FAQs

Questions submitted through this site are generally answered by the Procurement Administrator within two business days. A response will be sent directly to the questioner. If a question is not within the scope of the Procurement Administrator’s role or expertise, the Procurement Administrator may, instead of providing an answer, refer the questioner to an alternative source of information. All questions and answers are posted to this site, unless the question and answer repeat information already provided on the FAQ page or generally do not provide additional information that may be relevant to prospective suppliers.

Do you have a question? Please click here.

To receive updates and information regarding the RFPs directly, please click here to use our automated form to register to our mailing list.

Click here to view Block Energy FAQs.
Click here to view Utility DG FAQs.
Click here to view Wind and Solar FAQs.
Click here to view General FAQs.

FAQs with information that is no longer relevant are posted to the FAQ Archives page.


Block Energy FAQs
Click on the question to see the answer:

FAQ-BE-1
Q: Have the requirements for participating in the Block Energy / Standard Products RFP been established? Are these the same for all procurement events and RFPs?

The requirements for participating in the procurement events under the 2017 Illinois Power Agency Procurement Plan differ depending on the procurement event type. The requirements for a procurement event are stated in the RFP Rules for that procurement event. The DRAFT RFP Rules for the Block Energy/Standard Products RFP are available here:

https://www.ipa-energyrfp.com/spring-block-energy/draft-documents/

Final RFP documents are expected to be released on March 7, 2017. If you are inquiring about another RFP, please submit a follow-up question.

02-28-2017

FAQ-BE-2
Q: I would like to suggest one small change to the Pre-Bid Letter of Credit for each Company. If I remember correctly we have used that modification in the past. Can I suggest it again or can I assume that it will be acceptable to the Company?

The Procurement Administrator will not be soliciting comments on the Pre-Bid Letters of Credit for Ameren Illinois Company (“AIC”), Commonwealth Edison Company (“ComEd”), or MidAmerican Energy Company (“MEC”) since any changes to these documents consist solely of administrative updates.

The Pre-Bid Letter of Credit submitted for a procurement event for a Company in response to the STP RFP must be in the form of the Standard Pre-Bid Letter of Credit for that Company or incorporate only modifications approved by the Company as posted to the procurement website.  Please check whether the modification you seek is in the list of modifications posted here:

https://www.ipa-energyrfp.com/spring-block-energy/final-materials/

in the document with a title that begins “Acceptable Modifications” and that is posted directly underneath the Pre-Bid Letter of Credit for each Company.

If the modification you seek is NOT found in this document, you must assume that such a modification is NOT currently acceptable to the Company and that any Pre-Bid Letter of Credit that includes that modification will automatically be deficient.

03-09-2017

FAQ-BE-3
Q: How can I get the appropriate banking instructions for a utility’s Pre-Bid Letter of Credit?

Please email your request to the Procurement Administrator and you will receive the Standard Pre-Bid Letter of Credit with the appropriate banking instructions included.

03-13-2017

FAQ-BE-4
Q: Where can I find instructions for payment of the bid participation fee?

Instructions for payment of the bid participation fee are available from the Procurement Administrator. Please send your request via email.

03-13-2017

FAQ-BE-5
Q: Will the IPA accept payment of the bid participation fee via ACH or via wire transfer?

No. The only options for payment of the bid participation fee are by check or e-pay, according to the instructions provided by the Procurement Administrator.

03-13-2017

FAQ-BE-6
Q: The individual who usually serves as Officer of the Bidder is not available during the Part 1 Window but will be available during the Part 2 Window before the Part 2 Date. What should we do in the meantime for purposes of submitting the Part 1 Proposal?

Please name another individual with the appropriate qualifications to serve as Officer of the Bidder during the Part 1 Window. If the individual who usually serves as Officer of the Bidder returns prior to the Part 2 Date as you expect, and you wish for this individual to return to his role as Officer of the Bidder, then this individual would have to re-do all certifications of the Part 1 Proposal and submit these with the Part 2 Proposal.

03-14-2017

FAQ-BE-7
Q: For the Pre-Bid Letter of Credit due for each procurement event, can we rely on the documents that we submitted last year and issue the same document this year? How about for the guaranty?

You cannot rely on the documents submitted last year as the basis for documents submitted as part of your Proposal this year. There are several reasons for this, including the fact that there are administrative changes to the Pre-Bid Letter of Credit every year and the fact that ComEd has made changes to its standard form of guaranty.

A Bidder must submit the Standard Pre-Bid Letter of Credit for a Company or incorporate only modifications approved by the Company as posted to the procurement website. The Standard Pre-Bid Letters of Credit are available from the Procurement Administrator upon request.

A Bidder that relies on the financial standing of a Guaranty for the procurement event of a Company must use the standard form of Guaranty or incorporate only those modifications acceptable to the Company. For each Company, the form of Guaranty and the acceptable modifications thereto are included in the applicable supplier contract. For AIC and MEC, please review Schedule 1 to the Form of Guaranty within the Confirmation Agreement document. For ComEd, the form of Guaranty is provided here: https://www.ipa-energyrfp.com/?wpfb_dl=1101 and the optional changes are available here: https://www.ipa-energyrfp.com/?wpfb_dl=1102.

03-14-2017

FAQ-BE-8
Q: We will be unable to provide all required documents for our guarantor. The Bidder itself is not rated and does not have separate financial statement. We wish to use a letter of credit to fulfil the creditworthiness requirements under the applicable supplier contracts. How do we present this in our proposal?

One way to present your proposal is to indicate that the Bidder is relying on its own financial standing (by selecting “The Bidder is the Entity” in Section 3) and to indicate that financial statements are unavailable for the Bidder (by clicking “If the Entity is the Bidder and the information is not available, please click here” where required in Section 3).   You may also indicate in the Justification of Omissions that the Bidder does not have separate financial results or ratings.

03-14-2017

FAQ-BE-9
Q: Are we able to participate in the Block Energy/Standard Products RFP if the Entity on whose financial standing the Bidder relies is not rated or does not have financial documents (e.g. SEC Form 10-K, SEC Form 10-Q, etc.)?

Yes, a Bidder unable to provide the required financial documentation (either for the Bidder or a Guarantor) is eligible to participate in the RFP. Such Bidder, however, will not be extended any unsecured credit under the terms of the applicable supplier contract.

03-14-2017

FAQ-BE-10
Q: We would like our IT department to ensure that we can access the secure electronic file transfer interface for submission of bids. Can we get advance notice of the URL?

Details regarding the secure electronic file transfer interface is available from the Procurement Administrator upon request.

03-14-2017

FAQ-BE-11
Q: Can a Bidder in the Block Energy/Standard Products RFP submit cash instead of a Pre-Bid Letter of Credit to support its Bids?

No. With the Part 2 Proposal, a Bidder that intends to submit Bids for a Company’s Products and/or Combinations must submit an executed Pre-Bid Letter of Credit to that Company in an amount sufficient to support the Bids.  You must either use the Standard Pre-Bid Letter of Credit provided as an Appendix to the RFP Rules, or the Pre-Bid Letter of Credit must incorporate only those modifications to the Standard Pre-Bid Letter of Credit approved by the Company and posted to the procurement website.  Please see the list of acceptable modifications posted immediately below each Pre-Bid Letter of Credit on the Final Materials page of the Spring Block Energy section of the procurement website.

03-20-2017

FAQ-BE-12
Q: Is it possible to negotiate terms and submit comments on the applicable supplier contracts?

No. The deadline to submit comments on the form of the supplier contracts for the Spring 2017 Block Energy/Standard Products RFP (“STP RFP”) was February 21, 2017.  The final supplier contracts were posted to the Final Materials page of the Spring Block Energy section of the procurement website on March 6, 2017. There is no additional process by which comments on the contracts can be made. To participate in the STP RFP, a Bidder must accept the terms of the applicable standard contract.

03-20-2017

FAQ-BE-13
Q: When are the Pre-Bid Letters of Credit due under the Block Energy/Standard Products RFP?

Part 2 Proposals, including the Pre-Bidder Letters of Credit, are due by 12 PM (noon) CPT on March 29, 2017.

03-20-2017

FAQ-BE-14
Q: Where can I find the instructions on where to send the Pre-Bid Letter of Credit for each Company?

The Procurement Administrator confirms these instructions with each Bidder. You may also see Paragraphs V.2.3, V.3.3, and V.4.3 for the instructions on where to send the Pre-Bid Letter of Credit for AIC, ComEd, and MEC respectively.

03-20-2017

FAQ-BE-15
Q: Are we required to provide the Contract Delay Insert if we have provided the applicable Contract Insert?

No.

03-20-2017

FAQ-BE-16
Q: How can we confirm that our bank will be acceptable to each Company for purposes of issuing the letter of credit?

The requirement for the Pre-Bid Letter of Credit is that the bank must represent that it is as of the date of issuance of the letter of credit, its senior unsecured debt is rated “A” or better by Standard & Poor’s (“S&P”) if rated by S&P, “A2” or better by Moody’s Investors Service (“Moody’s”) if rated by Moody’s, and, “A” or better by Fitch Ratings (“Fitch”) if rated by Fitch.

You may ask the Procurement Administrator for confirmation for a particular bank. Please note that the requirements for a financial institution issuing a Letter of Credit during the term of the applicable supplier contract may be different. As such, this response only applies to the Pre-Bid Letter of Credit and not to the letters of credit during the term of the applicable supplier contracts.

03-20-2017

The legal notices and terms of use for the Sharefile website can be found here: https://www.citrix.com/about/legal/legal-notice/.

03-23-2017

FAQ-BE-18
Q: The Procurement Administrator sent to Bidders the Pre-Bid Letters of Credit via email. Are these documents the same as those posted to the Final Materials section on 3/17/2017?

The documents are the same except that the Letters of Credit sent to bidders via email include the bank information in Paragraph 7.

03-31-2017

FAQ-BE-19
Q: Will the utility accept additional terms added to the end of the Pre-Bid Letter of Credit?

The Pre-Bid Letter of Credit submitted for a procurement event for a Company in response to the STP RFP must be in the form of the Standard Pre-Bid Letter of Credit for that Company or incorporate only modifications approved by the Company as posted to the procurement website. Please check whether the modification you seek is in the list of modifications posted here:

https://www.ipa-energyrfp.com/spring-block-energy/final-materials/

in the document with a title that begins “Acceptable Modifications” and that is posted directly underneath the Pre-Bid Letter of Credit for each Company.

03-31-2017

FAQ-BE-20
Q: To support a bid on a combination, must the Pre-Bid Letter of Credit be for $5,000 for one block of the combination or must the Letter of Credit be for $5,000 times the number of months in the combination? For example, to support a bid on one October-November-December combination block, would I be required to post $5,000 for that block, or would I be required to post $15,000 for that block?

The $5,000 is an amount per block and per month for a combination of a given year and segment.  In your example, to bid on an October-November-December combination, the security requirement is $15,000 (three times $5,000 because there are three months).

03-31-2017

FAQ-BE-21
Q: If we are a current supplier to a Company and we have winning bids in the Block Energy/Standard Products RFP again this year, will we be required to execute the 2017 Agreement or will we simply be executing a Confirmation under our existing Agreement?

Each Bidder with bids approved by the Commission will be required to execute the 2017 Agreements.

03-31-2017

FAQ-BE-22
Q: What are the Supplier Fees for the Spring 2017 procurement event under the Block Energy/Standard Products RFP?

The Supplier Fees are as follows:

$ 92 per off-peak block

$ 138 per on-peak block

03-31-2017

FAQ-BE-23
Q: What accounts for the change in the Targets in the Block Energy/STP RFP?

The provisional Targets provided in the RFP Rules reflect the load forecasts provided by Ameren Illinois Company, Commonwealth Edison Company, and MidAmerican Energy Company in the 2017 Electricity Procurement Plan filed with the Illinois Commerce Commission by the Illinois Power Agency (“IPA”). The provisional Targets are based on July 2016 load forecasts. The Procurement Plan calls for the utilities to update their load forecasts in March 2017. The final Targets are based on these March 2017 load forecasts provided by the utilities to the IPA.

For more information regarding the load forecasts, please see Section 3 of the 2017 Procurement Plan available here: https://www.illinois.gov/sites/ipa/Pages/2017-Procurement-Plan.aspx.

04-02-2017

FAQ-BE-24
Q: When the evaluation of bids is complete, will bidders receive a communication by email or via secure electronic file transfer?

Each bidder will have received a communication via secure electronic file transfer of whether any of its Bids have been identified as winning Bids to the Commission.

04-04-2017

FAQ-BE-25
Q: What is the process after the Bid Date?

Please see paragraph VI.2.11 and VI.2.13 of the RFP Rules.

Within two (2) business days of the Bid Date, the Procurement Administrator will submit to the ICC a confidential report that will provide the results of the procurement event(s) on the Bid Date as well as a recommendation on whether these results should be accepted or rejected. Within two (2) business days of the Bid Date, the Procurement Monitor will submit to the ICC a confidential report regarding the results of the procurement event(s) on the Bid Date as well as a recommendation on whether these results should be accepted or rejected.  The ICC will decide whether to accept or reject the results of each procurement event within two (2) business days of receiving the confidential reports from the Procurement Administrator and the Procurement Monitor regarding the procurement event.

If the ICC accepts the results of a procurement event for a Company, the Procurement Administrator will notify all Bidders that submitted Bids in that procurement event whether some or all of their Bids were accepted by the ICC. Bidders that have some or all of their Bids for the procurement event for a Company accepted by the ICC are called winning Bidders for that procurement event of that Company. The Procurement Administrator notifies each winning Bidder of the number and price of blocks won for each month and Segment for that Company. The Procurement Administrator also provides to the Company procuring blocks through that procurement event the name of each winning Bidder, and for each such winning Bidder, the number and price of blocks won for each month and Segment.  For each Segment of each month, the price paid to the winning Bidder is the average of the Bidder’s own winning Bids for all blocks of that Product and for all blocks of a Combination that includes that Segment of that month.  Such notification is made as soon as practicable after the ICC decision.

04-10-2017

FAQ-BE-26
Q: When can we expect an invoice for the Supplier Fees? Will these come from the Procurement Administrator or from the IPA?

You should expect an invoice for the Supplier Fees directly from the IPA on April 7, 2017.

04-10-2017

FAQ-BE-27
Q: In the three days that we have available to fully execute the Agreements, will the utilities accept a signature page by facsimile or electronic means?

Please see each of the terms of the applicable supplier contracts. Delivery of an executed counterpart of a signature page by facsimile or electronic means is sufficient.

04-10-2017

FAQ-BE-28
Q: What is a seller paid under the contract for a given segment and month for which the seller has winning bids?

For each Segment of each month for a Company, a seller is paid the average of the seller’s approved Bids for all blocks of a Product and for all blocks of a Combination that includes that Segment of that month for a Company.

04-20-2017

FAQ-BE-29
Q: Is it a requirement to be a registered MISO Market Participant prior to participating in the Fall 2017 procurement event for capacity?

The RFP Rules, which would include the qualification standards, and the AIC Capacity Agreement, have not yet been posted. For the Fall 2016 procurement event for capacity, Bidders were not required to be a registered MISO Market Participant prior to participating in the procurement event.

05-17-2017

FAQ-BE-30
Q: When is the webcast for the Fall 2017 Block Energy and Capacity RFP (“BEC RFP”) scheduled?

