, 2016
i~
'-- ..
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 401
(continued}
Sheet No.
(a)
(b)
2.4
2.5
2.6
Location and Maintenance of Company's Equipment ............................................................ 411
Customer's Responsibility ........................................................................................................ 411
Piping and Appliances ........................................................................................................................ 412.
Access to Premises ............................................................................................................................ 412
Use of Gas by Customers .................................................................................................................. 412
3.
QUALITY..........................................................................................................................................................413
3.1
Gas ......................................................................................................................................................413
3.2
Heating Value of Gas Sold ................................................................................................................. 413
4.
POSSESSION OF GAS AND WARRANTY OF TITLE ................................................................................. 413
4.1
Cqntrol and Ownership of Gas Sold by Company ............................................................................ 413
4.2
Control and Ownership of Customer"Owned Gas ............................................................................ 413
4.3
Warranty ofTitle of Gas Purchased for Resale ................................................................................. 414
4.4
Warranty of Title of Customer"Owned Transportation Gas .............................................................. 414
I
I
!
I
5.
FORCE MAJEURE AND COMPANY LIABILITY.......................................................................................... 414
6.
TERMINATION OF SERVICE......................................................................................................................... 415
6.1
Termination of Service Without Notice .............................................................................................. 415
6.2
Termination of Service with Notice .................................................................................................... 416
6.3
Notice of Desire to Have Service Discontinued ................................................................................ 416
6.4
Reinstatement of Service ................................................................................................................... 417
6.5
Payment Due Upon Termination of Service ...................................................................................... 417
7.
AP.PLICATION, BILLING AND PAYMENT ................................................................................................... 417
7.1
Appllcation for Service ........................................................................................................................417
7.2
Customer Shall Satisfactorily Secure Account
(a) Security Deposits Applicable to Customers Taking Service Pursuant ~o Rate Schedules
RS, RTS, MPS, PDS, SGTS1/SGTS2/SGTS3, SGS1, ACS, ACTS, UGLS and UGLTS .... 418
(b) Security Deposits and other Financial Assurance Applicable to Customers Taking Service
Pursuant to Rate Schedules SGS2fSGS3, LGS1/LGS2, SS, TS1ffS2, BBS, LVfS, EDS,
DES, DPS and DGTS .............................................................................................................. 419
7.3
Billing and Payment. ........................................................................................................................... 420
(a) Billing ........................................................................................................................................420
(b) Payment .................................................................................................................................... 420
(c) Taxes ........................................................................................................................................421
,..
7.4
7.5
7.6
7.7
7.8
7 .9
7.10
8.
Late Payment Charge ................................. ,...................................................................................... 421
Adjustment of Biiiing Errors ................................................................................................................ 421
Calculation of Billing Adjustments ...................................................................................................... 421
Dishonored Payment .......................................................................................................................... 421
Refusal to Serve Proposed Customers ............................................................................................. 421
No Customer Shall Sell Gas to Another ............................................................................................ 422
Termination of Service on Disposal or Encumbrance of Property .................................................... 422
INSTALLATION OF DISTRIBUTION FACILITIES ........................................................................................ 422
8.1
Application ..........................................................................................................................................422
8.2
Installation Subject to Justlfication ..................................................................................................... 422
8.3
Individual Residential Applicants Not Requiring Main ...................................................................... 425
8.4
Entire Investment.. .............................................................................................................................. 425
Effective Date: February 1, 2016
Per August 21, 2015 Flnal Order in Case No. PUE-2014-00020
·\
I
I
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 402
Table of Contents for
General Terms and Conditions
(continued)
Sheet No.
8.5
8.6
8.7
8.8
8,9
New Demands on Existing Llne .................... :.................................................................................... 425
Special Service Connection ............................................................................................................... 425
CompanyWlll Own, Control Maintain ................................................................................................ 425
Relocations Other Than Master Meters ............................................................................................ 425
Relocations of Master Meters ............................................................................................................ 426
9. CHARGES AND PAYMENT FOR TEMPORARY SERVICE ........................................................................ 427
/
\
10. INTERUPTION AND CURTAILMENT OF SERVICE .................................................................................... 427
10.1
Definitions ...........................................................................................................................................427
(a) "Alternate Fuel Capacity (AFC)" .................................................................................................. 427
(b) "Boller Fuel" ................................................................................................................................. 427
(c) "Commercial Service" ..................................................................................................................427
(d) "Emergency" .............. :................................................................................................................. 427
(e) "Essential Human Needs: ........................................................................................................... 428
(f) "Essential Human Needs Emergency" ....................................................................................... 428
(g) "Human Needs Requirements" ................................................................................................... 428
(h) "Interruptible Service" .................................................................................................................. 428
(I) "Plant Protection" ......................................................................................................................... 428
U) "Residential Usage" ..................................................................................................................... 428
(k) "Electric Generating Start-up Requirements" ............................................................................. 428
(I) "Essential Electric Human Needs" .............................................................................................. 428
10.2.
10.3
10.4
10.5
Interruption of Non-Firm Services ...................................................................................................... 428
Curtailment of Firm Services ..................................................;........................................................... 429
Interruption or Curtailment due to Operational Necessity ................................................................. 430
Notices of Interruption or Curtailment ................................................................................................ 430
10.6
Penalty Provision for Takes in Excess of Authorized Quantities and Deliveries in Excess
of Authorized Supply When an Interruption or Curtailment has Been Invoked ......... :...................... 430
(a) Penalty for Takes in Excess of Authorized Daily Quantity ......................................................... 430
(b) Penalty for Takes in Excess of Authorized Partial Day Quantity ............................................... 431
(c) Penalty for Dellverles in Excess of Authorized Daily Supply ...................................................... 431
(d) Penalty Takes In Excess of Authorized Monthly Quantity .......................................................... 431
10.7
10.8
10.9
10.10
Disposition of Penaltles ...................................................................................................................... 432
Compensation for Deliveries During Curtailments ............................................................................ 432
Liability and lndemnity ........................................................................................................................ 432
Short~Term Extraordinary Relief From Curtailments ......................................................................... 433
11. ALTERNATIVE PRICE INDEX ....................................................................................................................... 433
12. RATE SCHEDULES RS, RTS, SGS1, SGS2, SGS3, SGTS1, SGTS2, SGTS3, MPS, PDS, UGLS, UGLTS
and ACTS - ADDITIONAL TERMS AND CONDITIONS ............................................................................ 433
12.1
Budget Payment Plan (BPP) ............................................................................................................. 433
(a) Budget Payment Plan Option ...................................................................................................... 433
(b) BPP General Provisions .............................................................................................................. 434
(c) Off-Season Equal Payment Plan ................................................................................................ 434
(d) Unusual Bill Extended Payment Plan .................................................................................. 435
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
FIRST REVISED SHEET NO. 403
SUPERSEDING
ORIGINAL SHEET NO. 403
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME N0.1
Table of Contents for
General Terms and Conditions
(continued)
Sheet No.
12.2
Weather Normalization Adjustment (WNA) ....................................................................................... 436
(a}(b) WNA General ........................................................................................................................... 436
(c) Definitions ...................................................................................................................................... 436
(d) Computation .................................................................................................................................. 437
12.3
Revenue Normalization Adjustment (RNA) ....................................................................................... 438
(a) (b) RNA Calculation ...................................................................................................................... 438
(c) WAMBR Calculation ..................................................................................................................... 439
(d) RNA Billing Factor (RNABF) Calculation ..................................................................................... 439
(e) RNA Billing .................................................................................................................................... 439
(f) Annual Allowed Distribution Revenue True-up (AADRT) ............................................................. 440
12.4
CARE Program Adjustment (CPA) .................................................................................................... 440
(a) (b) General .................................................................................................................................... 440
(c) Current Factor Calculation ........................................................................................................... 440
(d) Reconciliation Factor ................................................................................................................... 441
13. SERVICE VIA FARM TAPS ON HIGH PRESSURE INTERSTATE PIPELINES ........................................ 442
14. NEW SPACE HEATING SERVICE ................................................................................................................ 442
15. TRANSPORTATION SERVICE RATE SCHEDULES TS1/TS2 and LVTS -ADDITIONAL
TERMS AND CONDITIONS ........................................................................................................................... 442
15.1
Heat Content Adjustment ................................................................................................................... 442
(a) Heating Value of Gas .................................................................................................................... 443
(b) Sampling Under Certain Circumstances ...................................................................................... 443
15.2
Measurement of Point(s) of Receipt ............................................................................ ,..................... 444
15.3
Upstream Transportation Charges .................................................................................................... 444
15.4
Delivery Requirements ....................................................................................................................... 444
16. ORDER OF GAS THROUGH THE METER ................................................................................................... 444
17. PGA Terms and Conditions .......................................................................................................................... 445
17.1
BilUng Adjustment ............................................................................................................................... 445
(a) Application ................................................................................................................................... 445
{b) Definition of"Purchased Gas" ..................................................................................................... 445
17.2
Computation of Firm PGA .................................................................................................................. 445
(a) Base Cost- Firm Rate Schedules .............................................................................................. 445
(b) Base Cost - Combined Firm Sales Rate Schedules ................................................................. 446
(c) Calculation of Firm PGA- Sales ................................................................................................. 446
(d) Calculation of Firm PGA- Choice Program ............................................................................... 447
(e) Annual Roll-In .............................................................................................................................. 447
17.3
Computation of Interruptible PGA ...................................................................................................... 447
(a) Base Cost - Interruptible Rate Schedules .................................................................................. 447
(b) Calculation of Interruptible PGA. ................................................................................................. 447
(c) Annual Roll-In ............................................................................................................................. 448
Effective Date: September 28, 2016
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Division of Energy Regulation
Accepted for Filing
September 14, 2016
FIRST REVISED SHEET NO. 404
SUPERSEDING
ORIGINAL SHEET NO. 404
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
Table of Contents for
General Terms and Conditions
(continued)
Sheet No.
17.4
Computation of Banking and Balancing Service PGA ...................................................................... 449
(a) Base Cost- Rate Schedule BBS ............................................................................................... 449
(b) Calculation of the Non-Firm Banking and Balancing Service PGAs ........................................ 449
(c) Calculation of the Firm Banking and Balancing Service PGAs ................................................ 449
(d) Annual Roll-In ............................................................................................................................. 449
17.5
Actual Cost Adjustment ...................................................................................................................... 450
(a)(b) Calculation of ACA ................................................................................................................... 450
(c) Application to Next PGA .............................................................................................................. 451
17.6
Revenues From Off-System Sales and Capacity Release ............................................................... 452
(a) Definitions .................................................................................................................................... 452
(b) Operational Transactions ............................................................................................................ 453
(c) Retail Choice and Administrative Capacity Release Revenue .................................................. 453
(d) Off-System Sales and Capacity Release Incentive Mechanism ("Incentive Mechanism") ....... 453
17. 7
Refunds ............................................................................................................................................. 454
(a) Supplier Refunds Covered by Prior PGAs ................................................................................ 454
(b) Rounding .................................................................................................................................... 455
(c) lnterest ........................................................................................................................................ 455
(d) Annual Balances ......................................................................................................................... 455
17.8
Filfng ................................................................................................................................................... 455
(a) PGA ........................................................................................................................................ 455
(b) ACA ........................................................................................................................................ 455
17.9
17 .10
17.11
17.12
Details of Purchases ......................................................................................................................... .456
Cost Adjustments for Rate Schedule PDS ........................................................................................ 456
Transition Costs Recovery Mechanism .............................................................................................456
CARE Program Performance Incentive ("CPPl") .............................................................................457
18. SERVICE AGREEMENT GENERAL TERMS AND CONDITIONS .............................................................. 460
18.1
Form of Service Agreement ............................................................................................................... 460
18.2
Successors and Assigns .................................................................................................................... 460
18.3
Waiver of Default ................................................................................................................................ 460
18.4
Transfers Between Rate Schedules (excluding Rate Schedule LVTS) ........................................... 460
18.5
Operating Information and Estimates ................................................................................................ 461
19. OTHER SERVICE CHARGES ........................................................................................................................ 462
Type of Service ............................................................................................................................................ 462
20. INFRASTRUCTURE RELIABILITY AND REPLACEMENT ADJUSTMENT (IRRA) .................................. 463
21. MAKING ACCESS TO NATURAL GAS INFRASTUCTURE NOW (MAIN) RIDER .............................. 463
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
Accepted for Filing
Janaury 21, 2016
Division of Energy Reguiation-SCC
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 405
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
1.
DEFINITIONS
1.1
"Annual Transportation Quantity" sha[I mean the estimated consumption for the Customer for a 12
month period, as determined by the Company.
1.2
"Authorized Daily Supply" shall mean that quantity of gas which Customer is authorized to deliver
to the Company on a specified day when the Company has issued a BSR restricting a
transportation Customer's deliveries of natural gas.
1.3
"Authorized Partial Day Quantity" shall mean that portion of a Customer's Maximum Daily Quantity
of gas that a Customer is authorized to use during a specific period of time within a day when the
Company has completely or partially restricted its interruptlble services and/or initiated a curtailment
under the provisions of the tariff. The Authorized Partial Day Quantity shall represent the total amount
of gas Customer is authorized to use within the time period specified by the Company.
1.4
"Authorized Daily Quantity" sh.all mean that quantity of gas which Customer is authorized to use
. on a specified day when the Company has completely or partially restricted Its interruptible services
and/or initiated a curtailment under the provisions of this tariff.
1.5
"Authorized Monthly Quantity" shall mean that quantity of gas which Customer is authorized to
use during a specified month when the Company has initiated a curtailment under the provisions of
this tariff.
1.6
"Btu" shall mean one (1) British -thermal unit.
1.7
"Dekatherm" or "Dth" shall mean a unit of heat equivalent to 1,000,000 BTU's. The Company uses
Dths as the unit of measure for billing customers.
1.8
"Dekatherm Multiplier" shall mean a numeric multiplier that is applied to the volume of gas
consumed, measured In cubic feet, hundred cubic feet ("Ccf'1) or thousand cubic feet ("Mcf') to
determine the amount of energy consumed as measured in Dths
1.9
"Billing Month" shall mean the period elapsed between consecutive final monthly meter readings
and, when referred to in terms of a calendar month, shall mean that billing month the major portion of
which occurs in said calendar month.
1.10 "Company" shall mean Columbia Gas of Virginia, Inc.
1.11 "Customer" shall mean any corporation, municipality, governmental agency, person, group of
persons, or partnership to which the Company furnishes service. Service to each Individual
establishment, single-family residence, or separately metered apartment shall be treated as service to
an individual Customer. All applicants or co-applicants of a single family residence or separately
metered apartment shall be deemed the Customer.
1.12 "Customer's Premises" means a contiguous tract of real property owned or controlled by a
Customer, no part or parcel of which, at the time of the original service, is separated from the other by
publicly dedicated highways, streets or roads.
1.13 "Day" shall mean a period of twenty-four (24) consecutive hours, ending at 10:00 a.m. EST.
1.14 "High Pressure" shall mean service being furnished to a Customer at other than standard
distribution pressures.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE"2014--00020
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
c
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 406
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
{continued)
1.15 "Low Pressure" shall mean service being furnished to a Customer at standard distribution pressures.
1.16 "Maximum Dally Quantity" shall mean the greatest quantity of gas which the Company shall be
obligated to deliver to the Customer and which the Customer shall be entitled to receive from the
Company during any one day as specified In the Service Agreement.
1.17 "Mcf" shall mean one thousand (1,000) cubic feet of gas.
1.18 "Month" shall mean the period beginning at 10:00 a.m. EST. on the first "day" of the calendar month
and ending at the same hour on the first "day".of the next succeeding calendar month.
1.19 "Point of Delivery", unless otherwise agreed upon, shall be at the outlet of the Company owned
meter or, when pressure is reduced by the Company after metering, at the outlet side of the
Company's pressure regulator. Under unusual circumstances related to supply requirements or to the
topography of a Customer's premises, the Point of Delivery may be two or more metering locations
combined as to readings.
1.20 "Point(s) of Receipt" shall mean the point or points at which the Company has agreed to receive gas
delivered to it by the Customer, or others on behalf of the Customer, for transportation and delivery by
the Company to the Customer, as set forth In the Service Agreement.
c
"
~
1.21 "Daily Firm Quantity" shall mean the portion of a Customer's daily requirement the Customer has
chosen to purchase from, or have delivered by, the Company on a firm basis, set forth in the Service
Agreement.
1.22 "Choice Program" means gas transportation service provided under the Company's RTS, SGTS1,
SGTS2, SGTS3, UGLTS and ACTS rate schedules in combination with the Company's Rate
Schedule CSPS - Competitive Service Provider Service.
·
1.23 "Customer Group" means a group of residential customers or commerclal/\ndustrlal customers
served by a single CSP. The minimum size of this group is 100 customers or 10,000 Dth of annual
demand.
1.24 "Competitive Service Provider" (CSP) means a person that sells or offers to sell natural gas or a
related competitive energy service within the Commonwealth. This term includes affiliated
competitive service providers, as defined below, but does not include a party that supplies natural gas
exclusively for its own consumption or the consumption of one or more of Its affiliates.
1.25 "Affiliated Competitive Service Provider" means a competitive service provider that Is a separate
legal entity that controls, is controlled by, or is under common control of, a local distribution company
or its parent.
1.26 "Upstream Pipeline Scheduling Point" or "PSP" means (i) the single delivery polnt or set of delivery
points grouped or designated by an upstream pipeline for purposes of scheduling gas supplies for
delivery by such upstream pipeline; or (ii) the single delivery point or set of delivery points grouped or
designated by Company for operational purposes.
1.27 "M<)in" means a distribution line that serves as a common source of supply for more than one service
line.
1.28 "Service Line" means a distribution llne that transports gas from a common source of supply to a
customer meter or the connection to a customer's piping if there Is no customer meter.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 407
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
2. MEASUREMENT
2.1
High Pressure Accounts
(a)
Measurement Base
The volumetric measurement base shall be one (1) cubic foot of gas at a pressure base of
fourteen and seventy-three one hundredths (14.73) pounds per square inch, a temperature
base of sixty degrees (60°) Fahrenheit, and without adjustment for water vapor content.
(b)
Atmospheric Pressure
The average absolute atmospheric (barometric) pressure shall be assumed to be fourteen and
four"tenths (14.4) pounds to the square inch absolute, irrespective of actual elevation or
location of the delivery point above sea level or variations in actual barometric pressure from
time to time.
(c)
Flowing Temperature
The Company shall determine the temperature of the natural gas flowing through the meter or
meters by recorder, from established tables, or by use of temperature sensing elements used in
conjunction with electronic measuring devices.
{
(d)
Specific Gravity
The specific gravity of the natural. gas shall be determined by the Company, or at Customer
option by joint test, at the commencement of aeliverles hereunder and as often thereafter as
reasorably deemed necessary by either Company or Customer.
(e)
Super Compressibility
The deviation of the gas from the laws for ideal gases shall be determined by the Company, or
jointly at Customer's option, in one of the following ways:
(i) The deviation factors shall be computed by approved methods or read from standard
tables, in accordance with Report No. 3 of the Gas Measurement Committee of the
American Gas Association, as amended, expanded or tables superseded from time to time.
