Re: Performance Bnsed Rntemnking (“‘PBR ’‘ No.psc.ky.gov/PSCSCF/Post Case Referenced...
75
a BPL company Louisville Gas and Electric Company State Regulation and Rates 220 West Main Street PO Box 32010 Louisville, Kentucky 40232 Jeff DeRouen, Executive Director Public Service Coinmission of Kentucky 2 1 1 Sower Boulevard P.O. Box 6 15 Frankfort, Kentucky 4060 1 June 29,2012 Re: Performance Bnsed Rntemnking (“‘PBR ’‘ Case No. 2001-0001 7) Dear Mr. DeRouen: As directed in the Commission’s Order in the above-cited case dated October 26, 2001, and reaffirmed in its Orders dated May 27, 2005, in Case No. 2005- 00031 and April 30, 2010, in Case No. 2009-00550, Louisville Gas and Electric Company (“LG&E”) encloses herewith an original and four copies of the PRR quarterly activity report. This report is a summary of LG&E’s activity under the PBR mechanism for the period begiilning November 1 , 201 1 and ending April 30, 2012, and includes data and supporting documentation for the entirety of PRR Year 15 (November 1 , 201 1 through October 3 1 , 2012). The report includes the following: 1. The non-labor related O&M costs incurred to implement the PBR mechanisms, 2. The results of LG&E’s activity under the PBR. If you have any questions regarding this matter, please contact Clay Murphy, Director of Gas Management, Planning, and Supply at (502) 627-2424. D Sincerely, www.lge-ku.com Robert M. Conroy Director. Rates T 502-627-3324 F 502-627-3213 [email protected] U Robert M. Conroy Enclosures
Transcript of Re: Performance Bnsed Rntemnking (“‘PBR ’‘ No.psc.ky.gov/PSCSCF/Post Case Referenced...
a BPL company Louisville Gas and Electric Company State Regulation and Rates 220 West M a i n Street PO Box 32010 Louisville, Kentucky 40232
Jeff DeRouen, Executive Director Public Service Coinmission of Kentucky 2 1 1 Sower Boulevard P.O. Box 6 15 Frankfort, Kentucky 4060 1
June 29,2012
Re: Performance Bnsed Rntemnking (“‘PBR ’‘ Case No. 2001-0001 7)
Dear Mr. DeRouen:
As directed in the Commission’s Order in the above-cited case dated October 26, 2001, and reaffirmed in its Orders dated May 27, 2005, in Case No. 2005- 00031 and April 30, 2010, in Case No. 2009-00550, Louisville Gas and Electric Company (“LG&E”) encloses herewith an original and four copies of the PRR quarterly activity report. This report is a summary of LG&E’s activity under the PBR mechanism for the period begiilning November 1 , 201 1 and ending April 30, 2012, and includes data and supporting documentation for the entirety of PRR Year 15 (November 1 , 201 1 through October 3 1 , 2012).
The report includes the following:
1. The non-labor related O&M costs incurred to implement the PBR mechanisms,
2. The results of LG&E’s activity under the PBR.
If you have any questions regarding this matter, please contact Clay Murphy, Director of Gas Management, Planning, and Supply at (502) 627-2424.
D Sincerely,
www.lge-ku.com
Robert M. Conroy Di rector . Rates T 502-627-3324 F 502-627-3213 [email protected]
U Robert M. Conroy
Enclosures
Activity Under LG&E’s Performance-Based Ratemalting (“PBR”) Mechanism for February, March, and April 2012
Attached is a summary of LG&E’ s activity under tlie PBR meclianism for February, March, and April 20 12 of PBR Year 15 (November 1, 20 1 1 , tliroiigli October 3 1, 20 12) of LG&E’s gas supply cost PRR nieclianism. In accordance witli tlie Order in Case No. 2009-00550 dated April 30, 2010, LG&E is malting this quarterly filing.
In each of these quarterly reports, LG&E is supplyiiig tlie Public Service Commission (“Comiiiissioii”) witli iiiforiiiatioii wliicli is pertinent to the particular quarter. Also enclosed is tlie supporting docuineiitatioii related to tlie PBR calculations.
General Discussion:
The results for tliis quarter cannot and should not be extrapolated for tlie remainder of tlie 20 1 1 /20 12 PBR period. Savings or expenses may occur wider the PRR in later months wliicli iiiay offset tlie expenses or savings experienced to date.
Tlie results shown in this filing coinpare tlie various calculated benchinarks against actual gas costs for each PBR component by montli. The actual gas costs and voltiiiies set forth lierein do iiot correspond to the dollars and volumes actually boolted and repoi-ted by LG&E as purchased gas costs for tlie month as reported in LG&E’s Gas Supply Clause (“GSC”). Tlie actual costs and voluiiies used herein reflect adjustments made to LG&E’s costs aiid voluiiies, iiot in tlie month tlie adjustments were made aiid boolted, but in tlie iiioiitli for wliicli tlie adjustments are applicable. As billing or volumetric adjustiiients occur, the results set forth herein may be modified. If they occur at all, these adjiistiiients are not expected to be significant.
PBR-Gas Acquisition Index Factor (“GAIF”) is an iiicentive meclianisiii for gas coiiiiiiodity costs, Under tliis component, LG&E bencliiiiarlts its gas coiiiiiiodity costs against a calculated benclimarlt representative of tlie marltet price of gas by using various industry-accepted price postings. Factors affecting LG&E’s perforniaiice wider this portion of tlie PBR iiiecliaiiisni are discussed below.
Ptirchnsinn Pimtices nnd Str*cite,w’ LG&E has sought to generute sciviiigs iinder the PBR niechnnisiii by (1) nggressively nznnnging gas supplies to ensure that piirclinses will be ninde at less thnn cpplicnble gas szq7ply indices, (2) purchcrsing gas nt cupcicity- constmined points at which points nnttiral gns is tyjJically priced ut less thnn the sefireiiced indices, (3) mnxinzizing the use of LG&E ’s on-systenz stornge and off-system coiitrnct stornge by ciccelerntiiig or defeiv-ing iizjections (or withdrntvals) in order to iiicixiiiiize scivings under the PBR iiiechniiisiii, nnd (4) taking crclioiis in order. lo mitignte expenses uiider the HRF component of the GAIF L,G&E has not used any $nnncinl inslrzinzeiits to dcite in yiimziing its objectives iinder the PBR iiieclinnisni.
1
One of the indices used to bencliiiiarlc gas costs uiider this portion of the gas supply cost PBR meclianism failed to post for February 20 12. Specifically, “Inside FERC’s Gas Marlcet Report first-of-the-inoiitli posting for Texas Gas Zone SL” did not post an iiidex price for tliat month. Instead, LG&E used tlie first-of-the-moiitli posted price from tlie same publication for Texas Gas Zone 1 . LG&E believes that, since tlie failure only occurred for a single inoiitli, this substitution is botli reasonable and conservative as tlie price postiiigs for Texas Gas Zone 1 teiid to be lower tliaii Texas Gas Zone SL. In short, the temporary substitution teiids to widerstate any savings that may occiir uiider the meclianisiii by lowering the overall benchmark.
