MANITOBA HYDRO PROSPECTIVE COST OF SERVICE STUDY FOR ...€¦ · Manitoba Hydro 2017/18 & 2018/19...
Transcript of MANITOBA HYDRO PROSPECTIVE COST OF SERVICE STUDY FOR ...€¦ · Manitoba Hydro 2017/18 & 2018/19...
MANITOBA HYDRO
PROSPECTIVE COST OF SERVICE STUDY
FOR FISCAL YEAR ENDING
MARCH 31, 2018
INDEX
Section 1: Results ............................................................................................................................ 1
Section 2: Rate Base ........................................................................................................................ 5
Section 3: Functionalization of Operating & Depreciation Costs ................................................. 10
Section 4: Allocation of Costs ....................................................................................................... 15
Section 5: Development of Class Loads ........................................................................................ 27
Section 6: Revenue ....................................................................................................................... 35
Section 7: Historical RCC Ratios .................................................................................................... 37
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Available in accessible formats upon request
Manitoba Hydro May 2017 PCOSS18 Page 1
SECTION 1: RESULTS
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 1 Schedule 1.1 Revenue Cost Coverage Analysis
Manitoba Hydro May 2017 PCOSS18 Page 2
Man
itoba
Hyd
roPr
ospe
ctiv
e C
ost O
f Ser
vice
Stu
dyM
arch
31,
201
8R
even
ue C
ost C
over
age
Ana
lysi
s
S U
M M
A R
Y
Cla
ssR
CC
%N
et E
xpor
tT
otal
RC
C %
Tot
al C
ost
Rev
enue
Prio
r to
Rev
enue
Rev
enue
Cur
rent
Cus
tom
er C
lass
($00
0)($
000)
NER
($00
0)($
000)
Rat
es
Res
iden
tial
810,
916
60
7,10
6
74.9
%16
1,91
1
769,
017
94
.8%
Gen
eral
Ser
vice
- Sm
all N
on D
eman
d15
1,81
4
139,
479
91
.9%
31,3
13
170,
793
11
2.5%
Gen
eral
Ser
vice
- Sm
all D
eman
d18
5,20
0
146,
983
79
.4%
40,0
99
187,
082
10
1.0%
Gen
eral
Ser
vice
- M
ediu
m25
3,46
6
191,
737
75
.6%
57,4
72
249,
209
98
.3%
Gen
eral
Ser
vice
- La
rge
0 - 3
0kV
120,
404
89
,652
74
.5%
29,6
13
119,
265
99
.1%
Gen
eral
Ser
vice
- La
rge
30-1
00kV
*86
,975
69
,995
80
.5%
25,0
54
95,0
49
109.
3%G
ener
al S
ervi
ce -
Larg
e >1
00kV
*23
0,68
8
180,
458
78
.2%
70,0
42
250,
500
10
8.6%
*Inc
lude
s C
urta
ilmen
t Cus
tom
ers
SEP
737
84
4
114.
4%-
84
4
114.
4%
Are
a &
Roa
dway
Lig
htin
g22
,987
21
,571
93
.8%
1,48
2
23
,053
10
0.3%
Tot
al G
ener
al C
onsu
mer
s1,
863,
186
1,44
7,82
6
77
.7%
416,
987
1,
864,
813
100.
1%
Die
sel
8,99
6
7,
368
81.9
%-
7,
368
81.9
%
Expo
rt38
,159
45
5,14
6
1192
.7%
(416
,987
)
38
,159
10
0.0%
Tot
al S
yste
m1,
910,
341
1,91
0,34
1
10
0.0%
-
1,91
0,34
1
10
0.0%
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 1 Schedule 1.2 Customer, Demand, Energy Cost Analysis
Manitoba Hydro May 2017 PCOSS18 Page 3
Man
itoba
Hyd
ro
Pros
pect
ive
Cos
t Of S
ervi
ce S
tudy
- M
arch
31,
201
8
Cus
tom
er, D
eman
d, E
nerg
y C
ost A
naly
sis
SU
MM
AR
Y
C U
S T
O M
E R
D
E M
A N
DE
N E
R G
Y
Bill
able
Met
ered
Cos
tN
umbe
r of
Uni
t Cos
tC
ost
%
Dem
and
Uni
t Cos
tC
ost
Ener
gyU
nit C
ost
Cla
ss($
000)
Cus
tom
ers
$/M
onth
($00
0)R
ecov
ery
MV
A$/
KV
A($
000)
mW
h¢/
kWh
Res
iden
tial
77,8
1450
8,24
212
.76
38
7,88
6
0%
n/a
n/a
183,
304
7,58
6,09
67.
53
**
GS
Smal
l - N
on D
eman
d13
,971
42,7
0727
.26
67
,584
0%
n/a
n/a
38,9
46
1,
622,
627
6.57
**
GS
Smal
l - D
eman
d12
,317
4,19
724
4.57
81
,580
37
%2,
623
11.4
5
51,2
03
2,
146,
454
4.79
Gen
eral
Ser
vice
- M
ediu
m9,
511
2,12
537
2.96
11
0,28
6
92
%7,
722
13.1
4
76,1
97
3,
204,
436
2.65
Gen
eral
Ser
vice
- La
rge
<30k
V3,
531
321
n/a
46,1
14
100%
4,30
211
.54
*
41,1
47
1,
745,
362
2.36
G
ener
al S
ervi
ce -
Larg
e 30
-100
kV2,
462
40n/
a23
,211
10
0%3,
358
7.65
*
36,2
48
1,
578,
519
2.30
G
ener
al S
ervi
ce -
Larg
e >1
00kV
5,
826
16n/
a52
,900
10
0%7,
815
7.51
*
101,
920
4,50
4,93
92.
26
SEP
6731
181.
17
90
0%n/
an/
a58
0
25
,500
2.63
**
Are
a &
Roa
dway
Lig
htin
g16
,230
157,
982
8.56
3,28
3
0%n/
an/
a1,
991
82
,415
6.40
**
Tot
al G
ener
al C
onsu
mer
s14
1,72
971
5,66
177
2,93
4
25
,818
531,
537
22,4
96,3
47
Die
sel
396
785
42.0
6
-
0%
n/a
n/a
8,59
9
14,5
46
59
.12
**
Expo
rtn/
an/
an/
a-
0%n/
an/
a38
,159
8,55
7,00
0
0.
45
***
Tot
al S
yste
m14
2,12
571
6,44
677
2,93
4
25
,818
578,
296
31,0
67,8
93
* - i
nclu
des
reco
very
of c
usto
mer
cos
ts**
- in
clud
es re
cove
ry o
f dem
and
cost
s**
* -in
clud
es re
cove
ry o
f cus
tom
er a
nd d
eman
d co
sts
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 1 Schedule 1.3 Functional Cost Analysis
Manitoba Hydro May 2017 PCOSS18 Page 4
M
anito
ba H
ydro
Pros
pect
ive
Cos
t Of S
ervi
ce S
tudy
- M
arch
31,
201
8Fu
nctio
nal B
reak
dow
n
S U
M M
A R
Y
Gen
erat
ion
Tra
nsm
issi
onSu
btra
nsm
issi
onD
istr
ibut
ion
Dis
trib
utio
nT
otal
Cos
tC
ost
Cos
t C
ost
Cus
t Ser
vice
Plan
t Cos
tC
lass
($00
0)($
000)
%($
000)
%($
000)
%C
ost (
$000
)%
($00
0)%
Res
iden
tial
649,
004
291,
185
44.9
%66
,704
10.3
%37
,236
5.7%
73,6
5211
.3%
180,
228
27.8
%
Gen
eral
Ser
vice
- Sm
all N
on D
eman
d12
0,50
0
57
,563
47
.8%
11,6
539.
7%6,
456
5.4%
12,6
5610
.5%
32,1
7326
.7%
Gen
eral
Ser
vice
- Sm
all D
eman
d14
5,10
0
74
,188
51
.1%
14,4
4810
.0%
7,98
45.
5%7,
802
5.4%
40,6
7928
.0%
Gen
eral
Ser
vice
- M
ediu
m19
5,99
4
10
7,33
3
54
.8%
19,7
0310
.1%
10,8
435.
5%8,
298
4.2%
49,8
1725
.4%
Gen
eral
Ser
vice
- La
rge
<30k
V90
,791
55,9
78
61.7
%9,
479
10.4
%5,
185
5.7%
2,91
63.
2%17
,234
19.0
%G
ener
al S
ervi
ce -
Larg
e 30
-100
kV61
,921
47,8
72
77.3
%7,
507
12.1
%4,
080
6.6%
2,18
23.
5%28
10.
5%G
ener
al S
ervi
ce -
Larg
e >1
00kV
16
0,64
6
13
3,95
1
83
.4%
20,8
6913
.0%
00.
0%5,
585
3.5%
241
0.2%
SEP
737
580
78.7
%90
12.2
%0
0.0%
446.
0%23
3.1%
Are
a &
Roa
dway
Lig
htin
g21
,504
2,77
8
12.9
%49
92.
3%27
41.
3%91
24.
2%17
,041
79.2
%
Tot
al G
ener
al C
onsu
mer
s1,
446,
199
77
1,42
7
53
.3%
150,
951
10.4
%72
,057
5.0%
114,
047
7.9%
337,
717
23.4
%
Die
sel
8,99
6
8,59
9
95.6
%0
0.0%
00.
0%0
0.0%
396
4.4%
Expo
rt38
,159
38,1
59
100.
0%0
0.0%
00.
0%0
0.0%
00.