Such computations or selection of factors from tables will be based on the composition of
the gas and conditions at point of measurement, and the factors used will be checked by
tests of the gas made with such reasonable frequency as found necessary; or
(ii) The deviation factors shall be determined by tests of the gas made with such reasonable
frequency as found necessary.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE~2014·00020
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulalion-SCC
;:-:--
~
1'-·
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 408
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
(f)
Measuring Equipment
Unless otherwise agreed upon, the Company will own, install, maintain and operate measuring
stations equipped with displacement or flow meters and other necessary measuring equipment
to determine the volumes of gas delivered. The gas deltvered shall be measured in accordance
with the latest approved methods in use In the Industry generally. Displacement or turbine
meter readings shall be adjusted for pressure and temperature conditions. Customer may
install check-measuring equipment, provided such equipment is installed so as not to interfere
with the operations of the Company. The Company and Customer, In the presence of each
other, shall have access to the other's measuring equipment at all reasonable times, but, uni es;;
otherwise agreed upon, the reading, calibrating and adjustment thereof and the changing of
charts shall be done only by the owner thereof. Both the Company and Customer shall have
the right to be present at the time of any installing, reading, cleaning, changing, repairing,
inspecting, testing, calibrating or adjusting done In connection with the other's measuring
equipment. The records from such measuring equipment shall remain the property of their
owner, but, upon request, each will submit to the other its records and charts, together with
calculations therefrom, for inspection, subject to return within thirty (30) days after receipt
thereof. Customer shall exercise reasonable care in the installation, maintenance and
operation of its equipment so as to avoid any inaccuracy In the determination of the volume of
gas delivered.
·
(g)
Calibration and Test of Meters
The accuracy of all measuring equipment shall be verified by the owner at reasonable Intervals
and, if requested, in the presence of representatives of the other party. Neither the Company
nor Customer shall be required to vertfy the accuracy of such equipment more frequently than
once in any thirty (30) day period: If either party at any time desires a special test of any
measuring equipment, or if either party at any time observes an error in any such measuring
equipment, it will promptly notify the other party, and the parties shall then cooperate to secure
a prompt verification of the accuracy of such equipment.
(h)
Correction of Metering Errors
If, upon any test, any measuring equipment is found to be In error, such errors shall be taken
into account in a practical manner In computing the dellveries. If the resultant aggregate error
is not more than two percent (2%) fast, then previous deliveries corrected in such a manner
shall be considered accurate. If, however, the resultant aggregate error exceeds two percent
(2% ), previous recordings of such equipment shall be corrected to zero error for any period that
is known definitely or agreed upon, not to exceed a rebllling period of twelve (12) months. If the
period Is not known definitely or agreed upon, then such correction shall be for a period
extending over one half of the time elapsed since the last meter test, not to exceed a rebllling
period of twelve (12) months. All equfpment shall, In any case, be adjusted at the time of test to
record correctly.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order In Case No. PUE-2014-00020
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
/
I
\
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 409
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
(i)
Failure of Measuring Equipment
In the event any measuring equipment Is out of service, Is found registering inaccurately or
other measuring malfunction occurs and the error Is not determinable by test, previous
recordings or deliveries through such equipment, the amount of natural gas used by Customer
shall be estimated using the following methods:
(a)
By using the registration of any check meter or meters If installed and accurately
registering, or, in the absence of (a);
(b)
By correcting the error if the percentage of error is ascertainable by calibration, special
test or mathematical calculation, or, In the absence of both (a) and (b) then;
(c)
By estimating the quantity of delivery based on deliveries during periods under similar
conditions and any other relevant metering data, or,
(d)
By another method mutually agreed upon by the Customer and the Company.
The estimated readings so determined shall be used In determining the volume of gas delivered
for any known or agreed-upon applicable period, not to exceed a rebilling period of twelve (12)
months. In case the period is not known or agreed upon, such estimated deliveries shall be
used In determining the volume of gas de!Ivered hereunder during the latter half of the period
beginning on the date of the Immediately preceding test and ending on the date the measuring
equipment has been adjusted to record accurately, not to exceed a rebilling period of twelve
(12) months. The recordings of the measuring equipment during the first half of said period
shall be constdered accurate In computing deliveries.
l
'
Preservation of Records
Both the Company and Customer shall preserve for a period of at least three (3) years, or such
other longer period as may be required by public authority, all test data, charts and other similar
records.
(k}
Delivery Pressure
The delivery pressure of gas delivered hereunder shall be the varying pressures prevailing from
time to time in the lines from which the deliveries are made unless Customer and Company
mutually agree to some other delivery pressure which shall be specified in the Service
Agreement.
(I)
Dekatherm Adjustment
The Company shall apply a Dekatherm Multiplier to metered cubic foot usage to adjust for
heating value. This Dekatherm Multiplier shall be calculated monthly based on the most recent
reported heating value for the Pipeline Scheduling Point within the Company's service territory
In which the customer's meter(s) are located.
Effective Pate: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulatlon-SCC
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 410
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
2.2
Low Pressure Accounts
(a)
The Quantity of Gas Determined by Meter Reading
Except as otherwise indicated in an applicable schedule, the quantity of gas delivered
to each Customer shall be ascertained by a Customer or Company reading of the
meter furnished by the Company or by calculation. The Company's meters will be read
once each month. As to any Customer whose meter is unable to be read in a month,
the consumption for the month shall be determined by calculation on the basis of the
Customer's previous usage considering factors such as variations in weather, number
of days in the period and the trend In seasonal usage, in order to provide as nearly
accurate a blll as possible without actually reading the meter.
For a Customer that requests service to be discontinued pursuant to Section 6.3 or
initiation of service pursuant to Section 7, the final or Initial bill consumption may be
calculated or the Customer may elect to provide the Company with a meter reading
that Is subject to the Company's review. The Company shall provide Customers
requesting the discontinuance or Initiation of service with clear notice of their options to
have the final or initial consumption (1) calculated, (2) based on the Customer reading
the meter, or (3) based on the Company reading the meter. The Company will maintain
for twelve (12) months a record of the Customer's selected method used to determine
the final or initial bill consumption.
When the final or initial bill consumption is calculated, consumption shall be determined
on the basis of the Customer's previous usage considering factors such as variations In
weather, number of days in the period and the trend in seasonal usage In order to
provide as nearly accurate a bill as possible without actually reading the meter. Final or
initial bills will not be calculated when usage factors cannot be determined, in
circumstances under which usage has been established by fix factored measurement
by computer, meters were estimated for the previous billing cycle or accounts reflect
an insufficient billing history, or for gas transportation accounts, combined bill
accounts or premises where appliances have recently been red tagged.
(b)
Dekatherm Adjustment
The Company shall apply a Dekatherm Multiplier to metered cubic foot usage to adjust
for heating value. This Dekatherm Multiplier shall be calculated monthly based on the
most recent reported heating value for the Pipeline Scheduling Point within the
Company's service territory in which the customer's meter(s) are located
(c)
Monitertld Usage
The Company shall monitor each Customer's usage in order to detect unusual
deviations in individual Customer consumption. Prior to the billing of each account, the
Company will compare the Customer's current consumption with the prior year's usage.
Should an unusual deviation In the Customer's consumption be found, the Company
shall make a reasonable attempt to determine the reasons for the deviation. If the
cause of the deviation cannot be determined, a test of the Customer's meter shall be
made, and, if the meter registers more than two (2) percent fast, the utility shall
recalculate the Customer's bills and adjust the account on the basis of the test for a
period not exceeding twelve (12) months Immediately preceding the date of the meter
change.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGlNIA1 INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 411
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
(d)
Meter Testing
The Company shall make a free test of any meter upon written request of any
Customer provided such request Is not made more frequently than once each twentyfour months or the meter Is not scheduled for a periodic test. For subsequent tests
made at the Customer's request, the Customer shall advance the Special Meter Test
Charge set forth In Section 19 of the General Terms and Conditions to offset the cost of
the test. If such tests show the meter to be more than 2% fast, the Special Meter Test
Charge shall be refunded and adjustments made to the Customer's bill for a period
not exceeding twelve (12) months immediately preceding the date of the meter
change. If the meter Is found not to be more than 2% fast, the Special Meter Test
Charge shall be retained by the Company and previous meter readings shall be
deemed accurate for billing purposes.
2.3
Measuring Equipment
(a)
Location and Maintenance of Company's Equipment
The Company shall have the right to install any gas piping or other equipment as it
determines may be needed In connection with supplying gas at a convenient point or
points on the property or in the bullding(s) of the Customer.
The Customer shall provide suitable space for the installation of the necessary
metering apparatus, which space shall be accessible for reading, testing and servicing,
and protected from damage by the elements, negligence or deliberate acts of persons.
l
\..
Meters wlll normally be installed outdoors; however, when circumstances require,
meters may be Installed indoors, at the Company's discretion. When large meters are
necessary, the Company may require the Customer to furnish, at the Customer's own
expense, a suitable building to house the metering apparatus.
All equipment furnished and installed by the Company shall be and remain the property
of the company unless purchased from the Company.
(b)
Customer's Responsibility
The Customer shall be responsible at all times for the safekeeping of all Company
property installed on Customer's premises, and to that end shall give no one, except
the Company's authorized employees, access to such property.
The Customer shall be liable for the cost of repairs for damage done to Company's
property due to negligence. or misuse of it by the Customer or persons on the
Customer's Premises.
The Customer shalt be liable for all damages which may result from piping, appliances
or equipment of the Customer, whether or not purchased from or Installed by the
Company, from the use or misuse other than by the Company of the Company's
service or gas supplied by the Company or from the connection of the Company's
piping with the Customer's equipment.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order In Case No. PUE-2014-00020
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 412
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
2.4
Piping and Appliances
All piping, fixtures and appliances on the Customer's side of the meter or other Point of Delivery
shall b13 Installed and maintained under the sole responsibility and at th~ expense of the
Customer or owner of the Customer's Premises. Company shall have no responsibility or
liability for piping, fixtures, appliances or any other facilities on the Customer's side of the meter
or other Point of Delivery. In the event of a suspected gas leak in such piping, fixtures or
appliances, the Customer shall promptly notify the Company and the Company shall Investigate
said leakage report at no charge to the Customer. When the Company installs a common
metering location and underground piping to serve two or more buildings, the Company shall
maintain such lines to the Point of Delivery.
The piping, fixtures, and appliances for which the Customer is ·responsible shall be maintained
by the Customer In conform'ity with all State, Municipal or Federal requirements and with the
National Fuel Gas Code. The nature and conditions of this equipment shall be such as not to
endanger life or property, interfere with the service to other Customers or permit the passage of
gas without meter registration and it shall not be used for any illegal purpose. lf these
conditions are violated, the Company may refuse service or discontinue service without notice
until such violations are remedied by the Customer.
2.5
l\
2.6
Access to Premises
(a)
The authorized representatives of the Company shall be given access to the Premises
of the Customer at all reasonable hours for obtaining meter readings, for shutting off
the flow of gas for reasons herein prescribed, for inspection of piping and appliances,
and for inspecting, removing, repairing, or protecting from abuse or fraud any of the
property of the Company installed on the Premises. Access shall be granted at all
times for emergency purposes. The Company may refuse gas service or suspend it,
on refusal of legitimate access to the Premises or until any such damage, loss or other
conditions found shall have been settled to Its satisfaction.
(b)
If a Customer fails to keep an appointment for inspections or meter reading more than
one time during any calendar year, the Company may at Its discretion Install an
automated meter reading device, and charge the Customer therefore, including
charges pursuant to Section 19.
Use of Gas by Customers
The Customer agrees that no gas, other than that suitable for Its use and then available to It
through the facilities of the Company, shall be used in the operation of the Customer's
equipment without previous written notice to the Company.
The Service connections and metering apparatus supplied by the Company for each Customer
are definitely limited In capacity, and no additions to the equipment or load connected thereto
may be made except upon written notice to the Company.
The Customer shall install only such apparatus and appliances as are suitable for operation
with the character of gas supplied by the Company without undue disturbance of such supply,
and the gas must not be used by the Customer in such a manner as to cause objectionable
pressure fluctuations In the Company's general drstrlbution system.
Effective Date: February 1, 2016
Per August 21j 2015 Final Order in Case No. PUE-2014-00020
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
{
'<:
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 413
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
The Company reserves the right, but shall have no duty, to determine the suitability of
apparatus or appliances to be connected to Its system, and to determine whether the operation
of such apparatus or appliances will be detrimental to its general supply of gas. The Company
further reserves the right to refuse to supply gas or to discontinue service until such time as the
Customer conforms to Company regulations.
3.
QUALITY
3.1
Gas
The gas dellvered hereunder shall be a combustible gas consisting wholly of, or a mixture of:
3.2
(a)
Pipeline quality natural gas;
(b)
Gas generated by vaporization of Liquefied Natural Gas {LNG); or
(c)
Manufactured reformed or mixed gas consisting essentially of hydrocarbons of the
quality and character produced by nature in the petroleum, oil, and gas fields with
physical properties such that when the gases are commingled, they become
indistinguishable with respect to the physical properties of the mixture.
Heating Value of Gas Sold
The heating value of the natural gas sold by the Company shall be that shown on the
Company's monthly gas bills from its pipeline suppliers.
4.
POSSESSION OF GAS AND WARRANTY OF TITLE
4.1
Control and Ownership of Gas Sold by Company
(a)
As between Customer and Company, the Company shall be deemed to be the owner
and In control and possession of the natural gas sold by It pursuant to its sales rate
schedules until such gas Is physically delivered to Customer at the Point or Points of
Delivery. Customer shall be deemed to be the owner and in control and possession of
such gas thereafter.
(b)
Customer shall have no responsibility with respect to any natural gas purchased from
Company under Company's sales rate schedules until such gas is physically delivered
to Customer at the Point of Delivery, or on account of anything which may be done,
happen or arise with respect to said gas before such delivery; and the Company shall
have no responsibility with respect to said gas after such delivery to Customer, or on
account of Customer's gas transported by Company after such delivery.
\
4.2
Control and Ownership of Customer-Owned Gas
Customer shall be deemed to be the owner of all gas transported by Company on behalf of
Customer pursuant to Company's transportation service rate schedule(s). Company shall have
control and responsibility for such gas from the Point(s) of Receipt of such gas into Company's
distribution system until such gas is physically delivered to Customer at the Point(s) of Delivery.
Customer shall be deemed to be ln control and have responsibility for such gas before such
receipt by Company and after such delivery to Customer.
·
Effective Date: February 1, 2016
Per August 21 1 2015 Final Order in Case No. PUE-2014-00020
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulatio'n-SCC
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 414
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
It Is expressly understood and agreed that the Company assumes no obligation or liability
whatever for, or on account of, any condition on the Customer's Premises or for any defects or
suitability of Customer's piping, fixtures, fittings, or appliances, or for the inspection or repairs
thereof.
4.3
Warranty of Title of Gas Purchased for Resale
The Company agrees that it will, and it hereby does, warrant that it will at the time of physical
delivery to the Customer have good title to all gas which it has purchased for resale, free and
clear of all Hens, encumbrances and claims whatsoever, that it wlll at such time of delivery have
good right and title to sell said gas as aforesaid, that It will indemnify Customer and save it
harmless from all suits, actions, debits, accounts, damages, costs, losses and expenses arising
from or out of adverse claims of any or all persons to said gas.
'
4.4
Warranty of Title of Customer-Owned Transportation Gas
(a)
l·"
(b)
5.
Customer hereby warrants title to all gas to be delivered to the Company by Customer,
or others at Customer's direction, for transportation by the Company, and the right of
the Customer to deliver such gas, or to cause it to be delivered to the Company.
Customer warrants that all such gas Is owned by the Customer and is free from all liens
and adverse claims, Including but not limited to liens to secure payment of production
taxes, severance taxes and other taxes. Customer agrees to Indemnify the Company
and save the Company harmless from all suits, actions, debts, accounts, damages,
costs, losses and expenses arising from or out of adverse claims of any and all
persons to said gas or to royalties, taxes, license fees or charges thereon which are
applicable prior to delivery to the Company and after delivery by the Company to the
Customer to the gas being transported or which may be levied or assessed upon the
. delivery by the Customer, or others at the Customer's direction, to the Company or the
delivery by the Company to the Customer.
The Company warrants that it will have at the time of delivery to the Customer the right
to deliver the gas so transported and that it will indemnify and save the Customer
harmless from all suits, actions, debts, accounts, losses and expenses arising from or
out of adverse claims of any and all persons to said gas or to royalties, taxes, license
fees or charges thereon arising from the transportation of such gas by the Company for
the Customer and which are applicable after the receipt of such gas by the Company
and before the delivery thereof to the Customer.
FORCE MAJEURE AND COMPANY LIABILITY
Neither the Company nor Customer shall be liable in damages to the other for any act, omission .or
circumstance occasioned by or In consequence of any acts of God, strikes, lookouts and other labor
disputes, acts of the public enemy, wars, blockades, insurrections, riots, epidemics, landslides, lightning,
earthquakes, fires, storms, floods, washouts, arrests and restraints of rules and people, civil
disturbances, explosions, breakage or accident to machinery or lines of pipe, the binding order of any
court or governmental authority which has been resisted in good faith by all reasonable legal means,
and any other cause, whether of the kind herein enumerated or otherwise, not reasonably within the
control of the party claim Ing suspension and which by the exercise of due diligence such party Is unable
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
Accepted for Fillng
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
ORIGINAL SHEET NO. 415
SEVENTH REVISED VOLUME NO. 1
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
to prevent or overcome. Failure to prevent or settle any strike or strikes, including lockouts, shall not be
considered to be a matter within the control of the party claiming suspension and which by the exercise
of due diligence such party Is unable to prevent or overcome.
Such causes or contingencies affecting the performance hereunder by either the Company or
Customer, however, shall not relieve either of liability In the event of its concurring negligence or In the
event of its failure to use due diligence to remedy the situation and to remove the cause in an adequate
manner and with all reasonable dispatch, nor shall such causes or contingencies affecting such
performance relieve Customer from Its obligations to make payments of amounts then due hereunder.
The Company shall not be liable for any damages for failure to furnish a sufficient supply of gas or for
failure to distribute the Customer's gas to the Customer arising from any cause whatsoever beyond the
Company's reasonable control, or due to the Company's construction, operation or maintenance of its
facilities to the extent that such construction, operatlon or maintenance activities are performed in
compliance with general utility standards ..
6.
TERMINATION OF SERVICE
6.1
Termination of Service Without Notice
The Company reserves the right to terminate gas service to a Customer at any time without
notice, irrespective of any claim pending against the Company, upon the occurrence of any one
or more of the following events:
(a)
Whenever the Company, In its opinion, has reasonable cause to believe that the
Customer is receiving gas without paying therefore, or that its meter(s), pipes or other
apparatus have been tampered with ln any manner. In either of these events, the
Company shall have the right, In addition to Its other rights as provided In these Terms
and Conditions filed with the Commission, to require the Customer at the Customer's
own expense to have Installed piping in accordance with the Company's specifications
and subject to the Company's approval;
(b)
Whenever, in the Company's opinion, the condition of the Customer's piping,
equipment and appliances, is neither safe nor suitable for receiving gas, or, when the
Customer's use of gas or equipment Interferes with, or is detrimental to, the supply of
gas by the Company to any other Customer;
(c)
Where gas is being furnished over the Customer's private pipeline, or through a
pipeline, which Is not owned or leased by the Company, whenever In its opinion such
pipeline Is either in a not safe and suitable condition, or is Inadequate to receive gas;
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE·2014-00020
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 416
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
6.2
(d)
Whenever necessary to require compliance with an Interruption or curtailment request
pursuant to a Rate Schedule, Service Agreement, or the General Terms and
Conditions, or when the Company has reasonable cause to belleve that the continued
use of gas by a Customer, in excess of the· quantity authorized by the Company, may
prevent the Company from fulfilling its service obligation to essential human need
Customer requirements; or
(e)
In the event of physical harm, or a threat of physical harm, to the Company's
personnel, contractors, representatives or property.
