EIA’s U.S. Electric System Operating Data Tool webinar

>>Bill Booth: Good afternoon. My name is Bill Booth, and I’m a Senior Electricity Advisor at the
U.S. Energy Information Administration. I will be presenting today. This webinar
covers EIA’s U.S. Electric System Operating Data Tool. The webinar gives an overview
of the features of EIA’s web tool and answers questions about the way the data
is collected and displayed through the online tool. Let’s start with a few key takeaways. Since mid-2015, EIA has been collecting
near real-time hourly system demand data from each of the U.S. electric systems in
the lower 48 states. This data is being processed and posted
within an hour and 20 minutes of the end of the operating hour. And the webpage and
the data collection serve several objectives, that we’ll talk about in a second.
And we have a number of ways that analysts can get access to the historical data
for doing their analyses. We’re calling this version of what you see on the
website a public beta, and the primary reason for that is that there are some
significant data issues that we’re still working through. But, you know the, the
website is up there for people to, to look at and use. And the URL is down at
the bottom of the page. Alright, so just to give you a quick idea
what we’re going to do, I’m going to talk a little about the data itself.
What is it that were collecting, and then talk a little about the project
objectives that I mentioned earlier. But we’re going to spend most of the time
looking at the webpage and talking about data access. How can you get the data? And
after that, as John said, we’re going to be open to, to answering questions.
Alright, so what, what are we collecting? So we
are, as I said every 60 minutes, we are collecting a actual hourly demand, a
system demand value from each of the 66 electric systems which are called
balancing authorities. I’ll explain that in a second. That operate the U.S.
electric grid. We take that data and turn it around, as I said, in an hour and 20
minutes after the operating hour. So, for example, so we’re passed 3:20. We should
be able to see data for 2 p.m. Eastern Time on the tool. So we’ll, we’ll see cross
your fingers— we’ll see [laughs] if uh, if I’m correct on
that. That doesn’t always happen. In addition to the actual system
operating demand data, we collect some other information not
on an hourly basis. So it’s not as near real-time as the demand data. And this
includes, well, so this, this collection comes in in the morning and typically
post this by 8:20 in the morning, Eastern Time. And included in this data is a
hourly load forecast for the current day. What this allows you to do is with that
load forecast you can then compare as each hour comes, and we receive the
actual demand, uh value, we you can compare that to what the forecasted demand value
Is. And then for the prior day, we get three values. We get net generation, we
get net actual interchange which is the flow of electricity either in or out of
the, the electric system. And then we get an updated set of values for actual
demand for the prior day. So you might wonder,
so why are we collecting this information so, so I think
hopefully it’s evidence why collecting hourly system demand is a
value that is basically what’s driving the electric system. Of course the
electric system, one thing that’s unusual about the electric power industry is
there’s essentially no storage, so the supply into the system is driven by
demand. That the system is designed to, to maintain a balance between supply demand
in real-time and so the three elements that we’re collecting here: the net
generation or supply, the actual interchange, which is the flow in and out,
and demand are the three elements that make up that balance. And that’s why
these entities that are reporting here are called balancing authorities, because
their primary function is to maintain that balance between supply and demand.
And so that, that’s the focus of this collection is essentially demand,
but in addition to demand, system demand, but in addition to that, also
collecting the other element of that balance that is a essential feature, or
function in the electric power industry. Alright so let’s move on to some of the,
the objectives of this project. What can this collection do for people?
So a primary saying is the, you know near-realtime collection of demand data
provides some, some situational awareness. What’s the status on the electric system?
You know, how quickly as demand growing, you know, on a hot day? Those types of things.
In addition to that, we’re expecting this to
be of use in providing some ability to track a recovery of electric systems
that have experienced the disruption. So that may, may be of, uh, particular value.