0%
Tot
al S
yste
m1,
493,
354
81
8,18
6
54
.8%
150,
951
10.1
%72
,057
4.8%
114,
047
7.6%
338,
114
22.6
%
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Manitoba Hydro May 2017 PCOSS18 Page 5
SECTION 2: RATE BASE
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 2 Schedule 2.1 Functionalization of Rate Base
Manitoba Hydro May 2017 PCOSS18 Page 6
2018
PR
OSP
ECT
IVE
CO
ST O
F SE
RV
ICE
STU
DY
FUN
CT
ION
ALI
ZA
TIO
N O
F R
AT
E B
ASE
INV
EST
MEN
T
FOR
ECA
ST Y
EAR
EN
DIN
G M
AR
CH
31,
201
8
DIR
ECT
ALL
OC
AT
ION
SR
ate
Bas
eSu
b-D
istr
ibut
ion
Anc
illar
yA
sset
Cla
ssIn
vest
men
tG
ener
atio
nT
rans
mis
sion
Tra
nsm
issi
onPl
ant
Serv
ices
Serv
ices
Ligh
ting
Die
sel
GEN
ERA
TIO
N6,
126,
286,
090
6,12
6,28
6,09
0
-
-
-
-
-
-
-
-T
herm
al14
4,59
0,26
0
144,
590,
260
-
-
-
-
-
-
-
DIE
SEL
3,35
2,67
6
-
-
-
-
-
-
-
3,
352,
676
SUB
STA
TIO
N1,
938,
288,
350
19,3
78,8
22
87
3,77
2,40
7
272,
885,
514
71
1,69
9,42
6
-
60,5
52,1
80
-
-
-
HV
DC
449,
292,
382
44
9,29
2,38
2
-
-
-
-
-
-
-
TR
AN
SMIS
SIO
N51
1,15
7,43
8
21,7
46,5
80
48
9,41
0,85
8
-
-
-
-
-
-
- H
VD
C15
7,61
8,94
4
157,
618,
944
-
-
-
-
-
-
-
-
Ded
icat
ed R
adia
l Tab
s2,
997,
748
-
2,99
7,74
8
-
-
-
-
-
-
-
US
Inte
rcon
nect
ions
65,7
35,5
70
-
65
,735
,570
-
-
-
-
-
-
- N
on-T
ariff
able
Tra
nsm
issi
o68
,599
,853
-
68,5
99,8
53
-
-
-
-
-
-
DIS
TR
IBU
TIO
N1,
746,
202,
254
-
-
-
1,65
9,35
2,83
4
-
-
85
,888
,944
960,
476
SUB
TR
AN
SMIS
SIO
N26
7,23
8,16
2
-
-
267,
238,
162
-
-
-
-
-
TR
AN
SFO
RM
ERS
-
SU
BST
AT
ION
49,0
77,3
21
30
,111
,753
9,50
6,45
5
2,
937,
446
6,52
1,66
7
-
-
-
-
- D
IST
RIB
UT
ION
2,68
7,31
3
-
-
-
2,
687,
313
-
-
-
-
MET
ERS
52,5
43,0
91
-
-
-
52
,543
,091
-
-
-
-
BU
ILD
ING
S 44
1,12
0,84
3
213,
296,
415
54
,303
,093
16,7
12,4
46
69
,831
,927
78,5
85,4
08
-
5,
630,
328
2,76
1,22
6
CO
MM
UN
ICA
TIO
N23
2,53
2,65
3
131,
396,
630
32
,655
,135
10,8
32,7
57
47
,472
,550
-
10,1
75,5
81
-
-
`
GEN
ERA
L EQ
UIP
MEN
T26
9,53
7,58
2
130,
330,
273
33
,180
,759
10,2
11,7
87
42
,669
,325
48,0
17,9
55
-
3,
440,
293
1,68
7,18
9
S
UB
TO
TA
L12
,528
,858
,531
7,
424,
048,
149
1,63
0,16
1,87
7
58
0,81
8,11
2
2,59
2,77
8,13
4
12
6,60
3,36
3
70,7
27,7
61
94
,959
,566
8,76
1,56
7
MO
TO
R V
EHIC
LES
156,
394,
457
Tot
al R
ate
Bas
e In
vest
men
t12
,685
,252
,988
7,
424,
048,
149
1,63
0,16
1,87
7
58
0,81
8,11
2
2,59
2,77
8,13
4
12
6,60
3,36
3
70,7
27,7
61
94
,959
,566
8,76
1,56
7
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 2 Schedule 2.2 Functionalization of Interest
Manitoba Hydro May 2017 PCOSS18 Page 7
2018
PR
OSP
ECT
IVE
CO
ST O
F SE
RV
ICE
STU
DY
FUN
CT
ION
ALI
ZA
TIO
N O
F IN
TER
EST
EX
PEN
SE &
RES
ERV
E C
ON
TR
IBU
TIO
NFO
REC
AST
YEA
R E
ND
ING
MA
RC
H 3
1, 2
018
DIR
ECT
ALL
OC
AT
ION
SA
sset
Cla
ssIn
tere
st &
Res
erve
Sub-
Dis
trib
utio
nA
ncill
ary
Expe
nse
Gen
erat
ion
Tra
nsm
issi
onT
rans
mis
sion
Plan
tSe
rvic
esSe
rvic
esLi
ghtin
gD
iese
l
GEN
ERA
TIO
N28
6,38
5,22
7
28
6,38
5,22
7
-
-
-
-
-
-
-
-TH
ERM
AL
6,75
9,15
5
6,75
9,15
5
-
-
-
-
-
-
-
DIE
SEL
156,
727
-
-
-
-
-
-
-
156,
727
SUB
STA
TIO
N90
,609
,080
905,
901
40
,846
,200
12
,756
,567
33,2
69,7
82
-
2,83
0,63
0
-
-
-
HV
DC
21,0
03,0
51
21
,003
,051
-
-
-
-
-
-
-
TR
AN
SMIS
SIO
N23
,895
,054
1,01
6,58
6
22
,878
,468
-
-
-
-
-
-
-
HV
DC
7,36
8,20
6
7,36
8,20
6
-
-
-
-
-
-
-
-
Ded
icat
ed R
adia
l Tab
s14
0,13
6
-
14
0,13
6
-
-
-
-
-
-
- U
S In
terc
onne
ctio
ns3,
072,
938
-
3,
072,
938
-
-
-
-
-
-
- N
on-T
ariff
able
Tra
nsm
issi
on3,
206,
834
-
3,
206,
834
-
-
-
-
-
-
DIS
TR
IBU
TIO
N81
,629
,640
-
-
-
77
,569
,694
-
-
4,01
5,04
7
44,8
99
SUB
TR
AN
SMIS
SIO
N12
,492
,571
-
-
12,4
92,5
71
-
-
-
-
-
TR
AN
SFO
RM
ERS
-
SU
BST
AT
ION
2,29
4,21
5
1,40
7,63
3
44
4,39
8
137,
317
304,
868
-
-
-
-
-
DIS
TR
IBU
TIO
N12
5,62
4
-
-
-
125,
624
-
-
-
-
MET
ERS
2,45
6,23
0
-
-
-
2,
456,
230
-
-
-
-
BU
ILD
ING
S 20
,621
,057
9,97
0,95
8
2,
538,
504
781,
256
3,26
4,43
0
3,
673,
629
-
263,
201
129,
079
CO
MM
UN
ICA
TIO
N10
,870
,194
6,14
2,39
3
1,
526,
528
506,
398
2,21
9,19
7
-
475,
677
-
-
GEN
ERA
L EQ
UIP
MEN
T12
,600
,062
6,09
2,54
4
1,
551,
099
477,
370
1,99
4,66
1
2,
244,
693
-
160,
823
78,8
71
S
UB
TO
TA
L58
5,68
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MO
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Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 2 Schedule 2.3 Functionalization of Rate Base for Capital Tax
Manitoba Hydro May 2017 PCOSS18 Page 8
2018
PR
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Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 2 Schedule 2.4 Functionalization of Capital Tax
Manitoba Hydro May 2017 PCOSS18 Page 9
2018
PR
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Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Manitoba Hydro May 2017 PCOSS18 Page 10
SECTION 3: FUNCTIONALIZATION OF OPERATING & DEPRECIATION COSTS
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 3 Functionalization of Operating & Depreciation Costs
Manitoba Hydro May 2017 PCOSS18 Page 11
Functionalization of Operating
Manitoba Hydro’s financial reporting system (SAP), via settlement cost centres (SCC), provides
the initial functionalization of all functional operating & maintenance costs. Manitoba Hydro
uses approximately 400 cost centers to provide the level of detail necessary to functionalize
operating costs, as well as depreciation and rate base.
The number of costs centers used depends on the degree of granularity required for either
functionalization or associated business purposes (ie OATT). At the Generation and
Transmission level there is generally one cost center corresponding to each facility (generating
station, switching station, convertor station, substation or transmission line). Costs related to
Subtransmission, Distribution Plant and Distribution Services are generally captured in a smaller
number of non‐location specific cost centers, each corresponding to the sub‐functions used in
the study. For example there are distinct cost centers for Limestone GS, Henday CS and the
Glenboro‐Rugby 230 kV transmission line, but only a single cost center for subtransmission lines
or distribution substations.
Facility cost centres are used to capture the costs associated with maintaining or operating
facilities used to produce, transmit or distribute electrical energy or involved in providing
customer service. Non‐facility cost centres capture the costs associated with various
administrative services/functions or facilities which support administrative functions. These
administrative costs include activities such as human resources, payroll, buildings and other
such costs incurred to support the line activities that provide the delivery of power to our
customers.
