Public Works Committee - Regular Meeting

All right. Good morning, everyone. Welcome to Stomach County Council Public Infrastructure and Conservation Committee meeting for Tuesday, 12/02/2025 at 10AM. We are meeting here in the Jackson Boardroom and remotely. And before we do roll call, I do want to read our public comment script. We will be taking public comment beginning with in person and then remotely. In Zoom, click on the hand icon to raise your hand. If you're calling by phone, press 9 to raise your hand. When called upon, press 6 to unmute. Each speaker will have three minutes to speak, and please start your comment with your name and city of residence. And with that, we'll go ahead and do roll call.

Committee Chair Lo?

Present.

Vice Chair Dunn? Here. Committee Member Nearing? Committee Member Mead? Here. Committee Member Peterson?

Here.

Chair, there are four members present.

Great. Next on the agenda is public comment. Anybody in person wishing to do public comment today? All right. Do we have any hands raised online for public comment?

No hands are raised.

Okay. We'll go ahead and close public comment and move into our items today. First on the agenda is our discussion item, and we have the PUD with us today. And, I'll just turn it over to you guys. Go ahead.

And please introduce yourselves for the record.

Good morning. I'm Chris Scutter. I'm a power supply analyst with the PUD and working on long term resource planning.

Good morning. My name is Garrison Moore. I'm the senior manager of power supply, does which the long term planning, the regulatory compliance, the resource acquisition for Snohomish PUD's electricity supply.

Good morning. Brenda White with the PUD as well, and I manage our government relations. Relations. Brendan

Sorry. I am working on getting the technology set up here. Good morning. Thank you so much for having us. I'm really excited to come talk to you about our integrated resource plan.

We've already kinda gone through the introductions. One thing I will say is, if we can maybe hold questions to the end in case there are detailed questions, any clarification we can take during the presentation, but other kind of deeper questions maybe we hold to the end. I think the the big takeaway we wanna we wanna bring to you today, our takeaway message for you is that we want you to know that the PUD is proactively planning for our future. And, we're looking to, for for a clean and reliable and affordable, electric supply for Summers County, going into the future. I would hazard a guess.

Most of you don't know what an integrated resource plan is. So, we're gonna start with going over what an IRP or an integrated resource plan is, and then we'll talk a little bit about the results of our 2025 IRP, which we just released. So an IRP is the, long term plan that we do every four years. We look at the, current supply of electricity, that we have in our portfolio. We look at what our future demand is gonna be for that electricity.

Electricity. And then we take a look at what, resources we could add if there's a shortfall in the future for costs, risks, benefits. And then we find the lowest cost optimal mix of resources to, reasonably serve our customers, a reliable and affordable, clean energy supply. The end result of all this work is a action plan for the PUD staff to execute to go accomplish that resource plan, in the future. We are required by law.

Couple clean energy laws, require PUDs of our size to do resource plans. One is the Clean Energy Transformation Act. That's clean energy planning law. The other one is the Energy Independence Act. That one has a couple parts that are relevant to the to the IRP.

One is that we have to get certain kinds of resources into our portfolio, and then we also have to publish, two year conservation targets for, for our utility. And like I mentioned, we do these every four years, and then we update every two years thereafter. So we're in the middle of our large, IRP right now. And then in 2027, we'll update this one with new information. So at the highest level, an IRP really asks, how do we serve our customer owners, and what possible futures could the PD face?

Our study plan goes out through 2045. So what could we see between now and 2045 that, that the PD could face? Does our current existing energy supply meet those future needs? And if not, what resources could we add? What resources should we add? When would we need those resources? And at what scale would we need those resources? And then finally, how do we get from where we're to where we are today out to 2045? We have to create a road map that gets us from here to there all the way out for those twenty years. So that's kinda at the highest level in an IRP is.

We break our IRP into five steps, five phases. Phase one is our visioning and scoping process. That's where we determine the scope of our plan, what this plan is gonna study, what kind of futures we're taking a look at. I do have to shout out, the county, county staff was involved in phase one, and they were extremely helpful. So a big thank you to them.

The end result of phase one is we create scenarios and sensitivities that we plan to study through our IRP process. Phase two is looking at our load and resource balance. So we take a look at what our current load is, what our future load will be, looking at load growth from population, looking at, electrification of buildings, looking electric vehicle growth. All of that creates a composite load growth profile for us. We also look at what our current energy supply is and what that energy supply will look like into the future.