PRR - Transportation Index Factor (“TIF”) is an incentive mechanism for pipeline traiisportatioii costs. With this component, LG&E benclimarlcs its pipeline transportation costs against tlie transportation rates filed with tlie Federal Energy Regidatory Conimission (“FERC”) by either Texas Gas Transmission, L,LC (“Texas Gas”) or Teiiiiessee Gas Pipeline Coiiipaiiy (“Tennessee”), as applicable.
Pwchnsing Practices cind Stmtem. LG&E has s o ~ i g h ~ to ens~ire that stivings reszilt zinder the PBR inechnnisnz by (1) ciggressively negoliating pipeline discotints, and (2) releasing piixline capacity when not required by L,G&E to serve its czislonzers Factors qicf‘?cfiiig LG&E’s per~f~rmaiice zinder this portion of the PRR niechanism tire disczused below.
Texas Gas Trcinsinission LLC Rate Case. The rates chcirged by Texas Gas are final rates and are not being billed subject to rejiind.
Tennessee Gcis Pijxline Coni~nnv: The safes charged by Tennessee Gas are I final rates and are not being billed subject to wfiind.
PBR - Off-System Sales Index Factor (“OSSIF”) is an iiiceiitive mechanism for off- system sales. L,G&E may be in a position to sell natural gas or transportation services or botli above cost.
OfflSysteni Sales Activitv LG&E made ofj-system sales during the PBR period wiien t i le oppor 1 unity asose to generate savings, and LG&E had natzrml gas cinder contract and aveiilable for sale These off-system sales were iiiade to entities which are not affiliated ivith LG&E.
Information Required to be Reported: As required by tlie Commission, the followiiig iiiforiiiation is being supplied as a part of this filing.
Ccilczilated Reszilts During the 6 niontlis ended April 30, 201’2, LG&E hcis cichieved the following res lilts
2
P BR - GA IF PBR - TIF PBR - OSSIF Total
Nov. 2011 $389,638 $486,705 $0 $876,343 nec. $740,702 $491,849 $0 $1,232,551 Jan. 2012 $709,913 $492,678 $0 $I,202,5 91
Qlr Szibtotnl $ I 840,253 $ I ,4 71,232 $0 $3,31 I , 485
$572,358 $483,683 $0 $1,056,041 $405, I32 $482,443 $0 $88 7,5 75 $ I 19,633 $504,69 7 $0 $624) 330
Qlr Sz1btotul $I,097, I23 S I , 470,823 $0 $2,567,946
Torn1 $2,93 7,3 76 $2,942,055 $0 $5,879,431
The supporting cnlczilcrtions are enclosed with this.filing
Lobor nnd 0perotin.r n i d Mnintennnce (“O&M”) Costs The PBR mechanism reqiiires that LG&E exclude labor-related or other expenses typically classified as O&M expenses from the determination of any savings or expenses under the PRR mechanism. LG&E is required to report on a quarterly basis any costs reqiiired to iniplemeiit the PRR mecliaiiism. Inasmiicli as such costs cannot be shared between Coiiipaiiy and Customer, LG&E has sought to minimize iiicrernental costs. L,G&E has not incurred any significant quantifiable costs dririiig the period covered by this quarterly report for activity uiider the PBR mechanism.
3
PRR CALCULATIONS FOR THE 6 MONTHS ENDED APRIL 30,2012
PBR-GAIF SUPPORTING CALCULATIONS
PBR-GAIF CALCULATION OF BENCHMARK GAS COSTS
(“BGC”)
PRR-GAIF CALCULATION OF ACTUAL GAS COSTS
(" AGC 9 9 )
PBR-GAIF CALCULATION OF SAVINGS AND/OR EXPENSES
m
N
T-
E 3 0
- 0
PBR-GAIF INDICES
PBR-GAIF INDICES
TEXAS GAS - ZONE SL
u
a, v)
3
T
I-
? L e
w
bN
om
om
oo
oo
oo
a
v-N
cn
bo
oo
oo
oo
(9
am
Od
m0
00
00
00
m
mc
ic
ic
ic
io
oo
oo
o
3 w
N~
mw
ao
oo
oo
0
eeeeeeeeeeee
2 c
(J --I
0 0
0
0
0
0
0
0
0
0
'0 0
0
00
00
00
00
00
0
-o
Nm
-w
oo
oo
oo
w
w
mw
oa
w~
oo
oo
qo
u
-z
m~
mc
ic
iN
od
oo
oo
w
o eeeeeeeeeV
3ee
-0
a, v) 0
rl
U
a, s A
- m
? 8 I- ? L
P h
a, 0
"_
m 0
CL W
k
c
2 LL 0
Z 0
F 4
Y z)
Q 0
0
0
0
8 69
00
00
0
00
0
00
00
8?88 69696969
0
0
0
8 69
0
0
0
8 69
00
00
0
00
00
0
00
0
00
00
0
00
00
0
00
00
0
00
0
00
00
0
0000
69696969 00000
69
69
w3
69
69
0
0
0
0
0
69
0
0
0
8 69
00
00
0
00
0
00
00
0
00
0
00
00
0
00
0
00
00
0
00
0
69696969
69
69
69
w3
99
9P
9999
NN
NN
2
22
2
NN
NN
00
00
0
00
0
Na
am
69696969
-???;
00
00
0
00
00
0
00
0
00
00
0
00
00
0
00
0
ba
mc
s)
Cn
om
-co
-
Na
N
mm
oa
C
nc
s?
b.q
u?
b
mm
a
0
0
0
8 69
00
00
0
00
00
0
00
00
0
88
88
8
6969696969
22
22
2
00
00
0
-co
mC
\lcn
O
OT
-N
N
00
00
0
Q!Q
!Q!Q
!Q!
..... .T
.T
TT
I-
0
N
w
00
00
0
00
00
0
00
0
00
00
0
oT
-mc
o
0c
oc
nm
.i-
NN
NN
N
T-.r-N
69696969
6969696969
”N
99
9
c”
09
?9
NN
NN
U
n
W
00
00
0
mm
mm
o
wm
-0
0
oo
mo
o
N
d
00
00
0
omooo
dr
mm
o
NN
N
NN
NN
N
NN
NN
00
00
0
mmomm
ni r?
"cu
77
77999
$17 ...
6969
6969696969
6969696969
69
6969696969
6969696969
69696969
696969
€I3
t9
00
00
0
00
00
0
oc
oo
wc
o
ffc4
'it.f N
NN
NN
6969696969
6969696969
6969fE-69
696969
69
69
00
00
0
00
00
0
OJ
Wc
od
h
2w
0
00
0
00
cn
00
00
0
00
0
dc
nb
b
d
d
00
00
0
00
00
0
-L
Dc
nT
-b
NN
NN
N
u?
ff
u?
f
w
00
00
0
00
db
WW
m
oo
0
b
00
0
00
00
0
00
00
0
00
00
0Nb-m
00
0
NN
N
f""
69-69
6969696969
6969696969
69696969
696969
69
e3
d
PBR-GAIF INDICES
TEXAS GAS - ZONE 1
ma
mr
~N
00
00
00
l
.O
-o
3m
-b
00
00
00
$
o3
ot-.a
co
bo
oo
oo
o
Q
NN
t-
.m
Na
00
00
00
0-
0
00
00
00
00
00
0
flrw
00
00
00
00
00
00
wz
~
~o
q~
oo
oo
oo
o
u-
0
mm
mN
NN
00
00
00
y1)1
696969696969696969696969
d-
aT
-m
ac
no
oo
oo
o
mN
co
co
6l.