For me personally, a, a major objective of this
is education. What this, what this tool can provide is better understanding of
structure of the electric power industry And, and some understanding of the
dynamic nature of, of how the industry works. And then a third, a third, uh, objective is
the particularly the, the system demand information and the dynamic nature of it
as I mentioned before, is a essential, uh, piece
of information. If you want to try to evaluate essentially, al—almost anything
that you want to do with the electric power industry, but particularly, you know
some technology development, say renewables, wind and solar, the, those are
particular technologies where the time of day is very important in terms of
what you can expect to get out of those technologies. And to understand their
value, you need to match that up with what the shape of the demand is, changing
nature of demand. And also, a number of programs or policies in the industry:
Smart Grid, energy efficiency, demand response. The value of those depend on
when they’re implemented dur—you know during the, during
the day or during the week, those types of things. And then another way of saying
basically the same thing, is that developing and implementing a number of
technologies and programs can be helped by understanding how to take advantage
of the, the very nature of electric system operations. So those are, those are just
three of the uses that we foresee for this Information. There is others out there.
Alright, so let’s move to the next page. So we’re almost to the point of moving
into the demonstration. The approach I want to take on the demonstration is
instead of just sort of clicking through various pages. I want to use the tool to
answer a simple question somebody might have about, uh, what’s going
on the electric industry. The question I picked out here is to ask is—To what
extent does the New England system rely on electricity from outside their system?
And then in addition to that, answering that question we’re also going to be
talking about ways in which analysts can get access to the historical data.
Alright, so let me move on to the tool. Are there any questions,
John, that have come in that we should address at this point?>>John Krohn: Well
we could address a question that’s come in.>>Bill
Booth: Okay.>>John Krohn: One question is—What weather
model do you use for your demand forecasts?
>>Bill Booth: Well that’s an, that’s an excellent,[laughs] excellent
question. So we do not forecast demand. So the basis of this tool, if I didn’t
make that clear, is a, an information collection to the 66 entities tha—who
have the responsibility for maintaining the supply demand balance in the
industry. And one of the ways that they, they maintain that is that their job is
to schedule generation facilities to be available to meet demand. And so a major
way that they do that is they do demand forecasts and of course weather
forecasts are an essential part of that. So we, EIA
the data related to demand forecasts from these balancing authorities is not
something that’s coming from EIA. These are demand forcasts that are being
reported by the balancing authorities themselves, and they actually produce
quite a few demand forecasts to do their job. What we’ve asked of them is for them to
provide us their day-ahead demand forecasts, and that one
of the, two, two of the reasons for asking for the demand, their day-ahead demand forecasts
is that’s typically the demand forecasts that they use for unit
commitment. That is the decisions, the decisions to which units they’re going
to have available the next day. And then another reason that we wouldn’t have, you
know, demand forecasts that, that these systems will do demand forecasts
throughout the operating day. But if we were to do that we wouldn’t get it in
time for us to be able to put it into our tool. So by asking them to use their,
basically we’re asking them to report, uh, demand forecasts that they have
available when they’re reporting their information in, in the morning of
the operating day. Alright, so let’s move to the tool.
Alright, so here is the, the tool. So when you load up the tool for the first time,
this will be the default page that you’ll come to. There are actually
several primary pages associated with the tool. They’re three of them up here, up
in the upper left-hand corner. And there are
three tabs to get to them. So this is the
overview page and there is a map page and then there’s a detailed data page. So
this overview page is intended to provide sort of high-level a high-level
view to, to use some aggregate data. And we aggregate the data so that the basic
data that we receive from the balancing authorities is hourly data, everything is
hourly. So what we’re doing here is looking at
daily, we can look at daily and we can look at weekly. We get a full calendar
year of, of data we’ll probably add a yearly tab to this to provide some, some
look in from that perspective. But so we’re, we’re aggregating this by time, and
we’re also aggregating it by geography. So, so when we—we’re looking at U.S. level
data. So, this is data is for the whole United States or the, the 48 lower states
and then, we also can look at this data on a regional basis. So, and by default we
come in at the U.S. level, at the daily aggregate level, and it shows us the
current day. So over on the, the right-hand side we have the dates here
which you can change. And we’ll do some of that in a second.
Alright, so, so we’re looking daily data here. And the chart over on the left hide—hand
side of this the screen here is showing
demand. Hourly demand for today. And, and you’ll see a whole bunch of lines here.
