NWPP taps Southwest Power Pool to design its resource adequacy program
August 11, 2020
by Peter Maloney
APPA News
August 12, 2020
Northwest Power Pool (NWPP) has hired Southwest Power Pool (SPP) to develop a resource adequacy program for a set of 18 member utilities.
Public power participants in the RA program are the Bonneville Power Administration, the Balancing Area of Northern California (with its member, the Sacramento Municipal Utility District),
Chelan Public Utility District (PUD), Douglas PUD, Eugene Water and Electric Board, Grant PUD, Seattle City Light, Snohomish PUD, Tacoma Power and Turlock Irrigation District.
“Over the last few years, there have been several forecasts indicating shortfalls in resources relative to peak load in the 2020-2025 timeframe,” Frank Afranji, NWPP president, said via email. “These forecasts have created a strong incentive for utilities to work together to identify the regional resource adequacy needs.”
Over 5,000 megawatts of gas-fired generation were built in the Northwest between 2001 and 2010, but that pace has slowed recently. Only four gas plants, totaling 1,100 MW, have come online since 2011, according to an October 2019 NWPP report.
In recent years, many utilities in the region switched from building new generating resources to purchasing power through the wholesale market, and renewable development has been increasing. As of 2019, the Northwest had 450 MW of grid-scale solar power resources and 9,400 MW of wind power. Meanwhile, nearly 2,000 MW of coal-fired generating capacity in the Northwest is expected to retire by 2023 with another 1,500 MW expected to retire by 2029, according to the report.
Coal retirements combined with load growth could lead to capacity shortages as soon as this year and, by the mid-2020s, the region could face a capacity deficit of thousands of megawatts, leading to the risk of “extraordinary price volatility” and “unacceptable loss-of-load,” the report says.
The scope of SPP’s work for NWPP is expected to last through 2020 and will span the design phase of resource adequacy program development.
SPP will work with the NWPP and its participating member utilities to expand and refine the preliminary program design into a comprehensive resource adequacy program.
When the resource adequacy program is fully designed, NWPP members plan to conduct a competitive solicitation for a program administrator to implement and run the resource adequacy program.
“Southwest Power Pool has direct experience developing and running a resource adequacy program across multiple states and the skill set to help us determine key program design features to achieve the reliability objectives of the RA program,” Afranji said in a statement. “The program we are developing will be available to participants with different needs and interests across a wide swath of the West and we believe SPP’s multi-state RA program experience will help us develop a program that provides benefits for all participants as well as the region.”
The resource adequacy program would be voluntary to join, but once an entity has joined, they are obligated to fulfill the commitments under the program, Afranji said.
“Enforcement under the program is a design element that has not yet been defined,” he added.
Ditto emphasizes important of managing customer expectations during pandemic
August 11, 2020
by Paul Ciampoli
APPA News Director
August 12, 2020
In recent remarks at a Florida Municipal Electric Association (FMEA) virtual conference, Joy Ditto, President and CEO of the American Public Power Association, underscored the importance of managing customer expectations to ensure that public power utilities can continue to operate safely during the COVID-19 pandemic.
It is vital that customers “understand that what we’re doing is for them. That we’re essential workers, but we have protocols in place to maintain our safety” and that public power has a culture of safety, Ditto said on Aug. 3 in comments during FMEA’s “Powering On” virtual conference.
At the same time, there needs to be a recognition that “we do still need to operate our systems and that comes with a cost. We want to maintain affordable electricity, but we also still need to operate our systems.”
That ongoing communication with customers is key and while it is challenging in a virtual environment, there are ways it can be accomplished through social media and other channels, Ditto said.
Amy Zubaly, Executive Director of FMEA, moderated the session, “The Future of Public Power: How Lessons Learned From COVID-19 Can Help Us Better Serve Our Customers.”
Financial impact of pandemic
As for the financial impact of the pandemic on the power sector, Ditto pointed out that rating agencies continue to maintain stable outlooks on public power utilities.
However, depending on the severity of the economic downturn, there could be an impact on the ability of public power utilities to continue to maintain their systems optimally or access capital, she said.
At the same time, public power’s ability to show that it can make decisions locally “and that we are committed to high levels of reliability, but also affordability, is going to situate us well.”
But some public power communities are being hit harder than others in terms of the economic downturn “and that’s the other piece. That uneven impact is really something that’s going to be challenging, particularly for associations like mine, like FMEA, for joint action agencies to try to help bridge some of that downturn that is more specific to individual communities.”