Oo
oo
oo
o
Nl.Om0ab000000
oa
aa
cu
-0
00
00
0
N-
~d
--
cn
00
00
00
2
0
z W
QU
I5
AyQI
00
00
0
00
0
00
00
0
00
00
0
00
0
00
00
0
00
00
0
00
0
00
00
0
00
00
0
00
0
00
00
0
<W
Zt
-
00
00
0
00
0
00
00
0
00
00
0
00
0
00
00
0
CL
uQ
K o
oo
o
oo
oo
O
oo
OO
O
OO
O OoqO
OO
oo
o
tfttfttfttft tfttfttfttf)
tf
ft
ft
tf
tt
ft
e
tfttfttfttft tfttfttfte
tfttfttfttft-
~3
6~
0
00
0
00
00
0
00
00
0
00
0
00
00
0
00
00
& 0
CL
z3
9
Q
LL 0
Z
0
I= 4 Y 3
Q
0
c6 69
0
0
2 oj tft
0
-3
N
o! r
tft
0 0 loo 5: R E ? 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ornooln ornoln oolnlno
m b m w o d - w w o m N W O W br.. - wCoor. . (D N d - l n W W o W o w
1 g : 8 %
6969 6969696969 6969696969 6969696969 696969fB
0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
m o - N c c v r o r n b * m b m W l n b W C 0
o m m m m o m m o m
6969fB6969 6969696969 69696969fB fB696969
"7-99 C?z=?zs v?zz 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
m m xxY?xx cy=?V=?zz V???zz v=?zz
"f"""
0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 W W o o W I n b - C n W l n ood-0- a l n c t m
6969 fBfec f3 -6969 69fB696969 6969696969 69696969
t. r c v o * l n W r . . w o O r N m ~ l n W ~ w o O - c v m 6 l n W b W o o ~ ---~-V-r-r-cvcvcvNcvNNNcvcvm~ 2
69 69
69 fB
69 fB
00
00
0
mmomo
8 0
00
00
o
mo
ln
o
ob
mc
vw
N
NN
NN
wo
mm
o
w
00
00
0
mln
lnm
m
NN
N
NN
N-
00
00
0
mm
lnm
o
mm
v~
a
-.900o!
00
--
0
%?
p:
2 d
6469
69C)EF)696969
6969696969
6969696969
6969696969
69
00
00
0
0
00
00
0
0
N-
dr
N
W
00
00
0
00
00
0
ma
dd
N
00
-rT
-
00
00
0
00
00
0
Ln
Nc
od
-N
NN
NN
N
00
00
0
00
00
0
ma
bN
w
nin
iniN
hj
NN
NN
N
b
d
TT
TT
7
NN
NN
N
6969696969
6969696969
6969696969
€e69696969
69
00
00
0
00
00
0
ow
co
ac
o
0-
00
0
?
00
00
0
8 M
rr
.0
00
00
00
0
mo
Nw
w
0
d
6969
6969696969
6969696969
6969696969
6969696969
69
00
00
0
00
00
0
bc
oN
rd
0
00
00
0
00
00
N
bm
-b
NN
NN
-
7900o!
p~w=?;~
py
zp
2
W?Z
Z
d
co 2
ni
69
co 0
d
T-
N
69
ni
69
6969696969
6969696969
69696969
696969
69
69
I I
PRR-GAIF INDICES
TEXAS GAS - ZONE 4
I-
I
I- Z
0
2
U
0
Z
0
F 4 2 3 6
0
0
69
JY
Z~
0
00
0
00
00
ooooo
00
00
0
00
0 ooooo
00
00
0
00
0
00
00
0
00
00
0
00
0
00
00
0
00
00
0
00
0
00
00
0
00
00
0
00
0
00
00
0
69696969
69696969
6969696969
69696969
69696969
6969Ef)6969
Qw
o=
0
00
0
00
00
0
00
00
0
00
0
00
00
0
00
00
K
WZ
I:
0000
0cJ00 00000 0000 0000 0000q
?Sa
acnm
0
0
m
2 69
0
0
0
2 69
0
0
.r
:
69
0
m
00
00
0
00
00
g
g
g E
8
22
c,
-&
2 d
-m
m
W
mo
o0
oomoo
mm
Nb
W
-m
od
-
NN
NN
N
NN
NN
00
00
0
00
00
o
mo
ln
o
0r
.m
r.
o
NN
mN
N
c?"c9r-r- r-rn
Cq
Y
m
01010cqcq 0
99
01
m
mm
N
z
T-
T-
0
N
6969696969
6969696969
69ff3696969
69696969
'i-
N
oj W
69
69
69
T-
r. N
s 69
69
z
N
0
N
T
00
00
0
mm
om
m
00
00
0
mm
rb
b
ommoo
mm
mb
m
NN
NN
N
NN
NN
N
00
00
0
om
00
0
rW
T-
b.
0
00
00
0
omomo
NW
bO
W
mw
N
N
NN
NN
N
9--7-
9Tr.99
3 %
%
-?
""?
"
3>
116
zu 6969
6969696969
6969696469
6469696969
6969696969
n
00
00
0
00
00
0
00
00
0
WT
NO
W
00
00
0
bm
rw
w
NN
NN
N
NN
NN
N
00
00
0
00
00
0
NO
NO
W
NN
NN
N
00
00
0
00
00
0
mo
wr
m
00
9-(u
rl-
o
(u
r-0
c
uC
u7
-0
U
w d 69
0
0
Fr! w d 69
m
d
0
x 69
m
0
N
x b
b
W
.r
hi
64
PBR-GAIF INDICES
TENNESSEE - ZONE 0
go
00
00
00
00
00
00
0
00
00
00
00
00
0
gw
~
~~
~~
~0
00
00
0
wz
Y
j-
N0
mY
j-
00
00
00
0
u-
0
c4
c4
c4
~n
jn
jd
00
00
0
gry
*e**eeee*#e*
0
N
(3)
co
m
N
0, d
nj
69 n
j 69
0
0
m
0
0
N
cs? -i-
fB
U
>. 2 (I)
F
(I)
B
6969696969
6969696969
6969696969
69696969
69
69
00
00
T-m
co
m
d
00
00
8
%
00
00
0
00
00
0
mo
mm
m
co -
00
00
0
00
00
0
m-m
co
m
00
00
0
00
00
0
ommom
7999
Q?
?z?
z ?J
.zz
2 ri
00
00
8
Ki 3
a
mm
s
r! xzV
-?zz -9
99
01
zz??zz
o?v?$z 2
ri
xm
mm
m
W
2;;;. 6969696969
6969696969
6969696969
69696969
69 69
00
00
0
00
00
0
T-cot.r..m
00
00
dr.0
- 0
(D
00
00
0
00
00
0
mw
T-
mN
T
-
T-
00
00
0
00
00
0
mc
oc
od
m
mm
mm
w
6969
6969696969
6969696969
6969696969
69696969
69
69
6969696969
e969696969
696969
696969
69
69
6969696969
6969696969
696969
696969
69
69
a 0
PBR-GAIF INDICES
TENNESSEE - ZONE 1
~o
oo
mo
oo
oo
oo
N
mN
mr
.N
00
00
00
r-
co N
m r. d
0
0
0
0
0 0
-
?r
r-
m-
r-
ao
oo
oo
o
eeeeeeeeeeee
cc
icc
ip.j~
p.jc
oo
oo
oo
0
0
0
8 69
0
0
0
8 69
0
0
0
8 69
0 0
0
8 69
0
0
0
8 69
0
0
0
8 69
00
00
0
00
00
0
00
00
0
00
00
0
00
00
0
00
0
00
00
8
88
8
69696969
00
00
0
00
0
00
00
8
88
8
69696969
00
00
0
00
00
0
00
00
0
6969696969
82
88
8
00
00
0
00
0
00
00
00
00
69696969
c?