Termination of Service with Notice
The Company reserves the right to terminate gas service to a Customer with at least ten ('\O)
days written notice from the Company to the Customer, irrespective of any claim pending
against the Company, upon the occurrence of any one of the following events:
,.
{a)
For non-payment of bills;
(b)
For failure to comply with any of the Company's Gas Tariffs as filed with the
Commission, or with any of the conditions or obligations of any agreement with the
Company for the purchase and/or transportation of natural gas or Its equivalent:
(c)
Whenever the Customer has unreasonably denied a· company representative access
to the Company's meter, pipes or other apparatus installed on the Customer's
premises; or
(d)
To prevent fraud upon the Company, including the initiation, by a Customer who has an
outstanding bad debt balance, of service in someone else's name ln order to avoid
previous arrearages; or
{
Notice of termination shall be considered to be given a Customer when a copy of such notice is
left with the Customer, or left at the Premises where the bill is rendered, or posted in the United
States mail, addressed to the Customer's last post office address shown on the records of the
Company. Company shall diligently attempt to induce Customer to make all payments owed or
to comply with all applicable terms and conditions of service prior to discontinuing service.
6.3
Notice of Desire to Have Service Discontinued
Every Rate Schedule RS, RTS, MPS, UGLS, UGLTS, PDS, SGS1 /SGS2/SGS3,
SGTS1/SGTS2/SGTS3, ACS, and ACTS Customer who is about to vacate any premises
supplied with service by the Company, or who for any reason wishes to have service
discontinued, shall give at least three (3) working days notice thereof to the Company
specifying the date on which It is desired that service be discontinued. Until the Company
receives such notice, the Customer shall be responsible for all service rendered.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order In Case No. PUE-2014-00020
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 417
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
6.4
Reinstatement of Service
(a)
When service Is discontinued for any of the foregoing reasons, the Company may
refuse service to Customer until:
(i)
(ii)
(ii!)
(Iv)
(v)
6.5
All unsafe conditions have been corrected to the Company's satisfaction;
All fraudulent activity has ceased;
AH delinquent bills have been paid or satisfactory credit arrangements have been
made;
Reasonable assurance has been provided by Customer that any failure to
comply with the terms and conditions of the Company's Tariff will not occur in the
future; and
Customer shall have paid any applicable reconnect charges set forth in the
applicable Rate Schedule and these General Terms and Conditions.
(b)
When service is terminated for any of the foregoing reasons stated in Sections 6.1 and
6.2 during the months of December· through March, the Company will, except for
circumstances beyond Company's reasonable control, reconnect service to a
Customer by the end of the next business day after the Customer contacts the
Company and requests reconnection provided Customer has satisfied the conditions of
6.4(a) and any other applicable provisions of these General Terms and Conditions.
(c)
When service is terminated for any of the foregoing reasons stated in Sections 6.1 and
6.2 during the months of April through November, the Company will, except for
circumstances beyond Company's reasonable control, reconnect service to a
Customer by the end of the third business day after the Customer contacts the
Company and requests reconnection provided Customer has satisfied the conditions of
6.4(a) and any other applicable provisions of these General Terms and Conditions.
Payment Due Upon Termination of Service
In the event that service to a Customer's Premises is terminated, either voluntarily or
involuntarily, all claims for gas service previously provided and any continuing obligations under
an applicable Rate Schedule or Service Agreement shall become immediately due and
payable.
7.
APPLICATION, BILLING AND PAYMENT
7.1
Application for Service
(a)
Applications for gas service shall be initiated through the Company's designated toll
free phone number or the Company's designated Internet based Website, unless
otherwise directed by a Company representative.
(b)
The Company may, prior to initiating gas service and at other reasonable times, require
. the applicant to:
·
(i)
establish that the applicant is the owner or bona fide lessee of the premises and
to require all owners or bona fide lessees to have the gas service In their names;
and
Effective Date: February 1, 2016
Per August 21, 2016 Final Order In Case No. PUE-2014-00020
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 418
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
(ii)
(c)
Whether or not the Company Initially requires the applicant to comply with the
provisions of Section 7.1 (b), above, the applicant, by accepting gas service agrees to:
(i)
(ii)
(d)
7.2
comply at any time with the requirements specified in Section 7.1(b) above; and
be bound by the applicable rate schedule(s) and the General Terms and
Conditions contained in this Tariff.
Should at any time the Customer not comply with this Section 7, gas service may be
discontinued in accordance with Section 6 of these General Terms and Conditions.
Customer Shall Satisfactorily Secure Account
(a)
(
execute an application for service or, if applicable, a Service Agreement.
Security Deposits Applicable to Customers Taking Service Pursuant to Rate
Schedules RS, RTS, MPS, PDS, SGTS1, SGTS2, SGTS3, SGS1, ACS, ACTS,
UGLS and UGLTS
Before receiving gas service, a Customer shall establish credit to the satisfaction of the
Company and shall discharge, either by payment or agreement, any prior indebtedness
to the Company for gas service. The Company may require the Customer to deposit
with it Initially and from time to time, as a guarantee of payment for gas service, such
amounts of cash as In the Company's judgment will secure it from loss, not to exceed
the equivalent of the Customer's estimated liability for two highest months' usage.
For Rate Schedules RTS, SGTS1, SGTS2, SGTS3, ACTS and UGLTS, the amount of
the deposit will exclude the customer's gas cost component of the estimated liablllty. In
addition, existing customers for which the Company is holding a deposit that choose a
CSP and elect service under Rate Schedules RTS, SGTS1, SGTS2, SGTS3, ACTS or
UGLTS will be refunded the amount of their deposit equal to the gas cost component of
the deposit.
The Company shall not be bound to supply gas until these conditions are fulfilled and it
may discontinue service if the guarantee or increased guarantee Is not provided when
required.
Simple Interest will be paid annually at the rate prescribed by the Commission. Interest
will be paid on deposits held longer than three (3) months but the Company wUI not be
llabll? for any interest on such deposits thirty (30) days after termination of gas service.
When service is terminated, any balance of the amount deposited, plus accrued
interest thereon remaintng after deduction of all sums due the Company, will be
returned to the Customer.
A residential Customer who has established a record of prompt payment for twelve (12)
consecutive months wlll be refunded their total deposit plus accrued Interest.
A residential Customer will be permitted to pay In three (3) consecutive equal monthly
installments whenever the deposit exceeds One Hundred Dollars ($100.00). Interest
on such installment deposits shall not begin to accrue until the final Installment
payment ls made to the Company.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order In Case No. PUE-2014-00020
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 419
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
The Company shall have a reasonable time to read and remove meters and to
ascertain that the obligations of the Customer have been fully performed before being
required to return any deposit.
(b)
Security Deposits and Other Financial Assurance Applicable to Customers
Taking Service Pursuant to Rate Schedules SGS2, SGS3, LGS1/LG52, SS,
T511TS2, BBS, LVTS, EDS, DES, DPS and DGTS
Before receiving gas service, a Customer shall discharge, either by payment or
agreement, any prior Indebtedness to the Company for gas service. In addition, a
Customer shall establish a level of credit acceptable to the Company based on
standard credit factors such as previous payment history, Dun & Bradstreet or other
financial and credit ratings, trade references, bank information, unused line(s} of credit,
and financial Information. The Company shall have sole discretion to determine, on a
non-discriminatory basis, the level of a Customer's creditworthiness based on the
above criteria but will not deny creditworthiness without reasonable cause.
Notwithstanding a Customer's initial establishment of creditworthiness, a Customer
must continue to maintain an acceptable level of creditworthiness. Accordingly, a
Customer's creditworthiness and the corresponding amount of financial assurance
required from the Customer may be periodically reviewed and updated by the
Company to take into account changes in the Customer's credit risk profile.
In the absence of an acceptable level of creditworthiness, the Company may require
the Customer to deposit with it inlttally and from time to time, as a guarantee of
payment for gas used and other charges that may accrue under the Customer's
applicable Rate Schedule(s), such amounts of casti as in the Company's judgment will
secure it from loss. Alternatively, a Customer may establish and maintain financial
assurance (separately or in combination with a security deposit) through a letter of
credit or other form of surety acceptable to the Company.
The amount of financial assurance, if any, to be provided by a Customer shall be that
amount which the Company determines is reasonably required to protect it from
adverse financial Impacts due to the Customer's nonperformance, taking into account
the level of risk otherwise Imposed on the Company. The consideration of the level
of risk imposed on the Company may Include, but not be limited to, the level and type
of services contracted for by the Customer pursuant to applicable Rate Schedules;
the quantity of gas supply to be transported, consumed and/or banked by the
Customer; the Customer's over~all creditworthiness; the Customer's past payment
history with the Company; and any costs for which the Company may be liable
should the Customer fall to pay for services rendered under applicable Rate
Schedules. However, in no event shall a security deposit required hereunder exceed
the equivalent of the Customer's estimated liability calculated on the basis of two
highest month's throughput. A Customer's security deposit and other surety shall be
available to the Company to satisfy any of the Customer's obligations under
applicable Rate Schedules.
I
\
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulatlon"SCC
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
FIFTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 420
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
Simple interest will be paid annually on security deposits at the rate prescribed by the
Commission. Interest will be paid on deposits held longer than three (3) months but
the Company will not be liable for any interest on such deposits thirty (30) days after
termination of gas service. When service Is terminated, any balance of the amount
deposited, plus accrued Interest thereon remaining after deduction of all sums due the
Company, will be returned to the Customer.
A Customer who has established a record of timely payment for twelve (12)
consecutive month.s will be refunded their security deposit plus accrued interest;
provided, that the Customer is maintaining an acceptable level of creditworthiness.
The Company shall have a reasonable time to read and remove meters and to
ascertain that the obligations of the Customer have been fully performed before being
required to return any deposit.
7.3
Billing and Payment
{a)
Billing
On or before the tenth (10th) day following the later of: (I) the date of the final monthly
meter reading for each billing month; and (ii) receipt of ver'ified nominations for
transportation customers, the Company shall render to Customer a statement of the
total amount of gas delivered during the preceding billing month and the amount due.
When information necessary for billing purposes is in the control of Customer,
Customer shall furnish such information to the Company on or before the fifth (5th) day
following the date of final meter reading of each month.
Both the Company and Customer shall have the right to examine, at reasonable times,
books, records and charts of the other to the extent necessary to verify the accuracy of
any statement, charge or computation made under or pursuant to any of the provisions
hereof.
(b)
Payment
Customer shall pay the Company at such addresses or authorized collection agencies
as the Company shall designate. All bills shall be due when rendered.
If presentation of a bill by the Company is delayed beyond the tenth (10th) day
following the later of the date of final monthly meter reading and receipt of verified
nominations for transportation customers, then the time of payment shall
correspondingly be extended unless Customer Is responsible for such delay.
Specific payment application instructions, including the designation of partial payments,
must accompany each individual bill subject to the specific payment application. The
instructions must be in writing and Include each individual account number or account
identification and the exact dollar amount to apply to each individual account and in the
case of a partial payment, the specified payment application. The Company reserves
the right, in the absence of specific instructions from the Customer to the contrary, to
apply any payment or payments made by the Customer to any amount due to the
Company by the Customer, except as prescribed by 20 VAC 5-312 90 with respect to
customers taking service under Rate Schedule RTS, SGTS1, SGTS2, 8GTS3, ACTS
or UGLTS.
f
The Company's address for receipt of payments and payment Instructions shall be
designated on the bill.
~.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
FIRST REVISED SHEET NO. 421
SUPERSEDING
ORIGINAL SHEET NO. 421
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
(c)
Truces
Bills rendered under all Rate Schedules shall be subject to any effective tax levied by
governing bodies. Any Customer who is exempt from such tax shall so notify the
Company by providing written notice explaining the basis for the exemption claimed.
7.4
Late Payment Charge
Should a Customer fail to pay the entire amount of any previous bill by the next billing date, a
late payment penalty charge on the unpaid portion of the bill shall accrue at the rate of one and
one-half percent (1.5%) per month. However, this provision shall not apply to that portion of
any bill reasonably disputed by the Customer under normal and customary payment
procedures. Late payment charges only apply to the Company's charges.
7.5
Adjustment of Billing Errors
If it shall be found that at any time or times Customer has been overcharged or undercharged
under the provisions hereof, for reasons other than measurement as set forth in Section 2 of the
General Terms and Conditions, such error shall be adjusted within thirty (30) days of the
determination thereof, provided that such adjustment shall not be required for: (i) billing errors
involving undercharges that are reported or discovered more than twelve (12) months from the
date of billing statement reflecting the error; or {ii) billing errors involving overcharges that are
reported or discovered more than thirty six (36) months from the date of the billing statement
reflecting the error, unless the Customer presents a copy of the billing statement. In such
instances in which a Customer presents a copy of the billing statement an adjustment shall not
be required for billing errors reported or discovered more than sixty (60) months from the date
of the billing statement reflecting the error. If the parties are unable to agree on the adjustment
of any claimed error, any resort by either of the parties to legal procedure, either at law, in
equity or otherwise, shall be commenced within fifteen (15) months after the date of the
erroneous billing statement, or shall thereafter be forever barred.
7.6
Calculation of Billing Adjustments
i. Adjustments to a Customer's bill due to billing errors, meter malfunction or otherwise
will be based on the applicable Company rate(s) in effect for the billing month(s)
being adjusted.
ii. If adjustments are necessary under Rate Schedules TS1/TS2, LVTS, RTS,
SGTS1/SGTS2/SGTS3, ACTS, UGLTS, AS or CSPS that require a credit or debit of
natural gas to the applicable Quantity Bank or Nomination Group, the Company will
not be responsible or liable for gas cost differences between current market rates
and the non-Company commodity rates in effect for the billing month(s) being
adjusted.
7.7
Dishonored Payment
Should the Company receive a negotiable instrument from an applicant for service or Customer
in payment for any bill, charge or deposit due, and such negotiable instrument be dishonored,
Company may treat the accounts as if no such payment was ever received by the Company. In
addition, the Company shall charge the applicant or Customer the Returned Check Charge set
forth in Section 19 of the General Terms and Conditions. The Company also reserves the right
to require all future payments be made in cash or by money order.
7.8
Refusal to Serve Proposed Customers
(a)
The Company may decline to serve a proposed Customer until the Customer has
complied with state and municipal laws and regulations governing gas service as well
as the terms and conditions of the Company's tariff.
Effective Date: September 28, 2016
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Division of Energy Regulation
Accepted for Filing
September 14, 2016
FIRST REVISED SHEET NO. 422
SUPERSEDING
ORIG,INl;\L,.S,HEE;T:~Prft2;f.JG
O!V!SIOf'J OF E:f~Ei~:cw REGULATION
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
7.9
STME CC31\POlMTION COMMISSION
MAR 2 l1 2016
(b)
Until adequate facilities can be provided, the Company may decline to serve a
Proposed Customer if, In the best judgment of the Company, It does not have adequate
facilities to render the service applied for, or if the desired service Is of a character that
is likely to affect unfavorably service to other Customers.
(o)
Compliance with the Company's rules, requirements and specifications governing the
installation and maintenance of gas service, piping, house piping, meter and regulator
settings, minimum insulation standards, and appliance venting on Customer's
Premises ls a condition precedent to the Company's obligation to serve any proposed
Customer hereunder.
No Customer Shall Sell to Another
The Customer shall not supply or sell gas delivered through the Company's meter for use In
any Premises not served by such meter according to the records of the Company covering
such meter installation.
Exceptions: (I) A Customer who provides compressed natural gas at retail for use as
a motor fuel In natural gas vehicles, and does not resell natural gas for any other
purpose, and (Ii) a Customer who subscribes to Rate Schedule DES shall be exempt
from the prohibition against resale contained in this Section.
7.10
Termination of Service on Disposal or Encumbrance of Property
In the event that Customer's Premises Is sold, transferred, assigned or exchanged, either
voluntarily or involuntarily, gas service may, at the option of the Company, be terminated at
which time all claims for gas seNlce previously provided and any continuing obligations under
an applicable Rate Schedule shall become immediately due and payable.
8.
INSTALLATION OF DISTRIBUTION FACILITIES
8.1
Application
The provisions of this section apply to applicants requesting new service, or to applicants with
existing service, for which a change in load or change in applicable rate schedule requires
modifications to or replacement of existing mains, service lines, meters and other distribution
facilities.
8.2
Installation Subject to Justification
a.
If construction of a main extension, service line and/or other distribution facilities is
required to serve an applicant or group of applicants, unless otherwise Indicated In
Section 8.2a(i)3 below, the anticipated revenue to be received from the proposed
service must justify the anticipated cost of the facilities as determined by the
economic test described below. Except to the extent provided for in Section 8.2a(i)3
below, the Company shall not be required to Install facilities, absent the applicant
paying a deposit and/or a non-refundable contribution, where the revenues from such
installation will not justify the anticipated cost of the facilities. The Company may
require the appllcant or group of applicants to pay a refundable deposit and/or nonrefundable contribution equal to the anticipated cost of constructing the main lines,
service lines, meters, regulators and other distribution facilities ("Plant Investment").
Effective Date: June 1, 2016
Per February 19, 2016 Final Order In Case No. PUE-2015-00056
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
SECOND REVISED SHEET NO. 423
SUPERSEDING
FIRST REVISED SHEET NO. 423
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
i.
Non-Refundable Contribution. The amount of the required non-refundable
contribution will be calculated in accordance with the following economic test:
1.
The cost of the facilities installed will be calculated as the present
value of the costs associated with installing the facilities, including:
the total Plant Investment, annual operation and maintenance
expenses, property taxes, income taxes, and an allowance for return
on the total Plant Investment. The service line, meter and regulator
installation cost is to be determined from either the previous year's
average cost for the applicable customer class or from a detailed
cost estimate based on current labor and material cost. Main line
cost is to be determined from a detailed cost estimate using current
labor and material costs. The present value will be determined by
discounting the costs using the Company's overall rate of return, as
determined in its most recent rate case, including the authorized
return on common equity.
2.
The anticipated revenues will be calculated using currently
authorized rates for the applicable Customer class, excluding the
purchased gas charge. The annual revenue will be discounted at the
Company's overall rate of return, as determined in its most recent
rate case, including the authorized return on common equity to
determine the revenue present value. Estimated consumption will be
determined for each class of Customer based on their respective
rates, anticipated usage levels and/or consumption patterns.
Anticipated usage levels are estimated ·using standard factors for
consumption on file with the Commission. The current usage factors
used in the calculation are as follows:
Heat load= specific heat factor x the square footage of the building.
