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A
Good
morning,
broadcast
services
do
we
have
director
bobzian
on
Zoom.
A
All
right
we'll
call
this
meeting
of
the
Nevada's
Regional
transmission
coordination
task
force
to
order,
and
we
have
with
us
director
bobsian
on
the
zoom
and
I
think
we
have
Laura
Wickham
in
Carson
City
and
we
have
and
I'm
I
want
to
make
sure
I'm
saying
your
name
correct.
Here
we
have
Leslie
helget
in
in
Las
Vegas
with
us
and
so
Michelle
good.
A
All
right,
we
have
a
quorum
and
we
can
now
start
with
our
first
agenda
item,
which
is
public
comment,
and
the
public
comment
is
information
was
on
the
agenda
that
was
posted
and
that
was
distributed,
and
it
is.
A
I'm
sorry
I'm
trying
to
find
the
the
phone
number
but
I
don't
have
it
here
in
front
of
me,
but
if
we
could
please
limit
our
public
comment
to
about
three
minutes
per
person.
I
would
appreciate
that
and
we
can
get
started
so
do
we
have
anyone
on
the
phone
for
oh
I'm,
sorry
we'll
go
here
in
person
in
Las,
Vegas
and
and
then
we'll
go
up
to
Carson
City,
then
we'll
go
to
the
phone
good
morning.
Please
go
ahead
good
morning,
chair
Brooks
and
members.
B
Of
the
task
force,
my
name
is
jaina,
moan
and
I'm.
The
external
Affairs
director
for
The
Nature
Conservancy
in
Nevada
I'm
here
today
to
tell
you
about
a
new
study
that
The
Nature
Conservancy
released
last
week
called
power
of
Place
West.
It
is
a
comprehensive
energy,
economic
and
geospatial
study
that
analyzed
dozens
of
scenarios
that
achieve
clean
energy
goals
by
2050
in
11
Western
States.
B
Detailed
ecosystem
and
wildlife
habitat
information.
This
analysis
is
necessary
because
without
being
mindful
about
where
and
how
we
develop
this
new
energy
capacity,
we
risk
losing
some
of
the
West's
most
important
natural
areas
and
working
lands.
Currently,
50
of
all
renewable
projects
are
being
developed
on
top
of
our
most
productive
natural
areas
and
working
lands.
But
power
of
a
Place
West
reveals
good
news.
Our
research
discovered
that
there
are
four.
There
are
ways
for
our
western
states
to
affordably
meet
their
future.
B
Energy
energy
needs
achieve
economy-wide
Net,
Zero,
greenhouse
gas
emission
reductions
and
avoid
our
most
sensitive
natural
areas
and
working
lands
all
at
the
same
time,
specifically,
the
researchers
identified
an
optimal
development
scenario
that
affordably
reaches
Net
Zero
by
2050,
while
still
preserving
nearly
50
percent,
more
sensitive
natural
areas
and
working
lands
than
by
following
Today's
Energy
development
practices.
This
scenario
called
the
high
electrification
scenario,
assumes
economy-wide
electrification
of
energy
production,
Transportation,
building
and
Manufacturing
sectors.
It
includes
a
diversity
of
clean
energy
and
Climate
Technologies.
C
C
Serving
on
this
task
force,
we
encourage
you
to
check
out
the
power
of
Place
West
study
at
www.nature.org,
backslash
power
of
place
and
act
on
its
recommendations.
Thank
you
so
much
for
the
opportunity
to
come
and
speak
to
you
here
and
thank
you
for
your
service
on
this
task
force.
Thank
you,
Miss
moan.
C
Could
you
make
sure
that
you
get
with
Miss
ellget
from
the
office
governor's
office
of
energy
and
share
that
document
so
that
we
can
put
they
can
post
that
on
the
website,
where
we're
keeping
all
the
documents
for
this
particular
committee
and
that
way
committee
members
can
take
a
look
at
it
and
public
can
reference
it
as
well.
Absolutely.
Thank
you.
Thank
you.
Thank
you.
C
My
name
is
John
Williams
I'm,
with
the
Bonneville
power
Administration
good
afternoon,
Mr
chairman
of
morning,
sorry
about
that
I'm
in
Boise.
So
we're
an
hour
ahead
of
you
and
members
of
the
coordination
task
force.
Meeting
I
would
like
to
just
briefly
describe
BPA
our
service
area
and
our
participation
in
Regional
transmission
affairs.
C
C
C
Ppa
is
going
through
an
internal
process
in
the
next
phase
of
the
western
resource
adequacy.
Excuse
me
advocacy
program.
As
you
know,
co-generation
is
terminating
the
next
several
ten
years
and
Bonneville
and
other
utilities
are
working
to
ensure
a
reliable
transmission
grid,
and
to
do
that,
we
need
to
work
together,
coordinate
and
make
sure
we
have
the
resources
for
the
citizens
of
the
Pacific
Northwest,
as
well
as
the
Western
connect
connection,
which
involves
California
Nevada,
Utah
Wyoming
bpas,
also
participating
in
the
southwest
power
pools
next
phase
of
its
markets
plus
development
program.
C
C
C
C
C
C
So,
as
the
committee
looks
at
different
ways,
the
state
should
move
forward
as
the
point
of
contact
for
Bonneville
I
plan
to
continue
to
attend
your
meetings
and
whatever
you
need
from
Bonneville
I'm
here
to
help
out
the
best
way
I
can
and
with
that
Mr
chairman.
That
concludes
my
comments.
Thank
you.
Thank
you,
sir
good,
to
see
you
again
and
thank
you
for
the
update,
the
the
continuing
updates
from
Bonneville
and
appreciate
that
and
look
forward
to
to
hearing
from
you
again
at
the
next
meeting.
Yes
and
I
think
I
almost
forgot.
C
We
did
join
the
Imaging
balanced
market
and
we're
going
through
all
the
procedures
and
process
for
payments
and
all
the
things
that
go
along
with
that
and
so
forth.
Working
out
well
right
on
well
I
appreciate
that.
Thank
you
for
the
update.
Thank
you.
Anyone
else
down
here
in
Las
Vegas
for
public
comment,
all
right.
Let's
move
up
to
Carson
City,
and
is
there
anyone
in
Carson
City
for
a
public
comment.
C
C
C
C
That's
in
part
because
Nevada's
electric
grid
and
more
broadly
grid
infrastructure
across
the
West
currently
operates
like
a
bunch
of
islands.
Each
responsible
for
serving
all
extremes,
primarily
on
its
own,
a
regional
transmission
organization
or
RTO
connecting
the
western
states
would
allow
Nevada
to
tap
into
affordable,
clean
energy
from
sources
across
the
entire
western
region.
During
all
weather
conditions,
export
excess,
Nevada
Energy
when
there
is
a
surplus
and
develop
the
appropriate
transmission
infrastructure
to
ensure
maximum
grid
efficiencies.
B
At
lowest
cost
this
would
help
Nevada,
lower
electricity
costs
for
homes
and
businesses
boost
to
the
local
economy
and
bring
thousands
of
living
wage
jobs
to
the
Silver
State.
In
fact,
awe
just
released
a
report
two
weeks
ago
that
looks
at
the
economic
impact
of
a
west-wide
RTO
on
Nevada's
economy.
The
analysis
shows
that
joining
a
western
RTO
would
save
Nevada
in
32
million
dollars
per
year.
B
Altogether.
A
western
RTO
would
add
tens
of
millions
to
hundreds
of
millions
of
dollars
to
state
to
local
and
state
tax
revenues
and
between
550
million
and
2.2
billion
to
Nevada's
Gross
State
product
each
year.
I've
shared
the
report
with
members
of
the
task
force
via
email,
but
I'm
happy
to
Circle
up
with
anyone
to
answer
additional
questions
that
you
have
at
any
time.
We
look
forward
to
the
continued
conversation
about
how
transmission
and
energy
markets
can
benefit
Nevada,
and
thank
you
for
your
time
today.
B
B
Hi
yeah,
my
name
is
Marion
Mahoney
and
I
am
commenting
today
on
behalf
of
series
series
is
a
national
non-profit
that
works
with
influential
businesses
and
investors
in
Nevada
and
across
the
country
to
build
Equitable
market-based
solutions
to
today's
sustainability
challenges
and,
as
part
of
this
work,
series
organizes
that
business
for
Innovative,
climate
and
energy
policy
or
bicep
Network.
A
coalition
of
over
80
major
businesses
leading
consumer
Brands
and
Fortune
500,
with
many
with
operations
and
Facilities.
B
Here
in
Nevada,
major
companies
in
the
U.S
want
to
see
Western
State
coordinate
on
a
regional
plan
to
integrate
and
deploy
clean
energy
across
this
region.
Companies
have
ambitious
climate
and
energy
goals
to
be
more
specific.
More
than
260
companies,
including
many
Fortune
500,
have
committed
to
power
all
of
their
corporate
operations
with
100
renewable
energy,
and
here
in
Nevada,
over
45
companies
have
set
a
goal
of
being
powered
by
100
renewable
energy.
B
A
reasonable
approach
that
puts
decarbonization
front
and
center
will
help
them
meet
these
goals
and
stay
competitive
in
the
global
economy.
An
approach
that
improves
access
to
cost-effective
Quick
resources
also
attracts
new
Investments,
Innovation
and
jobs,
and
because
of
its
geography
and
abundant
natural
resources.
We
know
that
Nevada
will
be
Central
to
any
Regional
wholesale
energy
Market
constructs,
so
I
want
to
thank
you
for
considering
the
perspective
of
these
large
energy
customers,
and
please
thank
you
for
this
opportunity
to
put
forward
these
comments.
B
B
Yes,
hi
good
morning,
Mr,
chair
and
members
of
the
task
force,
my
name
is
Sam
Johnston
and
I'm
grateful
to
be
here
on
behalf
of
Interwest
energy.
Alliance
Interwest
is
a
trade
Association.
We
represent
roughly
40
of
the
largest
developers
and
manufacturers
of
utility
scale,
wind,
solar
storage
and
geothermal
resources,
including
many
who
have
developed
renewable
generation
facilities
here
in
Nevada
to
begin.
We
want
to
express
our
support
and
gratitude
for
this
task
force
and
the
work
that
it
did,
that
it
has
done
so
far.
B
We
see
the
effort
for
West
wide
utility
collaboration
through
an
RTO
as
the
single
most
important
policy
effort
facing
our
industry.
This
task
force
has
an
opportunity
to
demonstrate
Nevada's
leadership
on
the
RTO
issue.
It
can
do
that
by
asserting
that
Nevada
wants
its
electrical
utilities
to
join
an
RTO
that
includes
the
largest
Western
footprint
possible.
B
That
is
critically
important
because
the
larger
the
footprint,
the
more
an
RTO,
will
deliver
cost
savings
and
reliability
to
Nevada
customers.
I
see
that
during
your
last
meeting,
chair
Brooks
shared
the
state-led
market
study,
the
state-led
market
study
found
that
an
RTO
makes
electricity
delivery
more
efficient.
B
Having
an
RTO
that
includes
the
largest
Western
footprint
possible.
Would
connect
Nevada's,
solar
resources
to
other
states
where
renewable
energy
is
in
high
demand.
That
would
maximize
the
economic
development
potential
of
Nevada's
ideal
conditions
for
solar
resource
development,
but
Nevada
won't
just
be
sending
that
energy
outside
of
its
borders,
because
having
resources
in
Nevada
that
are
connected
to
a
wide
Marketplace
elsewhere
also
makes
them
more
affordable
for
Nevada
rate
payers.
B
This
task
force
can
show
that
it
recognizes
all
those
benefits
by
asserting
that
the
best
way
forward
for
the
West
is
if
it's
utilities
join
an
RPO
that
includes
the
largest
possible
Western
footprint.
We
appreciate
the
continued
engagement
and
effort
by
this
task
force
and
we
look
forward
to
the
task
forces
report.
Thank
you.
C
C-H-R-I-S-T-I-C-A-D-R-E-R-A
and
I'm
the
deputy
director
for
the
Nevada
conservation
League
we'd,
like
to
thank
the
task
force
for
their
work
on
this
important
topic,
which
is
critical
to
addressing
the
climate
crisis.
Climate
change
is
the
greatest
threat
to
Nevada's
future.
It
is
threatening
our
water
supply,
habitat
and
Landscape.
Extreme
heat
and
Wildfire
are
harming
our
health,
our
workers
and
our
businesses
to
meet
the
ambitious
but
necessary
climate
goals
of
a
hundred
percent
clean
power
and
zero
greenhouse
gas
emissions
by
2050
that
were
set
by
governor
sicilak
and
the
legislature.
C
We
must
move
away
from
all
fossil
fuels
as
quickly
as
possible.
In
order
to
do
this,
Nevada
needs
an
updated,
state-of-the-art
electricity
grid
and
the
ability
to
move
clean,
renewable
energy
across
state
lines
by
joining
an
RTO
Nevada
will
be
able
to
utilize
more
clean
energy
across
the
West,
while
keeping
energy
costs
low,
providing
more
reliable
energy
and
boosting
our
economy
through
the
creation
of
thousands
of
good
paying
jobs.
Nevada
families
deserve
access
to
clean
energy,
clean
air
and
clean
environment.
C
Joining
a
Western,
Regional
electricity
Market
will
allow
us
to
sell
our
excess
solar
to
other
states,
and
it
will
get
us
closer
to
achieving
our
climate
and
carbon
reduction
goals
while
creating
a
cleaner,
healthier
state
for
all
nevadans.
We
look
forward
to
seeing
the
task
force
before
in
the
upcoming
week.
Thank
you
for
your
time.
C
Share
your
public
line
is
open
and
working,
but
you
have
no
more
callers
at
this
time
all
right.
Thank
you
great.
We
can.
We
can
then
move
on
to
our
next
agenda
item
and
we
can
then
get
into
our
presentations.
C
All
right
so
welcome
everyone
to
this.
This
task
force
meeting
that
was
created
in
the
last
legislative
session
with
Senate
Bill
448,
and
this
is
our
second
meeting
in
our
first
meeting,
we've
laid
the
the
we
kind
we
discussed,
what
the
need
was
and
and
what
the
potential
benefits
could
be
of
Nevada
joining
into
entering
or
creating
a
a
a
regional
transmission
organization
or
and
and
how
that
could
affect
the
price
of
electricity
in
Nevada,
the
reliability
and
and
how
we
could
help
achieve
our
clean
energy
goals.
C
This
meeting
we
want
to
have
a
presentation
we're
going
to
have
presentations
from
three
organizations:
the
California
independent
system
operator,
the
Western
power
pool
and
Southwest
power
pool
those
three
organizations
provide
actually
our
rtos
and
isos
and
resource
adequacy
organizations
that
do
the
work
in
the
west
of
the
regional
transmission
coordination,
and
so
this
will
give
us
a
good
insight
into
the
organizations
that
are
actually
stood
up
and
doing
some
of
this
work
and
how
they
could
interplay
with
Nevada
and
each
other.
C
This
year,
we've
seen
the
constant
disruption
that
has
been
caused
by
the
escalating
climate
crisis,
and
it's
we
have
increased
demand
due
to
growth
of
the
economy
and
electrification
of
of
loads
that
were
served
by
fossil
fuels,
and
we
we've
seen
an
energy
crisis
in
Europe
that
was
caused
by
the
Russian
invasion
of
Ukraine,
as
well
as
gasoline
price
escalation
based
on
you
know
the
gouging
taking
place
by
the
oil
companies
in
this
world.
It's
it's
interesting
that
they
at
the
same
time,
we
have
the
highest
gasoline
prices
like
ever.
C
The
oil
companies
have
the
highest
profit
margins
ever
and-
and
there
is
definitely
a
correlation
there.
All
of
these
issues
facing
our
world,
our
nation,
our
state,
our
economy,
have
have
one
common
denominator,
and
that
is
transmission
and
we
need
we
need
more
of
it.
We
need
to
coordinate
amongst
ourselves
how
we
use
it
and
we
need
to
optimize
it,
and
all
of
these.
C
There
are
a
few
events
that
actually
happen
in
the
west,
since
we
last
met
and
I'd
like
to
mention
them
briefly.
One
miss
Steinberg
at
AE,
Advanced,
Energy
economy
already
mentioned,
and
that
was
the
Western
RTO
economic
impact
study
and
it's
a
region-wide
analysis
that
really
shows
some
of
the
benefits
of
that
a
RTO
could
provide
for
the
west,
and
that
is
available
at
the
at
the
inner
governor's
office
of
energy
website
and
that
that
website
is
energy,
Dot
nv.gov
and
to
get
to
there's
a
tab
to
get
to
this.
C
This
task
force
and
it's
the
forward,
slash
rtctf,
but
forward
slash,
but
you
can
see
it
once
you
go
to
the
governor's
office
of
energy
website
it's
front
and
center
and
easy
to
navigate
it's
an
easy,
easy
website
to
navigate
different
than
some
of
the
other
ones
here
in
government
and
then
also
with
Advanced
Energy
economy,
released
a
Nevada
specific
report
that
has
the
benefits
that
are
are
specific
just
to
our
state
within
that
economic
impact
study,
and
that
also
is
at
the
governor's
office
of
energy
website.
C
Just
the
top
lines
from
that
report,
though,
is
a
West
wide.
Rto
would
result
in
about
32
million
per
year
in
electricity
cost
savings
for
Nevada
compared
to
operation
of
the
electrical
grid
without
a
westwide
RTO,
and
this
does
take
into
account
likely
operational
costs
for
Nevada.
It
would
provide
anywhere
between
5
000
to
21
000
permanent
jobs
across
the
state.
With
these
jobs,
averaging
total
compensation
of
65
000
per
year
General,
it
would
generate
between
500
million
and
2.2
billion
in
additional
growth
State
product
per
year
across
the
state.
C
It
would
produce
incremental
state
and
local
tax
contributions
anywhere
between
25
and
100
million
dollars
a
year
and
create
76
to
as
as
much
as
800
temporary
construction
jobs
in
2030
just
from
the
development
of
of
clean
energy
resources
that
meet
a
corporate
demand
not
even
are
necessarily
our
RPS
requirements
or
the
investor
owned
and
Public
Utilities
here
in
the
state.
C
So
there
are
a
lot
of
benefits
that
are
specific
to
Nevada
and
it
reinforces
why
it
is
that
we're
doing
this
work
and
why
we're
taking
a
look
at
this.
Another
thing
that
happened
this
summer
is
a
California
state,
assemblyman
chairman
Chris,
Holden
crafted
and
then
introduced
ACR
assembly
concurrent
resolution
188,
which
passed
both
legislative
Chambers
with
unanimous
bipartisan
vote.
C
That
ACR
can
be
found
on
the
governor's
office
of
energy
website
for
your
review
as
well.
That
measure
requires
California
independent
system
operator
to
produce
a
report
that
summarizes
recent
relevant
studies
on
the
impacts
of
expanded,
Regional
electric
grid
cooperation
on
California
and
identifies
key
issues
that
will
most
likely
Advance
the
state's
energy
and
environmental
goals,
including
any
available
studies
that
reflect
the
impact
of
regionalization
on
transmission
costs
and
reliability
for
California
rate
payers.
C
This
report
report
shall
be
completed
in
consultation
with
the
California
balancing
authorities
and
is
due
to
the
California
legislature
by
February
28
2023,
and
it
has
already
started
some
conversations
in
the
state
of
California,
and
these
conversations
are
very
important
to
Nevada,
because
you
know,
as
as
I
always
say,
Nevada
is.
Is
we
share
650
miles
of
border
with
California
and
90
percent
of
every
Nevada
lives
within
50
miles
of
California?
So
it's
very
important
what
what
is
happening
to
just
to
the
west
of
us
as
the
largest
load
in
the
western
interconnect.
C
B
Megawatt
Peak
and
I,
the
Nevada
California
and
the
rest
of
the
West
avoided
blackouts
by
working
together.
So
what
I
would
not
like
to
necessarily
be
in
the
control
rooms
at
kaiso
or
here
in
LA,
in
in
Nevada
at
NV
Energy,
when
it
was
probably
about
6
p.m,
on
September
6th
and
we
were,
we
were
being
urged
by
NV
Energy
here
in
Nevada
to
to
conserve
and
and
envy
energy
was,
was
doing
everything
they
possibly
could
to
make
sure
that
they
could
provide
reliable
service
at
that.
B
Incredibly,
trying
time
when
we
had
that
heat
wave,
I
know,
I
was
like
game
time.
I've
put
my
I
got
all
my
automated
systems.
I
shut
off
all
my
air
conditioner
and
my
pool
pumps
and
and
my
my
hybrid
water,
heater
and
I
started
discharging
my
battery
into
the
grid
and
and
my
solar
was
kicking
and
and
I
thought
it
was
a
lot
of
fun,
but
I,
don't
think
a
lot
of
other
people
did
that
do
this,
for
a
living
I
see
a
couple
heads
shaking,
but
but
the
the
key.
B
The
key
thing
here
is
is
it
worked
and
it
worked
largely
I.
Think
there's
a
few
components
why
it
worked
it
Tran.
It
was
coordination
amongst
utilities.
Oops.
Sorry
I've
talked
to
my
friends
at
sdg
e
friends
at
kaiso
friends
at
NV
Energy,
and
they
were
talking
in
real
time
about
what
was
going
on
and
how
they
could
work
together.
So
coordination,
regionally
is
is
shows
us
that
the
value
of
coordination
regionally.
But
you
know
batteries
and
demand
response
were
rock
stars
in
in
this.
B
This
historic
event,
I
can't
recall
what
the
number
was,
but
when,
when
California
put
out
that,
basically
that
Statewide
alert
where
everybody's
phone
started
buzzing
and
beeping
and
saying
hey,
we
need
to
conserve
energy
and-
and
maybe
somebody
when
they're,
giving
the
presentation
later
or
somebody
even
on
the
committee
can
tell
me
what
that
number
was.
B
But
it
was
a
tremendous
amount
of
that
was
a
three
thousand
two
thousand
megawatts
like
dropped
immediately
based
on
demand
response
and
human
behavior,
and
you
know
it
restored
some
of
my
faith
in
humans
and
my
neighbors
in
that
they
cared
about
their
neighbors
enough
to
conserve
energy
and
averted
a
crisis.
So
those
were
some
lessons
learned
batteries,
demand
response
and
coordination
amongst
utilities
regionally.
So
those
were
some
of
the
the
big
events
of
the
summer
since
we
met
last
and
reinforced.