The webcast for the Fall 2017 Block Energy and Capacity RFP (“BEC RFP”) is scheduled for Wednesday, July 26, 2017.  If you have not done so already, RSVP now! Additional information regarding the webcast will be provided as it becomes available.  The call-in and WebEx login information will be provided early on the day of the webcast.

06-25-2017


Utility DG FAQs
Click on the question to see the answer:

FAQ-DG-1
Q: Will there be a further procurement event under the Supplemental Photovoltaic Procurement Plan? What are other renewable energy procurements are planned thus far for 2017?

The Supplemental Photovoltaic Procurement Plan developed by the IPA and approved by the Illinois Commerce Commission allows for a possible fourth procurement event in Spring 2017, called the Supplemental Photovoltaic Contingency Procurement. The Agency has determined that it is not necessary to conduct a Supplemental Photovoltaic Contingency Procurement.

The following renewable energy procurement events for 2017 are planned and tentative schedules have been released:

  • Two procurements for distributed renewable generation resources on behalf of Ameren Illinois, ComEd, and MidAmerican pursuant to the Agency’s 2017 Procurement Plan. The first of these procurement events is planned for this Spring and the schedule is available here:

   https://www.ipa-energyrfp.com/calendar/

  • Once Public Act 99-0906 becomes effective on June 1, 2017, the IPA expects to conduct an initial forward procurement event for Wind/Solar in summer 2017. The expected schedule, which is provided here:

   https://www.illinois.gov/sites/ipa/Documents/2017-Schedule-Announcement.pdf

   has bidder registration beginning June 22, 2017 and a Bid Date of August 10, 2017.

Additional forward solar procurement events will be scheduled at a later date. All such schedules will be posted to the Calendar page of the procurement website.

If you have not already done so, we suggest that you complete the form to Register to receive updates and information regarding the RFPs. These updates will include announcements of upcoming procurement events.

02-28-2017

FAQ-DG-2
Q: Does the IPA certify behind-the-meter Distributed Generation solar facilities for generating and tracking Illinois SRECs?

Illinois does not have a state process for certification of renewable energy facilities.

Separately the IPA has developed standards for the metering requirements of renewable energy PV facilities that are bid in to the IPA’s procurement events. The standards are found here:

https://www.illinois.gov/sites/ipa/Documents/IPA-metering-accuracy-standard-5-14-15.pdf

For information on generating and tracking of RECs, please contact M-RETS or GATS:

M-RETS Registry
Contact: Bryan Gower, M-RETS Administrator
Email: mrets@apx.com
Phone: 408-899-3340

gatsadmin@pjm-eis.com
(877) 750-GATS (4287)

For additional information on procurement events planned for 2017, as well for the change in definition of distributed renewable energy generation device pursuant to Public Act 99-0906 (which becomes effective on June 1, 2017), please consult:

https://www.illinois.gov/sites/ipa/Pages/News.aspx

https://www.illinois.gov/sites/ipa/Pages/Renewable_Resources.aspx

02-28-2017

FAQ-DG-3
Q: Is it expected that both existing and new projects will be allowed to participate in the Utility DG RFP?

It is expected that the procurement events under the Utility DG RFP will allow participation from both new and existing systems (please consult the Utility DG RFP when it is release for full eligibility criteria).

02-28-2017

FAQ-DG-4
Q: We are an aggregator and we are asking that certain parameters of the upcoming Utility DG RFP be announced by February 28, namely the capacity factors to be used and the actual Supplier Fee. Is that feasible?

With respect to the Supplier Fee, the IPA’s 2017 Procurement Plan (https://www.illinois.gov/sites/ipa/Documents/2017ProcurementPlan/ICCFiling/2017%20IPA%20Procurement%20Plan%20for%20ICC%20Filing%20%28Final%209-27-16%29.pdf)

states that “an estimated Supplier Fee per REC  will be announced prior to the opening of bidder registration, and the final Supplier Fee per REC will be announced after bidder registration is completed but prior to the bid due date.”  Typically the estimated Supplier Fee is provided during the webcast held prior to the opening of bidder registration, scheduled for March 27.  It is not feasible to provide an estimate of the Supplier Fee on February 28.  In response to your request, we will endeavour to provide an estimated Supplier Fee by March 3.  This estimate will be such that the actual Supplier Fee that will be announced once registration is completed but prior to the bid due date will be NO HIGHER than the previously announced estimated Supplier Fee.

With respect to the capacity factors, the final capacity factors were expected to be made available when the final RFP Rules are released, which is scheduled for March 27, 2017.  It is not feasible to provide final capacity factors by February 28.  Please take note of the capacity factors that were used in prior DG procurement events, available on p.6 of this document:

https://www.ipa-energyrfp.com/?wpfb_dl=901

In response to your request, we will endeavour to provide any updates to these capacity factors by March 3 as well.  Such updates will provide to bidders the final capacity factors and these capacity factors will not be subject to further change when the final RFP Rules are released.

02-28-2017

FAQ-DG-5
Q: Can a distributed generation system interconnected at the distribution level of a municipal utility or a rural electric cooperative in Illinois eligible to be bid in the DG RFP?

Yes.

02-28-2017

FAQ-DG-6
Q: For the Utility DG RFP, one of the systems that I could include is one where the system will be built on a site owned by someone other than the owner of the system. Is such a system eligible for participation?

The “host” for a system is the individual or entity that owns or controls the site where the system will be installed.  In the case you present, the host is a different individual or company from the owner of the system (the individual or company that will have title to the RECs produced by the system).

Systems for which the owner and the host are different individuals or companies are eligible for participation in the DG RFP.  However, such systems are typically required to submit additional documentation in the form of a “Host Acknowledgment”.  A Host Acknowledgment is a statement from the host that the host knows about the planned system and agrees to the system being installed.  A sample of the Host Acknowledgment from a prior procurement event is provided here:

https://www.ipa-energyrfp.com/2016-renewable-energy-resources-section/

(click on Appendix 5 under Spring 2016 Distributed Generation FINAL RFP Documents).

02-28-2017

FAQ-DG-7
Q: What was the Supplier Fee for the Spring 2016 Utility DG RFP?

The Supplier Fee for the Spring 2016 Utility DG RFP was $11.25 per REC for the quantity of RECs associated with winning Bids across all Delivery Years.

The Supplier Fee is paid only by suppliers whose bids are approved by the Illinois Commerce Commission.

02-28-2017

FAQ-DG-8
Q: Can the system owner use a parent guaranty instead of a letter of credit under the terms of the DG RFP and applicable supplier contract?

The Bidder (the company that will be presenting a proposal under the Utility Distributed Generation Request for Proposal, the “DG RFP”) will be required to present a Letter of Credit to support its bids with the Illinois Power Agency (“IPA”) as beneficiary. The terms of this Letter of Credit have been released and are available here:

https://www.ipa-energyrfp.com/spring-utility-dg/final-materials/

Should the Bidder have Bids that are approved by the Illinois Commerce Commission, the Letter of Credit would still be held during the term of the supplier contract. Please see Section V.2.3. of the DG RFP Rules for information on the reduction and return of the Letter of Credit.

Please note that the Bidder and the system owner may or may not be the same person/company. The requirement to provide a Letter of Credit applies to the Bidder.

03-09-2017

FAQ-DG-9
Q: Regarding the System Identification Form (Exhibit B), would you please let me know if the Host Acknowledgement and Certification form (Appendix C) is required in the instance that the system owner is not the host?

You seem to be referring to documents appended to the contract forms that were used in the procurement events under the Supplemental Photovoltaic Procurement Plan (“SPV”). Please note that the procurement event under the Utility DG RFP to be held this Spring uses an entirely different contract form and the requirements for the submission of a Proposal will be different from the requirements in the SPV procurement events.

Please see the draft contract form here (comments are due March 9):

https://www.ipa-energyrfp.com/spring-utility-dg/

Please also note that, to assist bidders who may preparing to participate in the DG RFP, the Procurement Administrator has made an early release of information and documents, including a Sample Host Acknowledgment. This Host Acknowledgment is included in the “Sample Documents” posted to this page:

https://www.ipa-energyrfp.com/spring-utility-dg/final-materials/

While the DG RFP Rules have not been released, it is anticipated that the Host Acknowledgment will be required for a system presented as part of your Proposal if: (i) the system is new (i.e., energized on or after June 1, 2017); and (ii) the System Owner and the Host are different entities or individuals.

03-09-2017

FAQ-DG-10
Q: As an alternative to issuing a Letter of Credit, are bidders able to meet collateral requirements by posting an equivalent amount of cash to the IPA?

No, the IPA will not accept cash to meet collateral requirements for the Utility DG RFP. All bidders must submit a Letter of Credit with their Part 2 Proposal.  This Letter of Credit stays in place at the start of the supply period to the extent that some of the systems presented in the Proposal have not begun accumulating metered deliveries or to the extent that some systems in the Small Size Class have not yet been identified.

All suppliers that are considering participation in the Utility DG RFP should begin at the earliest opportunity to work with their financial institutions to issue the Letter of Credit. The Letter of Credit has been posted here:

https://www.ipa-energyrfp.com/spring-utility-dg/final-materials/

If the financial institution of the bidder would like to propose modifications to the Letter of Credit, such modifications can be presented by the Bidder to the Procurement Administrator prior to the Part 1 Date (the date at which Part 1 Proposals are due).

03-13-2017

FAQ-DG-11
Q: Are the Utility DG procurement events targeted more to aggregators or individual system owners? Do the participants buy or sell renewable energy credits?

The IPA Utility DG procurement events are targeted more to aggregators (rather than individual system owners) to SELL (rather than buy) renewable energy credits.

03-13-2017

FAQ-DG-12
Q: Where can I find information for homeowners who may wish to participate in the IPA Utility DG procurement event through an aggregator? Is there a list of aggregators on your website?

The Illinois Solar Energy Association has information for homeowners generally and with respect to the IPA procurement events in particular:

http://www.illinoissolar.org/Procurement

The results of previous procurement events also provide the list of aggregators. These aggregators have been winning suppliers in the IPA’s procurement events:

https://www.ipa-energyrfp.com/?wpfb_dl=918

https://www.ipa-energyrfp.com/?wpfb_dl=832

https://www.ipa-energyrfp.com/?wpfb_dl=611

03-13-2017

FAQ-DG-13
Q: We are trying to become aggregators, but cannot find a process of how to do that. Can you give any guidance?

There is no certification or formalized process to become an aggregator. An aggregator refers to an entity that presents renewable energy systems that it does not own but for which it has ownership of RECs or the contractual right to legally transfer or assign the RECs to the utility.

Under the Utility DG RFP (“DG RGP”), the Bidder is expected to serve as the counterparty under the applicable supplier contract with the utility for the delivery of RECs.   There is a minimum 1 MW bid. While the Bidder can be a system owner or an aggregator, if smaller systems are presented, it would be expected that the bidder is an aggregator.

In the presentation of the proposal, an aggregator must demonstrate that it has ownership or the contractual right to legally transfer or assign RECs through executed Letters of Intent for each system that it does not own.

03-14-2017

FAQ-DG-14
Q: Is there a limitation on how large bids may be (so long as they meet the 1 MW threshold), or how many bids one Bidder can submit?

While the RFP Rules have yet to be finalized, we expect that a first limitation will be that the Bidder can, for the Large Size Class (systems 25 kW or above), present systems that together produce an annual quantity of RECs up to and including the overall Target (across all three utilities). Similarly, for the Small Size Class (systems below 25 kW), we expect that the limitation will be that the Bidder can present systems and a forecast quantity that together produce an annual quantity of RECs up to and including the overall Target (across all three utilities).

A second limitation is that any Individual system presented as part of a proposal for the Spring Utility DG RFP (“DG RGP”) is limited in size to 2,000 MW nameplate capacity (DC rating).

A third limitation is that a Bidder can submit a single proposal in response to the DG RFP.

03-14-2017

FAQ-DG-15
Q: Can a 1 MW bid include systems from both the Small Size Class and the Large Size Class? Must the Bidder present a single blended bid price? Will there be a single blended price under the applicable supplier contract?

Components of the first 1 MW Block presented by a Bidder may be of different technologies, may be from different Size Classes, and, for the Small Size Class, may be from identified systems or may include a forecast quantity.   To the extent that the first 1 MW Block features RECs from both the Large and the Small Size Classes, the Bidder must provide two Bid prices, a Bid price for each Size Class. Each price is a blend to the extent that the price applies potentially to several systems.

Under the applicable supplier contract with a given utility, there is a single blended price for each Size Class, which is calculated as the weighted average of the winning bid prices of the RECs that have been selected for award under the RFP process for that contract.

03-14-2017

FAQ-DG-16
Q: If we identify a system as part of our bid, but the system does not materialize and does not begin accumulating metered deliveries by May 31, 2018, can we substitute that system?

No. While the contracts for the Distributed Generation RFP (“DG RFP”) are not yet finalized, under the terms of the current draft contracts, there is no allowance for substitution (adding a system in place of a system identified as part of a winning bid). In the case that an identified system does not materialize or accumulate metered deliveries by May 31, 2018, the Bidder would forfeit the collateral associated with the RECs from such system. Furthermore, the project would be removed from the applicable supplier contract with a utility and the maximum quantity of RECs to be delivered under the contract would be reduced accordingly.

03-14-2017

FAQ-DG-17
Q: Is there a process to amend the system size under the terms of the draft DG supplier contracts?

No. Please review the DG contracts, which are on a portfolio basis and are not structured on a system by system basis. As part of the Proposal, a Bidder will be required to both identify the size of a system and to certify that the systems’ characteristics, including size, are true and accurate to the best of the Bidder’s knowledge and belief. The applicable supplier contract will specify a Maximum Annual Quantity to be delivered under the contract, which can be supplied from any of the systems identified as part of the bid (or identified subsequently if the winning bid initially specified a forecast quantity).

03-14-2017

FAQ-DG-18
Q: Can you clarify the deadlines to energize systems? Do systems identified in the bid have one year from bid date to install? Do systems from a forecast quantity have to be identified in 9 months from the bid date?

For the Spring Utility DG RFP, Bidders may include in their proposal both: 1) identified systems; or 2) a forecast quantity, a quantity of RECs that are not associated with identified systems in the Small Size Class. Identified systems must begin accumulating metered deliveries by the end of the 2017-18 year (on or prior to May 31, 2018).

For a forecast quantity, the Bidder must identify the systems no later than nine months after the start of the delivery year (i.e., by February 28, 2018) and such systems must begin accumulating metered deliveries by February 28, 2019.

03-14-2017

FAQ-DG-19
Q: Are the RFP Rules and final materials available for the DG RFP?

The RFP Rules and final materials are not yet available. These are scheduled to be posted to the Final Materials page of the Spring Utility DG section of the procurement website on March 27, 2017. Should draft documents become available, they will be posted to the Draft Documents page and an announcement will be sent to registrants and posted to the procurement website.

Please also note that, to assist bidders who may be preparing to participate in the DG RFP, the Procurement Administrator has made an early release of some information and documents, including a Sample Host Acknowledgment.  This information is posted here:

https://www.ipa-energyrfp.com/spring-utility-dg/final-materials/

03-14-2017

FAQ-DG-20
Q: Do you have a sample of an acceptable “Letter of Intent”?

Samples of the Letter of Intent can be found in the document titled ‘Sample Documents (March 3, 2017)’ that is posted here: https://www.ipa-energyrfp.com/spring-utility-dg/final-materials/.