Single Family New Construction Specific Heat Factor .......... 0.024
Multi-family New Construction Specific Heat Factor ............. 0.020
Conversion Specific Heat Factor ...................................... 0.026
Load credits for individual appliances beyond heat load are as follows:
Tank Water Heating ............................................ 21
Tankless/lnstantaneous Water Heating ................... 15
Cooking .............................................................. 4
Drying ................................................................ 3
Lights ............................................................... 13
Logs/Fireplace ................................................... 10
Grills ............................................................................... 2
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
DTH/Year
DTH/Year
DTH/Year
DTH/Year
DTH/Year
DTH/Year
DTH/Year
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for filing
September 27, 2016
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 424
SUPERSEDING
ORIGINAL SHEET NO. 424
/•, i/: .; i'1T c n:; )~ Fl LI r·~ G
CiVISION OF E.f'.JC:~iGY REGULATION
!) Tfo\TE CORPot~t\TION COMMISSIOM
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
3.
MAR 2 4 201(3
The difference between ( 1) and (2) above Is the "Net Present Value"
or "NPV".
(A). If the NPV is zero or positive, then no non-refundable contribution will
be required from Applicant and the application process can move
forward.
(B). If all the anticipated customers to be served from the expansion are
to be served under rate schedules RS, RTS, SGS-1, SGS-2, SGTS1, SGTS-2, ACS, or ACTS, ("SEP Rate Schedules") and the NPV Is
negatlve by an amount equal to or less than the product of $4,237
multiplied by the number of anticipated customers, then the applicant
may choose either (i) to pay a non-refundable contribution in an
amount necessary to achieve a zero ($0) NPV and enter an aid to
construction agreement with Company or (ii) have the expansion
pro!ect Included in Company's SEP making customers' premises
included In the project subject to the MAIN rider further described in
Section 21 of the General Terms and Conditions.
(C). If all the anticipated customers to be served from the expansion are to
be served by SEP Rate Schedules and the NPV Is negative by an
amount more than the product of $4,237 multiplied by the number of
anticipated customers, then the applicant may choose either (i) to
pay a .non-refundable contribution in an amount. necessary to
achieve a zero ($0) NVP and enter an aid to construction agreement
with Company or (ii) have the expansion included In Company's SEP
making customers' premises included in the project subject to the
MAIN rider further described in Section 21 of the General Terms and
Conditions and pay a non·refundable contribution In an amount when
combined with the product of $4,237 multiplied by the number of
anticipated customers will produce a zero ($0) NVP and enter an aid
to construction agreement with Company
(D). If the anticipated customers to be served from the expansion are not
to be served by SEP Rate Schedules and the NPV Is negative, then
a non-refundable contribution from Applicant will be required in an
amount necessary to achieve a zero ($0) NVP and Applicant shall
enter into an aid to construction agreement wlth Company.
(E). If only a portion of the anticipated customers to be served from the
expansion projects are to be served by SEP Rate Schedules and the
NPV is negative, then the portion of the cost of the facilities attributable
to the anticipated customers to be served by SEP Rate Schedules
shall be evaluated under subsection (1) and (2) and Applicant will be
afforded the applicable options under subsection (B) and (C) above
and the portion of cost of the facilltles attributable to the anticipated
customers to be served by other rate schedules shall be evaluated in
Effective Date: June 1, 2016
Per February 19, 2016 Flnal Order in Case No. PUE-2015-00056
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. ·1
>~
ORIGINAL SHEET NO. 424A
accordance subsection (1) and (2) and treated in accordance with
subsection D above.
::;- .-·.:) i·Ci{ FILING
DIVISION Oi~ EMERGY REGUL/.\Tlm-1
STATE CORPORJ.\TION COMMISSION (F). All options set forth in sections (A)-(D) above shall be subject to
Applicants deposit obligations described in subsection 8.2 (a) il below.
MAR 2 l1 2016
(G). Customers served off of expansion projects that have NPVs that are
zero or positive (after applying the payment of any non-refundable
contribution) may be sub/eat to the MAIN Rider if they benefit from
eligible system expansion infrastructure as described In Section 21 of
the General Terms and Conditions.
Ii.
Deposit Obligation
Deposit obligations can take the form of a
refundable deposit, delayed refundable deposit, performance obligation or
threshold use obligation. The amount of any deposit obligation will be equal
to the cost of the Initial Plant Investment, less the amount of the nonrefundable contribution determined in Section (i) above. The terms and
conditions of any deposit obligation will be specified In a line extension
agreement between the Company and the applicant. In the event a
refundable deposit is required, on an annual basis for a period of ten (10)
years from the date gas is made available, the Company will refund to the
depositor, or to his authorized agent, the following amaunt(s):
1. For each residential meter attached directly, or by service line, to that
portion of main installed pursuant to the signed !lne extension
agreement, an amount equal to the calculated refundable deposit divided
by the number of anticipated meters used to determine the deposit; and
2.
b.
For each commercial and/or industrial customer connected directly, or by
service line, to that portion of the main installed pursuant to the signed
line extension agreement, a calculated amount based on the actual
quantities of natural gas delivered each year to such commercial and/or
industrial customer(s) through said facilities, which amount shall be
further based on the then effective rates appllcable under such
commercial or industrial Customer's Rate Schedule.
Iii.
After ten (10) years from the date gas Is made available as set forth in an
executed line extension agreement, no refunds will be made. In no case
shall the total amount of the refund exceed the amount deposited with the
Company.
Iv.
The Company reserves the right to mal<e additional main extensions and/or
laterals off of the original main extension at any time, and shall not be
required to credit any deduction amount or make any refund to the applicant
on account of any Customers secured on such additional main extensions
and/or laterals.
All deposits made by the applicant will be adjusted for Income tax gross-up, unless the
Commission has otherwise approved appropriate recovery of this cost in the
Company's rates.
Effective Date: June 1, 2016
Per February 19, 2016 Final Order In Case No. PUE-20·15-00056
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 425
SUPERSEDING
ORIGINAL SHEET NO. 425
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
c.
8.3
Notwithstanding the provisions of Section 8.2 (a) and (b), the Company and applicant
may enter into some other mutually agreeable arrangement under which the proposed
facility can be justified or line extension costs satisfied by applicant.
Individual Residential Applicants Not Requiring Main
For individual residential applicants establishing or upgrading gas service that do not require
installing or upgrading mains, the Company will provide up to 150 feet of service line from the
existing main to Applicant's meter and related facilities without a charge, provided the Applicant
installs and uses the natural gas equipment listed in the service line agreement. Applicant will
be required to pay a non-refundable contribution for any cost associated with footage beyond
150 feet and/or any abnormal underground conditions or unusual permitting requirements. The
terms and conditions of the service line extension will be specified in a service line agreement.
A high pressure customer service regulator, if required, will not be provided without a charge for
any service line installed pursuant to this Section.
8.4
Entire Investment
The entire installation of the gas service line and connections from the main to the meter shall
be made by the Company, and any Customer accepting gas service under this Section 8 shall
be deemed to have granted the Company an easement across his Premises for such service.
This service line shall be of the size and type prescribed by the Company. No service line shall
be installed across private property other than the Premises of the structure to be supplied with
gas, except after special investigation and approval by the Company.
8.5
New Demands on Existing Line
Notwithstanding Section 8.2 above, when, in the opinion of the Company, an existing main,
service line and/or other distribution facilities are insufficient to supply new demand put upon
them and additional investment in facilities is required, the Company will install the facilities as
necessary and the cost to the Customer, if any, shall be as provided in Section 8.2.
8.6
Special Service Connection
When, at the request of a Customer, a special service connection or a service connection of
temporary character is made, the cost of the entire connection and removal of same, less the
salvage value of the returned material, will be charged to the Customer requesting same.
8.7
Company Will Own, Control and Maintain
The Company will own, control and maintain all service pipes, regulators, vents, meters, meter
connections, valves and other appurtenances from and including the main to the outlet side of
the meter regardless of any contributions to the cost thereof made by the Customer.
8.8
Relocations Other Than Master Meters
(a)
If a Customer requests relocation of existing service lines, meters, meter connections,
regulators, vents, valves, or other appurtenances, the Customer shall be responsible for
all costs involved in the relocation.
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 426
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
8.9
(b)
If the Company is required to relocate existing service lines, meters, meter connecNons,
regulators, vents, valves, or other appurtenances due to unsafe conditions or other
operational necessity, the customer shall be responsible for all costs Involved In the
relocation.
(c)
Customer shall indemnify the Company for al! claims, suits or actions for damages
against the Company resulting from a relocation.
Relocations of Master Meters
Upon the request of a Master Meter Operator, the Company may replace and subsequently
own and operate distribution facilities installed in place of a Master Meter Operator's natural
gas distribution facilities or, at the Company's sole discretion, otherwise acquire al! or a
portion of a Master Meter Operator's natural gas distribution facilities. A Master Meter
System replacement, or acquisition, will require the Master Meter Operator to consent to the
replacement pursuant to the terms of an executed line extension agreement.
(a)
"Master Meter System" shall be defined as a pipel!ne system for distributing gas within,
but not llmlted to, a definable area, such as a mobile home park, housing project, or
apartment complex, where the operator purchases metered gas from an outside
source for resale through a gas distribution pipeline system, The gas distribution
pipeline system supplies the ultimate consumer who either purchases the gas directly
through a meter or by other means, such as by rents. A Master Meter System, for
purposes of this Section, excludes Master Meter Systems serving nonwjurlsdlctional
federal, state or local government buildings such as federal military Installations, public
housing complexes, and the Washington Metropolitan Airport Authority.
(b)
The Company will generally prioritize higher risk Master Meter Systems (e.g. bare
steel, cast Iron, or other facilities identified through an Integrity management type of
review process) in soliciting and selecting investments among multiple Master Meter
Systems to be replaced (or acquired). The Company will review the Master Meter
prioritization annually with the Commission's Division of Utility and Railroad Safety in
an effort to reach a consensus on the replacement prioritization.
(c)
The relocation provisions of this Section apply only to Master Meter Systems that were
existing and operational on and before, and are relocated (or acquired) on and after,
April 30, 2014.
(d)
Following the completion of a Master Meter relocation (or acquisition) under this
Section, the Company w!ll own and operate the replaced (or acquired) natural gas
distribution facilities to the outlet of a Company meter to be located in close proximity
to the residential or commercial dwelling(s) to be served. The new location of
· metering facilities relocated under this Sectron shall be governed by Section 2.3 of the
Company's General Terms and Conditions.
(e)
Master Meter Relocations shall not be subject to the economic evaluation process and
deposit requirements of Section 8.2.
(f)
The costs of Master Meter Relocations Incurred by the Company under this Section
shall be recoverable through base non-gas rates. However, the Company shall not be
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No, PUE-2014-00020
Accepted for Flllng
Janaury 21, 2016
Division of Energy Regulat!on·SCC
COLUMBIA GAS OF' VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 427
obligated to spend more than $1,000,000 In any calendar year to replace (or acquire)
Master Meter Operators' piping and facilities located downstream of existing Master
Meters.
9.
(g)
The Company will Install the required mains, service lines, and metering and regulation
equipment only to accomplish the relocation. The Company will not be responsible for
costs to upgrade, repair, replace or otherwise modify piping or facilities located
downstream of the meter(s) or to upgrade, repair, replace or otherwise modify
appllances.
(h)
Except as specified hereafter, the Company shall not be responsible for the operation,
maintenance, repair or replacement of natural gas piping and faci!lt!es located
downstream of the outlet of the Company's Master Meter or, following replacement or
acquisition of a Master Meter System, downstream of the connection of the Company's
facilities to house piping. The Company will only be responsible for the operation,
maintenance, repair or replacement a Master Meter Operator's facilities downstream of
the outlet of the Company's Master Meter following the Company's execution of a
written agreement specifically defining the nature, extent and timing of such
responsibilities on and after the Company's acquisition of such Master Meter System,
which acquisition shall be within the Company's sole discretion.
CHARGES AND PAYMENT FOR TEMPORARY SERVICE
The Customer shall pay the cost for all material, labor and expenses incurred by the Company In
supplying gas service to the Customer for any temporary purpose or use, in addition to normal tariff
charges for gas used.
10.
INTERRUPTION AND CURTAILMENT OF' SERVICE
The Company recognizes Its primary public service obligation to maintain gas service to those
Customers for which it has a firm service obligation in all situations inclusive of an emergency. Of
highest priority are its service obllgat!ons to Customer requirements that qualify as firm, essential
human needs requirements.
10.1
Definitions
(a)
"Alternate Fuel.Capability (AFC}" shall mean that gas usage for which the Customer
has the installed storage and combustion facilities to use an alternate fuel, and that gas
usage of 10,000 Mcf or more per peak month for which it would be reasonable to install
facilities to use an alternate fuel. Propane shall be considered an alternate fuel only If it
is available and then only to the extent that volumes of propane were used prior to
September 29, 1976.
(b)
"Boiler Fuel" shall mean that usage of gas of 1,500 Mcf, or more, per peal< month for
the generation of electricity, production of steam, or heating of water.
(c)
"Commercial Service" shall mean service to Customers engaged primarily In the sale
of goods or services, to educational Institutions, to correctional institutions, and to
local, state and federal government agencies for uses other than those involving
manufacturing or electric power generation.
(d)
"Emergency" shall Include, but not be limited to, an unforeseen condition, occurrence,
or unplanned event resulting In a shortage of gas supplies, or an inability to deliver
Effective Date: February 1, 2016
Per August 21, 2015 Final Order In Case No. PUE-2014-00020
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulal!on-SCC
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 428
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
gas, such that Company's ablllty to serve Its Customers human needs requirements is
threatened.
(e)
"Essential Human Needs" shall mean that gas usage necessary to maintain service
to all residential Customers and Customers qualifying for human needs requirements
without AFC, subject to the following restrictions: (a) thermostats in residences,
apartments, sanatoriums, rest homes, hospitals, hotels, motels, prisons, and anywhere
else that people reside shall be set to 65° in the day and 55° at night, unless such
setting causes health hazards; and (b) thermostats in office buildings, retail stores,
schools, and other commercial, government and Industrial facilities shall be set to the
minimum level required to prevent Injury to life or property.
{f}
"Essential Human Needs Emergency" shall mean a situation In which gas supply, for
whatever reason, Is inadequate to meet requirements of Customers In Priorities 1 and 2
of Section 10.3, below.
(g)
"Human Needs Requirements" shall mean requirements for residences, critical for child
care and medical facilities, sanatoriums, rest homes, hotels, certain schools, critical
agriculture and food process needs, commercial cooking, prisons, plant protectton, water
and sewage treatment and electric generating unit start-up and flame stabilization.
(h)
"Interruptible Service" shall mean that service provided under interruptible Rate
Schedules or under special interruptible contracts.
(i)
"Plant Protection" shall mean that minimum use of gas necessary to prevent physical
damage to plant facilities, danger to plant personnel, and to protect material in
production. It shall not Include gas to maintain ongoing production of materials.
0)
"Residential Usage" shall mean that gas used for normal purposes in maintaining
permanent single and multi-family dwellings.
(k)
"Electric Generating Start-up Requirements" shall mean that usage of gas associated
with the start-up of base load generating units including requirements for flame
stabilization where alternate start-up fuels are unavailable. It shall not include gas used
for co-firing.
(I)
"Essential Electric Human Needs" shall mean that electric usage necessary to
maintain service to all residential Customers and Customers qualifying for human needs
requirements, subject to the following restrictions" (a) thermostats in residences,
apartments, sanatoriums, rest homes, hospitals, hotels, motels, prisons, and anywhere
else that people reside shall be set to 66° in the day and 55° at night, unless such setting
causes health hazards; and (b) thermostats In office buildings, retail stores, schools, and
other commercial, government and industrial facilities shall be set to the minimum level
required to prevent injury to llfe or property. Electric generation will be deemed to be
required for essential electric human needs if the electric utlllty has implemented
emergency load reduction procedures at least to the point of shedding non-critical
curtallable load.
§
'\
10.2
Interruption of Non-Firm Services
For any situation in which the supply available to the Company, or the Company's system
delivery capacity, ls not sufficient to simultaneously serve all non-firm Customer requirements
and maintain continuous, safe service to all firm Customer requirements, the Company shall
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
,.-
l-
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 429
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
have the right to partially or completely discontinue the provision of non-firm services. In
such event, the Company shall consider all non-firm services singularly, and as a group, in a
non-discriminatory manner to determine the order and extent of interruption necessary to
protect its firm service obligations.
The interruption of Customers pursuant to this Section shall be ordered as required by the
Company to properly recognize the applicable operating conditions for the affected operatlng
area(s), the expected duration of those operating conditions, the availability of gas and
required delivery capacity, and the required reduction In gas deliveries and services at the
time In conformity with the Company's public utility obligation.
10.3
Curtailment of Firm Services
If it is necessary, during an emergency or in the event of a situation as identified in Section
10.4, to further limit the provision of natural gas services jn order for the Company to maintain
service to higher priority Customers, the Company shall curtail or discontinue, In whole or in
part, firm gas services in the manner prescribed as follows:
PRIORlTIES FOR FIRM SERVICE
Priority 8-Requirements for boiler fuel.
Priority 7-Requirements of Customers with AFC that do not come under any other priority.
Priority 6-Customer requirements for human needs with AFC.
Priority 5-Electrlc generation requirements for essential electric human needs that do not have
available supplies of alternate fuels or alternate sources of electricity.
Priority 4-Customer requirements over 1,500 Mcf per peak month without AFC.
Priority 3-Non-Commercial: Customer requirements under 1,500 Mcf per peak month without
.
A~.
Prlorlty 2-Commercial: Customer requirements under 1,500 Mcf per peak month without AFC.
Priority 1-Customer requirements for residential service and requirements for human needs
without alternate fuel capability (AFC).
All Customer requirements within a priority class, or any sub-class thereof, which is subject to
curtailment, shall be curtailed on a comparable basis to the extent practicable for the period
of time specified by the Company. If a Customer's end-use requirements come under two or
more priorities, such requirements shall be treated separately when applying this schedule of
priorities. Trarisportation Customers will have equivalent end-use priorities as sales
Customers. However, In no event shall a transportation Customer be entitled to consume
natural gas quantities in excess of the Customer-owned quantities delivered to the Company
on their behalf on any day, plus any firm service quantities under contract with the Company.
Any remaining transportation Customer demand would not qualify for firm service under any
priority, Irrespective of actual end-use.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 430
SUPERSEDING
ORIGINAL SHEET NO. 430
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
10.4
Interruption or Curtailment Due to Operational Necessity
If, due to necessity to make modifications, tests, replacements, or repairs (excluding repairs
arising from the occurrence of a force majeure) to the Company's facilities or to the facilities of
the Company's supplier of gas, the gas available for delivery by the Company is insufficient to
meet all of the Company's expected requirements on any day, then the Company, upon
providing as much notice as reasonably practical under the circumstances, shall order
interruption and curtailment (if needed) by Customers pursuant to Sections 10.2 and 10.3, to
the extent required.
10.5
10.6
Notices of Interruption or Curtailment
(a)
Notices of curtailment or interruption will be given as much in advance as is
practicable. The Company will use reasonably appropriate means under the
circumstances to notify Customers, including phone, fax, email and/or public service
announcements. However, the provisions hereof for interruption or curtailment shall
in no way limit or restrict the Company from curtailing deliveries or interrupting
services as provided for in other provisions of this Tariff or a Service Agreement. In
providing a notice of interruption or curtailment, the Company will provide the affected
Customers the level of interruption or curtailment applicable at that time, which will
serve as the basis of their applicable Authorized Daily Quantity, Authorized Partial
Day Quantity or Authorized Monthly Quantity. In the case of curtailments, the notice
will include the level of curtailment for each priority applicable to such Customers.