99
9
00
00
0
00
0
00
00
00
00
69696969
99
99
00000
6969696969
NN
NN
I- 3
6 0
4 Y
22
22
2
0
0
m
x w
R
00
00
0
NO
W-
N
W
d
00
00
0
mo
WW
N
ooooo
ooomm
oommo
WN
CO
CO
O
00
00
0
mom00
dc
no
mo
m
rr
-r
9
79
99
N
NN
NN
N
NW
\I
NN
4
nj
nj
nj
nj
N
NN
NN
x
7-999
b9
W
m
h
PBR-GAIF INDICES
DELIVERY AREA INDEX (“DAI”)
W
0
Q
:
u- 0
Z
0
F
4
Y 3
Q 0
0
0
0
8 69
0
0
0
8 69
00
00
0
00
0
00
00
0
00
0
00
00
0
00
0
00
00
0
00
0
0000
69696969 0000
69696969
0
0
0
8 69
00
00
0
00
00
0
00
00
0
00
00
0
69696969tff
99
99
9
0
0
0
8 69
00
00
0
00
0
00
00
69696969
88
88
0
69
0
0
0
8 69
00
00
0
00
00
0
00
0
00
00
0
00
00
0
00
00
0
00
0
00
00
0
0000
6969tU69 00000
6969696969
u3 b
0
x tff u3 b
b
x 69 u3 b
m
N
69
c9
0 0
m
:
69
22
22
r
r
0
N
ct W
m
Zi w
Y n
U
2. 8
00
00
mo
cn
r- 0
00
00
0
00
00
0
-
o~
-m
cn
~ m
oo
cn
w
co
bc
om
- m
mm
mm
m
mm
mm
m
mm
m
00
00
0
00
00
0
00
00
0
00
00
0
00
00
dN
N.r
-
-7
-T
N
ON
-9
.?4;44
o :
B I- o
u-
0
00
00
0
00
0
00
00
0
00
mm
m
mm
mm
m
00
00
0
00
00
ooooo
ON
-r
-0
r
-r
-m
cn
N
mr
-
70
-
C?
c\lrlN
c\!
= q mz
?Tf?T$$
z
00
00
0
g 2
8%
z
00
00
0
8
8 8
% z
zs
00
00
0
0
883
ooooo
00
00
0
2
I;-
ooooo
Od
Wr
nO
r
-m
r-
r-
a
- 3
c”c
”c”?
c”
a?zV?zz
ma
N
o
lno
lnln
0
00
00
0010ln
ln
rn
Wr
-d
N
cncococoS
-
00
00
0
oo
oln
o
Or
r-
OW
NNNr-
00
00
0
01
00
Lo n
io
c
”?c
”c”c
” w
??zni -
T-
rT
--
rro
c”.C
n
6949696969
6969696949
6969496969
69
69
69
d-
ln
00
00
0
00
00
0
Wc
oc
nW
ln
~o
mo
cn
c
”o
or‘7
T
-N
NN
N
ni
-
ooooo
00
00
0
00
00
0
d-m
co
wc
o
NN
NN
T-
?c”c”c”c“ Y
T-r
-i-?
rr9
9c
”
d- z
69696969
6969696469
6949696969
6969696969
69
69
69
0
00
00
0
00
00
0
Wc
nW
r-
W
‘7
ni
o
d- T
-T
-T
-r
T-
c?z=?zz
69694969
6969696969
6969696969
6969696969
69
69
69
6969696969
6969696969
6969696969
6969694969
69
69
4969696969
6949696969
6969696969
6969496969
49 69
?
00
0
00
0
0)
Wd
N
m
0
00
0
00
00
ln
-a
i-
NN
NN
00
00
0
00
00
0
CO
b-
Wc
o
00
00
0
00
00
0
Wr
nc
od
-W
NN
NN
N
(4
kk
(4
k
Lo
cq
kc
qc
q
4.
696969
6969696969
6949496969
69696949
696969
69 69
00
0
88%
z W
co
00
0
r-
m-
0
00
0
00
00
m
co
r-m
00
00
0
00
00
0
dd
-W
Nm
0
00
00
0
00
00
T
-w
CY
or
+3
0
00
k
00
0
y?: V
??ZZ V?JF-?zz
v!zz
(??Z 7
29
O
WO
Y
ln
~l
696969
6969694969
6969696969
69696949
696969
69
69
PBR-GAIF CALCULATION OF
SUPPLY ZONE FIRM QUANTITY ENTITLEMENT PERCENTAGE
(“SZFQEP”)
PRR-TIF SUPPORTING CALCULATIONS
PBR-TIF CALCULATION OF BENCHMARK GAS
TRANSPORTATION COSTS (" I3 M GT C " )
C
; zn
t C
m
h
dl
I
PBR-TIF CALCULATION OF ANNUAL ACTUAL GAS
TRANSPORTATION COSTS (‘“AAGTC”)
s 6 2 1- b u)
m
z
2
0 0
3
0- w- w-
0- b- m-
mw
wm
mw
m
mc
9m
mm
6
9cf+
eE
F)w
cf+
PBR-TIF CALCULATION OF SAVINGS AND/OR EXPENSES
c"
I- It: (I) C3 Z
2 (I)
N
z 3
0 0
3
(3- hi
N- N
N
- cececececern
PRR-TIF TARIFF SHEETS
PBR-TIF TEXAS GAS TARIFF SHEETS
RATE NNS
Texas Gas Transmission, LLC FERC NGA Gas Tariff Fourth Revised Volume No. 1 Effective On: October 1, 201 1
Section 4.4 Currently Effective Rates - NNS
Version 4.0.0
Currently Effective Maximum Transportation Rates ($ per MMBtu) For Service Under Rate Schedule NNS
Zone SL Daily Demand Commodity Overrun
Daily Demand Commodity Overrun
Daily Demand Commodity Overrun
Daily Demand Commodity Overrun
Daily Demand Commodity Overrun
Zone 1
Zone 2
Zone 3
Zone 4
Base Tariff Rates
(1)
0.1800 0.0253 0.2053
0.2782 0.0431 0.3213
0.3088 0.0460 0.3548
0.3543 0.0490 0.4033
0.41 90 0.0614 0.4804
FERC ACA
(2)
0.0018 0.0018
0.0018 0.0018
0.0018 0.0018
0.0018 0.0018
0.0018 0.0018
Currently Effective
Rates (3)
0.1800 0.0271 0.2071
0.2782 0.0449 0.3231
0.3088 0.0478 0.3566
0.3543 0.0508 0.4051
0.41 90 0.0632 0.4822
Minimum Rate: Demand $-0-; Commodity -Zone SL 0.0163 Zone1 0.0186 Zone2 0.0223 Zone3 0.0262 Zone4 0.0308
Notes:
- The maximum reservation charge component of the maximum firm volumetric capacity release rate shall be the applicable maximum daily demand rate herein pursuant to Section 6.16 of the General Terms and Conditions.
