amended regular session agenda northern wasco … · 2018-06-29 · amended regular session agenda...

AMENDED REGULAR SESSION AGENDA NORTHERN WASCO COUNTY PEOPLE’S UTILITY DISTRICT

Board Room, 2345 River Road, The Dalles, Oregon JULY 3, 2018 6:00 p.m.

A. Public Comment Period

B. Consent Agenda These items will be acted upon as a single item, unless any member of the board wishes to move an item to the regular agenda for separate consideration.

1. Regular Session Minutes of June 5, 2018 2. May Outage Report 3. Energy Management/Marketing Report 4. Checks/Vouchers 5. May Financial Report 6. May Write Offs

C. Division Updates: (reports to be made by Division Directors or designated

representative) 1. Engineering/Operations 2. Finance & Risk 3. Power Resources 4. Corporate Services 5. General Manager 6. General Counsel

D. New Business

1. Approval of Northwest Energy Management Services (NEMS) Master Resource Agreement

2. Update on District’s 10-Year Capital Plan 3. Adoption of Amended Pole Contact Rates

E. Old Business

F. Items from Board Members

G. Board Reports / Items from Board Members

1. Oregon People’s Utility Districts Association (OPUDA) 2. Northwest Public Power Council (NWPPA) 3. Other

H. Approval of future meetings/travel/or related matters.

Future Meeting Dates: 1. July 17: Board Strategic Planning Work Session, 1 pm-3 pm 2. August 1: NRU Board of Directors, 9 am-2:30 pm, Sheraton @ PDX 3. August 1: PPC Forum, 3-5 pm, Sheraton Inn @ PDX 4. August 2: PPC Executive Committee, 8 am-12 pm, Sheraton Inn @ PDX 5. August 17: OPUDA Board Meeting, 8:30 am, SDAO Office in Salem

I. Miscellaneous Information

This Agenda is subject to last minute changes. Meetings are ADA accessible. For special accommodations please contact the

Northern Wasco County PUD Office in advance, (541) 296-2226. TDD 1-800-735-2900.

NORTHERN WASCO COUNTY PEOPLE’S UTILITY DISTRICT REGULAR SESSION

JUNE 5, 2018

PRESENT: Dan Williams, President Connie Karp, Vice President Roger Howe, Secretary

Clay Smith, Treasurer Howard Gonser, Director

President Williams called the Regular Session to order at 4:00 p.m. 4:01 p.m. President Williams recessed the Regular Session to convene into Executive Session as authorized by ORS 192.660 (2)(g) to consider preliminary negotiations involving matters of trade or commerce in which the governing body is in competition with governing bodies in other states or nations. Those present for the Executive Session included the Board of Directors, General Counsel James Foster; General Manager Roger Kline; Assistant General Manager/Director of Power Resources Kurt Conger; Principal Engineer & Strategic Asset Planner Paul Titus; Executive Assistant Kathy McBride; Director of Corporate Services Cyndi Gentry; Chief Financial Officer/Director of Finance & Enterprise Risk Harvey Hall; Key Accounts Manager Justin Brock; Operations & Engineering Manager Pat Morehart and District Consultant Michele Chait, E3. At 5:16 p.m. the Board adjourned from Executive Session to return to Regular Session. The Board recessed for dinner. At 6:00 p.m. President Williams reconvened the Board of Directors into Regular Session. The following individuals were present during the Regular Session: Counsel: James Foster NWCPUD Staff: General Manager Roger Kline; Assistant General Manager/Director of Power Resources Kurt Conger; Principal Engineer & Strategic Asset Planner Paul Titus; Operations & Engineering Manager Pat Morehart; Key Accounts Manager Justin Brock; Contracts & Risk Specialist Sue Powers; Director of Corporate Services Cyndi Gentry; Executive Assistant Kathy McBride; Asset/Program Manager Steve Horzynek; Energy

EXECUTIVE SESSION

NORTHERN WASCO COUNTY PUD REGULAR SESSION MINUTES JUNE 5, 2018 PAGE 2

Specialist Lance Kublick; Chief Finance Officer/Director of Finance & Enterprise Risk Harvey Hall; Hydro Electrical Technician Intern Cherish Southard Visitors: Wasco County Sheriff’s Department Representatives Alan Birchfield and Paul Ufford; Columbia Gorge Veterans Museum Representative Lisa Commander; EES Consulting, District Consultant, Ted Light; and Scott Taylor Lisa Commander, Columbia Gorge Veterans Museum Representative, stated that the Economic Development Grant Funding that was awarded to the Columbia Gorge Veterans Museum, by the Northern Wasco County People’s Utility District Board of Directors in 2017, has been spent. Commander provided the Board will a letter and documentation attached showing the expenditure of the grant funding. Commander stated that they have had 500 people visit the Veterans Museum since the grand opening last year. She thanked the Board for making a great investment in the community. Commander invited the Board to come and visit the Museum. Currently the Museum is displaying, “Vietnam, 1968” through the first of July, and then “Combat Veterans of the Gorge”. Items contained in the consent portion of the Agenda includes the following:

• Work Session Minutes of February 6, 2018

• Regular Session Minutes of May 1, 2018

• Work Session Minutes of May 10, 2018

• April Outage Report

• Energy Management/Marketing Report

• Checks/Vouchers

• April Financial Report

• April Write Offs

• Amended kWh Statement for the January 2018 Financial Report

• Amended kWh Statement for the February 2018 Financial Report

• Amended kWh Statement for the March 2018 Financial Report

PUBLIC COMMENT

CONSENT AGENDA


The Board considered the approval of the June 5, 2018 Consent Agenda. President Williams had a question pertaining to the Amended kWh Statements for the January through March 2018 Financial Reports. Principal Engineering & Strategic Asset Planner Paul Titus stated that the kWh Statements needed to be adjusted due to the error found in the formula of calculation at the end of Quarter 1. The kWh Statements have been amended to restate what the District bought from Bonneville Power Administration (BPA) Priority Firm (PF), short term rate and non-federal resources. This also affected the District’s line losses. {{{Director Gonser moved to approve the June 5, 2018 Consent Agenda as presented. Director Smith seconded the motion; it was then passed unanimously.}}} Assistant General Manager/Director of Power Resources Kurt Conger introduced Cherish Southard, Hydro Electrical Technician Intern, who is working at The Dalles Hydro Fishway Project. Southard is pursuing an electrical degree in Yakima, Washington. Southard is interested in hydro operations. Cherish Southard stated that the welcome that she has received since becoming an employee has been amazing. She is having a great time.

Engineering/Operations: Before Operations & Engineering Manager Pat Morehart began his report, a date nail dated 1926, which was taken out of one of the power poles replaced along Highway 216, was shown to the Board. Morehart provided the following report: Tygh Valley Transmission Pole Replacement Project:

• International Line Builders (ILB), District Contractor, started the Tygh Valley Distribution Rebuild Project on April 16, 2018.

• At end of this week, the Tygh Valley Distribution Rebuild Project will be approximately 70% complete.

• The contractor has reconductored from the White River Park to the intersection of Highway 197 and Highway 216.

• Next week ILB will be working on the poles in the town of Tygh Valley.

DIVISION UPDATES


Osmose:

• Osmose, District Pole Inspection Contractor, began the new round of pole inspections back on May 26, 2018.

• Osmose completed the work, for the current cycle of inspections, inspecting the structures on the 60 kV line between the District’s Three Mile Substation and White River Substation.

• Osmose has also inspected the poles in Tygh Valley, Dufur and Wamic.

• Of the poles inspected, 24 poles were found that needed to be replaced.

• District staff will be meeting with supervisors from Osmoses on June 13th to review inspection findings.

• Morehart reported on a pole that had been found during the inspection that was burnt off about five feet above the ground line in a remote area on Tygh Ridge. District staff went to work immediately to perform switching and to electrically isolate the compromised structure. District staff replaced the pole and completed the work in one day.

The Dalles Marina Rebuild Project:

• The recent flood levels on the Columbia River pushed boat houses at The Dalles Marina to interfere with the District’s electrical service to the Marina causing a fire in the eve of one of the boat houses.

• District staff responded immediately to the emergency dispatcher’s report of the fire and the Marina was de-energized on shore.

• Mid-Columbia Fire and Rescue extinguished the fire promptly saving the structure and containing the damage to the one boat house.

• For public safety and prudent utility practice, the Marina was de-energized until water levels subsided and a lowering trend was maintained.

• During that time, it was decided that the District would perform stray radiant and transient voltage and amperage testing to rule out the existents of those conditions before determining if the Marina should remain energized.

• A contractor with experience in electrical marina environments used special equipment to test the marina. The tests were performed on June 1st. The existence of radiant and stray voltage and current was found to be at low enough levels to not pose a danger.

• Due to the test results and the trend in lower water levels it was decided to leave the Marina energized.

During Morehart’s report, PowerPoint Slides were shown of the Tygh Valley Transmission Pole Replacement Project. A copy of the PowerPoint Slides is hereto attached and marked as Exhibit 1.


Operations:

• On the evening of May 23, 2018, District staff was called on to de-energize power in the neighborhood near East 16th Street and Nevada where a fully involved house fire was threatening a District pole and the surrounding homes.

• With the secondary service burnt down, the District’s on call staff opened disconnect switches feeding the primary circuit to approximately 30 residential customers until the fire was extinguished and work could be done safely on the burnt pole.

• The affected pole is still in service and is slated for replacement this summer.

• An emergency dispatcher called another time over a weekend in mid-May when a squirrel crawled up onto a primary riser pole outside of the District’s Tenth Street Substation and electrocuted himself.

• The contact from the squirrel did not trip the substation breaker. A grass fire was caused when the burning squirrel landed in the dry grass burning approximately a half acre of vacant property.

Vegetation Management Program:

• The District’s Vegetation Management Program continues to make progress in some of the District’s most difficult to access and heavily overgrown areas.

• Staff is still striving to reach a point where a systematic substation feeder trimming cycle becomes the method.

• Trees Inc., District Tree Contractor, is currently working on Wicks Reservoir Road. The line is remote and requires extensive climbing to access.

• Several photographs of vegetation removal by Trees Inc. were shown at this time. These photographs are hereto attached and marked as Exhibit 2.

American Public Power Association (APPA) Annual Conference:

• In May 2018, Asset/Program Manager Steve Horzynek attended the American Public Power Association (APPA) Annual Conference in North Carolina.

• Horzynek accepted on behalf of Northern Wasco County People’s Utility District the APPA Safety Award for no lost time injury accidents.

American Public Power Association (APPA) National Lineworker Rodeo:

• Photographs of Apprentice Lineman Tucker McCabe, which were taken at the recent American Public Power Association (APPA) National Lineworker Rodeo, were shown to the Board. Copies of said photographs are hereto attached and marked as Exhibit 3.

• McCabe competed at the APPA National Lineworker Rodeo held in North Carolina in April 2018.


• McCabe scored high in the academic portion of the competition and had competitive scores for time and technique in various tasks, such as insulator change-out, and hurt man rescue.

• McCabe has been advanced to the third step of his apprenticeship. The Board expressed how proud they are that McCabe went and competed at the APPA National Lineworker Rodeo.

Finance and Risk: Chief Financial Officer/Director of Finance & Enterprise Risk Harvey Hall reported as follows:

• The District’s April Financial Report indicates $380,000 to the positive for the year.

• The current meter count is 10,271; the District’s active customer count is continuing to climb.

• The District’s kWh usage continues to grow. Last year the District was at 229 million kWhs. The District is about 13 million kWhs more than this time last year.

• The District is experiencing some load and base growth.

• The Board has been previously introduced to Enterprise Risk Management (ERM) where risk is looked at and considered.

• Hall is working with a consultant, that he would like to propose to the Board. This consultant would develop a frame work to look at risk and to determine the Board and District’s risk appetite.

Some discussion occurred regarding Enterprise Risk Management. General Manager Roger Kline informed the Board that the District will use the International Standard Organization (ISO) Standard to make it fit for us. Hall noted that the ISO Standard is a common one that is used by neighboring utilities; it is broadly accepted. Director Gonser stated that he thinks it is a great idea; he is anxious to use the ERM process to make better decisions for the District. Hall reported as follows on Other Post-Employment Benefits (OPEB):

• The District has had an OPEB audit done every three years; the last one being done in December 2016.

• The Government Accounting Standards Board (GASB) rules have changed; GASB 75 changes the way that the audit is performed.


• The District is looking for a different auditor to perform the required OPEB audit this year. Staff spoke to McMillen and four other entities regarding the audit.

• McMillen stated that they could do the OPEB audit for a cost of $35,000. The District’s prior OPEB audit cost only $2,500.

• McMillen, after speaking to the Special Districts Association of Oregon (SDAO) regarding pooling the audit with other Special Districts, came back to Hall with a cost of around $2,500.

• Hall is continuing the audit discussion with McMillen. Some brief discussion occurred.

Power Resources: Assistant General Manager/Director of Power Resources Kurt Conger informed the Board that he is giving his time to Corporate Services. Corporate Services: Director of Corporate Services Cyndi Gentry reported as follows:

• When the UPN Reset Project was being wrapped up, Gentry asked Business Analyst Consultant Marijane Thompsen to look at some large work items for Corporate Services.

• Thompsen is preparing information and plans, along with a draft task list.

• A couple of the items that staff is looking at is check payment scanning functionality, and the installation of card payment hardware at the front counter, which would allow the kiosk to be removed.

• The District’s network needs to be updated before card swipe hardware can be installed. The District is out of switches and bandwidth.

• Another item that staff is looking at is the ONLINE Utility Exchange; a utility related credit check for new services.

• ONLINE Utility Exchange also provides collection services.

• Gentry asked if a member of the Board of Directors would be on an evaluation team to consider the services offered by ONLINE Utility Exchange.

• Staff would like input from the Board on what the credit check level should be to meet the needs of the District, as well as identifying if that is a service that the District needs to purchase.

• The District currently requires a letter of credit from another utility if the new customer does not have credit history with the District. In the absence of the letter of credit, the District has standards to set a deposit amount.

Some discussion occurred regarding ONLINE Credit Exchange.


President Williams stated that he would like to know how much staff time is spent monthly on un-collectibles. President Williams and Director Karp expressed an interest in participating on the evaluation team to look at services from ONLINE Credit Exchange. The last two items that Gentry reported on is as follows:

• Staff has been testing the latest version of UPN 37 over the last week and a half. The District can test without touching the system that is used to conduct business.

• A thank you card from the Lamoreaux family, District customer, was read out loud by Gentry. A copy of the thank you card is hereto attached and marked as Exhibit 4.

President Williams expressed the Board’s appreciation to Energy Management Specialist I Travis Hardy for his work with the District’s Low-Income Weatherization Program.

General Manager: General Manager Roger Kline reported as follows:

• A few months ago, a presentation and discussion occurred with the Board and Iris Tilly, Barren Leibman, regarding the District’s Retirement Plan.

• A Request for Proposals for Retirement Services was distributed by Barren Leibman on the District’s behalf.

• A total of seven (7) responses were received back from the RFP.

• Kline will be speaking to Tilly by phone on the next step of the Retirement Plan review process.

• A cross functional team will review the submitted proposals to come up with a recommendation for the Board’s consideration.

• Kline does not believe that Nationwide, the District’s current retirement services provider, responded to the RFP.

General Counsel:

General Counsel James Foster reported that he is still working with staff on developing templates for contracts so that the District has consistent contract language. Foster is working with Key Accounts Manager Justin Brock on some other matters. Director Smith asked a question pertaining to the McNary Crane Failure Litigation.


Foster responded by stating that he has touched base with Klickitat PUD General Manager Jim Smith on a number of occasions. Smith has been advised to call Foster if he needs anything. Foster stated that since the last meeting there has been no dramatic changes in the litigation. Conservation Potential Study: Energy Specialist Lance Kublick introduced to the Board Ted Light from EES Consulting. Light will be presenting a PowerPoint Presentation entitled “Conservation Potential Assessment”. A copy of the PowerPoint Presentation is hereto attached and marked as Exhibit 5. Some of the highlights from Light’s presentation is as follows:

• EES Consulting has completed numerous Conservation Potential Assessment (CPA) for northwest utilities.

• The CPA is the estimation of conservation resource potential available in Northern Wasco County People’s Utility District service territory.

• The CPA Model does not predict how savings will be accomplished.

• Comparison of 2009 CPA and 2017 CPA Cost-Effective Potential for 10-Year is as follows:

➢ Residential – 2009, 1.3; 2018, 1.4; 7% change ➢ Commercial – 2009, 1.0; 2018, 0.5; -48% change ➢ Industrial – 2009, 1.5; 2018, 0.2; -85% change ➢ Agricultural – 2009, 0.0; 2018; 0.2; NA change ➢ Distribution Efficiency – 2009, 0.0; 2018, 0.2; NA change ➢ Total – 2009, 3.8; 2018, 2.3; -39% change ➢ Note that the 2009 data refers to the CPA completed in 2009 for the time

period of 2009 through 2028. The 2018 assessment is for the timeframe 2019 through 2038.

• Comparison of 2009 CPA and 2017 CPA Cost-Effective Potential for 20-Year is as follows:

➢ Residential – 2009, 2.5; 2018, 2.4; -7% change ➢ Commercial – 2009, 1.0; 2018, 1.1; 12% change ➢ Industrial – 2009, 1.5; 2018, 0.3; -81% change ➢ Agricultural – 2009, 9.0; 2018, 0.0; NA change ➢ Distribution Efficiency – 2009, 0.0; 2018, 0.5; NA change ➢ Total – 2009, 5.0; 2018, 4.3; -15% change ➢ Note that the 2009 data refers to the CPA completed in 2009 for the time

period of 2009 through 2028. The 2018 assessment is for the timeframe 2019 through 2038.

NEW BUSINESS


• The District can expect to achieve 0.2 - 0.3 aMW per year in conservation resources.

• The 2018 assessment has a lower conservation potential than the 2009 assessment.

• Key program areas: residential weatherization; residential lighting; commercial lighting, and industrial sector.

Electric System Reliability & Infrastructure Status Report: Principal Engineer & Strategic Asset Planner Paul Titus stated that the Board was provided in the Board Packet with a copy of his memorandum regarding the District’s reliability statistics and the 2017 APPA eReliability Report. A copy of Titus memorandum and the 2017 APPA eReliability Report is hereto attached and marked as Exhibit 6. Some of the highlights from Titus’ presentation on the District’s electric system reliability and infrastructure status is as follows:

• Since 2013 the District has used APPA’s eReliability Tracker, a web-based software to track outages and create reliability metrics.

• The yearly cost for this web-based software is $100.

• APPA provides an annual report that provides reliability indices and compares the District to other utilities within a region and customer size class.

• The District has 10,043 customers, which is Class 4 (6,798 – 12,695 customers), with an approximate total of 85 utilities.

• The District is located within Region 9, which includes Oregon, Washington, Idaho, Montana and Alaska with 10 utilities.

• The District’s major event threshold is 6.3997 minutes, System Average Interruption Duration Index (SAIDI).

• The top five occurrence rates for sustained outage causes in the District’s Region are equipment, scheduled, tree, storm and bird.

• Momentary outages will be able to be tracked better once the District deploys AMI meters.

Titus reviewed and discussed with the Board at great length the following four graphs which were included in his presentation material:

❖ System Average Interruption Duration Index (SAIDI) ❖ System Average Interruption Frequency Index (SAIFI) ❖ Customer Average Interruption Duration Index (CAIDI) ❖ Average Service Availability Index (ASAI)


Titus stated in closing that the District is doing good. It is still important for the District to reinvest in our infrastructure resiliency and make sure we provide the most reliable service that we can to our customers. Kline stated that the take away message from Titus’ presentation is that the District’s electric system is still strong. However, some of the metrics are trending in the wrong way. The District needs to continue to invest in our electric system. Consideration and approval of Contract for The Dalles Marina Rebuild Project: Asset/Program Manager Steve Horzynek presented a PowerPoint Presentation entitled “Port of The Dalles Marina Electrical Upgrade”. A copy of said PowerPoint Presentation is hereto attached and marked as Exhibit 7. Some of the highlights from Horzynek’s presentation are as follows:

• Overhead transformer at The Dalles Marina is at capacity.

• Overhead lines with limited connection options and aged support structures.

• Hazards during high water.

• There is no ability to provide required Ground Fault (GFCI) protection.

• Limited service capacity to customers during peak occupancy.

• Outages are very common during peak occupancy.

• The District serves 63 meters at The Dalles Marina.

• Some of the following planned upgrades come with state mandates and increase in codes:

➢ New pad mount transformer on shore. ➢ Proper system ground protection. ➢ Increased service capacity providing reliability during peak occupancy. ➢ Industry standard marine electric distribution system. ➢ All conductors mounted to the dock above water line. ➢ Improved lighting. ➢ Provide proper infrastructure against electric shock drowning.3

• Each meter pedestal has two meters with lights.

• The District has received a lot of support from the marina tenants.

• Ready read meters are currently being used at the marina. Some discussion occurred regarding The Dalles Marina Rebuild Project and the estimated completion date for the project. General Manager Kline noted that the District does not have a separate rate class for temporary residential. The project cost is not to exceed $800,000.