And I apologize it’s a little difficult to see, so you’ll have to take my word for
it. We’ll see it a little better in a second, but, in amongst there, there’s
there’s a uh, a blue line which is we call it the chosen day. When the chosen
day is the default day at this point, which is today sort of hiding in between
the other lines there, and what we’re, what we’re doing is showing the information
we have for today. Trying to show it in context. So the context is we want to
compare it to what happened yesterday, what happened the same
day of the week last week, so Wednesday last week, and the a year ago the
same day of the week a year ago. And so, so as I said, the blue is sort
of hidden in here current day. If you can see it, you’ll
notice that there’s, there’s a dotted line up towards the, up toward the top.
That’s because, uh, that represents some hours that we have not gotten to yet. And
so what we’ve done is that we will show a solid line for the hours that we have
the data for, and we have it a, a , a dotted line for forecast data, so we’re mixing
actual and forecast for today. And you can just see here last week,
green is a little bit higher than today. And that’s just indicative of the fact that
last week was a little hotter in, sort of in toto,
we’re seeing it’s a little hotter sort of all across the country. And, but
yesterday and a year ago is just a little bit below what today
looks like. So since, so I want to talk a little about the region’s, so this
is the map over here is a selector for the regions and you can mouse-over and
see what the various regions available are and, what I want to do is select New
England since the, the question we want to add, answer has to do with New England.
So we can just take a quick look at, at New England here. So, so there’s a little
more disaggregated and, and so we have a little more separation between the lines.
The thing I find interesting about this one is that the relationship between the
lines seems to be different in the morning than it is later in the day, so
that’s kind of an interesting result there. Not quite sure what that’s,
what that’s all about but it’s an interesting question.
Alright the, just wanted to mention on this particular overview page I’ve been
talking about this demand tab here if you look in the upper left here, under
the ticker on the top, is actually sort of three sub-pages for the overview page.
We’ve been looking at demand. There’s a trade page, this page shows you
information about imports and exports of electricity to Canada and Mexico. And
then there’s a, a write-up about the grid which gives some, some basic descriptive
information about you know what, what the U.S.
grid is, and how, how it operates. So this is
hopefully some useful background information to, for you to look at to
understand better the information that we’re presenting here.
Alright, so what I’m going to do is reload the page just to make sure that
we’re looking at the right particular time, and then move to the second page of
the three that make up the tool. And so this is the da—the, the map.
Alright, so what’s your first thing to know about this map is that this map is,
this map is, shows information about one particular hour. And you
there’s some controls up in the upper right-hand corner you can use those to
pick the particular hour that you, that you want.
By default, by default it, it goes to the most recent hour for which we have data,
and what I’m noticing here is that down here is a message to say when it
was last updated. And looks like we have a little bit of a network problem in
terms of getting our real-time data so, so we’re only showing noon at the moment.
Let me just see if we can move up to one o’clock, so this is one o’clock it looks
like we’ve gotten some of the data but not all of the data. And if I try to go
to two o’clock which is what we should be able to see right now it’s not gonna
even let me do it. So, so we don’t have to do it for that, so I apologize that we’re
not able to show you the most recent data
but this is the nature of the beast at the moment. So let’s move back to, to
twelve o’clock, talk about this. Alright so, so one of the things that
that uh, by default I wanted to mention was by default you come in at Eastern Time,
but you can use these controls here. Just click on these little pies for the name
there and you can see the information from a different time zone. Also point
out this value the upper left. This is the total demand in the lower 48 states
for electricity for the hour ending noon today.
Alright, so what are we looking at here [someone clears throat]
with this, with this map? So this map is a schematic diagram of the structure of
the electric, electric system. How it operates. The underlying the map you’ll
see three colors there’s sort of a, not sure what that
is but, purple, purplish, light purple color in the West. We’ve got green in the East and
tan or gray in most of Texas. So those different colors are indicating what are
called Interconnections that’s Interconnections with a capital I. They
reflect the fact that the U.S. grid actually has three parts to it. It’s not
a single, not a single grid. What happens within Interconnections is
electricity is free-flowing. There are no, there are no
barriers there, or few barriers there. And the, but there is an ability to end,
but uh, the movement of power between Interconnections, the three areas I talked
about is limited, and they’re indicated by these little ties, bowties, that
indicate facilities that allow power to move back and forth. But, but they’re not
that’s not being done freely. You actually have to set that transfer to a specific
level. Alright the circles, what are the circles?