B
Why
we're
doing
what
we're
doing
here
you
know:
Nevada's
transmission
picture
is
changing
rapidly
with
plans
from
trans
Canyons,
crosstie
project,
LS
power,
Swift,
North
project,
the
grid,
lions
and
and
all
the
things
that
they're
doing
in
the
kaiso
system
in
southern
Nevada,
and
we
have
Transwest
Express
potential
line
from
Utah
to
California
and
and
envy
energy
is
moving
forward
with
greenlink
and
and
looking
at
many
other
opportunities
to
take
advantage
of
Nevada's
Geographic
position
in
the
West's
transmission
system.
B
Nv
Energy
also
continues
its
conversations
with
neighboring
utilities
and
and
with
kaiso,
and
with
spp
and
I'm,
looking
forward
to
hearing
about
the
status
of
kaiso,
spp
and
wpp
I,
I'm
sure
whoever's,
taking
notes
hates
me
in
all
my
acronyms,
the
California
independent
system
operator
or
kaiso
Southwest
power
pool
or
spp,
Western,
powerful
or
wpp,
and
and
what
progress
they
have
made
as
the
transmission
system
and
the
electricity
markets
evolve
across
the
West.
B
So,
first
up
today
we're
going
to
take
this
a
little
bit
about
out
of
order
to
accommodate
folks
schedules
and
we
are
going
to
have
I
believe
and
correct
me.
If
I'm
wrong,
we
are
going
to
have
Southwest
power
pool
up
first,
to
give
us
a
update
and
on
on
what
it
is
that
they
do
a
little
bit
of
the
history
and
status
of
that
organization
and
I
believe
unless
I
am
incorrect,
we
have
Cara
fornstrom
from
Southwest
power
pool
or
spp
up
to
give
us
a
presentation.
B
Foreign
there
we
can
now
we
can
good
morning,
chair
Brooks
and
members
of
the
task
force.
Thank
you
so
much
for
this
invitation
to
present
with
you
today,
I
have
my
colleague,
Steve
Johnson
with
me,
I'm
going
to
go
through
a
couple
of
slides
and
then
let
him
introduce
himself.
We
will
be
doing
tag
team
this
morning.
Let
me
get
my
screen
shared
here.
B
So,
as
chair
book
said,
my
name
is
Carol
Forrester
I'm,
director
of
state
regulatory
policy
for
spp
I've,
been
with
spp
since
January
of
2021
in
this
role
prior
to
that
I
served
at
the
Wyoming
Public
Service
Commission
for
eight
years,
the
last
two
is
Chairman
and
because
most
of
my
work
for
spp
is
focused
in
the
west,
I
continue
to
reside
in
Wyoming,
so
I'm
going
to
tell
you
about
our
presentation
today
and
then
I'll
turn
it
over
to
Steve
for
these
first
slides
and
he'll
introduce
himself
as
well.
B
So
today,
as
you
indicated
as
an
introduction,
we
want
to
talk
a
little
bit
about
our
background
and
summarize
for
you.
What
we
believe
the
benefits
of
markets
are.
What
we've
seen
from
a
quantitative
and
qualitative
basis
also,
then
provide
a
summary
of
what
we're
doing
in
the
west.
Our
different
Energy
Services
that
we're
offering
mostly
on
a
contract
Service
basis,
then
we'll
spend
a
little
bit
of
time
specifically
focused
on
markets
plus
and
then
conclude
and
answer
any
questions
that
you
might
have
so
with
that.
B
Yes,
we
can
thank
you,
I'm
Steve
Johnson,
with
Southwest
power
pool
I'm,
the
director
of
markets,
Administration
for
spp
I've,
been
here
since
2020.
prior
to
that,
my
entire
career
was
in
the
west
started
in
California,
with
Hitachi
Water
and
Power
on
their
Hydro
System
city
and
county
in
San,
Francisco's
hydro
system
and
then
spent
a
20-year
career
with
Western
area
power.
B
Administration
started
out
as
a
system
operator
and
finished
up
as
senior
vice
president
over
the
Colorado
River
storage
project
before
I
came
to
spp
and
in
fact,
I
see
a
couple
familiar
names
today
from
that
endeavor.
So
with
that
I'd
like
to
get
a
little
bit
into
a
little
bit
of
spp's
background
next
slide.
B
Okay,
there
we
go
thanks,
Carol,
all
right,
so
quickly.
Spp's
mission
is
working
together
to
responsibly
and
economically,
keep
the
lights
on
today
and
in
the
future
responsibly
and
economically
are
the
keywords
there.
Obviously,
both
are
important.
A
Leading
our
industry
to
a
brighter
future
while
delivering
the
best
energy
value
so
as
we
continue
to
move
through
the
changing
Energy
Mix
that
our
industry
is
experiencing,
to
do
that.
Well,
basically,
and
how
do
we
do
that?
Basically,
how
do
we?
How
do
we
accomplish
our
mission
and
engage
in
our
vision
next
slide?
A
D
And
with
those
relationships
we
can
achieve
collaborative
collaboratively
and
engage
passionately.
If
you
are
ever
a
witness
to
our
stakeholder
processes,
you
will
see
a
lot
of
this
going
on
and
sometimes
it
takes
us
a
little
longer
to
get
something
done,
but
when
we
do
finally
get
there
and
we
get
things
in
front
of
ferc,
we
generally
see
minimal
issues
with
with
passing
through
the
first
process
to
get
something
done.
So
while
it
may
take
a
little
more
time
on
the
front
end,
we
generally
achieve
what
we
want
to
achieve
very.
D
B
So
this
comes
in
a
couple
forms
one
thing
that
that
integrated
transmission
planning
and
resource
planning
can
do
in
operations
within
an
RTO
all
those
technical
aspects,
as
it
enables
us
to
to
push
the
envelope
with
renewable
penetration
and-
and
it
also
creates
a
form
where
we
can
engage
broad
stakeholders,
a
broad
stakeholder
group
to
come
together
to
really
work
on
these
issues
and
finally,
spp
Embraces
and
promotes
diversity
not
only
within
our
staff,
that's
extremely
important,
but
within
our
stakeholder
groups
and
even
within
our
energy
resource
mix.
Next
slide.
A
So
just
quickly,
here's
our
RTO
footprint
you'll
see
several
Maps
as
we
go
through
today.
One
will
kind
of
build
on
top
of
the
other,
but.
D
This
is
our
traditional
RTO
footprint
about
we,
we
set
our
new
Peak
this
summer
about
a
little
over
53
gigawatts
of
mode
next
slide.
D
So
we're
going
to
walk
through
several
Milestones
I
won't
read
every
one
but
just
hit
some
of
the
highlights.
1941
spp
formed
actually
formed
at
the
same
time
for
the
same
reason
as
as
at
the
time
Northwest
powerful,
and
that
was
to
mine
and
process
bauxite
into
aluminum
for
the
World
War
II
effort.
Actually,
there's
a
big
box
site
deposit
here
in
Arkansas
and
the
power
pool
was
needed
to
bring
the
energy
necessary
to
to
accomplish
that
fast
forwarding.
D
A
little
bit
you'll
note
that
in
1991
we
implemented
operating
Reserve
sharing
much
the
same
again
as
Northwest
power
pool
at
the
time
in
1997
we
were
one
of
the
first
reliability
coordinators,
we're
on
the
very
front
end
of
that
next
slide.
D
C
Is
actually
a
fascinating
thing?
It
took
us
actually
10
years
to
get
to
a
full
day
to
Market,
but
in
2007,
three
years
after
we
became
an
approved
RTO,
we
launched
our
first
energy
and
balance
service,
Market
next
slide
and
then
finally,
in
2014,
as
I
mentioned,
we
launched
our
integrated
Marketplace
for
our
day
two
market
and
became
the
regional
balancing.
Authority
emerged,
18,
balancing
authorities
into
one
and
then
in
2019,
you'll
notice.
C
So
what
is
energy
imbalance?
It
is
exactly
what
the
title
implies:
it's
just
the
difference
between
what
was
scheduled:
either
generator
output
or
load
the
difference
between
what
you
pre-scheduled
and
what
actually
happens
and
so
loads
best
guess.
We
never
hit
them
perfectly
generation
more
and
more
with
our
intermittent
resources.
While
we
have
some
really
sophisticated
tools
to
forecast
that
we
never
hit
it
perfectly
so
an
imbalanced
Market
comes
in
and
and
works
to
facilitate
either
receiving
excess
energy
or
providing
energy
additional
energy.
B
As
it
notes,
you
know,
we
calculate
lmps
much
the
same.
We
do
even
in
an
energy
imbalanced
Market,
but
with
the
day
two
Market.
Of
course
you
get
into
unit
commitment,
and
this
is
where
the
real
savings
can
occur,
because
if
we
can,
we
can
commit
more
economic
resources
ahead
of
time.
We
can
come
up
with
an
overall
lower
dispatch
cost.
It
also
allows
us
again
to
to
operate
the
system
with
very
Advanced
tools.
C
We're
able
to
operate
a
50
gigawatt
footprint
with
extremely
high
wind
penetration
numbers
at
times
with
just
one
percent
regulation,
which
is
which
is
incredible:
50
gigawatt
footprint,
with
500
megawatts
of
Regulation
and
up
to
90
penetration
with
wind.
It's
just
fascinating
what
these
in-hour
tools
can
do.
C
These
tools
are
necessary
to
get
and
make
the
goals
that
get
to
and
make
the
goals
that
all
the
western
states
are
looking
for
and,
of
course,
overseeing
all
this
spp
does
have
an
independent
Market
monitor
ensuring
that
the
market
designs
that
we
put
in
place
actually
are
fair
and
equitable.
Next
slide.
C
So
I
mentioned
earlier
about
diversity,
you'll
notice,
we
have
a
quite
diverse
membership
mix,
all
the
way
from
your
traditional
investor
owned
in
public
utilities,.
D
D
A
little
bit
about
fuel
production
and
fuel
diversity
you'll
see
that
wind
and
coal
are
battling
for
that
number
one
spot.
Actually,
in
2020,
wind
was
our
number
one
resource
based
on
energy,
with
the
Dynamics
of
the
winter
weather
event
and
21,
plus
the
change
in
gas
prices.
We
do.
We
are
still
seeing
those
that
fight
neck
and
neck
next
slide,
and
this
graph
actually.
B
Shows
that
quite
well
you'll
see
cold
dwindling,
as
our
wind
was
coming
up
since
2012
in
2012.
We
served
eight
percent
of
our
footprint
with
wind
and
today,
as
mentioned
we're
into
the
mid
30s
and
you'll
notice.
Coal
has
been
dwindling,
but
they
have
both
coal
and
gas
have
bounced
and
again,
that's
due
in
part
to
the
winter
weather
event
that
we
experienced
in
February
of
21
and
the
change
in
gas
prices
versus
coal
next
slide.
B
All
right
and
I
will
turn
it
over
to
Karen
carriers
to
the
next
segment
thanks
Steve.
So
now,
I'd
like
to
briefly
describe
the
three
major
categories
of
benefits
that
we
find
in
running
this
Market
economic
reliability
and
clean
energy
integration.
B
B
It
returned
103
million
dollars
in
the
first
year
alone,
and
it
only
cost
about
30
million
dollars
to
put
into
place.
So,
just
in
the
first
year
there
was
a
return
of
three
to
one
on
the
implementation
costs.
You'll
see
there
are
some
stats
on
the
integrated
Marketplace,
which
we'll
talk
about
in
more
detail
in
a
minute.
This
is
a
20
billion
dollar
market
that
we're
running
in
the
RTO
in
the
Eastern
interconnection
you'll
see
our
years
of
service.
D
Our
ability
to
do
transmission
planning
on
a
regional
basis
we'll
talk
about
that
in
a
little
more
detail.
In
a
moment
when
we
look
at
the
quantitative
benefits
of
the
RTO,
we
really
divide
them
into
these
four
buckets
that
are
on
your
screen
today
or
on
your
screen.
This
morning,
you'll
see
here,
2.14
billion
in
annual
savings
and
benefits.
You've
heard
some
numbers
in
the
west
of
potential
savings.
You
can
see
how
we
look
at
that
from
the
RTO
perspective
at
spp,
we
look
at
the
bucket
of
operations
and
reliability.
D
What
those
savings
and
benefits
are
obviously
just
the
running
of
the
market,
which
I
think
is
the
most
basic
economic
analysis
that
we've
run
in
the
west
to
date.
That
would
be
a
comparable
number
also
what
the
transmission
planning
build,
those
benefits
to
our
members
and
then
some
other
benefits
related
to
tariff
scheduling
and
services.
D
B
Spp
footprint
has
reduced
emissions
by
21
since
2014..
We
also
believe
that
there's
a
qualitative
benefit
of
improved
public
policy.
We
help
members
meet
their
reliability
goals,
I'm
sorry,
the
renewable
goals
and
provide
other
support
that
we
can
there
and
obviously
there's
Economic
Development
benefits
from
having
an
RTO,
especially
related
to
the
transmission
being
able
to
integrate
those
resources
in
various
places
within
the
footprint.
B
B
What
you'll
see
within
our
existing
footprint
is
that
light
blue
and
those
are
the
states
that
pretty
early
on
adapted
renewable
portfolio
standards
and
what
we've
seen
in
those
States
is
that
we've
been
able
to
assist
those
States
in
Meeting
those
goals
sooner
than
they
would
have
and
at
a
price
less
than
they
would
have,
but
for
the
market.
B
So
we've
seen
a
positive
influence
in
the
RTO
development
for
those
States
and
meeting
their
RPS
you'll
see
here,
you
know
really
just
the
Stark
example
of
our
success
in
integrating
wind
resources,
specifically
in
such
a
short
amount
of
time
in
2008
you'll
see
it
was
only
three
percent
of
our
annual
energy
production
and
the
numbers
that
Steve
showed
you
a
little
bit
early
other
earlier
2020
it
was
over
30
and
even
higher
in
2021.
More
anticipating
will
be
higher
in
2022
as
well.
B
A
With
90.2
percent,
a
wind
is
the
majority
of
that
88.5
percent.
We
have
a
lot
of
solar
in
our
queue
and
some
storage
resources
as
well,
but
to
date,
wind.
D
Has
really
been
the
renewable
resource
that
we've
been
able
to
integrate
into
our
Market
having
that
kind
of
penetration
brings
with
it.
The
challenge
of
reliability
and
you'll
see
here
one
day
that
we
had
where
we
had
a
swing
within
21
hours
of
16
gigs
related
to
wind,
and
so
this
requires
a
significant
investment
in
forecasting.
A
F
Of
wind
resources,
I
mentioned
transition
planning.
When
there's
been
just
a
couple
of
slides
on
this,
we
have
directed
the
construction
of
about
10
billion
dollars
in
transmission
upgrades
in
the
last
10
years,
and
we
believe
and
have
calculated
that
that
returns
a
benefit
to
our
members
of
3.5
to
1..
F
F
F
You
can
see
another
significant
point
in
2014
when
we
added
the
full
RTO
services
and
did
the
integrated
Marketplace.
You
can
see
how
prices
were
affected
by
that,
and
then
you
can
see,
as
we've
grown
the
footprint
over
time,
how
that
also
has
contributed
to
lower
prices.
So,
by
increasing
the
services
provided
by
the
RTO
and
expanding
the
footprint,
both
have
had
positive
impacts
on
lowering
the
wholesale
electricity
prices
for
consumers
within
our
footprint.
F
F
Kind
of
support
and
this
sort
of
vision
laid
out
in
this
document
that
we
are
pursuing
the
different
things
that
I
believe
Steve
is
now
going
to
summarize
for
you.
Thank
you
thanks
Kara,
so
yeah
we
will
touch
on
the
various
services
that
we
are
currently
providing
or
or
intend
to
provide
in
the
near
future.
So
next
slide.
F
So
first
thing
we'll
hit
on
is
our
reliability
coordination
service
that
we
provide
in
the
west,
and
this
is
a
separate
and
distinct
RC
service
from
our
RTO
reliability
coordinator
in
the
East.
So
an
RC
really
is
the
analogy
of
an
air
traffic
controller
of
both
power
grid.
That's
a
great
analogy
because
they
have
that
wide
area
view.
They
have
advanced
tools
to
help
them
predict
and
see.
What's
coming
in
the
very
near
term
and
they're
able
to
coordinate
with
many
entities
as
as
was
discussed
earlier
during
the
the
summer
heat
storm.
F
Actually,
rrc
was
was
involved
with
that
in
helping
work
with
with
the
entities
under
our
footprint
be
able
to
provide
emergency
energy
to
California
next
slide.
C
So
this
is
a
map,
as
I
mentioned,
we'll
be
building
on
this
map.
So
you'll
see
the
at
least
it's
kind
of
orange
on
my
screen
footprint,
that
is
our
RC
footprint
in
the
west
and
again
we're
also
a
reliability
coordinator
for
our
entire
RTO
in
the
East
you'll
see
the
crosshatch
section
up
in
Montana.
The
reason
that's
cross
hatched
is
because
there's
also
Terrace
tariff
Services,
provided
there
that's
wapa
of
a
Great
Plains
system.
Next
slide.
C
Next
thing,
I'd
like
to
touch
on
real
quick,
is
our
Western
Energy
and
balance
service
next
slide.
C
So
basically
it's
it's
a
contract
Service,
and
it
provides
just
that
real-time
energy
and
balance
Market
with
for
for
two
balancing
authorities
and
eight
Market
participants,
so
basically
wapa's
Western
area,
Colorado,
Missouri
and
Western
area,
Upper,
West,
balancing
authorities
total
of
about
four
gigawatts
of
load.
When
we
went
live
with
this
since
then,
we'll
go
ahead
and
go
to
the
next
slide.
C
We've
seen
some
addition
in
August
of
this
year
we
added
Colorado
Springs
Utilities,
they
joined,
they
joined
the
Wacom
balancing
Authority
and
the
Weiss
for
a
total
of
five
gigawatts
and
next
April
we'll
be
bringing
on
the
Public
Service
of
Colorado,
balancing
Authority
area
to
include
Platte,
River,
Black,
Hills,
Energy
and
Public
Service
of
Colorado,
and
that
will
bring
the
market
footprint
up
to
about
13
and
a
half
gigawatts.
So
great
growth
and
every
time
we
add
to
it.
The.
F
F
B
The
Weiss
entities
at
that
time
approached
the
RTO
in
order
to
begin
to
investigate
full
RTL
membership.
There
are
several
that
might
remember
the
Mountain
West
Effort
that
ultimately
failed.
This
was
different
and
is
different
than
that
and
that
the
goal
this
time
around
was
to
just
simply
join
the
RTO
with
minimal
changes.
The
very
minimal
changes
required
to
make
that
happen.
B
That
was
accomplished
from
a
terms
and
conditions.
Standpoint
I'll
go
ahead
and
go
to
the
timeline
next
slide.
B
In
there
we
go
in
you'll,
you'll
notice,
all
the
red
here,
that's
already
been
accomplished,
so
we
worked
through
some
initial
terms
of
conditions.
Essentially,
there
was
13
terms
and
conditions.
Some
of
those
were
as
simple
as
needing
to
add
additional.
F
F
We
did
complete
that
in
July
of
this
year
we
got
board
approval
for
that
last
set
of
terms
and
conditions.
So
now
we
are
working
with
those
interested
parties
to
help
give
them
the
information
they
need
to
move
through
their
various
public
processes
and
be
ready
to
sign
commitment
agreements
to
move
forward
by
q1
of
next
year.
I'm,
assuming
that
all
goes
well,
we
would
be
going
live
sometime
in
2025.
F
C
I
want
to
talk
a
minute
about
DC
ties
that
the
strategic
enabler
to
be
able
to
operate
a
single
RTO
across
200
connections
with
two
separate
balancing
authorities
is
DC
tie
capacity.
C
As
you
know,
we
have
a
distinct
interconnection
in
the
west
from
the
East.
We
will
be
leveraging.
G
Operation
to
begin
with,
as
was
discussed.
A
Earlier,
when
we're
looking
at
various
studies
in
the
west
that
show
the
benefit
of
a
single
RTO
or
various
RTO
Footprints
across
the
West,
one
thing
that
hasn't
really
been
studied
is
the
interplay
between
the
Midwest
or
the
spp
RTO
footprint
and
the
West.
If
you
were
to
take
the
Pacific
DC
inter
tie
just
that
single
inner
tie
and
place
it
between
Oklahoma
and
four
corners,
we
could
have
avoided
load
shed
summer
of
2020
and
winner
of
2021.,
the
first
being
in
the
west,
the
second
being
in
the
Midwest.
A
When
you
run
it's
a
publicly
available
data,
when
you
look
at
Midwest
wind
and
you
compare
it
to
Southwest
solar
we've
actually
compared
a
year
of
operational
data
between
the
California
ISO
and
the
spp
integrative
Marketplace
is
amazing,
although
we
know
this
from
previous
studies,
but
this
is
actual
operational
data.
It's
amazing
how
complementary
that
is
when
you
look
at
diversity
of
time
zones
Etc-
and
you
know,
as
we
continue
to
have
these
events-
we're
starting
to
call
them
gray,
Swan
events,
because
they
seem
to
be
a
little
too
often
to
be
Black.
A
Swan
events,
looking
beyond
our
traditional
footprints
for
additional
resource,
resiliency,
reliability
and,
frankly,
just
managing
those
stability
of
prices,
the
interplay
between
the
wind
and
solar,
those
Renewables
are
very
complementary.
Our
Wind
Blows
really
hard
at
night
and
we
are
adding
some
solar,
but
when
you
add
that
extra
two
hours
of
time
zone,
it's
that
much
more
effective,
so
just
something
to
think
about
as
we
go
forward.
I
would
encourage
folks
to
consider
looking
beyond
the
traditional
studies.
We've
done
just
in
the
west,
consider
what
is
available
right
across
the
border
next
slide.
B
All
right,
so
this
is
the
RTO
West
footprint,
you'll
notice.
It
does
not
include
the
Public
Service
of
Colorado
balancing
authority
authority
area.
Currently
they
are
not
currently
looking
to
pursue
the
RTO
at
this
time.
B
However,
it
does
include
the
rest
of
the
original
Weiss
participants
and
the
addition
of
Colorado
Springs
next
slide,
so
touch
them
just
a
minute
here
on
the
western
resource
adequacy
program.
Next
slide
and
you'll
hear
more
about
this
I
believe
here
in
a
few
minutes,
but
just
quickly,
spp
worked
with
the
Western
power
pool
to
develop
the
program
and
then
was
chosen
to
be
the
program
operator
for
rap.
B
So
rap
is
currently
working
through
its
face
process.
Again,
I
won't
spend
much
time
here,
because
I
know
you
will
hear
more
about
it
here
shortly.
Next
slide.