APPA recently urged its members to reach out to their senators and members of Congress to express support for the inclusion of language in a COVID package that was being negotiated by the White House and House and Senate leadership last week.
Senate Energy and Natural Resources Committee staff for Chairman Lisa Murkowski, R-Alaska, and Ranking Member Joe Manchin, D-W.Va., developed language with APPA and the National Rural Electric Cooperative Association to create a forgivable loan program for public power and rural electric cooperatives impacted by customer non-payments due to the COVID-19 pandemic.
Mutual aid
With respect to mutual aid, Zubaly “does an incredible job” when it comes to managing mutual aid and works in “strong coordination” with APPA’s mutual aid team, Ditto said.
In a Q&A with APPA earlier this year, Zubaly detailed how FMEA was taking a number of steps to ensure that planning for this year’s hurricane season was not disrupted by the COVID-19 pandemic.
Ditto also highlighted the fact that public power utilities have maintained high levels of performance this year during mutual aid events while also making sure that their frontline workers have effective protections against COVID during power restoration activities.
In April, Tennessee public power utility EPB noted that several steps had been taken to minimize the threat of COVID-19 exposure during power restoration work including providing mutual aid crews with gloves and masks.
And public power utility Jonesboro City Water and Light (CWL) took a number of steps to minimize the threat of exposure to COVID-19 for utility crews during a mutual aid effort to restore power to customers in the wake of a tornado that hit Jonesboro, Arkansas, in March.
CWL took several steps to minimize the potential exposure to COVID-19 for workers helping with restoration efforts, which were detailed in a “lessons learned” document that it prepared.
That focus on safety has continued in more recent mutual aid events.
Florida public power utility JEA this month sent crews to New York to help investor-owned utility Con Edison with power restoration efforts in the wake of Tropical Storm Isaias.
Ricky Erixton, JEA interim general manager for electric systems, noted that this was the first time JEA has participated in mutual aid during a pandemic. “We’re sending our guys with sanitizer, masks, all these types of things that help prevent the spread of COVID,” he said in a video posted on JEA’s Twitter feed.
Pandemic may lead to influx of workers
Among the longer-term effects that the COVID-19 pandemic may have on public power is that residents of large cities could decide that smaller towns and communities are more appealing, which in turn could lead to a more highly qualified and diverse workforce, Ditto said.
“This is total speculation on my part and it may not come to fruition, but I just think about how larger cities have been hit” hard by COVID-19 and whether that means city dwellers may find it more attractive to move to smaller towns and communities.
If one of the lasting results of the pandemic is for residents of larger cities to move to smaller towns and communities that could be a benefit to public power in terms of attracting a highly qualified workforce, “which has been a challenge for us sometimes, especially in our smaller communities,” Ditto said.
Also, in the context of public power’s enhanced focus on diversity and inclusion, such a shift could lead to greater diversity in smaller communities, she said.
In June, Ditto issued a statement on justice and equal opportunity in which she said that the electric utility industry must redouble its commitment to diversity at every level. “We’ve seen time and time again that this diversity and inclusion pays dividends, yielding teams that are rich with different backgrounds and ideas,” she said in the statement.
Kansas Municipal Energy Agency buys engineering firm to offer more services
August 11, 2020
by Peter Maloney
APPA News
August 11, 2020
The Kansas Municipal Energy Agency (KMEA) has acquired Mid-States Energy Works, a small engineering company based in Salina, Kansas.
Mid-States provides engineering, testing, troubleshooting, fabrication and installation of electrical equipment and controls.
KMEA, a joint action agency serving public power utilities in Kansas, has 81 members. Mid-States currently works for about half of those members, as well as other public power utilities in Kansas.
“Members had been asking us to get into the service arena,” Paul Mahlberg, KMEA’s general manager, said. The Mid-States acquisition allows for us to provides these types of services now rather than trying to build them up from scratch.”
“The fact that we both have the same vision of helping out the Kansas municipal utilities to be the best they can be… it became a win/win/win situation for Mid-States, KMEA and most importantly for the cities,” Mike Schmaderer, president of Mid-States, said in a statement.
The acquisition grew out of requests that KMEA’s members had been making for years. A couple years ago, KMEA did a strategic plan. As part of that plan, KMEA surveyed its members in 2019. The top response, according to Mahlberg, was for KMEA to expand the services it offers members. At the top of that list was line maintenance, followed by engineering, project management, substation maintenance and construction and power plant troubleshooting.