The PCOSS uses two similar approaches to functionalize administrative and common costs in
proportion to labour costs that result in nearly identical functionalization:
SAP Labour Allocator – granular allocation to SCC level based on labour costs charged to
each SCC. Used in the initial SAP functionalization of common O&M costs.
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 3 Functionalization of Operating & Depreciation Costs
Manitoba Hydro May 2017 PCOSS18 Page 12
Internal COS Labour Allocator – broad allocation to functions in proportion to
functionalized Operating costs (excluding water rentals, fuel, and power purchases).
Used for any subsequent offline functionalization of common Operating, Depreciation
or Rate Base.
The costs for non‐facility cost centres are allocated to facility cost centres on the basis of the
SAP Labour Allocator. Allocating administrative costs to a facility cost centre, which is in turn
functionalized, allows Manitoba Hydro to functionalize these costs without the need for explicit
functionalization of administrative costs in the COSS.
The functionalization of some costs is done outside of the Corporation’s accounting system
such as communication system costs which are functionalized to all functions except customer
service on the basis of the Internal COS Labour Allocator.
Schedule 3.1 provides the results of the functionalization of Operating costs.
Functionalization of Depreciation
The functionalization of Depreciation expense uses the same approach and cost centers used
for Operating costs. In PCOSS18, depreciation on Buildings and General Equipment has been
functionalized off‐line as part of Cost of Service. Previously, this common depreciation was
allocated to the individual facility cost center level as part of the SAP functionalization process.
Schedule 3.2 provides the results of the functionalization of Depreciation costs.
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 3 Schedule 3.1 Functionalization of Operating Costs
Manitoba Hydro May 2017 PCOSS18 Page 13
2018 PROSPECTIVE COST OF SERVICEFiscal Year Ending March 31, 2018
Functionalization of Operating Costs
Distribution Customer Ancilary StreetSCC Description Operating Generation Transmission Subtransmission Plant Service Services Diesel LightingCommon Generation Costs 32,790,072 32,790,072 Demand Side Management 1,079,294 1,079,294 Hydraulic Generation 241,513,639 241,513,639 Thermal Generation 33,524,827 33,524,827 Purchased Power 127,355,500 127,355,500 Generation Outlet Transmission 846,222 846,222 Generating Switching Stations 352,688 352,688 Convertor Stations 44,500,456 44,500,456 HVDC Lines 3,858,438 3,858,438 Generation Facilities & Costs 485,821,135 485,821,135
Common Trans Costs 29,033,639 - 29,033,639 Switching Stations 2,185,128 2,185,128 Transmission Substations 11,486,970 11,085,206 401,764 Dedicated Taps - - Non Tariffable Transmission 2,435,528 2,435,528 US Interface 6,444,115 6,444,115 Networked AC Transmission Lines 14,073,921 14,073,921 Transmission Facilities/Costs 65,659,301 - 65,257,536 401,764
Common Subtrans / Dist Costs 13,442,728 2,595,904 10,846,824
Common Subtransmission 7,316,555 7,316,555 Subtransmission Substations 9,308,991 9,308,991 Subtransmission Lines 1,822,922 1,822,922 Subtrans. Facilities & Costs 18,448,468 18,448,468
Common Distribution Costs 3,955,366 3,955,366 Distribution Substations 26,457,184 26,457,184 Distribution Pole & Wire 40,868,711 40,868,711 Transform/Volt. Regulation 5,763,709 5,763,709 Area & Roadway Lighting 6,215,185 6,215,185 Meters & Metering Transformers 40,818 40,818 Dist. Facilities & Costs 83,300,974 77,085,789 6,215,185
Market Research & Development 1,324,380 1,324,380 Education & Safety 1,240,782 1,240,782 Industrial & Commercial Solutions 4,313,006 4,313,006 Power Quality Investigations 1,046,615 1,046,615 Service Extensions 13,897,481 13,897,481 Contact Center - Outages 1,219,672 1,219,672 Rates & Regulatory 2,990,725 2,990,725 Line Locates 4,060,223 4,060,223 Bldg Moves/Safety Watches 3,058,386 3,058,386 Customer & Community Service Work 4,258,894 4,258,894 Customer General Inquiries 2,024,966 2,024,966 Wiring Inspections 3,458,817 3,458,817 Customer Billing 21,728,506 21,728,506 Customer Collections 11,730,206 11,730,206 Meter Reading 10,395,887 10,395,887 Customer Service Costs 86,748,547 86,748,547
Isolated Diesel Facilities 6,923,700 6,923,700
Communication & Control System 13,779,410 4,346,541 742,551 586,000 3,457,193 - 4,647,125 - -
Planned Grants In Lieu Taxes 16,911,948 11,161,886 4,058,868 338,239 1,352,956
Buildings and General Equipment 50,387,789 24,364,151 6,202,864 1,909,008 7,976,672 8,976,554 - 315,406 643,134
841,424,000 525,693,712 76,261,819 23,877,619 100,719,435 95,725,101 5,048,889 7,239,106 6,858,319
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 3 Schedule 3.2 Functionalization of Depreciation Costs
Manitoba Hydro May 2017 PCOSS18 Page 14
2018 PROSPECTIVE COST OF SERVICEFiscal Year Ending March 31, 2018
Functionalization of Depreciation Costs
Distribution Customer Ancilary StreetSCC Description Depreciation Generation Transmission Subtransmission Plant Service Services Diesel LightingCommon Generation Costs 995,476 995,476 Demand Side Management 36,190,875 36,190,875 Hydraulic Generation 108,544,098 108,544,098 Thermal Generation 14,613,836 14,613,836 Purchased Power - - Generation Outlet Transmission 302,388 302,388 Generating Switching Stations 898,856 898,856 Convertor Stations 31,977,651 31,977,651 HVDC Lines 2,777,412 2,777,412 Generation Facilities & Costs 196,300,593 196,300,593
Common Trans Costs - - Switching Stations 4,056,905 3,968,877 - - - 88,028 Transmission Substations 21,474,096 - 19,669,597 - - - 1,804,499 Dedicated Taps 44,765 44,765 Non Tariffable Transmission 1,028,827 1,028,827 US Interface 992,544 992,544 Networked AC Transmission Lines 8,765,994 8,765,994 Transmission Facilities/Costs 36,363,131 34,470,605 - - - 1,892,527
Common Subtrans / Dist Costs - - -
Common Subtransmission - - Subtransmission Substations 8,106,954 8,106,954 Subtransmission Lines 5,749,939 5,749,939 Subtrans. Facilities & Costs 13,856,893 13,856,893
Common Distribution Costs - - Distribution Substations 19,115,262 19,115,262 Distribution Pole & Wire 34,676,220 34,676,220 Transform/Volt. Regulation 9,951,619 9,951,619 Area & Roadway Lighting 2,702,623 2,702,623 Meters & Metering Transformers 5,795,602 5,795,602 Dist. Facilities & Costs 72,241,326 69,538,703 2,702,623
Market Research & Development - - Education & Safety - - Industrial & Commercial Solutions - - Power Quality Investigations - - Service Extensions - - Contact Center - Outages - - Rates & Regulatory 2,945,987 2,945,987 Line Locates - - Bldg Moves/Safety Watches - - Customer & Community Service Work - - Customer General Inquiries - - Wiring Inspections - - Customer Billing - - Customer Collections - - Meter Reading - - Customer Service Costs 2,945,987 2,945,987
Isolated Diesel Facilities 984,331 984,331
Communication & Control System 19,948,490 11,562,714 2,902,119 934,042 4,018,182 - 531,432 - -
Planned Grants In Lieu Taxes - - - - -
Buildings and General Equipment 47,828,048 23,126,432 5,887,754 1,812,029 7,571,451 8,520,537 - 299,383 610,462
390,468,798 230,989,738 43,260,477 16,602,964 81,128,336 11,466,524 2,423,959 1,283,714 3,313,085
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Manitoba Hydro May 2017 PCOSS18 Page 15
SECTION 4: ALLOCATION OF COSTS
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 4 Schedule 4.1 Classified Costs by Allocation Table
Manitoba Hydro May 2017 PCOSS18 Page 16
Prospective Cost Of Service StudyMarch 31, 2018
Classified Costs by Allocation Table
System Load Factor: 62.0%
AllocationTable Function Interest Depreciation Operating Common Costs Total
E12 Generation Energy Share 233,073 120,811 317,033 90,818 761,734 D14 Generation Demand Share 142,851 74,045 98,288 42,665 357,849
Common Costs 25,503 35,574 72,406 (133,483) - Total Generation 401,426 230,430 487,727 - 1,119,583
E13 Transmission Energy Share 2,217 615 3,995 2,603 9,431 D13 Transmission Demand Share 83,323 35,703 32,630 57,817 209,474
Common Costs 6,455 9,301 44,664 (60,420) - Total Transmission 91,996 45,619 81,290 - 218,905
D21 Subtrans 29,533 13,857 18,448 10,219 72,057 Common Costs 2,044 2,746 5,429 (10,219) - Total Subtransmission 31,577 16,603 23,878 - 72,057
D32 Dist. Plant Stations 38,927 19,115 26,457 14,723 99,222 D36 Dist. Plant Lines 72,685 34,244 40,359 25,663 172,951 D40 Dist. Plant S/E 16,528 9,952 5,764 5,618 37,862 C27 Dist. Plant Services 918 432 510 324 2,184 C40 Dist. Plant Meters 2,834 5,796 41 1,511 10,181
Common Costs 8,660 11,590 27,589 (47,839) - Total Distribution Plant 140,552 81,128 100,719 - 322,400
C11 Dist Serv Cust Acct - Billings - - 21,729 5,899 27,628 C12 Dist Serv Cust Acct - Collections - - 11,730 3,185 14,915 C14 Dist Serv Inspection - - 3,459 939 4,398 C15 Dist Serv Meter Read - - 10,396 2,823 13,218 C10 Dist Serv General - 2,946 13,894 4,572 21,412 C13 Dist Serv General - Smaller Customers - - 21,228 5,763 26,991 C23 Dist Serv Industrial & Commercial - - 4,313 1,171 5,484
Common Costs 6,855 8,521 8,977 (24,352) - Total Distribution Services 6,855 11,467 95,725 - 114,047
Total Allocated Costs 672,406 385,247 789,339 - 1,846,992
E01 Generation Diesel 180 978 6,623 818 8,599 C01 Distribution Diesel 52 6 300 38 396
Common Costs 241 299 315 (856) -
C01 Distribution Lighting 4,655 2,703 6,215 1,745 15,317 Common Costs 491 610 643 (1,745) -
D04 Transmission Taps - GSL >100kV 162 45 - 207
E01 Generation Export - 449 37,710 38,159 D04 Transmission Export -
E01 Generation SEP - GSM 192 100 231 523 D04 Transmission SEP - GSM 44 19 19 81 E01 Generation SEP - GSL 0-30kV 21 11 25 57 D04 Transmission SEP - GSL 0-30kV 5 2 2 9
Total Directs 6,042 5,222 52,085 - 63,349
Total 678,448 390,469 841,424 - 1,910,341
Energy 235,683 122,964 365,618 94,239 818,504
Demand 384,058 186,981 221,968 156,705 949,712
Customer 8,458 11,883 93,814 27,970 142,125
628,199 321,828 681,400 278,914 1,910,341
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 4 Schedule 4.2 Allocation Tables
Manitoba Hydro May 2017 PCOSS18 Page 17
Table Type Costs Allocated Method
E12 Unweighted
Energy
Energy related costs within
the Generation function.