B
Just
know
that
a
high
level,
you
know
we
will
be
working
as
a
program
operator
to
provide
all
these
functions,
so
loss
of
load
expectation,
calculating
cost
of
new
entry,
administering
the
forward
showing
and
operational
programs.
We
will
be
providing
the
tools
that
do
that,
based
on
Western
power,
pools
policy
and
governance
next
slide.
B
So
when
you
put
it
all
together,
this
is
what
the
map
looks
like
with
everything
overlaid
on
top
itself,
so
you
can
see
that
we
currently
are
providing
one
or
more
services
in
every
state
and
in
the
west,
and
we
are
looking
forward
to
continuing
to
bolster
our
services
as
we
go
forward.
Next
slide.
B
A
Thanks
Steve
we're
going
to
conclude
with
this
and
we'll
be
happy
to
take
any
questions
that
you
have.
We
launched
markets
plus
late
last
year
about
this
time
and
we
really
thought
these
eight
topics
on
the
screen.
B
Today
were
the
ones
that
we
needed
to
address
to
develop
the
markets
plus
offering
so
we
have
spent
this
last
year
working
on
each
of
those
through
various
forms.
Many
were
part
of
a
design
team
where
we
leveraged
stakeholders
to
help
us
lead
those
groups-
lots
of
webinars,
some
two-day
in-person
meetings
to
develop
this
and
we're
going
to
walk
through
some
of
these
major
issues.
Pretty
briefly
and
answer
any.
A
B
That
as
a
contract,
Service
like
the
Weiss
Market
and
the
RC
services
that
we're
providing,
they
all
have
an
independent
autonomous
governance
structure
from
the
RTO.
It
was
only
those
slides
that
Steve
talked
about
with
the
RTO
that
share
the
same
governance
structure
with
the
existing
RTO.
The
other
three
Contract
Services
have
developed
their
own
autonomous,
independent
governance
structures,
and
this
is
the
one
that
we've
developed
for
markets
plus
after
a
lot
of
work.
You'll
see
there
at
the
top
are
independent,
spp
board
of
directors.
B
Obviously,
the
markets
Plus
Market
will
be
operated
by
spp.
The
funds
needed
to
develop.
It
will
be
expended
by
spp.
They
will
everybody
who's
working
on,
it
is
employed
by
spp,
and
so
obviously,
the
corporate
board
of
directors
is
an
important
part
of
this.
However,
we
have
a
second
layer
of
Independence
for
the
governance
structure
within
markets
plus,
which
is
the
markets
plus
independent
panel.
It
will
be
made
up
of.
A
Five
individuals,
one
will
be
an
existing
spp
board
member,
but
the
other
four
will
be
elected
through
a
sector-based
nominating
process
that
you'll
see
on
the
left
there
in
Gray
we're
looking
for
people
with
market
experience,
obviously
Western
experience,
and
that
is
a
level
of
Independence.
They
will
have
the
final
say
on
all
things
strictly
related
to.
A
B
A
A
A
Similarly,
with
the
market,
design,
dashboard
and
I
apologize
for
any
confusion
of
those
two
being
outlined,
that's
just
a
mistake
on
our
part:
there's
no
reason
to
highlight
those
differently
than
the
others,
but
you
can
see
here
the
the
number
of
issues
that
were
involved
in
Market
design,
one
that
I
think
is
probably
of
particular
interest.
Is
the
greenhouse
gas
component
there's
a
tracking
component
as
well
as
a
market
component,
so.
B
Screen
a
little
more
detail
on
the
ghg
our
proposed
approach.
We
went
through
a
lot
of
stakeholder
input
on
this.
We
did
land
on
a
zonal
approach
and
you'll
see
here
some
of
the
basic
indications
of
how
that
will
work.
I
should
note
that
this
is
just
a
screenshot
of
a
presentation
that
that
we
did
earlier
so
I
don't
want
to
imply.
B
B
Attribution,
obviously,
the
market
monitoring
component
is
important
as
well.
We
presented
a
lot
of
information
about
those
options
on
April
27th
in
an
extensive
webinar,
whether
that
would
be
an
external
internal
or
a
hybrid
model.
We
discussed
this
through
a
panel
discussion
at
our
in-person
meeting
in
June
in
Denver.
We
then
asked
for
written
comments.
We
used
a
template
for
that
to
try
to
get
a
good
sense
of
where
people
were
on
those.
A
Three
options
and
other
issues
related
to
the
market
monitoring
component.
Those
comments
were
due
on
July
15th
and
showed
that
stakeholders,
the
majority
of
stakeholders,
did
prefer
an
internal
model,
and
so
that's
what
we've
included
in
the
service
offering
so
here
is
kind
of
where
we
are
with
markets.
B
A
B
All
day
the
15th
and
half
day,
the
16th
in
November,
where
we
will
present
a
summary
of
those
comments,
show.
C
To
those
have
additional
discussion
about
changes
that
need
to
be
made,
and
then
as
soon
as
spp
can
incorporate
those
changes
based
on
comments,
we'll
issue
the
final
service
offering
again,
this
will
not
include
Market
protocols
or
tariff
language,
but
it
is
the
broad
summary
of
what
this
Market
will
look
like.
Then,
we
launch
into
our
commitment
to
investigate
phase
which
we're
calling
phase
one
and
q1
of
2023.
I'll
talk
about
that
in
a
little
bit
more
detail
here,.
F
To
financially
supporting
this
phase,
one
which
will
be
the
Tariff
development
and
then
we'll
look
at
potential
phase,
two
cost
as
well.
The
overall
timeline
is
here:
we
are
at
the
bottom
of
step
two
by
issuing
that
service,
offering
step
three
will
really
be
next
year
and
part
of
2024
to
develop
the
fork
filing
process.
The.
C
So
that
was
probably
a
lot
of
information.
Obviously,
you'll
have
the
presentation
as
a
reference,
if
you
have
any
other
questions,
we're
happy
to
answer
anything
that
you
might
want
to
ask
us
today,
or
certainly
can
follow
up
with
us
at
any
time.
Following
the
presentation.
C
Thank
you.
Miss
barnstrom,
Mr,
Johnson
I,
appreciate
the
presentation.
I
have
some
questions
as
well,
but
I
want
to
give
the
committee
members
an
opportunity
to
ask
any
questions
if
they
had
any
and
I'll
go
up
to.
A
E
A
Chair,
it's
Rebecca,
Wagner,
Miss
Wagner,
please
go
ahead!
Thank
you!
Steve
and
Kara
for
the
for
the
presentation.
I
have
some
clarifying
questions
and
and
trying
to
wrap
my
head
around
timelines
and
the
connection
between
RTO
West
and
markets,
plus
so
I'm,
going
to
start
with
rtos
with
some
quick
questions
on
that.
A
G
G
G
Their
invitation
would
be
based
on
deseret's
participation
in
the
RTL
West,
and
while
they
have
some
jurisdiction
over
desert,
it's
it's
fairly
limited,
and
so
they
have
indicated
at
least
preliminarily
that
they
may
not
take
a
seat
on
the
RSC
because
they
don't
want
to
create
the
perception
that
they
have
more
jurisdiction
over
Deseret
than
they
do.
But
we
anticipate
the
other.
Three
states
will
take
a
seat
on
the
RSC.
G
I
think
your
mic
might
be
off
sorry
about
that,
so
it'll
be
a
it'll,
be
the
same
RSC
you're
not
going
to
have
separate
rscs
for
Western
and
Eastern
interconnect
correct
okay
in
so
in
2023
next
year,
beginning
of
next
year,
you
all
will
be
doing
we'll
you'll
be
asking
for
a
commitment
from
those
entities
that
have
already
indicated
that
they
were
going
forward
or
interested
in
RTO
West
and
then
thinking
of
launching
the
the
the
market
in
the
West
in
2025..
Is
that
the
right
timeline?
G
Yes,
so
is
there
going
to
be
any
I
mean
going
to
the
the
question
about
the
the
inner
ties?
What
what's
what's
the
timeline
on
evaluating
and
what
type
of
Investments
would
be
needed
to
be
made
to
to
really
make
those
available
and
useful
for
the
Western
interconnect.
G
This
is
a
question
on
the
DC
Thai
energize.
Yes,
yes,
so
of
course
that
map
I
showed
exists
today,
so
we
currently
have
1320
megawatts
available
bi-directional,
so
it
so
it's
essentially
double
that
and
of
that
510
megawatts
will
be
used
for
RTO
purposes.
So
so,
essentially,
there's
a
DC
tie
owned
by
Tri-State
and
Basin
electric
and
then
two
ties
owned
by
the
Western
area,
power
Administration.
Those
will
be
turned
over
to
the
RT
RTO
for
operation.
G
Beyond
that.
If
we
start
talking
about
some
some
large
capacity
like
I
mentioned,
that
is
something
that
folks
are
starting
to
talk
about,
but
nothing
has
there's,
there's
nothing.
That's
completely
materialized
Beyond,
some
doe
conversations
and
potentially
some
some
private
Capital,
maybe
looking
at
that.
But
there
are,
there
are
spots
on
the
grid
that
make
a
lot
of
sense
in
the
west.
G
You
know
coal
strip,
for
example,
once
that
power
plant
goes
down
in
Montana
Four
Corners,
as
I
mentioned
earlier,
a
lot
of
coal
shutting
down
with
a
large
AC
transmission
infrastructure
left
behind
and
there's
others
in
the
middle.
G
We
are
not
studying
that
yet
until
we
have
a
footprint,
we're
Regional
transmission
planning
would
be
prudent.
It
is
essentially
left
up
to
to
private
entities
and
or
States
other
entities.
To
look
at
that.
That
said,
we
would
participate
with
information
to
the
extent
we
could
be
very
interested
in
in
those
types
of
discussions.
G
Thanks
Steve,
that's
helpful,
Ragnar
that
there
was
a
really
lengthy
stakeholder
process
related
to
these
DC
ties
that
that
Steve
LED
it
was
more
than
a
year
and
I,
don't
know
if
Steve,
if
you
want
to
talk
about
a
little
bit,
but
I
just
want
to
be
clear
that
we
spent
a
ton
of
time
on
this
issue
between
the
East
and
the
West
really
working
through
how
this
would
work
in
bringing
in
the
Legacy
assets
and
then
how
cost
allocation
would
work
for
any
Investments
going
forward.
G
So
I
just
want
to
be
clear
that
we've
really
looked
at
this
at
a
lot
of
depth
and
it
took
a
lot
of
compromise
to
get
this
issue
through
the
board
in
July
yeah
thanks,
Kara
I
was
I
was
reflecting
back
to
the
one
slide
I
presented.
So
that
is
a
great
point.
We
spent
about
14
months
working
out
a
cost
allocation
for
the
DC
ties,
the
Legacy
D.C
ties
and
how
we
would
manage
the
congestion
allocation
congestion
rents
allocation
across
the
DC
ties.
G
G
The
assumption
is-
and
this
is
just
an
assumption-
that
likely
a
DC
line
or
DC
tie
would
be
at
least
a
major
portion
of
it
falling
to
a
regional
cost
allocation
bucket
so
specific
to
the
RTO.
Those
studies
would
kick
off
essentially
as
soon
as
we
get
into
our
first
planning
process
to
see
what
that
looks
like,
but
the
broader
footprint
like
I
was
talking
about.
That's
really
what
I
was
referring
to
earlier.
So
thank
you.
G
Kara
for
that
getting
me
straightened
out
on
the
clarification
and
then
chair,
if
I
just
want
to
try
to
make
the
linkage
with
so
markets,
plus
you're,
wrapping
up
the
market,
design
and
governance
now
and
in
the
first
quarter
of
2023.
There's
a
financially
binding
commitment,
I
think,
is
what
the
terminology
was.
G
What
does
that
is
that
the
cost
benefit
study
is
this,
where
the
utilities
can
identify
the
value
proposition
so
that
when
they
they
can
share
that
with
their
Regulators
I
mean
what
is
what
is
that
financially
binding
commitment
mean,
and
what
is
it?
What
do
you
mean
by
binding
like
once,
you're
in
you're
in.
G
So
I
think
there'll
be
additional
information
provided
on
this.
We
have
a
webinar
scheduled
in
early
November
to
talk
through
the
details
of
this
and
there'll,
be
more
information
in
the
final
service
offering
that's
issued
in
November
as
well,
but
in
the
draft
service
offering
we've
estimated
the
cost
of
phase
one
to
be
9.7
million
dollars
and
take
21
months.
G
We
intend
to
leverage
components
of
the
proposed
governance
structure
in
this
phase
to
develop
the
market
protocols,
the
remaining
governing
documents,
the
Tariff
language,
so
that
that
mpec,
that
participants
committee
would
be
stood
up
likely
working
groups
would
be
stood
up
and
then
we
would
use
our
governance
process
and
those
that
have
made
that
Financial
commitment
would
have
the
ability
to
participate
within
with
a
voting
structure.
That's
not
to
say
others
would
not
be
able
to
participate.
G
We
have
a
robust
and
inclusive
stakeholder
process,
so
anybody
can
take
the
mic
anytime
and
give
us
their
thoughts,
but
our
our
thinking
is
that
we
would
Leverage
The
governance
structure
with
potential
participants
in
the
way
that
we
would,
as
it
would
run
so.
Those
entities
that
commit
to
the
financial
component
of
this
would
get
votes
within
that
within
that
governance
structure.
The
webinar
that
I
just
mentioned
in
November
will
will
walk
through
in
a
bit
more
detail,
with
the
cost
allocation
of
that.
G
9.7
million
looks
like
whether
and
how
that
will
work
so,
and
we
do
anticipate,
perhaps
some
fine-tuning
of
that
number
and
the
timeline
in
the
service
offering
that
we
issue
in
mid-november.
Okay,
I,
don't
know
if
you
want
to
add
anything
to
that
or
if
I
hit
the
head
point.
The
high
points
I
think
you
hit
it
thanks.
Cara,
that's
super
helpful
and
then
just
thinking
about,
like
Nevada,
has
legislation
that
Envy
energy
has
to
join
an
RTO
by
2030.
G
We
have
off
ramps
in
2027.,
but
as
I
I
look
at
you
know
the
day
ahead.
Market
is
the
the
next
like
thing
to
think
about
is
bringing
benefits
to
customers,
but
markets
plus
is
a
separate
governance
than
RTO
West.
So
how
do
you
envision
these
two
migrating
together,
somehow
or
you're
in
markets
plus,
and
then
you
decide
hey?
This
is
working
out
really
well
we're
gonna
leave
we're
gonna
transition
or
migrate
into
RTO
West
I'm
I'm,
trying
to
figure
out
how
how
that
would
work.
G
G
Well,
as
Steve
mentioned
when
he
talked
about
the
R2
expansion
that
we're
looking
at
today
once
anytime,
that
happens
within
the
in
the
eastern
interconnection
and
now
in
the
western
inner
connection,
there's
a
process
that
is
triggered
within
spp's
governance
structure
to
look
at
any
potential
changes
that
need
to
be
made
to
accommodate
these
new
members.
Steve
mentioned
in
the
west
RTO
expansion.
There
were
13
terms
and
conditions
that
were
brought
to
the
board
in
July
of
2021
to
accommodate
the
new
membership.
G
I
would
note
that,
while
it
is
separate
and
autonomous
and
independent,
the
markets
plus
governance
structure
has
a
lot
of
components
that
are
similar
to
how
the
RTF
functions,
and
some
of
that
was
by
Design,
to
make
sure
that
the
concepts
that
are
super
important
within
spp
are
incorporated
into
markets
plus,
while
giving
all
the
the
difference
that
we
possibly
can
to
Western
stakeholders
about
what
they
want
to
see
in
a
governance
model.
G
So
the
process
would
involve
discussions
about
whether
changes
would
be
requested
and
then
obviously
would
go
through
the
governance
process
through
the
stakeholder
process
to
determine
whether
there
was
agreement
about
presenting
those
as
part
of
the
expansion
efforts.
G
G
Brian
there's
the
piece
of
piece
of
that
that
I
was
just
trying
to
figure
out
is
how
how
what
it
looks
like
when,
when
one
migrates
from
markets
plus
to
RTO,
West
and
and
Cara
did
a
great
job
answering
that.
So.
Thank
you.
G
G
G
You
miss
Wagner,
asked
a
question
about
the
q1
2023
Financial
commitment
and
I
just
want
to
is:
isn't
it
correct
that
that
is
really
a
a
service
offering
from
markets
plus
will
come
out
in
November
this
coming
November
and
the
energy
is
busy
writing
comments
on
the
latest
proposal,
but
but
when
that
service
offering
comes
out,
isn't
it
the
process
where
the
the
participants
will
have
the
opportunity
to
review
that
for
a
few
months
and
then
in
January
that
Financial
commitment
is
really
to
have
a
seat
and
a
voting
right
at
the
table
for
tariff
language,
Drafting
and
further
development
of
The
Proposal,
but
even
if
an
entity
does
not
participate
in
that,
they
can
still
join
the
markets
plus
day
ahead
Market.
G
As
long
as
they're
happy
with
the
outcome
of
of
that
process,
correct
and,
and
then
not
to
say,
I
mean
I.
Envy
energy
has
the
intention
to
participate
in
all
offerings
to
make
the
best
decision
for
the
state
or
recommendation,
but
is
isn't
isn't,
is
that
is
my
understanding
of
that
process
and
that
Financial
commitment
correct
that
it's
not
the
door
closing,
but
it
is
a
seat.
Is
it
is
a
decision
to
have
a
seat
at
the
table
for
further
development?
G
G
But
I
do
have
a
follow-up
question
on
another
matter,
relative
to
membership
and
I
believe
in
one
of
the
the
slides
you
showed
the
composition
of
the
membership
and
spp
excuse
me,
and
because
of
the
introduction
that
the
chair
gave
earlier
about
the
import
of
batteries
and
demand
response
and
maintaining
the
reliability
of
the
western
grid
through
that
stressful
period
in
September,
I
didn't
notice,
those
as
members
of
that
of
your
stakeholder
list
and
I'm
just
curious
to
ask
that
question
about
how
you're,
looking
at
the
changing
composition
of
the
electricity
grid
and
New
Market
participants
and
how
they
get
considered
in
in
the
membership
with
either
your
markets
Plus
or
the
RTL
West.
G
I
would
note
a
couple
things
about
spp's
process.
We
we
have,
as
you
mentioned
quite
a
diverse
group.
There
are
many
developers
that
are
working
on
a
lot
of
co-located
battery
storage
within
the
spp
footprint.
There
are
others.
If
you
notice
there
was
14
independent
transmission
companies
that
are
members
in
in
these
large
retail
customers.
G
I
mentioned
themselves
are
looking
at
these
things,
so
when
you're
looking
at
like
for
a
quarter,
22
22,
which
is
which
is
driving
a
lot
of
this,
this
type
of
what
I
call
smaller
scale
integration
point
being
is
ferc
is,
is
is
looking
at
this
and
we
have
to
respond
to
these
things.
G
We
do
have
entities
bringing
these
things
to
the
table
as
part
of
the
ga
GI
process
or
proposed
projects
that
we
are
studying
so
but
beyond
that,
I
just
want
to
mention
that
anyone
can
participate
in
our
process.
G
Our
meetings
are
all
public
and
open.
We've
had
we've
had
entities
that
have
participated
for
years
before
they
became
an
actual
member
of
spp.
So
it's
a
very
open
and
inclusive
process
to
be
able
to
discuss
these
types
of
things,
but
the
reality
is.
If
somebody
brings
a
project
to
the
table
through
one
of
our
planning
processes,
I
mean
it
will
be
looked
at,
Cara
I,
don't
know
if
you
wanted
to
touch
on
the
governance,
Siloam
or
not.
G
I
think
you
addressed
it.
Okay
and
maybe
I
would
just
ask
a
follow-up
question
relative
to
your
response,
which
is
understanding.
You
have
an
open
stakeholder
process.
I
guess
the
other
part
of
that
is
the
voting
process
and
having
a
voice
and
making
decisions
with
RTO
West
or
with
markets
plus.
So
can
you
speak
to
that
element?
Is
there
a
place
for
those
types
of
resources
in
voting
within
your
structure?
G
So
within
the
RTO
membership,
you
know,
gets
voting
rights,
and
so
you
can
become
a
member
in
the
RTO
by
paying
a
six
thousand
dollar
annual
fee,
and
then
you
are
eligible
to
participate
in
various
components
of
the
stakeholder
process
within
the
RTO.
In
terms
of
voting,
as
Steve
said,
anybody
can
participate,
but
voting
rights
come
with
membership.
The
governance
structure
within
the
RTO
is
expansive.
We
didn't
show
any
of
that
today,
but
it's
there
are
tons
of
opportunities
for
members
to
be
serving
on
working
groups
and
other
stakeholder
components
within
the
RTO.
G
The
markets
plus
governance
structure
has
a
category
of
stakeholders
called
markets,
Plus
Market
stakeholders
and
those
MMS.
We
call
them
are
eligible
for
voting
rights
on
the
impact
working
working
groups.
If
they
get
appointed
task
force
in
the
nominating
committee,
they
pay
a
five
thousand
dollar
annual
fee
to
get
that
sort
of
status
in
terms
of
voting
rights.
G
G
Thank
you.
Next
up,
we
have
Mr
lathors.
G
Thank
you,
chair
Brooks,
so
my
question
is
Also
regarding
the
membership
slide
on
slide
12
and
also
a
little
bit
of
slide
22
talking
about
Regional
planning
and
grid
modernization.
My
question
is:
to
what
extent
have
you
engaged
with
or
included
federally
recognized
tribes
within
your
areas
in
terms
of
either
membership,
Regional
planning
or
grid
modernization.
G
That's
a
great
question:
you
know:
I,
don't
I
know
indirectly
through
through
wapa
right
there's,
there's
a
large
tribal
customer
base
within
lapa
that
they
have
engaged,
but
I
would
have
to
go
back
and
ask
I'm,
not
100
sure,
but
maybe
Cara
has
that
answered
I.
Don't
we
can
certainly
follow
up
on
that.
G
So
I
have
a
few
questions
and-
and
they
were
mostly
kind
of
inspired
by
some
of
the
previous
questions
and
answers,
but
one
is
and
I
want
to
build
upon
what
Mr
lethoris
just
talked
about
like
the
rec,
the
the
representation
of
tribes
and
communities,
whatever
those
communities
might
be,
that
that
might
be
impacted
by
the
decisions
made
by
any
of
the
governance
structure,
whether
it's
in
the
western
RTO
or
markets
plus,
and
so
if,
if
like
and
I'll,
stick
with
markets
plus
because
I
think
you
know
just
to
me.