Around the same time, KMEA had embarked on a separate venture with one of its members, the City of Dighton. For 20 years, the city had contracted for line maintenance with the local rural electric cooperative, but it was now ready for a change.
KMEA hired a couple of linemen and signed a two-year agreement with the city to provide the labor for the operation and maintenance of the city’s distribution system, including preventative maintenance, repair, equipment testing and repair, connection and disconnection services, tree trimming, and streetlight maintenance. The “partnership with KMEA will provide us more control and involvement in maintenance and health of our electric system,” Dighton Mayor Doyle Capra said in a statement.
The Dighton partnership turned out to be a “parallel path” for KMEA, a path that “blended together” with the Mid-States acquisition, Mahlberg said. Dighton was its first member to receive KMEA’s new services, and now with a journeyman lineman and apprentice on board, the crew, along with the Mid-States staff, will be available to assist other KMEA members, Mahlberg said.
The relatively small size of many of KMEA’s members – the agency’s average member has 1,500 meters and some have as few as 100 – means that it is difficult for many of those utilities to be able to afford a full-time electrical maintenance staff.
In addition to having a dedicated maintenance staff it can share with its members, Mahlberg says KMEA will be able to offer services to its members at close to cost. In the near term, KMEA plans to amortize the purchase price into its rates, but over the longer term the agency plans to lower its fees and expand its services, Mahlberg said.
“We are doing more strategic thinking about how to grow the business.”
Among the services KMEA is looking at are preventive plans for substation maintenance, and it is also starting to look at a mobile substation that could be used anywhere throughout the state, Mahlberg said.
SRP Substation Troubleman Helps Save The Life Of A Car Crash Victim
August 3, 2020
by Paul Ciampoli
APPA News Director
August 3, 2020
Salt River Project Substation Troubleman John Boyle recently helped to save the life of a car crash victim in Mesa, Ariz.
Forrest Smith, Deputy Chief for the Mesa Fire and Medical Department, noted during a virtual presentation for a certificate of appreciation given to Boyle that the victim of the car crash was rescued “thanks to the quick actions” of Boyle.
Boyle was performing a line patrol inspection on July 6 when he came upon a car that had crashed into a ravine. When he saw movement in the vehicle he called 911.
“To help identify where the scene is, I am in a marked SRP single cab vehicle on top of the canal,” Boyle told a 911 operator.
Boyle approached the vehicle and administered first aid. He told the car crash victim that help was on the way.
Mary Cameli, Fire Chief for the Mesa Fire and Medical Department, told Boyle that “it’s folks like you that make the difference in terms of taking action when you see something and take the time needed to get us there to the call. You truly, truly made a difference in saving a life.”
“At SRP, we exist to serve our customers, and are stewards of the community,” said Nate Tate, SRP’s Director of Substation Design, Construction and Maintenance. “We take the health and safety of our community very seriously and the actions that you took that day exhibit our values,” Tate told Boyle. “We’re extremely proud of you.”
Boyle also received plaudits for his efforts from Craig Perez, SRP Section Supervisor, and Barry Kropp, SRP Manager of Field Maintenance.
“I’m just really proud of the training that I’ve had to provide situational awareness, public safety, the stewardship of some of the job roles that I have, both as a person, an employee, a community member,” Boyle said.
Boyle received the certificate of appreciation from the City of Mesa, the Mesa Fire and Medical Department and the Mesa Police Department.
Calif. CCAS Reach Agreement To Install Up To 20 MW Of Solar And Battery Backup Power
August 3, 2020
by Paul Ciampoli
APPA News Director
Posted August 3, 2020
Three California community choice aggregators have reached agreement with Sunrun to install up to roughly 20 megawatts of solar and battery backup power to 6,000 households vulnerable to emergency power shutoffs during the state’s wildfire season.
East Bay Community Energy, Peninsula Clean Energy and Silicon Valley Clean Energy have agreed with Sunrun to increase renewable power, reduce overall peak demand and improve grid reliability by putting this increased capacity online on a rolling basis from 2020 through 2022.
All three agencies have carve outs in their contracts for low-income customers, disadvantaged communities and vulnerable residents in Alameda, San Mateo and Santa Clara counties, including those hit by last year’s Pacific Gas & Electric emergency power shutoffs.