03-14-2017

FAQ-DG-21
Q: Will the IPA procure the lowest bids up to a specific REC quantify or a dollar amount?

Bids that meet or beat the benchmarks are selected in price order until the Target quantity of RECs is met on an annual basis or until the Budget is exhausted, whichever comes first.

03-14-2017

FAQ-DG-22
Q: Does a winning bidder receive their own bid price, or a market-clearing price?

A winning bidder receives the average of the bidder’s own winning bids (and not a market-clearing price).

03-14-2017

FAQ-DG-23
Q: When will the Supplier Fee be announced?

The Supplier Fee will be announced no later than the Part 2 Date. This Supplier Fee will not exceed $3.00/REC (the final Supplier Fee may be lower but will in no event be higher than $3.00/REC).

03-14-2017

FAQ-DG-24
Q: If we get an award for a forecast quantity of RECs for the Small Size Class under the Utility DG RFP, what are the consequences to us if we fail to identify the systems by the deadline or if the systems we do identify fail to accumulate metered deliveries by the deadline stated in the contract? If we get an award for systems not yet in operation (in either Size Class), what are the consequences to us if these systems fail to accumulate metered deliveries by the deadline?

The first consequence is that the quantities for which you can get paid under the contract will be reduced by the RECs associated with the systems that you fail to identify or by the RECs associated with the systems that fail to accumulate metered deliveries by the deadline. The second consequence is that the IPA will make a draw upon the letter of credit in an amount of $4 for each REC that was included in the winning Bids but that is deducted from the quantities for which you can get paid under the contract.

03-20-2017

FAQ-DG-25
Q: Is there collateral to be posted during the term of the DG contract? Where is this information in each of the applicable supplier contracts?

The amount of collateral to be posted is $4/REC based on the number of RECs across the term of the contract associated with your winning bids as specified in the 2017 Procurement Plan. This amount will be further explained in the RFP Rules when these become available. This amount of collateral is to be posted as a Letter of Credit with the IPA as beneficiary. The collateral is not posted with the utility as a term of the applicable supplier contract with the utility.

03-20-2017

FAQ-DG-26
Q: What are the circumstances in which I can lose all or part of the collateral that I would post during the term of the DG contract as a Letter of Credit with the IPA as beneficiary?

Please see the Letter of Credit here.  The conditions for drawing on the letter of credit are provided in Paragraph 2 to the Letter of Credit.

03-20-2017

FAQ-DG-27
Q: Is it an event of default under the applicable supplier contract for a utility if we do not deliver up to the Maximum Annual Quantity each Delivery Year?

No, it is not an event of default under the applicable supplier contract for a utility if you do not deliver up to the Maximum Annual Quantity provided that you meet the following conditions. If you do not meet the Maximum Annual Quantity, you must provide all of the RECs from the systems associated with the applicable supplier contract with the utility; you must not be withholding RECs from the utility or selling RECs from such systems to another party.

03-20-2017

FAQ-DG-28
Q: If a system fails to be built or energized, is the penalty forfeiture of the Performance Assurance of $4/REC, or is the penalty that the Supplier Fee is retained by the IPA, or both?

A winning bidder will have seven (7) business days after the Illinois Commerce Commission’s approval of the procurement event to pay the supplier fee associated with the winning bids. The supplier fee is not returned or refundable.

With its Part 2 Proposal, a Bidder must provide a Letter of Credit in an amount of $4 times the number of RECs that the Bidder can win across all systems and any forecast quantity for the five (5) Delivery Years under the applicable supplier contracts. This Letter of Credit stays in place, reduced on a prorated basis based upon the winning Bids, at the start of the supply period to the extent that some of the systems presented in the Proposal have not begun accumulating metered deliveries or to the extent that some systems in the Small Size Class have not yet been identified.

In the case that a system fails to be built or energized, the Bidder would forfeit the collateral associated with the RECs from such system. Furthermore, the project would be removed from the applicable supplier contract with a utility and the maximum quantity of RECs to be delivered under the contract would be reduced accordingly.

03-20-2017

FAQ-DG-29
Q: If a system identified in our proposal fails to deliver the expected number of RECs, is there a penalty?

In the event that an identified system in your proposal delivers RECs under the contract, but is not able to deliver the intended number of RECs designated in the contract, there is no penalty.

03-20-2017

FAQ-DG-30
Q: When is the Letter of Credit due? If our bank has requests for alternate language in some instances or non-material modifications, is there a process to submit these to the Procurement Administrator?

A Bidder must submit an original executed Letter of Credit to support its bids with its Part 2 Proposal. The Part 2 Proposal, including the Letter of Credit, must be submitted by 12 PM (noon) Thursday, April 20, 2017.

The Letter of Credit is available in final form here: https://www.ipa-energyrfp.com/spring-utility-dg/final-materials/. Should your financial institution have requests for alternate language, you may submit comments on the Letter of Credit to the Procurement Administrator by the time Part 1 Proposals are due, which is 12 PM (noon) CPT on April 5, 2017.

03-20-2017

FAQ-DG-31
Q: Can you confirm that there is no draw against the Letter of Credit if a system associated with an applicable supplier contract with a utility under the DG RFP does not deliver the expected quantity? Is there a draw or another financial consequence if we fail to deliver the maximum annual quantity in a delivery year under the contract?

As long as the system has been registered with PJM GATS or M-RETS and the initial meter read date of such system occurs by the deadline in the applicable supplier contract with the utility, then there are no specific quantities of RECs that such system is required to deliver. Under the applicable supplier contract, delivery of RECs is on a portfolio basis to meet the Maximum Annual Quantity in each Delivery Year and not on a system-by-system basis. Furthermore, there are no penalties associated with delivering less of than the Maximum Annual Quantity provided, however, that you are not withholding RECs from the systems identified in the applicable supplier contract. If you do not meet the Maximum Annual Quantity, you must provide all of the RECs from the systems associated with the applicable supplier contract with the utility; you must not be withholding RECs from the utility or selling RECs from such systems to another party.

03-20-2017

FAQ-DG-32
Q: If a system we identify as part of our winning bids falls through, can we substitute another system?

No. There is no allowance for transferring a winning bid to a new system in the case that the system identified in your proposal does not materialize. In this situation, under the contract, the Bidder would forfeit the collateral associated with the RECs from such system and the project would be removed from the contract.

03-20-2017

FAQ-DG-33
Q: Can you provide highlights of what are expected to be the requirements of the DG RFP? What is the qualification form used for?

The requirements for participation in the Utility Distributed Generation request for proposals (“DG RFP”), including required documentation, will be stated in the RFP Rules which will be posted March 27, 2017 to the ‘Final Materials’ section of the Spring Utility DG page of the procurement website. The qualification form is used for you to provide the required information and upload required documents. You can register for an account to receive login credentials to use the qualification form by completing the Qualification Registration Form and selecting the “Spring Utility DG” category. Login credentials are issued the day before the Part 1 Window opens, which is March 28, 2017.

Highlights of the requirements under the DG RFP include:

  • Each system presented in the proposal must be a distributed renewable energy generation device, i.e., it must be limited in nameplate capacity to 2,000 kW, behind the customer meter, and interconnected at the distribution level of an electric utility, alternative retail electric supplier, municipal utility, or a rural electric cooperative in Illinois.
  • The Bidder must be either the system owner or an aggregator that has ownership of the RECs of the systems or the contractual right to legally transfer or assign RECs from the systems.
  • Each bidder must provide a letter of credit in an amount of $4/REC.
  • The minimum bid size is 1 MW.
  • If Bids for a Bidder are approved by the Commission, the Bidder will deliver RECs to a utility under its applicable supplier contract at a single blended average price per REC for each Product (i.e., an average price for systems below 25 kW and another average price for systems between 25 and 2,000 kW). The single blended average price per REC for a Product will be calculated on the basis of the Bidder’s Bids for the RECs of that Product under contract with that utility.
  • To the extent possible, 50% of RECs procured will come from systems below 25 kW.

Please also note that, to assist bidders preparing to participate in the DG RFP, the Procurement Administrator has made an early release of information and documents, including samples of documentation required in certain cases. Please consult the Final Materials page of the Spring Utility DG section of the procurement website (https://www.ipa-energyrfp.com/spring-utility-dg/final-materials/). You may also view materials of prior DG RFPs using the “Previous RFPs” link of the procurement website (https://www.ipa-energyrfp.com/previous-rfps/).

03-23-2017

FAQ-DG-34
Q: Can we include in our Proposal existing systems that are already built and energized or is the DG RFP limited to only new systems?

You can include existing systems in your Proposal. The DG RFP is not limited to new systems. For purposes of the DG RFP, an existing system means a system that has been energized as of March 28, 2017.

03-29-2017

FAQ-DG-35
Q: If our winning bids include Forecast Quantities, can we identify systems in the Large Size Class for those RECs?

No, all systems that are identified pursuant to an award of a Forecast Quantity must be from the Small Size Class.

03-29-2017

FAQ-DG-36
Q: Suppose our winning bids include a Forecast Quantity and we identify a system of the Small Size Class that is energized prior to January 28, 2018 (say on October 1, 2017). Is the system disqualified from being included in the contract because it is energized prior to January 28, 2018? If such a system can be included in the contract, can we be paid for RECs starting when it is energized on October 1, 2017?

There is no requirement for systems identified to replace Forecast Quantities to be energized only after January 28, 2018.  Such a system that is energized on October 1, 2017 may be included in the contract.  However, the IPA will amend the list of systems in the contract to include any such systems only once after January 28, 2018.  RECs from such systems may only be transferred for payment after they have been confirmed by the IPA for inclusion in the applicable supplier contracts, which will occur after January 28, 2018 and by February 28, 2018.

03-29-2017

FAQ-DG-37
Q: Can we request an extension if a system fails to become energized by the deadline specified in the applicable supplier contract? How long is the extension? Can we also get an extension if we do not identify in time a system to replace a forecast quantity?

Any request to extend the deadline for an identified system to become energized must be made in writing to the IPA by the deadlines specified in the applicable supplier contract. Such extension may be granted at the IPA’s sole discretion but only for limited circumstances such as demonstrated delays in a utility approving interconnection of a system, or failure by the PJMGATS or M-RETS to process registration in a timely manner.  Any such extension will not exceed six months and may be shorter depending on the circumstances.  Please also note that no similar extension can be granted if a bidder fails to identify a system to replace a forecast quantity.

03-29-2017

FAQ-DG-38
Q: Can you provide a list of the differences between the Utility DG program and the Supplemental PV RFP?

We invite you to review the available documentation for the two programs to understand fully the differences. We highlight a few of these differences below:

The DG systems that are eligible are different:

  • The Supplemental PV RFP procured RECs produced by new distributed renewable energy devices that are of solar photovoltaic technology.
  • The Spring Utility DG RFP procures RECs produced by new or existing distributed renewable energy devices that may be from different technologies and are not limited to only solar photovoltaic.

The contract structure is different:

  • The SPV RFP featured a structure where there was one contract associated with each system and the counterparty to the contract was the Illinois Power Agency.
  • In the Utility DG RFP, there is a contract for a portfolio of systems and a winning bidder may have one or more contract with a utility (AIC, ComEd and/or MEC).

We also note that the Utility DG RFP has a minimum bid size of 1 MW and that, to the extent possible, the RFP seeks to procure 50% of RECs from systems below 25 kW.

03-29-2017

FAQ-DG-39
Q: How can I get instructions regarding payment of the Bid Participation Fee?

Please request those instructions from the Procurement Administrator at Illinois-RFP@nera.com.

03-29-2017

FAQ-DG-40
Q: I requested login credentials. Should I have received them by now?

Login credentials for the Spring Utility DG RFP have been issued. If you did not receive these credentials, please contact us at Illinois-RFP@nera.com.

03-29-2017

FAQ-DG-41
Q: Please confirm that the entity that is the Applicant of the IPA Letter of Credit can be different from the Seller that will sign the applicable DG contract with the utility.

This is correct. In the IPA Letter of Credit, the Applicant may be different from the Bidder that is indicated in Paragraph 12 of the IPA Letter of Credit. The Bidder indicated in the IPA Letter of Credit must be the Seller that will sign the applicable supplier contracts should the bids in the proposal submitted to the Procurement Event be approved.

03-29-2017

FAQ-DG-42
Q: Please confirm that the GATS or M-RETS account that is used under the applicable supplier contract for the transfer of RECs is determined by the Seller and we can indicate which GATS or M-RETS account we are using in the coversheet of the applicable Utility DG contract(s). For example, it can be the account of our parent if we do not have an account set up specifically for the Seller.

It is correct that use of PJM EIS GATS or M-RETS is required for the transfer of RECs under the applicable supplier contracts. Beyond that, the cover sheet does not require that the GATS or M-RETS account you are using for the transfer is specifically linked to the Seller name.

03-29-2017

FAQ-DG-43
Q: Please confirm that the instructions for where to send payment for REC Deliveries is determined by the Seller and we can indicate which bank account we want payment to be sent to in the coversheet of the applicable supplier contract.

You are correct. You determine where payment is to be sent under the applicable supplier contracts and you may indicate the information of your bank in the coversheet of the applicable supplier contracts.

03-29-2017

FAQ-DG-44
Q: Can we have multiple subsidiaries all bid in the Utility DG RFP?

Such a structure is likely inconsistent with the requirements of the RFP.  We strongly encourage you, before having multiple subsidiaries submit a proposal, to review the requirements of the Proposal under the Utility DG RFP. For instance, as a requirement of the Proposal, a Bidder is required to make a number of certifications, including:

  • The Bidder has no material information relating to the Proposal of another party;
  • Other than such discussions necessary for the preparation of the Proposal, the Bidder has not disclosed, publicly or to any other party, any material information relating to the Proposal, including the systems presented as part of the Proposal; the Bids for such systems; or the Products for which Bids are presented.

We note that the fact that you are asking whether multiple subsidiaries can all bid in the same procurement event under the Utility DG RFP implies that you have knowledge of each subsidiary’s  intention to submit a Proposal.  It thus would appear that you would not be able to make the certifications above (and potentially other certifications required by the Proposal).

03-29-2017

FAQ-DG-45
Q: With reference to Page 9 of the Bidder Information Webcast, I see the Overall Target of 27,702 RECs. Is this the number of RECs for one year of REC deliveries or is it the Target including all years under the applicable supplier contracts?

The Overall Target of 27,702 RECs is an annual number of RECs so that 138,510 RECs (i.e., 27,702 RECs x 5 years) could be delivered under the applicable supplier contracts.  The Overall Target is a total across both the Spring 2017 and Fall 2017 procurement events.

03-30-2017

FAQ-DG-46
Q: Can systems be interconnected to a distribution system of a municipal utility within Illinois?

Yes.  All systems must be in Illinois and must be interconnected to the distribution system of Ameren Illinois Company, Commonwealth Edison Company, MidAmerican Energy Company, Mt. Carmel Public Utility Co., or a “municipal utility” as defined in Section 3-105 of the Illinois Public Utilities Act, or a “rural electric cooperative” as defined in Section 3-119 of the Illinois Public Utilities Act.

03-30-2017

FAQ-DG-47
Q: Can the size of systems included in the portfolio from which we deliver RECs under the applicable supplier contracts change during the term of the contract?

Yes, the final system size may be different from the planned system size indicated in your Proposal as long as the new system size does not result in a change in the Size Class of the system (e.g., from Small to Large, or vice versa). However, note that if the system size changes for one or more of your systems, this will NOT lead to a change in the maximum number of RECs that can be delivered under the applicable supplier contracts.