G
Obviously
that's
like
the
baby
step
towards
the
the
Western
RTO
and
and
if
things
didn't
go
just
great
in
a
markets
plus
scenario,
I,
don't
think
we'd
go
any
further
and
so
I'll
stick
with
that.
So
we
talked
about
and
and
earlier
questions
about,
the
governance
structure,
sure
and
voting
rights
within
markets
plus,
and
so
it
looks
like
the
ultimate
kind
of
like
the
buck
stops
with
the
spp
board
of
directors.
G
So
if
are
all
decisions
going
to
be
up
for
a
vote
and
will
it
would
it
be
a
majority
vote
and
is
it
one
Member
One
vote?
Is
it
SRP
style,
the
more
land
you
got
and
the
more
power
you
use
the
more
votes
you
get
or
is
it?
Is
it
like
one
Member
One
vote?
Five
thousand
dollars
is
your
your
ticket
to
ride,
so
how?
How
is
that
going
to
work
well
well,
in
in
a
situation
like
with
tribal
representation?
G
Would
a
tribe
then
be
able
if
a
tribe
was
in
the
footprint
of
of
the
markets
plus
program?
Would
the
tribe
then
get
one
vote?
Would
multiple
tribes
get
multiple
votes,
so
I'm
just
trying
to
walk
through
some
like
potential
scenarios
there
in
the
markets
plus
context?
There
are
two
categories
that
you're
kind
of
referring
to
there:
it's
Market
participants
and
Market
stakeholders
and
those
entities.
They
would
have
a
representative
on
the
mpec,
the
participants
committee,
the
working
groups
Etc,
so
any
tribe
that
wanted
to
join
as
an
MMS
pay.
G
The
five
thousand
dollars
would
be
considered
a
Marcus,
Plus
Market
stakeholder
and
be
included
as
a
voting
member
of
these
governance
structures.
You
then
sort
of
talked
about
the
the
myth
and
then
the
board.
Those
are
completely
separate,
both
the
the
independent
Channel
and
FTP
board
members
are
required
to
be
completely
independent
of
any
markets
plus
participant.
They
can't
have
any
ties
at
all
to
those.
So
that's
a
separate
vote.
The
the
participants
and
stakeholders
on
the
mpec
will
make
recommendations
to
the
myth.
G
If
it's
a
markets
plus
exclusive
issue,
the
MIP
alone
will
vote
one
person,
one
vote,
simple
majority
vote,
so
three
out
of
those
five
would
would
carry
a
proposal
if
it's
a
markets
plus
specific
exclusive
issue,
that's
the
position
that
will
be
filed
at
for
spp
will
be
directed
to
file
that
if
it's
an
issue
that
implicates
the
organization,
a
staffing
issue,
the
requirement
of
issuing
a
debt-
something
that's
material-
and
this
is
all
laid
out
in
much
more
detail
within
our
service
offering.
But
those
are
the
broad
categories.
G
It
would
then
go
to
the
spp
board
of
directors
as
an
agenda
item
with
a
recommendation
from
the
myth
about
their
action,
so
they
would
vote
on
it.
They
may
have
to
go
to
the
MIP
or
I'm
sorry
to
the
spp
board.
The
way
that
we
do
that
within
the
wise.
For
example,
that
comes
to
the
spp
board
oftentimes
in
a
consent
agenda
item.
G
Okay,
thank
you.
So
so
the
stakeholders
and
participants
they
basically
just
get
input
to
the
MIP
and
the
MIP
makes
the
final
vote
and
it's
a
three
out
of
five
majority
vote.
Is
it
am
I
hearing
that
correct
instruction?
Sorry,
there
is
a
voting
structure
within
the
mpac,
which
is
where
participants
and
stakeholders
vote
on
issues.
So
they
look.
There's
a
voting
structure.
G
It's
three
different
categories:
it's
a
bit
complicated,
but
it
gets
spelled
out
what
those
categories
are,
and
it
requires
a
super
majority
with
the
impact
to
approve
something
and
that's
simply
a
recommendation
to
the
MIP
and
that's
where
the
authority
lies
is
within
the
MIP
and
then
potentially
within
the
board,
depending
on
what
the
issue
is:
okay,
so
who's
the
myth
who
appoints
them.
Where
do
they
come
from
and
how
do?
How
are
they
independent
from
the
stakeholders
or
the
participants?
G
There's
a
nominated
committee,
that's
sector
based
made
up
of
11
Representatives
and
then
every
Market
participant
in
Market
stakeholder
meets
at
what
we
call
the
The
Forum
to
vote
on
the
recommendations
from
that
nominating
committee
within
the
service,
offering
they're
spelled
out
what
those
qualifications
are
market
experience
Independence,
as
required
by
ferc
some
code
of
conduct,
things
that
spp
has
so
there
are
some
qualifications
there
within
the
service
offering
of
who
those
are,
but
they
will
go
through
a
a
thorough
and
comprehensive
nominating
process
with
a
national
search
firm,
similar
to
how
spp
conducts
their
board
searches
looking
for
highly
qualified
people
with
knowledge
necessary
to
to
serve
on
the
map.
G
Some
of
our
participants
have
suggested
they'd
like
that
additional
qualification
of
Western
experience,
so
that
may
be
something
that
gets
added
in
phase
one
next
year.
Other
issues
are
being
considered
for
qualifications,
issues
for
men
as
well.
Okay,
so
I
understand
the
MIP
nominating
committee
and
the
map.
What
about
the
MIP
selection
Forum?
So
we
have
participants
and
stakeholders
are
in
that
selection
Forum
as
every
and
then
you
need
a
super
majority
out
of
the
selection
Forum
to
approve
a
myth.
Member
is
that
correct.
G
G
Now
would
our
technology
providers
who
are
a
member
would
our
tribes
who
are
stakeholders?
Would
they
be
a
voting
member
on
the
selection
form?
Yes,
one
one
Member
One
vote
correct.
If
you
are
the
markets,
the
markets,
Plus
Market
participant
or
a
markets,
Plus
Market
stakeholder
having
paid
the
five
thousand
dollar
fee,
you
have
the
vote
at
The,
Forum,
okay.
So
so
that
is
where
you
know,
I
mean
input's
one
thing,
but
actual
ability
to
control
the
outcomes.
G
G
Obviously,
in
the
market,
because
they're
in
the
market
and
they've
already
paid
well
they've
paid
quite
a
bit,
which
leads
me
to
my
next
question:
is
that
Financial
going
to
slide
50
the
financial
commitment
stage
of
the
markets
plus
process
and
so
and
I'm
just
gonna,
I'm
I,
don't
know
of
anything
or
and
I'm,
not
implying
anything
I'm
going
to
use
a
hypothetical
Envy
energy,
for
instance?
Let's
say
they
want
to
be
markets
plus
a
participant
at
what
point
do
they
I
think
it's
slide
50.
G
Of
How
It's
recovered,
as
I
mentioned,
for
phase
one.
What
we
have
in
the
draft
service
offering
is
an
estimate
of
9.7
million
dollars
that
will
be
paid
by
participants
that
want
to
participate
in
phase
one.
We,
we
tend
to
include
a
an
estimate
of
the
cost
for
phase
two
actual
integration
and
implementation
of
the
market,
so
that
data
will
be
coming
so
9.75
is
that
a
one-time
payment
just
to
stand
up?
G
There
are
Provisions.
If
the
timeline
is
extended
for
certain
purposes,
there
may
be
a
monthly
run
rate,
for
example,
to
be
charged
depending
on
the
process.
Just
continue
to
support
the
staff.
That's
that's
been
hired
by
spp
to
to
prepare
these
documents.
There
are
travel
expenses,
meeting,
expenses,
etc.
Those
are
kind
of
the
big
components,
mostly
staff
are
the
big
components
of
that
phase.
One
budget,
but
it's
not
based
on
numbers
of
transactions,
volume
of
trading
or
volume
of
of
of
inter
transactions
or
energy
or
footprint,
or
anything
like
that.
G
Well,
there
is
a
Jenny
transaction
in
Phase
One,
we're
still
trying
to
develop
the
the
product
and
developing
that
I
guess.
It
would
be
answered
at
that
point:
anyways.
Okay,
all
right
cool.
That
component
of
what
you're
talking
about
would
be
part
of
of
how
to
Market
costs
would
be
allocated
once
you
Market
it:
okay,
okay,
great
and
then
we
developed
that'll
be
developed
during
that
phase.
G
One
process
during
Protocol
development
and
and
I
would
also
note
that
we
have
a
webinar
on
November
1st
to
to
address
this
exact
issue
phase
one
funding
and
what
that
looks
like
and
how
that
will
actually
be
divvied
up
amongst
the
participants
that
come
in
great
I,
think
offline
I'll
have
I'll,
ask
Envy
energy
and
the
Public
Utilities
Commission,
how
they
Envision
a
potential
9.7
million
dollars
being
recovered.
G
G
Miss
barbas
did
you
have
a
further
comment
or
question
just
one
follow-up
for
clarification:
the
9.7
million
for
developmental
purposes
in
phase
one
that
is
not
that
is
divided
between
all
the
participants
in
markets
plus
right
and
and
do
you
have
it?
Can
you
explain
the
allocation
methodology
for
that
9.7.
G
So
again,
we'll
be
hitting
that
on
November
1st.
To
be
perfectly
honest,
we
are
still
working
on
on
what
we
would
propose
and,
of
course,
there'll
be
some
some
interaction
between
November
1st
and
the
15th
and
16th
by
the
15th
and
16th.
We
will
be
making
a
proposal
on
how
we
want
to
cost
to
to
allocate
those
costs
so
we're
right
in
the
middle
of
the
sausage
making
process
I
mean
there's
been
discussions
about
some
sort
of
a
House
and
Senate
type
charge.
Where
it's
you
know,
half
of
everybody
pays
the
same.
G
Half
as
you
know,
load
base
something
like
that,
but
we
have
not
nailed
that
down
yet
to
be
perfectly
honest
again,
we
will
be
making
a
proposal
on
November
1st
see
what
feedback
we
get
and
then
we
will.
We
will
have
that
in
the
final
proposal.
G
Thank
you
Steve.
Thank
you
appreciate
that
clarification.
That
I
was
a
little
confused
on
that
point.
So
thanks
for
for
clarifying
that
anybody
else
on
the
committee
have
any
questions
all
right.
Thank
you
so
much.
We
really
appreciate
that
presentation,
and
that
was
that
was
really
helpful
for
me
and
obviously
that
presentation
is
online
and
it's
on
the
governor's
office
of
energy
website
for
anyone
who
wants
to
look
at
that
or
refer
back
to
it
later.
Thank
you
thank
you
for
for
your
presentation
this
morning
and
we
will
move
on.
G
We
now
can
move
on
to.
If
there's
no
other
questions,
we
can
move
on
to
the
next
agenda
item
and
our
next
agenda
item
and
again
we're
taking
things
a
little
out
of
order,
we'll
be
a
presentation
from
the
Western
power
pool
which
we
refer
to
as
wpp
in
our
world
of
acronyms
here
in
this
business,
and
it's
an
introduction
in
history
of
wpp
and
I
believe
we
have
Ryan
Roy
making
that
presentation
this
morning
and
I
see
him
on
the
not
so
big
screen
and
so
Mr
Roy.
G
You
can
go
right
ahead
whenever
you're
ready
good
morning
and
thank
you
all
for
our
opportunity
to
participate
in
this
discussion.
Hopefully
you
can
are
seeing
my
presentation
on
the
screen
here.
G
Yes,
sir,
we
are
thank
you
great,
so
I'm
Ryan,
Roy
I'm,
the
director
of
Technology
modeling
and
analytics
at
the
Western
power
pool.
Today
we're
going
to
talk
a
little
bit
about
our
organization,
the
Western
power
pool,
as
well
as
the
Western
resource
adequacy
program
that
we
have
been
working
on,
of
which
NV
Energy
has
been
participating
in
the
design.
G
So
we're
going
to
talk
a
little
bit
about
the
organization
as
a
whole.
Provide
you
some
background.
So
the
Western
power
pool
provides
a
range
of
valuable
grid,
integration
and
coordination
services
to
its
customers.
We'll
talk
a
little
bit
more
about
sort
of
the
footprint
as
a
whole,
but
just
wanted.
C
G
G
It
is
where
we're
going
to
be
a
jurisdictional
public
utility,
but
we
will
touch
lightly
on
some
of
the
other
services
that
we
offer.
So
we
offer
a
reserve
and
frequency
response
sharing.
We
have
a
training
platform
that
provides
CEUs
contingent,
continuing
education
units
for
system
operators
and
staff
of
utility
Northern
grid
transmission
planning
for
those
that
have
a
four
quarter
1000
requirement.
We
do
a
significant
amount
of
hydro
modeling
in
support
of.
As
the
gentleman
from
BPA
mentioned,
the
Columbia
River
treaty,
the
Pacific
Northwest
coordination
agreement.
G
Do
some
transmission
study
cost
work
as
well
as
the
Western
resource
adequacy
program.
G
So
a
brief
history
of
the
organization
we
were
established
in
1941
by
six
investor
owned
utilities
as
Steve
from
spp
mentioned,
sort
of
largely
in
response
to
gearing
up
for
wartime
activities,
we're
probably
we're
primarily
focused
on
hydro
coordination
in
support
of
the
Columbia
River
treaty
and
the
Pacific
Northwest
coordination
agreement.
Those
started
in
the
1960s.
We
have
a
very
large
storage
Hydro
resource
stack
in
the
Pacific
Northwest,
and
it
was
really
about
coordination
of
those
Hydro
resources
to
maximize
Regional
benefit.
G
We
established
an
informal
Reserve
sharing
program
in
the
1970s
added
the
transmission
planning
committee
in
1990.
Up
to
this
point,
this
was
largely
done
with
borrowed
staff
from
our
member
organizations.
In
1999
we
transitioned
to
full-time
staff,
really
sort
of
the
first.
You
know.
Large
systems
undertaking
was
fully
automating.
The
reserve
sharing
program
in
2002
we're
a
certified
ceu
provider
as
of
2005
and
a
fully
automated
trans
training
platform.
As
of
2014.
G
in
2019,
we
initiated
the
Western
resource
adequacy
program,
effort
or
wrap
staying
with
our
acronym
soup
here
so
sort
of
a
brief
history
of
the
organization,
we're
headquartered
in
Portland
Oregon,
a
relatively
small
organization
of
around
20
folks.
G
G
You
know
rap
is
going
to
be
a
for
jurisdictional
program
in
order
to
support
that
the
wpp
needs
to
become
a
public
utility
per
the
federal
power
act
in
in
order
to
administer
that
tariff
that
the
Western
resource
adequacy
program
tariff.
That
requires
a
couple
things.
We
need
a
fully
independent
board.
Currently
our
board
is
semi-independent.
They
have
no
oversight
or
governance
of
the
non-fur
jurisdictional
programs.
So
it's
important
to
note
our
Reserve
sharing
program
or
work
under
transmission
planning,
the
hydro
modeling.
G
The
wpp
is
going
to
act
as
the
rap
program
administrator.
We
will
be
administering
the
Tariff
managing
the
independent
board
and,
as
you
heard
from
Steve
and
Cara,
we
have
partnered
with
the
Southwest
power
pool
both
on
design
of
the
ra
program,
as
well
as
sort
of
day-to-day
administration
of
the
operation
of
that
program,
with
spp,
acting
as
the
program
operator
they're
going
to
perform
technical
operations
of
the
program,
and
you
saw
this
on
their
slide
before
showing
the
operations
program.
G
So
you
know
what
does
it
mean
for
the
Western
power
pool
to
act
as
a
public
utility?
So
we
need
a
fully
independent
board
of
directors.
So,
following
ferc
approval
of
the
Tariff,
we
have
filed
we're
expecting
or
hoping
for
an
answer
by
mid-December
and
critical
mass
commitment
by
participants.
Currently,
we
are
funded
through
the
end
of
the
year.
We
are
asking
our
participants
to
make
a
commitment
sort
of
minimum
to
your
commitment
to
the
program
at
the
end
of
the
year.
G
If
we
get
both
work,
approval
and
sort
of
critical
mass
of
participants,
we
would
transition
our
currently
semi-independent
self-perpetuating
board
to
a
fully
independent
board.
We
have
a
nominating
committee
that
is
working
on
that
process.
Currently
they
have
offered
a
slate
which
our
existing
board
will
vote
on
very
soon,
they're
also
going
to
oversee
the
pre-existing
wpp
functions.
G
So
you
know
the
board
of
directors,
obviously
their
role
codified
in
the
Tariff.
What
are
they
going
to
be
doing?
They're
going
to
direct
the
wpp
to
file
tariff
changes
under
the
federal
power
act?
Section
205.
This
is
probably
of
interest
to
you.
Folks.
There
are
certain
types
of
major
changes
to
the
rap
tariff
and
scope
that
can't
happen
without
a
super
majority
approval
of
our
participant
committee
and
one
of
those
things
would
be
forming
a
regional
transmission
organization.
G
Obviously,
you've
heard
in
the
west
here
about
the
incremental
approach
to
these
things.
There
was
strong
support
from
our
participant
committee
to
stand
up
a
standalone
resource
adequacy
program,
but
they
did
have
concerns
about
sort
of
the
board
taking
steps
to
one
either.
You
know
transform
itself
into
a
market
provider
or
a
regional
transmission
organization.
That
is
something
that
the
board
could
not
do
unilaterally.
G
Final
Authority
for
approval,
rejection
on
all
tariff
for
posting
proposed
tariff
changes,
and
they
can
propose
tariff
changes
to
be
considered
in
the
stakeholder
process.
So
we
have
a
stakeholder
process
and
we'll
talk
a
little
bit
about
this.
A
program
Review
Committee
made
up
of
a
membership
of
roughly
20
folks
representative
of
participants,
stakeholders
Etc,
that's
sort
of
where
the
ideas
for
the
rap
program
are
funneled
into.
We
have
our
participant
committee
made
up
of
those
entities
that
have
a
compliance
obligation
in
the
program
or
low
responsible
entities.
G
G
We
do
have
a
sector
represented
nominating
committee
to
nominate
the
board
so
currently
that
process
is
underway.
It's
made
up
not
only
of
participants
in
our
program,
but
stakeholders,
public
interest
organizations
Etc.
So
we
wanted
broad
representation
for
those
folks
putting
forth
a
slate
for
our
independent
board.
G
Rap
participant
participation
is
a
bit
interesting.
This
is
a
completely
voluntary
program,
so
there
is
no
manner
by
which
the
program
itself
can
compel
participation.
So
it's
completely
voluntary
by
load
responsible
entities.
The
lre
is
the
primary
entity
responsible
for
meeting
the
ra
requirements.
You
know
their
focus
is
program,
rights,
responsibility
and
compliance
when
they
sign
up
for
the
program,
they'll
sign
up
for
Western
resource
adequacy
agreement,
it's
a
pro
forma
agreement
and
that's
filed
in
the
rap
tariff.
Obviously,
for
folks,
like
Bonneville,
we
have
powerx
and
acting
on
behalf
of
BC
Hydro.
G
G
What
does
this
do?
You
know
they
fund
the
cost
of
administering
the
program
and
sit
on
the
ra
participants
committee.
So
there
was
a
discussion
previously
about
how
is
this
funded?
The
administrative
cost
of
this
program
will
be
funded
in
two
ways:
a
flat
charge
not
to
exceed
roughly
fifty
eight
thousand
dollars
for
each
load
responsible
entity
and
then
a
maximum
dollar
per
megawatt
rate
based
on
p50
load.
So
sort
of
you
know
similar
to
what
you
might
see.
G
Otherwise,
those
entities
that
are
have
a
larger
proportion
of
the
compliance
requirement
based
on
load
to
pay
a
larger
amount
of
the
administrative
costs
exit
like
entry
is
voluntary,
and
so
you
know
when
you're
thinking
about
a
forward
procured
resource
adequacy
program
with
potential
cost
of
new
entry
penalties.
You
know
that's
a
potential
significant.
G
You
know
financial
interest
for
folks.
We
wanted
to
set
up
extra
Provisions
like
entry
Provisions
make
them
voluntary
with
24
months
in
advance.
There
is
shorter
notice
Provisions
for
extenuating
circumstances
on
a
case-by-case
basis.
G
You
know,
or
in
case
of
significant
significant
reduction
of
peak
load
under
certain
conditions.
So
we
really
want
to
make
sure
we're
you
know.
Costs
are
allocated
appropriately
that
one
of
our
larger
or
several
more
larger
participants
don't
leave,
causing
an
undue
cost
burden
on
others.
So
we've
tried
to
be
thoughtful
about
both
entry
and
exit
provisions.
G
G
G
We
anticipate
some
non-standard
exit
Provisions
for
the
the
federal
entity
and
that's
really
due
to
their
specific
statutory
requirements.
So
that
would
be
a
BPA
we
currently
are
having
discussions
with
wapa,
although
they
are
not
an
existing
participant.
G
So
talk
a
little
bit
about
the
stakeholder
engagement
process
and
transparency
here,
so
we
have
a
sector-based
nominating
committee
to
nominate
the
board
of
directors.
We
also
have
a
sector-based
program,
Review
Committee-
and
this
is
really
the
Workhorse
for
program,
design,
reviews
and
updates.
All
of
the
changes,
even
if
directed
by
the
board
of
directors,
goes
to
our
program.
Review
Committee,
so
that'll
be
20
folks
made
up
of
obviously
load
responsible
entities,
pios
public
interest
organizations,
consumer
Advocates,
so
we'll
have
a
seat
on
that,
and
these
are
are
open
to
the
public
as
well.
G
We
do
have
a
kid
meeting
of
state
representatives,
so
you
know
very
similar
to
the
spp
framework
or
the
boss
or,
if
you're
familiar
with
the
energy
and
balance
Market.
This
is
one
rep
from
each
state
or
province
that
regulates
one
or
more
participants.
It
does
not
necessarily
have
to
be
a
commission,
it
could
be
an
energy
advisory
office
Etc.
G
We
are
having
open
meetings
for
the
Rhapsody
and
the
board
of
directors
when
making
decisions
about
the
rat.
This
is
I,
think
you
know
standard
practice,
materials
provided
in
advance
to
stakeholders
in
the
public.
You
know
we
really
like
to
say
sort
of
everybody
and
their
their
their
grandma
or
grandpa
is
welcome
to
show
up,
provide
us
feedback
on
the
program.
G
The
program
review
committees,
process
for
review
of
design
recommendations
includes
public
comments,
and
so
because
all
of
these
program
changes
are
sort
of
sourced
at
the
program.