The circles in are the 66 balancing authorities in the U.S. And the, the size
of the circles are sort of roughly reflect the this the uh, the peak load
for those systems. So you can see PJM and MISO, and or gotten SBP are some of
the largest systems in the country. Some of the, some of the smaller
circles on the map uh, if we were if we actually do it based
on their, their peak demand, you wouldn’t probably see them or they be a dot. So
it’s as I said just, just roughly. The lines between the circles reflect
one or more physical transmission connections between the systems. So two
circles don’t have a line between them that means they’re not directly
connected with each other. Alright, so what else do I want to say?
Alright, so one thing you can see here is we’ve got some colors in the circles.
One is black, so black is not good. Black indicates that we’re missing one
or more of the data elements here’s BPA has not been sending their hourly data
in today. And I think that’s the case for most of the other black circles. And we,
that this happens periodically and we follow up with them quickly we’ve had
communications with one of them today about about this issue. And they usually get
back online pretty quickly. The other colors the main colors you see here are
the blues and the oranges. There are various shades of those and those indicated
relationship between the, the actual and forecast demand. I said that that
relationship might be something that people are interested in, in seeing. And so
a blue circle means that actual demand is
below what the forecast demand is. The oranges indicate the actual demand is
above forecasts. And the intensity indicates, you know, the percentage above forecast or
below forecast. And so that, you know, can indicate particularly if it’s, you know,
dark orange, a mismatch between what, what the operator is expected through their
forecasts and what they’re actually seeing. That may mean that their system
is, is under stress.>>Tom Doggett: And Bill, just
To clarify, the over demand or under demand, that’s not, is that the running total for
the day or just for that particular hour?>>Bill Booth: This, this thing is just
for one particular hour. Yes. Good question. Alright, so why don’t
we move to talking about the answering a question that I raised him beginning of
the demonstration. So if I want to look at, if I want to look at uh, New England’s
reliance on outside sources I want to look at New England or course. Now questions
like this are ones which people typically wanna know for, for a
particular hour of the year, which is the hour of
the maximum demand and so we’ll start with that. I happen to know
what the, what the having looked at historical data that’s
available from here, what that day is. It wasn’t too, too, um, long ago. So for New
England the max demand happened on Friday the 12th.
And week, and it happened at four o’clock,
or 16:00 hours. So let’s see if I can choose 16:00 hours.
>>Tom Doggett: And it’s quiet, but it’s loading. We have dead air.
>>Bill Booth: Yes! [laughter] Yes. There we go. Here we go. Alright, so if you
want to look at the data for New England, one way you can do it is to roll over
the circle for New England. And what you get is a pop-up box that gives you the
data values, the four data values for New England for that hour. We also provide a,
a percentage for differential between, between forecast and actual demand in
the middle there. So to answer the question, we want to
start with the interchange. And that’s the number at the bottom. And it says
negative 3,399. The negative indicates that the power is flowing into the New
England system. If it was positive, it will be flowing out of the system. So, so
that’s, that’s how much is coming in from the outside. And we also want to look at
what the, the actual demand is. And that’s at the top. So that’s uh, 25,463. And
if you provide the interchange by the demand, you’ll get a percentage that’s of
this, of the demand that’s being satisfied by
external sources. Which if you do the math is about 13%. So, so that’s the answer
for that particular hour. The question that we’d raised. So you may want, so that’s
one way to do it. But you may want to, to look at the information little more
detailed, and perhaps more than just an hour. So you can do that easily by
clicking instead of, um mousing over you can click on the New England circle.