We then go into phase three, which is examining what options we potentially have in the future. Those are both demand side, so customer based resources, and supply side or generation based resources. We look at them for attributes, costs, and we kinda survey what technologies we think will be available in the future. In phase four, we take our in house optimization engine. We take all of those inputs.

So our load growth, our projected needs, our projected shortfalls in the future, and what resources are available to meet those future needs. We take all that, and we run it through an optimization engine that searches for the best, low cost solution to the various, scenarios and and portfolios that we expect to see. And then we develop a resource plan for each scenario. In phase five, we develop a a strategy around those, learnings from those scenarios and those, resource plans, and we develop a flexible resource strategy that allows us to develop our plans in the future, and then we create an action plan to execute on that resource strategy. So phase five kinda is that final result where we go from where we are today to in the future.

For context, this process takes between twenty four and eighteen months or so. It's been about two years that we've been working on our 2025 IRP, and we're gonna finish this one up, and adopt by the end of the year. Probably helps to start with where we're at today. This is our, what we think our 2026 power portfolio is going to look like. On the left, you can see the PUD's power supply.

We are predominantly a hydro based utility. Most of our power comes from the Federal Bonneville Power Administration or BPA, and most of Bonneville's power comes from the big federal Columbia hydro projects on the on the Columbia River. We also have a few of our own smaller resources that we own a contract for. The biggest of them being our, Jackson hydroelectric project up in up at Spada Lake, North of Monroe. That makes up our current power supply.

These are the scenarios and sensitivities that we decided to look at in this 2025 IRP. The base case, this is our sort of expected scenario. This is what we think the world is more than likely the middle ground of what we think the world could look like for twenty twenty years. High growth and low growth are, both variations on the base case. So we take, higher load growth, lower load growth, higher, you know, economic growth in the county, lower economic growth in the county.

We spread out those out over the twenty years. So that creates our high and low case. And that kinda sets the bounds of what we think the the study could look at. We had two other scenarios that sort of took a look at other possibilities. Our high-tech scenario, we looked at what would happen if novel technologies developed sooner and more technological adoption happened in the county.

And then the final one is a limited renewable scenario. There's been a lot of talk, around the region of, constraints on getting renewable energy projects in in service. So we wanted to look at what would happen if those resources came in later or came in at lower scales than we were thinking originally. And then on the bottom, we have three sensitivities that we wanted to look at, and these are variations on the base case where we looked at one change to the base case. As I mentioned on the last slide, we are predominantly customer, meaning that we get a lot of our power from BPA.

And we want to make sure that we're, accounting for those cost shifts if BPA costs go up or down. So that's one of our sensitivities we looked at, if Bonneville cost change. The second one is a thin rec market, which looks at the cost of, compliance with clean energy state laws and various strategies that we could take to comply with those with those laws. Then the third one is we have, two primary clean energy laws in the state. We looked at what would happen if there was only one, and those were combined into one clean energy policy.

So that kinda sets the bounds of our scenario. This is what we're looking at. Next, we had to look at our load forecast. So this is our load forecast. As you can see today, we're starting at about seven ninety average megawatts or so.

And then into the future, we're looking to be about 1,100 at the end of the study period. For reference, the dashed red line is our 2023 expected load growth. So you can see that, kinda overlaid on the orange line next to our high our high case from this time. So that kinda gives you, the what we're going to look at in the future, which is we're going to see load growth in the future from population changes and electrification electric vehicles. We need to figure out what resources we could potentially acquire to meet those needs.

On the demand side, we look at resources from our customers, and those are gonna primarily encompass, three studies that we did. First one is a conservation potential assessment. So we go out and acquire conservation. It's one of our primary resources. We pay for programs to allow our customers to use less energy.

So for example, if you go into Home Depot and you buy, a washer, a clothes clothes washer, you see a a sticker on there that says, you know, get a instant PED rebate. That's a conservation program from us because it is better for us to use less energy and to keep the resources we have now and use them more efficiently than it is to go get new resources. So we like to invest in our communities here in Sonoma County, and we we use conservation as one of our key resource acquisitions. New to us in this IRP cycle is our solar potential assessment. Our customers have consistently told us over the years that they wanna see more rooftop solar, and they wanna see what rooftop solar could look like as a as a resource for the PD.