Review
Committee
there's
really
an
ability
for
anybody
and
everybody
to
provide
feedback
on
design
changes,
changes
to
the
Tariff.
We
really
wanted
to
sort
of
maintain
an
open
and
transparent
stakeholder
process.
G
Although
we
are
not
a
market,
we're
not
establishing
a
capacity
Market,
not
establishing
an
RTO,
we
did
think
it
was
critically
important
that
we
find
a
place
for
sort
of
independent
confirmation
of
one.
Our
administration
of
the
Tariff,
and
two
sort
of
you
know,
is
the
design
meeting
the
intended
purposes,
and
so
for
that
reason
we
will
have
an
independent
evaluator.
This
independent
evaluator
is
going
to
provide
the
board
of
directors
with
outside
an
independent
assessment
of
program
operations,
accounting
settlement
and
design.
G
Talk
a
little
bit
about
sort
of
how
the
decision-making
process
works.
The
board
of
directors
has
ultimate
decision
making
Authority
for
the
rat,
the
rap
C,
the
ra
participant
committee
is
going
to
provide
advisory
votes
to
the
board
of
director
on
program
changes,
but
those
are
just
advisory.
It
is
a
House
and
Senate
style
voting,
so
you
do
get
to
one
vote
for
participation
and
then
house
is
based
on
your
p50
or
one
and
two
expected
load.
G
A
67
approval
on
both
House
and
Senate
tallies
needed
on
resolutions
that
were
approved
by
the
PRC.
So
our
hope
and
real
desire
is
that
these
ideas
changes
to
the
program
originate
with
the
program.
Review
Committee
sort
of
broad
stakeholder
public
participation
there.
That
would
then
move
to
our
rhapsy
and
and
the
intent
there
you
know,
approve
or
deny
on
an
advisory
basis
can
be
sent
back
to
the
PRC.
When
that
passes,
then
it
would
be
directed
to
the
board
of
directors
for
ultimate
approval.
G
The
PRC
will
provide
advisory
votes
to
the
Rhapsody
on
on
program
changes.
So
again,
when
we
talked
about
this
program,
there
was
a
real
need
and
desire
to
maintain
transparency,
ensure
that
there
was
sort
of
a
broad
ability
for
stakeholders,
States
and
others
to
participate
in.
This
is
this
process.
G
G
They
will
not
be
able
to
sort
of
attribute,
but
it
can
really
provide
information
to
the
Coster
and,
to
the
extent
that
there's
a
big
disagreement.
This
was
in
lieu
of
of
205
filing
rights
for
the
states.
They
can
sort
of
compel
the
Rhapsody
to
come
back
to
the
table
and
further
engage
on
issues
where
there
may
be
disagreement.
G
So
we
can
see
on
the
map
here.
This
is
the
current
participation
in
the
western
resource
adequacy
program.
This
is
what
we're
titling
sort
of
phase.
3A
we've
gone
through
the
initial
design,
sort
of
proof
of
concept.
We've
got
the
final
design
done.
We
filed
the
Tariff
with
fur,
and
these
are
the
26
participants
that
are
currently
part
of
that
process
and
we
will
be
asking
them
to
make
a
decision
to
sign
up
for
the
program
sort
of
subject
themselves
to
non-binding
operation
under
the
Tariff.
G
With
that
two-year
exit
provision,
a
broad
swath
of
folks
here
participating
stretching
from
a
BC
with
powerx
to
our
friends
there
in
the
desert,
Southwest
Nevada,
APS
SRP,
we
have
investor
owned
utilities,
Public
Utilities
cooperatives,
as
well
as
the
independent
power
producers
and
third-party
consumer
Choice
providers.
It's
important
to
note
that
this
was
an
industry
driven
initiative.
It
was
really
you
know,
primarily
to
start
folks
in
the
Pacific
Northwest
coming
to
the
table
saying
you
know,
there's
a
well
understood
potential
sort
of
resource
adequacy
or
looming
resource
adequacy
problem.
G
How
are
we
going
to
address
that?
Roughly
you
know
65
gigs
of
winter
load,
66
gigs
of
Summer
load.
Again,
participation
is
voluntary,
something
that
is
really
unique
to
this
program
is
generally
you
have
a
resource
adequacy
program
as
a
fundamental
component
of
the
RTO
and
we're
really
doing
this.
You
know
absent
a
RTO,
ISO
or
organized
Market
construct.
A
A
F
Program
requires
that
entities
demonstrate
that
they
have
secured
their
share
of
the
regional
capacity
need
for
the
upcoming
season
winter
season
and
by
and
a
summer
binding
season.
This
is
done
seven
months
in
advance.
The
capacity
need,
as
Steve
mentioned,
is
defined
by
a
loss
of
load
modeling.
One
of
the
real
value
propositions
here,
which
has
been
mentioned
previously,
is
sort
of
the
size
of
the
footprint
apps
in
California
and
some
of
our
folks,
you
know
pnm
Tucson
and
others
psco.
F
G
Performance,
how
do
we
access
that
diversity,
absence
and
RTO
or
an
ISO?
We
do
that
with
a
binding
operational
program.
The
operational
program
obligates
members
with
a
calculated
Surplus
and
I'll
talk
a
little
bit
about
that.
Coming
up
to
help
those
participants
with
a
calculated
deficit
on
the
hours
of
highest
need.
There's
going
to
be
some
days
where
your
load
is
low.
Temperatures
are
mild.
Your
vares
are
over
performing
that
sort
of
frees
up
Supply
that
can
be
shared
with
somebody
else.
G
That
in
a
group
of
26
plus
participants
with
that
size
of
load
and
resources,
you
should
be
able
to
meet
the
same
reliability
metric
at
a
lower
planning,
Reserve
margin
that
sort
of
provides
you
know,
rate
payers,
customer
owners,
investment,
cost
savings,
we'd
like
to
say
that
we're
going
to
help
inform
resource
selection.
What
is
very
important
to
note
here
is
that
state
commissions
and
their
regulated
utilities
maintain
sort
of
autonomy
over
the
IRP
planning
process.
So
we
are
in
no
way
dictating
resource
selection.
Our
program
is
technology
agnostic.
G
We
would
like
to
accredit
resources
in
a
way
that
is
fair.
Equitable
represents
its
contribution
to
Mitigation
Of
loss
of
load,
but
are
in
no
way
dictating
one
resource
over
another.
That
remains
that
the
strict
purview
of
of
the
states,
but
we
think
we
can
provide
information
to
help,
inform
that
resource
selection
and
we
hope
that
arrives
at
on
a
forward
basis.
Investment
cost
savings
for
and
use
customers.
F
Program
itself,
the
forward
showing
and
the
operations
program.
So
what
do
we
do
in
the
forward
showing
we
establish
a
regional
reliability
metric?
So
this
helps
us
set
the
capacity
need
and
what
metric
are
we
using
we're
currently
using
a
one
event
day
in
10
years,
loss
of
load
expectation,
so
spp
on
our
behalf?
They
have
a
you,
know,
highly
trained
and
well-educated
staff
and
good
at
doing
these
things,
we've
come
up.
G
G
We
do
that
currently
across
two
regions,
so
we
have
two
sub-regions
that
we're
modeling
the
desert,
Southwest
and
Eastern
side
of
our
footprint
and
the
Pacific
Northwest
portion
of
the
footprint,
so
that
modeling
is
done
on
two
separate
regions
to
arrive
at
the
capacity
you
need
necessary
to
maintain
that
one
event
day
in
10-year
metric,
we've
done
a
couple
of
things
here,
so
we've
applied
some
thoughtful
analytics.
We
hear
very
frequently
that.
G
To
a
gross
Peak,
you
know,
particularly
with
significant
bear
penetration,
doesn't
make
any
sense.
So
we
take
that
gross
Peak
that
load
for
our
footprint.
We
net
out
bear
performance,
and
then
we've
made
some
thoughtful
assumptions
about
interchange,
sort
of
looked
historically
at
what
transactions
say,
for
example,
may
leave
the
Pacific
Northwest
to
support
entities
in
California,
so.
F
Really,
what
is
that
load
profile,
including
not
only
load
Vera
performance,
but
interchange
transaction
as
well,
to
define
the
hours
of
the
greatest
need
and
we
call
those
capacity
critical
hours.
We
have
a
10-year
data
set
of
the
top
five
percent
net
load
plus
interchange
hours,
that
we
can
look
at
and
say.
This
is
indicative
of
the
hours
in
a
given
day
in
a
given
month
where
we
may
see
issues.
G
Then
you
know
once
we
understand
the
capacity
need,
we
have
to
provide
accreditation
or
qualifying
capacity
contribution
to
the
resources,
so
I've
got
to
slide
in
a
minute.
We'll
talk
about
what
that
looks.
Like
we
understand
the
need
on
one
side,
then
we
have
to
stack
up
capacity
credits
on
the
other
to
meet
that
need.
All
of
this
is
done
to
define
a
planning,
Reserve
margin.
So
out
of
this
work
comes
a
monthly
planning,
Reserve
margin
for
each
of
the
sub-regions
for
our
binding
Seasons.
So
we
have
June
through
September
and
excuse
me.
G
F
The
showing
does
include
a
deliverability
component.
So
it's
not
only
important
and
critical
that
there
is
sufficient
Steel
on
the
ground
capacity
available
on
these
hours
of
highest
need,
but
that
we
can
get
those
resources.
D
G
Of
your
p50
plus
PRM,
so
when
you
make
that
forward,
show-
and
you
not
only
have
to
show
sufficient
capacity,
but
you
have
to
show
that
you
can
get
that
actual
capacity
to
resources.
The
75
percent
was
not
a
modeled
solution.
It
was
heavily
negotiated.
There
were
clearly
some
folks
on
the
the
you
know:
no
deliverability
requirement
quite
a
few
more
folks
on
100
percent,
deliverability
or
transmission
requirement.
We
needed
something
that
we
thought
would
keep
Folks
at
the
table
without
a
sort
of
a
significant
impact
on
reliability.
G
There
is
a
a
requirement
that
you
sort
of
firm,
the
rest
of
that
up
prior
to
the
operating
day,
but
we
are
not
making
a
showing
or
evaluating
that
there
is
a
robust
exception
framework,
and
so,
as
many
folks
know,
there
are
transmission
constraints
in
the
west.
You
know
long-term
firm
is
not
always
available.
G
There
are
constrained
paths,
so
we
needed
to
make
or
take
into
account
that
those
situations
may
exist,
and
so
there
is
a
an
exception-
a
robust
exception
framework
documented
in
our
tariff
that
provides
sort
of
a
set
of
exceptions
for
certain
conditions.
G
So
capacity
accreditation
is
something
that's
you
know
of
interest
to
folks.
So
we'll
talk
a
little
bit
about
how
we
do
that,
our
wind
and
solar
resources-
that's
effective
load
carrying
capability,
we've
modeled,
both
the
wind
and
solar
in
zones.
So
we
calculate
the
elcc
on
a
zonal
basis,
allocate
that
capacity,
credit
to
resources
based
on
their
individual
performance.
In
that
zone,
run
of
river
we've
actually
looked
at
a
couple
different
things.
We
started
with
elcc.
F
G
The
storage
hydro,
which
is
a
large
portion
of
our
resource,
stack
for
the
entire
wrap
footprint.
We've
got
an
offline
methodology
for
that
thermal.
It's
a
ucap
method,
so
we're
calculating
an
adjusted,
effective
Forest
outage,
Factor,
short-term
storage.
We
are
moving
to
elcc
for
that,
particularly
with
the
addition
of
the
folks
in
the
desert
Southwest.
G
They
have
brought
sort
of
a
plethora
of
short-term
storage
into
our
resource
stack.
So
we've
tried
to
shore
up
the
way
that
we're
accrediting
that
particular
resource
hybrid
resource
and
there's
currently
not
a
co-optimization
of
the
storage
plus
there,
and
so
that's
done
on
a
sum
of
Parts
basis,
customer
side
resources.
So
somebody
mentioned
this:
we're
seeing
significant
growth
in
demand,
side
and
customer
side
resources
in
our
footprint,
particularly
you
know,
in
the
desert.
Southwest,
you
know
folks
are
telling
us.
It
may
be
upwards
of
sort
of
five
percent
of
the
of
their
load.
G
F
A
So
forward,
showing
that
seven
months
in
advance
of
The
Binding
season
capacity,
Plus
transmission
requirement.
So
then
we
get
to
the
operations
program.
So
the
intent
of
the
operations
program
is
to
evaluate
the
load,
responsible
load,
responsible
entities
situation
relative
to
the
forward
showing.
So
we
made
some
assumptions
about
your
load
about
your
resource
performance,
about
uncertainty
in
the
forward
showing
and
then
we
get
to
the
operations
day
and
I'll
talk
a
little
bit
about
the
timeline
associated
with
this
and
the
potential
impact
on
day
ahead
markets
in
a
minute.
G
Market
runs
trying
to
determine
who
is
Surplus
and
who
is
deficit
relative
to
the
forward,
showing
to
the
extent
that
you're
a
surplus
entity,
you
may
have
a
binding
obligation
to
a
deficit
entity
in
the
program.
This
starts
on
a
seven
day
ahead
basis.
That's
indicative.
We
get
to
the
the
wek
pre-scheduled
day
and
then
you
sort
of
binding
obligation
is
set.
It's
important
to
note
that
if
you're
deemed
to
be
Surplus,
somebody's
deficit
raises
their
hand
and
says
yes,
I
need
that
Supply.
A
A
So
now
we're
going
to
talk
a
little
bit
about
sort
of
interoperability
with
markets,
and
we
really
think
this
is
critical.
You
know,
for
two
reasons,
I
think
it's
rightly
been
identified
here
that
you
know
movement
towards
a
day-to-day
ahead.
Market
is
probably
the
incremental
step
to
an
RTO.
We
really
want
to
ensure
that
sort
of
the
wrap
is
maintaining
the
value
proposition
of
a
standalone
resource
adequacy
program,
but
being
thoughtful
about
our
potential
integration
with
these
Market
offerings.
So
we'll
talk
a
little
bit
about
that.
G
So
you
know,
let's
talk
about
what
this
hold
back
in
energy
delivery
obligation
is
and
how
it
may
relate
to
a
day
ahead.
Market,
so
rap
participants
are
forward
securing
capacity
from
an
identified
resource,
so
it
can
be
a
specific
Source
or
a
system
of
resources
that
are
in
the
portfolio.
That's
been
validated
right
with
transmission
for
deliverability
access
to
these
resources
or
similar
quality
resources
and
transmission
on
the
worst
of
worst
days
is
necessary
to
maintain
our
business
case.
G
If
we
think
of
NV
Energy
as
a
potential
participant
they've
lowered
their
plan
and
Reserve
margin,
you
know,
maybe
solar
is
underperforming.
Maybe
you
know
Idaho
or
somebody
is,
has
Surplus
that's
committed
to
NV
Energy.
We
really
want
to
ensure
that
these
Market
offerings
are
guaranteeing
that
access
to
NV
Energy
for
that
supply
that
that
you've
gone
through
a
forward
procurement
process.
You've
potentially
exposed
yourself
to
these
cost
of
new
entry
penalties,
sort
of
done
the
right
thing
leading
up
after
that
operations
program.
G
We
want
to
ensure
that
you
know
the
partners
in
the
wrap,
whether
they're
an
Edam
participant
a
markets
plus
participant
that
you
have
comfort
in
the
fact
that
you
can
receive
that
Supply
from
a
wrap
participant
regardless
of
the
market
they
may
or
may
not
be
participating
in
on
the
worst
days.
So
that's
very
critically
important
to
us
that
that
prioritization
of
supply
and
transmission
is
maintained
such
that
you
can
maintain
the
value
proposition
of
participation
in
the
wrap.
G
So
a
couple
things
here,
this
idea
of
hold
back
if
I'm
a
surplus
entity
I
have
what
is
now
known
as
a
a
hold
back
requirement.
So
what
is
that
requirement?
This
requirement
comes
on
the
pre-scheduled
day.
It's
going
to
be
known
in
Van
in
advance
of
roughly
0.900
930..
It's
a
potential
delivery
obligation.
It
means
that
I
may
have
to
hold
back,
say:
25
megawatts
on
hour,
ending
17
for
delivery
to
Idaho
or
delivery
to
APS
or
delivery
to
Pace.
G
G
Then
we
get
to
that
T
minus
105
time
frame
on
the
operating
day
that
hold
back
requirement.
That
capacity
may
be
translated
into
an
energy
delivery
requirement
if
you're
delivering
to
Idaho,
maybe
Idaho
raises
their
hand
and
said
yes,
I
asked
you
to
hold
back
25
megawatts
our
ending
17.
as
it
turns
out.
I
really
do
need
that,
so
that
hold
back
obligation
becomes
a
delivery
obligation
at
T,
minus
105.
F
G
Need
to
generate
can
be
reflected
in
the
day
ahead,
a
unit
commitment,
Market
run.
So
then
we
get
to
that
operating
day.
So
again,
this
this
requirement
to
deliver
whether
it
be
to
say
another
Market
participant
an
out-of-market
participant
that
obligation
is
known
prior
to
the
real-time
Market
being
run.
So
we
try
to
be
very
thoughtful
from
the
beginning.
G
Know
Federal
high
growth,
something
like
that.
It
really
is
a
megawatt
value,
you're
incentivized,
to
deliver
because
of
that
non-delivery
penalty.
The
rap
obligation
takes
into
account
uncertainty
in
both
the
day
ahead
and
the
real
time
time
frames.
So
we're
looking
at
that
load,
understanding
the
performance
of
bears
and
incorporating
uncertainty
into
this
calculation.
You
know,
meaning
we
want
to
be
sure
that
we're
not
obligating
capacity
to
the
program
that
might
need
to
stay
with
the
load
responsible
entity.
G
I
mentioned
this
previously
that
this
obligation
can
only
be
reduced
from
day
ahead
to
the
operating
day.
So
you
have
certainty
prior
to
that
data.
Head
Market
run
about
what
your
obligation
might
be.
G
B
H
Be
available
to
the
market
and
that
the
sort
of
the
market
can
take
those
things
into
account
such
that
the
participants
realize
the
benefit
of
that
forward:
procurement
and
diversity
in
the
operations.
Time
frame,
it's
critically
important
for
us
to
have
some
means
in
real
time
to
access
that
diversity,
whether
it
be
our
operations
program
or
a
market
that
helps
us,
maintain
the
viability
and
value
proposition
of
a
standalone
resource
adequacy
program
foreign.
H
So
talk
a
little
bit
about
interoperability
here,
because
I
think
this
is
an
important
topic
and
something
that
has
really
been
emerging.
As
the
market
offerings,
you
know,
sort
of
start
to
be
put
forth
and
and
really
materialize.
H
You
know
we
embraced
early
on
the
objective
of
combat
compatibility
with
existing
and
future
markets.
You
know
we
knew
we
had
the
eim
at
this
time.
We
kicked
off
this
effort.
There
was,
of
course,
discussion
about
Edam
picking
up,
we've
got
markets
plus
now
this
idea
of
interoperability
and
making
sure
that
these
programs
can
work
together
was
really
a
first-class
citizen
in
our
decision
making
process,
and
we
really
view
these,
as
Steve
and
Kara
said
as
a
way
to
these
markets
as
a
way
to
enhance
reliability.
H
G
So
we've
developed
a
set
of
principles.
These
are
draft
principles
but
I'll
just
kind
of
walk
through
these
real
quick.
We
are
in
the
process
of
working
with
our
participant
committee.
To
finalize
these.
We
have
shared
these
with
spp.
Several
of
our
folks
have
provided
presentations
to
them
on
on
how
interoperability
could
work.
Similarly,
in
the
Edam,
Forum
I've
seen
the
same
thing,
so
we
really
want
these
markets
to
be
designed
such
that
they
don't
interfere
or
preclude
participation
in
the
wrap.
You
know
we
have
a
broad
membership
participation
in
the
rap
effort.
G
You
know:
ipps
customer
owned
utilities,
investor
own
utilities
situated
differently
geographically,
obviously,
given
the
size
of
the
footprint,
so
we
would
really
like
to
ensure
that
the
markets
allow
participation
in
the
wrap,
respect
the
governance
framework
and
decision
making
of
the
wrap.
G
So
a
very
extensive
stakeholder
process
sort
of
went
into
establishing
the
governance
framework
that
I
talked
about
previously
a
lot
of
work
with
States,
getting
them
comfortable
with
where
we're
at
you
know,
understanding
how
rap
could
have
could
fit
into
the
IRP
planning
processes
in
areas
where
they
have
traditionally
maintained,
purview
and
there's
a
strong
feeling
that
you
know
the
governance
framework
established
should
be
maintained,
such
that
the
folks
realize
sort
of
the
benefit
that
went
into
that
negotiation
really
want
to
preserve
the
diversity
and
investment
cost
savings
derived
from
participation.
G
So
we
want
to
ensure
that
if
they've
gone
through
that
process
that
those
resources
are
there
to
meet
their
own
load,
that,
if
they're
importing
from
somebody
in
the
wrap
that
that
Supply
the
priority
of
supply
and
transmission
is
maintained,
we
want
to
preserve
the
delivery
of
those
diversity
benefits.
So
that's
hold
back
in
energy
in
the
operational
time
frame
if
I'm
a
market
participant
and
if
we
use
edem
for
an
example.
G
Likewise,
if
I
have
an
export
obligation
that
the
market
recognizes
that
export
obligation
maintains
the
priority
of
that
obligation,
such
that
the
non-market
participant
receives
the
benefit
of
Route
participation,
and
then
you
know
the
last
one
here
and
seeks
to
collaborate
with
rap
to
ensure
compatibility-
and
you
know
really
realize
those
operational
and
reliability
benefits.
I
will
say
that
we
have
you
know.
Spp
has
been
very
good.
Obviously,
we've
partnered
with
them,
as
you
heard
as
the
program
operator,
but
we
have
had
many
discussions
about
interoperability.
A
In
closing,
here
we're
going
to
talk
a
little
bit
about
timelines,
so
I
think
this
fits
in.
We
have
a
transition
to
a
binding
program,
so
we
originally
started
this
effort.
Our
intent
was
to
stand
up
a
program
that
would
be
fully
binding
in
2024,
so
in
working
with
our
participants,
you
know
some
folks
are
are
very
sort
of
dissimilarly
situated.
There
are
entities,
but
the
significant
Surplus
there
are
entities
who
have
been
sort
of
forthcoming
and
saying
I
have
a
transmission
portfolio.
A
I
have
traditionally
relied
on
Market
Imports
to
pair
with
my
transition,
transmission
portfolio
and
I
have
kind
of
a
demonstrated
need
in
the
two
to
five
year
kind
of
time
frame.