- For receipts from Duke Field Services' Carthage Plant/Gulf South Pipeline Company, LP, Enbridge Pipelines, L.P./Gulf South Pipeline Company, LP, Energy Transfer Company/Gulf South Pipeline Company, LP, and Enterprise Texas Pipeline L.P./Gulf South Pipeline Company, LP interconnects in Panola County, Texas, Customer shall pay an incremental transportation charge of:
Daily Demand $0.1288 Commodity $0.0068 Overrun $0.1356
These receipt points are available to those ciistomers agreeing to pay the incremental rate(s) applicable to such points and are not available for pooling under Rate Schedule TAPS.
PRR-TIF TEXAS GAS TARIFF SHEETS
RATE FT
Texas Gas Transmission, LLC FERC NGA Gas Tariff Fourth Revised Volume No. 1 Effective On: October 1, 201 1
Section 4.1 Currently Effective Rates - FT
Version 5.0.0
Currently Effective Maximum Daily Demand Rates ($ per MMBtu) For Service Under Rate Schedule FT
Currently Effective Rates [I]
SL-SL SL-1 s L-2 SL-3 SL-4 1-1 1-2 1-3 1-4 2-2 2-3 2-4 3-3 3-4 4 -4
0.0794 0.1552 0.21 20 0.2494 0.3142 0.1252 0.1820 0.21 94 0.2842 0.1332 0.1705 0.2334 0.1181 0.1810 0.1374
Minimum Rates: Demand $-0-
Backhaul rates equal forward haul rates from Zone SL to zone of delivery; provided, however, that intra-zone rates shall apply to intra-zone transportation, whether such intra-zone transportation is forward haul or hackhaul.
[I] Currently Effective Rates are equal to the Base Tariff Rates
Notes:
- The maximum reservation charge component of the maximum firm volumetric capacity release rate shall be the applicable maximum daily demand rate herein pursuant to Section 6.16 of the General Terms and Conditions.
- For receipts from Duke Field Services' Carthage Plant/Gulf South Pipeline Company, LP, Enbridge Pipelines, L.P./Gulf South Pipeline Company, LP, Energy Transfer Company/Gulf South Pipeline Company, LP, and Enterprise Texas Pipeline L.P./Gulf South Pipeline Company, LP interconnects in Panola County, Texas, Customer shall pay an incremental Daily Demand charge of $0.1288. These receipt points are available to those customers agreeing to pay the incremental rate(s) applicable to such points and are not available for pooling under Rate Schedule TAPS.
Texas Gas Transmission, LLC FERC NGA Gas Tariff Fourth Revised Volume No. 1 Effective On: October 1, 201 1
Section 4.1 Currently Effective Rates - FT
Version 5.0.0
Currently Effective Maximum Commodity Rates ($ per MMBtu) For Service Under Rate Schedule FT
SL-SL SL-1 SL-2 SL-3 SL-4 1-1 1-2 1-3 1-4 2-2 2-3 2-4 3-3 3-4 4-4
Base Tariff FERC Rates ACA
(1 1 (2)
0.01 04 0.0355 0.0399 0.0445 0.0528 0.0337 0.0385 0.0422 0.0508 0.0323 0.0360 0.0446 0.0312 0.0398 0.0360
0.0018 0.0018 0.001 8 0.0018 0.001 8 0.0018 0.0018 0.0018 0.0018 0.0018 0.001 8 0.0018 0.001 8 0.001 8 0.0018
Currently Effective
Rates (3)
0.0122 0.0373 0.0417 0.0463 0.0546 0.0355 0 0403 0 0440 0.0526 0.0341 0.0378 0.0464 0 0330 0 0416 0 0378
Minimum Rates: Commodity minimum base rates are presented in Section 4.12.
Backhaul rates equal forward haul rates from Zone SL to zone of delivery; provided, however, that intra- zone rates shall apply to intra-zone transportation, whether such intra-zone transportation is forward haul or backhaul.
Notes
- For receipts from Duke Field Services‘ Carthage Plant/Gulf South Pipeline Company, LP, Enbridge Pipelines, L.P./Gulf South Pipeline Company, LP, Energy Transfer Company/Gulf South Pipeline Company, LP, and Enterprise Texas Pipeline L.P./Gulf South Pipeline Company, LP interconnects in Panola County, Texas, Customer shall pay an incremental Commodity charge of $0.0068. These receipt points are available to those customers agreeing to pay the incremental rate(s) applicable to such points and are not available for pooling under Rate Schedule TAPS.
PBR-TIF TEXAS GAS TARIFF SHEETS
FUTE STF
Texas Gas Transmission, LLC FERC NGA Gas Tariff Fourth Revised Volume No. 1 Effective On: July 7, 201 1
Section 4.2 Currently Effective Rates - STF
Version 4.0.0
SL-SL SL-1 SL-2 SL-3 SL-4 1-1 1-2 1-3 1-4 2-2 2-3 2-4 3-3 3-4 4-4
Currently Effective Maximum Transportation Rates ($ per MMBtu) For Service under Rate Schedule STF
Peak (Winter)-Demand Off-peak (Summer)-Demand
Currently Effective Rates [ I1
0.1188 0.2322 0.3172 0.3731 0 4701 0.1873 0.2723 0.3282 0 4252 0.1992 0.2551 0.3492 0.1766 0.2'707 0 2056
Currently Effective Rates r l l
0.0516 0.1009 0.1378 0.1621 0.2042 0.0814 0.1183 0.1426 0.1847 0.0866 0,1108 0.1517 0.0768 0.1177 0.0893
Backhaul rates equal forward haul rates from Zone SL to zone of delivery; provided, however, that intra- zone rates shall apply to intra-zone transportation, whether such intra-zone transportation is forward haul or backhaul.
Notes:
- The STF commodity rate is the applicable FT commodity rate in Section 4.1, The STF overrun rate equals the daily demand rate plus applicable FT commodity rate. Minimum rate: Demand $4- The minimum commodity rate is presented in Section 4.12.
- For receipts from Duke Field Services' Carthage PIanVGulf South Pipeline Company, LP, Enbridge Pipelines, L.P./Gulf South Pipeline Company, LP, Energy Transfer Company/Giilf South Pipeline Company, LP, and Enterprise Texas Pipeline L.P./Gulf South Pipeline Company, LP interconnects in Panola County, Texas, Customer shall pay an incremental Daily Demand charge of $0.1288. These receipt points are available to those customers agreeing to pay the incremental rate(s) applicable to such points and are not available for pooling under Rate Schedule TAPS.