Annual kWh sales as measured at generation.
Distribution and transmission losses are assigned to each
rate class based upon the voltage level in which they
receive service.
E13 Unweighted
Energy
Energy related costs within
the Transmission function.
D13 Winter
Coincident
Peak Demand
Demand related costs within
the Transmission function.
Coincident peak demand of each class including losses
during the top 50 winter coincident peak hours. Utilizes
load research data for past eight years.
D14 Winter
Coincident
Peak Demand
Demand related costs within
the Generation function
D21
Winter
Coincident
Peak Demand
Costs within Subtransmission
function.
Coincident peak demand of each class including losses
during the top 50 winter coincident peak hours. Utilizes
load research data for past eight years.
Customers served at >100kV are excluded
D32 Class Non‐
Coincident
Peak Demand
Cost of Distribution stations
and station transformers
within the Distribution Plant
Function.
Non‐Coincident peak demand of each class including
losses. Utilizes load research data for past eight years.
Customers served at >30kV are excluded.
D36 Class Non‐
Coincident
Peak Demand
Cost of Distribution lines and
infrastructure within the
Distribution Plant Function.
Non‐Coincident peak demand of each class including
losses. Utilizes load research data for past eight years.
The demand of GSL 0‐30kV customers that do not use
Secondary Distribution is reduced 30%.
Customers served at >30kV are excluded.
D40 Class Non‐
Coincident
Peak Demand
Cost of Distribution
transformation within the
Distribution Plant function.
Non‐Coincident peak demand of each class including
losses. Utilizes load research data for past eight years.
GSL customers with customer owned transformation are
excluded.
C27 Weighted
Customer
Count –
Services
Cost of service drops within
the Distribution Plant
function
Customer count weighted by 5 for GSS:Three Phase,
GSM and GSL classes.
Customer count for Residential, GSS and GSM adjusted
to recognize that there are multiple customers served by
a single service.
Classes served at > 30 kV, Flat Rate Water Heating, Area
& Roadway Lighting excluded.
C40 Weighted
Customer
Count –
Meters
Costs of meters and
metering transformers
within the Distribution Plant
function
Customer count weighted by the relative cost of
metering equipment as shown in Schedule 4.7
Flat Rate Water Heating, A&RL excluded
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 4 Schedule 4.3 Customer Service Allocation Table
Manitoba Hydro May 2017 PCOSS18 Page 18
Table Classes1 Customer Service Activity Description Operating ($ million)
Allocator Rationale for Allocator
C10 General Customer Service
All Education & Safety Public Affairs, District office costs‐public safety and education
1.2 Revenue
Line Locates/Moves/Safety Watches are for public safety and the protection of MH infrastructure Revenue allocator recognizes that costs could alternately be treated as A&G, which would result in a directionally similar allocation of costs to classes.
Call Center Outage calls 1.2
Rates & Regulatory Public Hearings, Cost of Service, Rate Design, and Load Research costs
3.0
Marketing R&D Costs related to marketing plans, customer surveys, and enhancing business development in the province
1.3
Line Locates Cost of locates for customers, MH work, public streets and roadways.
4.1
Building Moves & Safety Watches
Costs related to building and equipment moves, and oversight of work conducted near electric plant
3.1
C10 Total 13.9
C23 I&CS
GSL Industrial & Commercial Solutions
Activities of departments focused on GSL incl. consultation, service extension, billing‐related inquiries, power quality, general inquiries
4.3 Revenue Service provided to GSL customers A revenue allocator recognizes that the cost to provide these services to customers generally increases as the size of the customer increases
C13 Customer Service – Smaller Customers
Excludes GSL
Customer & Community Service Work
Disconnects/reconnects for customer driven work, opening Customer Service Termination Enclosures, pulling meter, other work requested by the customer
4.3 Revenue Services provided to smaller customers; GSL are provided similar services by I&CS and are excluded A revenue allocator recognizes that the cost to provide these services to customers generally increases as the size of the customer increases
General Inquiries District offices responding to general inquiries 2.0
Power Quality District offices responding to power quality issues
1.0
Service Extensions Pricing of service work, administration of customer service policy
13.9
C13 Total ($ million) 21.2
1 Customer services costs are forecast separately for the Diesel class. Diesel is therefore excluded from all allocators.
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 4 Schedule 4.3 Customer Service Allocation Table
Manitoba Hydro May 2017 PCOSS18 Page 19
C11 Billings
Adjustments & Complex Billing
Activities associated with billing large and/or complex customers, master bills, applicable taxes, any detailed analysis associated with billing
2.2 Weighted Customer Count
All‐‐allocation based on estimate of time spent serving each class
Customer Accounts Administration of loans, customer moves, equal payment plan.
0.7 Allocation based on number of customer accounts excl. GSL (provided through I&CS), A&RL (provided in Complex Billing)
Field Billing District Office costs for payment receipt, cash balancing, moves, new customer accounts
7.2 Allocation based on number of customer accounts excluding GSL (billing inquiries handled by I&CS)
CIS Admin Support for staff using Banner, iNovah and MyBill.
1.2 All‐ allocation based on the number of customers (customer accounts for A&RL)
Administrative Postage, bill printing, Contact Centre billing related calls, and Banner maintenance
10.4
C11 Total 21.7
C12 Collections
Excl GSL, ARL
Collections Cost of customer collection activities and bad debt expense
11.7 Weighted Customer Count
Historical data of collection activity and bad debt categorizes between res and commercial. Commercial portion prorated between classes on customer count A&RL excluded‐‐ historically no collection issues. Infrequent GSL collection activities through I&CS.