It's
going
to
take
me
a
little
bit
longer.
They
have
said
yeah.
We
definitely
agree
with
that
forward
procurement,
sort
of
concept,
but
you
know,
frankly,
at
a
cost
of
new
entry
penalty.
Some
participants
have
a
significant
amount
of
work
to
do,
and
so
we've
changed
our
sort
of
transition
timeline
and
I'll
talk
about
that.
On
the
next
slide.
A
We
thought
it
was
critically
important
that
we
keep
Folks
at
the
table.
Keep
the
footprint
as
large
as
we
possibly
could
you
know,
keep
folks
moving
together
in
lockstep,
and
we
thought
this
thoughtful
transition
to
a
binding
program
allowed
that
we've
made
some
concessions
in
terms
of
participation.
It
allows
folks
to
participate
in
the
program
access
to
voluntary
Supply.
Even
if
they're
not
don't,
have
an
ability
sort
of
to
meet
that
forward
showing
requirement
they
can,
you
know,
be
sort
of
fully
non-binding.
A
A
A
So
there's
some
discretion
about
when
you
have
potential
exposure
to
those
costs
of
new
entry
penalties,
so
that's
sort
of
what
we've
laid
out
in
terms
of
this
transition
to
a
binding
program.
There
is
also
an
ability
for
those
participants
that
have
signed
up
to
be
binding,
I'm
sort
of
just
prior
to
on
that
binding
season
to
sort
of
make
a
reevaluation
there'll
be
no
options:
post
2028
it
would
be
fully
binding
in
2028,
but
there's
some
flexibility
to
accommodate
the
different
situations
among
our
participants.
A
A
We
have
are
working
on
currently
the
decision
and
criteria
for
folks
we're
asking
them
to
make
a
decision
about
which
season
they'll
go
binding
in
December
of
this
year.
In
the
event
that
we
don't
have
ferc
approval,
we
will
have
a
work
order
that
could
extend
our
funding
until
that
Frick
order
is
approved.
We're
obviously
hopeful
that
we
get
an
answer
by
then
in
the
event
of
a
deficiency
letter
or
something
like
that.
We
would
need
some
stop
Gap
funding
to
get
us
to
full
operations
under
the
Tariff.
A
So
I'll
go
ahead
and
and
pause
there.
That's
the
high
level
overview
of
the
organization
where
we're
headed
in
terms
of
governance,
a
sort
of
brief
overview
of
the
western
resource
adequacy
program,
interoperability
with
markets
and
where
we
are
at
with
standing
this
program
up
so
again
appreciate
the
ability
to
participate
and
I'd
like
to
say
you
know
thank
you
to
NV
Energy
for
their
participation
and
and
support
of
this
effort.
A
A
Well,
thank
you
very
much.
Mr
Roy.
Do
we
have
any
questions
from
the
committee
on
this
presentation
and
I'll
start
with
Carson
City.
A
A
Thank
you.
I
have
I,
have
a
few,
but
I
want
to
give
the
other
members
the
committee
down
here
in
Las
Vegas
the
opportunity.
If
anyone
has
any
questions,
oh
Mr,
new
Lloyd.
A
A
I
had
a
couple
of
follow-up
questions
for
you
and
I
wanted
to
start
with
a
statement
that
you
made
very
early
on
in
your
presentation
about
they're
not
being
support
for
an
RTO
within
the
wrap
and
I.
Just
wanted
to
ask
was
that
from
the
the
ra
participating
committee,
the
rapc
that
made
that
decision,
I
guess
I
would
characterize
it
slightly
differently,
not
that
there
was
not
support
for
an
RTO.
A
The.
What
folks
wanted
to
ensure
was
that
the
board
of
directors
could
not
unilaterally
establish
an
RTO
which
would
mandate
participation
by
members
currently
signed
on
to
the
Tariff.
So
I
think
that
was
the
real
kind
of
consideration,
not
that
there
wasn't
value
seen
in
an
RTO
just
there
was
concern
about
the
board
of
directors
being
able
to
sort
of
unilaterally
establish
a
regional
transmission
organization
that
would
compel
participation
based
on
their
signing
on
to
the
Tariff.
Okay.
Thank
you
for
that
clarification.
A
Just
wanted
to
also
ask
a
question
about
the
board:
the
the
movement
towards
a
new,
a
new
board
from
where
you
currently
sit,
and
could
you
talk
just
a
little
bit
about
the
number
of
board
seats
you
currently
have
and
then
what?
Where
you're,
moving
towards
with
the
new
selection
process?
A
A
As
we
move
to
this
transition,
we
have
a
slate
of
four
board
members.
We
have.
Additionally,
one
of
our
existing
board.
Members
will
become
a
voting
member
of
the
new
board,
so
that
would
be
five
holy,
independent
board
members,
one
of
which
will
be
an
existing
wpp
board
member.
Additionally,
the
other
two
that
are
semi-independent
will
be
given
advisory
seats.
So
to
start,
we
will
have
seven
folks
on
the
board
four
new.
A
That
slate
is
being
put
forward
now,
one
board
member
that
will
come
from
the
existing
semi-independent
members
and
two
advisory
seats
that
will
come
from
the
existing
semi
members
as
well.
Those
advisory
seats
will
roll
off
so
we'll
have
a
five-person
board,
fully
independent,
put
forth
by
the
nominee
committee.
A
Thank
you
one
other
question
also
about
how
the
decision-making
process
is
made,
and
you
indicated
that
the
rapc
would
provide
and
I
I
want
to
just
verify
that
this
is
correct.
A
super
majority
position
that
would
go
to
the
board
for
decision
is
that
correct,
yeah,
it's
it's
67
percent
of
house
and
and
Senate
style
voting,
and
that
is
an
advisory
to
the
board.
A
So
the
board
is
by
no
way
mandated
to
rubber
stamp
that,
but
it
would
be
sort
of
you
know
the
intent
is
that
our
our
hope
is
that
it
goes
through.
The
PRC
process
gets
voted
on
by
the
wraps.
He
gets
put
put
forward
to
the
board
for
a
vote.
Ideally,
we
would
have
sort
of
consensus
from
the
the
program
Review
Committee,
which
is
made
up
of
stakeholders.
You
know
anybody
can
come
to
that
and
the
ra
participants
committee
was
67
percent
and
then
go
to
a
vote
for
the
board.
Thank
you.
A
There's
nothing
to
preclude
a
stakeholder
from
going
directly
to
the
board
to
sort
of
object
any
of
the
what
has
made
it
through
that
process.
So
it's
really
opened
it
everybody.
We
anticipate
that
it
would
go
through
the
PRC
Rhapsody
board
process,
but
certainly
you
know
anybody
could
show
up
if
they
were
either
supportive
or
not
supportive
of
certain
initiatives,
and
then
the
community
of
state
representatives
you
indicated,
could
compel
the
rhapsy
to
reconsider
any
position
that
they
were
advancing
is
the
community
of
state
representatives?
A
There
wouldn't
be
any
reason
why
they
couldn't
do
that
exactly
in
lieu
of
the
section
205
filing
rights,
the
states
really
wanted
some
way
to
sort
of
ensure
that
they
could
have
a
meaningful
dialogue
with
the
with
the
Rhapsody
prior
to
you
know
their
vote
on
sending
something
on
an
advisory
basis
to
the
board.
There
wouldn't
be
any
reason
why
the
Coster
couldn't
go
there
directly
to
the
board,
but
you
know
the
States.
You
know
that
signed
or
brought
forth
very
complementary.
You
know
comments
on
the
process.
A
That
was
helpful.
I
have
a
few
more
questions.
If
that's
okay,
so
you
you
mentioned
also
that
the
way
that
you're
establishing
the
planning,
Reserve
margin
is
to
evaluate
these
critical
hours,
10
years
of
information
that
you
have
in
a
on
a
one
and
then
developing
a
planning,
Reserve
margin
based
on
a
one
in
ten
event,
weather
event,
I
assume,
yeah
and
then
adding
that
onto
the
one
in
two
year.
So
that
would
comparing
that
to
a
one
and
two
year,
and
that
would
essentially
be
your
planning
Reserve
margin.
A
Is
that
correct
yeah?
So
so
let
me
kind
of
provide
an
overview
of
this
process.
The
planning,
Reserve
margin
the
capacity
needed
to
mitigate
or
to
maintain
the
one
in
ten
reliable
reliability
metric
is
calculated,
probabilistically,
so
sort
of
you
know,
in
line
with
industry,
best
standard
practices.
For
this
type
of
thing,
there's
a
couple
places
that
we
use
the
capacity
critical
hours
one
we
use
them
in
in
accreditation
of
our
storage,
Hydro
resources,
so
the
storytaker
resources
are
not
accredited
using
elcc.
A
So
it's
that
performance
on
those
capacity
critical
hours,
with
a
nod
towards
how
much
storage
of
those
projects
could
have
been
utilized
that
defines
that
capacity
accreditation.
So
we
use
the
cch's
there
when
we
run
the
elcc
analysis
and
come
up
with
a
sort
of
a
megawatt
contribution
for
a
group
of
resources
based
on
the
Zone
they're
in
we
look
at
that
individual
resources,
performance.
I
On
those
capacity
critical
hours
to
allocate
the
megawatt
value
that
had
been
come
up
with
probabilistically,
so
we
wanted
to
stay
with
best
practices
but
recognize
the
individual
characteristics
of
certain
resources
that
was
important
to
stakeholders
important
to
ipps.
So
we
do
use
it
there,
and
so
it's
it's
not
used
in
establishing
the
reliability
metric.
That's
done!
Probabilistically!
You
know,
load
sampling,
resource
performance,
sampling,
outages,
but
it
is
done.
I
I
It's
translated
to
a
percent
of
load
that
PRM
that
planar
Reserve
margin
is
then
added
to
the
one
and
two
peak
load
to
just
determine
the
monthly
capacity
requirement,
and
are
you
able
to
share
what
range
of
planning
Reserve
margin
you're
looking
at
for
the
desert,
Southwest
versus
the
Pacific
Northwest,
absolutely
I
would
would
it
be
possible
to
provide
that
to
somebody
after
this,
of
course,
I
think,
of
course,
I
I
don't
want
to
misspeak
and
I.
I
Don't
know
it's
a
monthly
there's
nine
numbers
across
two
seasons,
so
I'd
be
I'd,
be
unlikely
to
get
it
correct
off
the
top
of
my
head.
What
we
do
see
is
a
higher
planning,
Reserve
margin
generally
in
the
summer,
obviously,
for
the
desert,
Southwest
and
a
higher
plan
and
Reserve
margin
in
the
winter
for
the
Pacific
Northwest
those
range
from
10
to
26
percent
off
the
top
of
my
head.
We
don't
currently
model
any
transmission
connectivity
between
the
two
sub-regions.
I
That
would
obviously
be
tremendously
beneficial
in
locking
this
unlocking
the
sub-regional
diversity
we
have
actually
written
into
the
Tariff
and
can
operationalize
that
transmission
should
it
exist,
an
lre
could
put
it
in.
You
know
folks
could
come
together,
procure
transmission
if
it
gets
built
in
the
future.
We
actually
have
a
mechanism
in
the
program
to
lower
the
planning.
Reserve
margin
should
that
sub-regional
region
to
region
transmission
exist
either.
I
There
you
go
if
you
could
share
that
with
Laura
Wickham
at
the
governor's
office
of
energy
and
then
all
of
the
all
the
members
of
the
task
force
can
can
have
access
to
that
and
I
have
a
few
questions:
I
I.
Look
this
going
back
to
the
committee
of
state
representatives
is
that
a
regulator
from
every
state
of
that
has
participating
members
and
how
is
it?
How
is
that
person
designated?
Is
it
designated
by
the
state?
Is
it
some?
I
Is
it
picked
by
the
the
program
who
who
gets
to
designate
who
that
is
and
who
are
those
people
every
state
or
Province?
Who
has
an
entity
that
is,
has
a
compliance
obligation
of
the
program?
They
actually
self-select
participation,
so
it
wouldn't
necessarily
have
to
be
say
a
commissioner
commission
staff.
It
could
be
from
an
energy
office
or
something
like
that.
So
it's
really
a
self-organized.
I
A
committee
of
state
representatives
we
have
partnered
with
you
know:
weeb
Maury
is
the
investor
on
utilities?
Are
funding
staff
through
mori's
organization
to
help
with
the
committee
of
state
representatives,
but
they're
generally
self-organized,
and
no
requirement
that
it
be
a
commission
staff?
It
could
be
somebody
from
an
energy
office,
so
so,
if
it's
self-organized
and
there's
no
requirements
like
who
picks
it
like
I
want
to
be
it.
I
Who
gets
to
tell
me
no
or
yes
like
that's
what
that's
what
I'm
trying
to
get
at
so
like?
Does
the
governor
make
an
appointment?
Does
the
or
does
the
the
rap
program
actually
pick
based
on
candidates
put
forward
and
just
to
be
clear?
I
don't
want
to
be
it.
I
was
just
using
that
as
an
example,
but
like
yeah,
like
I
may
have
to
understand.
I
may
have
to
get
back
to
you
on
that
one,
so
I,
don't
miss
it.
I
Okay,
I
appreciate
that
and,
and
then
I
I
have
another
question
like
so
What
in
in
this,
in
this
kind
of
non-binding
voluntary
participation
phase,
what
is
were
the
teeth
like
so
let's
say
you
have
a
Energy
Delivery
obligation
and
that
obligation
is
not
met
and
how?
I
How
can
you
enforce
that
and
and
what
what
are
some
of
the
the
ramifications
or
penalties
for
not
meeting
that
energy
obligation,
the
delivery
obligation
So?
Currently,
if
you're
a
non-binding
participant,
you
know
you
don't
have
a
binding
obligation,
and
so
we
wouldn't
be.
Your
Surplus
would
not
be
obligated
to
the
program.
If
you're
a
deficit
entity,
you
can
other
folks
can
voluntarily
provide
Supply
if
you're
a
surplus
entity
you
can
voluntarily
provide
Supply,
but
that
any
capacity
that
you
may
have
by
calculation
isn't
obligated
to
the
program.
I
So
there
really
is
no
binding
or
no
penalty
as
so
to
speak.
You
know,
if
you
sign
up
as
a
non-binding
participant.
You
are
funding
the
program.
You
don't
have
an
obligation
to
provide
voluntary
Supply
we're
not
calculating
whether
your
Surplus
or
deficit.
If
your
deficit
and
raise
your
hand,
there's
no
guarantee
you're
going
to
get
that
Supply,
it
would
be
all
on
a
voluntary
basis.
So,
in
that
regard
right
there
there's
nothing
to
sort
of.
You
know
compel
significant
participation.
I
What
we
have
heard
from
folks
is
that
you
know
we
don't
want
a
transfer
of
wealth
so
to
speak,
whereby
somebody,
for
example,
you
know
Puget
Sound
Energy,
who,
through
their
IRP
process,
has
been
very
clear
to
say
that
they've
traditionally
relied
on
the
day
ahead.
Market
they
know
they
have
a
need
because
of
load
growth.
You
know
to
sign
up
for
a
binding
program
in
2025
that
they
can't
pass
would
represent
sort
of
a
transfer
of
wealth
from
their
customer
rate.
I
I
We
have
participants
in
this
program
and,
to
be
frank,
you
know
we
don't
look
at
the
participant
participant
at
least
now
performance,
but
there
are
some
folks
with
significant
length
and
they
have
said
to
the
extent
that
we
are
in
this
together.
You
know
we
want
to
help
our
neighbors,
it's
non-binding.
I
Okay,
thank
you.
Go
ahead,
Mr
thoris,
thank
you,
chair,
Brooks,
so
similar
to
what
I
asked
before
I
was
curious
about
the
involvement
of
tribes
within
your
program,
either
as
part
of
the
stakeholder
engagement
process
or
as
participants.
I
So
we
currently
don't
have
any
load
responsible
entities
that
are
primarily
you
know,
sort
of
made
up
of
tribal
organizations.
Our
organization
does
through
our
partnership
with
energy,
Keepers
and
skq,
but
in
terms
of
the
stakeholder
process,
because
it's
an
open,
you
know
public
forum,
those
folks.
If
they're
members
of
consumer
and
utilities
have
environmental
biops
fish
concerns
natural
resources
concerns.
I
The
impact
of
you
know
what
it
means
to
put
a
wind
farm
somewhere,
for
example,
could
all
participate
in
the
program
Review
Committee,
probably
you
know
we
could
evaluate
sort
of
the
makeup
of
that
program.
Review
Committee
and
make
sure
that
we
have
representation
say
from
the
tribal
Community
rather
than
public
interest
organizations,
or
you
know
consumer
interests,
it
might
might
be
beneficial,
I
think
that's
something
we
should
explore.
I
I
There
is
not
currently
any
overlap.
You
know,
I
would
have
to
go
back
and
review
our
independence
criteria.
Talk
to
our
legal
staff,
I
I,
don't
know
that
we
would
anything
would
preclude
that
it
might
be
a
slightly
different
with
spp,
because
they
are
the
program
operator
that
we've
selected,
but
to
the
extent
that
they're,
you
know
independent
and
that's
generally
independent
of
members
and
participants.
You
know
at
least
on
the
surface
it
doesn't
seem
like
they
would
be
precluded.
I
J
Thank
you,
chair
Ryan.
It's
great
to
see
you
you're!
You
are
here.
Marker
is
a
lot
further
than
it
was
when
you
presented
to
my
members
this
spring.
So
I
really
appreciate
your
presentation.
The
chair
just
asked
a
question
about
the
non-binding
phase,
but
I
want
to
talk
a
little
bit
about
the
teeth
of
The
Binding
phase.
J
You
know
here
in
the
west
when
we
had
these
issues
at
the
beginning
of
last
month.
We
saw
behaviors
well
here.
I'll
take
a
step
back
first,
when
we're
talking
about
reliability,
I
see
a
big
role
in
base
load
resources,
schedulable
resources,
so
hydropower,
of
course,
thermal
and
then
batteries
I
think
have
a
big
role
to
play.
But
at
the
beginning
of
September
we
saw
some
participants
Utilities
in
the
west,
deploying
battery
resources
at
earlier
times
in
the
day
as
load
smoothing
resources,
as
opposed
to
reserving
those
resources
until
critical
hours.
J
You
know
generally
six
to
nine
PM,
so
let's
say
that
a
load
serving
entity
did
deploy
resources
in
a
way
that
was
internally
beneficial
earlier
in
the
day.
To
to
you
know,
prevent
issues,
but
then
did
not
Reserve
enough
for
these
critical
times
again.
That
just
generally
are
in
the
evening
in
the
west
right
now
what
what
are
the
teeth?
You
know
there
are
Financial
penalties,
but
how
is
rap-
and
you
know
these
RI
programs-
how
are
you
looking
at
preventing
that
just
becoming
the
cost
of
doing
business
if
you
will
well?
J
So
that's
a
good
question
so
the
way
that
we're
currently
intending
to
prevent
that
is,
make
the
cost
of
business
so
high
that
it's
not
an
economic
choice.
So
and,
to
be
honest,
you
know
we're
talking
about
up
to
50x,
so
50
times
the
index
for
non-delivery
penalty.
If
that
need
wasn't
able
to
be
served
by
the
program,
and
so
you
know,
you're
you're
understanding
your
potential
obligations
seven
days
in
advance,
you've
got
an
opportunity
on
the
day
ahead.
Should
it
exist
to
sort
of
procure
if
you
need
delivery
firm
up
that
transmission?
J
So
you
know
we
don't
want
it
to
be
an
economic
choice,
and
so
we
think
you
know
up
to
50
times
what
you
would
pay
to
just
have
procured
it
in
the
market.
Could
you
and
delivered
it?
You
know,
we
think,
that's
a
pretty
significant
disincentive.
Of
course
there
is
the
you
know
we're
all
in
this
together.
J
The
folks
have
a
real
kind
kind
of
interest
in
delivering
when
they
have
the
obligation,
because
they're
going
to
be
on
the
other
side
of
that
potentially
at
some
point
right,
so
I
think
there's
an
aspect
of
it.
That
is,
that
that's
probably
not
as
strong
an
incentive
as
50
times
the
index,
but
it
is
an
incentive
nonetheless,
and
then
of
course,
kind
of
the
independent
evaluator
and
board
of
directors.
Looking
at
these
things,
you
know
we
wouldn't
allow
somebody
to
stay
in
the
program
if
they
were
sort
of
habitually.
J
You
know
not
delivering
on
their
obligation.
Now
that
has
an
impact
on
a
forward
basis,
because
you've
gained
some
diversity
of
load
and
resources.
But
if
you
can't
realize
that
right,
that's
a
problem,
so
we've
tried
to
make
some
outside
of
financial
penalties.
You
know
just
a
strong
incentive
because
you
may
be,
on
the
opposite
end
of
this
Sunday
to
make
allowances
for
the
board
to
sort
of
address
bad
bad
actor
type
of
situations.
J
Mr
Hansen,
hi,
Ryan
I
have
a
quick
follow-up
to
that
line
of
questioning
there.
So
in
some
ra
markets,
there's
seasonal
testing
periods
for
resources
that
opt
into
the
market
and
they'll
say
we'll
give
you
a
three-week
period
where
that's
your
testing
period
in
any
given
moment.
The
market
could
call
on
that
resource
just
to
see
how
it
actually
does
react
see
now.
So
it's
kind
of
a
before
you
get
into
July
or
August,
and
you
realize
you
have
an
issue
with
that
resource
being
able
to
perform
it's
more
of
a
preventative.
J
Look
in
that
is
that
something
you're
considering
as
well
sure
we
we
have
in
our
tariff
testing
requirements,
for
you,
know
thermal
and
traditional
resources,
ones
that
aren't
accredited
probabilistically.
We
have
something
very
similar
for
customer
side,
resources
and
demand
response,
and
that's
really
sort
of
the
get
at
that
thing
that
you're
talking
about
and
tell
us
your
resources
is
good
for
a
certain
amount.
We
want
to
understand
what
that
is.
Much
of
that
is
going
to
be
in
the
business
practices
and,
frankly,
we
have
some
work
to
do
in
that
area.
J
Sort
of
this
non-bining
Runway
gives
us
a
little
bit
of
time
to
do
that,
but
we
have
contemplated
testing
right
around
criteria.
Excuse
me
for
many
of
our
resources
and
that's
going
to
give
the
program
operator
other
participants
and
and
the
program
administrator
comfort
that
those
resources
are
going
to
perform
now.
I
want
to
be
very
careful
to
say,
there's
clearly
with
recent
events.