03-30-2017

FAQ-DG-48
Q: What is the MW equivalent of the Overall Target of 27,702 RECs annually?

The overall target can only be converted to a specific MW measure by assuming a capacity factor.  However, projects of different technologies, which are all eligible for inclusion in your Proposal under the Utility DG RFP, have different capacity factors.  Thus such a conversion is not straightforward; to make your own calculations, please see the capacity factors that will be used in this RFP, available in Table 1 of the RFP Rules:

https://www.ipa-energyrfp.com/?wpfb_dl=1175

03-30-2017

FAQ-DG-49
Q: What is the deadline under the applicable supplier contracts for a system included in our Proposal to deliver its first REC?

The applicable supplier contracts do not have a deadline for delivery of the first REC.  Rather, the requirement for a system that is part of your winning bids is for the initial meter read date of such system to occur by May 31, 2018.

03-30-2017

FAQ-DG-50
Q: Is the Bid Participation Fee to be paid once per bidder or once per system?

The Bid Participation Fee of $500 is to be paid once per bidder for all procurement events in 2017 regardless of the number of procurement events in which you participate and regardless of the number of systems you may identify in your Proposal for the Spring 2017 procurement event under the Utility DG RFP.

03-30-2017

FAQ-DG-51
Q: If the system fails to meet its deadline for being energized and showing metered deliveries solely due to a delay in the interconnection by the utility, is the extension automatically granted?

There is no automatic extension under the terms of the applicable supplier contracts.  A Seller must request an extension in writing and such extension may be granted at the IPA’s sole discretion.  However, one of the circumstances specifically mentioned in the applicable supplier contracts as being a circumstance that could lead to an extension being granted is one where the Seller can demonstrate that there is a delay in the utility approving interconnection of a system.  Another such circumstance is the failure by the PJMGATS or M-RETS to process registration in a timely manner.

03-31-2017

FAQ-DG-52
Q: Is the Bid Participation Fee due at the IPA’s office on April 5 or is the requirement that we initiate payment by that date?

The Part 1 Proposal, including the Bid Participation Fee at the IPA’s office, is due at 12PM (CPT) on April 5.

03-31-2017

FAQ-DG-53
Q: Where can I find the webcast presentation?

The webcast presentation is posted to the Final Materials page of the Spring Utility DG Section of the procurement website.  These documents are dated March 27, 2017.

03-31-2017

FAQ-DG-54
Q: Can we sell RECs through the Utility DG RFP from systems in Iowa?

No.  A condition of eligibility of a system is that it be interconnected at the distribution level of an electric utility, alternative retail electric supplier, municipal utility, or a rural electric cooperative in Illinois and thus the system must be located in Illinois.

03-31-2017

FAQ-DG-55
Q: If one of our systems under-produces in the first year of the contract, can we make up the shortfall in the second year?

REC deliveries under the applicable supplier contracts are on a portfolio basis, which means that there is an overall maximum quantity to be delivered from all the systems under that contract but there is no specific quantity maximum quantity associated to a single system.  As a consequence, there is no quantity to “make up” from a particular, single system.

03-31-2017

FAQ-DG-56
Q: What is generally the end of the contract? If I have single system greater than 1 MW and the first REC Delivery from the system occurs on January 1, 2018, when does the contract expire?

The applicable supplier contracts define the end date of the contract for several different circumstances; please review, for example, Paragraph 2 on page 1 of the AIC REC Master Agreement.  Generally, the expiration of the contract is five years after the date of the first REC delivery by the last system in the portfolio. In your example, if the first REC delivery of this single system occurs on January 1, 2018, the contract expires on December 31, 2022.

03-31-2017

FAQ-DG-57
Q: The structure of the program seems to incentivize developers to bid into the system and then find projects to fill their REC obligations. Is that the intent of the program?

Section 1-75(c) of the IPA Act also requires the utilities to acquire RECs from distributed generation (“DG”) devices amounting to at least 1% of each utility’s total RECs target.  Please see the 2017 IPA Procurement Plan for further details on the intent of the procurement events approved under this Procurement Plan (https://www.illinois.gov/sites/ipa/Pages/2017-Procurement-Plan.aspx).

The Procurement Monitor recommended that bidders be allowed to offer “speculative RECs” in order to improve bidder response.  This recommendation was incorporated into this procurement event as bidders presenting a proposal may include a Forecast Quantity of RECs to be delivered by systems that they have yet to identify.

03-31-2017

FAQ-DG-58
Q: I understand that there could be a rebate for solar photovoltaic projects. Would this rebate be available to projects interconnected to a muni or coop?

It is expected that there will be a new rebate for smart inverters for photovoltaic projects as a consequence of Public Act 99-0906 .  The rebate would be provided by an electric utility that serves more than 200,000 customers in Illinois.

03-31-2017

FAQ-DG-59
Q: Can you confirm that the bank can use the following as an alternate Paragraph 14: “We, the Issuing Bank, certify that as of the Date of Issuance our senior unsecured debt is rated by at least one of Standard & Poor’s (S&P), Moody’s Investors Service (Moody’s), and Fitch Ratings (Fitch). We hereby certify that our senior unsecured debt is rated “A-” or better by S&P, or is rated “A3” or better by Moody’s, or is rated “A-” or better by Fitch. If affiliated with a foreign bank, we further certify we are a U.S. branch office of such foreign bank and that as of the Date of Issuance of this Letter of Credit, our senior unsecured debt meets the ratings requirement of this paragraph.”

Please refer to the document titled “Acceptable Modifications to the IPA LC (March 27, 2017)” posted to the Final Materials page of the Spring Utility DG section of the procurement website for all modifications to the Letter of Credit found acceptable by the IPA.  The modification you have indicated above appears to be modification 14.1 found on page 21.

03-31-2017

FAQ-DG-60
Q: Is it correct that the lowest priced bid must be on the first 1 MW of systems and that after the first 1 MW of systems, we can select any bid size as long as: (i) the bid is at least 100 kW; (ii) the bid price is more than the bid price of the first 1 MW; and (iii) each system is contained fully in one block?

That is generally correct.  We would add the following.  First, the first block may be larger than 1 MW (it must at least 1 MW).  Second, this first block may include systems of both Size Classes (and RECs for the Small Size Product may also be from a Forecast Quantity).  If the first block does include RECs from both Products, then you must provide two (2) separate bid prices, i.e., one for each Product.  Third, each additional block must be for only one Product (i.e., all systems must be from the Large Size Class or all systems from the Small Size Class plus any Forecast Quantity).  Fourth, the bid price for an additional block for a Product (Small or Large) must be greater than the bid price for that Product in the first block.

03-31-2017

FAQ-DG-61
Q: When we identify our systems using the Worksheet Insert, what do you mean by the customer account number?

In this cell of the Worksheet Insert, please enter the customer’s account number with the electric distribution utility.

03-31-2017

FAQ-DG-62
Q: You mentioned that there are items that are requirements of the Part 1 Proposal but for which a bidder can have additional time. How much more time can we have?

Please note that additional time is only provided for new systems (energized after March 28, 2017) and additional time is provided only for some (and not all) of the required items and documents (please refer to the RFP Rules, Paragraphs IV.3.3 and IV.3.4 for details).  All information required of existing systems must be provided with the Part 1 Proposal.  For new systems, some items, such as the tracking system from which RECs would be transferred, can be provided by the Part 2 Date (by noon CPT on April 20).

03-31-2017

FAQ-DG-63
Q: Have the Targets and Budgets been set for the Spring DG RFP?

Specific Targets and Budgets for the Spring procurement event are set at: (i) 70% of the Overall Targets and Overall Budget for ComEd as well as for AIC; and (ii) 100% for MEC.

The “Spring Targets” for AIC, ComEd, and MEC in the Spring DG RFP are:  4,928 RECs, 14,097 RECs, and 524 RECs respectively.  The “Spring Overall Target”, which is the sum of the Spring Targets across all three (3) Companies in this Spring 2017 DG RFP, is 19,549 RECs. These figures are per year.

The preliminary “Spring Budgets” for AIC, ComEd, and MEC in the Spring DG RFP are:  $10,010,028, $20,486,892, and $2,971,090 respectively.  The preliminary “Spring Overall Budget”, which is the sum of the preliminary Spring Budgets across all three (3) Companies in this Spring 2017 DG RFP, is $33,468,010.  These figures are for all years of the applicable supplier contracts.

Final Spring Budgets will be announced no later than three (3) business days prior to Bids being due.  Please see Paragraph I.2.5 through I.2.8 of the RFP Rules for more details.

04-02-2017

FAQ-DG-64
Q: I have a question about the Revenue Quality Metering accuracy metering requirements for a solar project in Illinois in the Large Size Class. I found a document on IPA website which states that all systems 25 kW and above must use a meter that meets ANSI C.12 standards. Does the ANSI C.12 imply that any 0.5 accuracy class meter is acceptable?

As part of your Proposal, you will be required to represent that: “A revenue quality meter has been or will be installed to measure the output of the system, compliant with the determination made by the Illinois Power Agency in its document “Revenue-Quality Metering Accuracy Standard and Acceptable Technologies”.  The relevant document is posted here: https://www.illinois.gov/sites/ipa/Documents/IPA-metering-accuracy-standard-5-14-15.pdf.

For systems 25 kW and above registered with GATS, the requirement is that such systems utilize a meter that meets ANSI C.12 standards.  For systems 25 kW and above registered with M‐RETS, the requirement is that such systems utilize an ANSI C.12 certified revenue quality meter, as may be further specified by the M-RETS operating procedures.  The standard is not stated solely in terms of accuracy and does not state that all meters accurate to plus or minus 5% are acceptable.  It is the responsibility of the bidder to ensure that any system presented satisfies the applicable metering standards so that the bidder can make all representations of the Proposal.

04-02-2017

FAQ-DG-65
Q: As part of our Proposal, can we commit to sell RECs from a system that is not yet built (or do we have to build the system first)?

You do not need to build the system first.  However, please note that it is the bidder’s responsibility to evaluate whether the bidder can provide all the information required by the DG RFP for a system that is not yet built and it is the bidder’s responsibility to evaluate whether the timeframes for completing development, registering the system in GATS or M-RETS and having the first meter read date for the system in the applicable supplier contracts are sufficient for the bidder’s particular circumstances.

For a system that is planned but not yet built, you may present such a system as a “new” system in your Proposal.  You will be required to provide information regarding the characteristics of the system. In particular, you will be required the following information regarding the system: a) system size; b) system location; c) system owner; and d) system host. (To see all information required, please refer to Paragraph IV.3.4 in the RFP Rules or see the Worksheet Insert #P1-2).  You may also be asked for supporting documentation in specific circumstances.  For instance, if the Owner (the owner of the system) and Host of the system (the owner of the premises where the system will be built) are not the same individual or company, you will be required to provide documentation showing that the Host agrees to the system’s installation.  If this system becomes part of your winning bids, you will have to show that the system has accumulated metered deliveries by May 31, 2018 (i.e., the system has been registered in GATS or M-RETS and the initial meter read date occurs on or before May 31, 2018).

For a system that is not yet identified (in particular, you cannot provide all the information required for presenting the system as new in your Proposal), and for a system in the Small Size Class (below 25 kW), and for such a system in that Size Class only, you may present a Forecast Quantity of RECs in your Proposal. A Forecast Quantity is a quantity of RECs that you are committing to sell and that will be generated from systems that cannot yet be fully identified.  If a Forecast Quantity is part of your winning bids, you will be required to fully identify the systems by January 28, 2018 and such systems must begin accumulating metered deliveries by February 28, 2019.  Please note that no payment for RECs from a Forecast Quantity can be made prior to February 28, 2018.

04-02-2017

FAQ-DG-66
Q: If our bank wants to propose modifications to the Standard IPA Letter of Credit, what is the process?

You may provide comments from your bank or propose modifications to the Standard IPA Letter of Credit.  Please provide such comments and or propose such modifications by submitting a redline of the Standard IPA Letter of Credit in Microsoft Word format.  You may provide this document by email or by upload to the space provided in Section 5 of the online Part 1 Form.  Any one of your comments or proposed modifications to the Standard IPA Letter of Credit that is found to be acceptable will be added to the list of modifications to the Standard IPA Letter of Credit approved by the IPA for use by all Bidders on an optional basis.

04-02-2017

FAQ-DG-67
Q: Where can I find the presentation from the Utility DG RFP webcast?

The webcast presentation and recording are posted to the Final Materials page of the Spring Utility DG Section of the procurement website and dated March 27, 2017.

04-02-2017

FAQ-DG-68
Q: Can you confirm that the “GATS/M-RETS system registration application and approval letter” is the only supporting document needed for an existing system?

Not necessarily.  The GATS/M-RETS system registration application and approval letter is sufficient to show that the system is existing (although other documentation may be provided to confirm that the system is existing).  However, there may be other documentation required based on the particular characteristics of the system. For instance, a Bidder must provide a Bidder-Owner Agreement for any system (new or existing) for which the Bidder and Owner are not the same individual or entity. More details regarding the documentation requirements can be found in Paragraph IV.3.4 of the RFP Rules.  Furthermore, you can use the Documentation Insert #P1-3 as a guide to the documentation needed for your particular systems.

04-02-2017

FAQ-DG-69
Q: What documents are acceptable to show that a system is an existing system?

A Bidder including an existing system in its Proposal must provide one of the following documents to support the qualification for each existing system:

  1. Interconnection Agreement;
  2. Net metering application approval letter;
  3. Final system inspection confirmation;
  4. GATS/M-RETS system registration application and approval letter;
  5. permission to operate letter; or:
  6. other relevant documentation clearly showing the date at which the system was energized or began operation.

Email copies of the GATS/M-RETS system registration application and approval letter should be uploaded in PDF format to the spaces provided in the online form or emailed to the Procurement Administrator at Illinois-RFP@nera.com.

04-02-2017

FAQ-DG-70
Q: If we are dealing with a Host that will have multiple systems on sites that the Host owns, can we present a single Host Acknowledgment for all sites?

A single Host Acknowledgment that covers all sites is acceptable.   Please make sure the single Host Acknowledgment refers to all systems that it covers.

04-03-2017

FAQ-DG-71
Q: Is there guidance available on the valuation for RECs?

The Procurement Administrator cannot provide guidance to bidders on valuations for RECs. We invite you to review the results of past procurement events under the Utility DG RFP or the SPV RFP. Results are posted to the top of each archived RFP page here:

https://www.ipa-energyrfp.com/previous-rfps/

Please note that these procurement events are for distributed generation.

04-03-2017

FAQ-DG-72
Q: I heard $3/REC during the webcast. What does this figure relate to?

The $3/REC mentioned during the webcast is the maximum amount of the supplier fee. Winning bidders pay the supplier fee within seven business days of the Commission decision on the procurement event.

04-03-2017

FAQ-DG-73
Q: I want to confirm that the maximum size of the system is 2,000 kW DC and not AC because the customer wants the system to be as large as possible.

In providing the size of the system, the bidder must provide the nameplate DC output rating of the system, expressed in kilowatts. Such size will be rounded to two (2) decimals.