Horzynek stated that staff estimates that the project will be completed by mid-September, if everything lines out with contractor’s time schedule. The plan is that the overhead structure will stay in place while the work is being done. Kline informed the Board that the District is hosting a meeting with The Dalles Marina tenants on the evening of Thursday, June 7th. Tenants will be updated on the District’s rebuild plans. Kline stated that Horzynek has done an excellent job overseeing the project. The District manages the electrical distribution system, but we do not raise or lower the river. Information on The Dalles Marina Rebuild Project will be shared with members of the public after the meeting with the marina tenants. The District has engineering drawings that are 100% complete. There is nothing that could not be changed or revised in the drawings if concerns are raised by the tenants. ***It was the consensus of the Board of Directors for staff to continue with The Dalles Marina Rebuild Project at a cost not to exceed $800,000***. Decision on awarding Economic Development Grant Funding: General Counsel James Foster provided the Board with the names of the organizations that did not meet the requirements of the District’s Economic Development Grant Program. Foster’s comments are as follows: City of The Dalles:

• The City of The Dalles’ Grant Application did not meet the budget requirements. Only costs were provided; no income was noted in the budget.

• There is no indication in the Application that the project will be started within the next 12 months; it is four years out.

Deschutes Rim Health Clinic:

• Grant funding cannot be awarded to the Deschutes Rim Health Clinic since the Clinic is located outside the District’s boundaries.

Wasco County Sheriff Reserves:

• Foster noted his concern with the response received, at the May Board Meeting from the Sheriff’s Department Representative, when he asked the question if the District funded the purchase of the equipment, could the needed funding for the

OLD BUSINESS


physical and psychological exams be obtained from another source. The answer to Foster’s question was no.

• Foster does not know how the District can expend money on the equipment if the County is unable to fund the exams of potential Sheriff Reserve candidates.

• Foster feels it is a good program in terms of the benefit to the community.

Wasco County/City of The Dalles Museum Commission:

• The Wasco County/City of The Dalles Museum Commission failed to submit their grant application on time. The application was withdrawn by Donna Lawrence on May 1, 2018 after she learned that the application was submitted one day late. Wasco County 4-H Association:

• The application from the Wasco County 4-H Association was received one day late.

• The 4-H Association’s Grant Application did not identify any hard goods; they were all consumables.

Alan Birchfield, Wasco County Sheriff’s Department Representative, stated there was a misunderstanding during the Sheriff’s Department grant application presentation as to the Department being able to come up with the funding for the physical and psychological testing, if the District only funded the equipment request. Birchfield expressed to the Board that he believes that he could come up with the needed funding for the exams. At the time of the presentation, Birchfield had stated that he did not have any money in the budget for the costs of the exams. At this time, the Board took each Economic Development Grant Application and noted if they supported the grant request. The Board’s support is noted below: Dufur School District, $15,000:

• Directors Gonser, Howe, Karp and Williams supported the project; Director Smith does not.

{{{Director Karp moved to award Northern Wasco County People’s Utility District Economic Development Grant Funding to the Dufur School District in the amount of $15,000. Director Gonser seconded the motion. President Williams suggested that the Board consider all the applications first before making a motion. Director Karp withdrew her motion. Director Gonser withdrew his second.}}}


Mid-Columbia Economic Development District:

• Directors Gonser, Karp and Williams supported the project; Directors Howe and Smith do not.

Tygh Valley Rural Fire Protection District:

• Directors Gonser, Howe, Karp and Williams supported the project; Director Smith does not.

Wasco County Sheriff Reserves:

Director Howe asked Alan Birchfield if he could guarantee that the Sheriff’s Department could get the needed $3,000 for the exam costs if the Board was to award Economic Development Grant Funding for the purchase of the equipment. Birchfield responded to Director Howe’s question by stating that he will have $3,000 in the Sheriff’s Department budget on July 1, 2018. The exam costs for the other volunteers is the amount that he does not have currently in his pocket. Foster stated that the equipment request was based on a certain number of volunteers that would take the exams. He asked if the Sheriff’s Department does not have the money for the exams, what is the equipment for? Further discussion occurred. It was noted by Paul Ufford that the equipment cost for each Sheriff Reserve Volunteer is $1,675. Birchfield noted that he has funding for eight (8) exams. There are six volunteers who need equipment. Currently the Reserves are using hand-me-down equipment.

• Directors Howe, Karp, Gonser and Williams supports funding $13,400 to the Wasco County Sheriff Reserves, which represents the cost of the equipment for six (6) individuals; Director Smith does not support.

Director Smith noted that he states each year that he does not approve of the economic development program due to the lack of participation in his District directly. Director Smith is opposed again; he does not like the way appropriations are made. Port of The Dalles, $20,000:

• Directors Gonser, Howe, Karp and Williams supported funding $16,000 to the Port of The Dalles; Director Smith does not.


The total costs of the projects supported by members of the Board is $54,860. The Board recessed at 8:06 p.m. to consider individually the dollar amount that they would support to award to the various applicants. At 8:17 p.m. the Board reconvened. Director Howe suggested the following Economic Development Grant allocations:

• Tygh Valley RFPD - $4,960.00

• Wasco County Sheriff Reserves - $13,400.00

• Port of The Dalles - $16,000

• Mid-Columbia Economic Development District - $5,469.55

• Dufur School District - $10,170.45 {{{Director Gonser moved to award Economic Development Grant Funding to the following organizations in the amounts listed: Tygh Valley Rural Fire Protection District, $4,960.00; Wasco County Sheriff Reserves, $13,400.00; Port of The Dalles, $16,000.00; Mid-Columbia Economic Development District, $5,469.55; and Dufur School District, $10,170.45. Director Howe seconded the motion; it was then passed by a vote of four (4) to one (1); Directors Williams, Karp, Howe and Gonser voted yes, while Director Smith voted no.}}} Energy Northwest Executive Board Meeting: Director Smith reported as follows on the Energy Northwest Executive Board Meeting on May 24th in Boise, Idaho:

• The Energy Northwest Executive Board discussed what to do about the newest request from Bonneville Power Administration (BPA) for another regional cooperation debt procedure.

Some discussion occurred after Director Smith suggested that District staff review the meeting materials that he brought back on the BPA proposal. Director Smith would like to have staff’s recommendation on the proposal before the upcoming Energy Northwest Executive Board’s conference call. General Manager Roger Kline commented that he thinks it is a good exercise to have the analysis, but he does not think staff would do it full justice as the economist would do at the Public Power Council (PPC).

ITEMS FROM BOARD MEMBERS


***It was the consensus of the Board of Directors that the District remain neutral on the request from Bonneville Power Administration for a regional cooperation debt procedure***. Oregon People’s Utility Districts Association (OPUDA): Director Smith reported as follows on the recent Oregon People’s Utility Districts Association (OPUDA) Board Meeting:

• OPUDA’s Bylaws, Article VIII Standing and Ad Hoc Committees, was discussed.

• Bonneville Power Administration (BPA) Grid Modification Plan on metering changes is ongoing.

• Northern Tier Transmission Group (NTTG) and ColumbiaGrid may combine.

• Ice Harbor Dam will need to spill a huge amount of water to comply with the order on gas limits.

• BPA has $510 million in reserves.

• On May 18, 2018 the water year was at 127.9.

• The spill charge will be $10.2 million.

• The updated OPUDA Directory was to have been printed on May 30th.

• OPUDA Board members need to come up with ideas on who the Rock Star Award should be presented to at this year’s OPUDA Annual Conference.

• OPUDA received a clean audit.

• Central Lincoln PUD’s budget for 2019 was approved with no increase. Central Lincoln PUD is talking about moving their headquarters.

• Tillamook PUD will have no increase next year. Tillamook moved from a two-year scholarship program to a four-year scholarship program.

• Emerald PUD has installed 3,000 AMI meters. Emerald PUD hopes to have 18,500 AMI meters installed by the end of the year.

Northwest Public Power Association: Director Smith reported as follows:

• Northwest Public Power Association (NWPPA) is in good financial shape.

• NWPPA is looking at $4.4 million in cash.

• NWPPA has received a clean audit.

• Last year, NWPPA had a 5% revenue increase.

BOARD REPORTS / ITEMS FROM BOARD MEMBERS


• NWPPA had $314,000 in surplus. Because of NWPPA’s financial health there is a possible 10% one-time dues reduction in 2019.

• The Idaho National Laboratory has a week-long learning program on cyber security that is free. Director Smith feels that the District should take advantage of the free program.

Energy Northwest:

• Energy Northwest had a successful $2 million bond sale at a good interest rate.

• The Columbia Generation Station’s last outage was caused by a transformer failure. The plant was down for six days.

Director Gonser presented for the Board’s consideration suggested changes to the Oregon People’s Utility Districts Association (OPUDA) Bylaws, Section VIII Standing and Ad Hoc Committees. Copies of the language being proposed by OPUDA and the suggested changes to the Bylaws as proposed by Director Gonser and President Williams are hereto attached and marked as Exhibits 8 and 9. Some discussion occurred regarding the proposed language changes to Section VIII of the OPUDA Bylaws. General Counsel James Foster had two suggestions. Foster suggested that the word “lobbyists” in the Directors’ proposal, Section 1. B., be changed to “lobbyist(s)” and that Section 2 be added to the Directors’ proposal to complete the entire Article VIII Section of the Bylaws. ***It was the consensus of the Board of Directors to support the proposed revised language to the Oregon People’s Utility Districts Association (OPUDA) Bylaws, Section VIII Standing and Ad Hoc Committee, as further revised per General Counsel’s suggestions***.

June 6, PPC Forum - Dan Williams, Howard Gonser, Connie Karp, Clay Smith

and Roger Howe June 7, PPC Executive Committee Meeting - Dan Williams, Howard Gonser,

Connie Karp, Clay Smith and Roger Howe June 7, NWPPA HDL Workshop – Dan Williams, Howard Gonser, Connie Karp,

Clay Smith, Roger Howe and James Foster June 13-14, NWPPA Senior Leadership Skills Series Session 3: Coaching – Clay

Smith and Roger Howe June 22, OPUDA Meeting – Dan Williams, Howard Gonser, Connie Karp, Clay

Smith and Roger Howe

APPROVAL OF FUTURE MEETINGS/TRAVEL/OR RELATED MATTERS


July 17, Strategic Action Plan Work Session, 1-3 p.m. – Dan Williams, Howard Gonser, Connie Karp and Clay Smith

July 20, OPUDA Meeting – Dan Williams, Howard Gonser, Connie Karp and Clay Smith General Counsel James Foster requested the Board’s approval for his attendance at the American Public Power Association (APPA) Legal & Regulatory Conference on October 7 – 10, 2018 in Charleston, South Carolina. ***It was the consensus of the Board of Directors to authorize General Counsel James Foster to attend the American Public Power Association’s Legal & Regulatory Conference in Charleston, South Carolina on October 7-10, 2018***. There being no further business the meeting adjourned at 8:59 p.m. ___________________________________ President ATTEST: _____________________________ Secretary

Tygh Ridge Transmission Pole Replacement

Pat Morehart

Operations & Engineering Manager

kathy-mcbride

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EXHIBIT 1

Trees Inc Recent Line Clearance

kathy-mcbride

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EXHIBIT 2

Tucker McCabe – APPA Lineworker’s Rodeo

kathy-mcbride

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EXHIBIT 3

kathy-mcbride

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EXHIBIT 4

NORTHERN WASCO PUD CONSERVATION POTENTIAL ASSESSMENTJUNE 5, 2018

1

Presented by:

Ted Light, Project [email protected](971) 247-4013

Consulting, Inc.EES

A registered professional engineering and management consulting firm with offices in Kirkland, WA, and Portland, OR

www.eesconsulting.com

kathy-mcbride

Typewritten Text

EXHIBIT 5

PRESENTATION OUTLINE

About EES Consulting

Background

How Savings Will be Achieved

Program Achievements

Results

Summary

Questions?

2

ABOUT EES CONSULTING

Multi-Disciplinary Consulting Firm with Offices in Kirkland, WA and Portland, OR

Completed Numerous Conservation Potential Assessments for NW Utilities

Specialize in Utilizing Models and Methods of NW Power Council’s 5th, 6th, and 7th

Power Plans, Adapting for Utility-Specific Analyses

Working with the Cadmus Group on potential assessment for BPA

Developed “Handbook for Potential Assessments in the Northwest”

Involved in Washington state EIA rules on CPAs

3

BACKGROUND – WHAT IS A CPA?

Estimate of conservation resource potential available in Northern Wasco PUD’s service territory

The conservation potential is:

Technically Possible

Achievable (accounting for market barriers, market maturity)

Cost-Effective

4

BACKGROUND – CHANGES SINCE 2009

New measures: LEDs, Ductless Heat Pumps, Heat Pump Water Heaters*

Natural Gas Prices

New Power Plan – Emphasis on Capacity

• Hourly Load Profiles

• Deferred Generation Capacity value

• Social Cost of Carbon

Updated building stock

Updated financial parameters, specific to Northern Wasco PUD

Program Achievement6

HOW SAVINGS WILL BE ACHIEVED

CPA Model Does Not Predict How Savings Will be Accomplished

Savings Could be Realized Through

• Utility programs

• Utility share of the Northwest Energy Efficiency Alliance’s accomplishments

• State & federal codes and standards

7

NORTHERN WASCO PUD SAVINGS HISTORY

8

0

500

1,000

1,500

2,000

2,500

3,000

3,500

4,000

2012 2013 2014 2015 2016 2017

MW

h

Residential Low-Income Commercial & Industrial

2017 CPA RESULTS

9

Cost Effective Potential - Base Case (aMW)

2-Year 6-Year 10-Year 20-Year

Residential 0.3 0.8 1.4 2.4

Commercial 0.1 0.2 0.5 1.1

Industrial 0.1 0.2 0.2 0.3

Agricultural 0.0 0.0 0.0 0.0

Distribution Efficiency 0.0 0.1 0.2 0.5

Total 0.4 1.3 2.3 4.3

RESULTS – COMPARISON

Comparison of 2009 CPA and 2017 CPA Cost-Effective Potential

10-Year 20-Year

2009 2018 % Change 2009 2018 % Change

Residential 1.3 1.4 7% 2.5 2.4 -7%

Commercial 1.0 0.5 -48% 1.0 1.1 12%

Industrial 1.5 0.2 -85% 1.5 0.3 -81%

Agricultural 0.0 0.0 NA 0.0 0.0 NA

Distribution Efficiency 0.0 0.2 NA 0.0 0.5 NA

Total 3.8 2.3 -39% 5.0 4.3 -15%

BENCHMARKING CHANGES

11

-45%

-40%

-35%

-30%

-25%

-20%

-15%

-10%

-5%

0%

Utility B (2011-2017)

Utility A (2011-2017)

NW PowerCouncil

Utility C (2011-2017)

N Wasco PUD(2009-2017)

Utility D (2011-2017)

12

RESULTS – ANNUAL

0.00

0.05

0.10

0.15

0.20

0.25

0.30

Co

st-E

ffecti

ve a

MW

Residential Commercial Industrial Agricultural Distribution Efficiency

RESIDENTIAL POTENTIAL

13

-

0.02

0.04

0.06

0.08

0.10

0.12

0.14

0.16

2018 2019 2020 2021 2022 2023 2024 2025 2026 2027

aM

W

Water Heating

Lighting

HVAC

Electronics

COMMERCIAL POTENTIAL

14

-

0.01

0.02

0.03

0.04

0.05

0.06

0.07

2018 2019 2020 2021 2022 2023 2024 2025 2026 2027

aM

W

Water Heating

Refrigeration

Motors/Drives

Lighting

HVAC

Food Preparation

INDUSTRIAL POTENTIAL

15

-

0.005

0.010

0.015

0.020

0.025

0.030

0.035

2018 2019 2020 2021 2022 2023 2024 2025 2026 2027

aM

W

Wood

Process Loads

Lighting

Hi-Tech

Energy Management

SUMMARY

District can expect to achieve 0.2-0.3 aMW per year in conservation resources

Lower conservation potential than 2009 assessment, in line with recent achievement

Results show higher sensitivity to avoided cost assumptions

Key Program Areas:

Residential Weatherization

Residential Lighting

Commercial Lighting

Industrial Sector

16

THANK YOU

MEMORANDUM

NORTHERN WASCO COUNTY PEOPLE’S UTILITY DISTRICT

DATE: May 11, 2018 TO: Directors Gonser, Smith, Carp, Williams, Howe, General Counsel Foster & General Manager Kline FROM: Paul Titus, Principal Engineer & Strategic Asset Planner SUBJECT: Reliability Statistics and 2017 APPA eReliability Report Since 2013, the District has used eReliability Tracker, a web-based software offered from American Public Power Association (APPA), to track outages and create reliability metrics. The yearly cost for this subscription service is $100. APPA provides a report at the end of the calendar year that provides reliability indices and compares to other utilities within a region and customer size class. These numbers are used in KPI reporting for benchmarks and for submission towards APPA RP3 application. The District has 10,043 customers which is Class 4, 6,798 – 12,695 customers, with an approximate total of 85 utilities. Also, the District is located within Region 9, which includes Oregon, Washington, Idaho, Montana and Alaska, with 10 utilities. Attached is the 2017 APPA eReliability Report and graphs of past results, which indicate the District has been outperforming in most instances as compared to other utilities. Even with the positive results, capital investment in facilities and resiliency is still needed to provide exceptional customer satisfaction. Thanks, Paul

kathy-mcbride

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EXHIBIT 6

Reliability reflects both historic and ongoing engineering investment decisions within a utility. Proper use of reliability metrics ensures that a utility is not only performing its intended function, but also is providing service in a consistent and effective manner. Even though the primary use of reliability statistics is for self-evaluation, utilities can use these statistics to compare with data from similar utilities. However, differences such as electrical network configuration, ambient environment, weather conditions, and number of customers served typically limit most utility-to-utility comparisons. Due to the diverse range of utilities that use the eReliability Tracker, this report endeavors to group utilities by size and region to improve comparative analyses while reducing differences. Since this report contains overall data for all utilities that use the eReliability Tracker, it is important to consider the effect that a particularly large or small utility can have on the rest of the data. To ease the issues associated with comparability, reliability statistics are calculated for each utility with their respective customer weight taken into account prior to being aggregated with other utilities. This means that all utilities are equally weighted and all individual statistics are developed on a per customer basis.

The aggregate statistics displayed in this report are calculated from utilities that experienced more than two outages in 2017. Also, utilities that experienced no outages this year, or did not upload any data, will have None/Null values in their report for their utility-specific data and were not included in the aggregate analysis.

The aggregate statistics provided in the following sections of the report are based on data from 253 utilities.

Northern Wasco County PUD

I. General Overview

Funded by a grant from the Demonstration of Energy & Efficiency Developments (DEED) Program, the eReliability Tracker Annual Report was created by the American Public Power Association (the Association) to assist utilities in their efforts to understand and analyze their electric system. This report focuses on distribution system reliability across the country and is customized to each utility. The data used to generate this report reflect activity in the eReliability Tracker from January 1, 2017 to December 31, 2017. Note that if you currently do not have a full year of data in the system, this analysis may not properly reflect your utility's statistics since it only includes data recorded as of February 3, 2018; therefore, any changes made after that date are not represented herein.

2

17

60 57

9

45

7

23 25

10

00

10

20

30

40

50

60

70

1 2 3 4 5 6 7 8 9 10Association Region

Count

of

Utilit

ies

Table 1

Customer size range per customer size class

Figure 1

Number of eReliability Tracker utilities per Association region

Your utility belongs to customer size class and region .4 9

This report separates utilities into groups of equal numbers of utilities according to their number of customers served. As seen in Table 1, the customer size distribution of utilities that use the eReliability Tracker is split into five distinct customer size class groups of approximately 85 utilities per group.

Class 1:

Class 2:

Class 3:

Class 4:

Class 5:

0 -1,497

1,498 - 3,126

3,127 - 6,797

12,696 - 650,000

6,798 - 12,695

Figure 2

Association map of regions

Since the utilities considered in this report represent a wide variety of locations across the United States, each utility is also grouped with all others located in their corresponding American Public Power Association region. Figure 1 shows the number of utilities using the eReliability Tracker in each Association region and Figure 2 displays the Association's current United States map of regional divisions.

3

II. IEEE Statistics

When using reliability metrics, a good place to start is with the industry standard metrics found in the IEEE 1366 guide. For each individual utility, the eReliability Tracker performs IEEE 1366 calculations for System Average Interruption Duration Index (SAIDI), System Average Interruption Frequency Index (SAIFI), Customer Average Interruption Duration Index (CAIDI), Momentary Average Interruption Frequency Index (MAIFI) and Average Service Availability Index (ASAI).

When collecting the necessary data for reliability indices, utilities often take differing approaches. Some utilities prefer to include information as detailed as circuit type or phases impacted, while others include only the minimum required. In all cases, the more details a utility provides, the more practical their analysis will be. As a basis for calculating these statistics in the eReliability Tracker, the following are required:

- Total number of customers served on the day of the outage- Start and end date/time of the outage - Number of customers that lost power

Due to the differences in how some utilities analyze major events (MEs) relative to their base statistics, it is important to note how they are calculated and used in this report. An example of a major event could be severe weather, such as a tornado or thunderstorm, which can lead to unusually long outages in comparison to your distribution system's typical outage. In the eReliability Tracker and in this report, the Association's major event threshold is used, which is a calculation based directly on outage events, rather than event days. The major event threshold allows a utility to remove outages that exceed the IEEE 2.5 beta threshold for events, which takes into account the utility's past outage history up to 10 years. In the eReliability Tracker, if a utility does not have at least 36 outage events prior to the year being analyzed, no threshold is calculated; therefore, the field below showing your utility's threshold will be blank and the calculations without MEs in the SAIDI section of this report will be the same as the calculations with MEs for your utility. More outage history will provide a better threshold for your utility.