C14 Inspections
Excludes A&RL
Inspections Inspection of customer‐owned plant 3.5 Weighted Customer Count
Historical data categorizes between residential and commercial. Costs then prorated based on customer count. A&RL facilities not customer‐owned and thus excluded
C15 Meter Reading
Excludes A&RL
Meter Reading Cost of meter reading activities 10.4 Weighted Customer Count
Weights reflect the relative frequency of meter reads. Excludes unmetered A&RL
Total Customer Service 86.7
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 4 Schedule 4.4 Updated Billings Weighting Factors
Manitoba Hydro May 2017 PCOSS18 Page 20
2018
Unweighted
Customer
Adjustments
& Complex
Billing1 CIS Admin2Customer
Accounts2 Field Billing2
Admin
(Postage,
Contact
Center,
Banner)2
Residential ‐ Std & A/E 485,421 70.8% 83.7% 83.9% 83.8% 83.7%
Residential ‐ Seasonal 19,717 1.0% 3.4% 3.4% 3.4% 3.4%
Residential ‐ FRWH 3,104 0.5% 0.5% 0.5% 0.5%
GSS ND 53,751 5.3% 9.3% 9.3% 9.3% 9.3%
GSS Demand 12,867 1.3% 2.2% 2.2% 2.2% 2.2%
GSS Seasonal 909 0.0% 0.2% 0.2% 0.2% 0.2%
GSS FRWH 328 0.1% 0.1% 0.1% 0.1%
GSM 2,152 16.5% 0.4% 0.4% 0.4% 0.4%
GSL 0‐30 kV 325 3.8% 0.1% 0.1%
GSL 30‐100 kV 40 0.5% 0.0% 0.0%
GSL >100kV 16 0.2% 0.0% 0.0%
A&RL 1,221 0.6% 0.2% 0.2% 0.2%
579,851 100.0% 100.0% 100.0% 100.0% 100.0%
1 ‐ shares based on estimate of time serving each class
2 ‐ shares based on customer count, limited to classes served by department
Billing Electric EFT's Forecast $
18.8 9.8 5.8 4,063,974
2018 Forecast Operating ($)
2,221,560 1,155,211 687,203 7,235,191 10,429,341
2018
Unweighted
Customer
Adjustments
& Complex
Billing CIS Admin
Customer
Accounting Field Billing
Admin
(Postage,
Contact
Center,
Banner) Total Cost Unit Cost
Weighting
Factor
Residential ‐ Std & A/E 485,421 1,572,865 967,083 576,884 6,060,907 8,730,900 17,908,638 36.89 1.10
Residential ‐ Seasonal 19,717 21,237 39,281 23,432 246,184 354,635 684,769 34.73 1.00
Residential ‐ FRWH 3,104 ‐ 6,184 3,689 38,756 55,829 104,458 33.65 1.00
GSS ND 53,751 118,303 107,086 63,879 671,128 966,779 1,927,175 35.85 1.10
GSS Demand 12,867 28,320 25,634 15,291 160,656 231,429 461,330 35.85 1.10
GSS Seasonal 909 979 1,811 1,080 11,350 16,349 31,569 34.73 1.00
GSS FRWH 328 ‐ 653 390 4,095 5,899 11,038 33.65 1.00
GSM 2,152 366,557 4,287 2,557 26,870 38,706 438,978 203.99 6.10
GSL 0‐30 kV 325 85,276 647 ‐ ‐ 5,846 91,769 282.37 8.40
GSL 30‐100 kV 40 10,496 80 ‐ ‐ 719 11,295 282.37 8.40
GSL >100kV 16 4,198 32 ‐ ‐ 288 4,518 282.37 8.40
A&RL 1,221 13,329 2,433 ‐ 15,245 21,961 52,968 43.38 1.30
579,851 2,221,560 1,155,211 687,203 7,235,191 10,429,341 21,728,506
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 4 Schedule 4.5 Updated Collections Weighting Factor
Manitoba Hydro May 2017 PCOSS18 Page 21
Accoun
ts in
Arre
ars
As at F
eb 2017
Share
Resid
entia
l > 90 da
ys18,522
92.5%
Gene
ral Servic
e > 60
days
1,492
7.5%
20,014
100.0%
Bad De
bt Expen
se $
2014/15
2015/16
Resid
entia
l2,899,744
4,079,678
Gene
ral Servic
e575,999
652,689
Total
3,475,743
4,732,367
Bad De
bt Expen
se $
2014/15
2015/16
Average
Resid
entia
l83%
86%
84.8%
Gene
ral Servic
e17%
14%
15.2%
Forecast Collection Co
sts
9,186,206
Forecast Bad
Deb
t Expen
se2,544,000
Resid
entia
lGe
neral Servic
eRe
siden
tial
Gene
ral Servic
e
Accoun
ts Collections
Collections
Bad
Deb
t
Expe
nse
Bad
Deb
t
Expe
nse
Total
Unit
Weight
8,501,394
684,812
2,157,770
386,230
Resid
entia
l485,421
8,169,560
2,073,546
10,243,106
21.1
1.4
Resid
entia
l Seasona
l19,717
331,834
84,224
416,058
21.1
1.4
Total R
esiden
tial
505,138
GSS N
D53,751
528,270
297,941
826,211
15.4
1.0
GSS D
eman
d12,867
126,458
71,322
197,780
15.4
1.0
GSS S
easona
l909
8,934
5,039
13,972
15.4
1.0
GSM in
cl SEP
2,152
21,150
11,929
33,079
15.4
1.0
Total G
eneral Se
rvice
69,679
Total
8,501,394
684,812
2,157,770
386,230
11,730,206
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 4 Schedule 4.6 Updated Meter Reading Weighting Factor
Manitoba Hydro May 2017 PCOSS18 Page 22
Met
er R
eadi
ng W
eigh
ting
Fac
tor
2017
/18
Met
er R
eadi
ng F
requ
ency
2017
/18
Ann
ual M
eter
Rea
ding
s
Bi-
Bi-
Mon
thly
Mon
thly
Ann
ual
Self
Rea
dT
otal
Mon
thly
Mon
thly
Ann
ual
Self
Rea
dT
otal
Wei
ghtin
gR
ate
Cla
ss12
/yr
6/yr
1/yr
ever
y 3
yr12
61
1/3
Fact
or
Res
iden
tial
405,
363
80,0
5848
5,42
12,
432,
178
26,6
862,
458,
864
5R
esid
entia
l - S
easo
nal
19,7
1719
,717
19,7
1719
,717
1
GSS
Non
Dem
and1
53,0
1753
,017
318,
102
318,
102
6G
SS D
eman
d12
,867
12,8
6715
4,40
415
4,40
412
GSS
Sea
sona
l90
990
990
990
91
SEP
- GSM
2727
324
324
12SE
P - G
SL4
448
4812
GSM
2,12
52,
125
25,5
0025
,500
12
GSL
0 -
30 k
V32
132
13,
852
3,85
212
GSL
30
kV -
100
kV40
4048
048
012
GSL
> 1
00 k
V16
1619
219
212
15,4
0045
8,38
020
,626
80,0
5857
4,46
418
4,80
02,
750,
280
20,6
2626
,686
2,98
2,39
2
Not
e 1
- exc
lude
s 73
4 no
n-m
eter
ed a
ccou
nts
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 4 Schedule 4.7 Updated Meter Investment Weighting Factor
Manitoba Hydro May 2017 PCOSS18 Page 23
Customer Class Weighted Average
Cost Weight
Residential
$34.6
1.1
GSS ND ‐ single phase
$31.9
1.0
GSS ND ‐ three phase
$453.3
14.2
GSS D ‐ single phase
$364.6
11.4
GSS D ‐ three phase
$3,365.4
105.5
GSM
$3,900.7
122.3
GSL 0‐30kV
$13,338.9
418.2
GSL 30‐100kV
$49,411.0
1,549.1
GSL >100kV
$106,010.1
3,323.7
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 4 Schedule 4.8 Updated SCADA Allocator
Manitoba Hydro May 2017 PCOSS18 Page 24
SCADA Allocator
Station Name RTU
Count Gen Trans Subtrans Dist
Atwood Station ‐ 1079 4 0% 0% 0% 100%
Adelaide Station ‐ 1530 1 0% 0% 0% 100%
Amy Station ‐ 1506 1 0% 0% 0% 100%
Arlington Station ‐ 1504 1 0% 0% 0% 100%
Ashern Station ‐ 2338 1 0% 100% 0% 0%
Birchtree Station ‐ 2659 1 0% 100% 0% 0%
Birtle Station ‐ 2644 1 0% 100% 0% 0%
Bissett DSC ‐ 3829 1 0% 0% 0% 100%
Border Main Station ‐ 2822 1 0% 100% 0% 0%
Boyd Station ‐ 1510 1 0% 0% 0% 100%
Brandon Generation Station 1 100% 0% 0% 0%
Brandon Victoria Station ‐ 2060 1 0% 100% 0% 0%
Burrows Station ‐ 1527 1 0% 0% 0% 100%
Cambridge Station ‐ 1515 1 0% 0% 0% 100%
Carberry North Station ‐ 2149 1 0% 0% 0% 100%
Charles Station ‐ 1511 1 0% 0% 0% 100%
Chisago 500 Station (US) 1 0% 100% 0% 0%
Church Station ‐ 1525 1 0% 0% 0% 100%
Cliff Lake Main Station ‐ 2744 1 0% 100% 0% 0%
Cornwallis Station ‐ 2590 1 0% 100% 0% 0%
Court Station ‐ 1086 1 0% 0% 0% 100%
Crocus Plains Station ‐ 2735 1 0% 0% 0% 100%
Dawson Road Station ‐ 1008 1 0% 0% 0% 100%
Des Meurons Station ‐ 1009 1 0% 0% 0% 100%
Dorsey Station ‐ 1075 3 0% 100% 0% 0%
Edmonton Station ‐ 1521 1 0% 0% 0% 100%
Elm Creek Station ‐ 2738 1 0% 0% 0% 100%
Empress Station ‐ 1520 1 0% 0% 0% 100%
Fife Station ‐ 1524 1 0% 0% 0% 100%
Forbes 500 (US) 1 0% 100% 0% 0%
Fortier Station ‐ 2689 1 0% 100% 0% 0%
Glenboro Station ‐ 2634 1 0% 100% 0% 0%
Grand Rapids Generating Station 1 100% 0% 0% 0%
Grand Rapids Switching Station 1 0% 100% 0% 0%
Great Falls Generating Station 1 0% 100% 0% 0%
Harrow Station ‐ 1402 1 0% 100% 0% 0%
Henday Station ‐ 2730 1 100% 0% 0% 0%
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 4 Schedule 4.8 Updated SCADA Allocator
Manitoba Hydro May 2017 PCOSS18 Page 25
Station Name RTU
Count Gen Trans Subtrans Dist
Herblet Lake Station ‐ 2779 1 0% 100% 0% 0%
Highland Park Station ‐ 2740 1 0% 0% 0% 100%
Inco Station ‐ 2410 1 0% 100% 0% 0%
Jenpeg Station ‐ 198 2 100% 0% 0% 0%
Jessie Station ‐ 1522 1 0% 0% 0% 100%
Keewatin Station ‐ 1518 1 0% 0% 0% 100%
Keewatinohk Station ‐ 2766 1 100% 0% 0% 0%
Kelsey Generating Station 1 0% 100% 0% 0%