Noting your comment that “the customer wants to go as large as possible”, please be aware that in presenting a system in a Proposal under the Utility Distributed Generation RFP, the system must qualify as “distributed generation”. The 2,000 kW maximum is one, but only one of the criteria for the system to qualify as distributed generation. The other criteria are:

  • The system is located, or will be located when installed, on the customer side of a customer’s electric meter;
  • The system is, or will be, primarily used to offset that customer’s electricity load;
  • The system is or will be interconnected to the distribution system of an interconnecting distribution company in Illinois (an electric utility, alternative retail electric supplier, municipal utility, or rural electric cooperative located in Illinois).

Thus, in particular, a system that is not sized to the customer’s load and used primarily to offset that customer’s load is not eligible for the Utility DG RFP. This criterion places a second limit on the size of the system.

04-03-2017

FAQ-DG-74
Q: What are the criteria for a system to be a distributed renewable energy generation device?

For the Utility DG RFP, each system must be a distributed renewable generation device, which means that the system is:

(1) powered by wind, solar thermal energy, photovoltaic cells and panels, biodiesel, crops and untreated and unadulterated organic waste biomass, tree waste, and hydropower that does not involve new construction or significant expansion of hydropower dams;

(2) interconnected at the distribution system level of either an electric utility, an alternative retail electric supplier, a municipal utility, or a rural electric cooperative;

(3) located on the customer side of the customer’s electric meter and primarily used to offset that customer’s electricity load; and

(4) limited in nameplate capacity to no more than 2,000 kilowatts.

04-03-2017

FAQ-DG-75
Q: Are two systems installed on the same site necessarily disqualified from being bid separately into different procurement events?

Two systems that are co-located at the same site would not necessarily be disqualified from being bid separately into different procurement events. For example, if each system had its own Revenue Quality Meter and each system was behind the customer’s meter with each system with a separate utility account, then this would be acceptable.

04-03-2017

FAQ-DG-76
Q: Can you provide more information on M-RETS and GATS and their relevance for the Utility DG RFP?

M-RETS and GATS are tracking systems for RECs. Please find more information at the following websites:

http://www.mrets.org/

https://www.pjm-eis.com/

Bidders with bids approved by the Commission will be required to demonstrate that each one of their systems has been registered in M-RETS or GATS and that each system has begun accumulating metered deliveries tracked by GATS or M-RETS by specific deadlines. RECs procured through this RFP will be transferred from the Supplier’s account in GATS or in M-RETS to the account of the applicable Company in the relevant tracking system. In its Worksheet Insert (#P1-2), a Bidder must identify GATS or M-RETS as the tracking system from which RECs from the system would be transferred to the Company under the applicable supplier contract.

04-04-2017

FAQ-DG-77
Q: We have several systems in our Proposal that we do not own but for which the System Owner and Host are the same entity. What happens if we gain ownership of the systems after the bidding process? If we do so, will a Host Acknowledgment be required at that time?

Please note that a Host Acknowledgement is required in the case of a new system (i.e., not energized as of March 28, 2017).

For the systems to which you refer in your question, if the System Owner and the Host are the same, but the Bidder is not the owner, you, the Bidder, will be required to provide i) a signed contract between the Bidder and the System Owner; or (ii) a letter of intent between the Bidder and the System Owner in which the System Owner agrees that it intends to give the Bidder unconditioned title to the RECs from the systems or the right to legally transfer or assign such RECs to a Company under the term of the applicable supplier contract.

All information provided and certifications made in the Part 1 Proposal, including the identity of the owner of the system, must remain valid and in full force until seventeen (17) business days after the Bid Date. During the Proposal process, once a system is marked as done, and the Bidder is notified of that fact, the Bidder may not change the information or documentation with respect to that system. If the information or documents for the system are no longer valid, the system must be withdrawn from the Proposal.

If the systems to which you refer in your question are part of bids that are approved by the Commission, and after the seventeen (17) days after the Bid Date there is a change in ownership of the system, no further documentation will be required at that time.

04-04-2017

FAQ-DG-78
Q: Can we ask the Procurement Administrator to review some of the backup documentation for our systems in advance of submitting the Part 1 Proposal? We are not using the sample document provided by the Procurement Administrator but we would like to make sure that these are nevertheless acceptable.

You may provide any such document by email to the Procurement Administrator. The Procurement Administrator endeavors to provide such courtesy review but cannot guarantee that such review will be completed before you submit your Part 1 Proposal. We may provide such courtesy review by phone with an email confirmation, saying that the documents that you provided and that we reviewed are/are not in an acceptable format.

Please note, after a courtesy review of your documents, the Procurement Administrator may nevertheless request further information regarding these documents if any aspect of these documents is not consistent with information otherwise provided in your proposal.

04-04-2017

FAQ-DG-79
Q: Can you confirm that for forecast quantities, we cannot receive payment for RECs until February 28, 2018? Can you please provide some references in the applicable supplier contract to help me understand where this is stated? Can you confirm that for systems that are identified and presented in the Proposal, we could potentially receive payment for RECs with our first invoice in July?

The applicable supplier contracts provide for the purchase of RECs from the Seller’s portfolio of systems, which include “Initial Systems” and/or “Subsequent Systems”.

Initial Systems refer to those systems that were included in the Proposal, for which information regarding system characteristics was provided, for which appropriate documentation was provided in the proposal submission process, and that were part of the bidder’s approved bids. For Initial Systems, you may deliver RECs and start receiving payment at any point after such systems have been registered in GATS or M-RETS and have an initial meter read date.  (Please note that the initial meter read date must be on or prior to May 31, 2018 for each such system, otherwise the system is removed from the portfolio of eligible systems for which you may deliver RECs under the applicable supplier contract. This is discussed in Section 4(c) of the (AIC DG) REC Contract and the (MEC DG) REC Contract, and in Section 2.10(c) of the ComEd Master (DG) Agreement.)  Thus, you could potentially receive payment for an invoice in July that could include, for example, RECs delivered from existing systems presented in your Proposal.

Subsequent Systems refer to those systems that are identified to replace a Forecast Quantity that was part of the bidder’s approved bids. These systems are not presented in the bidder’s Proposal and are only identified subsequent to the execution of the applicable supplier contracts. You must submit to the IPA the documents required to identify the characteristics of such systems by January 28, 2018.  The IPA must confirm the addition of such systems to the portfolio of eligible systems under the applicable supplier contracts. The IPA will make one such confirmation, for all systems that are to be added to the portfolio.  Such confirmation is expected to occur between January 28, 2018 and February 28, 2018.  (This process is discussed in Section 4(b) of the (AIC DG) REC Contract and the (MEC DG) REC Contract, and in Section 2.10(b) of the ComEd Master (DG) Agreement.)  Only once such systems are confirmed by the IPA can you deliver RECs from these systems for payment.  Thus, no payment for RECs from such systems would occur prior to February 28, 2018.

04-04-2017

FAQ-DG-80
Q: We are planning to develop a system in the Large Size Class and there is one complication. The roof needs repairs before the system is installed. Can we still include the system in our Proposal? What are the deadlines for the system to be operational?

If you include this system in your Proposal, and the system becomes part of bids approved by the Commission, you will be required to complete the registration of the system in GATS or M-RETS and for the initial meter read date as recorded in GATS and M-RETS to occur by May 31, 2018. If you include this system in your Proposal, it would be considered a “new” system.

04-04-2017

FAQ-DG-81
Q: Can the entity named as the Bidder in the Proposal be different from the Applicant under the Letter of Credit?

The Bidder identified in the Part 1 Proposal must match the Bidder defined in Paragraph 12 of the Letter of Credit. However, the Applicant in the Letter of Credit may or may not be the Bidder.

04-04-2017

FAQ-DG-82
Q: Can we bid in a system that we do not own and then, if we win, assign our contract to the owner of the system?

No, as part of its Proposal, a Bidder will be required to agree to the terms of the applicable supplier contracts and to demonstrate that it has ownership of the RECs for such system or that it has the contractual right to legally transfer or assign RECs from such system to a Company. The Bidder will be the counterparty under the applicable supplier contracts for the delivery of RECs.

04-04-2017

FAQ-DG-83
Q: In the Standard IPA Letter of Credit, can Paragraph 9 explicitly reference the expiry date as a termination point of the Letter of Credit? For example, by adding a clause (c) that states that the Letter of Credit will terminate on the earliest of: “(a) the date you have made drawings which exhaust the amount available to be drawn under this Letter of Credit; or (b) the date we receive from you a Certificate of Cancellation in the form of Annex 3 hereto together with the original of this Letter of Credit (and subsequent amendments, if any) returned for cancellation; or: (c) the Stated Expiry Date?

Paragraph 1 of the Letter of Credit states:

“It is a condition of this Letter of Credit that it shall be deemed automatically extended, without amendment, for additional period(s) of 364 days from the expiration date hereof, or any future expiration date”

By proposing to add the condition to Paragraph 9 of the Letter of Credit that the Letter of Credit will expire on “the Stated Expiry Date”, you directly contradict the terms in Paragraph 1. The Letter of Credit cannot both be: (i) automatically renewing for an additional year and (ii) terminate on the stated expiration date, which will be one year from issuance. As such, this proposed modification, and any modification similar in concept, is unacceptable.

04-04-2017

FAQ-DG-84
Q: With an automatic renewal of the Letter of Credit, does it mean that the Letter of Credit is potentially valid in perpetuity?

No, this does not mean that the Letter of Credit would remain valid in perpetuity; it just means that the exact termination date is subject to uncertainty because it depends on the Bidder’s exact circumstances. These circumstances are detailed in the RFP Rules and summarized here for your convenience, with approximate dates.

If you do not have bids that are approved by the Commission, the Letter of Credit will be returned as soon as practicable after the Commission decision (expected May 3, 2017). If you have bids approved by the Commission, the amount of the Letter of Credit is reduced to match the number of RECs in your winning bids as soon as the Supplier Fees are paid (7 business days after the Commission decision, expected May 12, 2017).   The Letter of Credit is then further reduced as you show that your systems are producing RECs. Specifically:

  • If all your systems are existing and you are not bidding Forecast Quantities, one would expect that all your systems will demonstrate that they have accumulated metered deliveries by the end of the first quarter under the contract, at which point the Letter of Credit would be returned (approximately July 31, 2017).
  • If some of your systems are new but you are not bidding Forecast Quantities, the new systems must be registered in GATS or M-RETS and have the initial meter read date recorded in GATS and M-RETS by May 31, 2018. In that case, the Letter of Credit would be returned by the end of the next quarter, approximately July 31, 2018.
  • If you are bidding Forecast Quantities, the Letter of Credit expires and is returned when all systems must be identified and all such systems must be registered in GATS or M-RETS and have had their initial meter read date by February 28, 2019. In that case, the Letter of Credit would be returned by the end of the next quarter, approximately March 31, 2019.

Note that, under the terms of the applicable supplier contracts, a bidder may ask for an extension for a system to become energized. This could lead to a later return of the Letter of Credit. However, such an extension, if it is granted, will not exceed six months.

04-04-2017

FAQ-DG-85
Q: Can co-located systems be considered separate systems for purposes of bidding in the procurement event? What other conditions should we be aware of?

Systems that are co-located can be considered to be separate systems for purposes of bidding in the procurement event as long as each system has its own separate revenue quality meter and has its own identifier in the applicable tracking system (GATS or M-RETS).

Such systems must also meet the interconnection conditions of the applicable utility and, as a distributed renewable generation device, must be located on the customer side of the customer’s electric meter and be primarily used to offset that customer’s electricity load.

04-04-2017

FAQ-DG-86
Q: If we are not including Forecast Quantities in our Proposal, do we still need to submit the Speculative Insert (#P1-4)?

No. This Insert only applies if you wish to include Forecast Quantities in your Proposal.

04-04-2017

FAQ-DG-87
Q: In Section 4 of the Part 1 Form, we are asked for our forecast quantity. Is this quantity a number of RECs or a number of kW? Is this quantity annual or for the entire duration of the applicable supplier contracts?

The Forecast Quantity is a quantity of RECs that you expect to be produced by systems that you have not yet identified during a single year.

04-10-2017

FAQ-DG-88
Q: How should we calculate the annual number of RECs that will be our Forecast Quantity?

You should calculate the number of RECs that you expect the systems that you have not yet identified to produce annually. For a given system, you can calculate the number of RECs as follows:

(size of system in MW) x (capacity factor for specific technology) x 8760

For example, if you have not yet identified but anticipate a 100 kW photovoltaic system (fixed mount), this would be:

(0.1) x (0.1438) x 8760 = 126 (rounded from 125.97)

If you provide a Forecast Quantity, the Procurement Administrator uses a capacity factor of 14.38% to calculate the associated capacity for purposes of verifying that you meet the 1 MW minimum bid. For example, if you have not identified but anticipate a 100 kW tracking photovoltaic system, the annual RECs would be:

(0.1) x (0.1700) x 8760 = 149 (rounded from 148.92)

The capacity that the Procurement Administrator will associate with a Forecast Quantity of 149 will be:

149 / (0.1438 x 8760) = .11828 MW or 118.28 kW

04-10-2017

FAQ-DG-89
Q: An existing system can be presented in the DG RFP. Does that include systems that are under contract with the IPA pursuant to another procurement event (for example, a procurement event under the SPV RFP)?

No. Systems that are under contract, either with the IPA pursuant to a procurement event under the SPV RFP, or with a utility pursuant to a procurement event under the DG RFP, cannot be presented as part of your Proposal in the Spring 2017 Utility DG RFP.

04-10-2017

FAQ-DG-90
Q: Can we still submit comments or proposed modifications on the Standard IPA Letter of Credit?

Yes. The Procurement Administrator will continue to process comments or proposed modifications for all submissions received by 12 PM (noon) CPT on April 12, 2017.

04-10-2017

FAQ-DG-91
Q: We are presenting some systems that we acquired after the systems had received their GATS approval. Thus, we do not have the approval letter. However, for purposes of documenting the fact that the system is existing, we can provide an Excel file from the GATS website showing that the system has been approved by GATS. Will that be acceptable?

The GATS approval Excel file will be accepted as the approval letter in your particular circumstances.

04-10-2017

FAQ-DG-92
Q: In Paragraph 9 of the Standard IPA Letter of Credit, can we add “the expiration date of the Letter of Credit in accordance with Paragraph 1” as an event of termination?

The IPA has reviewed this proposed modification and found it not to be acceptable.

Your bank may want to consider acceptable modification 1.4, provided below for your convenience.

We, ______________(the “Issuing Bank”), hereby establish this Irrevocable Standby Letter of Credit (this “Letter of Credit”) in your favor in the amount of USD $________________, effective immediately and available to you at sight upon demand at our counters at ________________[designate Issuing Bank’s location for presentments]. This Letter of Credit shall expire 364 days from date of issuance, unless terminated earlier in accordance with the provisions of Paragraph 9 hereof, or otherwise extended. It is a condition of this Letter of Credit that it shall be deemed automatically extended, without amendment, for up to two additional period(s) of 364 days from the expiration date hereof, or any future expiration date, unless at least ninety (90) days before its current expiration date, we send notice to you in writing by registered mail or overnight courier at the address above, and we send notice to the Applicant, that we do not intend to extend this Letter of Credit.

04-10-2017

FAQ-DG-93
Q: Where can I find information and documents regarding the Fall 2017 Distributed Generation RFP?

Information regarding the Fall 2017 Distributed Generation RFP has not yet been released. As guidance you may review the Spring 2017 Distributed Generation RFP documents, which are available here:

https://www.ipa-energyrfp.com/spring-utility-dg/final-materials/

Please note that some aspects of the RFP may change for the Fall procurement event.

04-10-2017

FAQ-DG-94
Q: What is an Agency Agreement?