Your utility's APPA major event threshold is (minutes).6.3997

The tables in this section can be used by utilities to better understand the performance of their electric system relative to other utilities nationally and to those within their region or size class. In the SAIDI section, indices are calculated for all outages with and without major events; furthermore, the data are broken down to show calculations for scheduled and unscheduled outages. For each of the reliability indices, the second table breaks down the national data into quartile ranges, a minimum value, and a maximum value.

If there is no major event threshold calculated for your utility, these fields are left blank and the calculations in this report including Major Events and excluding them will be the same. Your utility must have at least 36 outage events recorded in the eReliability Tracker in order to calculate a Major Event Threshold.

1

1

4

Your utility's SAIDI: 63.5717

448.1083

125.3523100.7792

56.0832

227.6868

461.5984

95.5004 82.8786

179.1688

00

50

100

150

200

250

300

350

400

450

500

1 2 3 4 5 6 7 8 9 10

Association Regions

Ave

rag

e S

AID

I (m

inu

tes)

Average eReliability Tracker SAIDI 161.7605

Average SAIDI for Utilities Within Your Region 179.1688

Average SAIDI for Utilities Within Your Customer Size Class 230.6849

Minimum Value 0.1282

First Quartile (25th percentile) 23.6535

Third Quartile (75th percentile) 120.8739

Median Quartile (50th percentile) 54.863

Maximum Value 5208.0378

Figure 3

Average SAIDI for all utilities that use the eReliability Tracker per region

System Average Interruption Duration Index (SAIDI)

Since SAIDI is a sustained interruption index, only outages lasting longer than five minutes are included in the calculations. SAIDI is calculated by dividing the sum of all customer interruption durations within the specified time frame by the average number of customers served during that period. For example, a utility with 100 customer minutes of outages and 100 customers would have a SAIDI of 1.

Note that in the tables below, scheduled and unscheduled calculations include major events. Also note that wherever major events are excluded, the exclusion is based on the APPA major event threshold.

3.3511

4.4295

10.1163

3.7064

60.2302

157.4675

169.2191

226.9916

0.1282

20.5479

52.3865

114.7618

5199.7198

0

0

0.097

1.3001

208

Unscheduled ScheduledAll

Unscheduled ScheduledAll

Table 3

Summary statistics of the SAIDI data compiled from the eReliability Tracker

Table 2

Average SAIDI for all utilities that use the eReliability Tracker (with and without MEs), belong to

your region, and are grouped in your customer size class

36.5016

62.1498

66.8243

70.9849

No MEs

0.1282

10.6552

27.2189

60.6194

1412.0408

No MEs

SAIDI is defined as the average interruption duration (in minutes) for customers served by the utility system during a specific time period.

5

Your utility's SAIFI: 0.7314

1.3118

0.7409 0.7275 0.69490.8483

1.7043

1.1042

0.6488

0.9241

00

0.2

0.4

0.6

0.8

1

1.2

1.4

1.6

1.8

1 2 3 4 5 6 7 8 9 10

Association Regions

Ave

rag

e S

AIF

I (I

nte

rru

ptio

ns)

Average eReliability Tracker SAIFI 0.8515

Average SAIFI for Utilities Within Your Region 0.9241

Average SAIFI for Utilities Within Your Customer Size Class 0.8991






Figure 4

Average SAIFI for all utilities that use the eReliability Tracker per region

System Average Interruption Frequency Index (SAIFI)

Since SAIFI is a sustained interruption index, only outages lasting longer than five minutes are included in the calculations. SAIFI is calculated by dividing the total number of customer interruptions by the average number of customers served during that time period. For example, a utility with 150 customer interruptions and 200 customers would have a SAIFI of 0.75 interruptions per customer.

Table 5

Summary statistics of the SAIFI data compiled from the eReliability Tracker

Table 4

Average SAIFI for all utilities that use the eReliability Tracker, belong to your region, and are

grouped in your customer size class

SAIFI is defined as the average number of instances a customer on the utility system will experience an interruption during a specific time period.

6

340.985

525.2002

111.453889.589

634.764

151.763895.6323

134.1772171.8783

00

100

200

300

400

500

600

700

1 2 3 4 5 6 7 8 9 10

Association Regions

Ave

rag

e C

AID

I (m

inu

tes)

Figure 5

Average CAIDI for all utilities that use the eReliability Tracker per region

Customer Average Interruption Duration Index (CAIDI)

Since CAIDI is a sustained interruption index, only outages lasting longer than five minutes are included in the calculations. It is calculated by dividing the sum of all customer interruption durations during that time period by the number of customers that experienced one or more interruptions during that time period. This metric reflects the average customer experience (minutes of duration) during an outage.

Your utility's CAIDI: 86.9172

Average eReliability Tracker CAIDI 321.6103

Average CAIDI for Utilities Within Your Region 171.8783

Average CAIDI for Utilities Within Your Customer Size Class 227.8248






Table 6

Average CAIDI for all utilities that use the eReliability Tracker, belong to your region, and are


Table 7

Summary statistics of the CAIDI data compiled from the eReliability Tracker

CAIDI is defined as the average duration (in minutes) of an interruption experienced by customers during a specific time frame.

7

Your utility's MAIFI: 0

0.26730.2283

0.686

0.0197

0.2899

0.6716

0.1806

0.3432

0.0935

00

0.1

0.2

0.3

0.4

0.5

0.6

0.7

0.8

1 2 3 4 5 6 7 8 9 10

Association Regions

Ave

rag

e M

AIF

I (I

nte

rru

ptio

ns)

Average eReliability Tracker MAIFI 0.3515

Average MAIFI for Utilities Within Your Region 0.0935

Average MAIFI for Utilities Within Your Customer Size Class 0.309

Minimum Value 0

First Quartile (25th percentile) 0


Median Quartile (50th percentile) 0


Figure 6

Average MAIFI for all utilities that use the eReliability Tracker per region

Momentary Average Interruption Frequency Index (MAIFI)

In this report, an outage with a duration of less than five minutes is classfied as momentary. The index is calculated by dividing the total number of momentary customer interruptions by the total number of customers served by the utility. Momentary outages can be more difficult to track and many smaller utilities may not have the technology to do so; therefore, some utilities may have a MAIFI of zero.

Table 9

Summary statistics of the MAIFI data compiled from the eReliability Tracker

Table 8

Average MAIFI for all utilities that use the eReliability Tracker, belong to your region, and are


MAIFI is defined as the average number of times a customer on the utility system will experience a momentary interruption.

8

Your utility's ASAI (%): 99.9906

99.9147 99.9761 99.9808 99.9894 99.9566 99.9121 99.9818 99.9849 99.9677

00.00

20.00

40.00

60.00

80.00

100.00

120.00

1 2 3 4 5 6 7 8 9 10

Association Regions

Ave

rag

e A

SA

I (%

)

Average eReliability Tracker ASAI 99.9693

Average ASAI for Utilities Within Your Region 99.9677

Average ASAI for Utilities Within Your Customer Size Class 99.9561






Figure 7

Average ASAI for all utilities that use the eReliability Tracker per region

Average Service Availability Index (ASAI)

This load-based index represents the percentage availability of electric service to customers within the time period analyzed. It is caclulated by dividing the total hours service is available to customers by the total hours that service is demanded by the customers. For example, an ASAI of 99.99% means that electric service was available for 99.99% of the time during the given time period.

Table 11

Summary statistics of the ASAI data compiled from the eReliability Tracker

Table 10

Average ASAI for all utilities that use the eReliability Tracker, belong to your region, and are


ASAI is defined as a measure of the average availability of the sub-transmission and distribution systems that serve customers.

9

2016 Energy Information Administration (EIA) Form 861 Data

EIA surveys electric power utilities annually through EIA Form 861 to collect electric industry data and subsequently make that data available to the public. In 2014, EIA began publishing reliability statistics in their survey from utility participants; therefore, the Association included EIA reliability statistics in this report for informational purposes. Please note that the following data includes investor-owned, rural cooperative, and public power utilities that were large enough to be required to fill out the full EIA 861, not the EIA 861-S form (for smaller entities). In addition, since the collection and release of EIA form data lags by more than a year, the data provided here is based on 2016 data only. Therefore, it is suggested that the aggregate statistics contained herein be used only as an informational tool for further comparison of reliability statistics.

In the table, if an entity calculates SAIDI, SAIFI, and determines major event days in accordance with the IEEE 1366-2003 or IEEE 1366-2012 standard, they are included under the "IEEE Method" columns. If the entity calculates these values via another method, they are included under the "Other Method" columns.

Additionally, it looks as though a number of utilities submitted incorrect data, which shows itself most in the average SAIFI numbers. For more general information on reliability metrics you can see the Association’s website at http://publicpower.org/reliability. Although EIA collected other reliability-related data, the tables below only include SAIDI and SAIFI data. The full set of data can be downloaded at this link: http://www.eia.gov/electricity/data/eia861/

Table 13

Summary statistics of the SAIFI data compiled from 2016 data collected by EIA

Form EIA-861 collects information on the status of electric power industry participants involved in the generation, transmission, distribution, and sale of electric energy in the United States, its territories, and Puerto Rico.

Table 12

Summary statistics of the SAIDI data compiled from 2016 data collected by EIA

All No MEDs All No MEDs

IEEE Method Other Method

All No MEDs All No MEDs

IEEE Method Other Method

128.6160

Minimum Value

First Quartile (25th percentile)

Third Quartile (75th percentile)

Median Quartile (50th percentile)

Maximum Value

Average 314.2593 111.4045210.6055

0.00000.2840 0.17400.1740

54.380081.7025 23.510031.4225

101.9000154.8600 80.900097.0000

164.5150292.7500 153.3400205.1620

1099.07006957.4700 648.00003163.4000

1.2989

Minimum Value

First Quartile (25th percentile)

Third Quartile (75th percentile)

Median Quartile (50th percentile)

Maximum Value

Average 1.6569 1.05751.3222

0.00000.0040 0.00000.0000

0.67000.8800 0.39000.4740

1.07001.3400 0.93001.0540

1.56002.0600 1.44001.7920

28.020029.0000 5.880013.0000

10

Analysis of Miles of Line and Interruptions

Benchmarking metrics were created to help utilities explore the relationship between outages, overhead line exposure, and customer density. More specifically, by using interruptions per overhead mile of line and customers per mile utilities can benchmark reliability against system characteristics along with the customer normalized metrics included in the rest of the report. These system topography-related metrics can be helpful in understanding, for example, utility reliability against weather and animal-related outages relative to similarly dense and exposed utilities.

Table 14

Analysis of overhead miles of line and interruptions

Interruptions per Mile Customers per Mile

Average for eReliability Tracker Utilities

Average for Utilities Within Your Region

Your Utility:

Your utility's overhead miles of line as reported by Ventyx: 198.15

0.3482 50.5678

0.9053 104.7849

0.6005 108.212

11

III. Outage Causes

In general, sustained outages are the most commonly tracked outage type. In many analyses of sustained outages, utilities tend to exclude scheduled outages, partial power, customer-related problems, and qualifying major events from their reliability indices calculations. While this is a valid method for reporting, these outages should be included for internal review to make utility-level decisions. In this section, we evaluate common causes of sustained outages for your utility, corresponding region, and for all utilities that use the eReliability Tracker. It is important to note that in this report, sustained outages are classified as outages that last longer than five minutes, as defined by IEEE 1366.

Sustained Outage Causes

Equipment failure, extreme weather events, wildlife and vegetation are some of the most common causes of electric system outages. However, certain factors, such as regional weather and animal/vegetation patterns, can make a different set of causes more prevalent to a specific group of utilities. The following sections of this report include graphs depicting common causes of outages for your individual utility, all utilities in your region, and all utilities using the eReliability Tracker. The charts containing aggregate information are customer-weighted to account for differences in utility size for a better analytical comparison.

For example, a particularly large utility may have a large number of outages compared to a small utility; in order to avoid skewing the data towards large utilities, the number of cause occurrences is divided by customer size to account for the differences. In the figures below, the data represent the number of occurrences for each group of 1000 customers. For instance, a customer-weighted occurrence rate of "1" means 1 outage of that outage cause per 1000 customers on average in 2017.

Note that the sustained outage cause analysis is more comprehensive than the momentary outage cause analysis due to a bigger and more robust sample size for sustained outages. Regardless, tracking both sustained and momentary outages helps utilities understand and reduce outages. To successfully use the outage information tracked by your utility, it is imperative to classify and record outages in detail. The more information provided per outage, the more conclusive and practical your analyses will be.

12

0.9253

0.5856

0.3765 0.36140.2744

0

0.2

0.4

0.6

0.8

1

Outage Cause Types

Occu

rre

nce

Ra

tes

Figure 9

Top five customer-weighted causes of sustained outages for your utility

Figure 10

Top five customer-weighted occurrence rates for sustained outage causes in your region

1.09780.998

0.79840.6986 0.6986

0

0.2

0.4

0.6

0.8

1

1.2

Outage Cause Types

Occu

rre

nce

Ra

tes

Electrical Failure Tree Unknown Customer Service Utility Maintenance and Repairs

2

2

Equipment Scheduled Tree Storm Bird

Figure 8

Top five customer-weighted occurrence rates for common causes of sustained outages for all

utilities that use the eReliability Tracker Service

1.2187

1.0485 1.0099

0.8259

0.579

0

0.2

0.4

0.6

0.8

1

1.2

1.4

Trees Human Weather Squirrel Unknown

Outage Causes Types

Occu

rre

nce

Ra

tes

2

Tree Unknown Squirrel Equipment Electrical Failure

For each utility, the number of occurrences for each cause is divided by that utility's customer size (in 1000s) to create an occurence rate that can be compared across different utility sizes.

2

13

0 0 0 0 00

0.2

0.4

0.6

0.8

1

Outage Cause Types

Occu

rre

nce

Ra

tes

0.1914

0.0578 0.05220.0383 0.038

0

0.05

0.1

0.15

0.2

0.25

Trees Human Weather Squirrel Unknown

Outage Cause Types

Occu

rre

nce

Ra

tes

Momentary Outage Causes

Figure 11

Top five customer-weighted occurrence rates for common causes of momentary outages for all

utilities that use the eReliability Tracker Service

The ability to track momentary outages can be difficult or unavailable on some systems, but due to the hazard they pose for electronic equipment, it is important to track and analyze momentary causes. In this section, we evaluate common causes of momentary outages for your utility, region and customer size class as well as common causes for all utilities that use the eReliability Tracker. Please note that only outages lasting less than five minutes are classified as momentary, as defined by IEEE 1366.

2

Unknown Utility Maintenance and Repairs

Customer Service Equipment Replacement Equipment

Figure 12

Top five customer-weighted causes of momentary outages for your utility2, 3

None None None None None

If your utility has less than eight momentary outages recorded in the eReliability Tracker, this graph will be blank.3

14

0.0402 0.0385 0.0385

0.0318

0.0251

0

0.01

0.02

0.03

0.04

0.05

Outage Cause Types

Occu

rre

nce

Ra

tes

Figure 13

Top five customer-weighted occurrence rates for momentary outage causes in your region2

Thank you for using the eReliability Tracker, and we hope this report is useful to your utility

in analyzing your system. If you have any questions regarding the material provided in

this report, please contact:

Storm Scheduled Unknown Equipment Tree

Copyright 2018 by the American Public Power Association. All rights reserved.

APPA's Reliability Team

Michael J. HylandAlex HofmannTanzina Islam

Christina OspinaEthan Epstein

American Public Power Association2451 Crystal Drive, Suite 1000

Arlington, VA 22202

[email protected]

15

2013 2014 2015 2016 2017

NWCPUD SAIDI 15.9294 22.0325 58.2888 61.5366 63.5717

Average SAIDI 133.6884 111.6347 97.0148 92.3956 161.7605

Region SAIDI 93.739 281.861 448.1401 151.0079 179.1688

Class SAIDI 201.0751 87.1486 87.4765 85.4668 230.6849

0

50

100

150

200

250

300

350

400

450

500

System Average Interupption Duration Index (SAIDI) -The average interuption duration (in minutes) for customers served by the utility system during a

specific time period - (Customers impacted x Outage Duration / Average of all customers)

NWCPUD SAIDI Average SAIDI Region SAIDI Class SAIDI

2013 2014 2015 2016 2017

NWCPUD SAIFI 0.0893 0.3461 0.7227 0.3762 0.7314

Average SAIFI 0.8056 0.9615 0.7355 0.7961 0.8515

Region SAIFI 0.6607 1.5575 1.3615 0.6521 0.9241

Class SAIFI 1.0026 0.8387 0.5571 0.7013 0.8991

0

0.2

0.4

0.6

0.8

1

1.2

1.4

1.6

1.8

System Average Interupption Frequency Index (SAIFI) -The average number of instances a customer on the utility system will experience an interruption

during a specific time period- (Sum of impacted customers during outage / Average of all customers)

NWCPUD SAIFI Average SAIFI Region SAIFI Class SAIFI

2013 2014 2015 2016 2017

NWCPUD CAIDI 178.4755 63.6616 80.6516 163.5578 86.9172

Average CAIDI 137.6557 108.8292 113.6645 134.3941 321.6103

Region CAIDI 142.4651 162.7736 248.4204 508.2063 171.8783

Class CAIDI 161.156 107.7752 109.2855 116.6985 227.8248

0

100

200

300

400

500

600

Customer Average Interupption Duration Index (CAIDI) -The average duration (in minutes) of an interruption experienced by customers during a specific time

frame - (Customers impacted x Outage duration / Sum of customers impacted)

NWCPUD CAIDI Average CAIDI Region CAIDI Class CAIDI

2013 2014 2015 2016 2017

NWCPUD ASAI 99.997% 99.996% 99.989% 99.988% 99.991%

Average ASAI 99.978% 99.979% 99.982% 99.983% 99.969%

Region ASAI 99.982% 99.954% 99.916% 99.977% 99.968%

Class ASAI 99.962% 99.983% 99.984% 99.984% 99.956%

99.880%

99.900%

99.920%

99.940%

99.960%

99.980%

100.000%

Average Service Availability Index (ASAI) -The measure of the average availability of the sub-transmission and distribution systems that serve

customers

NWCPUD ASAI Average ASAI Region ASAI Class ASAI

Port of The Dalles Marina Electrical Upgrade

Steve Horzynek

Asset/Program Manager – Engineering Team Lead

kathy-mcbride

Typewritten Text

kathy-mcbride

Typewritten Text

EXHIBIT 7

Current Conditions/Issues• Overhead transformer at capacity

• Overhead lines with limited connection options and aged support structures

• Hazards during high water

• No ability to provide required Ground Fault (GFCI) protection

• Very limited service capacity to customers during peak occupancy

• Outages very typical during peak occupancy

Planned Upgrades • New pad mount transformer on shore

• Proper system ground protection

• Increased service capacity providing reliability during peak occupancy

• Industry standard marine electric distribution system

• All conductors mounted to the dock above water line

• Improved lighting

• Provide proper infrastructure against electric shock drowning

THE DALLES MARINA ELECTRICAL SYSTEM REPLACEMENT - 2018

Dock Mounted Distribution Transformer

EATON Lighthouse SS Two Meter Pedestal with light

Rev 1.2 4/19/18

AMENDED AND RESTATED BYLAWS OF

OREGON PEOPLE’S UTILITY DISTRICT ASSOCIATION, INC. ENACTED MAY 11, 2012

ARTICLE VIII Standing and Ad Hoc Committees

Section 1. In order to effectively and efficiently carry out the work and business of the Association, the following Standing Committees shall be appointed by the President:

A. The Budget Committee shall be composed of a representative from each Regular Member PUD. They shall meet prior to the annual meeting in order to prepare a budget for approval at the annual meeting.

B. The Legislative Oversight Committee shall be composed of the Regular

Member’s General Manager or their staff delegate and the President of the Board of Directors. They are charged with working with the OPUDA lobbyist to take legislative action and advise the Board of Directors about legislative activities.

Section 2. The President may appoint such ad hoc committees as the President deems necessary or appropriate from time to time to advance the policies and accomplish the objectives of the Association. The membership and activities of ad hoc committees shall be at the direction of the President. Ad hoc committees shall be created and/or renewed annually at the discretion of the current President.

kathy-mcbride

Typewritten Text

EXHIBIT 8

ARTICLE VIII

STANDING AND AD HOC COMMITTEES

Section 1. In order to effectively and efficiently carry out the work and business of the

Association, the following Standing Committees shall be appointed by the President:

A. The Budget Committee shall be composed of a representative from each Regular

Member PUD. They shall meet/communicate in order to prepare a budget for Board

approval by the end of the calendar year.

B. The Legislative Oversight Committee shall be composed of the Regular Member’s

General Manager or their staff delegate and the President of the Board of Directors.

They are charged to work with the OPUDA lobbyists, devise a legislative plan, seek Board

approval, and carry out necessary actions.