Balancing authority circle. And here we come up with the, this actually brings
up the, the third page on the tool. So we, we’ve moved on to
that. And what we’re showing here is in the top chart here, is hourly actual and
forecast demand for two days based upon the day that we were looking at before,
which is August 12th. And, so you know you can pick information off of here, and
we’ll show some other things. We show here a differential between forecast
and actual demand. And then this, this chart here in the middle with all the
blue lines dropping down is the interchange or the or the inflow and
outflow of electricity from the New England system. So you can see it’s
fairly consistent importing for these particular days and then, you know, we can
pick off the particular hour that there’s our,
there’s our four o’clock hour there. [female voice in the background]
The uh 3,399 right there. So, so one of the things that folks who might want to be
interested to see is, alright so they’re importing a lot of energy.
Well where are they getting it from? And so, so we can look at that and let me just jump
quickly back to the, the status map. And let’s see if I can do this right we
can actually zoom in. Uh, let’s see if I can grab this. And, so just
to look more closely at New England. And we can see who New England is
interconnected with, so it’s interconnected with three balancing
authorities the New York ISO, Hydro-Quebec which is up here, and New Brunswick. So those
are the three entities that we can, that we would expect to want to see how much
power is coming in from each those. So we can click back on this. Go to
the detailed data page, and scroll down to the bottom. And what we see in the
middle of page here, some colored lines. These represent the, these represents the
imports of electricity from those three systems. Just to point, point this out, up
towards the line, this line here, up towards the top is the zero line. So most
of, most of what we’re seeing here is negative numbers which is consistent
with what we were seeing above. The yellow line at the bottom is Hydro-Quebec.
And so this is, you know around 2,000 megawatts, pretty consistent over
those two days. It’s not surprising because Hydro-Quebec and New England
have a long-term contract to bring in significant amounts of power from their
hydro system. And then the green line is New Brunswick. Somewhat less imports, but
fairly steady. Not as steady is Hydro-Quebec. And then the brown line is
New York which is also during these days, this importing for the most part except
for the early morning hours on the first day. So, so that’s a way of looking at where,
where power is coming from. The other thing that particularly analysts may be
interested in is, well how do I get the data. So, you know this is all nice and
and good, and we can look at things and we can uh, analyze some things, but hey I
just want to get the data and, and run with it and do some things. So every chart here,
up in the upper right-hand corner has a
download button to it. We can open that up. And there you know two, two formats for
getting the, the image of, of the chart. There’s a data download if you want to
get the data that, that is being presented on the chart.
You can download that data, and then there’s a way of copying the chart
itself, that you can then paste into a, uh, a webpage. And this will allow you to, to
present this chart on your own webpage and the data will be updated
automatically. Alright, so another way to get data is to, [microphone
pops] is to go up here in the upper left-hand
corner under the, under the scroll bar. And instead of looking at the, the graph
we can look at the data table, so this brings up the four of data elements for,
for New England, for this period, and scroll over to our 4p.m. hour. And here are
the top is the demand va—value that we were using for calculation and the
bottom of the interchange value, but now we’ve added forecast demand and the net
generation value there. So for this data table it also has a
a download function in the upper right-hand corner.
This looks a little different from the one showed you before. There’s a way of
getting to the EIA’s Open Data page related to the API data series that, that
make this data available and it’ll take you to some information about how to use
the, the Excel add-in. There’s also a way of doing the bulk download of API data.
And that will take you there. If you want to download some database files instead,
you can use this, this drop-down menu to select a file, and
these, these files are sort of taking six months chunks of data from the database, uh
that you can download. So you select that, and
hit the download button. Alright, so another, another way to get
the data series is, I’m almost finished, thank you. Another way is, one other way to
get the data series is to use the API key on this page, and so we’ll just click
on that. And what it brings up is here’s the Open Data page. Here is the, so this
is our API query browser, which can use to find all the data series that are
available from, from EIA. The top here is the
API call, which is important for really being able to grab the data. Gives you a
chart of the data series. You can see this data series starts on July 1st,
2015 and goes to today. And then below that is, is a table with
the data in it. Alright, so there was one, one other thing
I wanted to mention on the, on the map before we moved to, before we move to
Questions. So start with the overview. I mention—mentioned selecting regions.
And, and so here are the regions that we have available. I’m guessing for most of
you these regions are unfamiliar to you. You’re probably used to NERC regions.