You
know,
particularly
in
Texas
this
idea
of
resiliency.
That
is
something
I
think
we,
along
with
others,
are,
are
very
much
kind
of
struggling
with.
J
You
know
not
only
sort
of
the
capacity
requirement
of
the
program,
but
what
it
looks
like
from
an
energy
perspective.
You
know
we
given
the
incremental
nature
of
what
we
were
asked
to
do
focused
on
a
capacity
adequacy
program,
but
we're
very
closely
watching
this.
It's
of
particular
concern
to
kind
of
how
our
program,
given
our
Reliance
on
hydro
as
a
potentially
fuel
limited
resource,
so
I
want
to
be
careful
to
say.
Yes,
there
is
this
testing
requirement.
The
testing
requirement
is
really
around.
J
Did
we
excuse
me,
do
we
have
any
further
questions
from
the
commit
the
task
force
either
up
north
or
down
here
all
right?
Well,
thank
you.
So
much
I
appreciate
the
presentation
and
and
look
forward
to
any
any
follow-up
materials
that
you
want
to
share
with
the
task
force,
and
we
will
use
this
presentation
you
shared
with
us
this
morning
as
a
reference
in
future
conversation.
So
thank
you
so
much
that
was
a
very
informative.
J
So
we
will
we
have
one
more
presentation
and
it's
from
the
California
independent
system
operator,
and
then
we
will
have
a
brief
kind
of
summary
of
next
steps
on
report
from
director
Bob
cyan
after
that,
but
I
think
it
sounds
like
I.
Don't
want
to
take
a
long
lunch
break
because
we'll
be
I!
Think
we'll
be
done
relatively.
J
You
know,
quick
around
one
o'clock-ish,
so
I
would
like
to
take
like
a
10
to
15
minute
break
right
now
and
then
we'll
come
back
and
we'll
hear
from
kaiso
and
director
bobsian,
and
that
will
be
all
of
our
work
for
the
day.
So
it
is
now
1207
if
we
could
be
reconvened
around
12
20.
That
would
be
great.
I
Just
keep
that
in
mind
when
we're
asking
questions
this
afternoon
and
as
we
make
our
way
back
to
our
seats,
we
could
get
started
and
we
have
with
us
today
from
the
California
independent
system
operator.
We
have
Stacy
Crowley
and
we
have
Holly
Taylor
who
are
going
to
give
their
presentation
this
this
afternoon
and
you
can
get
started
whenever
you're
ready.
I
I
These
Arenas.
So
today,
Holly
and
I
wanted
to
just
go
over
a
couple
of
our
current
activities.
I
first
wanted
to
touch
on
transmission
planning,
and
some
of
the
projects
that
we
see
coming
through
I
know
that's
very
important
to
this
task
force.
Second,
we'll
talk,
Holly
will
talk
on
the
current
market
activities,
including
the
Western
Energy
and
balance
Market.
I
Our
look
at
the
day
ahead,
market
and
Beyond
I'll
go
back
and
touch
on
governance,
which
I
know
is
a
key
issue
for
you
all
and
then
just
finished
on
a
quick
observation
on
the
summer
heat
event
that
we
had
around
Labor
Day.
So
that
is
our
plan
for
today
and
we'll
go
through
fairly
quickly.
This
is
the
obligatory
opening
slide
of
what
the
California
independent
system
operator
is
and
does
I.
Think
most
of
you
had
heard
have
heard
from
us
in
the
past,
but
you
know
we're
situated
in
the
west
as
right.
I
Now,
the
only
Market
operator,
with
the
edition
of
the
the
Weiss,
the
Western
Energy
imbalance,
services
from
spp,
and
we
operate
in
10
states
with
the
energy
and
balance
Market
and
the
we
perform
the
reliability
coordination
services
for
much
of
the
West.
I
So
when
we
get
into
transmission
planning,
clearly
it's
been
a
an
important
topic
in
the
west
to
see
that
a
lot
of
the
new
generation
that's
being
put
forward
in
terms
of
plans
both
through
irps
and
state
policies,
can
actually
access
the
grid
right.
So
the
idea
of
new
transmission
throughout
the
West
is
seen
as
critical
to
helping
states
meet
their
energy
goals
and
helping
utilities
get
those
resources
online.
I
So
this
20-year
resource
plan
was
really
meant
to
sort
of
start
the
conversation
and
really
see
where
generally
most
of
the
build
out
will
come
from,
and
so
this
map,
while
it's
a
little
bit
busy,
is
really
meant
to
describe
the
key
areas
where
we
see
resources
being
developed
and
then
where
they
would
need
to
be
brought
at
least
to
serve
California
load
and
and
the
small
portion
of
Nevada.
I
So,
given
those
long
lead
times,
we
wanted
to
get
this
conversation
going
and
you'll
see
that
it's
it's
a
diverse
mix
and
we've
we've
often
recognized
the
need
for
that.
I
So
this
was
just
helpful
and
it's
and
it
started
to
to
look
at
the
cost
associated
with
the
transmission
projects
and,
as
you
can
see
from
this
chart,
our
findings
are
that
you
know
we
see
about
30
billion
dollars
worth
of
transmission
costs,
to
get
us
to
our
2045
goals
that
you
know
in
transmission.
That
isn't
it's
not
too
bad.
But
it
is
it's
a
lot
of
work
and
it's
a
lot
of
work.
That's
going
to
take
coordination
permitting
and
and
a
real
emphasis
on
on
keeping
that
ball
moving
forward.
I
So,
in
addition
to
that
20-year
Outlook,
we
also,
as
I
mentioned,
we
do
an
annual
transmission
plan
that
looks
out
10
years
and
and
that
we
do
that
every
year.
But
we
also
are
working
with
stakeholders
to
keep
improving
that
process,
because
things
change
right.
The
the
the
needs
of
the
system
keep
changing.
So
we
are
in
process
of
trying
to
improve
the
transmission
planning
process
to
really
recognize
the
situation
we're
now.
I
This
is
this
is
fairly
detailed,
but
what
I
wanted
to
point
out
was
that
we
are
in
the
middle
of
this
process
and,
if
folks
have
interest
in
engaging,
we
can
certainly
certainly
welcome
your
input.
But
the
idea
here
is
that
we
want
to
match
up
the
timeline
of
of
our
process
with
with
stakeholders
to
make
sure
that
they
are
able
to
engage
and
bring
their
projects
forward.
I
Have
the
the
dialogue
amongst
the
larger
group
and
bring
a
plan
forward
to
our
board
for
approval
every
year,
and
so
we're
just
shifting
the
timeline.
Usually,
we
ask
for
submittals
by
January
we're
now
going
to
move
to
March
so
that
our
board
can
take
a
look
at
that
and
approve
that
in
a
timely
way.
We
also
just
want
to
improve
transparency
and
coordination
amongst
the
other
processes
going
on.
So
that's
resource
procurement
and
Outlook
load
forecasting.
A
It's
been
discussed
a
little
bit
already,
but
the
there's
significant
transmission
projects
being
considered
in
the
west
and
and
Senator
Brooks
mentioned
a
number
of
them.
It
is
so
the
iso
is
its
own
planning
region,
but
we
work
closely
with
West
connect,
which
is
a
planning
region
within
which
Envy
energy
sits,
and
then
the
third
planning
region
in
the
west
is
called
Northern
grid
and
we,
as
planning
regions,
get
together
annually
to
look
at
these.
What
I
would
call,
inter
state
or
inter-regional
transmission
projects
to
see
if
there.
F
Are
those
sort
of
mutual
benefits
Associated
across
the
the
service
Footprints
in
developing
those
lines?
So
this
map
is
really
intended
to
show
the
past
several
years
of
conversation.
With
regards
to
these
inter-regional
planning
projects,
you
recognize
many
of
the
names
and
several
of
them
are
have
Nevada's
Focus
I.
F
Think
chair,
Brooks,
also
recognized
that
Nevada
is,
is
in
a
unique
position,
both
in
terms
of
geography
and
in
terms
of
the
interconnection
right,
just
the
physical
transmission
infrastructure
that
we
have
that
you
are
critical
to
the
flow
of
electricity
throughout
the
west
and
I
think
you
know
the
West
recognizes
the
unique
situation
that
Nevada
is
in
in
so
many
ways.
There
are
some
interesting
projects,
we're
trying
to
be
creative
in
our
world
to
to
get
some
of
these
projects
off
the
ground,
recognizing
that
it
does
take
a
long
time.
F
I
Through
reliability
filters,
we
offer
this
subscriber
participating
transmission
owner
model
for
Transwest
Express.
They
came
to
us
with
an
interest
in
doing
that
and
we
found
a
way
to
really
recognize
the
need.
This
chicken
and
egg
scenario
right
where
they
have
gone
a
long
way
to
developing
the
permanent
transmission
rights
of
way,
but
they
haven't
yet
gotten
the
perch
power
purchase
agreements
on
the
other
end.
So
this
is
a
way
for
them
to
get
that
process
moving,
but
it
does
not.
I
It
does
not
burden
the
California
rate
payers
or
the
rate
the
consumers
of
our
footprint
until
they
have
the
contracts
and
until
they
work
out
their
the
pricing.
So
this
is
a
really
interesting
model.
It's
one
that
I
think
is
very
unique.
It
provides
access
to
the
geographically
diverse
resources
that
we're
looking
at
and
and
Transwest
Express
would
look
for
the
recovery
of
their
Cross
of
their
costs
directly
by
the
subscribers
to
that
line.
So
it
really
wouldn't
put
any
undue
burden
on
customers
until
those
contracts
became
clear.
I
We're
also
looking
at
projects
like
swept
North
and
others
to
see.
If
there's
interest
in
the
the
Idaho
wind
resources
that
that
would
access-
and
we
have
a
current
process
underway
to
really
solicit
interest
in
that
type
of
project,
so
we
want
to
keep
our
eye
on
the
ball,
because
you
both
have
to
look
near
term
at
what
we
need
for
reliability
and
to
get
us
through
these,
these
near-term,
Summers
and
and
that
kind
of
thing.
I
Finally,
on
this
section,
I
just
wanted
to
note
the
interconnection
cue,
which
I
know
a
lot
of
people
have
been
talking
about,
and
certainly
it's
quite
large,
so
you'll
see
here
over
230
000
megawatts
of
of
resources
that
want
to
get
into
our
our
system,
and
we
need
to
figure
out
how
to
make
that
more
reasonable
right.
We
all
recognize
that
that's
that's
not
reasonable
and
that
we
don't
want
any
projects
that
maybe
are
not
as
realistic
as
others
to
impede
those
that
really
are
right.
I
So
we
again
are
working
with
stakeholders
to
try
to
improve
that
process,
really
make
sure
that
projects
are
setting
milestones
and
meeting
those
Milestone
goals,
or
else
they're
sort
of
lose
their
spot
in
the
queue
so
just
to
say
that
we
understand
that
that's
an
issue,
and
that
is
part
and
parcel
to
getting
these
transmission
projects
built
as
to
having
a
realistic
interconnection.
Cue,
so
I'm
going
to
now
turn
it
over
to
to
Holly
Taylor,
and
she
will
talk
about
our
current
market
activities.
All
right!
Excuse
me,
thank
you,
Stacy!
Thank
you.
I
F
I
We'll
bring
on
three
additional
members
growing
that
number
of
participating
entities
to
22
and
representing
approximately
79
of
load
in
the
western
interconnection.
So
again
many
benefits
for
customers,
Inc
and
particip,
including
enhanced
grid
reliability.
It
brings
economic
benefits
again
to
Market
participants,
electricity
customers.
It's
really
helped
us
to
improve
integration
of
renewable
energy
resources
into
the
grid
and
also
improved
operational
Efficiencies
For
example.
It's
reduced
the
need
for
real-time,
flexible
reserves,
and
it's
also
contributed
to
the
reduction
of
CO2
emissions,
a
reduction
exceeding
760
000
metric
tons.
I
So
many
benefits
we'll
go
ahead
to
the
next
slide
and
going
to
those
benefits.
F
Benefits
specifically
we're
expecting
a
third
quarter
benefits
report
here
soon.
What
you
see
here
reflects
our
second
quarter
benefits
for
2022
and
so
far
since
its
launch
in
2014.
The
cumulative
benefits
of
weem
are
approximately
2.4
billion
dollars
and
envy
energy.
Speaking
specifically
to
that
entity.
Envy
energy
joined
in
descent,
late,
December
in
December
of
2015
and
cumulative
benefits
to
date
for
NV
Energy
are
in
excess
of
174
million
dollars.
So
this
Market,
the
Western
Energy
and
balance
Market.
F
Alright,
so
now
looking
to
expand
upon
those
benefits
of
the
real-time
Market,
we're
looking
at
the
an
extended
day
ahead,
market
we've
been
engaging
stakeholders
in
this
process.
This
is
a
voluntary
day
ahead.
Market
that
has
We
Believe
has
the
potential
to
deliver
additional
economic
reliability
and
environmental
benefits
Beyond
those
we've
experienced
with
the
weem
so
with
unit
commitment
in
the
day
ahead.
This
is
allows
us
to
access
more
economic
Supply.
It
provides
additional
operational
and
capacity
benefits
with
respect
to
reliability.
F
I
What
we're
doing
with
the
weem,
while
still
respecting
individual
visual
State
policies,
so
looking
at
our
Edam
time
timeline
and
stakeholder
engagement,
I'll
just
say
that
stakeholder
working
groups
have
been
critical
to
the
design
of
this
Market.
Our
stakeholder
working
groups
have
been
well
attended.
They
were
engaged
early
on
in
both
shaping
the
scope
of
this
initiative
and
prioritizing
the
issues
to
be
covered
as
part
of
this
initiative,
all
along
and
the
stakeholders
continue
to
be
very
deeply
engaged.
I
So
as
we
continue
that
we
continue
to
experience
a
robust
dialogue
and
this,
so
some
key
elements
of
this
effort
really
are
that
opportunity
for
stakeholders
to
engage
and
help
design
this
this
market
and
also
working
together
toward
designing
a
to
developing
a
fair
design
approach.
That
applies
equally
to
all
participants.
So,
coming
up
this
to
proposal,
a
final
proposal
will
go
to
the
board
and
we
governing
body.
As
you
see
in
the
last
bullet
here,
the
iso
Board
of
Governors
has
committed
to
supporting
joint
Authority
for
decision
making
on
the
Edam
proposal.
I
I
With
respect
to
the
day
ahead
resource
efficiency
evaluation,
this
is
looking
at
each
hour
to
make
sure
that
each
entity
is
coming
into
the
market
with
sufficient
Supply
to
reliably
serve
its
load.
This
evaluation
is
compatible
with
the
Western
resource
adequacy
program,
with
the
wrap
the
resource
adequacy
programs
it
and
it
essentially
Bridges
the
gap
between
an
evaluation
of
resource
adequacy
and
adequacy
in
the
real-time
market.
I
So
it
runs
in
the
day
ahead
to
again
make
sure
that
all
participating
entities
are
coming
in
with
the
supply
necessary
to
reliably
serve
their
load
and
just
quickly
I'll
note
I'll
touch
on
a
few
others
transmission
availability
in
the
Edam.
We
want
to
make
sure,
there's
enough
transmission
capacity
to
allow
economic
transfers
to
be
optimized
over
that
Edam
footprint
and
then
I'll.
Lastly,
touch
on
greenhouse
gas
accounting.
I
I
I
So
I
have
a
next
slide
and
I'm
not
going
to
dive
into
this,
but
happy
to
answer.
Questions
later
connect
with
you
later
on
this,
but
we
do
recognize
that
transmission
service
and
Market
scheduling
priorities,
also
known
as
wheel
through.
We
recognize
that
this
is
a
very
important
issue
for
stakeholders,
we're
engaging
stakeholders
in
a
dialogue
here,
looking
Across
the
Nation
and
the
West
to
see
how
others
handle
wheel,
throughs.
C
A
A
A
So
first
and
you've
heard
a
lot
about
governance
structures
here
today
and
they're
all
you
know
somewhat
similar,
but
where
you
have
sort
of
the
need
for
an
independent
board
making
decisions.
And
then
you
know
a
series
of
of
committees
or
touch
points
where
stakeholders
can
engage
and
participate
in
the
in
the
dialogue
going
through.
A
So
this
chart
and
description
is
really
the
the
basis
of
our
current
governance
structure,
where
we
have
I
think
many
of
you
know
a
Board
of
Governors
that
was
statutorily
created
in
California
that
is
appointed
by
the
governor
and
confirmed
by
the
state
senate.
That
independent
board
means
that
they
don't
have
any
financial
interest
in
the
market
and
that
that
definition
of
Independence
is
similar
to
that.
You
would
find
at
spp
and
and
the
rap
program
that
they're
looking
to
create
it's
sort
of
that.
A
They
can't
have
skin
in
the
game
when
they're,
making
these
decisions
and
when
we
started
the
energy
and
balance
Market.
We
had
a
stakeholder
group
also
develop
the
governance
structure
for
to
really
include
that
Regional
voice,
and
that
is
by
creating
a
second
body.
We
call
it
the
eim
or
weim
governing
body.
They
are
also
a
five-member
independent
board.
They
are
self-selected
rather
than
being
selected
by
the
governor.
A
They
are
selected
through
a
nomination
process
and
the
board
itself
appoints
new
members
to
it,
and
so
those
two
bodies
stand
together
when
it's
related
to
energy
imbalance,
Market
issues,
they
stand
together
and
make
joint
joint
decisions,
the
governing
body
where
it
doesn't
have
that
joint
Authority
has
advisory
input
over
all
real-time
rules
if
it
doesn't
fall
within
the
energy
and
balance
Market
itself.
A
So
that's
the
decision-making
process.
Currently
as
it
stands
for
the
Western
Energy
imbalance
Market.
There
is
a
dispute
resolution
process
so
that
if
one
body
doesn't
agree
with
the
proposal,
it
would
go
back
to
stakeholders
to
try
to
find
a
solution
and
bring
it
back
forward,
and
that
goes
further
to
say.
If
that
doesn't
work,.
H
There's
other
remedies,
including
having
the
governing
body
file
an
alternate
opinion
to
ferc
when
we
file
so
there's
some
some
safeguards
put
in
place.
If,
if
the
two
bodies
don't
agree
so
far,
they
have
not
had
a
dispute
on
decisions
to
date.
The
other
components
of
our
governance
structure
are
equally
important,
and
that
is
the
stakeholder.
The
way
for
stakeholders
to
engage
you've
heard
this
morning
about
various
types
of
State
regulator,
committees
or
state
representative
committees,
and
that's
an
important
component.
We
have
what
we
call
the
body
of
State
Regulators.
H
This
is
a
member
of
a
Utility
Commission
from
each
state
in
which
the
energy
and
balance
Market
operates,
and
we
have
a
regional
issues
Forum.
That
is
meant
to
be
really
an
open
self-governing
Forum.
To
talk
about
any
issues
that
are
of
interest
to
a
this
is
a
cross-sectional
group
of
stakeholders
to
talk
about
Market
issues.
They
can
bring
advice
to
the
governing
body
or
the
or
the
board
or
ISO
management
at
any
time,
there's
General
stakeholder
input,
so
we
have
really
a
flat
hierarchy
of
stakeholder
engagement.
F
Have
three
other
groups
worth
mentioning?
We
have
a
market
surveillance
committee,
they
are
independent.
A
High
level
in
terms
of
its
performance
and
sort
of
equity
issues,
and
so
they
are
paid
independently,
they
work
directly
with
the
board
on
key
Market
issues
and
the
department
of
Market
Market
monitoring
that
is
universal
across
isos.
It
is
something
that
for
wants
to
have
where
this
group
can
confidentially
look
at
potential,
Market
manipulation
and
other
things
that
need
to
get
flagged
and
taken
care
of
through
the
Federal
Energy
Regulatory
Commission.
So
that
group
is
an
important
piece
of
this
puzzle
and
recently
the
group
of
stakeholders.
A
When
we
looked
at
enhancing
the
role
of
of
the
governing
body
they
had
asked
for,
and
we
have
implemented
the
hiring
of
an
independent
Market
expert.
This
is
a
market
expert
that
is
hired
selected
by
the
governing
body
itself
and
works
directly
with
the
governing
body
to
answer
any
questions
they
might
have
on
the
market.
So
if
there's
any
perception
that
our
Market
surveillance
committee
has
some
undue
influence
because
it's
managed
by
our
board,
this
independent
Market
expert
is
meant
to
say
no.
This
is
this
is
for
the
governing
body.
A
A
Look
at
making
a
proposal
to
the
board
and
the
governing
body
on
these
changes.
You'll
see
this
is
just
a
list
of
the
current
governing
body
members,
your
own
Rebecca
Wagner,
sitting
on
this
committee
and
has
been
actually
engaged
in
these
governance
conversations
from
the
very
beginning,
so
you
have
good
representation
there.
We
also
have
a
member
of
of
the
body
of
State
regulators
and
non-voting
members
from
both
the
governing
body
and
the
board
to
really
sit
in.
A
They
have
taken
quite
a
bit
of
stakeholder
feedback,
have
had
some
public
meetings
and
discussions
on
this,
but
they
are
recommending
generally
to
support
this
joint
Authority
model
that
I
explained
earlier
so
using
that
same
joint
Authority
model,
but
expanding
the
scope
of
decisions
that
fall
under
joint
authority
to
include
applicable
day
ahead
Market
rules.
They
are
still
contemplating
the
exact
scope
of
that
and
that
will
be
in
the
paper
that
they
produce
here
at
the
end
of
the
month.
A
A
Should
we
look
at
the
qualifications
of
the
people
sitting
on
that
body,
and
things
like
that,
also
recognizing
that
both
the
board
and
the
governing
body
have
the
interests
of
all
Market
participants
in
line.
So
when
they're
making
decisions
they're,
they
have
to
have
this
hat
of
a
full
Market
participation,
engagement
and
I
think
that
that
is
something
that
this
committee
wants
to
re-emphasize
in
the
governing
documents
itself.
A
Through
our
bylaws
and
and
things
like
that,
so
again,
they
will
put
a
paper
out
in
October
and
they
will
to
align
with
what
Holly
mentioned
on
the
market
design.
They
will
try
to
get
to
a
decision
by
the
governing
body
and
the
board
early
next
year,
switching
to
assembly
concurrent
resolution
188-
and
this
is
something
that
chair
Brooks
mentioned
at
the
onset
of
this
the
hearing.
This
is
a
bill
that
assemblyman
Chris
Holden
put
forward.