NOTE: THE UNDERLINED INFORMATION ABOVE ARE CHANGES TO THE PROPOSED OPUDA

BY-LAW REVISIONS…

kathy-mcbride

Typewritten Text

EXHIBIT 9

kathy-mcbride

Typewritten Text

31-May-18

Time & Duration

Date Address/Location Cause T off T on Mins # Out Cust Min

5/21/18 4800 Mill Creek Rd Connector pulled apart at transformer. 5/21/2018 13:30 5/21/2018 14:30 60 1 60

5/26/18 4653 Hwy 30Blown Primary fuse. Crew replaced and re-

energized.5/26/2018 5:00 5/26/2018 6:20 80 1 80

5/28/18 3063 Valley View DrSquirrel shorted line at pole, underground

primary. Crew replaced and re-energized.5/28/2018 14:00 5/28/2018 15:30 90 2 180

CustomersGeneral Information

Outage Report

Energy Efficiency Program Summary

Incentive Payments and Credits

Month: May 2018 Fiscal Year: BPA FY17

Efficiency

Incentives BPA EEI

Program Incentives Pd Credits Rec'd Paid FYTD Credit FYTD

Heat Pump Incentive Pd. -$27,400

Heat Pump Credit $20,900

Heat Pump Contractor Pmts -$2,200

Water Heaters Incentive Pd. -$500 -$4,500

Water Heaters Credit $500 $4,500

Weatherization Incentive Pd -$2,255 -$46,988

Weatherization Credit $1,529 $22,258

Appliances Incentive Pd -$300 -$2,490

Appliances Credit $120 $810

Comm. Lighting Incentive Pd -$2,780 -$27,048

Comm. Lighting Credit $2,780 $25,848

CFL, LED, And SH Incentive Pd

CFL, LED, and SH Credit

Energy Smart Grocer (ESG) Pd

ESG Credit

Low Income Weatherization Pd -$85,102 -$382,032

Low Income Weatherization Credit $64,177 $291,396

Low Income Admin Credit $1,303 $7,900

Irrigation Incentive Pd

Irrigation Credit

Admin Credit $529 $21,000

Custom Projects Credit $52,946

Totals -$90,937 $70,937 -$492,658 $447,557 34.4%

May-18 Net Incentives Paid -$20,000

BPA rate period Max Credit Amount - Budget $1,302,664

BPA rate period Max Credit - Budget Remaining $855,106 65.6%

Work Completed in May-18

6/25/2018 Copy of 2018-05 YTD EE Report.xlsx FY Summary


Incentive Payments and Credits

Month: May 2018 Fiscal Year: BPA FY17

Incentives BPA EEI

Program Incentives Pd Credits Rec'dEst. kWh Savings

per Year Paid FYTD Credit FYTD

Heat Pump Incentive Pd. - -$27,400 65,583.8

Heat Pump Credit $20,900

Heat Pump Contractor Pmts -$2,200

Water Heaters Incentive Pd. -$500 1,644.5 -$4,500 14,880.6

Water Heaters Credit $500 $4,500

Weatherization Incentive Pd -$2,255 5,061.8 -$46,988 61,789.9

Weatherization Credit $1,529 $22,258

Appliances Incentive Pd -$300 575.6 -$2,490 3,885.3

Appliances Credit $120 $810

Comm. Lighting Incentive Pd -$2,780 13,973.3 -$27,048 209,415.9

Comm. Lighting Credit $2,780 $25,848

CFL, LED, And SH Incentive Pd - -

CFL, LED, and SH Credit

Energy Smart Grocer (ESG) Pd

ESG Credit

Low Income Wx Pd -$85,102 32,565.4 -$382,032 197,785.4

Low Income Wx Credit $64,177 $291,396

Low Income Admin Credit $1,303 $7,900

Irrigation Incentive Pd

Irrigation Credit

Admin Credit $529 $21,000

Custom Projects Credit - $52,946 224,796.1

Totals -$90,937 $70,937 53,820.6 -$492,658 $447,557 778,137.0

May-18 Net Incentives Paid -$20,000

BPA rate period Max Credit Amount - Budget $1,302,664

BPA rate period Max Credit Amount - Budget Spent $447,557

BPA rate period Max Credit - Budget Remaining $855,106

** = Total Estimated kWh Savings FYTD are annual savings expected to accrue over the measure life and this report

does not include savings from measures implemented in prior years

Work Completed in May-18 Total Est. kWh

Savings per Year

FYTD **

6/25/2018 Copy of 2018-05 YTD EE Report.xlsx FY Summary kWh

6/25/2018 Northern Wasco County PUD

Energy Efficiency Incentives

FY 2014

Program Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Paid FYTD Credit FYTD

Heat Pump Incentive Pd. -$1,000.00 -$7,200.00 -$7,200.00 -$4,000.00 -$1,000.00 -$2,000.00 -$5,000.00 $0.00 -$27,400.00

Heat Pump Credit $800.00 $6,000.00 $5,500.00 $2,700.00 $500.00 $1,500.00 $3,900.00 $0.00 $20,900.00

Heat Pump Contractor Pmts -$160.00 -$680.00 -$1,080.00 -$200.00 -$80.00 $0.00 -$2,200.00

Water Heaters Incentive Pd. -$2,000.00 $0.00 -$500.00 $0.00 -$500.00 -$1,000.00 $0.00 -$500.00 -$4,500.00

Water Heaters Credit $2,000.00 $0.00 $500.00 $0.00 $500.00 $1,000.00 $0.00 $500.00 $4,500.00

Weatherization Incentive Pd -$6,310.25 -$5,484.34 -$3,978.71 -$3,405.00 -$12,233.85 -$9,895.00 -$3,426.36 -$2,254.98 -$46,988.49

Weatherization Credit $2,798.71 $1,821.41 $2,233.46 $1,528.56 $7,528.84 $3,280.90 $1,537.69 $1,528.73 $22,258.30

Appliances Incentive Pd -$405.00 -$345.00 -$375.00 -$435.00 -$30.00 -$420.00 -$180.00 -$300.00 -$2,490.00

Appliances Credit $150.00 $60.00 $150.00 $150.00 $0.00 $120.00 $60.00 $120.00 $810.00

Comm. Lighting Incentive Pd -$600.00 -$1,200.00 -$3,920.00 -$2,597.50 -$10,360.00 -$5,210.00 -$380.00 -$2,780.00 -$27,047.50

Comm. Lighting Credit $600.00 $0.00 $3,920.00 $2,597.50 $10,360.00 $5,210.00 $380.00 $2,780.00 $25,847.50

CFL, LED, And SH Incentive Pd $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00

CFL, LED, and SH Credit $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00

Energy Smart Grocer (ESG) Pd $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00

ESG Credit $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00

Low Income Weatherization Pd -$59,965.00 -$61,337.80 -$49,413.00 -$38,685.00 -$7,325.00 -$29,505.00 -$50,699.04 -$85,102.10 -$382,031.94

Low Income Weatherization Credit $50,220.00 $45,335.00 $37,775.00 $26,640.00 $6,900.00 $26,600.00 $33,749.04 $64,176.80 $291,395.84

Low Income Admin Credit $1,350.20 $1,278.30 $1,186.36 $1,183.13 $266.92 $894.18 $438.11 $1,302.61 $7,899.81

Irrigation Incentive Pd $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00

Irrigation Credit $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00

Admin Credit $774.78 $1,016.85 $9,502.18 $3,618.29 $3,158.25 $1,660.75 $739.76 $528.99 $20,999.85

Custom Projects Credit $0.00 $0.00 $36,518.96 $16,426.83 $0.00 $0.00 $0.00 $0.00 $52,945.79

Custom Projects Pd. -$36,518.96 -$16,426.83 $0.00 $0.00 $0.00 $0.00

Totals -$11,586.56 -$20,215.58 -$5,299.71 -$11,785.02 -$2,434.84 -$7,844.17 -$18,880.80 -$19,999.95 $0.00 $0.00 $0.00 $0.00 -$492,657.93 $447,557.09 34.4%

BPA rate period Max Credit Amount - Budget $1,302,663.56 100.0%

BPA rate period Max Credit Amount - Budget Spent $447,557.09 34.4%

BPA rate period Max Credit - Budget Remaining $855,106.47 65.6%

6/25/2018 Copy of 2018-05 YTD EE Report.xlsx FY Monthly

6/25/2018 Northern Wasco County PUD

Energy Efficiency Incentives

FY 2014

Program Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Total YTD

HE Heat Pumps 0.0 0.0 793.3 3,711.2 793.9 1,459.0 1,330.5 0.0 8,087.8

DHP 2,629.1 19,767.0 19,325.4 2,629.1 0.0 2,629.1 10,516.3 0.0 57,495.9

Water Heaters / HPWH 6,662.5 0.0 1,728.9 0.0 1,555.6 3,289.1 0.0 1,644.5 14,880.6

Weatherization 7,686.9 5,366.1 6,937.6 3,526.3 21,073.9 8,393.7 3,743.6 5,061.8 61,789.9

Appliances 719.5 287.8 719.5 719.5 0.0 575.6 287.8 575.6 3,885.3

Comm. Lighting 1,533.0 47,462.0 48,960.7 14,164.4 55,533.4 25,172.9 2,616.2 13,973.3 209,415.9

CFL, LED & SH 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Low Income Weatherization 34,045.6 31,957.5 29,659.1 29,578.2 6,673.0 22,353.9 10,952.7 32,565.4 197,785.4

Custom Projects 0.0 0.0 159,089.1 65,707.0 0.0 0.0 0.0 0.0 224,796.1

Totals 53,276.6 104,840.4 267,213.6 120,035.8 85,629.8 63,873.1 29,447.2 53,820.6 0.0 0.0 0.0 0.0 778,137.0

*Values are expressed in Estimated kWh savings per year for measures implemented during each month

6/25/2018 Copy of 2018-05 YTD EE Report.xlsx kWh Savings Monthly


Measure Counts

Month:

Program Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep YTD Total

Heat Pumps 1 7 7 4 1 2 5 0 27

Water Heaters 4 0 1 0 1 2 0 1 9

Weatherization 7 6 7 4 6 7 3 4 44

Clothes Washers 5 3 5 5 0 4 2 4 28

Dish Washers 0 0 0 0 0 0 0 0 0

Refrigerators 1 4 0 2 1 4 1 0 13

Comm. Lighting 1 1 2 2 1 2 1 2 12

CFL Bulbs 0 0 0 0 0 0 0 0 0

LED Bulbs 0 0 0 0 0 0 0 0 0

Shower Heads 0 0 0 0 0 0 0 0 0

Energy Smart Grocer 0 0 0 0 0 0 0 0 0

Low Income Weatherization13 14 12 10 2 7 10 18 86

May 2018

6/25/2018 FY Measure Counts

NORTHERN WASCO COUNTY PUD CHECK REGISTER FOR 05/18 PAGE 1PRG. CHKREGTR (CKRA) ACCT 131.20 DESC BANK OF THE WEST GENERAL FUND RUN DATE 06/28/18 08:40 AM

SEQ VOID CHECK BRK DATE VENDOR NAME AMOUNT DESCRIPTION

66338 5/04/18 3 AFLAC 1,663.63 INSURANCE PREMIUMS - APR 2018

66339 5/04/18 2341 BARTELLS, LORI ANN 500.00 HTPMP WTR HTR-BARTELLS-1215 E 12

66340 5/04/18 379 BISHOP SANITATION INC 67.50 9268 TREE SRV 03/20-04/16

66341 5/04/18 20 BOHN'S PRINTING INC 354.75 BUDGET/LEVELIZED POST CARDS POSTERS

66342 5/04/18 2340 BRADFORD, TODD 585.56 WEATHERZTN-BRADFORD-2210 W 13TH

66343 5/04/18 158 CENTURYLINK 53.58 PHONE SERVICE - APRIL 2018

66344 5/04/18 1269 COASTAL FARM & HOME SUPPLY 49.99 FUEL TRANSFER HOSE

66345 5/04/18 666 DISCOVER RENTALS 229.00 GENIE SCISSOR LIFT RENTAL 04/24

66346 5/04/18 118 FOSTER & YOUNG LLP 13,537.21 FILE# 10-0910 GOOGLE 04/2017 FILE #89-0636 GENERAL 04/2018

66347 5/04/18 64 GENERAL PACIFIC INC. 2,046.00 TIE WRAPLOCK, C NECK 4/0-266

66348 5/04/18 1264 GORDON CONSTRUCTION 5,580.00 WEATHERZTN-COMMANDER-1110 ROBERT

66349 5/04/18 695 GORGE GLASS & CONTRACTING 4,613.00 WEATHRZTN-MEDINA-112 W 12TH

66350 5/04/18 555 GORGE MAIL (A-OK PAK & SHIP) 72.68 SHIPPING IDLER SHEAVE

66351 5/04/18 665 GREEN HOME CONSTRUCTION 11,500.00 WEATHRZTN-COMMANDER-1110 ROBERTS WEATHRZTN-MAYA-1418 E 12TH

66352 5/04/18 89 HOME DEPOT CREDIT SERVICES 490.21 WOOD/TAPPING KIT STAND BUILIDNG SUPPLIES BUILDING SUPPLIES

66353 5/04/18 87 KODL RADIO 120.00 ADS: CHERRY FESTIVAL 04/2018

66354 5/04/18 1497 LELEVIER, BERNADETTE 303.00 WEATHERIZTN-LELEVIER-1708 E 14TH

66355 5/04/18 298 MCMASTER-CARR SUPPLY CO 112.43 TORC BIT FOR IMPACT DRIVER FLAT HEAD SCREWS 1/4" HEX SHANK

66356 5/04/18 2144 MOSS ADAMS LLP 10,996.00 PROGRESS BILLING 12/17 FINANCIAL

66357 5/04/18 650 NRECA 8,459.74 INSURANCE PREMIUMS 05/2018

66358 5/04/18 103 NRECA GROUP BENEFITS TRUST 96,229.20 INSURANCE PREMIUMS 05/2018

66359 5/04/18 2141 OSMOSE UTILITIES SERVICES 31,598.34 POLE INSPECTIONS POLE INSPECTIONS



66360 5/04/18 1415 PACER PROPANE, DBA 76.54 PROPANE - TK#52 PROPANE - TK#52 PROPANE - TK#52

66361 5/04/18 429 PACIFIC STATES MARINE 789.25 SMOLT MONITRNG 03/01/18-03/31/18

66362 5/04/18 1716 POWERWORLD CORPORATION 3,666.67 POWER WORLD SIMULATOR LICENSE

66363 5/04/18 292 SAWYERS TRUE VALUE 1,107.19 FUEL HOSE ADAPTER ROLLER KIT/CHAIN LINKS LED BULBS - GIVEAWAY

66364 5/04/18 2338 SERNA, MARK 75.00 CLTHS WSHR RBT-SERNA-1424 E 12TH

66365 5/04/18 417 SPECIAL DISTRICTS INSURANCE 91.00 PROPERTY/AUTO INSURANCE CHANGES

66366 5/04/18 431 STAPLES ADVANTAGE 72.86 AIR DUSTER/DRAWER ORGANIZER/SHAR

66367 5/04/18 144 THE DALLES NAPA AUTO PARTS 2.58 SNAP RINGS - TK#56

66368 5/04/18 2074 TREES, INC. 7,292.90 TREE TRIMMING THRU 04/21

66369 5/04/18 2127 US LINEN & UNIFORM INC 149.02 MAT SERVICE 04/11/18 MAT SERVICE 04/25/18

66370 5/04/18 1317 VERSALIFT NORTHWEST LLC 6,660.29 180 DAY INSPECTION - TK#29 180 DAY INSPECTION - TK#56 180 DAY INSPECTION - TK#23 180 DAY INSPECTION - TK#25 180 DAY INSPECTION - TK#55 AERIAL INSPECTION - TK#29 AERIAL INSPECTION - TK#3 AERIAL INSPECTION - TK#56 AERIAL INSPECTION - TK#23 AERIAL INSPECTION - TK#25 AERIAL INSPECTION - TK#55 AERIAL INSPECTION - GENIE LIFT TRAVEL&EXPENSES ONLY

66371 5/04/18 2330 WELLS, JAMES 132.50 PER DIEM-CO-SAFETY CERT-04/25-27

66372 5/04/18 164 WESCO DISTRIBUTION INC 88,168.15 GUY WIRE/STIRRUP CLAMP/VICTOR VICTOR VI4604 ST INSUL 4/0 ACSR PENGUIN WIRE, GUY 20 M LOAD BREAK CUTOUT/BLADES OKON 161-23-3072 15LV 1/0 220MIL

66373 5/04/18 2339 ZEIGLER, ROBIN & CAROLINE 1,000.00 HEAT PUMP RBT-ZEIGLER-2424 E 11T

66374 5/11/18 11 ALTEC INDUSTRIES INC 777.00 DODGE COMPUTER PROGRAMMING



66375 5/11/18 2190 AMAZON 1,772.19 REPLACEMENT CHAIR WHEELS OFFICE CHAIR SLIP COVERS ERGONOMIC MOUSE-N.ERICKSEN FIT BITS POWER REC SKILLS TEST SUPPLIES FIT BIT

66376 5/11/18 4 AMERICAN PUBLIC POWER 2,410.00 SPRING INSTITUTE 2018 - T. HARDY

66377 5/11/18 2306 AN XSTREAM ELECTRIC LLC 10,080.00 CONSULTING SERVICE T.D. MARINA

66378 5/11/18 561 BASLER ELECTRIC COMPANY 14,205.60 PROGRESS BILLING 30%

66379 5/11/18 20 BOHN'S PRINTING INC 606.94 ADMIN/OFFCE/ENGRG/FA COPIES-APR

66380 5/11/18 473 CDW GOVERNMENT INC 870.10 SSDs FOR PC UPGRADES

66381 5/11/18 2188 CENTRATEL LLC 361.39 ANSWERING SERVICE APRIL

66382 5/11/18 32 CITY OF DUFUR 1,799.79 EXCHANGE OF SERVICE FEE - APR

66383 5/11/18 1803 D HITTLE & ASSOCIATES 2,863.00 ENGRNG-TYGH VALLEY-THRU 04/24/18

66384 5/11/18 2224 DUFUR HISTORICALSOCIETY 100.00 2018 VINTAGE DUFUR DAYS

66385 5/11/18 315 EES CONSULTING INC 2,120.00 CONSERVATION STUDY THRU 04/30/18

66386 5/11/18 992 ELECTRICAL CONSULTANTS INC 29,769.20 ENGINEERING-THE DALLES MARINA

66387 5/11/18 793 FUTURA SYSTEMS INC 1,200.00 04/2018 BILLING

66388 5/11/18 2233 GEISER, GLORIA 100.00 SMARTTHERMOSTAT REBT-2719 E 10TH

66389 5/11/18 64 GENERAL PACIFIC INC. 7,292.00 ALUMA FORM AF8824 COND #4/0 AL UG TX 600V

66390 5/11/18 695 GORGE GLASS & CONTRACTING 6,456.60 WEATHRZTN-VALDIVIA-814 E 13TH WTHRZTN-PENNINGTON-80184 DODSON

66391 5/11/18 555 GORGE MAIL (A-OK PAK & SHIP) 59.58 SHIPPING:HJ ARNETT 04/24/18

66392 5/11/18 665 GREEN HOME CONSTRUCTION 12,950.00 WEATHRZTN-KUIPER-812 E 7TH WEATHERZTN-ANDERSON-389 BOHNA ST

66393 5/11/18 7 H J ARNETT INDUSTRIES LLC 286.43 GLOVE TESTING/GLOVES

66394 5/11/18 302 HATTENHAUER ENERGY CO LLC 305.50 FUEL CHARGES 04/01/18-04/15/18 FUEL CHARGES-04/16/18-04/30/18

66395 5/11/18 454 HRA VEBA TRUST 3,836.37 VEBA ER CONTRIBUTIONS EMP DED - HRA VEBA GRP 1 PRETAX EMP DED - HRA VEBA GRP 2 PRETAX



66396 5/11/18 79 I.B.E.W. LOCAL 125 1,156.34 UNION DUES 05/2018

66397 5/11/18 434 JERRY'S JANITORIAL 5,004.99 JANITORIAL CLEANING FEB 2018 JANITORIAL CLEANING MAR 2018 JANITORIAL CLEANING APR 2018

66398 5/11/18 186 KLICKITAT COUNTY PUD 1,114.02 TRANSMISSION COSTS APR-2018

66399 5/11/18 16 NATIONWIDE TRUST CO FSB 9,131.27 EMP DED - DEF COMP 457B-BRD MEM EMP DED - DEFERRED COMP 457B EMP DED - 457B LOAN

66400 5/11/18 366 NATIONWIDE TRUST CO FSB 19,585.57 EMP BEN EMPLOYER 457B/401K MATCH EMP BEN EMPLOYER 401K MATCH EMP BEN EMPLOYER 457B MATCH EMP DED - 401K LOAN EMP DED - NATIONWIDE 401K

66401 5/11/18 108 NORTHWEST PUBLIC POWER ASSN 3,040.00 TRNG-STAKING TECH CERT/PERMITS E&O CONFERENCE 2018 E&O CONFERENCE 2018