So we wanted to assess what the potential is for solar, rooftop solar in Sonoma County. So we looked at that, and we looked at what, what benefits could be derived if the PUD offered an incentive for small, medium, and large on a customer scale systems. Then what doesn't show up in our energy supply, but it's certainly important to us, is demand response. So demand response and the demand response potential assessment looks at if you can shift energy away from the peak hours, which are the most costly and most, difficult to serve for us. If you can shift energy away from those hours, we can reduce costs for our customers.

So demand response is the ability to move, move energy usage either by behavior programs or by technological programs. We wanted to look at what what those programs could could provide for a benefit to the beauty, by either reducing or deferring infrastructure investments on the beauty side. So those are all the demand side resource, studies that we did. The other half of that is supply side resource. We did a technological survey.

We looked out around the the region to find out what technology we think is available. On here, you'll see some very common right? Solar and wind are very common in the region. We did look at energy storage both here and paired with resources. We also looked at some other technologies that are further in the future, and, we put all these together into one menu.

This is the menu that we use this year, for both attributes and costs. We looked at what each resource is doing and how much each resource could potentially cost. All of that, we put through our optimization engine, and this was the long term resource strategy that came out. As sort of has happened in the past. Conservation has been a key resource addition for us, so acquiring more conservation, from our customers.

Demand response and renewable resources are our primary resource acquisitions. On the bottom stack in the blue is, energy efficiency and conservation. The green is renewable resources at utility scale, so the big wind farms and solar farms in Eastern Washington. And then the orange at the top is BPA power purchases in the short term, which allows us to, sort of build a bridge between those resource acquisitions at scale. So and then the yellow, we had some local solar programs that seemed to that worked out, to reduce costs for us as well.

The primary driver for us this time was regulatory compliance. That was kind of the reason that the resource plan came out the way it did, but these results aren't drastically different from our previous IRPs. This is a portion of the, near term actions that we specified in the IRP for SPD staff. So we're going to acquire 7.5 annual average megawatts of cost effective conservation by '27. That's our biennial conservation target as required by the EIA.

We wanna look at and develop more demand response and smart rates programs. So those are gonna provide some, program development for us. We will be developing local PD solar at sort of the medium scale five megawatt solar projects here in the county. And then we're gonna look at exploring some larger, customer owned solar, larger rooftop solar, so bigger than 50 kilowatt programs for our in the county, for our customers. We do need to do some more work on battery energy storage locally cited here in the county.

It is, something that the staff, we just wanna have more numbers around and more, and better understanding of the of the energy storage component of of our resource plan. And then something that's regionally and nationally a big topic of conversation is large load requests. So whether that's a new industrial plant or a new data center trying to come into the county, we are gonna develop a strategy and framework to, to handle those and process those requests internally. And then finally, to continue to build on our public process, we've, we're gonna enhance our, phase one visioning process. We reach more customers, and we're gonna especially look at targeting and working on ways to reach customers who maybe don't speak English as a first language.

That's kind of one of our our core goals is to enhance and develop that community outreach process for our, IRP process. With that, I know I went through a lot. I went through it very quickly. I will we are here to take questions. So thank you very much.

Thank you for your presentation. I have about a dozen questions, so I'm gonna get about three or four in and then turn it over to other council members and maybe follow-up after that. But one of the things in your slide was, about the hydro that we get. I know we have the solar up in Arlington. So the PUD renewables 0.3% is that kind of where we're getting solar and solar that are on people's homes? Does that fit in that point 3%, or where does that fit on the graph?

That's for us, that looks like a load reduction for us, so that wouldn't be part of that pie chart that you saw. It looks a little bit like conservation or energy efficiency because, you know, we're we're serving on the other side of that interconnection to the grid. But just in the grand scheme of things, if our annual load today looks like about seven ninety average megawatts. We have connected residential rooftop solar in excess of 40 megawatts nameplate. That produces, call it, 10% of that nameplate.

So something like in the ballpark of four average megawatts contributing towards that seven ninety.

Great. And then, I did energy tour recently, and and I heard the term about brownouts coming up in Washington State, and then we had a legislator last week talk about brownouts. Is that something that we should be concerned about here in Snohomish County with potential brownouts? And if so, what should people be doing to maybe combat that? Is it battery energy storage, or is it putting solar on their homes? Or can you talk a little bit about the potential for brownouts?

Yeah. Absolutely. You know, one of the things that is not in this slide deck, but was a a major part of 2025 for us at the Snohomish PUD, is we changed about 90% of our power portfolio in almost all of our long distance transmission portfolio. The reason we did that was we wanted to reduce the risk of resource adequacy challenges in the future and we also saw a potential cost saving opportunity for our customers that could set us up well for the long term. So without boring you with too many details, our previous product, which we held from BPA for both power and transmission before October 1, amounted to us getting sort of generation as it was produced from the Columbia River projects.