An Agency Agreement is a contractual relationship whereby one entity (the “agent”) acts on behalf of one or more other entities (the “principals”) in regards to the specific business specified in the agreement.

04-10-2017

FAQ-DG-95
Q: We have a system that spans two buildings and is behind the meter of two different customers. The system has a single GATS account. For purposes of the DG RFP, do we present this as one or two systems?

With a single GATS account, this should be considered to be one system.

04-10-2017

FAQ-DG-96
Q: What should be the amount of the Letter of Credit?

A Bidder must, with its Part 2 Proposal, submit an executed Letter of Credit in the amount of $4 times the number of RECs that the Bidder can win across all systems and the total Forecast Quantity across all delivery years under the applicable supplier contracts. Please note that Attachment 5 to the Part 1 Notification, which was re-issued to all bidders with a correction, includes the required amount of the Letter of Credit assuming you intend to bid on all identified systems and the total Forecast Quantity that you presented in your Part 1 Proposal.

04-20-2017

FAQ-DG-97
Q: Can you provide some examples of how to calculate the required amount for the Letter of Credit?

We provide two examples of the calculations for the required amount for the Letter of Credit, strictly for illustrative purposes.

Example 1. A Bidder presents no identified systems and a total Forecast Quantity of 2,000 RECs. Since this is an annual quantity of RECs, to support the bids, the Letter of Credit must be in an amount of at least:

2,000 RECs x 5 contract years x $4 = $40,000.

Example 2. A Bidder presents a 1 MW solar photovoltaic system (fixed mount) in its Part 1 Proposal. The annual quantity of RECs associated with this system is:

Annual quantity of RECs = 1 MW x 0.1438 capacity factor x 8,760 hours/yr = 1,259.688 RECs

The result is rounded to the nearest REC, i.e., 1,260 RECs, and it represents an annual quantity of RECs. If the Bidder has multiple systems, the Bidder would calculate the number of RECs for each system and round the result for each system separately.

Since this is an annual quantity of RECs, to support the bids, the Letter of Credit must be in an amount of at least:

Required Letter of Credit amount = 1,260 RECs x 5 contract years x $4 = $25,200.

04-20-2017

FAQ-DG-98
Q: Is the entity named as the Bidder in the Part 1 Proposal required to also be the entity that would sign the applicable supplier contracts if the Bidder has bids approved by the Commission?

Yes. With respect to signing the applicable supplier contracts, the entity named as the Bidder in the Part 1 Proposal must be the party that executes the applicable supplier contracts if the Bidder has bids approved by the Commission.

04-20-2017

FAQ-DG-99
Q: Is the entity named as the Bidder in the Part 1 Proposal required to also be the Applicant for the Letter of Credit?

No. With respect to the Letter of Credit, the entity named as the Bidder in the Part 1 Proposal must be identified as such in Paragraph 12 of the Letter of Credit. However, the Applicant, and the entity named in Paragraph 1 of the Letter of Credit, may or may not be the Bidder.

04-20-2017

FAQ-DG-100
Q: The System Owner and the Bidder are different entities. Do we need a letter of intent stating that we have ownership of the RECs from the system?

Any information or documentation that is still required of you to support identified systems is listed in your Part 1 Complete Notice. If, for a given system, the Bidder and System Owner are not the same individual or entity and you have not yet provided a Letter of Intent or other supporting document to show that the Bidder has ownership of the RECs, you will be required to do so by the Part 2 Date, April 20, 2017 at 12 pm (noon) CPT.

04-20-2017

FAQ-DG-101
Q: For one of the systems we present in our Proposal, the Host and System Owner are the same. What documentation will be required (if any) if the ownership of that system is transferred from the Host to us after we win the bid?

All information provided and certifications made in the Proposal, including the identity of the owner of the system, must remain valid and in full force until seventeen (17) business days after the Bid Date. If the systems to which you refer in your question are part of bids that are approved by the Commission, and after the seventeen (17) days after the Bid Date there is a change in ownership of the system, no further documentation will be required at that time.

04-20-2017

FAQ-DG-102
Q: Can we submit a check or cash instead of the Letter of Credit?

The IPA will not accept cash or a check to meet collateral requirements for the Utility DG RFP. All bidders must submit a Letter of Credit with their Part 2 Proposal either in the form of the Standard IPA Letter of Credit or using only modifications acceptable to the IPA and posted to the procurement website.

04-20-2017

FAQ-DG-103
Q: The bank is issuing our Letter of Credit but they cannot promise that it will be received by the IPA by the deadline of 12 PM (noon) CPT on April 20. Will our Part 2 Proposal be automatically rejected?

If your original Letter of Credit is not received by the IPA by the Part 2 Date of 12 PM (noon) CPT on April 20, 2017, you will be given two business days (until 6 PM CPT on April 24) to cure this deficiency. If you do not provide any response by the deadline provided to you, your Part 2 Proposal will be rejected.

04-20-2017

FAQ-DG-104
Q: Can we change the identity of the bidder at the Part 2 Proposal stage?

The bidder in the Part 2 Proposal must be the same as the entity identified as the bidder in the Part 1 Proposal.

04-20-2017

FAQ-DG-105
Q: Can we submit the supplier fees at this time or must we wait until there is a decision of the Commission on the results of the procurement event and the IPA sends us an invoice?

You must wait to receive an invoice from the IPA with the exact amount of the supplier fees as well as full payment instructions before submitting payment.  Supplier fees cannot be paid at this time.

04-20-2017

FAQ-DG-106
Q: Should we contact the IPA or GATS for meter-read verification procedures?

Please contact GATS directly regarding meter-read verification procedures:

gatsadmin@pjm-eis.com

(877) 750-GATS (4287)

04-27-2017

FAQ-DG-107
Q: Are the payments under the applicable supplier contracts based on the RECs actually produced by our solar systems or based on the RECs that would be expected from these systems given their sizes and the capacity factors? If based on actual production, what would happen in an extremely cloudy year?

Under the applicable supplier contracts, payments are based on RECs delivered (so, the production of all the systems under contract, subject to the Maximum Annual Quantity in each Delivery Year). The applicable supplier contracts are structured on a portfolio basis and are not structured on a system-by-system basis. The applicable supplier contract will specify a Maximum Annual Quantity to be delivered, which can be supplied from any of the systems identified as part of the approved bids (or identified subsequently if the approved bids initially specified a forecast quantity) and allocated to the applicable supplier contract with the utility.

If it is an extremely cloudy year and all of your systems produce less than expected, there are two consequences. First, REC payments will be based only on the RECs that you deliver, so that these payments may be lower than those associated with the Maximum Annual Quantity.   Second, if you do not deliver up to the Maximum Annual Quantity, you must provide all of the RECs produced by the systems associated with the applicable supplier contract with the utility; you must not be withholding RECs from the utility or selling RECs from such systems to another party. Such action would be a condition of default under the applicable supplier contracts.

04-27-2017

FAQ-DG-108
Q: Will the IPA accept payment of the supplier fees by wire transfer or must we pay by check?

The IPA does not accept payment via wire transfer but does accept payment by check. Supplier fees are paid only by suppliers with bids approved by the Illinois Commerce Commission (“ICC”).  The ICC is expected to render a decision on the results of the procurement event on May 3, 2017.  Instructions for payment of the supplier fees will be sent to suppliers with approved bids at that time.

04-27-2017

FAQ-DG-109
Q: What are the supplier fees? Were these announced on schedule?

The supplier fee is $3 per REC for the quantity of RECs associated with winning Bids across all Delivery Years.  The supplier fee per REC was announced on April 25, 2017 within the deadline provided by the RFP Rules.

04-27-2017

FAQ-DG-110
Q: If our First Block includes systems from both Size Classes, is it the case that either all of our systems from both Size Classes will be selected or none of them will be selected?

If your First Block includes RECs from both Size Classes, you are required to submit two Bid prices, one for each Product (i.e., one for RECs from the Small Size Class and one for RECs from the Large Size Class). These Bid prices will be evaluated separately.  It is not the case that the entire block is evaluated on a blended price basis.  Thus, it is possible for the evaluation of Bids to select the portion of your First Block for one Size Class and not the portion from the other Size Class.

04-27-2017

FAQ-DG-111
Q: What happens if the actual size of one of our systems turns out to be less than expected? Does this lead to a draw on the Letter of Credit?

The final system size may be different from the planned system size indicated in your Proposal as long as the new system size does not result in a change in the Size Class of the system (e.g., from Small to Large, or vice versa).  This does not in itself lead to a draw on the Letter of Credit (although if you fail to identify sufficient capacity to correspond to the forecast quantity you bid, this could lead to a draw on the Letter of Credit).

Please note that if the system size is reduced for one or more of your systems, this will NOT lead to a reduction in the Maximum Annual Quantity, which is the number of RECs expected to be delivered under the applicable supplier contracts. If you do not deliver the Maximum Annual Quantity, there is no penalty under the applicable supplier contracts as long as you provide all of the RECs from the systems associated with the applicable supplier contract with the utility.  You must not be withholding RECs from the utility or selling RECs from such systems to another party (such action would be a condition of default under the applicable supplier contract).

04-27-2017

FAQ-DG-112
Q: Are wind resources eligible to bid in the IPA’s procurement events? Can I still participate in the Spring 2017 procurement event?

The Utility Distributed Generation RFP (“DG RFP”) solicits suppliers to deliver RECs generated from distributed generation systems to AIC, to ComEd, or to MEC (each a “Company”) or to any combination of these three (3) Companies. Such device may be powered by wind, solar thermal energy, photovoltaic cells and panels, biodiesel, crops and untreated and unadulterated organic waste biomass, tree waste, and hydropower that does not involve new construction or significant expansion of hydropower dams.

The deadlines for the Spring 2017 DG RFP have passed. There will be a second procurement event in the Fall.  While the specifics of the requirements may change at that time, please consult the RFP Rules posted to the Final Materials page of the Spring Utility DG section of the procurement website for details regarding the qualification process and requirements for participation.

If the wind projects to which you are referring are not distributed generation devices, please review information regarding the Initial Forward Procurement as it becomes available. That procurement event has an expected bid date of August 10, 2017 (which would place the start of activities under this procurement event in June).

04-27-2017

FAQ-DG-113
Q: Could a party be prevented from participating in the IPA’s procurement events because of an on-going lawsuit?

It is unclear to us the procurement event to which you refer.  Any such requirements would be representations under the applicable supplier contracts regarding the party’s ability to perform.  Please review the supplier contracts applicable to the procurement event to which you are referring for additional information.

04-27-2017

FAQ-DG-114
Q: I understand that if we have bids that are approved by the Commission, we may be required to signed the applicable supplier contract with more than one utility. Is it possible that a block that is part of our approved bids would be split across two contracts?

The RFP Rules specify that in no case will the allocation of approved Bids result in the RECs from a given system being delivered to more than one Company.  To the extent possible, the allocation of approved Bids will avoid RECs from a given block being delivered to more than one Company.  However, if required to satisfy the Target for MEC, it is possible that such a situation could occur.

04-27-2017

FAQ-DG-115
Q: Will the Fall Utility DG RFP bidding process, parameters, and requirements be the same as the Spring Utility DG RFP?

The Procurement Administrator expects to provide draft documents or a release of parameters for the Fall Utility DG RFP in August 2017. Please check back at that time for additional information about this upcoming RFP.

05-17-2017

FAQ-DG-116
Q: I am clicking on the results page for the DG RFP. It is blank. Where can I find the results of the Spring DG RFP?

The results of the Spring 2017 Utility Distributed Generation RFP (“DG RFP”) have been archived here: https://www.ipa-energyrfp.com/2017-distributed-generation-rfp/

You are likely clicking on the results page for the Fall 2017 DG RFP, which will be populated only when those results become available.

06-13-2017


Wind and Solar FAQs
Click on the question to see the answer:

FAQ-W&S-45
Q: How are RECs delivered to the utilities?

Under the REC Contract, the Seller will deliver RECs to the account of the Buyer in PJM EIS GATS or M-RETS, as applicable.  The RECs will be in an unretired state.

06-25-2017

FAQ-W&S-44
Q: Will the Letter of Credit to support the bid of $15,000/MW be credited towards the REC Agreement Collateral Requirement?

No, the Letter of Credit to support the bid will be cancelled and returned to the bidder.  If the bidder is not a winning bidder in the RFP, such cancellation and return will occur as soon as practicable after the Commission decision on the results of the procurement event.  If the bidder is a winning bidder in the RFP and the winning bidder will sign a REC Contract with a Company, such cancellation and return will occur once all formalities of contract execution with the Company have been completed and once all suppliers fees have been paid to the IPA.

06-25-2017

FAQ-W&S-43
Q: What is the anticipated date of when the Collateral Requirement will be required under the REC Agreement?

The REC Contract (Draft 1) requires the Seller to post any financial guarantees within two (2) business days of a request by the Buyer if such a request is received by 1 PM Eastern Prevailing Time or within three (3) business days otherwise.

06-25-2017

FAQ-W&S-42
Q: Is there a preferred way for the Annual Quantity to be calculated for a project

The participant in the RFP will provide the Annual Quantity for the project as part of its bid.  There is no requirement for this Annual Quantity to be calculated in a specific way and there is no preference that will be assigned in the evaluation based on how the Annual Quantity relates to the capacity of the project.

06-25-2017

FAQ-W&S-41
Q: Are RECs generated by the project above the Annual Quantity, up to the Maximum Contract Quantity, paid for by the IPA?

Under the REC Contract, the purchaser of the RECs will be AIC, ComEd, or MEC.  In a given year, the Seller can deliver up to the Annual Quantity but no more.  If the project generates RECs in excess of the Annual Quantity, these are the property of the Seller.  The Seller can sell these RECs elsewhere, including by offering them in other IPA procurement events, or the Seller can keep the RECs (“bank” them) in case the project does not generate sufficient RECs to meet the Annual Quantity in a future year.  There are no provisions in the REC Contract or elsewhere whereby the IPA automatically purchases such excess RECs.  If the project generates fewer RECs than the Annual Quantity in a given year and the Seller does not provide RECs generated by the project in a prior to meet the Annual Quantity, the Seller is paid only for the RECs delivered.  Furthermore, the Seller cannot “make up” the quantity at a future time by delivering more than the Annual Quantity in a future year.  Thus, the total quantity delivered over the term of the REC Contract never exceeds the Maximum Contract Quantity and the total quantity delivered will fall short of the Maximum Contract Quantity if the Seller delivers less than the Annual Quantity in any year.

06-25-2017

FAQ-W&S-40
Q: Does the Delivery Year Requirement correspond to the Annual Quantity or to the Maximum Contract Quantity under the REC Contract?

Under the REC Contract, the Annual Quantity is specified as the number of RECs to be delivered in each year of the 15-year term of the REC Contract.  The Maximum Contract Quantity is a quantity over the course of the entire term of the REC Contract and the number of RECs to be delivered to the Buyer cannot exceed this quantity, which is calculated as 15 (years) times the Annual Quantity.

The Delivery Year Requirement is the Annual Quantity except for the first 365 days during which the delivery requirement is 50% of Annual Quantity (and the Annual Quantity is pro-rated during the last Delivery Year if it does not consist of a full twelve months.

06-25-2017

FAQ-W&S-39
Q: Can a project satisfy both the definition of a utility-scale solar project and the definition of a brownfield site photovoltaic project? If so, does the participant in the RFP have the option of which Category to use for the project?