Kettle Generating Station 1 100% 0% 0% 0%
King Station ‐ 1501 1 0% 0% 0% 100%
Kirkfield Station ‐ 1407 1 0% 100% 0% 0%
Laverendrye Station ‐ 1435 1 0% 100% 0% 0%
Letellier Station ‐ 2074 1 0% 100% 0% 0%
Limestone Generating Station 2 100% 0% 0% 0%
Lindsay Station ‐ 1507 1 0% 0% 0% 100%
Logan Station ‐ 1523 1 0% 0% 0% 100%
Longspruce Generating Station 3 100% 0% 0% 0%
Madison Station ‐ 1043 1 0% 0% 0% 100%
Manigotagan Station ‐ 2611 1 0% 100% 0% 0%
Martin Station ‐ 1517 2 0% 0% 0% 100%
McArthur Falls Generating Station 1 0% 100% 0% 0%
McPhillips Station ‐ 1401 2 0% 100% 0% 0%
Mercy Street Main Station ‐ 2595 1 0% 100% 0% 0%
Minitonas Station ‐ 2466 1 0% 100% 0% 0%
Missi Falls Station ‐ 934 1 100% 0% 0% 0%
Mohawk Station ‐ 1046 2 0% 100% 0% 0%
Mystery Lake Road Station ‐ 2632 1 0% 100% 0% 0%
Neepawa Station ‐ 2165 1 0% 100% 0% 0%
Neepawa 230kV Station ‐ 2166 1 0% 100% 0% 0%
Notigi Station ‐ 2713 1 0% 0% 0% 100%
Overflowing River Main Station ‐ 2643 1 0% 100% 0% 0%
Parkdale Station ‐ 1409 1 0% 100% 0% 0%
Peace Gardens Station (US) 1 0% 100% 0% 0%
Pine Falls Station ‐ 2686 1 0% 100% 0% 0%
Plessis Station ‐ 1436 1 0% 100% 0% 0%
Point Du Bois Generating Station 1 100% 0% 0% 0%
Ponton Station ‐ 2699 1 0% 100% 0% 0%
Portage Sask Station ‐ 2002 1 0% 100% 0% 0%
Portage South Station ‐ 2751 1 0% 100% 0% 0%
Radisson Converter Station ‐ 4210 1 100% 0% 0% 0%
Rall's Island Station ‐ 2638 1 0% 100% 0% 0%
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 4 Schedule 4.8 Updated SCADA Allocator
Manitoba Hydro May 2017 PCOSS18 Page 26
Station Name RTU
Count Gen Trans Subtrans Dist
Raven Lake Station ‐ 2591 1 0% 100% 0% 0%
Reston South Station ‐ 2039 1 0% 100% 0% 0%
Richer Station ‐ 2756 1 0% 100% 0% 0%
Ridgeway Station ‐ 1076 2 0% 100% 0% 0%
Riel 230 kV Station 3 0% 100% 0% 0%
Roblin Main Station ‐ 2676 1 0% 100% 0% 0%
Rockwood Station ‐ 2231 1 0% 100% 0% 0%
Roseau County Station (US) 1 0% 100% 0% 0%
Ross Lake Main Station ‐ 2719 1 0% 100% 0% 0%
Rosser Station ‐ 1408 2 0% 100% 0% 0%
Rover Station ‐ 1503 1 0% 0% 0% 100%
Scotland Station ‐ 1505 1 0% 0% 100% 0%
Selkirk Generating Station 1 100% 0% 0% 0%
Seven Sisters Generating Station 2 100% 0% 0% 0%
Sherbrook Station ‐ 1514 1 0% 0% 100% 0%
Silver Station ‐ 2500 1 0% 0% 100% 0%
Slave Falls Generating Station 1 100% 0% 0% 0%
St. James Station ‐ 1026 2 0% 100% 0% 0%
St. Joseph Station ‐ 2827 1 100% 0% 0% 0%
St. Leon Station ‐ 2703 1 0% 100% 0% 0%
St. Matthews Station ‐ 1508 1 0% 0% 0% 100%
St. Vital Station ‐ 1406 2 0% 100% 0% 0%
Stafford Station ‐ 1528 1 0% 100% 0% 0%
Stanley Station ‐ 2737 1 0% 0% 100% 0%
Strathcona Station ‐ 1509 1 0% 0% 0% 100%
Taylor Station ‐ 1516 1 0% 0% 0% 100%
Transcona Station ‐ 1403 1 0% 100% 0% 0%
Transcona East Station ‐ 1098 1 0% 0% 100% 0%
Vermillion Main Station ‐ 2594 1 0% 100% 0% 0%
Virden West Station ‐ 2762 1 0% 100% 0% 0%
Whiteshell Station ‐ 2167 2 0% 100% 0% 0%
Wilkes Station ‐ 1085 1 0% 0% 0% 100%
Wuskwatim Generating Station 1 100% 0% 0% 0%
Wuskwatim Switching Station 1 0% 100% 0% 0%
York Station ‐ 1502 1 0% 0% 0% 100%
133 16% 52% 4% 29%
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Manitoba Hydro May 2017 PCOSS18 Page 27
SECTION 5: DEVELOPMENT OF CLASS LOADS
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 5 Development of Class Loads
Manitoba Hydro May 2017 PCOSS18 Page 28
Development of Class Loads
In Schedule 5.3, the energy sales at the meter are grossed up by distribution and transmission
losses from Schedule 5.1, to yield estimated energy generated to serve the various classes and
subclasses.
The class coincident peak load factors are used to derive class coincident peaks at the meter,
which are reduced by forecast DSM savings. Estimated distribution losses and transmission
losses are applied to provide the estimate of class coincident peak at generation. Finally, class
coincidence factors based on the Load Research information have been applied to derive class
Non‐coincident peaks. The calculation of class Coincident Peak and Non‐coincident Peak can
both be found in Schedule 5.3.
The Flat Rate Water Heating class coincident demand is estimated on the basis of 1 kW
customer peak for the Residential class and 3.3 kW for General Service Small class.
Street light energy consumption forecast is based on the inventory wattage multiplied by 4,200
hours of use per year, a figure based on Load Research results. The customer count is based on
May 2016 actual billing data plus forecast additions to the system of 1,202 lights to year end
2018.
Forecast export energy in PCOSS18 includes 9,166 GWh in sales, which equals 10,218 GWh at
Generation after adding back transmission losses of 1,052 GWh. This energy is used to calculate
variable hydraulic O&M costs and the pro‐rata share of water rentals attributed to exports
Computation and Assignment of Losses
In order to reflect differential losses by class, energy sales and demand must be measured at
generation as opposed to the meter when allocating energy and capacity costs. This is
accomplished by assigning distribution and transmission losses to each of the rate classes based
upon the voltage level in which they receive service.
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 5 Development of Class Loads
Manitoba Hydro May 2017 PCOSS18 Page 29
Schedule 5.1 shows the computation of expected transmission and distribution losses on
Manitoba Hydro’s Integrated System. Common bus energy losses have been taken from the
2016 Electric Load Forecast and adjusted to reflect forecast DSM savings. Distribution energy
losses are simply the difference between sales at meter and energy at common bus.
Distribution losses at time of system peak are calculated in Schedule 5.2 based on the approach
used by Mr. M. W. Gustafson in his article, “Approximating the System Loss Equation”. The
adjustment factor of ‐13% for temperature reflects the reduction in the resistivity of conductors
between 0C and ‐30C, 0C being the average Winnipeg temperature and the ambient
temperature on the peak load day usually being around ‐30C.
Distribution energy losses are assigned first. Customers receiving service at greater than 30 kV
have been assigned losses based upon a uniform percentage of metered sales (1.5%).
Customers receiving service at supply voltage less than 30 kV share in the residual losses. A
differential percentage has been assigned depending upon whether service is taken at primary
or secondary voltage level. General Service Small ‐ Three Phase, General Service Medium and
General Service Large are assumed to receive service at a primary service level, while
Residential, Area and Roadway Lighting and General Service Small ‐ Single Phase are assumed
to receive service at the secondary level. Capacity losses on the Distribution system are
assigned in a similar manner.
The table below summarizes the assignment of the Distribution energy loss differential.
Residual Losses Assigned on a Differential Percentage Basis
Secondary
Primary – Utility‐owned transformation
Primary – Customer‐owned transformation
+1.6%
‐0.1%
‐1.0%
Transmission losses are shared equally by all rate classes based upon deliveries from common
bus, i.e., sales at the meter plus assigned distribution losses.
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 5 Development of Class Loads
Manitoba Hydro May 2017 PCOSS18 Page 30
For the Surplus Energy Program customers losses are assigned consistent with the class’s
service voltage levels and transformation ownership.