So, you know, what the heck’s this all about? Uh, why did
we do this? So if you go to the map, these regions we believe
better represent the, the, how the industry, how the
operations in the industry are organized. And so each of these regions is our
roll-ups of data from the balancing authority level. And so, so they follow
the, the contours of the footprints of the, the balancing authorities. And that’s
probably a major difference that you, you’ll see. Now I, you know, know that there are
a lot of folks from, from states, state
folks on the call. I know that you like to, to get your data in you know
state-by-state basis. You know at a state-level, unfortunately the nature of
this information does not allow for us to present it on a state-by-state basis.
The only the only states that basically that is represented here is New York
State, and that’s because [someone clears their throat] their
electric system, their footprint basically follows the, the contours of
the state. Now, the value of looking at this the for state people, is to better
understand how the electric systems that are in your state that supply, supply
electricity in your state, fit into the, the, the whole picture of how the U.S.
grid is set up. You know and you’ve gotta come from a bunch of different
configurations, so we’ve got New England. Course there’s one system that serves
six states, but you can go down and look at, at Florida. And there are 11 systems
that supply, you know, power in that state. So, so there’s a lot of, lots of
differences in terms of how, how these electric systems matchup or
don’t match up with, with the states. So, alright,
so why don’t we stop there and move on to questions.
>>John Krohn: Well thank you for that presentation Bill. We have quite a few questions and I
want to thank everyone for submitting them during Bill’s presentation. Let’s get
started with a question on the example that you are navigating Bill, as it
relates to ISO New England.>>Bill Booth: Yeah.
>>John Krohn: The question is—So if I’m getting it right,
at 16:00, which I believe is the hour that you were looking at,>>Bill Booth: Yep.
>>John Krohn: ISO New England was exporting and importing at
the same time.>>Bill Booth: No. So, so the way, the
nature, the nature of, the nature of interchange, how it’s measured, is that so,
so power may be flowing in and out of, of the system. And if you’ve got, if you’ve
got multiple systems connected to it, yes, in a particular hour, power maybe
flowing in from one and flowing out to another [inaudible murmur in the background]
that that can happen. In this particular case, for that particular
hour, Power was flowing in from all three of
the neighboring systems into, into New England. So, so I’m not sure [laughs] why
you’re thinking that it’s like flowing in and out.
I mean, now it is, so this is just representing at the system level
what’s going on. Now these lines here between New England and these other
systems actually represent multiple lines and it’s perfectly possible that
during that hour, power would be flowing you know one way on one line, in one
line, and out on another line. That type of thing will happen. And even on a
single line during that hour, it may be, you know flowing in at, at a certain
point and later in the hour flowing out. So the number that we are collecting,
which is net interchange, the net means that we’re just looking at
over the hour, what was the average, and so that average
can only be in one direction or the other.>>John Krohn: Switching gears,
the next question is—Can we find available generation capacity
within authorities?>>Bill Booth: So not, not directly in this tool.
However, EIA does collect information on it’s 860 form and which, which lists the
plants, and units within plants. Data about units within plant in the U.S. And
on that form, we list what balancing authority they are associated with. And
so using that data, you can answer that question.>>John Krohn: Similar question to the
one we just answered— Is there a way to isolate data for a
single company within an operating system?>>Bill Booth: So, no. So the one, one thing
that’s very important to, to understand is that this data is only at the system
level. And when I mean system, I mean the balancing authority level. It does not
give you any grant, more granularity in terms of what’s making up that system,
whether it’s generators, or whether it’s, it’s utilities within that, within that
balancing authority.>>John Krohn: Are there any
plans to show a breakout of where the energy source comes from in the tool? For
example, coal, natural gas, hydro or renewables?>>Bill Booth: So, we’re currently
in the comment period for proposed revisions.
A new clearance cycle for the, the 930. And one of, one of the
proposals that we’re making is to ask, or require, balancing authorities to report
to us their net generation broken down by a set of, of standard fuel types.