(b)
Notwithstanding the foregoing, notices of BSRs, and the resulting Authorized Daily
Quantity and Authorized Daily Supply, shall be governed by the provisions of Rate
Schedule BBS or an otherwise applicable Service Agreement.
Penalty Provision for Takes in Excess of Authorized Quantities and Deliveries in
Excess of Authorized Supply When an Interruption or Curtailment Has Been Invoked
(a)
Penalty for Takes in Excess of Authorized Daily Quantity
For each day on which a Customer's actual consumption has exceeded its applicable
Authorized Daily Quantity, the Customer shall be assessed penalties and charges
computed as follows:
i.
Any penalty or charge incurred by the Company under the terms of its
contracts with supplier(s) or transporter(s) to the extent caused by the
Customer's failure to comply.
and
ii.
To the extent that the excess usage is consumed by a Customer taking
service under Rate Schedule BBS, TS1rfS2, LVTS or LGS1/LGS2, such
excess usage will be considered consumption of the Company's gas supply
and Customer will be charged for such consumption at 150% of the midpoint
Transco, zone 6 non-N.Y. city gate price as published in Gas Daily for that
day.
and
iii.
To the extent that the excess usage is consumed by a Customer taking
service under Rate Schedule TS1rfS2, LVTS, or LGS1/LGS2,
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
FIRST REVISED SHEET NO. 431
SUPERSEDING
ORIGINAL SHEET NO. 431
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
{continued)
during an interruption or curtailment described in Section 10.2 or 10.3, such
excess usage will be considered consumption of the Company's gas supply
and Customer will be charged $24/Dth in addition to the other charges
described in this section.
(b)
Penalty for Takes in Excess of Authorized Partial Day Quantity
For each day on which a Customer's actual consumption has exceeded its applicable
Authorized Partial Day Quantity, the Customer shall be assessed penalties and charges
computed as follows:
i.
Any penalty or charge incurred by the Company under the terms of its
contracts with supplier(s) or transporter(s) to the extent caused by the
Customer's failure to comply.
and
ii.
To the extent that the excess usage is consumed by a Customer taking
service under Rate Schedule BBS, TS1/TS2, LVTS, or LGS, such excess
usage will be considered consumption of the Company's gas supply and
Customer will be charged for such consumption at 150% of the midpoint
Transco, zone 6 non-N.Y. city gate price as published in Gas Daily for that
day.
and
iii.
(c)
To the extent that the excess usage is consumed by a Customer taking
service under Rate Schedule TS1/TS2, LVTS, or LGS1/LGS2, during an
interruption or curtailment described in Section 10.2 or ·10.3, such excess
usage will be considered consumption of the Company's gas supply and
Customer will be charged $24/Dth in addition to the other charges described
in this section.
Penalty for Deliveries in Excess of Authorized Daily Supply
For each day on which the actual deliveries of a Customer taking service under Rate
Schedule BBS, TS1/TS2 or LVTS exceeds its applicable Authorized Daily Supply, the
Customer shall be assessed penalties and charges computed as follows:
i.
Any penalty or charge incurred by the Company under the terms of its contracts
with supplier(s) or transporter(s) to the extent caused by the Customer's failure to
comply.
and
ii.
(d)
Such over-deliveries will be considered excess deliveries to the Company, and
Company will purchase such over-deliveries at 50% of the midpoint Transco,
zone 6 non-N.Y. city gate price as published in Gas Daily for that day.
Penalty Takes in Excess of Authorized Monthly Quantity
For each month in which a Customer's actual consumption has exceeded the
applicable Authorized Monthly Quantity, the Customer shall be assessed penalties and
charges computed as follows:
Effective Date: September 28, 2016
Interim, Subject to Refund
SCC Case No. PUE-2016-00333
Division of Energy Regulation
Accepted for Filing
September 14, 2016
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 432
SUPERSEDING
ORIGINAL SHEET NO. 432
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
i.
Any penalty or charge incurred by the Company under the terms of its contracts
with supplier(s) or transporter(s) to the extent caused by the Customer's failure to
comply;
and
ii.
10. 7
To the extent that the excess usage is consumed by a Customer taking service
under Rate Schedule TS1/TS2, LVTS or LGS1/LGS2, such excess usage will be
considered consumption of the Company's gas supply and Customer will be
charged for such consumption at 150% of the average of the midpoint Transco,
zone 6 non-N.Y. city gate prices as published in Gas Daily for the applicable
month.
Disposition of Penalties
The commodity based penalties and charges recovered as a consequence of the application of
Section 10.6, above, shall flow through the Company's PGA mechanism (including the Actual
Cost Adjustment).
10.8
10.9
Compensation for Deliveries during Curtailments
(a)
The Company may request that transportation Customers allow the use of their
Customer-owned gas to supply higher priority end-usages. Similarly, the Company
may request that Agents subscribing to Rate Schedule AS and CSPs subscribing to
Rate Schedule CSPS (collectively "Marketers") allow the use of their
Customer/Marketer-owned gas to supply higher priority end-usages.
Should
transportation Customers or Marketers refuse to allow the use of their gas during
emergencies and the ability of the Company to serve essential . human needs is
threatened, the Company may delay delivery of Customer/Marketer-owned gas and
utilize the gas to serve essential human needs when significant relief would be
provided by the use of such gas, until such time as the supply threat to essential
human needs has been resolved. The Company shall notify the Commission that it
has delayed transportation gas deliveries under this provision without the
Customer's/Marketer's agreement.
(b)
Transportation Customers/Marketers shall be compensated for the use of
transportation gas voluntarily supplied or otherwise used in an emergency to assist
the Company. The level of compensation shall be determined through negotiation
with the transportation Customer/Marketer. Such compensation shall be limited to (i)
the reasonable costs associated with alternate fuels, or (ii) the price difference
associated with resupplying gas to the Customer/Marketer. Compensation is not
intended to reflect damages, whether consequential or otherwise, that may result
from the use of Customer/Marketer-owned gas. Transportation Customers/Marketers
or the Company may request that the State Corporation Commission waive the
foregoing compensation limit for the purpose of negotiating contingency emergency
supply agreements. Any such agreement must be approved by the Commission
unless otherwise specified in this Tariff.
Liability and Indemnity
The Company shall not be liable for any loss, cost, damage, injury or expenses that may be
sustained by the Customer by reason of partial or complete curtailment, interruption or
Effective Date: September 28, 2016
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Division of Energy Regulation
Accepted for Filing
September 14, 2016
l
,-
\-
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 433
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
discontinuance of gas services. The Customer shall indemnify and hold the Company
harmless against any losses and costs with respect to any personal injury or damage to the
property of the Company or third parties, which result proximately from Customer's fa!lure to
comply with a requested Interruption or curtailment.
10.10
Short~Term
Extraordinary Relief from Curtailments
The Company has the authority, in its sole discretion, to grant extraordinary relief to any
Customer confronted with an emergency that requires immediate exemption from curtallment,
provided what no single exemption will exceed ten (10) days without prior approval of the State
Corporation Commission.
It shall be the responsibility of the Customer requesting such
extraordinary relief to provide the Company with all data necessary, In the Company's
Judgment, for the Company to determine if an undue hardship has been fully documented and
warrants relief from curtailment for any such period not exceeding ten (10) days.
11.
12.
ALTERNATIVE PRICE INDEX
(a)
In the event that the mid-point city gate price for deliveries that Is published In Gas Daily
under Transco, zone 6 non-N.Y., which is referenced throughout this tariff, is not published
for a particular day (e.g. on a weekend or holiday), the Company will utilize the last published
day's Index for that day.
(b)
In the event that the mid-point city gate price for deliveries that Is published in Gas Dally
under Transco, zone 6 non-N.Y., which Is referenced throughout this tariff, is no longer
published or ceases to exist, the Company wtll determine the most suitable substitute index
price and file an updated tariff with such substitute index price, within 30 days, with the SCC's
Division of Energy Regulation.
RATE SCHEDULES RS, RTS, SGS1, SGS2, SG53, SGTS1, SGT52, SGTS3, MPS, PDS, UG!-S,
UGLTS, ACS and ACTS ··ADDITIONAL TERMS AND CONDITIONS
12.1 Budget Payment Plan (BPP)
(a)
Budget Payment Plan Option
At the request of any residential Customer who uses gas as the primary source for space
heating, monthly budget payments for such Customer shall be made as follows:
t'
i{
Effective Date: February 1, 2016
Per August 21, 2015 Final Order In Case No. PUE-2014-00020.
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulatlon-SCC
COLUMBIA GAS OF VIRGINIA, INC
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 434
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
{continued)
(b)
(c}
(I)
Monthly budget payments shall be based on an amount equivalent to 1/12 of the
Customer's estimated annual bill and such payments shall commence with bills rendered
during the May billing cycle. A Customer applying for the Plan for the first time will be
accepted in any month and their payment will be determined by dividing their estimated
bill for the remainder of the budget period ending in April by the number of months
remaining in that budget period. Thereafter, mor.ithly payments wlll be In accordance with
this budget plan of payment.
(II)
The last levellzed payment under this budget plan will end with the March billing cycle.
Payment due for the April billing cycle will be for the difference between the amount
applicable to actual gas consumed during the twelve-month (or other applicable) period
and the amount actually paid during the eleven (or other applicable) months from ·May
through March of each year.
BPP General Provisions
(i)
The monthly budget payment, which shall be based on the estimated annual bill of the
Customer, shall not be construed by the Customer as a guaranty or assurance that the
total actual charges will not exceed such estimate. The Company may, at any time,
submit a revised estimate to the Customer whenever, In the Company's judgment, such
revision is deemed advisable.
(ii)
The billing under this budget plan of payment Is for the convenience of the Customer.
Bills will be rendered at the regular billing dates and will show the amount budget
Customers are to pay. The bill wHI also show the actual gas used and the amount
calculated at the applicable rate contained In the Company's Tariff. In addition, such bills
will show the balance of the Customer's account.
(ill)
If the Customer's budget account is In arrears, this budget plan may be canceled by the
Company and the Customer billed in accordance with the applicable Rate Schedule. In
the event of such cancellatlon, the account balance shall then become due. In the event
a Customer discontinues service and has a credit balance, such balance shall be
refunded.
Off-Season Equal Payment Plan
At the request of any residential Customer who uses gas as the primary source for space
heating, an equal payment plan can be made for any number of months between May and April
of each year.
A residential Customer applying will be accepted and payment amount will be determined as
follows:
(i)
Total gas consumption for the same months involved during the previous year will be
determined.
(Ii)
The total gas consumption determined will be adjusted to normal weather.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 435
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
(Ill)
The total gas consumption Is then divided into equal Dth over the remaining months in
the extended period.
(Iv)
The equal Dth is multiplied by the current rate in effect to obtain a monthly amount.
(v)
The equal monthly amount is multiplied by the total months in the extended payment
period to obtain the total amount due.
(vi)
Any remaining unpaid balance is added to the total amount due in the extended payment
to obtain the total amount due.
(vii)
The total amount due is then divided into equal payments over the remaining months in
the extended payment period. If such equal payment should not divide into even dollar
amounts, such equal payments are increased to the next even dollar amount.
(viii) At 'the end of the equal payment period, the customer's balance will be applied, debit or
credit, In calculating the monthly payment amount for the next equal payment plan period.
Alternatively, the customer may elect to receive a refund of any over payment or pay any
under payment.
•'
~
(d)
Unusual Bill Extended Payment Plan
At the request of any residential Customer who uses gas as the primary source for space
heating, an extended payment plan may be devised wherein the excess cost over .the normal
bill can be amortized over several payments. With this arrangement, a Customer Is permitted
to pay a part of the excess amount over varying periods in addition to the Customer's regular
monthly bill.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014·00020
I
Accepted for Fiiing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, ING.
GAS TARIFF
.
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 436
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
12.2
Weather Normalization Adjustment {WNA)
(a)
Effective with bills rendered for the first billing unit for December and continuing through the
last billing unit for April, weather normalized quantities shall be utilized to caloulat~. the non~
gas portion of the bills for all residential customers served under Rate Schedules RS, RTS,
MPS, and PDS, and commercial customers served under Rate Schedules
SGS1/SGS2/SGS3, SGTS1/SGTS2/SGTS3, MPS and POS, as well as any customers taking
service pursuant to Rate Schedule EDS that utilize the aforementioned Rate Schedules
(collectively "Applicable Customers").
(b)
Each commercial customer served under Rate Schedules SGS1/SGS2/SGS3,
SGTS1/SGTS2/SGTS3, MPS and PDS, as well as any customers taking service pursuant to
Rate Schedule EDS that utilize the aforementioned Rate Schedules that believes a
substantial portion of its usage is not weather sensitive, may request a statistical analysis to
determine if there is a reasonable and verifiable correlation between its Net Winter Usage
(NWU as defined below) and the concurrent degree days. In preparing the analysis, the
Company will regress the customer's NWU during the WNA periods for the most recent three
years with the actual degree days for the same period. If it is found that the customer's NWU
is not reasonably correlated with weather, the customer wll! be exempt from the WNA for a
minimum of three years. If it is determined that the customer's NWU is reasonably correlated
with weather, the WNA will continue to be applied. A customer who disputes the Company's
findings may request an informal review by the Staff of the Virginia State Corporation
Commission ("Commission) or a formal review by the Commission. ·
'
• @
\.
If the customer is deemed exempt from the WNA, after three years, the Company may again
analyze the customer's NWU to determine if the nature of the customer's usage has changed
and has become reasonably correlated with weather. If it is determined that the customer's
NWU is correlated with weather, the application of the WNA will be reinstated. Such analysis
may be initiated at the request of the customer or initiated by the Company without the
customer's request. A customer who disputes the Company's findings may request an
informal review by the Staff or a formal review by the Commission.
(o)
Definitions
(i)
Actual Heating Degree Days {AHDD) - The average hourly temperature for each day
subtracted from a reference temperature of 65 degrees, but not less ihan zero, for the
cumulative days of an Applicable Customer's designated billing unit.
(II)
Normal Heating Degree Days (NHDD) • the 30 year rolling average of the AHDD,
updated on a calendar year basis, corresponding to the period utilized fn Section
12.2{c)(i) for an Applicable Customer's designated billing unit. The initial 30 year rolling
average of the AHDD shall be for the 30 year period ending December 31, 2010 (WNA
applicable to meter readings on and after February 1, 2011).
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 437
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
:f
(iii)
Base Load Monthly Quantities (BLMQ) - the average daily consumption by an
Applicable Customer, measured in Dth, for the two months with the lowest consumption
per billing day from the period of the three immediately preceding summer months, of
July, August and September, updated annually, multiplied by the number of days In the
Applicable Customer's designated bllllng unit. If an Applicable Customer's BLMQ
cannot be determined in this manner, the Company will utilize the BLMQ for the
premfses or establishment or, if such BLMQ Is not available, the Company will utilize
the overall average base load quantity, measured In Dth, for the corresponding
customer class to determine the Applicable Customer's BLMQ until such time as the
BLMQ can be calculated using the Applicable Customer's consumption data.
(Iv)
Actual Monthly Quantities (AMQ) - the quantity of gas consumed by an Applicable
Customer during the designated billing unit utilized in Section 12.2(c}(i), measured In
Dth, as determined pursuant to Section 2 of the General Terms and Conditions.
(v)
Weather Normalized Billing Quantities (WNBQ) - the restated monthly Dth to be appfled
to the non-gas portion of bills referenced In Section 12.2(a), as computed for each
Applicable Customer using the formula set forth In Section 12.2(d) below.
(vi)
Net Winter Usage (NWU) - the AMQ less the BLMQ for the WNA application period.
(vii)
Weather Normalization Adjustment Quantity (WNAQ) - the quantity in Dth by which a
customer's bill will be adjusted to reflect normal weather.
:~
\
(d)
Computation
(I)
The WNBQ calculation will be performed individually for each Applicable Customer.
(Ii)
The WNBQ for the month of billing will be equal to the AMQ less BLMQ, times the ratio
of the NHDD divided by AHDD, plus the BLMQ, as stated in the following equation,
WNBQ"" [(Afv1Q- BLMQ) x (NHDD/AHDD)] + BLMQ
=WNBQ-AMQ
(iii)
WNAQ
(iv)
WNA = WNAQ multiplied by the weighted average quantity rate for the applicable rate
schedule.
(v)
The heating degree day calculations will be based on a weighted average of the
weather stations used for the Company's service territory.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in C<l:se No. PUE-2014-00020
FIRST REVISED SHEET NO. 438
SUPERSEDING
ORIGINAL SHEET NO. 438
COLUMBIA GAS OF VIRGI NIA
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
12.3
Revenue Normalization Adjustment (RNA)
(a)
(b)
The RNA will be calculated for each billing month separately for the residential,
small general service 1 and small general service 2 Customer Classes. For
purposes of the RNA, the Company's Residential Customer Class is defined as
all customers taking service under Rate Schedules RS and RTS. For purposes of
the RNA, the Company's Small General Service 1 Customer Class is defined as
all customers taking service under Rate Schedules SGS1, SGTS1 and
commercial and industrial customers taking service under Rate Schedule EDS.
For purposes of the RNA, the Company's Small General Service 2 Customer
Class is defined as all customers taking service under Rate Schedules SGS2,
SGTS2 and commercial and industrial customers taking service under Rate
Schedule EDS.
RNA Calculation
(i)
Base Monthly Normalized Non-Gas Revenue Per Bill (BMNR) - Utilizing
the monthly base non-gas revenue and number of bills corresponding to
the rates established by the Commission in the Company's most recent
rate case or performance based ratemaking proceeding in which its base
non-gas rates were increased, decreased or confirmed, and separately for
each applicable Customer Class, divide each applicable billing month's
weather normalized non-gas revenue by the corresponding number of bills
for that month. The resulting BMNR's are in the table below:
Residential
BMNR
Month
January
February
March
April
May
June
July
August
September
October
November
December
Annual Allowed
Distribution
Revenue
Rate Schedules
RS and RTS
$85.35
$84.15
$71.68
$49.50
$32.16
$25.47
$23.89
$23.19
$23.32
$26.91
$38.63
$61.67
Small General
Service
BMNR
Rate Schedules
SGS1, SGTS1 and
$96.68
$102.76
$95.40
$54.64
$34.12
$29.27
$28.65
$28.51
$28.77
$30.75
$38.41
$61.51
Small General
Service
BMNR
Rate Schedules
SGS2, SGTS2 and
EDS
$196.69
$200.32
$182.41
$117.16
$76.68
$61.09
$64.50
$62.33
$59.21
$66.58
$88.82
$133.33
$629.47
$1,309.12
EDS
$545.92
(ii) Authorized Monthly Normalized Non-Gas
Revenue (AMNR) - The
AMNR is calculated by multiplying the applicable billing month's BMNR
from the table in Section 12.3(b){i) by the actual number of bills for that
billing month, separately for the Residential, Small General SeNice 1 and
Small General Service 2 Customer Classes.