PBR-TIF TENNESSEE TARIFF SHEETS
RATE FT-A
Tennessee Gas Pipeline Company, L.L.C. FERC NGA Gas Tarif f S ix th Revised Volume No. 1
Fifth Revised Sheet No. 1 4 Superseding
Fourth Revised Sheet No. 14
RATES PER DEKATHERM FIRM TRANSPORTATION RATES
RATE SCHEDULE FOR FT-A ___________________________________============= ___-__-__-______---__--------------
Base Reservation Rates DELIVERY ZONE --------------------------RECEIPT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
ZONE 0 L 1 2 3 4 5 6 _______________________________I________--------- - - - - - -"----- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
0 $5.7504 $12.1229 $16.3405 $16.6314 $18.3503 $19.4843 $24.4547 L $5.0941 1 $8.7060 $8.3414 $11.1329 $15.8114 $15.6260 $17.6356 $21.6916 2 $16.3406 $11.0654 $5.7084 $5.3300 $6.8689 $9.4859 $12.2575 3 $16.6314 $8.7447 $5.7553 $4.1249 $6.4085 $11.6731 $13.4872 4 $21.1425 $19.4839 $7.3648 $11.2429 $5.4700 $5.9240 $8.4896 5 $25.2282 $17.6984 $7.7303 $9.3742 $6.0880 $5.7043 $7.4396 6 $29.1846 $20.3275 $13.9551 $15.3850 $10.8692 $5.6613 $4.8846
Daily Base Reservation Rate 1/ DELIVERY ZONE _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ RECEIPT ______1_________11___________I__________------------------------------------------------------------------------
ZONE 0 L 1 2 3 4 5 6
0 $0.1891 $0.3986 $0.5372 $0.5468 $0.6033 $0.6406 $0.8040 L $0.1675 1 $0.2862 $0.2742 $0.3660 $0.5198 $0.5137 $0.5798 $0.7131 2 $0.5372 $0.3638 $0.1877 $0.1752 $0.2258 $0.3119 $0.4030 3 $0.5468 $0.2875 $0.1892 $0.1356 $0.2107 $0.3838 $0.4434 4 $0.6951 $0.6406 $0.2421 $0.3696 $0.1798 $0.1948 $0.2791 5 $0.8294 $0.5819 $0.2541 $0.3082 $0.2002 $0.1875 $0.2446 6 $0.9595 $0.6683 $0.4588 $0.5058 $0.3573 $0.1861 $0.1606
_____-__"__________1____________________-------------------------------------------------------------------------
Maximum Reservation Rates 2 /, 3 / DELIVERY ZONE --------------------------RECEIPT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
ZONE 0 L 1 2 3 4 5 6 ________________________________1_______-------------------------------------------------------------------------
0 $5.7504 $12.1229 $16.3405 $16.6314 $18.3503 $19.4843 $24.4547 L $5.0941 1 $8.7060 $8.3414 $11.1329 $15.8114 $15.6260 $17.6356 $21.6916 2 $16.3406 $11,0654 $5.7084 $5.3300 $6.8689 $9.4859 $12.2575 3 $16.6314 $8.7447 $5.7553 $4,1249 $6.4085 $11.6731 $13.4872 4 $21.1425 $19.4839 $7.3648 $1 1.2429 $5.4700 $5.9240 $8.4896 5 $25.2282 $17.6984 $7.7303 $9.3742 $6.0880 $5.7043 $7.4396 6 $29.1846 $20.3275 $13.9551 $15.3850 $10.8692 $5.6613 $4.8846
Notes: 1/ 2/
3/
Applicable to demand charge credits and secondary points under discounted rate agreements. Includes a per Dth charge for the PC8 Surcharge Adjustment per Article XXXII of the General Terms and Conditions of $0.0000. Includes a per Dth charge for the PS/GHG Surcharge Adjustment per Article XXXVIII of the General Terms and Conditions of $0.0000.
Issued: January 27, 2012 Effective: February 1, 2012
Docket No. R P l l - 1 5 6 6 - 0 0 9 Accepted: Apri l 19, 201.2
Tennessee Gas Pipeline Company, L.L.C. FERC NGA Gas Tarif f Sixth Revised Volume No. 1
Fourth Revised Sheet No. 14 Superseding
Third Revised Sheet No. 14
RATES PER DEKATHERM
$5,7504 $12.1229 $16.3405 $16.6314 $18.3503 $19.4843 $24.4547
$8.7060 $8.3414 $11.1329 $15.8114 $15.6260 $17.6356 $21.6916 $16.3406 $11.0654 $5.7084 $5.3300 $6.8689 $9.4859 $12.2575 $16.6314 $8.7447 $5.7553 $4.1249 $6.4085 $11.6731 $13.4872 $21.1425 $19.4839 $7.3648 $11.2429 $5.4700 $5.9240 $8.4896 $25.2282 $17.6984 $7.7303 $9.3742 $6.0880 $5.7043 $7.4396 $29.1846 $20.3275 $13.9551 $15.3850 $10,8692 $5,6613 $4.8846
$5.0941
Daily Ease Reservation Rate I/ DELIVERY ZONE ____________________- - - - -~ RECEIPT .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
ZONE 0 L 1 2 3 4 5 6
0 $0.1891 $0.3986 $0.5372 $0.5468 $0.6033 $0.6406 $0.8040 L $0.1675 1 $0,2862 $0.2742 $0.3660 $0.5198 $0.5137 $0.5798 $0.7131 2 $0.5372 $0.3638 $0.1877 $0.1752 $0.2258 $0.3119 $0.4030 3 $0.5468 $0.2875 $0.1892 $0.1356 $0.2107 $0.3838 $0.4434 4 $0.6951 $0.6406 $0.2421 $0.3696 $0.1798 $0.1948 $0.2791 5 $0.8294 $0.5819 $0.2541 $0,3082 $0.2002 $0.1875 $0.2446 6 $0.9595 $0.6683 $0.4588 $0.5058 $0.3573 $0.1861 $0.1606
______________________________I_________--"-----------------------"----------------------"---------"-------------
0 $5.7504 $12.1229 $16.3405 $16.6314 $18.3503 $19.4843 $24.4547 L $5.0941 1 $8.7060 $8.3414 $11.1329 $15.8114 $15.6260 $17.6356 $21.6916 2 $16.3406 $11.0654 $5.7084 $5.3300 $6.8689 $9.4859 $12.2575 3 $16.6314 $8.7447 $5.7553 $4.1249 $6.4085 $11.6731 $13.4872
$19.4839 $7.3648 $11.2429 $5.4700 $5.9240 $8.4896 $17.6984 $7.7303 $9.3742 $6.0880 $5.7043 $7.4396 $20.3275 $13.9551 $15.3850 $10.8692 $5.6613 $4.8846
4 $21.1425 5 $25.2282 6 $29.1846
1/ 2/
Applicable to demand charge credits and secondary points under discounted rate agreements. Includes a per Dth charge for the PCB Surcharge Adjustment per Article XXXII of the General Terms and Conditions of $0.0000 Daily Reservation.