So the answer is yes.>>John Krohn: Are there any plans to include wholesale
energy prices in the tool?>>Bill Booth: So, no. So we, we
are, we, we have been, you know, working on separately from this, we have been
working on developing access to uh RTO energy prices, and, you know this is a
work in, work in progress at the moment. And, not associated so, so this tool has
no prices in it, and you know I don’t know what once, once we were able to
develop our, our RTO portal as we’re, we’re talking about it at the moment, you
know, we’ll have to think about what the relationships we’d have, what one thing, you
know, we can say is that all seven RTOS are represented in this tool at the
moment. Because they all happen to be a balancing authority. In addition to being
an energy market, and many other things.>>John Krohn:
One question that it relates to generation within a particular state—Will the model
or data be detailed enough to see the effects of renewable generation in
California? For example, what has been called the ducks curve?>>Bill Booth: So,
currently the information we have is not adequate for
us to use this information to create the a, a version of the duck curve. Uh,
once, and the reason for that is that the duck curve depends upon information
specific to the output of renewable resources. And so we don’t have that yet.
But as I mentioned earlier, for an earlier question, we do plan to add that
capability and once we have that we would be able to, or anybody would be
able to use the information to create duck curves.>>John Krohn: Are there plans
to create a toggle to view the load data from
a NERC region and geographical region perspective?>>Bill
Booth: No. [laughs] So, we don’t have that information,
you know, for those regions. So I’m, I’m assuming you’re, you’re, uh when you’re
saying geographic regions you’re saying something different from the regions
that we are presenting here today. And so we’re, we’re just not collecting the data
that way.>>John Krohn: Why is the daily demand curve
megawatthours instead of megawatts?>>Bill Booth:
[Laughs]So, one can get into a philosophical discussion about whether it’s megawatts
or megawatthours. The reality is that for an hour, the two,
the two units are identical to each other. So, yes I would,
we’ve had suggestions that we should change this or that or the other thing
that, but I think most people understand what we’re talking about.>>John Krohn: When
you say data for noon in Eastern Standard Time,
is that summation of data for noon in Eastern Standard Time, 11:00a.m. in Central
Standard Time, 10:00a.m. in Mountain Time? And
so on, and so forth?>>Bill Booth: That, for the,
for the annual, for the U.S. aggregate you’re absolutely right. That is we are, we are,
when we’re aggregating, we’re aggregating for the same time period in those
different time zones they happen to be, [microphone pops] you know
named a different hour. [Laughs]>>John Krohn: Is the
data for a prior year, prior week, and prior day,
real-time data, day-ahead data, or historical data?>>Bill Booth: So I think,
so, other than the demand forecast,
everything that we’re talking about here is historical data. So, so it’s not day-ahead.
I mean so the demand forecasts are a day-ahead forecast but, but everything
else is historical.>>John Krohn: How are transmission
losses accounted for in the reported data? Bill Booth: So, so that’s really, so we, that
the the best answer I can give you is that, we
don’t know. That is, that is based upon how each of the balancing authorities
choose to represent their, their, their system data. I believe that in most cases
system losses are, are included in demand.>>John Krohn: What was net generation netted
by? Is that indicative of station use? Also, is
pumped storage loading treated as demand or as a reduction to generation?>>Bill Booth:
So, so again both of those have to do with how
the reporting entity handles those. So I can’t, I can’t tell you definitively what
the, what, what the answer is. Net generation is net of station use, yes.
>>John Krohn: I need one moment here, please bear with me. Is there a way to get data for
any residential home in any area?>>Bill Booth:
So, okay [laughs] so this is a, a great question.
So one of the things I’m trying to convey to folks is that
this is looking at the U.S. electric system from a very high level. Very
high level perspective that is at the system level. So, there is no information
here about household level anything. This is, this is you know, you know the
total, total electric system, you know, the, the generators in the particular area, the,
the load serving entities in the particular area, the end users in that
particular area, and the transmission fac—and distribution facilities in that area. All
the, all that wrapped up into you know just a few numbers, uh each hour.>>Tom Doggett:
And just to follow-up on that Bill—>>Bill Booth:
Mmhmm.>>Tom Doggett: so, the tool is not going to show people, something
happening in a residential neighborhood? An, an outage, something small or a squirrel?