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing October 17, 2016
Accepted for Filfng
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 439
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
(c)
(iii)
Weather Adjusted Monthly Booked Revenues (WAMBR) -The WAMBR
is the applicable billing month's non-gas revenue recorded on the books of
the Company adjusted to remove the effects of colder or warmer than
normal weather pursuant to Section 12.3(c) and excluding the revenue
resulting from the billing of the RNABF pursuant to Section 12.3(e), which
shall be calculated separately for the Residential, Small General Service 1
and Small General Service 2 Customer Classes.
(iv)
Revenue Normalization Adjustment (RNA) - The RNA will be equal to
the difference of the AMNR minus the WAMBR for the applicable billing
month, which shall be calculated separately for the Residential, Small
General Service 1 and ·small General Service 2 Customer Classes.
WAMBR Calculation - For each rate schedule subject to the RNA pursuant to
Section 12.3(a), the WAMBR will be equal to the applicable billing month's non-gas
revenue recorded on the books of the Company which includes the sum of the WNA
revenues calculated for each applicable customer pursuant to Section 12.2(d)(iv).
(d)
RNA Billing Factor (RNABF) Calculation
The RNABF for the Residential, Small General Service 1 and Small General Service
2 Customer Classes, calculated separately, will be equal to the amount derived in
12.3(b)(\v) plus or minus any prior months' under or over applied RNA, divided by the
estimated normalized quantity of sales and retail choice service for the third
succeeding billing month following the billing month's RNA. For example, each
Customer Class' RNA for the January billing month will be divided by that Customer
Class' estimated quantities for the April billing month to determine the applicable
RNABF.
(e)
RNA Billing
The RNABF determined In 12.3(d) for the Residential, Small General Service 1 and
Small General Service 2 Customer Classes will be applied to the bills for each
applicable Customer Class beginning with the first billing unit for the third succeeding
billing month following the billing Month's RNA. For example, the Residential
Customer Class' RNA for the January billing month would be billed beginning with the
first billing unit for the April billing month.
Effective Date: February 1 j 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
COLUMBIA GAS OF VIRGINIA
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 440
SUPERSEDING
ORIGINAL SHEET NO. 440
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
(f)
Annual Allowed Distribution Revenue True-up (AADRT)
(i)
At the end of each calendar year, for each applicable Customer Class, the average
number of customers will be computed by dividing the year's total bills by twelve.
(ii)
The Annual Allowed Distribution Revenue (AADR) for each applicable Customer
Class will be computed by multiplying the average number of customers computed
in Section 12.3(f)(i) above by the sum of the BMNR for the year.
(iii)
The MORT for each applicable Customer Class will be equal to the difference in
the sum of the monthly AMNR's computed in Section 12.3(b)(ii) for the year and
subtracted from the MOR computed in Section 12.3(f)(ii).
(iv)
The MORT will be included with the RNABF calculation pursuant to Section
12.3(d) for December of each year and billed to each applicable Customer Class
pursuant to Section 12.3(e) above.
12.4 CARE Program Adjustment (CPA)
(a)
Customer bills applicable to the Residential and Small General Service Rate Schedules
identified in Section 12.3(a) shall include an adjustment providing for the recovery of
costs associated with conservation and energy efficiency programs approved by the
Commission. A CPA will be determined separately for the Residential and Small General
Service Customer Classes, with the Small General Service 1 and Small General Service
2 Customer Classes having the same CPA factor.
{b)
The CPA will be comprised of a Current Factor to be effective during the billing months of
January through December of each year, commencing with the first billing unit for
January 2010, and a Reconciling Factor to be effective during the billing months of
January through December of each year, commencing with the first billing unit for
January 2011.
(c)
Current Factor Calculation
(i)
The Current Factor for the 12 month period beginning January of each year shall
consist of a program level factor and a portfolio level factor, defined below. The
current factor shall be determined separately for the Residential and Small General
Service Customer Classes by adding the program level factor for each Customer
Class to the portfolio level factor applicable to all Customer Classes.
Program Level Factor - The program level factor shall be determined
separately for the Residential and Small General Service Customer Classes by
dividing the total projected program level costs for the upcoming 12 month
period beginning January of each year of conservation and energy efficiency
programs approved by the Commission and attributable to such Customer
Class by the applicable estimated 12 month normalized quantity of sales and
retail choice service.
Portfolio Level Factor - The portfolio level factor shall be the same factor for all
applicable Customer Classes and shall be determined by dividing the total
projected portfolio level administrative costs for the upcoming 12 month period
beginning January of each year of conservation and energy efficiency
programs approved by the Commission by the applicable estimated 12 month
normalized quantity of sales and retail choice service.
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
.
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 441
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
{continued)
(Ii)
Projected costs of conservation and energy efficiency programs shall include utility
expenditures, Incentive payments to customers, and those costs not elsewhere
recovered In base non-gas rates Including, but not limited to, Incremental Company
labor and related expenses, consultant fees and expenses, vendor fees and
expenses, and office supplies and expenses Incurred in the implementation and
operatio,n of the such conservation and energy efficiency programs.
(Ill)
Costs w,ill be attributable to each applicable Customer Class as follows:
1.
Costs directly attributable to a specific cortservation or energy efficiency
program w!ll be directly assigned to the Customer Class to which such
program applies. Costs, other than administrative costs, that are not directly
attributable to a specific conservation or energy efficiency program will be
allocated to each Customer Class using the projected usage for each
applicable Customer Class. These costs will be considered program level
costs.
2.
Administrative costs not directly attributable to a specific conservation or
energy efficiency program will be considered portfolio level costs.
(d) Reconciliation Factor
(i)
The Reconciliation Factor for each Customer Class will be equal to the difference
between the actual costs of conservation and energy efficiency programs
approved by the Commission, as described In Section 12.4(c)(iii), for the 12
month period ended October of each year, and the CPA collections from
customers within such Customer Class for the 12 month period ended October of
each year, plus or minus any under or over applied Reconciliation Factor from
the previous year, attributable to such Customer Class. The actual costs used
for the calculation of the Reconciliation Factor for each applicable Customer
Class will consist of the program level costs specific to each Customer Class plus
a portion of the portfolio level costs, which will be allocated to the Residential and
Small General Service Customer Classes based on actual quantities for the 12
month period ended October of each year. The costs of conservation and energy
efficiency programs shall include interest as computed in Section 12.4(d)(li), for
the twelve month period ended October. The over/under collection derived
above will be collected from or credited to customers within the corresponding
Customer Class over a twelve month period commencing in the next succeeding
January billing month utilizing estimated normalized twelve month sales and
retail choice quantities for the applicable Customer Class.
(ii)
The Company shall compute interest (income or expense) by applicable
Customer Class on that portion of the actual collections from customers that
dlffers from the actual conservation or energy efficiency program costs. Interest
will be calculated based on the monthly average over/under collected balance,
for the 12 month period ended October, utilizing the Company's short~term
borrowing interest rate.
(Ill)
Notwithstanding the foregoing provfsions of 12.4(d)(i) and (ii), the initial
Reconciliation Factor shall be calculated based on the actual period of costs and
collections rather than a 12 month period.
Effective Date: February 1, 2016
Per August 2.1. 2015 Final Order in Case No. PUE-2014-00020
c.
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 442
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
13.
SERVICE VIA FARM TAPS ON HIGH PRESSURE INTERSTATE PIPELINES
Where the service line and related facilities of a Customer taking service under Rate Schedule RS,
RTS, SGS1, SGS2, SGS3, SGTS1, SGTS2, SGTS3, ACS, ACTS, UGLS or UGLTS are
interconnected directly to a high-pressure Interstate pipeline, the Company's obligation to serve such
Customer is contingent upon the Interstate pipeline making gas service available to Company to serve
such Customer. The Company makes no warranty, express or Implied, as to either the length of time
such natural gas service will be available, or its availability at any specific point in time.
14.
NEW SPACE HEATING SERVICE
In order to safeguard continued good service to its present Customers, to enable It to attach new space
heating loads in an orderly manner, and to enable it properly to anticipate and plan for future
requirements of !ts Customers, the following additional terms and conditions shall apply to the sale of
gas for space heating:
15.
(a)
The obligation of the Company to supply gas for space heating to any Customer shall be
conditioned upon the filing by the Customer of a written application and the issuance by the
Company of a written approval;
(b)
The obligation of the Company to Issue written approval to a proposed Customer for gas for
space heating purposes shall be conditioned upon the existence of Customer facilities
adequate to carry the load Involved;
(c)
The obligation of the Company to supply gas under an approval shall be conditioned upon the
installation of the space heating equipment within a reasonable time after the issuance of the
written approval; and
(d)
The obligation of the Company to supply gas for space heating In commercial and industrial
classifications in excess of 1,000,000 Btu per hour input shall be conditioned, when such is
necessary In the discretion of the Company io protect service to other classes of Customers,
upon the installation by the Customer of standby equipment and its undertaking to use such
equipment when so requested by the Company.
TRANSPORTATION SERVICE RATE SCHEDULES TS1/TS2 and LVTS " ADDITIONAL TERMS
AND CONDITIONS
15.1
Heat Content Adjustment
When Company receives Customer's gas from an interstate pipeline on a dekatherm {one
million Btu) basis, for redelivery to Customer's facilities on an Mcf basis, Company will make a
heat content adjustment:
Effective Date: February 1, 2016
Per August 21, 2015 Final Order In Case No. PUE~2014·00020
/..--
'\,
...
Accepted for Fiiing
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 443
GENERAL TERMS AND CONDlTIONS
ALL RATE SCHEDULES
(continued)
(a)
Heating Value of Gas
The heating value assigned to Customer's gas by the pipeline delivering such gas to
the Company, as reported monthly by such pipeline to the Company, will be used each
billing month to establish the heating value of the gas delivered by Company to
Customer.
(b)
Sampling under Certain Circumstances
·If locally produced gas or gas from pipelines other than the pipeline directly delivering
Customer's gas to Company is introduced Into Company's pipeline serving Customer's
facilities so as to raise a question as to the applicabillty of the heating value determined
by the delivering pipeline, either Company or Customer may request that gas samples
. be taken to determine the heating value of the gas received by Customer at its
facilities. The following provisions will apply ln the event either party elects to have gas
samples taken:
(I)
The party requesting the sample(s) will pay all costs connected with obtaining
the sample(s) and having the sample(s) analyzed.
(ii)
The gas sample(s) shall be obtained at or in the vicinity of Customer's facilities
during normal operating hours of the facilities.
(iii)
The gas sample(s) will be analyzed at a Company testtng facility or at a testing
facility approved by the Company.
(Iv)
If the analysis is done by an outside testing facility, the testing facility will
forward the results directly to Company and Customer, using a format provided
by Company for recording the results of the analysis. If Company performs the
analysis, the Company testing facility will forward the results directly to
Customer.
(v)
Multiple samples taken during any billing month will be averaged to obtain a
Btu value; that Btu value will be applied only for that particular billing month.
No retroactive adjustments based on Btu readings w!!I be made to billings for
any prior month.
(vi)
The average Btu value obtained from sample(s) during any bllling month shall
be used to determine the quantities delivered by Company to Customer only If
such Btu value Is more than 103% or less than 97% of the delivering pipeline's
Btu value, without adjustment for water vapor content value, provided by the
delivering pipeline for that month. Otherwise, the delivering pipeline's Btu
value will be used.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE·2014·00020
x
~-
Accepted for Ffllng
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 444
-
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
15.2
Measurement at Polnt(s) of Receipt
When Company receives Customer's gas at Polnt(s) of Receipt from an interstate pipeline, all
measurement shall be performed in accordance with the terms of Company's agreement with
that interstate pipeline and shall be conclusive for purposes of all transportation agreements
between Company and Customer.
15.3
Upstream Transportation Charges
If transportation service is provided by another entity to transport Customer's gas, any cost
incurred by or billed to, Company with regard thereto, shall be billed to Customer by Company
and paid by Customer. Such costs may include, but are not limited to, transportation or delivery
charges, gas quantities retained for company use and unaccounted-for gas, filing fees, and
penalties Incurred as a result of gas quantity Imbalances or other factors set forth in the
applicable rate schedule(s) of such other transporting entity. Customer shall also reimburse
Company for any filing fees paid by Company to an entity other than those considered above
when necessary to commence or continue gas transportation service to Customer. Company
. will receive Customer's approval before taking any action that results in either the initiation of
said transportation service or the incurrence of said filing fees.
15.4
Delivery Requirements
All Customers, Agents and Marketers delivering gas supplies to a facility being served under
Rate Schedules TS1/TS2, BBS or LVTS must deliver gas to the PSP behind which that facility
is located.
16.
ORDER OF GAS THROUGH THE METER
Gas flowing through a Customer's meter shall be accounted for on a daily basis In the following
sequential manner:
(a)
Gas not owned by the Company being delivered to the Company for transportation and delivery
to the Customer shall be the first gas through the meter for such day,
(b)
Company authorized deliveries from a Customer's Quantity Bank.
(c)
Customer contracted firm sales or Standby Service.
(d)
Company authorized interruptible sales service quantities.
(e)
Quantities not authorized by the Company.
(
\
Effective Date: February 1, 2016
Per August 21, 201 Final Order In Case No. PUE-2014·00020
a
FIRST REVISED SHEET NO. 445
SUPERSEDING
ORIGINAL SHEET NO. 445
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
17.
NOV 21 2016
PGA TERMS AND CONDITIONS
17.1
ACCEPTED FOR FILING
DIVISION OF ENERGY REGULATION
STATE CORPORATION COMMISSION
Billing Adjustment
(a)
Application
The rates for all gas sales services and Rate Schedules RTS, SGTS1, SGTS2, SGTS3,
UGLTS, ACTS and BBS, other than Optional Alternate Fuel Displacement sales under Rate
Schedule LGS1/LGS2 and Rate Schedule PDS, shall be increased or decreased by an
amount hereinafter described as the Purchased Gas Adjustment Factor (PGA).
(b)
Definition of "Purchased Gas"
The term "purchased gas" as used in determination of the PGA shall include, but not be
limited to, the following sources of gas, including related transportation, storage, handling
costs required for delivery to the Company's facilities, and all costs associated with the
purchase and sales of gas price hedging futures contracts applicable to: 30% of the
Company's forecasted non-storage normal winter demand (December through February),
commencing with the 2013-2014 Winter Season and continuing through the 2016-2017
Winter Season, of its Customers that pay the PGA/ACA, as determined at the outset of each
hedging purchase period, pursuant to the Company's Gas Price Fledging Plan:
17.2
(i)
Natural and substitute natural gas (SNG) and liquefied natural gas (LNG) from
pipeline and other suppliers including exchange gas;
(ii)
LNG from other than pipeline sources;
(iii)
Liquefied petroleum gas (LPG); and
(iv)
Other hydrocarbons used as feedstock for production of SNG and spot or emergency
purchases.
Computation of Firm PGA
The PGA, calculated to the nearest $0,001 per Dth, shall be computed each quarter for firm sales
Customers under Rate Schedules RS, SGS1, SGS2, SGS3, UGLS and MPS and to the nearest
$0.0001 per Dth for firm customers under Rate Schedule LGS1/LGS2 in the following manner:
(a)
Base Cost - Firm Rate Schedules
The base cost of purchased gas applicable to each of the Company's firm sales rate
schedules is as follows:
Total Base Cost
Of Gas
(per Dth)
Demand
(per Dth)
Commodity
(per Dth)
RS, MPS
$ 3.0300
$ 3.4340
$ 6.464
SGS1/SGS2/SGS3, UGLS
$ 2.2560
$ 3.4340
$ 5.690
LGS1/LGS2
$0.4510
$ 3.4340
$ 3.8850
SS1/SS2
$0.4510
$ 3.4340
$ 3.8850
Rate Schedule
'
Effective Date: November 29, 2016
COLUMBIA GAS OF VIRGINIA, INC,
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
SECOND REVISED SHEET NO. 446
SUPERSEDING
FIRST SHEET NO. 446
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
(b)
ACCEPTED FOR FILING
DIVISION OF ENERGY REGULATION
STATE CORPORATION COMMISSION
NOV 21 2016
Base Cost - Combined Firm Sales Rate Schedules
The base cost of purchased gas applicable to the combined total sales for the firm
sales rate schedules in 17.2(a) of this section is $6.1660 per Dth. This is the sum of the
demand cost of $2.7320 and the commodity cost of $3.4340. The base cost of
purchased gas for RTS, SGTS1, SGTS2, SGTS3, UGLTS and ACTS is $2,359.
(c)
Calculation of Firm PGA - Sales
The PGA for all firm sales rate schedules shall be determined as follows:
(i)
For estimated quantities purchased as specified in Section 17.1(b)(i), the
annual billing demands and the quarterly commodity purchases for firm sales
rate schedules will be priced at the estimated wholesale rates of the
Company's suppliers. For the purposes of calculating the firm PGA, Gas
Inventory Charges (GIC's) and other similar charges from the Company's
pipeline suppliers will be considered as a demand cost of gas. For purposes of
the interruptible PGAs, such charges will be considered as a commodity cost
of gas.
(ii)
The estimated quantities of all other types of gas or hydrocarbons purchased
as specified in Section 17.1 (b)(ii), (iii), and (iv), for firm sales rates schedules
during the billing quarter will be priced at the respective prices at which such
quantities were charged to expense accounts on the Company's books. These
purchases will be included with the commodity charges in Section 17.2(c)(i).
(iii)
The sum of commodity amounts determined in Section 17.2(c)(1) and (ii),
carrying costs on gas storage balances, and applicable billing adjustments, will
be divided by the projected firm Dth sales, less any sales related to applicable
billing adjustments, for the billing quarter to determine the quarterly commodity
cost per Dth. Carrying costs on gas storage balances for the Firm PGA-Sales
will be based on allocated average storage balances for the billing quarter
multiplied by the overall rate of return, as determined in its most recent rate
case, including the authorized return on common equity, plus an allowance for
income taxes.
(iv)
The sum of demand amounts determined in Section 17.2(c)(i) and (ii), and
applicable billing adjustments, less any demand costs directly assigned to rate
schedules or Customers, other than those directly assigned the Choice
Program, will be divided by the projected firm Dth sales, including quantities
transported under rate schedules RTS, SGTS1, SGTS2, SGTS3, UGLTS and
ACTS, less any sales related to applicable billing adjustments, for the billing
quarter to determine the quarterly demand cost per Dth.
1
(v)
The sum of amounts determined in Section 17.2(c)(iii) and (iv) for separately
computed demand and commodity amounts will be the current cost per Dth of
gas purchased for sales under applicable schedules (Current Cost).
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: November 29, 2016
FIRST REVISED SHEET NO. 447
SUPERSEDING
ORIGINAL SHEET NO. 447
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
(d)
ACCEPTED FOR FILING
DIVISION OF ENERGY REGULATION
STATE CORPORATION COMMISSION
NOV 21 2016
(vi)
The Current Cost determined in Section 17.2(c)(v) will be adjusted to provide
for the recovery of uncollectible accounts expense by multiplying the Current
Cost times one plus the uncollectible accrual rate used to establish base nongas rates in the Company's most recent rate proceeding.
(vii)
The PGA shall be the difference between the base cost set forth in Section
17.2(b) and the current cost determined in Section 17.2(c)(vi).
Calculation of Firm PGA - Choice Program
The PGA for rate schedules RTS, SGTS1, SGTS2, SGTS3, UGLTS and ACTS shall
be determined as follows:
(i) The unit demand cost of firm capacity, as calculated in Section 17.2c(iv), minus
(ii) The weighted average unit demand cost of capacity offered for assignment in the
Choice Program, plus
(iii) Variable storage costs, minus
(iv) The base cost set forth in Section 17.2(b).