But anything we needed beyond that was our responsibility on a day to day and hour to hour basis, which meant that we at the PUD, using a trade floor, were purchasing from the secondary market for electricity and finding the available transmission to flow that back to Snohomish County. And we were concerned that with some of the larger load growth in the region and some of the cost to keep up with population growth and economic growth here at home in Snohomish County that we could be at increased risk of being in periods of time where it's an hour where there's a lot of demand and there's not a lot of supply in the secondary market. So we converted all of our BPA power product to a different BPA product that covers after our local hydro projects all of our load needs. So now we're not in that secondary market anymore on a day to day and hour to hour basis. We also converted our transmission product to a fixed nominal product.

So I mentioned we had a seven ninety average load. Well, our peak in the winter is about 1,600 megawatts. Right? So in a given hour, it can be a lot more than that. And our transmission portfolio was about 1,600 megawatts of fixed point a to point b transmission.

We converted that to a network model that flexes up and down with our load and we only pay for the amount that we use. So we think that sets us up well for the future because instead of needing to procure additional paths of transmission, we now have access to the full network, and it will grow at the scale that we grow here in Snohomish County. Just to bow on top of this very long monologue I recognize is that in 2026, our budget for power supply and transmission for our load in Snohomish County is gonna be about $315,000,000, a big number, But a number that pales in comparison to our 2025 budget for power and transmission was about $365,000,000 So we feel like we've better positioned the utility and also saved a significant amount of money for our ratepayers. So what

I heard through all that is Snohomish County is better prepared for brownouts than other portions of the state. Would that be fair to say? That'd be fair

to say.

Thank you. All right. I'll turn it over to other councilmembers for questions. Council member Dunn?

Yeah. Thank you. I just had a question about AI and the use of AI and how it's more seems to be more of a power drain than expected even probably in your last reporting. So how is it reflected in the scenarios?

Yeah. It's a really good question, and I'm worried I'm gonna give you a really long answer again. But I want you to have all the best information. So when we do our power plants, you know, we have a long relationship with our residential customers, the commercial sector, industrial sector here. We can forecast out what that growth looks like in those sectors pretty good.

We have a pretty good track record over and over a period of time. We know that we get somewhere between 3,000 to 7,000 new connections per year, and we know about what the energy intensity of those connections looks like. Data centers and some of these large load requests are different than that. Going back to that July number, right, it's not unusual for a data center to be in excess of 100 megawatts, which would be roughly an eighth of our load all at once. Typical annual load growth is between eight and ten average megawatts.

So would be about 10 times larger than a typical increment of load growth. If we were to embed that into our long term power plans and plan as if one of those loads is going to show up and then it doesn't, we will have invested a significant amount of ratepayer dollars into resources and infrastructure that add cost to our system but may not have a home for that load. And so there can be a stranded asset risk if we bring that into our power plan. So instead, you know, we plan for the customers and the load growth that we expect to materialize, and we develop additional strategies for if those loads do materialize. How would we address that, and what are the options and the strategies so that we can accommodate new load but protect the customers that are here from any rate impacts?

Any other questions? Great. When I started here nine years ago, one of the first things I did was go up to Sunset Falls and tour that area, and that was a huge discussion at the time. And about a year later, that got shut down. Since that time, I've been out to Jackson Hydro project many times.

You guys have invited me out for that. I've been out to the Woods Creek, and and some of the others. Are there any other potential areas, for growth for hydropower, other power resources? Obviously, like, have the Arlington, solar. Are there other projects in the county that we as a council should be aware of potentially?

We're always in sort of a a process of evaluating how we can optimize and improve the output of projects. So existing projects, we're always looking at to see if if there's a potential to make them more useful. But as we look long term at some of the drivers of our resource plan, some of those drivers are clean energy laws in Washington State, and hydropower gets different regulatory compliance value than some of the other resources that are out there like wind, like solar. So for us, as we do the economic evaluation of everything that we could do, we're finding that at least right now with the regulatory framework we have, wind and solar outcompete new hydro resources because they reduce regulatory costs more than hydropower does.

My last question, like I said, I have a dozen more and I'll probably follow-up off line. But you brought up the best systems, battery energy storage systems. And I was in Skagit County yesterday. That's been a huge topic up in Skagit County, especially. You're you're looking at it here at the PUD level.