66402 5/11/18 2108 NW NATURAL 361.09 NATURAL GAS 04/03/18-05/02/18 NATURAL GAS 04/03/18-05/02/18

66403 5/11/18 112 ONE CALL CONCEPTS INC 109.20 OR UTILITY NOTIFICATION 04/2018

66404 5/11/18 120 OREGON DEPARTMENT OF REVENUE 451.72 OR DEPT REVENUE - GARNISHMENT

66405 5/11/18 667 OREGON SECRETARY OF STATE 350.00 2017 AUDIT FILING FEE

66406 5/11/18 214 PLATT ELECTRIC SUPPLY INC 2,337.89 PVC 2-1/2-45DEG-24RAD W/BELLE CUTTER CBL-RED/WHT/BLU 3/4X66COD PVC CONDUIT CPLG

66407 5/11/18 2247 POWER MONITORS, INC. 1,863.84

66408 5/11/18 2292 QUALITY LIFE INTERGOVERNMENT 450.00 INTERNET SERVICE

66409 5/11/18 2112 RADCOMP COMPUTERS, INC. 12,913.10 SERVER REPLACEMENT & INFRASTRUCT SERVER REPLACEMENT & INFRASTRUCT REMOTE/HELPDESK-04/2018

66410 5/11/18 137 RURALITE SERVICES INC. 4,084.02 MAGAZINE & WEBSITE - 04/2018

66411 5/11/18 2342 SCHELLINGER, JON 1,126.80 AIIRFARE-ATLANTA-SEDC/FUTURA

66412 5/11/18 1572 SKYBITZ, INC 1,811.81 GPS MONTHLY PLAN - DECEMBER GPS MONTHLY PLAN - JANUARY GPS MONTHLY PLAN - FEBRUARY

66413 5/11/18 450 SMITH, CLAY 367.38 TRAVEL-PDX-PPC-05/02-05/03



66414 5/11/18 1847 SPARKLE CAR WASH, LLC 34.50 CAR WASHES - APRIL

66415 5/11/18 1813 STATE COLLECTION AND 369.23 EMP DED - NEVADA CHILD SUPPORT

66416 5/11/18 2059 TERMINIX INTERNATIONAL 129.00 PEST CONTROL 04/10/18

66417 5/11/18 148 THE DALLES CHRONICLE 1,673.00 DISPLAY AD COLOR/CHERRY FESTIVAL

66418 5/11/18 151 THE DALLES DISPOSAL SERVICE 405.86 GARBAGE 04/01/18-04/30/18

66419 5/11/18 295 THE DALLES FITNESS CLUB 152.90 FITNESS CLUB DUES 05/2018

66420 5/11/18 1811 URSPRUNG, KATHY 570.00 MAGAZINE COSTS 05/2017

66421 5/11/18 1317 VERSALIFT NORTHWEST LLC 267.50 180 DAY INSPECTION - TK#3

66422 5/11/18 2025 VISTA SANITATION 300.00 TD HYDRO PORTABLE TOILETS

66423 5/11/18 1365 WASCO COUNTY 1,906.91 FUEL CHARGES 03/01/18-03/31/18

66424 5/11/18 162 WASCO ELECTRIC COOPERATIVE 50.50 ENDRSBY CUTOFF 03/12/18-04/12/18

66425 5/11/18 743 WILLIAMS, DAN 367.38 TRAVEL-PDX-PPC-05/02-05/03

66426 5/11/18 1345 WORRELL, RILEY J 9,775.00 WEATRZTN-BROWN-1132 STARLIGHT WEATHRZTN-GARCIA-4109 CHEN #E14

66427 5/11/18 1812 WYOMING CHILD SUPPORT 318.46 EMP DED - WYOMING CHILD SUPPORT

66428 5/18/18 2190 AMAZON 508.84 MAGENTIC WHITEBOARD/STANCHIONS

66429 5/18/18 2306 AN XSTREAM ELECTRIC LLC 472.00 CONSULTING SERVICE T.D. MARINA

66430 5/18/18 551 BICOASTAL MEDIA LLC 275.00 ADS: CHERRY FESTIVAL 04/2018

66431 5/18/18 1156 CABLE HUSTON BENEDICT 12,720.00 GOOGLE ANALYSIS/SURETY BOND

66432 5/18/18 150 CITY OF THE DALLES 279.33 WATER & SEWER 03/09/18-04/10/18

66433 5/18/18 583 CLEARESULT CONSULTING, INC 400.00 APP PROC-HEATPUMP 04/01-04/30/18

66434 5/18/18 1269 COASTAL FARM & HOME SUPPLY 59.96 VESTS (4)

66435 5/18/18 2346 COLUMBIA CINEMAS 820.00 WATTAGE RDCTN-CINEMAS-2727 W 7TH

66436 5/18/18 99000405 COUSINS RESTAURANT 2,752.12 BANQ OFFSITE DINNER 4/2/18 BANQ OFFSITE DINNER 4/2/18 BANQ OFFSITE DINNER 4/2/18 BANQ OFFSITE DINNER 4/6/18 BANQ OFFSITE BRKFST 4/18/18 BANQ OFFSITE BRKFST 4/19/18 BANQ OFFSITE DINNER 4/18/18



66437 5/18/18 344 CRESTLINE CONSTRUCTION LLC 43,478.58 TRACT B REGRADE

66438 5/18/18 571 DEVCO MECHANICAL INC. 119.30 WEATHERZTN-HERNANDEZ-771 FLORAL

66439 5/18/18 1223 FP MAILING SOLUTIONS 216.00 POSTBASE RENTL 05/07/18-08/06/18

66440 5/18/18 2345 GARCIA, ELIZABETH 75.00 CLOTHES WSHR-GARCIA-619 WASCO DR

66441 5/18/18 66 GONSER, HOWARD 89.93 TRAVEL-PDX-PPC-05/02

66442 5/18/18 695 GORGE GLASS & CONTRACTING 6,245.80 WTHRZTN-COLTON-84289 HWY216 WTHRZTN-LERMA-4109 CHEN #D30

66443 5/18/18 1968 HALL, HARVEY 73.92 TRAVEL-SKAMANIA-LEADERSHIP-05/08

66444 5/18/18 2305 HERZIG ENGINEERING 6,000.00 FACILTY ARC FLASH ANALYSIS

66445 5/18/18 2186 INTERFACING TECHNOLOGIES COR 31,200.00 EPC SAAS SOLUTION - ANNUAL FEE

66446 5/18/18 1915 KLINE, ROGER 155.00 TRAVEL-PDX-NRU/PPC-05/02-05/04

66447 5/18/18 2000 LOOMIS 331.30 ARMORED CAR SERVICE

66448 5/18/18 2322 MAKE IT HAPPEN, LLC 2,975.00 CONSULTING SERVICES THRU 04/30/1

66449 5/18/18 2087 MARLIN BUSINESS BANK 1,011.45 COPIER LEASE - APRIL

66450 5/18/18 668 MID COLUMBIA HEALTH 300.00 HOLE SPONSORSHIP GOLF TOURN 2018

66451 5/18/18 1416 OS ENGINEERING 1,045.00 TROUBLESHOOTING TDF

66452 5/18/18 1415 PACER PROPANE, DBA 22.72 PROPANE - TK#52

66453 5/18/18 429 PACIFIC STATES MARINE 4,562.71 FINAL BILL 2017 CONTRACT SMOLT MONITRNG 04/01/18-04/30/18

66454 5/18/18 214 PLATT ELECTRIC SUPPLY INC 75.59 ELECTRICAL SUPPLIES ELECTRICAL SUPPLIES POWERHOUSE SUPPLIES

66455 5/18/18 2039 PORT OF THE DALLES 600.00 MAY LEASE DESIGN LLC TLK

66456 5/18/18 2299 POWERS, SUE 92.65 MILEAGE-OR PROCUREMENT TRAINING

66457 5/18/18 2112 RADCOMP COMPUTERS, INC. 2,543.90 OFFICE 365 - APRIL

66458 5/18/18 292 SAWYERS TRUE VALUE 37.95 TRUFUEL

66459 5/18/18 1378 SCHWABE, WILLIAMSON & WYATT 682.50 LEGAL SERIVCES-AUDIT-04/30/18

66460 5/18/18 1981 SELECTEMP 10,349.88 CONSULTANT-THOMPSON-THRU 04/22 GUIDINGER TDF CONSULTATION



CONSULTANT-THOMPSON-THRU 04/29 GUIDIINGER, ROBERT CONSULTANT-THOMPSON-THRU 05/06

66461 5/18/18 456 SPARTAN PROMOTIONAL GROUP 902.68 CARD MAGNETS LATEX BALLONS WITH IMPRINT

66462 5/18/18 431 STAPLES ADVANTAGE 7.40 EXPO LOW ODOR DRY ERASE MARKERS

66463 5/18/18 472 TENNESON ENGINEERING CORP 7,654.17 WO#15018/SURVEYORCREW/TYGHVALL

66464 5/18/18 99001820 TENOLD, RICHARD 1,000.00 HEAT PUMP RBT-TENOLD-2108 LEWIS

66465 5/18/18 626 TRIAXIS ENGINEERING INC 2,720.00 QUENETT CREEK SUBSTATION TO TLK1

66466 5/18/18 375 U.S. CELLULAR, DBA 56.45 SUBSTATION CELLULAR MODEM

66467 5/18/18 2116 WHISTLE WORKWEAR 163.40 FR HI VIS CLOHING FOR 2018

66484 * 5/25/18 2100 AGUILAR, ADAM 25.00 2018 LOGO CLOTHING

66485 5/25/18 1166 ALL DIESEL TRUCK & 322.78 CHECK HYDRAULIC LEAK UNDER CAB

66486 5/25/18 1883 ANIXTER POWER SOLUTIONS LLC 16,142.36 WASHER/GUYLINK/BRACE/ANCHROD GUY LINK ASSEMBLY/ANCH ROD SERV-ENS SLEEVES PINK TO PINK INSU 55-5 F-NECK HL PIN TYPE TOOL CUTTER W/CRIMP HEAD CONN LUG 4POS NUT SQ 3/8 ADAPTER/CU TP XFMR/BOLT MACH XARMS BRACE BRACE CROSSAMRS WASHER LOCK&ROUND/BOLT MACH CLEVIS THIMBLE 1-3/8 INSU GUY STRAIN BOLT OVALEYE/MACH/RODGROUND

66487 5/25/18 230 AT&T MOBILITY 1,026.13 GROUP CELL CHARGES 03/24-04/23 HORZYNEK CELL CHARGS 03/24-04/23

66488 5/25/18 658 BARRAN LIEBMAN LLP 1,835.00 FILE#708395.2 RETRMNT THRU 04/30 FILE#708395.1 GEN THRU 04/30

66489 5/25/18 2088 BISHOP TOWING & REPAIR LLC 733.61 LUBE/OIL/FILTER TK#3 LUBE/OIL/FILTERS TK#55

66490 5/25/18 20 BOHN'S PRINTING INC 108.50 500 N2N POST CARDS

66491 5/25/18 157 CASH & CARRY(UNITED GROCERS) 46.72 TBL CVR/NAPKIN/PUPPLE TBLC

66492 5/25/18 2267 DIRECTV, LLC 30.52 TV SERVICES 04/04/18-06/03/18



66493 5/25/18 1106 DOWERS, DON 25.00 2018 LOGO CLOTHING

66494 5/25/18 2335 ENERGY AND ENVIRONMENTAL 21,146.64 DEVELOPE LARGE USER ANALYSIS

66495 5/25/18 1957 FAIRFIELD INN & SUITES 1,502.04 ACCOMODATIONS FONTICELLO, MATIAS

66496 5/25/18 173 FASTENAL 19.34 ADHESIVE WASHERS

66497 5/25/18 2337 FOXIT CORPORATION 1,393.20 FOXIT PRO LICENSE

66498 5/25/18 64 GENERAL PACIFIC INC. 694.50 TIE WRAPLOCK WTC-0125 GROUND WIRE MOLDING

66499 5/25/18 1962 GENTRY, CYNTHIA 428.66 TRAVEL-PDX/SAN DIEGO-WEI/SANS-05

66500 5/25/18 175 GILLS POINT S 693.04 4 TIRES FOR TK#53

66501 5/25/18 695 GORGE GLASS & CONTRACTING 5,635.80 WEATHERZTN-COLTON-84286 HWY 216 WEATHRZTN-LAMOREAUX-3231 W 7TH

66502 5/25/18 555 GORGE MAIL (A-OK PAK & SHIP) 44.96 RETURN SHIMS TO MCMASTER-CARR

66503 5/25/18 1743 HARDY, TRAVIS 589.22 TRAVEL-DENVER-APPA-05/13-05/19

66504 5/25/18 2348 HAREN, BARBARA 75.00 CLOTHES WSHR-HAREN-2317 W 13TH

66505 5/25/18 1802 HENDRICKS, GREG 25.00 2018 LOGO CLOTHING

66506 5/25/18 454 HRA VEBA TRUST 3,836.37 VEBA ER CONTRIBUTIONS EMP DED - HRA VEBA GRP 1 PRETAX EMP DED - HRA VEBA GRP 2 PRETAX

66507 5/25/18 1308 HUFF, GEORGE A 25.00 2018 LOGO CLOTHING

66508 5/25/18 2186 INTERFACING TECHNOLOGIES COR 18,750.00 EPC SERVICES

66509 5/25/18 219 INTERNATIONAL LINE BUILDERS 191,504.90 TYGH VALLEY REBUILD THRU 05/02 TYGH VALLEY REBUILD WORK

66510 5/25/18 2058 JACOB AIR 4,265.00 HEATPUMP-DUREE-80342 WAMIC MARKT

66511 5/25/18 186 KLICKITAT COUNTY PUD 266.66 ACTUAL CHARGES 05/07/2018

66512 5/25/18 770 MARTINSON, RICK 286.21 WEATHRZTN-MARTINSON-301 W 12TH

66513 5/25/18 16 NATIONWIDE TRUST CO FSB 9,201.27 EMP DED - DEFERRED COMP 457B EMP DED - DEF COMP 457B-BRD MEM EMP DED - 457B LOAN

66514 5/25/18 366 NATIONWIDE TRUST CO FSB 19,593.47 EMP BEN EMPLOYER 401K MATCH EMP BEN EMPLOYER 457B MATCH



EMP DED - 401K LOAN EMP DED - NATIONWIDE 401K

66515 5/25/18 2110 NORTHWEST LINEMAN COLLEGE 5.00 LCP DISTANCE PROGRAM-MCCABE

66516 5/25/18 108 NORTHWEST PUBLIC POWER ASSN 7,300.00 WAREHOUSE/INVENTORY-03/21-TACOMA NWPPA S. POWERS 04/10/18 NWPPA S. POWERS 03/21/18 NWPPA CONFERENCE 05/20/18 NWPPA S. POWERS 05/15/18 HDL WORKSHOP-BOARD/COUNSEL-06/07

66517 5/25/18 2061 OLIVER, DON & JUNE 1,960.00 WATTGE RDCTN-OLIVERS-414 FEDERAL

66518 5/25/18 120 OREGON DEPARTMENT OF REVENUE 482.39 OR DEPT REVENUE - GARNISHMENT

66519 5/25/18 99001375 ORTEGA, EDUARDO 25.00 2018 LOGO CLOTHING

66520 5/25/18 2141 OSMOSE UTILITIES SERVICES 47,452.62 POLE INSPECTIONS POLE INSPECTIONS POLE INSPECTIONS

66521 5/25/18 214 PLATT ELECTRIC SUPPLY INC 153.75 1COND TERM/10AWG WIRE/CABLE TIE 10AWG WIRE 10" ANGLES/CURVED BLD PCKT/SCR H

66522 5/25/18 2299 POWERS, SUE 674.74 TRAVEL-MISSOULA-NWPPA-05/14-17

66523 5/25/18 2112 RADCOMP COMPUTERS, INC. 400.00 RUGGED DISPLAY PORT DESK DOCK

66524 5/25/18 2271 RON TONKIN TOYOTA 71,901.72 2018 TOYOTA 4RUNNER-TK#62 2018 TOYOTA 4RUNNER-TK#63

66525 5/25/18 137 RURALITE SERVICES INC. 3,997.31 MAGAZINE & WEBSITE - 05/2018

66526 5/25/18 1981 SELECTEMP 3,614.60 CONSULTATION FEES CONSULTANT-THOMPSON-THRU 05/13 GUIDINGER, ROBERT

66527 5/25/18 703 SPECIALTY ENGINEERING INC 11,138.20 REGULATOR MAINTENANCE-10TH ST

66528 5/25/18 1813 STATE COLLECTION AND 369.23 EMP DED - NEVADA CHILD SUPPORT

66529 5/25/18 1329 STULL, RAY 25.00 2018 LOGO CLOTHING

66530 5/25/18 524 SUPPLYWORKS 985.28 JANITORIAL SUPPLIES

66531 5/25/18 144 THE DALLES NAPA AUTO PARTS 39.96 PREMIUM BLUE DIESEL FUILD

66532 5/25/18 581 TITUS, PAUL 466.45 TRAVEL-DENVER-APPA-05/13-05/19

66533 5/25/18 2074 TREES, INC. 23,555.30 TREE TRIMMING THRU 04/28



TREE TRIMMING THRU 05/05 TREE TRIMMING THRU 05/12

66534 5/25/18 1365 WASCO COUNTY 2,712.06 FUEL CHARGES 04/01/18-04/30/18

66535 5/25/18 164 WESCO DISTRIBUTION INC 14,225.42 STAND OFF BRACKET 15" SQUEEZ-ON 421-82 GUY GUARD/STIRRUP CLAMP/COMP TER STAPLES 2 X 5/8 X .162 LOADBREAK 100AMP CUTOUT PENCELL PE BOX & LID/DOME

66536 5/25/18 2116 WHISTLE WORKWEAR 19,378.86 FR HI VIS CLOHING FOR 2018 FR HI VIS CLOHING FOR 2018

66537 5/25/18 743 WILLIAMS, DAN 380.63 TRAVEL-SALEM-OPUDA-05/17-05/18

66538 5/25/18 1345 WORRELL, RILEY J 4,480.00 WEATHRZTN-LAMOREAUX-3231 W 7TH

66539 5/25/18 1812 WYOMING CHILD SUPPORT 318.46 EMP DED - WYOMING CHILD SUPPORT

66540 5/25/18 602 YEOMAN, JAMES E 25.00 2018 LOGO CLOTHING

TOTAL CHECKS 187 TOTAL AMOUNT 1,139,661.15


SEQ VOID ACH SEQ BRK DATE VENDOR NAME AMOUNT DESCRIPTION

1215 5/03/18 949 BONNEVILLE POWER 1,614,558.00 BPA POWER BILL 03/2018

1216 5/03/18 949 BONNEVILLE POWER 235,028.00 BPA TRANSMISSION BILL 03/2018

1223 * 5/01/18 904 OREGON DEPARTMENT OF REVENUE 9,824.14 PAYROLL TAXES

1224 5/01/18 872 IRS 40,605.38 PAYROLL TAXES

1234 * 5/17/18 22 OREGON DEPARTMENT OF JUSTICE 2,777.54 EMP DED - OREGON CHILD SUPPORT

1235 5/15/18 872 IRS 40,941.47 PAYROLL TAXES

1237 * 5/15/18 904 OREGON DEPARTMENT OF REVENUE 9,972.49 PAYROLL TAXES

1240 * 5/18/18 1723 CHELAN COUNTY PUD 636,744.00 POWER PURCHASED - CHELAN 04/2018

1241 5/24/18 22 OREGON DEPARTMENT OF JUSTICE 2,777.54 EMP DED - OREGON CHILD SUPPORT

1242 5/29/18 904 OREGON DEPARTMENT OF REVENUE 10,155.69 PAYROLL TAXES

1245 * 5/25/18 400 WASHINGTON STATE DEPARTMENT 3,058.98 USE TAX 04/01/18-04/30/18 GEN

1247 * 5/10/18 2011 US BANK ONE CARD 19,023.04 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16 VISA CARD PURCHASES 03/17-04/16

1248 5/10/18 636 NIES 32,922.00 MARKET PURCH/REMARKETING CR/TRNF



1251 * 5/29/18 872 IRS 42,121.74 PAYROLL TAXES

TOTAL DRAFTS 14 TOTAL AMOUNT 2,700,510.01

GRAND TOTAL 201 GRAND TOTAL AMOUNT 3,840,171.16

PGM. CHECKREG BILLING CHECK REGISTER RUN DATE 06/28/18 08:42 AM NORTHERN WASCO COUNTY PUD PAGE 1

CHECK CHECK CHECK PAID UNDEV VOID MBRSEP NAME NUMBER CHECK AMT DATE TYPE DATE CODE CODE

49094-001 AMES KRISTI JANINE 66468 181.28 51818 SG 52918 67543-002 ANDREWS JAMES LAWRENCE 66469 58.37 51818 SG 52918 68365-001 BROGAN SAM WILEY 66470 115.68 51818 SG 52339-004 GARCIA FRANCISCO JAVIER 66471 9.38 51818 SG 67116-001 GOODENOUGH PROPERTIES LLC 66472 61.56 51818 SG 52518 66479-001 HACHA CARMEN 66473 23.72 51818 SG 68371-001 MERSEREAU MICHAEL ALLEN 66474 99.17 51818 SG 53018 55432-002 MIDDLETON JOHN L 66475 196.27 51818 SG 44531-002 PUTNAM ABBY FAYE 66476 56.95 51818 SG 53018 60283-014 RESOURCES NW INC 66477 116.74 51818 SG 52518 57539-004 ROSS VICKIE 66478 99.33 51818 SG 53018 67474-001 SODEN STEPHEN JOEL 66479 86.44 51818 SG 52918 67405-001 TACHELLA RAMSEY A 66480 120.15 51818 SG 52318 65282-002 GARZA NINO RAMON 66481 176.66 51818 MN 52518 65298-001 TAYLOR SHAWNA 66482 142.37 51818 MN 52118