Public Act 099-0906 defines these two types of projects as follows.  (1) A “utility-scale solar project” is facility that: (a) generates electricity using photovoltaic cells; and (b) has a nameplate capacity that is greater than 2,000 kW.  (2) A “brownfield site photovoltaic project” is a facility that: (a) is interconnected to an electric utility, a municipal utility, a public utility, or an electric cooperative; and (b) is located at a site that is regulated by any of the following entities under the following programs: (i) the United States Environmental Protection Agency under the federal Comprehensive Environmental Response, Compensation, and Liability Act of 1980, as amended; or (ii) the United States Environmental Protection Agency under the Corrective Action Program of the bituminous rank and greater than 1.7 pounds of sulfur per million btu content, unless the clean coal facility does not use gasification technology and was operating as a conventional coal-fired electric generating facility on June 1, 2009 (the effective date of Public Act 95-1027) federal Resource Conservation and Recovery Act, as amended; or (iii) the Illinois Environmental Protection Agency under the Illinois Site Remediation Program; or (iv) the Illinois Environmental Protection Agency under the Illinois Solid Waste Program.

There is no size criterion for a brownfield site photovoltaic project and thus it is possible for a project to satisfy both definitions.  This would be the case for a photovoltaic project that is:  interconnected at the distribution level as defined in 2(a) above; located on a brownfield site as defined in 2(b) above; and with a nameplate capacity of 2,000 kW or more as in 1(b) above.  In that case, the participant in the Wind and Solar RFP would be able to elect to describe its Project as either a utility-scale solar project or a brownfield site photovoltaic project, at its option (but not both).

06-25-2017

FAQ-W&S-38
Q: The next round of feasibility study results from PJM could be released as late as the first or second week of August 2017. Would the IPA consider delaying the Bid Date?

Thank you for your comment.  As announced on Friday, June 23, the IPA will be soliciting a second round of comments on the REC Contract.  The schedule has changed and the Bid Date will be August 31, 2017 (instead of August 10, 2017).

06-25-2017

FAQ-W&S-37
Q: Can renewable energy sources other than wind and solar, such as hydro for example, also participate in the upcoming procurement events?

No.  Public Act 99-0906 (“Act”), which became effective June 1, 2017, calls for an initial forward procurement of one million renewable energy credits (“RECs”) annually from new utility-scale wind projects and of one million RECs annually from new utility-scale solar projects and brownfield site photovoltaic projects.  The first procurement event will seek the entirety of the one million RECs annually from new utility-scale wind projects and will seek a portion of the one million RECs annually from new utility-scale solar projects and brownfield site photovoltaic projects.  There will be multiple events to procure RECs from new utility-scale solar projects and brownfield site photovoltaic projects.  No other renewable energy source are contemplated by the Act for these procurement events.

06-21-2017

FAQ-W&S-36
Q: How can I navigate to the FAQs for the Wind and Solar RFP?

To view the FAQs for the Wind and Solar RFP, navigate to the FAQs page of the procurement website, and either:

  • select “Click here to view Wind and Solar”; or
  • scroll down the page until you see the heading “Wind and Solar FAQs”.
06-21-2017

FAQ-W&S-35
Q: Is the IPA the buyer of the RECs in the initial forward procurements?

While the IPA is responsible for the procurement of RECs in the initial forward procurements, the IPA is not buyer of these RECs.  The buyers of the RECs, and the counterparties to the contract with winning bidders in the upcoming Wind and Solar RFP, are the utilities,  Ameren Illinois Company d/b/a Ameren Illinois, Commonwealth Edison Company, and MidAmerican Energy Company (“MidAmerican” or “MEC”).

06-21-2017

FAQ-W&S-34
Q: Will the IPA consider repowered facilities as “new” projects for purposes of the upcoming procurement event under the Wind and Solar RFP?

No.  The statutory support for the initial forward procurements envisions that procurements of RECs occur only from “new” projects.  The definitions of “new” wind and photovoltaic projects found in Section 1-75(c) of the IPA Act refers to new “renewable energy generating facilities,” with “facility” defined in the IPA Act as “an electric generating unit or a co-generating unit that produces electricity along with related equipment necessary to connect the facility to an electric transmission or distribution system.”  As a substantial portion of what constitutes the “facility” would not be “new,” and as repowered facilities would be competing for selection on the basis of price with facilities featuring entirely “new” components, the IPA does not consider repowered projects to be “new” projects that qualify for the initial forward procurement.  To the extent that parties believe that such projects should be considered “new” for future RFPs, parties may offer those comments as part of their comments on the draft of the IPA’s long-term renewable resources procurement plan scheduled to be released in September 2017.

06-21-2017

FAQ-W&S-33
Q: An August Bid Date for the first procurement event under the Wind and Solar RFP means that the Bid Date occurs prior to the expected recommendations for remedy by the International Trade Commission for the Suniva trade case and prior to implementation of the final remedy. Does the IPA plan to issue any guidance on how bidders should address this?

The IPA cannot issue guidance on a case pending before the International Trade Commission.  It is the responsibility of the bidder to decide if or how to take the potential outcome of the case into account in their participation in the Wind and Solar RFP.  We note that there are multiple procurement events for utility-scale solar and that more information regarding this issue may be available in later procurement events.

06-16-2017

FAQ-W&S-32
Q: Does Public Act 099-0906 specify, in its definitions of the projects eligible for the Wind and Solar RFP, whether the projects have to be behind the meter or in front of the meter?

In its definition of the utility-scale wind, utility-scale solar, and brownfield photovoltaic, Public Act 099-0906 does not specify whether the system is in-front-of or behind the meter.

06-16-2017

FAQ-W&S-31
Q: We cannot attend the webcast on the draft REC Contract for the Solar and Wind RFP. Where can we access the materials?

The webcast presentation and audio recording were posted to the Draft Documents page of the Wind and Solar Section of the procurement website on June 6, 2017.

06-13-2017

FAQ-W&S-30
Q: What is the bid participation fee for the Wind and Solar RFP? Is this fee paid for each project or for each participant? Are there other fees for which a participant is responsible?

Each participant in the Wind and Solar RFP will be required to pay a non-refundable Bid Participation Fee of $500 (unless such participant has already paid a Bid Participation Fee in 2017 pursuant to its participation in the Block Energy RFP or the Distributed Generation RFP).  A participant that presents several projects is only required to pay a single Bid Participation Fee.  The Bid Participation Fee will be used to cover part of the costs of the 2017 procurement events.  The Supplier Fees, which are levied only on those participants that have bids approved by the Illinois Commerce Commission, are also used to cover part of the costs of the procurement events.  An estimate of the Supplier Fees, which will be in $/REC and will be applied to the annual quantity of RECs for a winning project, will be provided during the webcast planned for June 28.

06-13-2017

FAQ-W&S-29
Q: How long was the webcast on the draft REC contract scheduled for?

The webcast for the Wind and Solar RFP was scheduled for 90 minutes.  The webcast presentation and audio recording are posted to the Draft Documents page of the Wind and Solar Section of the procurement website.

06-13-2017

FAQ-W&S-28
Q: Are wind or solar RECs evaluated together? Just want to make sure that the process does not put solar at a disadvantage.

Wind and Solar bids will be evaluated separately.

06-09-2017

FAQ-W&S-27
Q: If projects sell their energy (but not their RECs) to an affiliated utility with a rate base via a PPA, does this mean that the project has a return from a rate base and is ineligible to participate?

Section 1-75(c)(1)(J) of the Illinois Power Agency Act provides that renewable energy credits from generating units “whose costs are being recovered through rates regulated by this State or any other state or states on or after January 1, 2017” are ineligible for Illinois RPS compliance. Primarily, the IPA believes that this requirement was intended to ensure that RECs from rate-based projects approved by a state’s public utilities commission are not eligible to be used to satisfy the Illinois RPS, and thus is generally not intended to encompass off-take agreements, power purchase agreements, or the wholesale sales of energy, unless those transactions were expressly approved by the state’s public utilities commission or other relevant regulatory authority in a proceeding to set regulated utility rates.  However, a final interpretation of this language is not being offered through this RFP process; further detail around the determination of whether a generating unit’s “costs are being recovered through” regulated “rates” will be included in the IPA’s long-term renewable resources plan, and any final determinations about the scope of projects included in that prohibition will be subject to final determination by the Illinois Commerce Commission in its Order approving the IPA’s proposed plan.

06-09-2017

FAQ-W&S-26
Q: If I build a 10 MW project that produces 12,000,000 kWh and I bid $100/REC, is the collateral requirement under the REC Contract $1.8M?

That is correct. If your project’s annual production is 12,000,000 kWh then the REC production is 12,000 RECs (12,000,000 kWh = 12,000 MWh = 12,000 annual RECs). Prior to the first REC delivery, the collateral requirement is 1.5 times the Annual Contract Value or $50,000, whichever is greater. With a bid price of $100 per REC, the Annual Contract Value is $100 x 12,000 or $1.2M.  Thus, the collateral requirement is the greater of $1.2M x 1.5 = $1.8M or $50,000, which is $1.8M.

After the first REC delivery, the collateral requirement is reduced to 1 time the Annual Contract Value or $50,000, whichever is greater. Finally, the collateral requirement in the last delivery year is reduced to reflect the amount that will be delivered in that delivery year (which may be less than a full year).

Revised 6-12-2017 first posted 6-09-2017

06-09-2017

FAQ-W&S-25
Q: What is the remedy to the Seller for the failure of the Buyer to purchase the RECs?

Failure by Buyer to make payment for RECs is an Event of Default under Article 5.1(a) of the Master REC Agreement included as part of the REC Contract. Remedies afforded to Seller include remedies set forth in Articles 5.2, 5.3 and 5.5 of the Master REC Agreement as modified by the Cover Sheet of the REC Contract.

06-09-2017

FAQ-W&S-24
Q: Does the IPA routinely accept proposed contract comments and modifications from interested parties?

Yes, a comment process for the contract form is a standard practice in connection with all IPA competitive procurement events as required by the Public Utilities Act. If you have any comments or concerns regarding the current draft of the REC Contract, please submit them before the deadline at 6 PM CPT Wednesday, June 14, 2017. The Invitation to Comment, which includes instructions for submitting comments, is found on the Draft Documents page of the Wind and Solar section of the procurement website.

06-09-2017

FAQ-W&S-23
Q: Why is the contract governed by New York law instead of Illinois law?

New York law is provided as the governing law to be consistent with other contracts for the procurement of RECs by the utilities. Please submit a redlined Microsoft Word document with any edits you would like to propose for consideration before the deadline at 6 PM CPT Wednesday, June 14, 2017. The Invitation to Comment, which includes instructions for submitting comments, is found on the Draft Documents page of the Wind and Solar section of the procurement website.

06-09-2017

FAQ-W&S-22
Q: Can we use RECs issued prior to the contract execution to meet the Delivery Year Requirements during the Delivery Term?

Only RECs based on electricity generated during the Delivery Term and 2 months prior to the start of the Delivery Term would be eligible for delivery during the Delivery Term as such term is defined in the REC Contract.

06-09-2017

FAQ-W&S-21
Q: Will instructions and documents be provided for payment of fees and security required by the RFP process?

Yes, instructions will be provided upon request by email to Illinois-RFP@nera.com. The IRS Form W-9 for the IPA and payment instructions for the bid participation fee will be available as soon as practicable and no later June 28, 2017, the date the RFP documents are issued.

06-09-2017

FAQ-W&S-20
Q: Will the final REC Contract explicitly state that excess RECs in a Delivery Year may be used in subsequent Delivery Years?

The currently proposed contract terms are available on the Draft Documents page of the Wind and Solar section of the procurement website. Please submit a redlined Microsoft Word document with any edits you would like to propose for consideration before the deadline at 6 PM CPT Wednesday, June 14, 2017. The Invitation to Comment, which includes instructions for submitting comments, is found on the Draft Documents page of the Wind and Solar section of the procurement website.

06-09-2017

FAQ-W&S-19
Q: What is the definition of “Applicable Program” as used in Section 6: Certifications of the REC Contract?

The Illinois Renewable Portfolios Standard (“RPS “) is the “Applicable Program” under this REC Contract. Information on the Illinois RPS can be found in Section 1-75(c) of the IPA Act.

06-09-2017

FAQ-W&S-18
Q: Are the collateral requirements consistent with other state RPS programs and if not, how are they inconsistent?

The Procurement Administrator answers questions related to the IPA procurement events. Potential participants are entirely responsible for research of other state RPS programs.

06-09-2017

FAQ-W&S-17
Q: Can you explain the intent of Section 5(f) of the Cover Sheet of the REC Contract? [(f) At least 50% of the Project is located within the physical location identified in the Site Description in Table 1.]

This provision ensures that the site provided for the Project as part of the Proposal, and for which a description is provided in Table 1, is substantially similar to the site of the Project when such Project is fully developed. The Seller must certify that the RECs delivered come from the Project and that such Project is in majority at the site provided in the Proposal.  Thus, the Seller cannot substitute another Project in a different location for the Project presented in its Proposal and the development of the Project at the Proposal stage must be sufficient to substantially describe the site. Additional information about site control will be part of the early information release expected the week of June 12.

06-09-2017

FAQ-W&S-16
Q: If Seller delivers 50% of the Delivery Year Requirement in a Delivery Year, can Seller make up that shortfall in the Subsequent Delivery Year by delivering 150% of the Delivery Year Requirement?

No, accounting is made for the Delivery Year Requirement at the end of each Delivery Year. You cannot make up for shortfalls in a Delivery Year with subsequent Delivery Years’ excess production of RECs.

06-09-2017

FAQ-W&S-15
Q: Are there minimum and maximum contract sizes for solar?

There is no minimum on the contract quantity presented in the Proposal. The maximum that can be provided is the target in the procurement event.  For solar multiple procurement events are expected and thus this maximum will be different for each procurement event and will be below the 1,000,000 REC annual target.

As a reminder, while there is no minimum contract size, there is a minimum on the nameplate capacity of utility-scale solar projects, which is 2 MW AC. This minimum size requirement does not apply to brownfield site PV projects.

06-09-2017

FAQ-W&S-14
Q: What are the qualification requirements for a project to participate in the Wind and Solar RFP?

The RFP Rules for the Wind and Solar RFP have not yet been finalized. The requirements are expected to cover interconnection, site control, and the type of bidder fees that may be due.

The Procurement Administrator posted an outline of the proposal requirements on a draft and preliminary basis on June 14, 2017. This document is posted to the Draft Documents Page of the Wind and Solar section of the procurement website.

This early information release was announced to the registrants’ list.  If you have not yet registered for announcements, please do so by filling out the Registration Form and selecting the “Wind and Solar RFP” category.

06-16-2017

FAQ-W&S-13
Q: After the contract is finalized and posted on June 27, 2017, will there be any opportunity to negotiate the terms of the contract?

No. As required by Section 16-111.5 on the bid solicitation process, after the standard form contract is finalized and posted on June 27, 2017, all bidders in the Wind and Solar RFP will be required to accept the terms of the final contract prior to submission of bids. If you have any comments or concerns regarding the current draft of the REC Contract, please submit them before the deadline at 6 PM CPT Wednesday, June 14, 2017. The Invitation to Comment, which includes instructions for submitting comments, is found on the Draft Documents page of the Wind and Solar section of the procurement website.

06-09-2017

FAQ-W&S-12
Q: Are you accepting proposed modifications to the Forms of the Guaranty during the contract comment process?