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 5 Schedule 5.1 Calculation of Losses
Manitoba Hydro May 2017 PCOSS18 Page 31
MANITOBA HYDROPROSPECTIVE COST OF SERVICE STUDY
March 31, 2018
CALCULATION OF LOSSES
MANITOBAENERGY (in MWh) HYDRO
Firm Energy at Generation (After DSM) 25,814,985,118
Common Bus Losses (After DSM) 2,193,374,957
Deliveries From Common Bus 23,621,610,160
Sales at Meter 22,616,347,309
Distribution Losses 1,005,262,852
MANITOBADEMAND (in MW) HYDRO
Firm Peak Capacity At Generation (After DSM) 4,444.2
Common Bus Losses (After DSM) 353.8
Deliveries From Common Bus 4,090.4
Demand at Meter 3,859.2
Distribution Losses 231.2
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 5 Schedule 5.2 Determination of Coincident Peak Distribution Losses
Manitoba Hydro May 2017 PCOSS18 Page 32
MANITO BA HYDRO
2018 PRO SPECTIVE CO ST O F SERVICE STUDY
March 31, 2018
DETERMINATIO N O F CO INCIDENT PEAK DISTRIBUTIO N LO SSES
1) ENERGY SALES AND TOTAL LOSSES ON DISTRIBUTION SYSTEM
Energy @
Sales Losses Common Bus
RESIDENTIAL 7,586,095,624 516,097,624 8,102,193,247
G.S.S. SINGLE PHASE 1,367,289,679 93,019,517 1,460,309,197
G.S.S. THREE PHASE 2,401,792,062 122,568,368 2,524,360,430
* G.S.M. 3,227,436,082 164,702,674 3,392,138,756
* G.S.L. O - 30 1,747,861,584 73,466,202 1,821,327,786
G.S.L. 30 - 100 1,578,518,748 23,677,781 1,602,196,529
LIGHTING 82,414,669 5,606,839 88,021,508
MAN. HYDRO CONSTRUCTION 120,000,000 6,123,846 126,123,846
18,111,408,448 1,005,262,852 19,116,671,299
* (includes SEP sales)
2) COINCIDENT PEAK AT COMMON BUS
C.P. AT GENERATION 4,516.24
LESS SALES AT CB LEVEL :
- EXPORTS 0.00
- * G.S.L. >100 (548.96)
C.B. LOSSES (353.82)
EXPORT LOSSES 0.00
COINCIDENT PEAK AT COMMON BUS 3,613.47
3) LOAD FACTOR AT COMMON BUS 60.4%
(Hours per Year = 8,760)
4) EQUIVALENT HOURS LOSS FACTOR
EQF = (0.08 x 60.39%) + (0.92 x (60.39%)²)
= 0.383863
5) NO LOAD LOSS FACTOR AS A PERCENTAGE OF DISTRIBUTION ENERGY LOSSES 18.00%
a) 1,005,263 x 0.1800 = 180,947 MW.H
b) 1,005,263 x 0.1800 = 20.7 MW @ PEAK
8,760
6) CO-EFFICIENT OF SYSTEM LOSSES
= 1,005,263. - 180,947
8,760 x (3,613.47)² x 0.38386
= 0.000019
7) SYSTEM DISTRIBUTION LOSSES AT PEAK
= 20.66 + 0.000019 X (3,613.47)²
= 265.80
8) ADJUSTMENT FACTOR FOR TEMPERATURE -13.0%
9) SYSTEM DISTRIBUTION LOSSES AT PEAK ASSIGNED IN COSS 231.242 MW
10) RELATIONSHIP PEAK TO AVERAGE LOSSES (based on sales @ meter).
AVERAGE (KW.h) 1,005,263 / 18,111,408 = 5.55%
PEAK (MW) 231.24 / 3,382.224 = 6.84%
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 5 Schedule 5.3 Prospective Peak Load Report – Using Top 50 Peak Hours
Manitoba Hydro May 2017 PCOSS18 Page 33
2018 Prospective Cost of Service StudyProspective Peak Load ReportUsing Top 50 Peak Hours Energy Data
Forecast Total KW.hForecast Total KW.h Forecast Sales KW.h Generated# Cust. Sales DSM KW.h After DSM Distribution Common Bus Adjusted
C90 Before DSM Savings E20 Losses Losses E12
Residential Residential 485,421 7,614,181,121 (127,969,536) 7,486,211,585 509,302,308 742,420,175 8,737,934,068 Seasonal 19,717 88,790,723 - 88,790,723 6,040,615 8,805,525 103,636,863 Water Heating 3,104 11,093,316 - 11,093,316 754,701 1,100,143 12,948,160
Total Residential 508,242 7,714,065,160 (127,969,536) 7,586,095,624 516,097,624 752,325,843 8,854,519,090
GS Small - Single Phase Non-Demand 41,470 956,390,990 (23,296,343) 933,094,647 63,480,340 92,536,563 1,089,111,550 Demand 4,197 435,182,203 (10,136,170) 425,046,033 28,916,752 42,152,529 496,115,314
Subtotal 45,667 1,391,573,193 (33,432,514) 1,358,140,679 92,397,092 134,689,092 1,585,226,864 Seasonal 909 5,460,000 - 5,460,000 371,455 541,477 6,372,932 Water Heating 328 3,689,000 - 3,689,000 250,970 365,844 4,305,815
Total Single Phase 46,904 1,400,722,193 (33,432,514) 1,367,289,679 93,019,517 135,596,414 1,595,905,611
GS Small - Three Phase Non-Demand 12,281 697,370,650 (16,986,971) 680,383,679 34,721,373 66,400,787 781,505,839 Demand 8,670 1,762,459,204 (41,050,822) 1,721,408,382 87,846,996 167,997,669 1,977,253,047
Total Three Phase 20,951 2,459,829,854 (58,037,792) 2,401,792,062 122,568,368 234,398,456 2,758,758,886
Total G.S.Small Non-Demand 53,751 1,653,761,640 (40,283,314) 1,613,478,326 98,201,713 158,937,350 1,870,617,389 Demand 12,867 2,197,641,407 (51,186,992) 2,146,454,415 116,763,748 210,150,198 2,473,368,360 Sub-Total G.S. Small 66,618 3,851,403,047 (91,470,306) 3,759,932,741 214,965,461 369,087,548 4,343,985,750 Seasonal 909 5,460,000 - 5,460,000 371,455 541,477 6,372,932 Water Heating 328 3,689,000 - 3,689,000 250,970 365,844 4,305,815 Total GS Small 67,855 3,860,552,047 (91,470,306) 3,769,081,741 215,587,886 369,994,870 4,354,664,497
General Service - Medium 2,125 3,284,168,472 (79,732,390) 3,204,436,082 163,528,937 312,731,015 3,680,696,034
General Service - Large0 - 30 Kv 321 1,810,414,755 (65,053,171) 1,745,361,584 73,361,122 168,876,754 1,987,599,460
30 - 100 kV 39 1,447,300,000 (64,627,251) 1,382,672,749 20,740,091 130,313,326 1,533,726,166 30 - 100 kV - Curtailment Cust's 1 205,000,000 (9,154,001) 195,845,999 2,937,690 18,457,978 217,241,667
Over 100 Kv 14 2,772,402,000 (16,798,788) 2,755,603,212 - 255,870,410 3,011,473,622 Over 100 Kv - Curtailment Cust's 2 1,760,000,000 (10,664,351) 1,749,335,649 - 162,433,847 1,911,769,496
Total G.S.- Large 377 7,995,116,755 (166,297,562) 7,828,819,193 97,038,904 735,952,314 8,661,810,411
SEPGSM 27 23,000,000 23,000,000 1,173,737 2,244,642 26,418,380 GSL 0 - 30 Kv 4 2,500,000 2,500,000 105,080 241,894 2,846,974 Total SEP 31 25,500,000 - 25,500,000 1,278,817 2,486,536 29,265,353
Street Lighting 131,695 89,414,746 (18,853,882) 70,560,864 4,800,400 6,997,639 82,358,903 Sentinel Lighting 26,287 11,853,805 - 11,853,805 806,439 1,175,562 13,835,805
Total - Lighting 157,982 101,268,551 (18,853,882) 82,414,669 5,606,839 8,173,201 96,194,709
Total - General Consumers 736,612 22,980,670,985 (484,323,676) 22,496,347,309 999,139,006 2,181,663,779 25,677,150,094
Extra Provincial - - - - - Man Hydro - Construction 120,000,000 120,000,000 6,123,846 11,711,178 137,835,024
Integrated System 736,612 23,100,670,985 (484,323,676) 22,616,347,309 1,005,262,852 2,193,374,957 25,814,985,118
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 5 Schedule 5.3 Prospective Peak Load Report – Using Top 50 Peak Hours
Manitoba Hydro May 2017 PCOSS18 Page 34
2018 Prospective Cost of Service StudyProspective Peak Load ReportUsing Top 50 Peak Hours Demand Data
Class ClassCP @ Demand Demand
CP CP @ Meter Forecast CP @ Meter Distrib Common Bus Gen. Class NCP MW NCP MWLoad Before DSM DSM MW After DSM Losses Losses MW Coinc. @ Meter @ Gen.Factor MW Savings MW MW MW D13/D14 Factor D50 D20
Residential Residential 50.6% 1,718.3 (47.6) 1,670.7 136.8 156.3 1,963.9 90.0% 1,856.7 2,182.4 Seasonal 157.8% 6.4 6.4 0.5 0.6 7.6 8.0% 80.3 94.4 Water Heating 63.8% 2.0 2.0 0.2 0.2 2.3 80.0% 2.5 2.9
Total Residential 51.0% 1,726.7 (47.6) 1,679.1 137.5 157.1 1,973.7 86.6% 1,939.4 2,279.7