I think what I've heard from the community up there is the struggle of placing these in farmland or next to streams. Obviously, here in Snohomish County, we already have a lot of resources in East Snohomish County with our hydro projects. So when we talk about site potentially siting these energy storage systems, are you looking to cite these on our farmland because we just had like a gas leak on our farmland the last couple of weeks? Are we looking to put these more towards where the population is? What kind of goes into your discussion on where these potentially might be located in Snomish County?

For us, the most economic places to put a battery energy storage system is right where we already have infrastructure and especially where we already have substations with additional space by those substations. It results in the lowest infrastructure cost for interconnection. The zoning oftentimes is already appropriate, and the land use is already appropriate. So we do have batteries in Arlington at the Clean Energy Center, but, you know, we're also in an industrial area. Are appropriately zoned for it with other PUD infrastructure.

That's probably our best model for the appropriate use cases of battery energy storage systems just because it also results in the lowest cost for our customers, and we don't have plans to go outside that box.

Well, thank you so much for your time today. Really appreciate you being here. We should have done this a lot sooner, but, we'll invite you back again as as more topics come up, and we can talk about transmission lines or smart meters or some of the other things that the public reaches out to us about. So thank you so much for your time. Brenda, do you wanna say anything?

I would. Just in closing, what a privilege to be here with, you know, phenomenal effort and team. That all being said, Swish County is a significant partner of ours, and so we're grateful for that partnership year round, the collaboration that we have with various teams, and being part of really this journey of growing together. So that's my parting word is words is is growing together, and we're working really hard to to meet that growth with your comprehensive planning. And we're sensitive to some of the questions, Councilmember Low, that you brought up.

Obviously, our site development for clean energy projects will be where the need is the greatest as well, and they tend to also be, you know, in more of our, you know, more denser areas and where where it is sited near our infrastructure. Infrastructure, I don't think we'll be looking at farms. So Great.

Thank you so much. Thanks for being here today. All right. We have seven action items we need to do today, and those should go fairly quickly. So we'll go ahead and move to our action items. And first is, ordinance 25 dash zero eight zero. Good

morning, committee chair Low and council members. For the record, Deb of the Symbelle council staff. Proposed ordinance 25 dash zero eight zero is for the proposed vacation and abandonment for a portion of unopened Snohomish County right of way known as 40th Street Southeast. The total right of way to be vacated is 30 feet by 89 feet portion. And that portion, of that portion, 20 feet of the eight by 89 feet, it was deeded to the county in 1942 and is listed as a class b road right of way, which requires the petitioners to pay 50% of the appraised market value.

Then 10 feet of by 89 feet of that was dedicated in 1969 with the recording of the Glenwood Vista Platte. Brett and Angela Nicholson have submitted a road vacation petition for the 2,670 square feet that is adjacent to their property to be vacated. The county engineer has written their report and recommends approval of the petition with conditions. The requested action for council to move the ordinance tomorrow's GLS meeting on December 3 to set time and date for public hearing with the suggested date of 01/07/2026 at the hour 10:30AM. This concludes my staff report. I'm available for any

Alright. Any comments or questions from council members? Alright. We'll go ahead and move this to GLS tomorrow on December 3 to set time and date for a public hearing and go to motion 25 dash five zero nine.

Thank you. Proposed motion 25 dash five zero nine would approve and authorize the county executive to sign supplement number seven to the professional services agreement CCF04Dash23 with PH Consulting LLC for the amount of $11,978.99. This is for a total amount not to exceed $140,625.48 under Snohomish County code three point zero four point one nine zero. The Department of Public Works received federal funding to complete spot safety improvements on the 84th Street corridor from SR Nine to SR 92. And this is considered a high volume corridor at high speeds.

This project is included in the tip as project number DDot67Dot03. And the additional funding will allow for additional assistance during the bidding and engineering services during construction. The requested action is for council to move the motion to GLS on December 10 for consideration. And this concludes my staff report. I'm available for any questions.

Alright. Any comments or questions from council members? Alright. Hearing none, we'll go ahead and move this to GLS on December 10 on consent unless there's objection. Hearing none, we'll go and move that to consent and go to motion 25 dash five two two.