The contracts are part of a joint solicitation last November from the three CCAs and Santa Clara municipal utility Silicon Valley Power that was issued shortly after emergency power shutoffs last fall affected hundreds of thousands of customers in the Bay Area.
By reducing peak power demand, these contracts will effectively enable the use of local resources to help fulfill state resource adequacy requirements.
This requirement has historically been filled through purchasing resource adequacy supplies from distant power plants.
The new contracts will shift the purchase of resource adequacy to new local solar power and battery storage systems that provide the benefits of backup power directly to local homes and businesses, the CCAs noted in a July 30 news release.
“The wildfires that disrupted our power and lives last fall have given us an opportunity to find ways to better protect our most vulnerable customers from losing essential supplies and comfort during emergency outages. By partnering with Sunrun and our local non-profit agencies, we can identify those customers who can benefit the most from this program,” Peninsula Clean Energy CEO Jan Pepper said.
Additional information about Sunrun is available here.
The American Public Power Association has initiated a new category of membership for community choice aggregation programs.
FERC, NERC White Paper Aims To Help Identify Supply Chain Vendors To Mitigate Possible Risks
August 3, 2020
by Paul Ciampoli
APPA News Director
Posted August 3, 2020
The Federal Energy Regulatory Commission (FERC) and the North American Electric Reliability Corporation (NERC) on July 31 published a joint white paper to help the electric utilities identify specific vendors of components on their networks so that they can take any necessary action to mitigate potential risks to the bulk power system (BPS).
The purpose of the white paper is to provide example approaches on assessing infrastructure and the deployment of specific foreign adversary components that could be used to impact the BPS. While there are several noninvasive methods highlighted in the document, industry may have other methods to identify foreign vendor equipment or components, FERC and NERC noted.
“In addition, industry should consider developing and implementing a process to not only initially identify vendor suppliers, but also to implement an overarching process that could be periodically re-performed and assessed against previous results.”
The white paper notes that in 2012, the House Permanent Select Committee on Intelligence released a bipartisan report assessing the security threat posed by Chinese telecommunication companies. This report recommended against the use of Huawei or ZTE equipment by U.S. government agencies and federal contractors and encouraged the private sector to exclude such equipment as well.
Due to the pervasiveness of these manufacturers throughout the marketplace, the electric sector may unknowingly be using devices from foreign adversaries that could negatively impact the BPS, FERC and NERC said.
To facilitate the identification of these devices, this report details possible techniques that noninvasively identify one component, the network interface controller (NIC), which generally takes the form of an integrated circuit chip integrated into a motherboard or upon a host bus adapter card.
According to the white paper, research has demonstrated numerous avenues to compromise systems using NICs as a method for undetected access for an attacker. “While the techniques described in this report will aid in identifying the NIC vendor, please note that the presence of foreign vendor equipment does not necessarily indicate malicious activity,” FERC and NERC said.
The report identifies the noninvasive techniques that security professionals may employ to identify a vendor of a NIC. “This approach selects the NIC as a well-known and often-targeted component and contemplates methods for easy identification of devices often not readily labeled by suspect vendors or that may integrate suspect vendor components.”
The techniques described in the report are not the only methods of detection nor do they encompass the only concerns industry should have about malicious activity and attacks, the white paper said.
FERC and NERC said that before implementing any approach detailed in the white paper, “caution dictates complete testing in a non-production network to minimize or eliminate operational impacts. If a vendor of concern is identified, it does not confirm there is malicious activity in the network. Actions should be taken to determine if the device or component exhibits malicious activity.”
The white paper is available here.
MEAG Power, JEA, And Jacksonville Unveil Settlement of Litigation Tied to Vogtle PPA
July 31, 2020
By Paul Ciampoli
APPA News Director
Posted July 31, 2020
Florida public power utility JEA, the City of Jacksonville and the Municipal Electric Authority of Georgia (MEAG Power) on July 30 announced a settlement of all disputed issues relating to the new Units 3 and 4 of the Alvin W. Vogtle Electric Generating Plant, a nuclear power generating facility in Georgia, and an amended and restated power purchase agreement.
The JEA board, the City of Jacksonville and the MEAG Power Board approved the settlement.
Terms of the settlement include JEA and the City of Jacksonville dismissing their civil action against MEAG Power currently pending in U.S. District Court, and MEAG Power dismissing its lawsuits against JEA currently pending in U.S. District Court and the U.S. Court of Appeals.