Issued: November 10, 2 0 1 1 Effective: November 10, 2011
Docket No. RP12-144-000 Accepted: December 2,2011
Tennessee Gas Pipeline Company, L.L.C. FERC NGA Gas Tarif f S ix th Revised Volume No. 1
Seventh Revised Sheet No. 15 Superseding
Six th Revised Sheet No. 15
RATES PER DEKATHERM
0 $0.0032 $0.0115 $0.0177 $0.0219 $0.2751 $0.2625 $0.3124 L $0.0012 1 $0.0042 $0,0081 $0.0147 $0.0179 $0.2339 $0.2385 $0.2723 2 $0.0167 $0.0087 $0.0012 $0.0028 $0.0757 $0.1214 $0.1345 3 $0.0207 $0.0169 $0.0026 $0.0002 $0.1012 $0.1400 $0.1528 4 $0.0250 $0.0205 $0.0087 $0.0105 $0.0468 $0.0662 $0.1073 5 $0.0284 $0.0256 $0.0100 $0.0118 $0.0659 $0.0653 $0.0811 6 $0.0346 $0.0300 $0.0143 $0.0163 $0.1014 $0.0549 $0.0334
Minimum Commodity Rates 11, 2/ DELIVERY ZONE
ZONE 0 L 1 2 3 4 5 6 . . . . . . . . . . . . . . . . . . . . . . . . . . RECEIPT----------------------------------------~-----------------------------------------------------------------
_________________________1______________------------------"--------------------"-----*---------------------
0 $0.0050 $0.0133 $0.0195 $0.0237 $0.0268 $0.0302 $0.0364 L $0.0030 1 $0.0060 $0.0099 $0.0165 $0.0197 $0.0228 $0.0274 $0.0318 2 $0.0185 $0.0105 $0.0030 $0.0046 $0.0074 $0.0118 $0.0161 3 $0.0225 $0.0187 $0.0044 $0.0020 $0.0099 $0.0136 $0.0181 4 $0.0268 $0.0223 $0.0105 $0.0123 $0.0046 $0.0064 $0.0110 5 $0.0302 $0.0274 $0.0118 $0.0136 $0.0064 $0.0064 $0.0084 6 $0.0364 $0.0318 $0.0161 $0.0181 $0,0104 $0.0059 $0.0038
Maximum Commodity Rates DELIVERY ZONE
L 1 2 3
0 $0.0050 L 1 $0.0060 2 $0.0185 3 $0.0225 4 $0.0268 5 $0.0302 6 $0.0364
Notes:
$0.0133 $0.0195 $0.0237
$0.0099 $0.016S $0.0197 $0.0105 $0.0030 $0.0046 $0.0187 $0.0044 $0.0020 $0.0223 $0.0105 $0.0123 $0.0274 $0.0118 $0,0136 $0.0318 $0.0161 $0.0181
$0.0030
4 - -- - - - - -. $0.2769
$0.2357 $0.0775 $0.1030 $0.0486 $0.0677 $0.1032
-------____--- 5
$0.2643
$0.2403 $0.1232 $0.1418 $0.0680 $0.0671 $0.0567
. - - - - - - - - _ _ -. $0.3142
$0.2741 $0.1363 $0.1546 $0.109 1 $0.0829 $0.0352
1/ 2/
Includes a per Dth charge for (ACA) Annual Charge Adjustment of $0.0018 The applicable F&LR's and EPCR's, determined pursuant to Article XXXVII of the General Terms and Conditions, are listed on Sheet No. 32. For service that is rendered entirely by displacement and far gas scheduled and allocated for receipt at the Dracut, Massachusetts receipt point, Shipper shall render only the quantity of gas associated with Losses of 0.21%. Includes a per Dth charge for the PS/GHG Surcharge Adjustment per Article XXXVIII of the General Terms and Conditions of $0.0000"
31
Issued: March 1, 2012 Effective: April 1, 2012
Docket No. RP12-450-000 Accepted: March 30, 2012
Tennessee Gas Pipeline Company, L.L.C. FERC NGA Gas Tariff S ix th Revised Volume No. 1
Six th Revised Sheet No. 15 Superseding
Fif th Revised Sheet No. 15
RATES PER DEI<ATHERM
0 $0.0050 $0.0133 $0.0195 $0.0237 $0.0268 $0.0302 $0.0364
1 $0.0060 $0,0099 $0.0165 $0.0197 $0.0228 $0.0274 $0.0318 2 $0.0185 $0.0105 $0.0030 $0.0046 $0.0074 $0.0118 $0.0161
L $0.0030
3 $0.0225 $0.0187 $0.0044 $0.0020 $0.0099 $0.0136 $o .a i s i 4 $0.0268 $0.0223 go.oio5 $0.0123 $0.0046 $0.0064 $o.oiio 5 $0.0302 $0.0274 $0.0118 $0.0136 $0.0064 $0.0064 $0.0084 6 $0.0364 $0.0318 $0,0161 $0.0181 $0.0104 $0.0059 $0.0038
............................. 0 $0.0050 L $0.0030
2 $0.0185 3 $0.0225
1 $0.0060
4 $0.0268 5 $0.0302 6 $0.0364
Notes:
. - - - - - - - - - _-. $0.0133
$0.0099 $0.0105 $0.0187 $0.0223 $0.0274 $0.0318
. _ _ - - - - - - _ _ - - - -. $0.0195
$0.0165
$0.0044 $0.0105 $0.0118 $0.0161
$0.0030
~
$0.0237
$0.0197 $0.0046 $0.0020 $0.0123 $0.0136 $0.0181
-_____________. $0.2769
$0.2357 $0.0775 $0.1030 $0.0486 $0.0677 $0.1032
.-__-_.I_ - - _ _ - - $0.2643
$0.2403 $0.1232 $0.1418 $0.0680 $0.0671 $0.0567
$0.3142
$0.2741 $0.1363 $0.1546 $0.1091 $0.0829 $0.0352
1/ 2/
Includes a per Dth charge for (ACA) Annual Charge Adjustment of $0.0018 The applicable F&LR's and EPCR's, determined pursuant to Article XXXVII of the General Terms and Conditions, are listed on Sheet No. 32. For service that is rendered entirely by displacement, Shipper shall render only the quantity of gas associated with Losses of 0.09%. Includes a per Dth charge for the PSIGHG Surcharge Adjustment per Article XXXVIII of the General Terms and Conditions of 3/ $o.oooo.
Issued: January 27, 2012 Effective: February 1, 2012
Docket No. R P l l - 1 5 6 6 Accepted:
Tennessee Gas Pipeline Company, L.L.C. FERC NGA Gas Tarif f S ix th Revised Volume No. 1
Fifth Revised Sheet No, 15 Superseding
Fourth Revised Sheet No, 15
RATES PER DEKATHERM
0 $0.0032 $0.0115 $0.0177 $0.0219 $0.2751 $0.2625 $0.3124
1 $0.0042 $0,0081 $0.0147 $0.0179 $0.2339 $0.2385 $0.2723 2 $0.0167 $0.0087 $0,0012 $0.0028 $0.0757 $0.1214 $0.1345 3 $0.0207 $0.0169 $0.0026 $0.0002 $0.1012 $0.1400 $0.1528 4 $0.0250 $0.0205 $0.0087 $0.0105 $0.0468 $0.0662 $0.1073 5 $0.0284 6 $0.0346
L $0.0012
$0.0256 $0.0100 $0,0118 $0.0659 $0.0653 $0.0811 $0.0300 $0.0143 $0.0163 $0.1014 $0.0549 $0.0334
Minimum Commodity Rates l f , 2f 3f DELIVERY ZONE
ZONE 0 L 1 2 3 4 5 6 _ _ _ - _ " l _ " " - - - - - - _ - - _ _ _ _ _ _ I
"----------_-------"1________________1_1----------------------------------~-----------------.-----------~--
0 $0.0080 $0.0247 $0.0372 $0.0457 $0.0534 $0.0604 $0.0727 L $0.0040 1 $0.0100 $0.0179 $0.0312 $0.0376 $0.0451 $0.0547 $0.0632 2 $0.0362 $0,0191 $0.0039 $0.0072 $0.0132 $0.0223 $0.0305 3 $0.0445 $0.0366 $0.0070 $0.0020 $0.0183 $0.0261 $0.0348 4 $0.0534 $0.0429 $0.0191 $0.0227 $0.0073 $0.0112 $0.0200 5 $0.0604 $0.0547 $0.0223 $0.0261 $0.0111 $0.0111 $0.0147 6 $0.0727 $0.0632 $0.0305 $0.0348 $0.0188 $0.0094 $0.0051
0 $0.0080 $0.0247 $0.0372 $0.0457 $0.3035 $0.2945 $0.3505 L $0.0040 1 $0.0100 $0.0179 $0.0312 $0.0376 $0.2580 $0.2676 $0.3055 2 $0.0362 $0.0191 $0.0039 $0.0072 $0.0833 $0,1337 $0.1507 3 $0.0445 $0.0366 $0.0070 $0.0020 $0.1114 $0.1543 $0.1713 4 $0.0534 $0.0429 $0.0191 $0.0227 $0.0513 $0.0728 $0.1181 5 $0.0604 $0.0547 $0.0223 $0.0261 $0.0724 $0.0718 $0.0892 6 $0.0727 $0.0632 $0.0305 $0.0348 $0.1116 $0.0602 $0.0365
1/ 2/
Includes a per Dth charge for (ACA) Annual Charge Adjustment of $0.0018 The applicable FBILR's determined pursuant to Article XXXVII of the General Terms and Conditions are listed on Sheet No. 32. For service that is rendered entirely by displacement, Shipper shall render only the quantity of gas associated with Losses of 0.09%. Includes a per Dth charge for EPCR Adjustment per Article XXXVIII o f the General Terms and Conditions and listed on Sheet No. 33. Includes a per Dth charge for the Hurricane Surcharge Adjustment per Article XXXIX of the General Terms and Conditions and listed on Sheet No. 34.