>>Bill Booth: Right.>>Tom Doggett: Something that—>>Bill Booth:
Right.>>Tom Doggett: A wire. But, is it able to
see something in a bigger area if there’s an outage for,
I don’t know, any major event? And has there
been an example of that you see—>>Bill Booth: Right.>>Tom
Doggett: —so far.>>Bill Booth: So of course, that depends on
a couple of things that, so how big the outage is, but
it’s really how big the outage is relative to how big
the size of the, the region is. So we’ve had a lot of customer outages in
Louisiana recently because of flooding. Unfortunately Louisiana, so if we click
this chart, or we just mouse over this chart we can see the region that
Louisiana is part of, and it’s the, the largest geographic region in the country.
[Laughs] So, so even though the number of customers that lost power were, was very
large, it’s still very small compared to all the customers in this particular
region, so my guess is that we wouldn’t be able to see the effect there.
However we, we did have a, an incidence or earlier this summer or spring in Tacoma.
So, so Tacoma is very different from this system we’re talking about that
that Louisiana is in which is Miso. So Tacoma is up in the Pacific Northwest, and
let me find it here. There’s Tacoma and so they’re, you know, a city. So it’s uh,
fairly small relative to some of these other
balancing authorities out here. And they had an incident where they lost power
and their central business district around noontime. And that was significant
enough that we were able to look at the demand data that they were reporting to
us and see a, you know, noticeable dip in demand for that hour so, so yes. Depending
on the circumstances, you may or may not be
able to see the incidence of, of, of power outages.>>John Krohn: I think we have time
for just two more questions.
If the demand data is day ahead, why are you waiting until 20 minutes after
the hour?>>Bill Booth: So, so let’s, let’s be clear
about what we’re collecting about demand. We’re collecting two things about the
demand. The first thing is we are collecting a day ahead demand forecast.
And what that means is that the electric system is doing a forecast, so you know, the
electric system did a forecast yesterday afternoon of what demand would be today.
So that’s a day ahead forecast. And they report that to us in the morning of today.
Separate from that, we are receiving every hour the actual demand
that took place. And so that is not a day ahead
value, that is a value for the most recent hour. So, so that’s the distinction
there.>>John Krohn: And our final question of the
webinar—Are there plans to include an hourly phasor angle snapshot per balancing
authority for a more clear stability visualization of the grid?>>Bill Booth: So
the, the quick answer to that is no. [Laughs]
And I’d have to actually think about that a, a little to be able to, to figure out if that would relate to what we’re
doing here at all. And before we go, I wanted to, to mention
one other thing here at the bottom of, for those who are interested in, in using
the data. And I did mention that this is still a Beta. And so we have significant
data quality issues that we, we’re working to resolve. On both the map page and the
detailed data page, down at the bottom on the left-hand side is a link to a PDF
document uh, called data users guide and known issues. And so this is, this is a, a document
that will help you understand what, what the data is. How to get access to the
data. And talk about some of the you know there, there’s some peculiarities about
these balancing authorities that you probably should be aware of, that we list
here. We have a discussion here about the nature of some of the data quality
issues that we’re, we’re dealing with in general. And then, we have a listing down
here of specific issues for the balancing authorities of what’s these, so
if you’re planning to use this data to do something, you probably want to look
at this document before you, before you do that.>>John Krohn: And along those lines, if someone goes to use the tool few days
from now and you might forget some of the intricate functionalities that
Bill mentioned, you can visit EIA’s YouTube page, where we have a series
of tutorial videos that helps you navigate the different
functionalities of the Electric System Operating Data Tool.>>Bill Booth: Ok.>>John
Krohn: So with that I wanted to thank everyone for
joining us today. We appreciate the time that you
took out of your busy schedules to take part in this event. Please feel free to
try out the tool on your own using the knowledge that you gained today. If you
have any questions or feedback please feel free to submit those questions via
EIA’s Beta page, or by emailing Bill at: William dot Booth at EIA dot gov, which is
on the screen in front of you .>>Bill Booth: Right.
So it’s part of the presentation that was sent to you.>>John Krohn: Thanks everyone. We hope you enjoy the rest of your day!

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