A
He
had
74
co-sponsors
on
the
bill
and
it
was
unanimously
approved
over
in
both
houses,
and
so
that
shows
real
support
for
for
the
intent
behind
this
resolution
and
I
won't
repeat
what
the
senator
said,
but
it's
really
looking
at
existing
studies,
refreshing
the
minds
of
of
the
of
the
legislators
to
say:
okay,
what's
been
going,
a
lot
has
changed
since
we
last
talked
about
governance
of
the
iso
in
front
of
the
California
legislature.
Let's
raise
awareness,
let's
show
the
value
that
has
already
been
accrued
through
the
Western
Energy
imbalance.
Market.
A
Let's
recognize
that
states
have
implemented
more
advanced,
clean
energy
policies
around
the
West.
Let's
recognize
is
that
Nevada
and
Colorado
passed
legislation
requiring
their
utilities
to
join
isos
Etc.
So
really
life
has
changed
in
the
west
since
California
last.
Looked
at
this,
so
raise
awareness
is
a
is
a
really
critical
component.
A
So,
with
the
passage
of
that
bill,
the
iso
has
implemented
or
starting
to
implement
the
activities
within
that
we
have
coordinated
with
the
California
balancing
authorities
within
the
state
that
includes
MV
energy.
By
the
way
they
have
a
small
footprint
of
their
balancing
Authority
responsibilities
in
the
Tahoe
region,
and
we
have
sort
of
introduced
a
high
level
set
of
action
items
and
Milestones
that
we'd
like
to
meet
with
them.
A
So
we
will
host
a
call
next
Monday
at
10
am
specific
time
to
really
kick
off
this
conversation.
We
will
show
and
post
the
list
of
studies
that
we
would
like
to
consider,
but
we
also
want
stakeholder
input.
Is
this
the
right
list
of
studies?
Would
you
like
us
to
add
more?
Would
you
like
us
to
remove
some
and
then
nrel
will
set
forward
and
and
assemble
their
sort
of
summary
around
the
key
issues
associated
with
regionalization?
A
In
the
west,
we
will
continue
to
ask
for
stakeholder
feedback
along
the
way
and
in
that
market
notice,
which
will
go
out
today.
There'll
be
an
email
box.
Where
you
can,
you
can
put
information,
and
certainly
you
can
always
contact
me
or
Holly
if
you've
got
any
questions
on
that
along
the
way.
But
we're
excited
to
implement
that
and
chair
Holden
is
excited
to
see
that
get
submitted
to
the
legislature
before
the
end
of
February
of
next
year.
I
just
added
a
quote
from
the
assemblyman.
A
He
is
really
and
I
know
he's
worked
closely
with
Senator
Brooks
and
other
legislators
around
the
West
to
just
Express
the
importance
of
the
coordination
amongst
State
leadership
on
these
issues
and
I
think
he
wants
to
Foster
that
he
invited
folks
in
to
talk
about
this
when
he
has
hearings
and
things,
and
likewise
he'd
like
to
come
out
to
the
west
and
really
have
a
good
conversation
around
this.
A
Okay,
so
I'm
going
to
wrap
up
with
just
a
quick
summary
but
I
think
Senator
Brooks
did
a
great
job
of
describing
the
events
of
of
September,
but
it's
something
that
I
think
really
is
a
real
case
for
the
coordination,
the
collaboration
that
happened
across
the
west
and
those
relationships
that
have
been
developed
because
of
the
energy
imbalance
Market,
you
know
now,
CEOs
are
picking
up
the
phone
and
calling
each
other.
A
A
We
called
Flex
alerts
10
days
in
a
row
and,
as
the
senator
mentioned,
we
broke
records
all
along
the
way
for
high
heat
days
and
and
load
across
the
west,
and
in
California
there
were
several
things
that
that
that
helped
us
and-
and
we've
talked
about
a
few
of
them
already
that
coordination.
A
A
I
forget
at
what
time
I
it
was
five
or
six,
and
we
immediately
saw
that
drop
and
it
was
I,
think
Californians
realized.
We
were
in
dire
situation,
and
so
there
was
about
a
2,
000
megawatt
drop
in
load
pretty
quickly
because
of
that
conservation
demand
response,
which
is
paid
in
many
cases.
There's
there's
several
types
of
programs.
We
have
for
demand
response
that
really
helped
I
have
a
chart
here,
just
to
show
you
now.
A
We
also
had
a
record
three-hour
ramp,
which
we
call
that
so
that
ramp,
when
the
Sun
goes
down
and
energy
is
still
needed.
We
have
we
needed
7
000
megawatts
over
that
three
hour
period,
which
is
a
significant
amount
of
energy.
Over
that
period,
batteries
played
a
significant
role
and
Miss
Turner
I
know
you
brought
that
up.
Batteries
are
a
new,
a
new
technology
for
our
system
right
and
so
we're
learning.
A
So
all
that
said,
it
really
was
a
test
case
for
for
that
collaboration,
we
believe
that,
with
an
Edam
with
a
day
ahead,
Market
the
the
event
would
have
been
even
better
responded
to.
So
we
have
that
day
ahead.
Acknowledgment
and
commitment
of
units,
so
I
think
day
ahead
would
only
enhance
that
reliability.
A
Here's
some
stats,
we
WE
Post
monthly
statistics
on
our
website
that
just
to
show
you,
if
there's
any
new
records
that
have
been
broken
things
like
that,
and
it
just
sort
of
shows
you
that
this
the
system
and
the
resources
are
evolving
over
time
and
the
new
mix
is
helpful.
We
need
that
diversity
to
really
make
this
work,
and
this
is
just
a
wrap-up
slide
to
show
you
that
all
of
these
things
matter
right.
The
engagement
with
our
neighbors,
the
collaboration
new
technologies,
electrification.
A
All
of
these
things
matter
in
this
in
this
transition
to
clean
energy
resources,
and
it's
going
to
be
all
hands
on
deck
to
make
sure
we're
we're
making
that
work.
A
So
with
that,
we
Ollie
and
I
are
happy
to
answer
any
questions.
Thank
you.
Thank
you.
Miss,
Crowley
and
and
I
I.
Think
up
most
of
this.
This
task
force
is
a
little
more
familiar
with
with
California
ISO
than
they
are
with
with
spp
or
or
wpp.
Just
because
of
the
years
of
talking,
collaborating
and
talking
back
and
forth.
I
know
I'm
very
familiar
with
ISO,
but
do
we
have
any
questions
from
the
committee
for
the
ISO
this
afternoon?
A
Oh
we'll
start
I'm
going
to
start
on
the
end
and
move
this
way.
Mr
barbash.
A
Thank
you,
Stacy
and
Holly
for
the
presentation
appreciate
that
I
just
have
a
question
on
the
on
the
governance
piece
because,
like
Senator,
our
chairman
Brooks,
located
the
we're
all
more
familiar
with
the
California
Market
than
spp,
but
to
tag
along
with
the
question
that
I
think
Miss
Wagner
was
asking
in
Carson
how
the
spp
market
would
trans
governance
would
transfer
into,
or
the
markets
plus
would
transfer
into
an
spp
RTO.
What
do
you
see?
A
I
guess,
unlike
spp,
that's
set
up
with
multiple
States
California,
being
primarily
in
one
state
and
being
a
a
product
of
California
state
legislation,
with
a
governance
board
appointed
by
the
by
the
governor
of
California.
What
do
you
see
as
the
process
and
if
you
could
even
put
a
a
timeline
up?
You
know
like
a
an
optimistic
timeline
and
a
pessimistic
timeline
for
how
that
governance
would
transition
to
a
multi-state
governance
structure
over
time.
We
know
what
the
California
legislative
process
sure
I
have
my
thoughts
that
have
been
really.
A
You
know
evolving
over
the
nine
years
I've
been
at
the
iso,
but
certainly
the
the
main
component
would
be
to
allow
enable
the
California
ISO,
which
would
likely
then
change
its
name,
to
have
a
board
that
is
self-selected
or
selected
in
an
independent
way
like
these
other
isos
and
like
the
rap
are
describing
where
it's
through
a
stakeholder
nominating
process
and
either
the
the
board
self-selects
or
some
there's
some
other
mechanism
there.
So
that
is
the
goal
right
so
that
no
one
state
has
you
know
the
the
the
influence
to
select
the
board.
A
So
that
would
be.
That
would
be
the
goal
and
in
doing
that,
you'd
have
to
basically
repeal
pieces
of
the
statute
to
allow
that
enable
us
to
to
do
that,
and
then
we
would
in
our
own
bylaws,
just
like
every
other
multi-state
ISO
in
our
own
bylaws
and
our
own
structure.
We
would
develop
the
governance
structure
that
stakeholders
could
support
in
terms
of
a
timeline
for
that.
We
certainly
see
the
day
ahead.
Market
Evolution
as
being
as
being
important
for
I,
would
say
Market
participants
to
to
continue
to
feel
more
comfortable
right.
A
We've
we've
all
recognized
that
that
real-time
Market
eim
has
built
confidence
in
in
working
in
markets
and
confidence
in
in
what
others
bring
to
the
table.
Edam
will
do
that
same
building
more
confidence
and
then
and
then
we
need
to
see
interest
in
full.
You
know
sort
of
full
Market
participation
through
an
RTO
and
then
I
would
imagine
there
would
be
a
transition
and
we'd
have
to
figure
out
exactly
what
that
looks
like
we
have.
A
We
had
proposed
some
transition
elements
in
the
previous
work
through
the
legislative
process
back
in
2015
2016
under
SB
350,
as
well
as
2017
2018,
under
a
bill
that
assemblyman
Holden
brought
forward
called
assembly
Bill
813.
A
So
there
was
some
what
happened
was
there
was
a
set
of
principles
established
to
say
if
these
principles
were
true,
then
we
would
start
to
repeal
the
statute
in
the
California
legislature
and
the
principles
talk
about
States,
maintaining
their
current
existing
Authority,
oversighting
and
resource
procurement,
and
that
kind
of
thing
that
there
would
be
a
voice
for
States
and
things
that
matter
to
States
like
planning,
Reserve
margins
and
cost
allocation.
A
And
if
those
principles
were
two
and
that
we
produced
a
governance
structure,
then
you
would
repeal
statute.
So
that
would
take
several
several
years.
We
believe
that
no
one,
no
utility
could
join
us
as
a
as
a
participating
transmission
owner
next
year
without
other
Market
design
changes.
So
it's
probably
you
know.
The
word
is
six
years
away.
Something
like
that.
Maybe
three.
A
If
we're
optimistic,
thank
you
and
a
compliments
on
the
on
the
summer
or
the
the
fall
Heat,
Wave
I
should
say,
and
how
in
the
world
did
you
get
the
the
amber
alerts
out
so
quickly?
Was
that
working
with
the
state
and
was
that
the
Kaiser
or
is
that
the
utilities
doing
that
was
100
the
governor's
office?
Okay
yep,
so
that
was
not
our
call
or
even
our
suggestion.
It
was
I.
Think
I
think
the
governor
governor's
office
was
very
involved
in
this.
A
In
you
know,
just
caring
about
keeping
the
lights
on
in
the
state
and
their
team,
you
know
they
have.
They
had
the
Opera
the
office
of
emergency
services
working.
You
know
on
call
and
I
think
that
was
one
of
the
tools
in
their
toolbox
that
they
decided
to
use.
We
recognize
that
that's
not
a
tool
that
that
folks
could
count
on
often
right.
That
was
a
special
circumstance,
even
the
flex
alerts.
You
know
you
10
days
of
asking
people
to
cut
their.
You
know.
A
Energy
usage
from
four
to
eight
is
asking
a
lot
when
it's
115
day
after
day
that
that
can't
be
the
long-term
solution,
and
that's
why
we
need
you
know
a
more
diverse
set
of
resources.
A
We
have
all
transmission
lines,
and
so
that's
really
the
spirit
of
some
of
the
questions
that
I've
been
asking
today
and
so
I
see
the
resource
and
transmission
development
plan
significant
transmission
projects.
It's
not
that
I
think
that
these
are
bad
ideas.
But
my
question
is
again:
what
are
the
engagement?
What
is
the
involvement
with
tribes,
our
tribes
just
treat
it
like
members
of
the
public
when
they
should
be
treated
to
Sovereign
Nations,
and
not
only
that,
but
if
we're
going
to
be
developing
good
policies
and
I
do
believe
that
this
is
good
policy.
A
A
However,
they've
been
consulted
with
or
collaborated
with,
and
as
a
reminder
to
this
task
force
under
chapter
233a
of
the
NRS
section
6-3,
a
state
agency
shall
make
a
reasonable
effort
to
collaborate
with
tribes
in
the
development
and
implementation
of
policies,
agreements
and
programs
of
the
state
agency
that
directly
affects
those
Indian
tribes
and
so
I
want
to
see
how
we're,
including
tribes
in
this
process,
I
can't
speak
for
them,
they're
each
their
own
respective
Sovereign
Nation
and
are
able
to
make
policy
decisions
on
their
own,
but
I
want
to
make
sure
that
this
is
something
that
is
going
to
also
be
consistent
with
their
values.
A
We
talk
about
stakeholder
scope
and
issues,
but
I
want
to
see
consideration
of
tribal
sovereignty,
tribal
self-determination,
making
sure
that
these
are
done
in
a
culturally
appropriate
way
and
in
a
way
that
will
benefit
tribal
communities
as
well,
and
so,
if
you
have
any
experience
with
how
tribes
have
been
included,
I
would
love
to
hear
that
sure.
Thank
you
at
a
very
important
question.
I.
A
There
is
an
example,
at
least
in
our
footprint
recently,
where
the
Morongo
band
of
mission
Indians
became
a
participating
transmission
owner
in
our
system,
and
they
did
that
to
the
benefit
of
their
of
their
of
their
tribe.
A
It
supports
it
was
supportive
of
the
renewable
resources
in
their
area
and
it's
we
call
it
the
west
of
Devers
transmission
project
that
brought
power
in
from
Riverside
and
the
Imperial
County
areas
into
into
the
grid,
and
that
was
a
really
great
partnership,
at
least
the
way
we
experienced
it
and
it
allowed
the
tribe
to
to
engage
in
the
process,
understand
the
benefits
that
would
accrue
to
them
and
well
as
well
as
helping
to
serve
clean
energy
resources
into
the
system.
So
that's
one
example:
people
that
we
have.
A
We
also
know
that
they
are
a
large
part
of
the
conversation
when
it
comes
to
citing
and
permitting
through
State
processes.
That
California
has
they
had
a
a
committee.
Drecp
I
think
it
was
desert
renewable
energy
coordination.
I
forget
the
acronym
I
can
provide
that
to
you,
but
it's
it
was
a
multi-year
look
at
where
the
best
places
are
to
develop
resources
and
I
know
the
tribes
had
a
lot
of
influence
and
input
into
where
to
build
and
where
not
to
build
right,
so
absolutely
an
important
component.
A
A
Mr
Newman,
my
question
is
on
your
subscribing
participating
transmission
owner.
Can
you
explain
how
that
program
works
and
how
the
rates
are
recovered
on
that
and
the
governance
behind
the
transmission
ownership
sure?
So
in
this
case,
the
transmission
developer
would
seek
out
contracts
for
the
the
procurement
of
the
resources
on
the
other
end,
in
this
case
it's
Wyoming
wind
and
they
would
seek
rate
recovery
through
the
subscription
of
of
the
line
and
the
resources.
On
the
other
end,
the
iso
would
only
at
the
point
where
there
was
serving
ISO
customers.
A
Would
they
include
that
in
the
transmission
access
charge,
which
is
our
way
of
of
recovering
the
rates
from
the
from
the
transmission
lines
that
we
put
in
it
is?
It
is
entirely
in
their
Court
to
make
that
happen.
So
it
is
up
to
them
to
get
the
subscriptions
and
they
meet
the
timelines,
and
then
they
would
use
the
contracts
that
they
signed
to
get
the
firm
rights
to
the
transmission
line
on
their
own,
and
that
would
I'm
not
describing
this
very
well.
A
They
would
essentially
charge
their
subscribers.
A
The
cost
of
of
that
follow
should
the
subscribers
only
come
from
California,
or
can
they
come
from
any
of
the
states
that
transmission
line
is
actually
Crossing
through
so
the
way
the
transmission,
the
Transwest
Express
project
is
being
contemplated,
is
that
they
will
have
it's
a
it's
a
DC
line
until
a
point
in
I
think
Utah,
and
at
that
point
it
becomes
ac
lines
and
at
that
point
other
utilities
could
take
a
subscription
onto
those
lines
in
both
directions,
so
other
utilities
could
certainly
subscribe
to
that
line
and
then
there
would
be
the
own,
their
own
cost
structure
associated
with
that.
A
Thank
you.
Did
we
lose
Carson
City,
or
is
it
just
the
camera
off.
A
Yeah
Senator
Brooks
we're
still
here.
Do
we
even
hear
us
yeah
I
can
hear
you
I
just
couldn't
see
you
so,
okay,
I
wasn't
sure.
If
we
lost
you
we're
still
here
we
can
hear
you
Anthony.
Are
there
any?
Are
there
any
questions
there
you
are.
Are
there
any
questions
from
any
of
the
members
in
Carson
City?
Any
further
questions
all
right?
A
Well,
that's
great
and
I
appreciate
you
coming
in
today
and
making
this
presentation
and
I
encourage
our
members
to
participate
in
the
process,
especially
the
ACR
188
process,
because
I
think
that
the
that
is
a
venue
where
we
will
want
to
make
our
concerns
and
or
ideas
heard
so
that
it
informs
the
2023
legislative
process
with
Chris
assemblyman,
Chris,
Holden
and
and
Chris
Holden
Chris,
Brooks
and
Chris
Hanson
are
collectively
referred
to
as
the
Chris's
and
so
I
I,
because
all
three
of
us
work
in
this
area
and
we're
friends
and
so
but
I
I.
A
It
will
and
I
think
that
that's
the
what
that
process
was
meant
for,
and
it's
for
a
body
like
ours
to
make
our
input
known
during
this
process.
So
the
first
call
was
Monday.
If
there's
any
way,
you
could
share
that
with
the
committee
the
best
way
to
get
onto
that,
because,
while
the
kaiso
website
is
very
informative
and
robust,
it
is
sometimes
a
little
difficult
to
navigate
because
it
is
so
comprehensive.
So
if
you
could
help
us
that'd
be
great
all
right
with
that.
A
A
We
will
move
on
to
our
next
agenda
item,
which
is
from
it
was
going
to
be
from
director
bobson,
but
he
had
to
go
do
something
else,
so
it's
going
to
be
I
believe
from
Laura
Wickham
up
in
Carson
City,
and
it
would
be
a
preview
and
discussion
of
the
draft
task
for
task
force
report,
a
reminder
to
those
on
the
committee
in
the
statute
that
created
the
task
force.
It
also
tasked
the
task
force
with
creating
a
report
to
the
legislature
and
to
the
governor
in
November.
A
Now
the
the
report
will
be
just
basically
some
of
the
findings
and
or
recommendations
if
any
of
the
the
first
two
meetings
of
the
task
force
and
my
my
anticipation
is
that
this
report
won't
be
as
robust
as
future
reports,
because
this
was
the
first
couple
of
meetings
was
really
about
us
gathering
information
and
getting
a
baseline
of
knowledge.
But
we
will
hear
about
the
process
moving
forward
from
Miss
Wickham
right
now.
A
So
apologies
director,
Bob
Zion,
had
a
heart
stop
at
one
and
he
had
a
scheduling
conflict.
So
I
will
do
my
best
to
provide
a
an
update
on
this
task
force
report.
The
governor's
office
of
energy
as
a
supporting
agency
to
this
task
force
will
be
working
on
the
legislatively
mandated
report
and
we'll
make
a
draft
available
to
all
task,
4
members
and
the
public
in
the
coming
weeks.
A
Our
intent
is
to
have
a
final
report
to
present
for
approval
during
our
next
scheduled
meeting,
which
will
be
on
November
17th
and
it
will
be
held
virtually
if
any
members
have
comments
or
recommendations.
You
are
welcome
to
individually
send
comments
to
staff
so
me
or
the
task
force,
email
and
please
refrain
from
copying
each
other
or
bcing
each
other
and
those
recommendations
will
be
incorporated
into
the
draft
report.
A
And
I'll
take
any
questions
perfect.
Thank
you.
Thank
you.
Do
we
have
any
questions
for
Miss,
Wickham
or
myself
on
that
process?
Miss
barbash,
thank
you
is
the
next
meeting
you
said
it
would
be
held
virtually.
Is
that
exclusively
virtually
or
will
there
be
in-person
locations
as
well?
It
will
be
exclusively
online.
A
A
Remember
what
Miss
Wickham
said:
please
don't
BCC
or
blind
copy
or
copy
other
members
when
making
any
sort
of
suggestions
and
or
questions
to
the
office
of
energy
or
myself
and
that's
kind
of
important,
and
if
you
have
any
questions
on
that
process,
either
myself
or
Miss
Wickham
or
director
Bob
scene
can
probably
answer
those
questions
and
I
look
forward
to
seeing
everyone
on
during
that
meeting,
and
so
that
is
it
for
that
agenda
item.
A
We
can
move
to
our
our
second
and
last
public
comment
period
and
please
remember
if
we
have
anyone
to
make
public
comment
to
keep
it
to
three
minutes
if
possible,
and
we
can
start
public
comment
up
in
Carson
City.
If
there's
anybody
that
wants
to
make
public
comment
in
Carson
City,
please
come
to
the
table.
A
A
Share
your
public
Line's
been
working
and
you
have
no
callers
at
this
time
all
right.
Thank
you.
So
much
so
with
that.
I
would
like
to
thank
all
of
LCB
and
their
staff,
who
always
make
sure
that
these
meetings
run
very
smoothly.
I'm
constantly
Amazed.
A
By
how
smoothly
these
meetings
run,
and
this
will
probably
be
my
last
meeting
with
LCB
as
a
legislator,
so
I
I
I,
will
probably
I
have
announced
my
my
intention
to
resign
from
the
Nevada
legislature
here
in
a
few
weeks,
and
so
this
will
be
the
last
meeting
where
I
will
be
in
lcb's
offices
as
a
legislator.
So
they've
always
done
a
wonderful
job
and
I'm
so
glad
to
be
able
to
have
a
meeting
such
a
good
meeting.
A
As
my
final
one
and
I
also
would
like
to
thank
all
the
members
of
this
task
force
for
participating
today
and
all
the
presenters
who
helped
us
out
and
the
office
of
energy.
Thank
you
for
for
Staffing
this
meeting
and
for
doing
all
the
hard
work
to
make
it
a
possibility,
and
with
that
I
will
adjourn.