Also, JEA, the City of Jacksonville and MEAG Power agree to accept without challenge or appeal a June 17 order entered by U.S. District Judge Mark Cohen, including without limitation his determination that the JEA PPA is valid and enforceable. Terms also include certain provisions that will create additional future value to both JEA and MEAG Power, JEA and MEAG Power said in a news release.
In his June 17 ruling, Cohen said that a power purchase agreement between JEA and MEAG Power tied to the expansion project at Plant Vogtle was valid and enforceable.
Under the terms of the PPA, which was signed in 2008, and amended and restated in 2014, JEA committed to purchase all of the energy generated by the new units 3 and 4 of the Vogtle plant, as part of “Project J,” during their first 20 years of operation, as well as to pay for approximately 41 percent of MEAG Power’s share of the construction cost for the new units during those 20 years.
JEA and the City of Jacksonville, Fla., in 2018 filed a complaint in Florida state court for declaratory judgment regarding the PPA. The complaint was filed in the Fourth Judicial Circuit Court of Florida on the same day that MEAG Power filed a breach of contract lawsuit against JEA.
Plant Vogtle Units 3 and 4 are two 1,100-megawatt Westinghouse AP1000 nuclear reactors being constructed in Burke County, Ga.
MEAG Power’s co-owners in the Vogtle expansion project are Georgia Power (45.7 percent), Oglethorpe Power (30.0 percent) and Dalton Utilities (1.6 percent).
MEAG Power provides wholesale electricity to 49 member communities in Georgia, who own their local distribution systems. JEA, which is located in Jacksonville, Fla., serves an estimated 478,000 electric, 357,000 water, 279,000 sewer customers and 15,000 reclaimed water customers.
EPA Final Rule Makes Changes To CCR Regulations, Finalizes Deadline For Units To Initiate Closure
July 31, 2020
by Paul Ciampoli
APPA News Director
Posted July 31, 2020
The Environmental Protection Agency (EPA) on July 29 finalized several changes to the regulations for coal combustion residuals, known as CCR or coal ash.
The final rule released by EPA implements a court’s vacatur of certain closure requirements as well as adds provisions that enhance the public’s access to information about the management of coal ash at electric utilities, EPA said.
Under the final rule, the revised deadline for all unlined CCR surface impoundments and surface impoundments that fail an aquifer location restriction to initiate closure or retrofit is April 11, 2021. This date replaces the existing October 31, 2020 date. The new date is based on data APPA members and utility interest groups provided EPA during the proposed public comment period, which outlined technically feasible planning and construction timelines.
The rule is also known as the Part A rule is just one of a suite of rules EPA is in the process of issuing in response to court orders. On a call with stakeholders to roll of the final rule Administrator Wheeler also noted the EPA is working to issue its final rule Part B rule, to provide a new liner equivalency provision allowing facilities to demonstrate that certain clay-lined units and other alternative liner systems perform as well as the composite liner criteria in the rule later this year.
The final rule, “Hazardous and Solid Waste Management System: Disposal of Coal Combustion Action: Residuals from Electric Utilities; A Holistic Approach to Closure Part A: Deadline to Initiate Closure,” expressly extends the existing alternative closure provisions to include both CCR and non-CCR waste streams.
Under the final rule, requests to qualify for an alternative closure extension must be submitted to EPA or an authorized state by November 30, 2020.
In addition, the maximum amount of time available to continue operation under the site-specific alternative closure provision for unlined impoundments is October 15, 2023.
However, the date is October 15, 2024 for unlined impoundments that meet all location restrictions, the safety factor assessment, and have not detected a statistically significant increase above an applicable groundwater protection standard.
The timeframes for the alternative closure provision involving the cessation of coal-fired generation remain the same as in the existing rule. Unlined impoundments that are 40 acres or smaller would have to cease the receipt of waste and complete closure by October 17, 2023, while unlined impoundments larger than 40 acres would have to cease the receipt of waste and have completed closure by October 17, 2028.
Meanwhile, EPA is finalizing two of the proposed amendments from the August 2019 rule — the addition of an executive summary to the annual groundwater monitoring and corrective action reports and the amended requirements to the publicly accessible CCR Internet sites.
The final rule becomes effective 30 days after publication in the Federal Register. A pre-publication version of the Federal Register notice is available here.
APPA files comments on proposed CCR permit program
In related news, the American Public Power Association on July 20 filed comments on EPA’s proposed federal CCR permit program.