(e)
Annual Roll-In
Effective with the December billing month of each year, the base cost of gas shall be
revised to reflect the cost of purchased gas as determined in Sections 17.2(c)(v),
excluding carrying costs on gas storage balances, and 17.2(d) for the 12 months ended
August of that year, which base cost of gas shall be effective through the November
billing month of the following year. Concurrently, the rates for monthly consumption set
forth in all firm sales rate schedules as well as transportation rate schedules RTS,
SGTS1, SGTS2, SGTS3, UGLTS and ACTS shall be revised to reflect an appropriately
revised base cost.
17.3
Computation of Interruptible PGA
(a)
Base Cost - Interruptible Rate Schedules
The base cost of purchased gas applicable to the combined total commodity sales for
the interruptible sales rate schedules is $3.4340 per Dth.
(b)
Calculation of Interruptible PGA
The PGA for all interruptible sales rate schedules shall be determined as follows:
(i)
For estimated quantities purchased as specified in Section 17.1(b)(i) , the
quarterly commodity purchases for interruptible sales rate schedules will be
priced at the estimated wholesale rates of the Company's suppliers.
Effective Date: November 29, 2016
FIRST REVISED SHEET NO. 448
SUPERSEDING
ORIGINAL SHEET NO. 448
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
GENERALTERMSANDCONDIT~NS
ALL RATE SCHEDULES
(continued)
(c)
(ii)
The estimated quantities of all other types of gas or hydrocarbons purchased as
specified in Section 17.1 (b)(ii), (iii) and (iv), for interruptible sales rate schedules
during the billing quarter will be priced at the respective prices at which such
quantities were charged to expense accounts on the Company's books.
(iii)
The sum of amounts determined in Section 17.3(b)(i) and (ii), carrying costs on
gas storage balances and applicable billing adjustments, will be divided by the
projected interruptible Dth sales for the billing quarter to determine the current
cost per Dth of gas purchased for sales under applicable schedules (Current
Cost). Carrying costs on gas storage balances for the Interruptible PGA will be
based on allocated average storage balances for the billing quarter multiplied by
the overall rate of return, as determined in its most recent rate case, including
the authorized return on common equity, plus an allowance for income taxes.
(iv)
The PGA shall be the difference between the base cost set forth in Section
17.3(a) and the current cost determined in Section 17.3(b)(iii).
Annual Roll-In
Effective with the December billing month of each year, the base cost of gas shall be
revised to reflect the cost of purchased gas as determined in Section 17.3(b)(iii),
excluding carrying costs on gas storage balances, for the 12 months ended August 31
of that year, which base cost of gas shall be effective through the November billing month
of the following year; and concurrently the rates for monthly consumption set forth in all
interruptible sales Rate Schedules shall be revised to reflect an appropriately revised
base cost.
Effective Date: September 28, 2016
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Division of Energy Regulation
Accepted for Filing
September 14, 2016
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 449
SUPERSEDING
ORIGINAL SHEET NO. 449
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
17.4
Computation of Banking and Balancing Service PGA
{a)
Base Cost - Rate Schedule BBS
The base cost of gas purchased applicable to Rate Schedule BBS - Banking and
Balancing Service is listed on Rate Sheet 5.
(b)
(c)
(d)
Calculation of the Non-Firm Banking and Balancing Service PGAs
{i)
The Bank Tolerance percentage selected by the Customer will be multiplied
by seven (7) months of Columbia Gas Transmission Corporation's (TCO)
Firm Storage Service (FSS) Capacity Charge; plus
(ii)
The product of TCO's FSS injection and withdrawal charge multiplied by the
percentage of Rate Schedule TS1/TS2 and AS Customer quantities using
storage; plus
(iii)
The product of TCO's Storage Service Transportation (SST) charge multiplied
by the percentage of Rate Schedule TS1/TS2 and AS Customer quantities
using storage; plus
(iv)
The product of the Rate Schedule LGS1/LGS2 interruptible commodity cost of
gas multiplied by TCO's retainage factors, and the Bank Tolerance percentage
selected by the Customer.
(v)
The PGA shall be the difference between the base cost set forth in Section
17.4 (a) and the current cost determined in Section 17.4 (b) (i - iv).
Calculation of the Firm Banking and Balancing Service PGAs
(i)
The PGA for the Firm Banking and Balancing Service throughput rate will be
equal to the Bank Tolerance percentage selected by the Customer multiplied
by five (5) months of TCO's FSS Capacity Charge, plus the Non-Firm
Banking and Balancing Service current cost calculated in Section 17.4(b)(iiv), less the base cost set forth in 17.4(a);
(ii)
The PGA for the Firm Banking and Balancing Service demand charge that
will be applied to 5.0% of the Customer's Maximum Daily Quantity will be
equal to: (1) the TCO FSS Monthly Demand Charge; (2) plus the product of
TCO's Rate Schedule SST Monthly Demand Charge multiplied by 75%; (3)
less the base cost set forth in 17.4(a).
Annual Roll-In
(i)
Effective with the December billing month of each year, the base cost of gas
shall be revised to reflect the cost of purchased gas as determined in Sections
17.4(b)(i-iv) and 17.4(c)(i-ii), for the 12 months ended August 31 of that year,
which base cost of gas shall be effective through the November billing month
of the following year.
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 450
SUPERSEDING
ORIGINAL SHEET NO. 450
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
17.5
Actual Cost Adjustment
(a)
Calculation of ACA
An annual Actual Cost Adjustment ("ACA"), containing separate demand and
commodity components, shall be computed for transportation Rate Schedules RTS,
SGTS1, SGTS2, SGTS3 and UGLTS, and each sales Rate Schedule except Rate
Schedules SS and PDS, and become effective along with the quarterly PGA.
The ACA will not apply to Optional Fuel Displacement Service under Rate Schedule
LGS1/LGS2 or to Rate Schedules ACS, ACTS or SS. The calculation of the ACA will
exclude purchased gas expenses and sales of each of the aforementioned optional
service under LGS1/LGS2 and the listed Rate Schedules.
(b)
The annual ACA determined in 17.S(a) will include carrying costs, which will be
accrued on the outstanding Account 191 balance existing at the end of each month.
The carrying costs shall be the Company's weighted average cost of short-term debt
for the most recent month in which short-term debt was outstanding.
The ACA shall be calculated based on a Determination Period, which shall be the
twelve-month period September 1 through August 31 of each year of PGA
application. The ACA shall be determined from the commodity cost of gas purchased
and the demand cost of gas purchased excluding supplier refunds, as recorded on the
books of the Company for the Determination Period. The commodity and demand
· costs will then be allocated to each applicable firm sales rate schedule and
transportation rate schedule in accordance with the applicable allocation factors
established in the Company's most recent rate proceeding (other than for sales
excluded from application of the PGA and ACA by Subsection 17.1(a) above,
subtracting there from an amount equal to:
(i)
the Base Cost of purchased gas per Dth as specified in Section 17.2(a),
17.3(a), or 17.4(a) as applicable, or that Base Cost which was used to
calculate the PGA factors in effect during the Determination Period multiplied
by the actual quantities of gas sold during the Determination Period;
(ii)
the PGA revenues during the Determination period;
(iii)
an adjustment for the net ACA over -or under-collection during the
Determination Period;
(iv)
the Direct Refund amount of any supplier refunds held on the Company books
for which direct refund factors have not been calculated and filed for refunding
to Customers;
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
FIRST REVISED SHEET NO. 451
SUPERSEDING
ORIGINAL SHEET NO. 451
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
(c)
(v)
An adjustment for Off-System Sales Margins and Capacity Release
Revenues, as defined in Section 17.6, received by the Company during the
Determination Period ;
(vi)
An adjustment to remove any cost subsidy from Metered Propane Service
(MPS) by (1) determining the natural gas equivalent (NGE) of propane
consumed by MPS customers using the NGE factor set forth in rate schedule
MPS, (2) multiplying the NGE by the Company's Weighted Average
Commodity Cost of Gas ("WACCOG") for each month in the ACA
determination Period, (3) multiplying the total Determination Period NGE by the
Company's residential customer class weighted average demand cost of gas
for the same Determination Period, (4) substitute the total of the NGE costs
from Steps (2) and (3) for the actual propane costs in the ACA;
(vii)
The commodity based penalties and charges collected by the Company
pursuant to Section 10.6 of the General Terms and Conditions;
(viii)
An adjustment applicable only to Rate Schedules RS, RTS, SGS1, SGS2,
SGTS1 and SGTS2 for the Company's share of any performance based
incentives for delivering conservation and energy efficiency benefits calculated
pursuant to Section 17.12;
(xi)
An adjustment for the carrying costs on gas storage balances, which shall be
calculated by subtracting from the recovered carrying cost on gas storage
balances calculated pursuant to Sections 17.2(c)(iii), and 17.3(b)(iii), the actual
gas storage carrying costs determined by multiplying the 13 month average
gas storage balances for the ACA determination period by the overall rate of
return, as determined in its most recent rate case, including the authorized
return on common equity, plus an allowance for income taxes; and
(x)
An adjustment for the actual gas cost uncollectible expense, which shall be
calculated by subtracting from the recovered uncollectible gas cost expense
pursuant to Section 17.2(c)(vi), the product of the applicable billed quantities
multiplied by the Company's weighted average cost of gas multiplied by the
actual uncollectible accrual rates for each month in the ACA determination
period.
Application to Next PGA
The amount derived in Section 17 .5(b) shall be divided by estimated Dth quantities of
gas to be sold during the next twelve months for each firm sales rate schedule specified
in Section 17.1(a) and the resulting unit rate shall be reflected in the Purchased Gas
Adjustment for a twelve-month period commencing with the second PGA quarter after the
ending month of the Determination Period specified in Section 17 .5(b) (December
quarter), or for such period of less than twelve months as may be required to fully refund
or recover the amount described in Section 17.5(b) above. The demand amount derived
in Section 17.5(b) shall be divided by the total estimated Dth quantities of gas to be sold
during the next twelve months for each firm rate schedule including the estimated
transportation quantities for transportation rate schedules RTS, SGTS1, SGTS2, SGTS3,
and UGLTS.
Effective Date: September 28, 2016
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Division of Energy Regulation
Accepted for Filing
September 14, 2016
FIRST REVISED SHEET NO. 452
SUPERSEDING
ORIGINAL SHEET NO. 452
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
Any customer electing service under Rate Schedules RS, RTS, SGS1 , SGS2, SGS3,
SGTS1, SGTS2, SGTS3, UGLS or UGLTS shall be subject to the entire ACA factor as
derived in Section 17.5(b) for only a period equivalent to the number of months of the
prior 12 month period during which such customer was served under Rate Schedules
RS, SGS1, SGS2, SGS3, or UGLS. The Customer shall be subject to the demand
portion of the ACA as derived in 17.5(b) months for only a period equivalent to the
number of months of the prior twelve month period during which the Customer was
served under Rate Schedule RTS, SGTS1, SGTS2, SGTS3, or UGLTS.
17.6
Revenues From Off-System Sales and Capacity Release
(a)
Definitions
(i)
"Off-System Sales Margin" shall mean revenues received by the Company
from the sale of unbundled or re-bundled gas supply and capacity products
plus savings generated by the transaction(s) in the form of costs avoided as a
result of the transaction(s) ("Avoided Costs"), less the costs caused by the
transaction. Off-System Sales Margin excludes Operational Transaction Cost
as defined in Section 17.6(a)(iv) below. Off-System Sales arrangements
include flowing gas sales, incremental gas sales, exchanges, and asset
management arrangements.
For flowing gas sales, the costs will be the daily average city gate commodity
cost of the gas supplies purchased by the Company and flowing on the first of
the month, Which will be referred to as the first of month gas cost ("FOMGC").
For sales made upstream of the Company's city gate, the cost of transportation,
including retainage, from the point of sale to the city gate will be subtracted from
the FOMGC. This amount will be further adjusted to include applicable taxes
and other costs that have been or will be incurred.
For incremental gas sales, the costs will be the purchase price of the gas sold,
adjusted for applicable costs such as pipeline transportation charges, retainage,
applicable taxes and other costs, and further adjusted for savings in the form of
Avoided Costs.
For other off system sales products, the costs will be the incremental costs
incurred in the transaction, such as pipeline transportation charges, retainage,
applicable taxes and other costs, and further adjusted for savings in the form of
Avoided Costs.
(ii)
"Capacity Release Revenue" shall mean revenue the Company receives in
the form of demand charge credits on its pipeline invoices from arrangements
to sell, in the secondary capacity market, interstate pipeline transportation
and/or storage capacity held under contract by the Company. Capacity
Release Revenue excludes Retail Choice Capacity Release Revenue and
Administrative Capacity Release Revenue as defined in Sections 17.6(a)(v) and
17.6(a)(vi), respectively.
Effective Date: September 28, 2016
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Division of Energy Regulation
Accepted for Filing
September 14, 2016
FIRST REVISED SHEET NO. 453
SUPERSEDING
ORIGINAL SHEET NO. 453
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
(b)
(iii)
"Incentive Dollars" shall mean the sum of Off-System Sales Margin as
defined in Section 17.6(a)(i) and Capacity Release Revenue as defined in
Section 17.6(a)(ii).
(iv)
"Operational Transaction Cost" shall mean the costs that result from off
system transactions entered into by the Company for the purpose of averting
a higher cost to the PGA such as pipeline penalties, supplier keep whole
charges and take-or-pay charges.
(v)
"Retail Choice Capacity Release Revenue" shall mean revenue the
Company receives in the form of demand charge credits on its pipeline
invoices for capacity released to Competitive Service Providers pursuant to
Section 7 of Rate Schedule CSPS.
(vi)
"Administrative Capacity Release Revenue" shall mean revenue the
Company receives in the form of demand charge credits on its pipeline
invoices for capacity released to a supplier who uses that capacity to manage
the delivery of gas purchased by the Company where the supplier applies the
cost of that capacity to the price of gas charged to the Company. An
Administrative Capacity Release can facilitate an asset management
arrangement that generates Incentive Dollars.
Operational Transactions
All Operational Transaction Costs as defined in Section 17.6 (a)(iv) above, incurred by
the Company will be applied to the ACA of the applicable sales service rate schedules
and transportation rate schedules based on the allocation method set forth in Section
17.S(a), above.
(c)
Retail Choice and Administrative Capacity Release Revenue
All Retail Choice and Administrative Capacity Release Revenue as defined in Sections
17.6(a)(v) and 17.6(a)(vi) above, respectively, will be credited to the ACA of the
applicable firm sales service rate schedules and transportation rate schedules based
on the allocation method set forth in Section 17.5(a), above.
(d)
Off-System Sales and Capacity Release Incentive Mechanism ("Incentive
Mechanism")
(i)
The Incentive Mechanism Program Year ("Program Year") will begin on the first
day of September each year and end on the last day of August each subsequent
year. However, the initial Program Year will run for an abbreviated period of eight
months beginning January 1, 2008 and ending August 31, 2008. For the initial
Program Year, the annual amounts determined in Sections 17.6(d)(ii) and (iii) will
be multiplied by a factor of 8/12ths to reflect the abbreviated period for the initial
Program Year.
Effective Date: September 28, 2016
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Division of Energy Regulation
Accepted for Filing
September 14, 2016
FIRST REVISED SHEET NO. 454
SUPERSEDING
ORIGINAL SHEET NO. 454
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
(ii)
The Minimum Incentive Dollars (MID) as used in Section 17.6(d)(iv) below, will
be determined separately for each Program Year. The baseline MID is
$1,500,000. The baseline MID will be adjusted for each Program Year by
dividing the average Program Year peak day delivery portfolio for firm delivery
into the Company's system for each month of the Program Year by 414,835
Dth (the Company's peak day firm delivery portfolio as of July 12, 2007), and
multiplying the quotient by $1,500,000.
(iii)
The Program Year Threshold (PYT) for sharing as used in Section 17.6(d)(iv)
below, will be determined separately for each Program Year. The baseline
Threshold is $2,800,000. The baseline Threshold will be adjusted for each
Program Year by dividing the average Program Year peak day delivery
portfolio for firm delivery into the Company's system for each month of the
Program Year by 414,835 Dth (the Company's peak day firm delivery portfolio
as of July 12, 2007), and multiplying the quotient by $2,800,000.
(iv)
Incentive Dollars (ID), as defined in Section 17.6(a) (iii) above, will be credited
to the ACA of the applicable sales service rate schedules and transportation rate
schedules based on the allocation method set forth in Section 17.S(a), above.
The amount of the Program Year ID ACA credit will be determined from the table
below.
Step 1
Step 2
Step·3
Step 4
ID<=MID
ID>MID
ID>PYT
ID>=PYT/.75
17. 7
but, ID<=PYT
but, ID<=PYT/.75
ACA Credit=MID
ACA Credit=ID
ACA Credit=PYT
ACA Credit=ID X .75
Refunds
(a)
Supplier Refunds Covered by Prior PGAs
When the Company receives a refund from its suppliers which results from a reduction
in supplier prices applicable to prior periods and was previously reflected in the PGA,
the Company shall pass on such refunds to its Customers as hereinafter described;
however, no Customer shall receive such refunds with respect to gas purchased under
the Optional Alternate Fuel Displacement sales provisions of Rate Schedules
LGS1/LGS2. These supplier refunds shall be divided into their demand and commodity
components and reflected in the applicable demand and commodity rates.
(i)
The total dollars of any commodity refunds plus interest received, if any, shall be
divided by the actual total sales in Dth to retail Customers under rates that
reflected the refunded dollars during the prior period, for which the refund was
made to produce the Direct Refund Factor. The total dollars of any demand
refunds plus interest received, if any, shall be divided by the actual total sales in
Dth, including transportation quantities for Rate Schedules RTS SGTS1, SGTS2,
SGTS3, UGLTS and ACTS if applicable to that particular refund, to retail
Customers under rates that reflected the refunded dollars during the prior period,
for which the refund was made to produce the Direct Refund Factor. However,
should the Company receive minor refunds (less than $.01 per Dth of sales),
such refunds will be held until refunds have a $.01 per Dth Refund Factor.
Interim, Subject to Refund
Effective Date: September 28, 2016
SCC Case No. PUE-2016-00033
Division of Energy Regulation
Accepted for Filing
September 14, 2016
FIRST REVISED SHEET NO. 455
SUPERSEDING
ORIGINAL SHEET NO. 455
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
(ii)
Direct refunds shall be calculated for large volume firm and interruptible
Customers purchasing gas during the prior period for which the refund was
made under rates that reflected the refunded dollars, by multiplying the Direct
Refund Factor times the quantity of such gas purchased by each such
Customer during such prior period. Direct Refunds shall be made by the end of
the second PGA quarter after the date of receipt of the refund and shall be by
bill credit or check sent to each such Customer.
(iii)
The total dollars of Direct Refunds shall be subtracted from total refund dollars
plus interest received, if any. The remainder shall be applied as mitigation of
Choice transition costs and flowed through to customers per Section
17.11 (b)(3) of the General Terms and Conditions.
(iv)
(b)
No Customer receiving Direct Refunds may also receive refunds through the
PGA unless it was also purchasing firm gas from the Company during the prior
period for which the refunds were made.
Rounding
The refund factor is to be computed to the nearest $0.001 per Dth.