TOTALS 15 1544.07

NORTHERN WASCO COUNTY PUD CHECK REGISTER FOR 05/18 PAGE 1PRG. CHKREGTR (CKRA) ACCT 131.40 DESC BANK OF THE WEST MCNARY OP FUND RUN DATE 06/28/18 08:40 AM


8120 5/04/18 2100 AGUILAR, ADAM 265.26 NWHA HOOD RIVER 2018

8121 5/04/18 118 FOSTER & YOUNG LLP 2,755.28 FILE #15-1204 MCNARY PRJ 04/2018

8122 5/11/18 169 EASTERN OREGON TELECOM LLC 726.78 PHONE & INTRNT SRVCS 05/01-05/30

8123 5/11/18 1969 JIMMYS JOHNS PORTBLE TOILETS 240.00 PORTABLE TOILETS 4/01-04/30 2018

8124 5/18/18 2305 HERZIG ENGINEERING 3,500.00 MCNARY ARC FLASH ANALYSIS

8125 5/18/18 89 HOME DEPOT CREDIT SERVICES 178.66 HOUSEKEEPING SUPPLIES

8126 5/18/18 335 NORTH COAST ELECTRIC CO 731.82 SYL QHE/WIRE NUTS FLOODLIGHT 105W SYL QHE-2X32T8

8127 5/18/18 711 OXARC INC 160.75 ANNUAL MAINTENANCE FIRE EXTINGUI CYLINDER RENTAL

8128 5/18/18 324 SMITTYS ACE HARDWARE 19.99 TRASH CAN

8129 5/25/18 647 A-1 INDUSTRIAL HOSE & SUPPLY 1,473.53 HYDRAULIC HOSE HPU DESIGN/FAB

8130 5/25/18 230 AT&T MOBILITY 26.75 MCNARY HYDRO 03/24-04/23

8131 5/25/18 1568 BLUE MTN BOTTLED WATER INC 20.00 (3) 5 GAL WATER BOTTLE

TOTAL CHECKS 12 TOTAL AMOUNT 10,098.82

NORTHERN WASCO COUNTY PUD CHECK REGISTER FOR 05/18 PAGE 2PRG. CHKREGTR (CKRA) ACCT 131.40 DESC BANK OF THE WEST MCNARY OP FUND RUN DATE 06/28/18 08:40 AM


1225 5/01/18 872 IRS 168.79 PAYROLL TAXES

1236 * 5/15/18 872 IRS 212.87 PAYROLL TAXES

1244 * 5/29/18 872 IRS 524.63 PAYROLL TAXES

1246 * 5/25/18 400 WASHINGTON STATE DEPARTMENT 2,372.09 USE TAX 04/01/18-04/30/18 MCN

TOTAL DRAFTS 4 TOTAL AMOUNT 3,278.38

GRAND TOTAL 16 GRAND TOTAL AMOUNT 13,377.20

2018 2017 NO. OF CUSTTHIS MONTH YTD YTD THIS MONTH

1. SINGLE PHASE SERVICE 8,420,091 67,771,236 79,273,084 9,384 4. THREE PHASE SERVICE 1,361,205 7,397,871 8,171,900 458 5. DEMAND SERVICE 5,519,295 27,773,926 27,534,858 161 6. PRIMARY SERVICE 42,796,548 193,041,343 140,561,427 13 8. IRRIGATION 121,852 162,275 104,350 51 9. PUBLIC STREET LIGHTING 40,939 199,265 190,130 2 11. SECURITY LIGHTS & OTHER MISC. 89,000 456,535 479,602 n/a

12. TOTAL 58,348,930 296,802,451 256,315,351 10,069

ENERGY GENERATED, PURCHASED, AND INTERCHANGED 2018 2017THIS MONTH YTD YTD

Generation for station use (kWH)The Dalles Scheduled Net Generation (excluding station use) 3,224,000 14,856,000 14,860,000The Dalles Actual Net Generation (excluding station use) 3,338,320 15,914,540 13,981,480Generation Imbalance: The Dalles bought/(sold) (114,320) (1,058,540) 878,520McNary Scheduled Net Generation (excluding station use) 2,606,000 12,504,000 8,805,000McNary Actual Net Generation (excluding station use) 2,405,652 12,676,107 9,181,505Generation Imbalance: McNary bought/(sold) 200,348 (172,107) (376,505)

Environmental Displacement McNary 0 0 0

Purchased energy: Bonneville Power Administration - PF 44,946,918 236,742,483 166,742,056 Bonneville Power Administration - Short Term Rate 543,864 2,648,413 728,223 Non-Federal Resources 19,344,000 91,319,000 79,706,000

Total purchases and generation 70,664,782 358,069,896 270,841,279

Disposition of energy generated and purchased:

Total sales of electric energy 61,572,930 311,658,451 271,175,351

Energy used by electric utility (excluding station use) 32,149 241,654 267,394

Total energy accounted for 61,605,079 311,900,105 271,442,745

Total energy losses--Distribution 891,417 (2,362,808) (601,466)

Energy generated and purchased 62,496,496 309,537,297 270,841,279

MAY 2018

MONTHLY FINANCIAL AND OPERATING REPORT

NORTHERN WASCO COUNTY PUD FOR THE MONTH ENDING MAY 2018

KWH SOLD

ELECTRIC ENERGY STATEMENTNORTHERN WASCO COUNTY PUD

BPA KWH Report 6/28/2018 - 1:15 PM1

MARKET VALUE YIELD MATURITY

136.8 LOCAL GOV'T POOL $17,571,529.04 2.1000 RATE CHANGES

DAILY

TOTAL LOCAL GOV'T POOL $17,571,529.04 2.1000

136.83 CORPORATE DEBT

Bank of America na $0.00 1.450 5/12/2018

Bank of Novia Scotia $497,134.42 2.050 6/5/2019

Federal Home Loan Banks $995,900.00 2.000 9/13/2019

JPMorgan Chase & Co $994,028.68 1.850 3/22/2019

Royal Bank of Canada $946,628.00 1.600 3/15/2019

Toronto-Dominion Bank $996,218.36 1.550 1/22/2019

Wells Fargo & Company $495,419.10 1.750 5/24/2019

TOTAL CORPORATE DEBT $4,925,328.56 2.042

136.00 TOTAL INVESTMENTS $22,496,857.60

RESTRICTED RESERVES:

Rate Stabilization Fund 4,600,000$

2016 Bond Reserve Fund 796,175$

Construction Funds-2016 Bonds 3,284,165$

TOTAL RESTRICTED RESERVES 8,680,340$

COMMITTED RESERVES:

Working Capital $2,000,000

Contingency & Emergency Preparedness $1,000,000

Hydro $578,987

Capital Imprv & Major Capital Projects $500,000

Market Security & Collateral $3,500,000

OPEB Liability Reserve Fund $289,496

Customer Deposits and Interest $3,995,097

TOTAL COMMITTED RESERVES 11,863,580$

UNCOMMITTED RESERVES 1,952,937$

TOTAL INVESTMENTS 22,496,858$

INVESTMENT BALANCE

5/31/2018

INVEST 2018.05 6/29/2018 - 9:55 AM2

* * * NORTHERN WASCO PUD * * *STATEMENT OF NET POSITION

For Period Ending

Current Year Last YearCurrent month Current monthY-T-D Amount Y-T-D Amount

ASSETS AND OTHER DEBITS

PROPERTY ACCOUNTS:

ELECTRIC PLANT 85,759,494.82 66,352,054.91 CONSTRUCTION WORK IN PROGRESS 2,242,146.86 10,831,939.47

TOTAL PROPERTY 88,001,641.68 77,183,994.38 LESS: DEPRECIATION & AMORTIZATION (42,949,116.05) (39,552,353.12)

DEPRECIATED COST OF UTILITY PLANT 45,052,525.63 37,631,641.26 INVESTMENT & FUND ACCOUNTS:OTHER INVESTMENTS-BOND RESERVES - - FISHERIE'S MITIGATION TRUST FUND 1,645,775.05 1,797,576.94

TOTAL INVESTMENTS & FUND ACCOUNTS 1,645,775.05 1,797,576.94

CURRENT & ACCRUED ASSETS:

CASH 3,635,695.00 2,638,267.26 US BANK TRUST, 2012 BOND FUND - MCNARY 237,520.58 250,174.40 US BANK TRUST, 2016 BOND FUND 238,156.25 292,402.95 TEMPORARY INVESTMENTS-GENERAL FUND 22,496,857.60 24,140,002.79 ACCOUNTS RECEIVABLE CUSTOMERS 2,979,210.26 2,308,883.12 LESS RESERVE (91,665.10) (92,926.39) ACCOUNTS REC. CUSTOMER - NET 2,887,545.16 2,215,956.73 UNBILLED REVENUE 799,980.89 - OTHER ACCTS & NOTES REC. - NET 999,536.82 955,392.37 MATERIALS & SUPPLIES 683,811.93 641,128.52 PREPAYMENTS 417,504.10 292,441.80 OTHER CURRENT & ACCRUED ASSETS 18,837.66 (17,293.88)

TOTAL CURRENT & ACCRUED ASSETS 32,415,445.99 31,408,472.94

DEFERRED DEBITS:

CLEARING ACCOUNTS 207,082.12 672.00 OTHER DEFERRED DEBITS - - PS & I - MCNARY 2,815.00 2,815.00 AMORT OF DEBT EXPENSES - - BPA CONTRIBUTION TO MCNARY PROJECT 12,310,210.85 13,886,876.91

TOTAL DEFERRED DEBITS 12,520,107.97 13,890,363.91

TOTAL ASSETS & OTHER DEBITS 91,633,854.64 84,728,055.05

May 31, 2018

NWBS Balance Sheet 05.31.18 6/29/2018 - 11:12 AM3

* * * NORTHERN WASCO PUD * * *STATEMENT OF NET POSITION

For Period Ending

Current Year Last YearCurrent month Current monthY-T-D Amount Y-T-D Amount

May 31, 2018

LIABS & EARNED SURPLUS LONG-TERM DEBT:

BONDS PAYABLE 2012A 7,520,000.00 7,520,000.00 BONDS PAYABLE 2012B 2,415,000.00 5,310,000.00 BONDS PAYABLE 2016 REVENUE 11,790,000.00 11,790,000.00 TD HYDRO - CONTRACTS PAYABLE - 19,298.40 UNAMORTIZED PREMIUM - 2005 BONDS - -UNAMORTIZED PREMIUM - 2012 BONDS 915,959.96 1,056,876.92 UNAMORTIZED PREMIUM - 2016 BONDS 1,127,525.14 1,175,335.42 CAPITAL LEASE NON-CURRENT LIAB 18,876.08 25,168.04

TOTAL LONG-TERM DEBT 23,787,361.18 26,896,678.78

CURRENT AND ACCRUED LIABILITIES:

CURR PORTION LT DEBT 1,460,000.00 ACCOUNTS PAYABLE 4,539,760.25 1,892,707.06 ACCRUED 190 CONTRACT FEES 197,270.74 152,843.69 CUSTOMERS DEPOSITS 3,995,097.14 5,070,970.53 ACCRUED VACATION & SICK LEAVE 402,109.36 401,563.20 ACCRUED INTEREST 474,927.66 502,884.58 OTHER CURRENT & ACCRUED LIABILITIES 336,600.43 1,035,701.11

TOTAL CURRENT & ACCRUED LIABILITIES 11,405,765.58 9,056,670.17 DEFERRED CREDITS:

ADVANCES ON CONSTRUCTION 116,160.00 - BPA CRC & ECA PROGRAMS (70,637.57) - FISHERIE'S MITIGATION TRUST FUND 1,645,775.05 1,797,576.94 POST RETIREMENT HEALTH PLAN 446,702.22 419,374.60 CONTRIBUTIONS IN AID OF CONSTRUCTION 580,335.75 -

TOTAL DEFERRED CREDITS 2,718,335.45 2,216,951.54

SURPLUS AND INVESTMENT ACCOUNTS EARNED SURPLUS:

BALANCE FIRST OF YEAR 53,298,105.74 46,859,345.57 NET INCOME 348,743.30 (377,134.40) MISC. DEBITS & CREDITS - - EXTRAORDINARY DEDUCT-MCNARY - -

BALANCE AT END OF PERIOD 53,646,849.04 46,482,211.17 INVESTMENT OF MUNICIPALITY 75,543.39 75,543.39

TOTAL SURPLUS & INVESTMENTS 53,722,392.43 46,557,754.56

TOTAL LIABILITIES & EARNED SURPLUS 91,633,854.64 84,728,055.05

NWBS Balance Sheet 05.31.18 6/29/2018 - 11:12 AM4

Last Year Current Last YearCurrent Month Current Month Y-T-D Y-T-D

Amount Amount Amount Amount

ENERGY SALES

1 SINGLE PHASE SERVICE 647,137.55$ 658,624.66$ 4,625,102.55$ 4,917,144.36$ 2 THREE PHASE SERVICE 100,962.97$ 87,350.02$ 518,530.06 458,889.82$ 3 DEMAND SERVICE 318,049.33$ 297,344.65$ 1,591,791.34 1,469,283.22$ 4 PRIMARY SERVICE 2,217,352.55$ 1,571,009.09$ 10,844,654.62 8,176,177.84$ 5 IRRIGATION 13,603.37$ 10,179.24$ 26,168.26 20,151.69$ 6 STREET LIGHTING 34,489.51$ 34,827.31$ 173,683.54 119,214.73$ 7 PURE POWER 275.00$ 305.00$ 1,380.00 1,533.17$ 8 UNBILLED REVENUE -$ -$ - (171,318.00)$

10 TOTAL 3,331,870.28 2,659,639.97 17,781,310.37 14,991,076.83

OTHER REVENUES

11 TRANSMISSION WHEELING 12,490.00$ 12,643.00$ 52,770.00 47,341.00$ 12 REVENUE FROM THE DALLES HYDRO 27,624.76$ 39,590.00$ 249,485.29 200,610.29$ 13 SERVICE CHARGES 10,900.51$ 5,439.00$ 45,907.30 30,188.97$ 14 RENT FROM ELECTRIC PROPERTY 7,265.87$ 6,943.00$ 36,354.43 34,763.00$

16 TOTAL OTHER REVENUE 58,281.14 64,615.00 384,517.02 312,903.26

17 TOTAL OPERATING REVENUE 3,390,151.42 2,724,254.97 18,165,827.39 15,303,980.09

OPERATING EXPENSES

19 LICENSE/PERMIT COSTS - HYDROS -$ 26.30$ 27.35 78.90$ 21 OPERATION/MAINTENANCE - TD HYDRO 23,608.76$ 32,321.07$ 286,747.37 173,287.30$

OPERATION/MAINTENANCE - MCNARY HYDRO 26,118.00$ 21,296.70$ 212,620.21 126,811.44$ 22 POWER PURCHASES 1,987,924.00$ 1,498,856.60$ 11,055,347.15 9,718,831.57$

OTHER POWER SUPPLY EXPENSE 49,184.39$ 18,928.53$ 175,971.18 86,465.11$ 23 TRANSMISSION COSTS - BPA 212,615.00$ 164,888.91$ 1,176,385.00 989,088.00$

TRANSMISSION COSTS - TD HYDRO 11,418.68$ 17,069.80$ 40,364.83 72,355.86$ TRANSMISSION COSTS - MCNARY HYDRO 2,454.36$ 4,341.00$ (965.64) 6,666.00$ TRANSMISSION COSTS - NON FEDERAL 6,331.00$ 7,937.00$ 42,245.00 44,943.00$

25 TRANSMISSION - O&M 4,795.83$ 19,959.94$ 32,734.35 46,195.93$ 26 DISTRIBUTION - O&M 234,062.92$ 196,031.50$ 1,010,520.55 1,054,739.37$ 27 CUSTOMER ACCOUNTS & COLLECTION 64,768.37$ 55,869.95$ 313,748.07 290,512.48$ 29 SALES PROMOTION 6,107.47$ 6,035.60$ 26,113.88 46,372.93$ 31 ADMINISTRATIVE & GENERAL 356,322.62$ 281,298.76$ 1,458,744.49 1,363,928.50$ 33 WEATHERIZATION & CONSERVATION 45,741.28$ 74,831.10$ 169,552.12 338,354.82$ 35 CUSTOMER INFO/ASSISTANCE 11,910.21$ 4,813.47$ 32,390.48 32,897.64$ 36 WELLNESS 1,035.83$ 1,128.19$ 4,956.63 5,767.53$

38 TOTAL OPERATING EXPENSES 3,044,398.72 2,405,634.42 16,037,503.02 14,397,296.38

***NORTHERN WASCO PUD*** MONTHLY FINANCIAL & OPERATING REPORT

January 01, 2018 - December 31, 2018May 2018

NWOP & NWIS Monthly FinOpRep 05.31.18 6/29/2018 - 11:13 AM5

Last Year Current Last YearCurrent Month Current Month Y-T-D Y-T-D

Amount Amount Amount Amount

***NORTHERN WASCO PUD*** MONTHLY FINANCIAL & OPERATING REPORT

January 01, 2018 - December 31, 2018May 2018

1 TOTAL OPERATING REVENUE 3,390,151.42 2,724,254.97 18,165,827.39 15,303,980.09

3 TOTAL OPERATING EXPENSE 3,044,398.72 2,405,634.42 16,037,503.02 14,397,296.38 4 DEPRECIATION 216,318.45 162,986.91$ 1,078,266.08 811,429.53$ 6 TAXES 137,275.65 100,572.28$ 709,041.38 547,945.91$

8 TOTAL OPER. REV. DED. 3,397,992.82 2,669,193.61 17,824,810.48 15,756,671.82

9 OPERATING INCOME (LOSS) (7,841.40) 55,061.36 341,016.91 (452,691.73)

OTHER INCOME

11 MISC. NON-OPERATING REVENUE 54,510.55 (44,682.96)$ 187,044.99 84,316.67$

12 TOTAL OTHER INCOME 54,510.55 (44,682.96) 187,044.99 84,316.67

13 GROSS INCOME (LOSS) 46,669.15 10,378.40 528,061.90 (368,375.06)

INCOME DEDUCTIONS

14 INTEREST ON LONG TERM DEBT 40,003.12 39,847.91$ 199,239.55 199,212.10$ 15 OTHER DEDUCTIONS - -$ - 786.19$ 17 AMORT. OF DEBT EXPENSE (3,984.19) (3,984.19)$ (19,920.95) (19,920.95)$

19 TOTAL INCOME DEDUCTIONS 36,018.93 35,863.72 179,318.60 180,077.34

NET INCOME (LOSS) 10,650.22 (25,485.32) 348,743.30 (548,452.40)

EXTRAORDINARY ITEM - -$ - -$

NET INCOME (LOSS) 10,650.22 (25,485.32) 348,743.30 (548,452.40)

NWOP & NWIS Monthly FinOpRep 05.31.18 6/29/2018 - 11:13 AM6

5 Months = 41.7%

Current Year Current % of BudgetTotal Budget Y-T-D Amount to Current YTD

REVENUESSales - Single Phase Service 9,817,376.00$ 4,625,102.55$ 47.1%Sales - Three Phase Service 1,172,575.00 518,530.06 44.2%Sales - Demand Service 4,100,599.00 1,591,791.34 38.8%Sales - Primary Service 24,228,180.00 10,844,654.62 44.8%Sales - Irrigation 236,503.00 26,168.26 11.1%Sales - Street Lights 465,744.00 173,683.54 37.3%Sales - Pure Power 4,350.00 1,380.00 31.7%Sales - Energy Unbilled - - 0.0%Transmission Wheeling 130,503.00 52,770.00 40.4%Revenue from T.D. Hydro 862,009.00 249,485.29 28.9%Service Charges 41,858.00 45,907.30 109.7%Pole Contact Rents 85,000.00 36,354.43 42.8%CIAC - Revenue 450,000.00 21,402.00 4.8%Interest Income 242,601.00 147,581.43 60.8%Other Non-Operating Income-TD Hydro 57,791.00 - 0.0%Other Non-Operating Income-McNary - 0.0%Miscellaneous Income or (Loss) 12,500.00 18,061.56 144.5%Miscellaneous Income or (Loss)-McNary - 0.0%

Total Revenues 41,907,589.00$ 18,352,872.38$ 43.8%

EXPENSES Operations & Maintenance:

License/Permit Costs - T.D. Hydro 50,000.00$ -$ 0.0%License/Permit Costs - McNary Hydro 45,000.00 27.35 0.1%Operation/Maintenance - T.D. Hydro 498,657.00 286,747.37 57.5%Operation/Maintenance - McNary Hydro 365,246.00 212,620.21 58.2%Power Purchases 24,707,002.00 11,055,347.15 44.7%Other Power Supply Expense 255,677.00 175,971.18 68.8%Transmission Costs - BPA 2,677,173.00 1,176,385.00 43.9%Transmission Costs - TD Hydro 142,464.00 40,364.83 28.3%Transmission Costs - McNary Hydro 33,684.00 (965.64) -2.9%Transmission Costs - Non Federal 119,868.00 42,245.00 35.2%Transmission Substation 48,757.00 194.52 0.4%Transmission Lines 15,739.00 5,369.31 34.1%Transmission Reliability 99,263.00 27,170.52 27.4%T & D Joint Use 72,133.00 - 0.0%Meter Expense 246,325.00 37,587.41 15.3%Misc. Distribution Expense 243,102.00 91,886.84 37.8%Rents 3,550.00 11,823.36 333.1%Distribution Substations 232,234.00 51,879.40 22.3%Overhead Lines 1,302,166.00 441,113.27 33.9%Tree Trimming 607,347.00 264,885.91 43.6%Underground Lines 193,826.00 67,452.77 34.8%Transformers 53,853.00 1,606.28 3.0%Street Lights 100,020.00 23,214.87 23.2%Maintenance of Misc. Distribution 54,721.00 11,468.82 21.0%Communications Equipment 1,000.00 7,601.62 760.2%

Total Operations & Maintenance 32,168,807.00 14,031,997.35 43.6%

2018 COMPARISON - BUDGET vs. ACTUAL

Revenues and ExpensesAs of May 2018

NWIB Budget VS Actual 05.31.18 6/28/2018 - 4:53 PM7

5 Months = 41.7%

Current Year Current % of BudgetTotal Budget Y-T-D Amount to Current YTD


Revenues and ExpensesAs of May 2018

EXPENSES continued Customers Accounts & Collections:

Meter Reading 227,386.00 71,897.98 31.6%Billing & Collections 492,001.00 233,042.52 47.4%Reserve for Uncollectibles 18,000.00 7,500.00 41.7%Interest on Deposits 1,800.00 1,307.57 72.6%

Total Customer Accounts & Collections 739,187.00 313,748.07 42.4%

Customers Assistance & Sales:Energy Management Programs 1,212,336.00 405,616.31 33.5%BPA ECA Credits (646,848.00) (236,064.19) 36.5%Ruralite 57,000.00 20,889.40 36.6%Customer Services 39,052.00 11,501.08 29.5%Advertising 57,541.00 26,113.88 45.4%Wellness 12,187.00 4,956.63 40.7%Economic Development 50,000.00 - 0.0%

Total Customer Assistance & Sales 781,268.00 233,013.11 29.8%

Administrative & General:Office Salaries 1,880,927.00 772,381.48 41.1%Office Expenses 239,587.00 169,466.43 70.7%Outside Services 381,356.00 188,280.26 49.4%Property Insurance 200,900.00 79,409.25 39.5%Insurance & Job Training 168,319.00 13,518.63 8.0%Employee Benefits - - 0.0%Directors Compensation 247,046.00 101,647.80 41.1%Misc. Expenses, Associations 239,589.00 98,848.92 41.3%Maintenace of General Plant 112,700.00 35,191.72 31.2%

Total Administrative & General 3,470,424.00 1,458,744.49 42.0%

Other Expenses:Depreciation 2,477,372.00 1,078,266.08 43.5%Property Taxes 485,000.00 201,905.71 41.6%ORS 190.003 Contract Fees 1,209,000.00 507,135.67 41.9%Social Security Taxes - - 0.0%Interest on Long-Term Debt 476,313.00 199,239.55 41.8%Debt Expenses (47,810.00) (19,920.95) 41.7%Other Deductions-McNary - 0.0%

Total Other Expenses 4,599,875.00 1,966,626.06 42.8%

Total Expenses 41,759,561.00 18,004,129.08 43.1%

Net Income or (Loss) 148,028.00 348,743.30 235.6%

NWIB Budget VS Actual 05.31.18 6/28/2018 - 4:53 PM8

5 Months = 41.7%

2018 Budget Actual %

WORK-IN-PROGRESS

Construction Work-in-Progress 12/31/17 ($1,010,725) Construction Work-in-Progress for 2018 includes hydro $2,159,567

Retirement Work-in-Progress $76,559 0.0%

PLANT CONSTRUCTION

Transmission:

Transmission Substation $0 $0 0.0%

Transmission Towers & Fixtures $0 $0 0.0%

Transmission Pole Replacement $0 $0 0.0%

Distribution:

Substation $850,000 $0 0.0%

Pole Replacements $367,500 $81,035 22.1%

Overhead Additions $200,000 $91,123 45.6%

Underground Additions $673,500 $206,574 30.7%

Transformer Additions $102,500 $44,174 43.1%

Service Additions $61,800 $18,754 30.3%

Meter Replacements $750,000 $4,428 0.6%

Security/Yard Lights $15,450 $30,105 194.9%

Street Lights & Additions $8,200 $28,928 352.8%

Structures & Improvements-Office $600,000 $0 0.0%

The Dalles Hydro Additions $590,000 $19,259 3.3%

McNary Hydro Additions $315,000 $0 0.0%

Total Plant Construction $4,533,950 $524,380 11.6%

EQUIPMENT:

Office $20,000 $0 0.0%

Computer Hardware & Software $303,400 $37,197 12.3%

Vehicles/Power Equipment $250,000 $135,209 54.1%

Tools/Lab Equipment $35,000 $4,405 12.6%

Communications Equipment $1,500 $0 0.0%

Total Equipment $609,900 $176,812 29.0% Total Plant & Equipment $5,143,850 $701,192 13.6%

SPECIAL PROJECTS:

McNary Exciter $75,000 $28,324 37.8%

The Dalles Exciter $75,000 $54,256 72.3% Total Special Projects $150,000 $82,580 55.1%

DEBT REQUIREMENTS:

Bonds (principal) $0 $0 0.0%

Total Debt Requirements 0.0%

TOTAL CAPITAL EXPENDITURES $5,293,850 $783,771 14.8%


Capital Expenditures

May 2018

CapitalBudget VS Actual 05.31.18 6/28/2018 - 4:12 PM9

Account

Number

Closing

Date

Last

Payment Balance

66354001 03/29/18 03/28/18 29.53$

67876001 03/08/18 02/05/18 176.86$

40015001 03/09/18 03/26/18 144.70$

67299001 03/15/18 02/05/18 105.05$

67217001 03/08/18 01/18/18 153.35$

52849002 03/02/18 01/12/18 118.59$

47522001 03/21/18 02/26/18 94.98$

19243001 Deceased 03/26/18 03/26/18 25.46$

848.52$

Commercial Accounts

64975001 3/2/2018 2/23/2018 214.43

214.43$

Total Write-Offs 1,062.95$

2018 2017 2016

Monthly Write-offs for May 1,062.95$ 5,960.26$ 4,346.20$

Total Write-Offs to date: 9,441.93$ 14,730.52$ 15,981.69$

Less: Credit Collections to date (6,725.05)$ (6,170.93)$ (4,775.97)$

NET WRITE-OFFS TO DATE: 2,716.88$ 8,559.59$ 11,205.72$

Total Write-Offs to date as a percent of revenue to date: 0.0012 0.0019 0.0024

Credit Bureau's share of collections to date: -$ -$ -$

MAY 2018 Write-Off's

1

MASTER RESOURCE AGREEMENT

FOR

NORTHWEST INTERGOVERNMENTAL ENERGY SUPPLY

THIS MASTER RESOURCE AGREEMENT (“Agreement”), dated as of __________________

(“Effective Date”) is entered into by and between Northwest Intergovernmental Energy Supply

(“NIES”), an Oregon intergovernmental entity and Northern Wasco County PUD, a people’s

utility district (hereafter “Member”).

RECITALS

WHEREAS:

A. NIES and Member are Parties to a Joint Resource Planning and Acquisition

Agreement (“JRPAA”) dated December 10, 2014, pursuant to which Member

may agree to participate in a NIES-Owned Resource pursuant to the terms and

conditions of this Master Resource Agreement; and

B. Member wishes to participate in one or more Transactions beginning in BPA

Fiscal Year 2020 or thereafter; and

C. NIES will exercise its best efforts to execute one or more Enabling Agreements

and Confirmations with third party sellers that meet Member’s Transaction

criteria; and

D. If NIES can execute an Enabling Agreement and Confirmation that meets

Member’s Transaction criteria, then the Parties desire to establish a Fixed

Purchase Amount and a Percentage Cost Responsibility (“PCR”) for each

Transaction consistent with the terms and conditions of the JRPAA, the applicable

Enabling Agreement and Confirmation, this Agreement, and any applicable NIES

credit support or other policy or other applicable agreement between NIES and

Member.

NOW THEREFORE, NIES and Member agree as follows:

AGREEMENT

2

1. Definitions. All capitalized terms used herein shall have the respective meanings set forth in

the JRPAA, as applicable, or below unless the context in which such term is used clearly

requires otherwise.

1.1. “BPA Fiscal Year” begins October 1 and ends September 30.

1.2. “Enabling Agreement” means a master agreement between NIES and a third party

seller or purchaser that provides the general terms and conditions for the purchase,

sale, or exchange of electricity.

1.3. “Confirmation” is the documentation of an agreement between NIES and a third party

seller or purchaser pursuant to an Enabling Agreement, for the purchase or sale and

delivery of electric power at a specified quantity, price, and delivery point and other

specified terms.

1.4. “Remarket” is the NIES resale on behalf of Member of all or a portion of Member’s

Fixed Purchase Amount associated with a Transaction.

1.5. “Resource Costs” are calculated for each Transaction by multiplying Member’s Fixed

Purchase Amount (converted to megawatt hours) for such Transaction by the

Transaction Price plus Member’s share of any additional costs incurred by NIES that

are directly related to the purchase and delivery of the Resource for that particular

year. Additional costs may include, without limitation, any costs incurred by NIES to

provide credit support or financial security for the purchase and delivery of the

Resource. Member’s Resource Costs for a Transaction may also include the direct

(non-proportionate) allocation of costs incurred by NIES in connection with the

purchase and delivery of the Resource that would not have been incurred but for

Member’s participation in the Resource. Resource Costs do not include Specific

Resource Investigation Costs, which are recovered separately from the Resource Costs.

Exhibit A lists Member’s estimated annual Resource Cost for each Transaction.

1.6. “Transaction” is Member’s participation, as set forth in Exhibit A, in any NIES-Owned

Resource that is documented in a Confirmation.

1.7. “Transaction Price” is the price per megawatt hour listed in the Confirmation executed

by NIES as documented in Exhibit A.

1.8. For purposes of this Agreement, a “signature” or “signed” document or a “vote in

writing” as that term is used in section 3.4 may include electronic signatures that

comply with the provisions of the Electronic Signatures in Global and National

Commerce Act, 15 U.S.C. §§ 7001-7031, or a comparable Oregon state law applicable

to NIES, and that include a user identification number or password as a method of

verification of the identity of the person signing a document.

2. Transaction Terms and Conditions

3

2.1. Member’s Participation. Member may participate in one or more Transactions under

this Agreement. Each Transaction in which Member participates shall be documented

in Exhibit A.

2.2. Member’s Fixed Purchase Amount. Member shall have a Fixed Purchase Amount for

each Transaction in which it has agreed to participate, which shall be documented in

Exhibit A.

2.3. Member’s PCR. Member shall have a PCR for each Transaction listed in Exhibit A.

Member’s PCR shall equal its Fixed Purchase Amount divided by the sum of all NIES

members’ Fixed Purchase Amounts for that particular NIES-Owned Resource.

2.4. Member’s Voting Rights. Member’s Voting Rights for each Transaction in which it

participates shall equal its PCR for that Transaction.

2.5. Member’s Obligation to Pay Resource Costs. Pursuant to section III(D)(3) of the

JRPAA , Member shall pay its Resource Costs with respect to any Transaction listed in

Exhibit A.

2.6. Creditworthiness and Credit Support Requirements. During the term of any

Transaction listed on Exhibit A, Member shall be bound by and shall abide by all

terms and conditions of NIES’ then applicable Credit and Risk Management Policy.

2.7. Monthly Invoicing. NIES will submit an invoice to Member on or before the fifth day

of the month of delivery itemizing Member’s monthly Resource Costs for each

Transaction listed in Exhibit A. On or after the tenth day of that month, Member

hereby authorizes NIES, through its designee NEMS, to perform an Automated

Clearing House (ACH) electronic funds transfer to withdraw the funds in the amount

of the invoice from Member’s bank account. Notwithstanding the foregoing, NIES

may invoice Member based on charges for scheduled deliveries in the current month

and the next two succeeding months as estimated by NIES, and Member shall be

obligated to pay such invoices in advance of actual deliveries.

2.8. Indemnity. Member shall indemnify and hold harmless NIES and any non-

participating NIES members, from and against any and all costs, claims, demands,

losses, causes of action, damage, lawsuits, judgments, including attorneys' fees and

costs arising from or associated with Member’s share of the NIES-Owned Resource

subject to this Master Resource Agreement. For purposes of this indemnity,

“Member’s share” shall be based on Member’s PCR for such NIES-Owned Resource.

Member shall be solely liable for, and shall indemnify and hold harmless NIES, non-

participating NIES members, and all other Participating Members from and against,

any and all costs, claims, demands, losses, causes of action, damage, lawsuits,

judgments, including attorneys' fees and costs arising out of: (a) Member’s obligation

to pay its Resource Costs, and (b) NIES Remarketing of all or a portion of Member’s

Fixed Purchase Amount.

4

2.9. Member’s Share of Specific Resource Investigation Costs. NIES and Member agree

that Member shall be responsible for its share, equal to its PCR, of Specific Resource

Investigation Costs incurred by NIES for each Transaction. Member shall be

responsible for such costs for each resource investigation in which Member

participates pursuant to Sections 3.1 or 3.2 below even if Member elects not to

participate in a Transaction pursuant to Section 3.4. Such Specific Resource

Investigation Costs shall be payable upon invoice by NIES. Notwithstanding the

foregoing, Member and NIES agree that Member’s Specific Resource Investigation

Costs under this Agreement shall not exceed $1,000.00 per Transaction unless

Member agrees in writing to pay any additional Specific Resource Investigation Costs.

3. Process to Participate in a Transaction

3.1. Resource Investigation Initiated by Member. Member shall notify NIES that it desires

to initiate an investigation into a potential NIES-Owned Resource by submitting a

letter to NIES, using the template contained in Exhibit B. The notification letter must

specify Member’s desired annual megawatt amount and maximum purchase price and

any other attributes Member requires of the Transaction. Member acknowledges and

agrees that, upon NIES' receipt of such notice from Member, NIES will notify all other

NIES members of its intent to form a Resource Committee to investigate a potential

NIES-Owned Resource. Other NIES members will have three (3) business days to

notify NIES of their desire to participate in the investigation of such potential NIES-

Owned Resource and to appoint a representative to the Resource Committee by

submitting a letter or email to NIES, using the template contained in Exhibit B.

3.2. Resource Investigation Initiated by Other NIES Members. Upon NIES' receipt of

notice from any other NIES member to initiate a resource investigation, NIES shall

notify Member of its intent to form a Resource Committee to investigate a potential

NIES-Owned Resource. Upon receipt of such notice, Member shall have three (3)

business days to notify NIES of its desire to participate in the investigation of such

potential NIES-Owned Resource and to appoint a representative to the Resource

Committee by submitting a letter or email to NIES, using the template contained in

Exhibit B.

3.3. Resource Committee. With respect to any resource investigation that Member has

initiated pursuant to Section 3.1 or in which Member has notified NIES of its intent to

participate pursuant to Section 3.2, NIES shall establish a Resource Committee with a

representative of Member and a representative from each additional NIES member

providing notice of its intent to participate. NIES shall establish a PCR for Member at

this time.

3.4. Resource Committee Voting. With respect to any Resource Committee established by

NIES pursuant to Section 3.3 in which Member has a representative, NIES shall

provide Member written or electronic notice at least two (2) business days before any

Resource Committee vote to authorize NIES to enter into a Confirmation. Member’s

Resource Committee representative, and the representatives of each other participating

5

NIES member, shall vote to either approve or reject NIES’ execution of the

Confirmation.

The vote of Member’s representative, and each other Resource Committee

representative, shall be made and communicated to NIES in writing on or before the

deadline established by NIES. The failure to submit a timely and written vote shall be

deemed to be a vote against entering into a Transaction. Member shall not be bound

by any Confirmation executed by NIES pursuant to this Agreement unless Member’s

Resource Committee representative has timely and affirmatively voted in writing to

authorize NIES to execute the Confirmation. Such written vote authorizing NIES to

execute a Confirmation shall be signed by Member’s Resource Committee

representative and shall be in the form attached hereto as Exhibit D.

If Member’s Resource Committee representative does not affirmatively vote in writing

to authorize the execution of the Confirmation by the deadline established by NIES,

then Member’s right to participate in a Transaction with respect to such NIES-Owned

Resource shall automatically be terminated. In such case, Member’s representative

will no longer be a member of the Resource Committee and will not have a PCR or

Voting Rights. Member remains obligated, however, to pay its share of any Specific

Resource Investigation Costs incurred prior to the voting deadline.

If Member’s Resource Committee representative does affirmatively vote in writing to

authorize the execution of the Confirmation by the deadline established by NIES, but

the representative of any other participating NIES member does not affirmatively vote

in writing to authorize the execution of the Confirmation, then NIES shall not be

authorized to execute the Confirmation. In such case, the representatives of the NIES

members not voting or voting against the Confirmation shall be removed from the

Resource Committee and the PCR and Voting Rights of Member and of each of the

NIES members whose representatives voted in favor of executing the Confirmation

shall be adjusted to reflect the new composition of the remaining participating NIES

members. The remaining representatives of the revised and reconstituted Resource

Committee may thereafter vote to authorize or reject NIES’ execution of the

Confirmation. The voting requirements set forth above shall remain applicable to each

subsequent vote. This voting process shall be repeated until all remaining Resource

Committee representatives have unanimously voted in writing or via electronic

message to authorize the execution of the Confirmation and all approved terms.

3.5. NIES Authorized to Transact. Upon the unanimous approval by the Resource

Committee pursuant to section 3.4, NIES shall be authorized to execute a Confirmation

under the terms and conditions set forth in Section IV.C of the JRPAA and as

approved by the Resource Committee. NIES agrees to attempt to execute such

Confirmation no later than ten (10) business days after it has received authorization to

transact. If for any reason NIES is unable to execute a Confirmation within ten (10)

business days after receiving authorization to transact, then such authorization shall

automatically terminate unless a longer deadline is expressly permitted in Exhibit D as

initially submitted, or as subsequently amended in writing, by Member’s Resource

6

Committee representative and by the Resource Committee representatives of each

other Participating Member.

NIES shall have no liability to Member under this Agreement or otherwise, if for any

reason NIES is unable to execute a Confirmation as approved by the Resource

Committee. NIES’ execution of a Confirmation consistent with this Agreement

establishes a Transaction that is binding on Member without any further authorization

or approval from Member’s governing body. Upon NIES’ execution of a

Confirmation, NIES shall send a revised Exhibit A to Member reflecting the

Transaction. Member shall be bound to participate in such Transaction according to

the terms of the JRPPA and this Master Resource Agreement.

4. Remarketing

4.1. Member’s Request to Remarket. Member may request that NIES Remarket its Fixed

Purchase Amount or a portion thereof at any time before or during the term of a

Transaction. Member shall make such request NIES at least three (3) business days

prior to the first desired Remarketing delivery date. Member shall authorize NIES in

writing using Exhibit C, and Member must identify the desired megawatt amount,

minimum Remarketing price, term length, and any other attributes required by

Member.

4.2. NIES Authorized to Remarket. Upon receipt of an authorization to Remarket all or a

portion of Member’s Fixed Purchase Amount, NIES shall use commercially

reasonable efforts to Remarket in accordance with Member’s request. NIES agrees to

attempt to execute such Confirmation no later than ten (10) business days after it has

received authorization to transact. NIES shall have no liability to Member under this

Agreement or otherwise, if for any reason NIES is unable to execute a Confirmation as

approved by the Member. NIES’ execution of a Confirmation consistent with this

Agreement establishes a Transaction that is binding on Member without any further

authorization or approval from Member’s governing body. Upon NIES’ execution of a

Confirmation, NIES shall send a revised Exhibit A to Member reflecting the

Transaction. Member shall be bound to participate in such Transaction according to

the terms of the JRPPA and this Master Resource Agreement.

4.3. No Price Guarantee. Member acknowledges and agrees that the Remarket price may

be different than the original Transaction Price, which could result in a net loss or net

gain to the Member. NIES shall have no liability if it is unable to Remarket the Fixed

Purchase Amount on the terms requested by Member. If for any reason the

Remarketing is not completed, then Member shall remain obligated to receive and pay

for Member’s entire Fixed Purchase Amount at the original Transaction Price all as set

forth in Exhibit A. In the event that the Remarket price is greater than Transaction

Price, then Member shall be entitled to receive the positive difference between

Remarket price and the Transaction Price.

5. Representations.

7

5.1. Member Representations. Member represents and warrants as follows:

(i) Member has the corporate power and authority to execute and deliver this

Agreement.