APPA is generally supportive of the proposed rule as it would establish a federal permitting backstop as opposed to the self-implementing 2015 CCR rule.
In a related matter, EPA is reopening the public comment period for the proposed Federal CCR Permit Program for an additional 7 days.
EPA decided to reopen the comment period to allow submittal of additional comments on the proposal due to an error involving the premature closing of the docket on www.regulations.gov, the electronic portal through which comments can be submitted on agency rulemakings.
The comment period for the federal permit program proposal was closed on Sunday, July 19 instead of Monday, July 20.
APPA said that members may want to re-submit their comments via the www.regulations.gov portal even if they previously emailed or mailed comments. Comment will be due on or before August 7, 2020. Click here for the Federal Register notice.
APPA, Other Groups Ask Court To Review FCC 6 GHz Report And Order
July 30, 2020
by Paul Ciampoli
APPA News Director
Posted July 30, 2020
The American Public Power Association, the Utilities Technology Council (UTC) and National Rural Electric Cooperative Association (NRECA) on July 27, asked the U.S. Court of Appeals for the District of Columbia Circuit to review a Federal Communications Commission (FCC) Report and Order (R&O) to open the 6 GHz band of spectrum to unlicensed usage.
The FCC issued its R&O to open the 6 GHz band of spectrum to unlicensed usage in May, which went into effect July 27.
The R&O allows two types of unlicensed operations, low powered indoor use and outdoor use protected with automated frequency coordination technology.
APPA, along with a broad coalition of incumbent license holders, offered extensive comments during the R&O consideration raising concerns regarding interference to operations that could result from opening the band to unlicensed users and requesting further testing and protections from the FCC.
The petition seeks review by the court that the FCC R&O violates the Administrative Procedures Act “on the grounds that it is arbitrary, capricious, and an abuse of discretion.”
The petition asks the court to hold that the FCC’s R&O unlawfully authorizes unlicensed low power indoor operations without sufficient safeguards to prevent harmful interference to licensed operations.
APPA, UTC and NRECA also want the court to hold that the FCC was arbitrary and capricious in failing to adequately consider studies on the record that show that unlicensed operations will cause harmful interference to licensed systems.
In addition, the court should vacate those portions of the R&O it finds to be arbitrary and capricious or otherwise unlawful or defective, the petition said.
The court should also remand to the FCC for proceedings consistent with the court’s findings and/or “provide such other relief as the court deems appropriate.”
No timetable has been set by the court, but it is unlikely the court will hear the case before 2021 at the earliest.
In recent joint comments submitted to the FCC, APPA and several other trade groups argued that the FCC should refrain from further expansion of unlicensed operations in the 6 GHz band “until such time that additional testing has been conducted to prove that unlicensed operations will not cause harmful interference to licensed microwave systems.”
Kentucky Municipal Energy Agency Issues RFP For Intermediate Capacity And Energy
July 30, 2020
by Paul Ciampoli
APPA News Director
Posted July 30, 2020
The Kentucky Municipal Energy Agency (KYMEA) is seeking proposals to supply intermediate electric capacity and energy to it starting June 1, 2022 for terms of three to 20 years.
KYMEA on July 24 said that it prefers to purchase capacity and energy from resources delivered by a seller to MISO Zone 6, the LGE/KU transmission system or a distribution system of one of KYMEA’s members.
KYMEA, an inter-local agency which provides electric power and related services to municipal utilities, anticipates considering purchases ranging from 30 megawatts to 60 MW.
This invitation and all proposals are subject to the provisions of KYMEA’s request for proposals (RFP), which provides specifications for the solicitation.
The RFP specifically provides that prospective proposers must contact only Rob Leesman at KYMEA to obtain information about this solicitation, KYMEA noted.
Contacts by prospective proposers with KYMEA Board members and other representatives of KYMEA or its members will be a cause for disqualification of proposals as further explained in the RFP.
The RFP requires submittal of a proposal responsive to the solicitation and containing data at a level sufficient for KYMEA to screen alternatives to determine if the proposal is reasonably susceptible of being accepted for award based upon the evaluation factors set out in the RFP.
Potential proposers may request a copy of the RFP by emailing KYMEA at: rleesman@kymea.org.
Those requesting the RFP are asked to provide the organization’s legal name and address and a primary contact name, email address and phone number.
Proposals must be received by email no later than 2 pm EDT on August 19, 2020.