GS Small - Single Phase Non-Demand 62.4% 174.8 (5.7) 169.2 13.9 15.8 198.8 86.8% 194.9 229.1 Demand 66.4% 74.8 (2.4) 72.4 5.9 6.8 85.1 90.4% 80.1 94.2
Subtotal 63.6% 249.7 (8.1) 241.6 19.8 22.6 284.0 87.8% 275.1 323.3 Seasonal 162.5% 0.4 0.4 0.0 0.0 0.5 8.0% 4.8 5.6 Water Heating 69.1% 0.6 0.6 0.0 0.1 0.7 75.0% 0.8 1.0
Total Single Phase 63.8% 250.7 (8.1) 242.6 19.9 22.7 285.1 86.4% 280.7 329.9
GS Small - Three Phase Non-Demand 62.4% 127.5 (4.1) 123.4 7.5 11.3 142.2 86.8% 142.1 163.8 Demand 66.4% 303.1 (9.9) 293.3 17.9 26.9 338.1 90.4% 324.5 374.1
Total Three Phase 65.2% 430.6 (14.0) 416.6 25.4 38.2 480.3 89.3% 466.6 537.9
Total G.S.Small Non-Demand 60.9% 302.3 (9.8) 292.5 21.4 27.2 341.0 86.8% 337.1 393.0 Demand 64.8% 378.0 (12.3) 365.7 23.8 33.7 423.2 90.4% 404.6 468.3 Sub-Total G.S. Small 64.6% 680.3 (22.1) 658.2 45.2 60.8 764.2 88.7% 741.7 861.2 Seasonal 162.3% 0.4 - 0.4 0.0 0.0 0.5 8.0% 4.8 5.6 Water Heating 69.1% 0.6 - 0.6 0.0 0.1 0.7 75.0% 0.8 1.0 Total GS Small 64.7% 681.3 (22.1) 659.2 45.2 60.9 765.4 88.2% 747.3 867.8
General Service - Medium 73.0% 513.8 (15.2) 498.6 30.4 45.8 574.7 91.3% 546.0 629.3
General Service - Large0 - 30 Kv 80.3% 257.5 (16.6) 240.9 12.0 21.9 274.8 89.9% 268.1 305.8
30 - 100 kV 91.3% 180.9 (8.7) 172.3 3.2 15.2 190.6 76.9% 224.0 247.9 30 - 100 kV - Curtailment Cust's 96.1% 24.4 (1.2) 23.2 0.4 2.0 † 25.7 95.6% 24.3 26.9
Over 100 Kv 91.0% 347.8 (3.5) 344.2 - 29.8 374.0 85.8% 401.3 436.0 Over 100 Kv - Curtailment Cust's 97.1% 206.8 (2.1) 204.7 - 17.7 † 222.4 85.3% 240.1 260.9
Total G.S.- Large 89.7% 1,017.4 (32.0) 985.4 15.6 86.6 1,087.6 85.1% 1,157.8 1,277.5
SEPGSM 47.3% 5.5 5.5 0.3 0.5 6.4 84.0% 6.6 7.6 GSL 0 - 30 Kv 157.1% 0.2 0.2 0.0 0.0 0.2 10.9% 1.7 1.9 Total SEP 50.8% 5.7 - 5.7 0.3 0.5 6.6 69.3% 8.3 9.5
Street Lighting 76.2% 13.4 (2.8) 10.6 0.9 1.0 12.4 65.1% 16.3 19.1 Sentinel Lighting 76.2% 1.8 - 1.8 0.1 0.2 2.1 65.1% 2.7 3.2
Total - Lighting 76.2% 15.2 (2.8) 12.4 1.0 1.2 14.5 65.1% 19.0 22.3
Total - General Consumers 66.2% 3,960.2 (119.8) 3,840.4 230.1 352.1 4,422.6 86.9% 4,417.8 5,086.2
Extra Provincial 0.0% - - - 0.0Man Hydro - Construction 73.0% 18.8 18.8 1.1 1.7 21.6
Integrated System 66.3% 3,978.9 (119.8) 3,859.2 231.2 353.8 4,444.2
† Demand for curtailable customers is forecast as if customers are not curtailed at time of system peak.
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Manitoba Hydro May 2017 PCOSS18 Page 35
SECTION 6: REVENUE
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 6 Schedule 6.1 Adjusted Revenue Including DSM Reduction at Approved Rates
Manitoba Hydro May 2017 PCOSS18 Page 36
2018 PROSPECTIVE COST OF SERVICE STUDYADJUSTED REVENUE INCLUDING DSM REDUCTION @ APPROVED RATES
For Year Ended March 31, 2018
GeneralUnadjusted Transfer to Allowable Revenue To Operating To Export Other Consumer Total adjusted
Revenue Class Revenue BPIII Reserve after BPIII Reserve Expense Revenue Accrual Adjustment Revenue
ResidentialResidential 639,179,993 (46,089,792) 593,090,201 138,810 4,578,118 597,807,129 Seasonal 8,863,561 (639,131) 8,224,430 63,485 8,287,915 Water Heating 1,081,149 (77,959) 1,003,190 235 7,744 1,011,168
649,124,703 (46,806,882) 602,317,821 - - 139,045 4,649,347 607,106,212
General Service - Small
Non Demand 148,861,976 (10,734,093) 138,127,883 32,328 263,979 138,424,190 Seasonal 685,949 (49,462) 636,487 1,216 637,703 Water Heating 448,802 (32,362) 416,440 97 796 417,333 Total Non Demand 149,996,727 (10,815,917) 139,180,810 - - 32,426 265,991 139,479,227
Demand 158,066,037 (11,397,777) 146,668,260 34,327 280,301 146,982,888 158,066,037 (11,397,777) 146,668,260 - - 34,327 280,301 146,982,888
SEPGSM 763,052 763,052 179 1,458 764,689 GSL 0-30kV 78,825 78,825 18 151 78,994
841,877 - 841,877 - - 197 1,609 843,683
General Service - Medium 206,195,123 (14,868,254) 191,326,869 44,779 365,649 191,737,297 206,195,123 (14,868,254) 191,326,869 - - 44,779 365,649 191,737,297
General Service - Large 0 - 30 kV 96,412,556 (6,952,087) 89,460,469 20,938 170,970 89,652,377 30 - 100 kV 66,767,573 (4,814,455) 61,953,118 61,953,118 30-100 kV Curtailable 8,667,271 (624,977) 8,042,294 8,042,294 > 100 kV 121,247,532 (8,742,879) 112,504,653 112,504,653 > 100 kV Curtailable 73,234,329 (5,280,758) 67,953,570 67,953,570
366,329,261 (26,415,157) 339,914,104 - - 20,938 170,970 340,106,012
Area & Roadway LightingStreet Lighting 19,818,490 (1,429,066) 18,389,424 18,389,424 Sentinel Lighting 3,421,568 (246,721) 3,174,847 743 6,068 3,181,657
23,240,058 (1,675,787) 21,564,271 - - 743 6,068 21,571,082
Diesel Residential 748,964 (54,006) 694,958 694,958 Full Cost 7,192,116 (518,607) 6,673,509 6,673,509
7,941,080 (572,613) 7,368,467 - - - - 7,368,467
General Consumers 1,561,734,866 (112,552,387) 1,449,182,479 - - 272,455 5,739,934 1,455,194,869
Accrual - Other 293,628 (21,173) 272,455 (272,455) - Miscellaneous - Non-Energy 879,000 (63,383) 815,617 (815,617) - Late Pmt & Cust Adj - Residential 5,010,654 (361,307) 4,649,347 (4,649,347) - Late Pmt & Cust Adj - Other 1,175,338 (84,751) 1,090,588 (1,090,588) - Total General Consumers 1,569,093,486 (113,083,000) 1,456,010,486 - (815,617) - - 1,455,194,869
BP III Reserve (113,083,000) - Extra-Provincial 454,201,375 454,201,375 944,617 455,145,992 Other (Non Energy) 30,312,945 30,312,945 (30,183,945) (129,000) - Total Revenue 1,940,524,806 (113,083,000) 1,827,441,806 (30,183,945) - - - 1,910,340,861
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Manitoba Hydro May 2017 PCOSS18 Page 37
SECTION 7: HISTORICAL RCC RATIOS
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1
Section 7 Schedule 7.1 Historical RCC Ratios
Manitoba Hydro May 2017 PCOSS18 Page 38
PCOSS18
PCOSS14
164/16
PCOSS14‐
Amen
ded
PCOSS13
PCOSS11
PCOSS10
PCOSS08
116/08
PCOSS08
117/06
PCOSS06
117/06
PCOSS06
PCOSS04
PCOSS03
PCOSS02
PCOSS01
PCOSS99
PCOSS97
PCOSS95
Residential 94.8% 95.5% 99.9% 99.2% 95.9% 96.4% 96.2% 96.4% 94.1% 97.0% 90.6% 92.4% 96.5% 90.7% 92.1% 91.4% 90.2%
GSS ND 112.5% 108.5% 108.0% 107.6% 104.8% 105.7% 101.4% 104.3% 107.4% 107.4% 104.9% 107.3% 109.4% 104.4% 106.9% 107.3% 107.8%
GSS D 101.0% 103.4% 104.5% 103.7% 103.8% 102.8% 107.8% 107.2% 106.9% 105.4% 109.7% 108.4% 104.7% 105.4% 107.7% 104.5% 105.3%
GSM 98.3% 100.3% 99.3% 100.0% 101.1% 101.3% 100.2% 101.1% 101.4% 100.6% 104.8% 102.9% 104.4% 109.4% 105.5% 102.4% 106.1%
GSL 0–30kV 99.1% 96.1% 91.1% 93.3% 91.9% 92.3% 89.9% 90.4% 91.3% 90.1% 99.9% 93.4% 96.8% 102.6% 101.4% 100.9% 105.2%
GSL 30‐100kV 109.3% 108.0% 99.8% 96.6% 104.2% 106.8% 108.4% 103.7% 104.7% 101.5% 109.5% 108.8% 109.4% 118.8% 110.3% 108.1% 111.8%
GSL >100kV 108.6% 107.1% 98.5% 100.5% 112.6% 109.2% 112.0% 108.7% 110.0% 103.2% 114.2% 113.5% 99.8% 115.9% 109.5% 111.0% 110.9%
A&RL 100.3% 99.5% 100.3% 101.8% 105.2% 100.0% 102.4% 105.8% 107.7% 107.1% 108.9% 109.9% 101.9% 92.0% 93.4% 108.8% 119.6%
Manitoba Hydro 2017/18 & 2018/19 General Rate Application Appendix 8.1