(ii) The execution and delivery by Member of this Agreement and the performance by

Member of the actions contemplated on its part hereby have been duly authorized

by the governing body of the Member.

(iii) This Agreement has been duly executed and delivered by the Member and is a valid

and binding agreement of the Member, enforceable against the Member in

accordance with its terms, subject only to limitations on enforceability imposed by

(i) applicable bankruptcy, insolvency, reorganization, moratorium, or similar laws

affecting creditors’ rights generally, and (ii) general equitable principles.

(iv) Member’s representative serving on any Resource Committee has been duly

appointed by Member and delegated the legal authority by Member’s governing

body to bind Member to Transactions pursuant to this Master Resource Agreement.

5.2. NIES Representations. NIES represents and warrants as follows:

(i) NIES has the corporate power and authority to execute and deliver this Agreement.

(ii) The execution and delivery of this Agreement by NIES and the performance by

NIES of the actions contemplated on its part hereby have been duly authorized by

the Board of Directors of NIES.

(iii) This Agreement has been duly executed and delivered by NIES and is a valid and

binding agreement of NIES, enforceable against NIES in accordance with its terms,

subject only to limitations on enforceability imposed by (i) applicable bankruptcy,

insolvency, reorganization, moratorium, or similar laws affecting creditors’ rights

generally, and (ii) general equitable principles.

6. Miscellaneous.

6.1. Termination Date. This Agreement shall terminate if and when the JRPPA expires or

terminates. This Agreement may also be terminated by either party hereto with or

without cause by giving the other party not less than thirty (30) days written notice.

Notwithstanding the forgoing, the applicable provisions of this Agreement shall

survive termination until all outstanding Transactions listed on Exhibit A have expired

or have been terminated and all existing obligations arising under this Agreement, any

Specific Resource Investigation Agreement, any Confirmation and/or under any

agreement to provide credit support shall continue to be enforceable until fully

satisfied.

6.2. Additional Remedies. Nothing herein is intended to limit the remedies available to a

non-defaulting party under this Agreement, the JRPAA, an applicable Enabling

Agreement or Confirmation or by law. In particular, but without limitation, if NIES is

8

the non-defaulting party in any Transaction in which Member is the defaulting party,

NIES shall have the right (i) to indefinitely suspend NIES’ performance of all

Transactions with Member under this Agreement; and (ii) during any period of

suspension, Remarket Member’s Fixed Purchase Amount, and (iii) recover any losses

due to a differential between the Resource Cost and the amount recovered from the

Remarketing of Member’s Fixed Purchase Amount. NIES and Member may agree to

terms for a resumption of performance of any Transaction for which performance has

been suspended.

6.3. Binding Effect; Assignment. This Agreement shall be binding upon and inure to the

benefit of NIES and Member and their respective successors and permitted assigns.

Member may not make any transfer or assignment of this Agreement, other than an

assignment for security, without NIES’ prior written consent. Any assignment made

without a consent required hereunder shall be void and of no force or effect.

6.4. Amendments. This Agreement may be amended by agreement between NIES and

Member, but no such amendment to this Agreement shall be effective unless it is in

writing, executed by both parties.

6.5. Entire Agreement; Waiver. This Agreement, together with Exhibits A through D, the

Credit Policy and other applicable policies of NIES, any applicable Enabling

Agreement or Confirmation, and the JRPAA, constitutes the entire agreement between

the parties hereto relating to the subject matter contemplated by this Agreement and

supersedes all prior agreements, whether oral or written. The subject matter of this

Agreement involves only Transactions for the delivery of power commencing in BPA

Fiscal Year 2020 or later, and nothing in this Agreement is intended to supersede the

terms of any existing or future agreement that would fit the definition of a Transaction

but commenced prior to BPA Fiscal Year 2020.

6.6. Conflicts. This Agreement and the JRPAA shall be interpreted to be consistent if

possible; however, in the event of any irreconcilable conflict between the provisions of

this Agreement and the JRPAA, the provisions of this Agreement shall prevail.

6.7. Counterparts. This Agreement may be executed in multiple counterparts to be

construed as one.

6.8. Severability. If any part, term, or provision of this Agreement is held by a court of

competent jurisdiction to be unenforceable, the validity of the remaining portions or

provisions shall not be affected, and the rights and obligations of the parties shall be

construed and enforced as if this Agreement did not contain the particular part, term, or

provision held to be unenforceable.

6.9. Governing Law. This Agreement shall be governed by, and construed in accordance

with, the laws of the State of Oregon.

IN WITNESS WHEREOF, NIES and the Member have caused this Agreement to be executed,

attested, sealed and delivered by their respective duly authorized officers as of the day and year

first written above.

9

Northern Wasco County PUD Northwest Intergovernmental Energy Supply

Date: Date:

By: By:

Its: Its: President

Draft as of 9/16/16

Revision No. X Dated XX/XX/XX

10

Exhibit A: List of Member Transactions

This Exhibit documents the Transactions that Member has agreed to purchase from NIES. Each revision supersedes any prior Exhibit

A.

Date of

Transaction

Transaction

No.

Fixed

Purchase

Amount

(aMW)

Percentage

Cost

Responsibility

MWh Transaction

Price

Resource Cost

(MWh *

Transaction Price)

Credit

Support/

Financial

Security

Costs

Other

Costs

Term Delivery

Point

NIES Exhibit B template draft – 9/16/16

11

EXHIBIT B

MARKET PURCHASE NOTIFICATION FORM

Please use the following form to notify NIES of your desire to participate in a market purchase

Transaction. Please submit this form electronically to NIES at [email protected].

NEW MARKET PURCHASE TRANSACTION

1) A Fixed Purchase Amount for any amount up to but not exceeding the following amounts of

power for each Fiscal Year1 (FY), stated in whole average megawatts, and not exceeding the

maximum purchase price for each FY stated below:

2020 = _____ aMW @ $_____/MWh

2021 = _____ aMW @ $_____/MWh

2022 = _____ aMW @ $_____/MWh

2023 = _____ aMW @ $_____/MWh

2025 = _____ aMW @ $_____/MWh

2026 = _____ aMW @ $_____/MWh

2027 = _____ aMW @ $_____/MWh

2028 = _____ aMW @ $_____/MWh

2) Please identify any other attributes that are required as part of the transaction:

Submitted By:

On Behalf Of: Northern Wasco County PUD

Date:

1 Fiscal Year begins October 1 and ends September 30

mailto:[email protected]

NIES Exhibit C template draft – 9/16/16

12

EXHIBIT C

MARKET PURCHASE REMARKETING AUTHORIZATION FORM

I _______________________, acting as the Resource Committee Representative on behalf of

Northern Wasco County PUD authorize NIES to execute a Confirmation in order to Remarket

the following amounts of power for each month listed below, stated in whole average megawatts,

and not below the minimum remarketing price stated below:

Month Year

_____ ______= _____ aMW @ $_____/MWh

_____ ______= _____ aMW @ $_____/MWh

_____ ______= _____ aMW @ $_____/MWh

_____ ______= _____ aMW @ $_____/MWh

_____ ______= _____ aMW @ $_____/MWh

_____ ______= _____ aMW @ $_____/MWh

_____ ______= _____ aMW @ $_____/MWh

_____ ______= _____ aMW @ $_____/MWh

_____ ______= _____ aMW @ $_____/MWh

_____ ______= _____ aMW @ $_____/MWh

_____ ______= _____ aMW @ $_____/MWh

_____ ______= _____ aMW @ $_____/MWh

Additional conditions or requirements:

Signed: _______________________

Title: _______________________

Date: _______________________

NIES Exhibit D template draft – 9/16/16

13

EXHIBIT D

MARKET PURCHASE TRANSACTION AUTHORIZATION FORM

I _______________________, acting as the Resource Committee Representative on behalf of

Northern Wasco County PUD authorize NIES to execute a Confirmation in order to purchase the

following amounts of power for each Fiscal Year2 (FY), stated in whole average megawatts, and not

exceeding the maximum purchase price for each FY stated below:

2020 = _____ aMW @ $_____/MWh

2021 = _____ aMW @ $_____/MWh

2022 = _____ aMW @ $_____/MWh

2023 = _____ aMW @ $_____/MWh

2025 = _____ aMW @ $_____/MWh

2026 = _____ aMW @ $_____/MWh

2027 = _____ aMW @ $_____/MWh

2028 = _____ aMW @ $_____/MWh

Additional conditions or requirements:

Signed: _______________________

Title: _______________________

Date: _______________________

2 Fiscal Year begins October 1 and ends September 30

Column Labels

Values 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 Grand Total

Sum of Cost 3,118,900 7,815,250 6,787,501 6,504,664 2,095,251 1,795,277 2,835,753 2,621,694 863,113 2,371,624 3,932,443 40,741,469

Sum of CIAC -235,000 -242,050 -519,312 -631,791 -264,495 -272,429 -280,602 -289,020 -297,691 -306,622 -315,820 -3,654,832

Sum of Net Cost 2,883,900 7,573,200 6,268,189 5,872,873 1,830,757 1,522,848 2,555,151 2,332,674 565,422 2,065,002 3,616,622 37,086,637

Northern Wasco County PUD Capital Improvement Plan 2018-

2028

-2,000,000

-1,000,000

0

1,000,000

2,000,000

3,000,000

4,000,000

5,000,000

6,000,000

7,000,000

8,000,000

9,000,000

Sum of Cost Sum of CIAC Sum of Net Cost

2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028

Year

Values

Sum of CostSum of CIAC Sum of Net Cost

Row Labels 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 Grand Total

Columbia Heights 170,000 50,000 26,000 9,000 1,000,000 1,255,000

Columbia Heights - Replace Battery Bank 20,000 20,000

Landscaping around Columbia Heights Sub 30,000 30,000

Replace Control Building 50,000 50,000

Replace URD Cable - E 21st Lewis/View Court 70,000 70,000

Replace URD Cable - 1400 Block E 21st 50,000 50,000

Replace URD Cable - 1420 E 16th 10,000 10,000



Add Second Transformer 1,000,000 1,000,000

Distribution 210,000 216,150 222,485 229,009 235,729 242,651 249,781 257,124 264,688 272,479 280,503 2,680,598

Installation of coordination devices and switches 5,000 5,000 5,000 5,000 5,000 5,000 5,000 5,000 5,000 5,000 5,000 55,000

Underground line extensions to serve new load 150,000 154,500 159,135 163,909 168,826 173,891 179,108 184,481 190,016 195,716 201,587 1,921,169

Overhead line extensions to serve newload 55,000 56,650 58,350 60,100 61,903 63,760 65,673 67,643 69,672 71,763 73,915 704,429

Dufur 75,000 250,000 325,000

Replace URD Cable and convert to 7200 V 75,000 75,000

Wasco Electric Tie 250,000 250,000

East Side Substation 175,000 4,000,000 800,000 4,975,000

Construct new substation 4,000,000 4,000,000

Construct substation feeders 800,000 800,000

Design new sbustation 175,000 175,000

Lease Lights 5,000 5,150 5,305 5,464 5,628 5,796 5,970 6,149 6,334 6,524 6,720 64,039

Convert to LED Lights 5,000 5,150 5,305 5,464 5,628 5,796 5,970 6,149 6,334 6,524 6,720 64,039

Meters 500,000 1,750,000 10,000 10,000 10,000 10,000 10,000 10,000 10,000 10,000 10,000 2,340,000

AMI Installation and meters 500,000 1,750,000 2,250,000

Purchase new meters 10,000 10,000 10,000 10,000 10,000 10,000 10,000 10,000 10,000 90,000

Rivertrail 600,000 600,000

Install feeders and switchgear 600,000 600,000

Second Street 400,000 570,000 950,000 2,000,000 3,920,000

Add Feeder F18 to reduce load on the F12 Downtown Feeder 200,000 200,000

Install recloser on G187 - F12 - Downtown 30,000 30,000

Lone Pine Village - I-84 Freeway Undercrossing 150,000 150,000

Rebuild and reconductor Downtown Feeder From G187 to G159 300,000 300,000

Reconductor F15 W 2nd Street 150,000 150,000

Shilo Inns - Replace UG wire and replace transformers 50,000 50,000

Urban Renewal - 3rd Street Lincoln to Taylor 270,000 270,000

Upgrade 115 kV Switches and buswork 750,000 750,000

Replace URD Cable - Tillicum Apartments 20,000 20,000

Replace Transformers 2,000,000 2,000,000

Service Additions 60,000 61,800 63,654 65,564 67,531 69,556 71,643 73,792 76,006 78,286 80,635 768,468

New underground and overhead services 60,000 61,800 63,654 65,564 67,531 69,556 71,643 73,792 76,006 78,286 80,635 768,468

Seufert 1,000,000 3,100,000 4,100,000

Rebuild Substation 3,000,000 3,000,000

City of The Dalles E 19th & Thompson Street Improvement 100,000 100,000

Rebuild Distritbution line from Old Moody to Deschutes 1,000,000 1,000,000

Street Lights 10,000 10,300 10,609 10,927 11,255 11,593 11,941 12,299 12,668 13,048 13,439 128,078

Convert to LED Lights 10,000 10,300 10,609 10,927 11,255 11,593 11,941 12,299 12,668 13,048 13,439 128,078

System Improvements 50,000 51,500 53,045 54,636 56,275 57,964 59,703 61,494 63,339 65,239 67,196 640,390

Distribution pole replacement and misc. improvements 50,000 51,500 53,045 54,636 56,275 57,964 59,703 61,494 63,339 65,239 67,196 640,390

Tenth Street 815,000 1,565,000 2,380,000

Change out 10th Street Substation 20/27/33 MVA with LTC 1,500,000 1,500,000

Rebuild and Reconductor F23 along Mill Creek Road 800,000 800,000

Replace URD Cable - Valley Vista Nursing Home 15,000 15,000

Replace URD Cable - Pomona Meadows 65,000 65,000

Three Mile 65,000 65,000

Construct new control building and upgrade relays 65,000 65,000

Transmission 1,500,000 1,500,000 3,000,000 3,000,000 9,000,000

Rebuild and Reconductor 115 kV Big Eddy to East Side Sub 1,500,000 1,500,000

Rebuild and Reconductor 115 kV East Side to Columbia Heights 1,500,000 1,500,000

Rebuild and Reconductor 69 kV Line Three Mile to Dufur 3,000,000 3,000,000

Rebuild and Reconductor 69 kV Line Dufur to Oak Springs 3,000,000 3,000,000

Tygh Valley 800,000 2,500,000 3,300,000

Rebuild and reconductor Tygh Valley Feeder 800,000 800,000

Rebuild Tygh Valley Substation 2,500,000 2,500,000

Grand Total 2,545,000 6,034,900 5,961,097 5,849,600 1,636,418 1,347,560 2,409,037 1,920,858 433,034 1,945,575 3,458,492 3,000,000 36,541,573

Row Labels 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 Grand Total

Building 20,000 150,000 20,000 20,000 20,000 20,000 20,000 20,000 20,000 20,000 20,000 350,000

Miscellaneous Capital 20,000 20,000 20,000 20,000 20,000 20,000 20,000 20,000 20,000 20,000 200,000

Main Office Foundation Settling 150,000 150,000

Office 0 0 0 0 0 0 0 0 0 0 0 0

Equipment 0 0 0 0 0 0 0 0 0 0 0 0

Test Equipment 0 0 0 0 0 0 0 0 0 0 0 0

Test Equipment 0 0 0 0 0 0 0 0 0 0 0 0

Tools 15,000 15,450 15,914 16,391 16,883 17,389 17,911 18,448 19,002 19,572 20,159 192,117

Tools 15,000 15,450 15,914 16,391 16,883 17,389 17,911 18,448 19,002 19,572 20,159 192,117

Transformers 100,000 103,000 106,090 109,273 112,551 115,927 119,405 122,987 126,677 130,477 134,392 1,280,780

Purchase new transformers 100,000 103,000 106,090 109,273 112,551 115,927 119,405 122,987 126,677 130,477 134,392 1,280,780

Grand Total 135,000 268,450 142,004 145,664 149,434 153,317 157,316 161,435 165,679 170,049 174,550 1,822,897


Vehicles 195,000 455,000 225,000 435,000 185,000 200,000 200,000 450,000 200,000 200,000 200,000 2,945,000

Replace Vehicles 200,000 200,000 450,000 200,000 200,000 200,000 1,450,000

#5 1997 TD Hydro F-350 60,000 60,000

#4 2004 Chevy Trail Blazer 4x4 Pool Vehicle 45,000 45,000

#3 2009 Dodge 5500 Trouble Truck 145,000 145,000

#6 2005 Dodge Dakota Pickup 55,000 55,000

#7 2005 Dodge Durango SUV 45,000 45,000

#8 1992 Caterpiller Fork Lift TD Hydro 85,000 85,000

#9 2009 Ford F-350 4x4 Foreman Rig 85,000 85,000

#10 2009 Ford F-350 4x4 Formean Rig 85,000 85,000

#14 2007 Ford F-150 4x4 1/2 ton pickup 45,000 45,000

#30 1980 Tandem Axle Pole Trailer 65,000 65,000

#33 1980 Tandem Axle Pole Trailer 35,000 35,000

#35 Single Axle Two Reel Trailer 50,000 50,000

#36 1981 Pole/Transformer Dolly 50,000 50,000

Backyard Derrick 200,000 200,000

#25 New Digger Derrick Truck 300,000 300,000

#17 2005 Dodge Durango 45,000 45,000

#31 1980 3 Axle, Three Reel Trailer 100,000 100,000

Grand Total 195,000 455,000 225,000 435,000 185,000 200,000 200,000 450,000 200,000 200,000 200,000 2,945,000


McNary Fishway - NWASCO Share 37,500 17,500 410,000 10,000 10,000 10,000 10,000 10,000 10,000 10,000 10,000 545,000

Replace Exciter 37,500 37,500

Elevator installation 400,000 400,000

Battery Charger 7,500 7,500


The Dalles Fishway 790,000 30,000 15,000 15,000 15,000 15,000 15,000 15,000 15,000 15,000 940,000

Replace Exciter 75,000 75,000

Juvenile Fish Sampling Facility 700,000 700,000

Battery Charger 15,000 15,000


Grand Total 37,500 807,500 440,000 25,000 25,000 25,000 25,000 25,000 25,000 25,000 25,000 1,485,000


IT 206,400 249,400 19,400 49,400 99,400 69,400 44,400 64,400 39,400 31,000 74,400 947,000

Core Infrastructure 108,400 164,400 19,400 19,400 19,400 54,400 44,400 34,400 19,400 31,000 74,400 589,000

ERP-Related Products (UPN & Futura) 30,000 65,000 0 15,000 0 15,000 0 15,000 0 0 0 140,000

Other Projects 68,000 20,000 0 15,000 80,000 0 0 15,000 20,000 0 0 218,000

Grand Total 206,400 249,400 19,400 49,400 99,400 69,400 44,400 64,400 39,400 31,000 74,400 947,000

DATE: June 19, 2018 TO: NORTHERN WASCO COUNTY BOARD OF DIRECTORS FROM: Lana Egbert, Lead Sr. Financial Analyst RE: Pole Contact Rate Change ______________________________________________________________________

The District’s pole contact rental rate has been updated for 2018 based on the 2017

financial statements. The annual rental rate will increase from $12.54 (2017 rate) to

$14.06 per contact if the licensee is compliant and $14.86 (2017 rate) to $16.67 per

contact if not compliant.

Certified letters have been sent to pole contact licensees of the proposed new rates on

June 18th, 2018. The Licensees will be allowed 60 days for comment. The

recommendation is that the District make the following changes effective July 1st, 2018.

CenturyLink is the District’s only licensee whose billing begins on July 1st, 2018 all

others begin on January 1st, 2019.

Adopted: 07/03/18 Amended Pole Contact Rates

NORTHERN WASCO COUNTY PEOPLE’S UTILITY DISTRICT

AMENDED POLE CONTACT RATES

Effective July 1, 2018

COMPLIANT RATE: $14.06 per contact NON-COMPLIANT RATE: $16.67 per contact ADOPTED this 3rd day of July, 2018 ________________________________ President ATTEST: ________________________________ Secretary

Northwest Requirements Utilities Board of Directors Meeting

Wednesday, August 1, 2018

9:00 am to 2:30 pm

Mt. St. Helens Rooms A, B, & C Sheraton Portland Airport

8235 NE Airport Way

Lunch Provided Please R.S.V.P. by replying to this email with any dietary requests. Or R.S.V.P. to Sybil by email

[email protected] or by phone (503) 233-5823, thank you!

For room reservations we have contracted a “Club Rate” of $155.00 per night with premium services.

Access to the Club Lounge, for up to 4 guests per room.

Open 24/7, the lounge has grab and go items available: bottled waters, soda, granola bars, whole fruit, self‐serve espresso machine, etc.

Complimentary continental breakfast with one hot item served 5:30 to 8:30 a.m.

Evening Hors D’oeuvres, served 5:00 to 7:30 pm, consisting of Chef’s choice appetizers and 2 complimentary house wine or domestic beers and well drinks discounted to $5.

A dedicated work area in the lounge with two computers and a printer.

To get this rate you must book by July 13th. Please call Monique Taylor at 503-335-2857 or use this link: https://www.starwoodmeeting.com/Book/NWRequirementJuly

amended regular session agenda northern wasco … · 2018-06-29 · amended regular session agenda...

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