Yes. You may provide comments on the entire draft REC Contract. All comments and proposed modifications to any part of the draft REC Contract should be provided in a redlined Microsoft Word document.

06-09-2017

FAQ-W&S-11
Q: Regarding the August 10, 2017 date that is referenced on Slide 5 of the presentation from the Wind and Solar RFP Virtual Contract Workshop held on June 6, 2017, is this when the RFP will be issued or when bids are due?

August 10, 2017 is the expected Bid Date for the Wind and Solar RFP. The final contracts are expected to be posted on June 27, 2017 and the RFP documents are expected to be issued on June 28, 2017.

06-09-2017

FAQ-W&S-10
Q: Will the REC contract terms for the Wind and Solar RFP (Initial Forward Procurement) be the same as the contract terms for the forthcoming Adjustable Block Program for Distributed Generation projects?

No. The REC Contract terms for the Wind and Solar RFP (Initial Forward Procurement) are in draft form and are still under development, it would be premature to compare these terms with other contracts that are not yet under development and will not be under development until sometime after the IPA’s long-term renewable resources plan is approved by the Illinois Commerce Commission (early 2018). The projects eligible for the Adjustable Block Program, however, are distributed generation or community solar projects (and not utility-scale), and are governed by different provisions of the IPA Act (Section 1-75(c)(1)(G) for the Initial Forward Procurement, and Section 1-75(c)(1)(L) for the Adjustable Block Program). It is therefore expected that the terms of the two contracts will differ.

06-09-2017

FAQ-W&S-9
Q: Besides the webcast on the draft REC Contract, will there be a separate workshop or presentation regarding RFP requirements?

Yes, a separate webcast will be held to explain the RFP process and requirements. This webcast is scheduled to be held on June 28, 2017 after the final contract is posted. You can RSVP for this webcast now!

06-09-2017

FAQ-W&S-8
Q: Are replacement RECs allowed under the terms of the draft contract? For example, can a successful bidder whose project’s production has fallen short of its annual quantity buy another successful bidder’s RECs produced from a winning project in excess of its annual quantity to meet its delivery year obligation?

No. RECs must be delivered from the project to which the contract was awarded.

06-09-2017

FAQ-W&S-7
Q: Given there will likely be multiple utility contracts signed for each winning project, is the unsecured credit of $2.5 MM in the REC Contract granted to investment grade entities per utility or across multiple utility contracts?

If a Seller or a Seller’s guarantor is creditworthy and meets the credit rating requirements under the REC Contract, the $2.5MM unsecured credit is granted by each utility separately to you for all your contracts with the applicable utility. For example, if you have several projects that are associated with winning bids, the unsecured credit of $2.5MM will apply across all of your contracts with a given utility.

06-09-2017

FAQ-W&S-6
Q: On slide 13 of the presentation from the Wind and Solar RFP Virtual Contract Workshop held on June 6, 2017, there appears to be a discrepancy in the number of RECs the Seller won (6,000 RECs) and the Maximum Contract Quantity (15,000 RECs) indicated in the example Table 1. Please explain this discrepancy.

This is not a discrepancy. The example on this slide illustrates a hypothetical Seller that was awarded 6,000 RECs to be delivered on an annual basis. These winning RECs are then allocated to the Buyers (the three electric utility counterparties to the contracts) as follows: 1,350 RECs to AIC; 3,650 RECs to ComEd; and 1,000 RECs to MEC.  For illustrative purposes, Table 1 from the REC Contract is shown for the corresponding MEC contract, which indicates the Annual Quantity of 1,000 RECs and the Maximum Contract Quantity, or the maximum quantity of RECs to be delivered to MEC over the 15 year term of the contract, of 15,000 RECs.

06-09-2017

FAQ-W&S-5
Q: Are the REC prices used in examples provided in the presentation from the Wind and Solar RFP Virtual Contract Workshop held on June 6, 2017 intended to be representative of expected bid prices?

No. All prices and quantities used in the examples in the presentation are provided for illustrative purposes only.

06-09-2017

FAQ-W&S-4
Q: Does the Wind and Solar RFP (Initial Forward Procurement) contemplate procuring power from qualifying projects in addition to RECs?

No, this procurement is for RECs only. The contract does not include an energy component.

06-09-2017

FAQ-W&S-3
Q: What does the project requirement of “NOT a generating unit whose costs are being recovered through rates regulated by Illinois or other state(s)” mean?

This provision is set forth in the Illinois Power Agency (“IPA”) Act, Section 1-75(c)(1)(J), with renewable energy credits from generating units “whose costs are being recovered through rates regulated by this State or any other state or states on or after January 1, 2017” being ineligible for Illinois RPS compliance. Primarily, the IPA believes that this requirement was intended to ensure that RECs from rate-based projects approved by a state’s public utilities commission are not eligible to be used to satisfy the Illinois RPS, and thus is generally not intended to encompass off-take agreements, power purchase agreements, or the wholesale sales of energy, unless those transactions were expressly approved by the state’s public utilities commission or other relevant regulatory authority in a proceeding to set regulated utility rates. However, a final interpretation of this language is not being offered through this RFP process; further detail around the determination of whether a generating unit’s “costs are being recovered through” regulated “rates” will be included in the IPA’s long-term renewable resources plan, and any final determinations about the scope of projects included in that prohibition will be subject to final determination by the Illinois Commerce Commission in its Order regarding the IPA’s proposed plan.

06-09-2017

FAQ-W&S-2
Q: Is the contract form subject to approval by the Illinois Commerce Commission (“ICC”)?

As required under Section 16-111.5 of the Public Utilities Act (through Section 1-75(c)(1)(G)(v) of the IPA Act), the Procurement Administrator develops the contracts in consultation with each of the applicable utilities, the Illinois Power Agency, the ICC Staff, and the Procurement Monitor. Only if these parties are unable to come to a consensus would the ICC then make a determination on the final contract form.

06-09-2017

FAQ-W&S-1
Q: Will it be a requirement of the Wind and Solar procurement event (Initial Forward Procurement) that projects be located in Illinois?

No, projects may be located in Illinois or in a State that is adjacent to Illinois. However, for renewable energy credits to qualify for the Illinois RPS for projects located in a state adjacent to Illinois, then the project must meet the public interest criteria specified in Section 1-75(c)(1)(I) of the IPA Act. All further information related to application of the public interest criteria will be first proposed in the Illinois Power Agency’s long-term renewable resources procurement plan (due to be released within 120 days of June 1, 2017), with the Illinois Commerce Commission having final approval of the application of these criteria through its administrative order approving the IPA’s plan. Please review Section 5(d) of the draft REC Contract regarding the consequences for an adjacent-state project being subsequently found to be ineligible for the Illinois RPS under application of the public interest criteria.

06-09-2017


General FAQs
Click on the question to see the answer:

FAQ-Gen-1
Q: When are login credentials issued to access the online Part 1 Form prior to a procurement event?

Login credentials are issued the day before the Part 1 Window opens. Returning bidders as well as participants that requested an account for the first time all receive their credentials on the same date. When requesting an account for the first time, participants should ensure that they select the category corresponding to the procurement event of interest at the bottom of the web form.

If you do not receive login credentials on the day before the Part 1 Window opens, please contact us via email (Illinois-RFP@nera.com). Please include your name, phone number, company name, and email address in your communication to us.

02-27-2017

FAQ-Gen-2
Q: Can we use the “ask a question” form to ask general questions or only to ask information specifically about the procurement events?

This website is for the IPA’s procurement events of electric supply and renewable energy products.  The “ask a question” form is expected to be used by suppliers that are looking for information relevant to their participation in these procurement events. While we respond to all stakeholders that submit questions, we do not respond to general questions or provide general information that is not specific to the IPA’s procurement events.

02-27-2017

FAQ-Gen-3
Q: Where can I find the results from previous RFPs?

Results are posted to the top of each archived RFP page here:
https://www.ipa-energyrfp.com/previous-rfps/

Results are also posted to the Illinois Commerce Commission website here:
https://www.icc.illinois.gov/electricity/workshops/

02-27-2017

FAQ-Gen-4
Q: Where can I find information regarding past RFPs?

Up to procurement events from 2012, links to the RFPs are provided in two columns, one for ComEd and one for Ameren Illinois, at this link:

https://www.ipa-energyrfp.com/previous-rfps/

For the procurement events from 2014 onward, links to the RFPs are provided for all participating utilities at the top of this page:

https://www.ipa-energyrfp.com/previous-rfps/

For instance, the information related to the 2015 energy and capacity procurements are here:

https://www.ipa-energyrfp.com/2015-standard-products-section/

02-27-2017

FAQ-Gen-5
Q: Will there be a further procurement event under the Supplemental Photovoltaic Procurement Plan? What are other renewable energy procurements are planned thus far for 2017?

The Supplemental Photovoltaic Procurement Plan developed by the IPA and approved by the Illinois Commerce Commission allows for a possible fourth procurement event in Spring 2017, called the Supplemental Photovoltaic Contingency Procurement. The Agency has determined that it is not necessary to conduct a Supplemental Photovoltaic Contingency Procurement.

The following renewable energy procurement events for 2017 are planned and tentative schedules have been released:

  • Two procurements for distributed renewable generation resources on behalf of Ameren Illinois, ComEd, and MidAmerican pursuant to the Agency’s 2017 Procurement Plan. The first of these procurement events is planned for this Spring and the schedule is available here:

   https://www.ipa-energyrfp.com/calendar/

  • Once Public Act 99-0906 becomes effective on June 1, 2017, the IPA expects to conduct an initial forward procurement event for Wind/Solar in summer 2017. The expected schedule, which is provided here:

   https://www.illinois.gov/sites/ipa/Documents/2017-Schedule-Announcement.pdf

   has bidder registration beginning June 22, 2017 and a Bid Date of August 10, 2017.

Additional forward solar procurement events will be scheduled at a later date. All such schedules will be posted to the Calendar page of the procurement website.

If you have not already done so, we suggest that you complete the form to Register to receive updates and information regarding the RFPs. These updates will include announcements of upcoming procurement events.

02-28-2017

FAQ-Gen-6
Q: If two affiliates participate in different procurement events in a given year, do they pay a single bid participation fee or would each entity pay its own bid participation fee?

The two entities would be submitting separate proposals for different procurement events and each entity would pay its own bid participation fee.

03-02-2017

FAQ-Gen-7
Q: Is there information available at this point on how the programs to be held under Public Act 099-0906 will be implemented?

At this time, there is no implementation information regarding the programs to be held under Public Act 099-0906. This Act was signed into law on December 7, 2016 and will go into effect on June 1, 2017. The link below is to the bill itself:

http://www.ilga.gov/legislation/publicacts/99/PDF/099-0906.pdf

03-09-2017

FAQ-Gen-8
Q: How can we contact the Procurement Administrator by phone?

If you wish to speak to the Procurement Administrator, please send us an email with the topic of your question and your phone number. The appropriate individual from the Procurement Administrator will give you a call at the number you provided.

03-20-2017

FAQ-Gen-9
Q: Can you provide an overview of the product from the 2016 capacity procurement event for Ameren Illinois Company (“AIC”)? Were bidders required to identify the capacity resources as part of the RFP?

Under the 2016 capacity procurement event for AIC, there was no requirement for identifying resources within the proposal submitted in response to the Standard Products RFP. However, the winning bidder was responsible for the registration of the Planning Resources in MISO and for all obligations associated with such Planning Resources to ensure that the Zonal Resource Credits (“ZRCs”) delivered to AIC have good and marketable titles.

The product for bid was annual ZRCs, as such term is defined in MISO’s Business Practice Manuals and MISO’s Open Access Transmission, Energy and Operating Reserve Market Tariff for a given planning year. A target of ZRCs to be procured was established as a given percentage of AIC’s requirement in that planning year.   A winning bidder would be required to deliver the contracted quantity of ZRCs by submitting the appropriate transactions in the Module E Capacity Tracking Tool. The amount paid to the winning bidder was the average of the winning bidder’s own approved Bids for all ZRCs in that planning year, in $/MW-Day, multiplied by the number of ZRCs delivered, multiplied by the number of calendar days in the Planning Year. If any of the ZRCs were not located in Local Resource Zone 4, which is the zone in which AIC capacity obligations reside, the payment to the winning bidder was adjusted as follows. If the clearing price of the MISO Planning Resource auction for LRZ 4 was greater than the clearing price of source zone for the ZRCs, then the payment would be reduced by the difference in the clearing prices between the two zones multiplied by the quantity of ZRCs. Conversely, if the clearing price of the MISO Planning Resource auction for LRZ 4 was less than the clearing price of source zone for the ZRCs, then the payment would be increased by the difference in the clearing prices between the two zones multiplied by the quantity of ZRCs.

03-23-2017

FAQ-Gen-10
Q: Is information available regarding the Fall 2017 AIC capacity procurement event? What are the changes that are expected compared to the Fall 2016 AIC capacity procurement event?

Information regarding the Fall 2017 AIC capacity procurement event is not yet available. The 2017 Procurement Plan does not propose changes to the process that was used for the Fall 2016 AIC capacity procurement event, for which documents are available under the “Previous RFP” section of the procurement website (in the Fall 2016 Standard Products RFP).

03-23-2017

FAQ-Gen-11
Q: Is there a REC RFP this year in the same format as was used in the last two years?

There is no procurement event planned for 2017 using the exact format of the REC RFP From the past two years.  Please see the tentative schedule of the IPA for other renewable energy events:

https://www.illinois.gov/sites/ipa/Documents/2017-Schedule-Announcement.pdf

04-02-2017

FAQ-Gen-12
Q: Will my login credentials change in the Fall for a procurement event under the same RFP?

The Procurement Administrator will provide login credentials for the Fall RFP a day prior to the opening of the Part 1 Window. We will confirm at that time either that the login credentials will remain the same or provide you with updated credentials.

04-03-2017

FAQ-Gen-13
Q: Is there a target for the Initial Forward Wind/Solar RFP scheduled for Q3 of 2017?

This information is not yet available. When available, the information will be posted to the procurement website and may be sent in an announcement to website registrants. You can register to receive announcements from the Procurement Administrator here:

https://www.ipa-energyrfp.com/contact-us/register/

04-03-2017

FAQ-Gen-14
Q: Where are the materials from the workshops held by the IPA posted and will these include recordings of the workshops?

All materials from the workshops held by the IPA will be posted to the Illinois Power Agency’s (“IPA”) website at: https://www.illinois.gov/sites/ipa/. These materials include the presentations but not recordings of the workshops.

05-17-2017

FAQ-Gen-15
Q: Will the utilities be purchasing energy or capacity in addition to the RECs through the Wind and Solar Initial Forward Procurements?

No, the Initial Forward Procurements will only procure RECs.

05-17-2017

FAQ-Gen-16
Q: Can you please provide the addresses for the procurement website and for the IPA’s website?

You can access the procurement website at: https://www.ipa-energyrfp.com/.  You can access the IPA website at: https://www.illinois.gov/sites/ipa/Pages/default.aspx.

06-13-2017

FAQ-GEN-17
Q: Where can I find information regarding the workshops held by the Illinois Power Agency in May?

All publicly available information regarding the Illinois Power Agency Workshops held on May 10, May 17, May 18, and May 24 can be found on the Renewable Resources tab of the IPA’s website:
https://www.illinois.gov/sites/ipa/Pages/RenewableResourcesWorkshops.aspx

06-25-2017