31
4f
Issued: November 10, 2011 Effective: November 10, 2011
Docket No. RP12-144-000 Accepted: December 2, 2011
Tennessee Gas Pipeline Company, L.L.C. FERC NGA Gas Tarif f S ix th Revised Volume No. 1
Sixth Revised Sheet No. 32 Superseding
Fif th Revised Sheet No. 32
0 L 1 2 3 4 5 6
0 $0.0035 $0.0134 $0.0208 $0.0258 $0.0312 $0.0355 $0.0426 L $0.0012 1 $0.0047 $0.0094 $0.0172 $0.0211 $0.0262 $0.0320 $0.0368 2 $0.0208 $0.0101 $0.0011 $0.0031 $0.0068 $0.0124 $0.0169 3 $0.0258 $0.0211 $0.0031 $0.0000 $0.0099 $0.0147 $0.0196 4 $0.0312 $0.0242 $0.0100 $0.0122 $0.0032 $0.0056 $0.0106 5 $0.0355 $0.0320 $0.0124 $0.0147 $0.0056 $0.0055 $0.0073 6 $0.0426 $0.0368 $0.0169 $0.0196 $0.0098 $0.0041 $0.0015
1/ 21 For service that is rendered entirely by displacement and far gas scheduled and allocated for receipt at the Dracut,
31 41
Included in the above F&LR is the Losses component of the F&LR equal to 0.21%.
Massachusetts receipt point, Shipper shall render only the quantity of gas associated with Losses of 0.21%. The F&LR’s and EPCR’s listed above are applicable to FT-A, FT-BH, FT-G, FT-GS, NET, NET-284 and IT. The F&LR’s and EPCR’s determined pursuant to Article XXXVI I of the General Terms and Conditions.
Issued: March 1, 2012 Effective: April I, 2012
Docket No. RP12-450-000 Accepted: March 30, 2012
Tennessee Gas Pipeline Company, L.L.C. FERC NGA Gas Tarif f S ix th Revised Volume No. 1
Fifth Revised Sheet No. 32 Superseding
Fourth Revised Sheet No. 32
0 0.43% 1.32% 1.97% 2.42% 2.90% 3.28% 3.91% L 0.22% 1 0.54% 0.96% 1.65% 1.99% 2.45% 2.97% 3.40% 2 1.97% 1.02% 0.22O/0 0.39% 0.72% 1.22% 1.63% 3 2.42% 1.99% 0.39% 0.12% 1.00% 1.42% 1.86% 4 2.90% 2.27% 1.01% 1.21% 0.41% 0.62% l.O6% 5 3.28% 2.97% 1.22% 1.42% 0.61% 0.61% 0.77% 6 3.91% 3.40% 1.63% 1.86% 0.99% 0.49% 0.25%
0 $0.0030 L 1 $0.0040 2 $0.0177 3 $0.0220 4 $0.0266 5 $0.0302 6 $0.0363
$0.0114 $0,0177 $0.0220 $0.0266 $0.0302 $0.0363 $0.0010
$0.0080 $0.0147 $0.0179 $0.0223 $0.0273 $0.0314 $0.0086 $0.0009 $0.0026 $0.0058 $0.0105 $0.0144 $0.0179 $0.0026 $0.0000 $0.0084 $0.0125 $0.0167
$0.0273 $0.0105 $0.0125 $0.0047 $0.0047 $0.0063 $0.0314 $0,0144 $0.0167 $0.0084 $0.0035 $0.0013
$0.0206 $o.0086 $0.aio4 $0.0027 $0.0048 $o.oogo
1/ 2/
31 4/
Included in the above F&LR is the Losses component of the F&LR equal to 0.09%. For service that is rendered entirely by displacement and for gas scheduled and allocated for receipt at the Dracut, Massachusetts receipt point, Shipper shall render only the quantity of gas associated with Losses of 0.09°/~/o. The F&LR's and EPCR's listed above are applicable to FT-A, FT-BH, FT-G, FT-GS, NET, NET-284 and IT. The F&LR's and EPCR's determined pursuant to Article XXXVII of the General Terms and C,onditions.
Issued: l anuary 27, 2012 Effective: February 1, 2012
Docket No. R P l l - 1 5 6 6 Accepted :
Tennessee Gas Pipeline Company, L.L.C. FERC NGA Gas Tarif f S ix th Revised Volume No. 1
Second Revised Sheet No. 33 Superseding
Subst i tu te First Revised Sheet No. 33
0 $0.0030 L i $0.0040 2 $0.0177 3 $0.0220 4 $0.0266 s $0.0302 6 $0.0363
STORAGE 21 $0.000
1/ 2/ 3/
The EPCR listed above are applicable to FT-A, FT-BH, FT-G, FT-GS, NET, NET-284 and I T The EPCR listed above is applicable to FS-MA, FS-PA, IS-MA, and IS-PA EPCR determined pursuant to Article XXXVIII of the General Terms and Conditions.
Issued: November 10, 2011 Effective: November 10, 2011
Docket No. RP12-144-000 Accepted: December 2, 2011
PBR-OSSIF SUPPORTING CALCULATIONS
PBR-OSSIF CALCULATION OF OFF-SYSTEM SALES REVENUE
(“OSREV”), OUT-OF-POCKET COSTS (“OOPC”), AND NET REVENUE (“NR”)
W
b
3
z W
K
2;
00
00
00
00
00
00
0
696969696969696969696969
69
00
00
00
00
00
00
0
696969696969696969696969
69
00
00
00
00
00
00
0
696969696969696969696969
69
00
00
00
00
00
00
0
696969696969646964696969
69