Thank you. Proposed motion 25 dash five two two would approve and authorize the county executive to sign an interlocal agreement between Snohomish County and the Alderwood Water and Wastewater District considering utility construction associated with the Alderwood Mall Parkway and SR 529 to the 1 60th Street Southwest improvement project. This is tip project number EDot60. Aldwood Water and Wastewater has requested that the county incorporate the construction of 766 feet of eight inch and 143 feet of 12 inch restrained joint ductile iron water main into the project, which the Alderwood water and wastewater will reimburse the county for the actual cost of completing this work. The estimated reimbursement cost is $1,719,013.78.

And the requested action is for council to move the motion to GLS on December 10 for consideration. This concludes my staff report. I'm available for any questions.

And I just wanna clarify for the record. It's 52 SR5252168? Correct. Yes. Okay. Great. Alright. Any comments or questions from council members? Alright. We'll go ahead and move this to GLS on December 10 unless there's objection. Hearing none, we'll move this to GLS on December 10 and go to motion 25 dash five two nine.

Thank you. Proposed motion 25 Dash five two nine would approve and authorize the county executive to sign the interlocal agreement between Snohomish County and the Alderwood Water and Wastewater District for utility construction associated with the Ash Way overlay project on 164th Street Southwest to the Park And Ride. This is tip project number BDot01Dot20. Alderwood Water and Wastewater desires to replace and adjust their water valve boxes and sewer maintenance hole collars and covers to the finished grade during the overlay project. All costs associated with the project would be reimbursed by the water district and wastewater district with the established expense or the estimated expense, excuse me, of $19,080.60.

The requested action is for council to move the motion to GLS on December 10 for consideration. And this concludes my staff report, and I'm available for any questions.

Alright. Any comments or questions from council members? Alright. We'll go ahead and move this to GLS on December 10 on consent unless there's objection. Hearing none, we'll move that to consent and go to motion 25 dash five four two.

Thank you. Proposed motion 25 dash five four two would authorize an approved surplus and sale for remnant property parcel with a tax ID number of 29060900206100 to neighboring property owner Andrew Wittenberg and authorized the property officer of the Department of Facilities and Fleet to prepare and execute all documents necessary to facilitate and complete the sale under Snohomish County code 4.46. In November 2006, Snohomish County Department of Parks and Recreation sold a portion of the Centennial Trail to the city of Lake Stevens. The sale created a 2,613 square foot remnant property. Neither the county nor the city have a use for this remnant property, and the goal is to surplus and then sell this remnant property to the adjoining neighbor.

He has expressed an interest in purchasing this remnant property for a negotiated price of $8,000, including co closing costs. Requested action is for counsel to move the motion to GLS on December 10 for consideration. And this concludes my staff report. I'm available for any questions.

All right. Any comments or questions from council members? All right. Hearing none, we'll go ahead and move this to consent on December 10 unless there's objection. Hearing none, we'll go ahead and move this to GLS on December 10 and go to motion 25 dash five three eight.

Thank you. Proposed motion 25 dash five three eight would approve and authorize the county executive to execute an interlocal agreement and associated work orders and amendments between Snohomish County and the Snohomish Regional Fire and Rescue to provide information technology services under RCW 39.34 and Snohomish County code three point zero four and three point zero one. This is a new agreement and would start on 02/18/2026 through 02/17/2030 with a not to exceed amount of $100,000 Anticipated revenue over the course of the contract is $66,150 and the requested action is for counsel to move the motion to GLS on December 10 for consideration. This concludes my staff report, I'm available for any questions.

All right. Any comments or questions from council members? Hearing none, we'll go ahead and move this to consent on December 10 unless there's objection. Hearing none, we'll move that to consent and go to motion 20 five-five 38. Excuse me. Motion 20 five-five 47. Thank you.

Thank you. Proposed motion 25 dash five four seven would approve and authorize the county executive to execute interlocal agreement and associated work orders and amendments between Snohomish County and the city of Everett to provide information technology services under RCW 39.34 and Snohomish County code three point zero four and three point zero one. This agreement also includes the ability for the city to use the county's agreement with EagleView, which is a Pictometer International Corporation that provides ortho imagery or for GIS purposes. The requested action is for councils to move the motion to GLS on December 3, which is tomorrow for consideration. This is an urgent request as the existing ILA is expiring. This concludes my staff report, I'm available for any questions.

Alright. Any comments or questions from council members? Right. We'll go ahead and move this to consent on December 3 unless there's objection. Hearing none, we'll move that to consent. That brings us to the conclusion of our meeting. I believe we are in recess until our meeting this afternoon with legislators. So thank you.