(c)
Interest
The Company will pay applicable interest on the refund dollars to be returned to
Customers at the current rate prescribed by the Commission applicable to customer
deposits.
(d)
Annual Balances
Any refund balance remaining on the books of the Company at the end of twelve
months of refund application shall be added to a subsequent supplier refund or to the
ACA calculation, whichever occurs first, in such manner as to reflect any over or under
refunds.
17.8
Filing
(a)
PGA
The Company will file with the Virginia State Corporation Commission's Division of
Energy Regulation a copy of the computation of the PGA or refund credit and
verification of its supplier change in prices or refunds, if necessary, prior to the
beginning of each PGA quarter, or at other such times as may be appropriate, which
PGA or refund credit shall be subject to Commission approval.
(b)
ACA
The ACA shall be computed and filed with the Commission for review at twelve-month
intervals, which ACA shall be subject to Commission approval.
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 456
SUPERSEDING
ORIGINAL SHEET NO. 456
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
Details of Purchases
17.9
The Company shall make available to the State Corporation Commission's Division of
Public Utility Accounting all details of purchases as required.
17.10
17.11
Cost Adjustments for Rate Schedule PDS
(a)
The Company shall calculate and charge customers under Rate Schedule PDS
("Propane Delivery Service") the cost of propane calculated on a quarterly basis a
Propane Cost Adjustment ("PCA"). This cost shall be calculated in the same manner
as the PGA calculated for natural gas customers, but substituting the costs for
propane, including delivery costs.
(b)
The Company shall calculate and charge customers under Rate Schedule PDS
("Propane Delivery Service") the cost of propane calculated on an annual basis a
Propane Actual Cost Adjustment ("PAGA"). This cost shall be calculated in the same
manner as the ACA calculated for natural gas customers, but substituting the costs for
propane, including delivery costs.
(b)
The PCA and PAGA will be filed with the Commission's Division of Energy Regulation
as part of the Company's PGA and ACA filings pursuant to Sections 17.S(a) and (b),
respectively.
TRANSITION COSTS RECOVERY MECHANISM
(a) Applicability
Applicable to all RS, SGS1, SGS2, SGS3, UGLS, ACS, RTS, SGTS1, SGTS2, SGTS3,
UGLTS and ACTS Customers.
(b) Transition Costs Recovery Mechanism
(1)
(2)
The following costs shall be included for recovery:
(i)
Information Technology - Incremental expenses for computer programming
enhancements to facilitate the Choice Program.
(ii)
Education - Expenses for customer education conducted by the Company for
the Choice Program, including development of program and materials and
implementation.
The following recoveries shall mitigate transition costs:
(i)
Supplier Refunds - An allocated amount of supplier refunds as calculated per
Section17.7 of the General Terms and Conditions.
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
COLUMBIA GAS OF VIRGINIA
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
SECOND REVISED SHEET NO. 457
SUPERSEDING
FIRST REVISED SHEET NO. 457
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
(3)
17.12
The Transition Costs Recovery Charge based on the unmitigated transition costs is
calculated as follows:
(i)
For the current application period January through December, a rate
per Dth shall be computed by dividing the projected unmitigated
transition costs, as defined above, for the twelve months ending
October 31, the accumulation period, by the projected annual sales
and transportation quantities under rate schedules RS, SGS1, SGS2,
SGS3, UGLS, ACS, RTS, SGTS1, SGTS2, SGTS3, UGLTS, and
ACTS for the application period. The per Dth factor will be applied to
customer bills for a twelve month period beginning with the January
billing cycle.
(ii)
An annual reconciliation factor shall be computed by subtracting from
the prior year's actual transition costs incurred during the accumulation
period (twelve months ending October 31) plus any remaining prior
year's balance, the recoveries during the same twelve month period.
The result shall be divided by the projected annual sales and
transportation quantities under rate schedules RS, SGS1, SGS2,
SGS3, UGLS, ACS, RTS, SGTS1, SGTS2, SGTS3, UGLTS, and
ACTS for the current application period. The per Dth factor will be
applied to customer bills for a twelve month period beginning with the
January billing cycle.
(iii)
The factors calculated in (i) and (ii) will be combined to produce the
net Transition Costs Recovery Charge reflected on Rate Sheet 3A.
CARE Program Performance Incentive ("CPPI")
(a)
The CPPI applicable to CARE Program Years 2010 through 2014 as computed in
Section 17 .12(b) below will be recovered from customers served under Rate Schedules
RS, RTS, SGS1, SGS2, SGTS1, SGTS2, SGS3, SGTS3 and EDS pursuant to Sections
17.5(b)(viii). The CPPI applicable to CARE Program Years 2015 and beyond as
computed in Section 17.12(b) below will be recovered from customers served under
Rate Schedules RS, RTS, SGS1, SGS2, SGTS1, SGTS2 and EDS pursuant to
Sections 17 .5(b )(viii).
(b)
For the twelve months ending December 31 of each year in which measures
implemented pursuant to the CARE Plan are generating benefits and usage reductions
meet one of the targets set forth in Section 17.12(d), the CPPI will be equal to a
percentage of the net economic benefits for the year, as set forth below. Net economic
benefits will be calculated by totaling the monetized energy benefits for the year and
subtracting a pro-rated share of the recovered CARE Program costs pursuant to Section
12.4. The total energy benefits are defined as the sum of the usage reductions attributed
to all participants in CARE Plan programs in that year measured from the date of
installation through the end of the measure's deemed operational lifetime, valued at the
actual cost of gas for that year. The CPPI will be calculated following the formula
contained in Section 17.12(c) and allocated to Residential and Small General Service
Customer Classes using projected sales, with the Small General Service 1 and Small
General Service 2 Customer Classes having the same CPPI.
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
COLUMBIA GAS OF VIRGINIA
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 458
SUPERSEDING
ORIGINAL SHEET NO. 458
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
(c)
The CPPI mechanism for each year that the benefits are achieved from the CARE Program
pursuant to 17.12(b) is shown mathematically as follows:
Eq. (1)
Where:
CPPft =the performance incentive for year t. The performance incentive will be
calculated for each year that a measure installed in a CARE Program year is
operating within its deemed operational lifetime. ($)
Rate1 =the percent share of the net benefits as described in 17.12( d) (%)
Dth1,1 = the verified natural gas savings for any measure i installed during a CARE
Program year delivering savings in year t as described in 17 .12 (e). (Dth)
WACOGr =the Company's jurisdictional weighted average cost of gas in year
t
($/Dth)
X =the number of individual measures in the CARE program
Cpa,alloc,t
=the allocated Care Program costs for year t as described in 17.12(f)
amortized over a 15 year period. ($)
(d)
The rate is a function of the company's program-to-date annual savings (on a quantity basis)
targets for that program year. The rate increases based upon the company's level of
achievement toward the target as follows:
•
At less than 50%, no incentive will be earned for that year.
•
At 50 percent to 59.9 percent of the savings target, the rate equals 5 percent.
•
At 60 percent to 69.9 percent of the savings target, the rate equals 10 percent.
•
At 70 percent and above of the savings target, the rate equals 15 percent
Interim, Subject to Refund
SCC Case No. PUE-2016-00033
Effective Date: September 28, 2016
Division of Energy Regulation
Accepted for Filing
September 14, 2016
COLUMBIA GAS OF VIRGINIA
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
FIRST REVISED SHEET NO. 459
SUPERSEDING
ORIGINAL SHEET NO. 459
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
The usage reduction targets for the CARE Plan are based upon the savings attributed to all
participants in the CARE Program measured from the year of installation to year t as follows:
2016:
26,629 Dth
2017:
59,889 Dth
2018:
94,929 Dth
The rate for all subsequent years (2019 and beyond) will equal the rate determined in 2018.
(e)
The natural gas savings is calculated for all measures participating in the CARE Program from
the month of installation through year t, within the measure's deemed operational lifetime.
Natural gas savings attributed to the measure's first year and last year will be pro-rated to
account for the level of natural gas savings achieved in that year based upon the month of the
measure's installation and the measure's deemed operational lifetime; respectively.
Measure impacts will be based upon the Company's annual measurement and verification
report (M&V Report) conducted in each of the three CARE Plan program years. The impacts
documented in the annual M&V Report will continue to be applied in years subsequent to the
three year CARE program period. M&V activities will not be conducted after the third CARE
Program year.
(f)
The annual Care Program Cost allotment (Cpa,auoc,t) is calculated by amortizing the recovered
program costs in each program year pursuant to Section 12.4 over a 15-year period. The
calculation is as follows:
Program Year (t)
Equation
I
c
1
2
- cpa,l
pa,alloc,t -
ls
c pa,1 c pa,2
C
pa,a//ac,t
=ls+ lS
·····-······..·············-·········---··..········- ···························-····················-···································-······-·······-························
3-15
16
17
c
c
c
c pa,a//oc,I =~+~+~
15
15
15
C
_
cpa,2 + c pa,3
-15 lS
c
c pa,allaa,t -~
-
pa,allaa,I
15
Where:
Cpa.t =the program costs recovered in CARE Program year (t) pursuant to Section
12.4 ($)
Effective Date: March 31, 2016
Per February 23, 2016 Final Order in Case No. PUE·2015-00072
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
1.l_:__
,1
t~
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 460
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
18.
SERVICE AGREEMENT GENERAL TERMS AND CONDITIONS
18.1
Form of Service Agreement
Customers desiring to receive service under one or more Rate Schedules requiring a Form of
'Service Agreement shall enter into a contract with the Company under the applicable form of
Service Agreement. Customers desiring to receive service under Rate Schedule LVTS shall
enter Into a negotiated Service Agreement with the Company. Such Service Agreement shall
indicate thereon the Rate Schedule under which service shall be rendered, Such Service
Agreement shall be subject to the provisions contained In the designated Rate Schedule and
the General Terms and Conditions applicable thereto or any subsequent changes and
revisions, which are made in accordance with valid laws, orders, rules, and regulations of duly
constituted authorities having jurisdiction.
18.2
18.3
Successors and Assigns
(a)
Any company which shall succeed by purchase, merger or consolidation to the
properties of the Company, and any affiliated successor In Interest which shall acquire
from the Company the properties of the Company used in rendering service to
Customer, shall be entitled to the rights and shall be subject to the obligations of its
predecessor In title under any Service Agreement between Company and Customer.
(b)
Customer may assign a Service Agreement for service under an applicable Rate
Schedule to a company that succeeds by purchase, merger or consolidation to the
properties of the Customer and any .affiliated successor in interest which shall acquire
from the Customer the properties of the Customer receiving service under such Service
Agreement upon the consent of the Company, which consent shall not unreasonably be
withheld.
(c)
Either Customer or Company may assign or pledge the Service Agreement between
them under the provisions of any mortgage, deed of trust, Indenture or similar instrument
which it has executed or may execute hereafter; provided, however, such mortgage,
deed of trust, indenture or similar Instrument shall cover the properties of such party as
an entirety unless such party is an affiliated successor in interest as above; otherwise
neither party shall assign any Service Agreement between them or any of its rights
thereunder.
Waiver of Default
No waiver by either party of any one or more defaults by the other in the performance of any
provisions of a Service Agreement between them shall operate or be construed as a waiver of
any future default or defaults, whether of a like or of a different character.
18.4
Transfers Between Rate Schedules (excluding Rate Schedule LVTS)
(a)
{
'
If a Customer desires to transfer service from one to another of the Company's Rate
Schedules, Customer shall give notice to the Company by January 2 of any year and If
Customer is advised by the Company that It has the required gas supply, capacity, and
facil!tfes to accommodate such transfer, then Customer, on or before April 1 of such
year shall execute a contract to become effective November 1 of such year.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE·2014-00020
Accepted for Flllng
Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 461
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
{
\.
18.5
(b)
In transferring between Rate Schedules, a Customer may, at Its election, retain Its firm
demand level, provided it Is located behind the same PSP (as designated by the
delivering pipeline or the Company for purposes of Its operations) and of a similar
character and load factor as the firm demand service currently received by the
Customer.
(c)
The Company may, under specified circumstances, permit a customer that ls subject to
an existing Service Agreement to contract for service under a different Rate
Schedule(s) or at a different level of service upon less than the notice required by
Section 18.4(a) and notwithstanding the remaining term applicable to the customer
pursuant to an applicable Rate Schedule or Service Agreement. To be eligible to
contract for service under a different Rate Schedule(s) or at a different level of service
under this provision: (i) the Company must have the required gas supply, capacity, and
facilities to accommodate such a change In Rate Schedule or level of service; (ii) the
Customer must provide the Company with evidence of a significant change in business
circumstances necessitating the proposed change In Rate Schedule or level of service;
(iii) the Company must determine that the change in Rate Schedule or level of service
will not be economically disadvantageous to other Customers; (iv) the Customer must
pay the higher of the Customer Charge applicable under the Customer's then current
and proposed Rate Schedules for the remaining term applicable under the Customer's
then current Rate Schedule; and (v) the Customer must execute any applicable Service
Agreement(s) governing new Rate Schedules under which the Customer subscribes to
service. The types of changes in Rate Schedule(s) or levels of service to which this
provision applies are limited to the following:
(1}
An increase in the Customer's bani< tolerance Linder Rate Schedule BBS;
(2)
An increase in the contracted level of Standby Service under Rate Schedule
SS;
(3)
A transfer from Rate Schedule TS1frS2 to either Rate Schedule
SGS1/SGS2/SGS3 or LGS1/LGS2, provided that the Customer contracts for
or otherwise agrees to compensate the Company for a level of firm service
(including firm BBS and SS) that Is at or above the Customer's current level of
firm service for a period equivalent to the remaining term of the Customer's
TS1ffS2 Service Agreement; or
(4}
A transfer from Rate Schedule LGS1/LGS2 to Rate Schedule TS1fTS2,
provided that the Customer contracts for Standby Service at or above the
Customer's current level of contracted firm LGS capability for a period
equivalent to the remaining term of the Customer's LGS1/LGS2 Service
Agreement.
Operating Information and Estimates
Upon request of the Company, Customer shall from time to time submit estimates of the daily,
monthly and annual quantities of gas required, Including peak day requirements, together with
such other operating data as the Company may reasonably require In order to plan its
operations.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order In Case No. PUE"2014·00020
Accepted for Filing
,Janaury 21, 2016
Division of Energy Regulation-sec
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
ORIGINAL SHEET NO. 462
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued}
19.
OTHER SERVICE CHARGES
Type of Service
Charge
Reconnect Meter After Disconnect of Meter ........................................................................ Minimum of $87
The actual cost, as calculated under "other Special Services" described below, will be charged
if the reconnection must be made at the main connection.
Special Meter Test (Subsequent test of meter within twenty-four (24) months of free meter test) ...... $125
Returned Check Charge ........................................................................................................................... $21
Priority service or return trip ..................................................................................................................... $87
The priority service charge is applicable:
(a) when a reconnect is requested sooner than required by Section 6.4; and
(b) for all other services If requested sooner than three (3) business days.
On Premise Collection Charge ................................................................................................................. $41
Customer Initiation Charge (without non-jurisdictional service)- Company Read Meter ....................... $46
Customer Initiation Charge (without non-jurisdictional service) - other than
Company Read Meter........... :.....................................................................................................................$4
Customer Initiation Charge (with non-Jurisdictional service) .................................................................... $37
Other Special Services ................................................................................................................. Actual Cost
Charges will be based on actual time required to perform service and will include the currently
effective charges for labor, vehicles overheads and materials:
The Customer Initiation charge shall not apply to service to builders of residential homes who
request temporary service, to landlords who have executed a landlord/tenant agreement with the
Company, or to LGS1/LGS2, rs1rrs2 or LVTS Customers. The Company may waive the
Customer initiation charge for good cause.
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No. PUE-2014-00020
FIRST REVISED SHEET NO. 463
SUPERSEDING
ORIGINAL SHEET NO. 463
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
GENERAL TERMS AND CONDITIONS
ALL RATE SCHEDULES
(continued)
20. INFRASTRUCTURE RELIABILITY AND REPLACEMENT ADJUSTMENT
The Company's Infrastructure Reliability and Replacement Adjustment ("IRRA") is
Implemented as a component of the Company's SAVE Plan pursuant to the Steps to
Advance Virginia's Energy Plan Act. The IRRA Is comprised of an Infrastructure
Replacement Current Rate ("IRCR"), which includes a return on investment, revenue
conversion factor, depreciation and property taxes, associated with eligible infrastructure
costs, and an Infrastructure Replacement Reconciliation Rate ("IRRR"), which includes
carrying costs.
The IRRR will be computed by rate schedule at the conclusion of each year of the SAVE
Plan as the difference between the actual collections of the IRCR and actual eligible
Infrastructure replacement costs, plus or minus any under- or over-recovered IRRR from
the previous SAVE Plan year's lRRR billing period. The results of that calculation will be
divided by, the estimated number of bills for the IRRR billing period to derive the IRRR
applicable during the IRRR billing period.
The IRRA will be equal to the IRCR plus or minus the IRRR to be effective with the first
billing unit for January of each year of the SAVE Plan. For each year of the SAVE Plan, the
IRRA will be billed monthly and shown as a line item on customer bills. The IRRAs for
each rate schedule are set forth in Rate Sheets 3, 3A, 4 and 4A of the Company's currently
approved tariff.
The calculations of both rates along with the supporting detail and workpapers will be filed
annually with the State Corporation Commission. Customers receiving service under Rate
Schedules RS, RTS, MPS, PDS, SGTS1, SGTS2, SGTS3, SGS1, SGS2, SGS3, ACS,
ACTS, LGS1/LGS2, TS1/TS2 and EDS will be subject to the IRRA.
Making Access to Natural Gas Infrastructure Now (MAIN) Rider
The Company's Making Access to Natural Gas Infrastructure Now Rider ("MAIN Rider") is
implemented as a component of the Company's System Expansion Program pursuant to the
Natural Gas System Expansion Infrastructure Act. Any customers taking service under Rate
Schedules RS, RTS, SGS-1, SGS-2, SGTS-1, SGTS-2, ACS, or ACTS, at premises which
benefits from "eligible system expansion infrastructure" (as that term is defined in Va. Code §56610) shall be subject to and billed the MAIN Rider in a fixed amount of $6.63 per month for a
period of 240 months from the date natural gas service is provided to such premises, unless such
period or amount is modified by the Virginia State Corporation Commission. The Company w!ll
accumulate "eligible expansion investment" (as that term Is defined in Va. Code §56·610) in the
System Expansion Program for a period the lesser of (I) five years beginning with the initial
program Investment or (Ii) until the maximum level of suoh investment approved by the Virginia
State Corporation Commission, is reached.
ACCEPTED FOF~ FILING
DIVISION OF ENERGY REGULATION
ST.ti.TE COl~POH/\T/ON COMMISSION
MAR 2 l1 2016
Effective Date: June 1, 2016
Per February 19, 2016 Flnal Order in Case No. PUE·2015·00056
COLUMBIA GAS OF VIRGINIA, INC.
GAS TARIFF
SEVENTH REVISED VOLUME NO. 1
Accepted for Filing
Janaury 21, 2016
Division of Energy Regulation-sec
&~
.{
\
;'
j
Original Shee1 Nos. 464 through 499 of this Tariff are reserved for future use:
Effective Date: February 1, 2016
Per August 21, 2015 Final Order in Case No, PUE-2014-00020