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.

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Block Energy and Capacity 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-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-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

FAQ-BE-31
Q: Regarding the comment process for the draft (AIC) Capacity Agreement, am I correct to assume that you are soliciting comments only on proposed changes that have been made relative to the previously used 2016 (AIC) Capacity Agreement and not on the entire contract?

Yes, you are correct.

07-13-2017

FAQ-BE-32
Q: The (AIC) Capacity Agreement provides in “Schedule 1 to the Form of Guaranty,” a list of acceptable modifications to the standard Guaranty (Attachment B). Am I correct that modifications on this list is acceptable for all counterparties to use on an optional basis and we are not required to request pre-approval to use these modifications.

Yes, you are correct.

07-13-2017

FAQ-BE-33
Q: Am I required to submit a Bid Participation for the Fall 2017 Block Energy and Capacity RFP if I paid a Bid Participation Fee during the Spring 2017 Block Energy/Standard Products RFP?

No. A Bidder is only required to pay a Bid Participation Fee if it has not paid the Bid Participation Fee pursuant to its participation in a prior 2017 procurement event.

07-20-2017

FAQ-BE-34
Q: Is the Procurement Administrator accepting comments on the letters of credit? If so, when is the deadline to provide comments? Additionally, is the Procurement Administrator accepting comments on other aspects of the Fall 2017 Block Energy and Capacity RFP?

Bidders may provide comments on the Standard Pre-Bid Letters of Credit for a Company, including the AIC Energy, ComEd, MEC, and AIC Capacity procurement events. Each Bidder provides comments to the applicable Standard Pre-Bid Letter of Credit for a Company that is posted to the procurement website using tracked changes in Microsoft Word. Any one of a Bidder’s comments or proposed modifications may result in an addition to the list of modifications to the Standard Pre-Bid Letter of Credit approved by a Company for use by all Bidders on an optional basis. The deadline to provide comments on the Standard Pre-Bid Letters of Credit is the Part 1 Date of August 3, 2017.

The Procurement Administrator is not accepting comments on other aspects of the Fall 2017 Block Energy and Capacity RFP at this time.

07-20-2017

FAQ-BE-35
Q: What is the provisional ZRC Target for the upcoming Ameren Illinois Company (“AIC”) Capacity procurement event and when will the ZRC Target be finalized? Additionally, is there a cap on the number of ZRCs a single Bidder can win?

The provisional ZRC Target is 926 ZRCs for the upcoming AIC Capacity procurement event.  The final ZRC Target is expected to be provided to Bidders on the date of the Part 1 Notification (August 8, 2017). A Bidder may bid on any number of ZRCs up to the ZRC Target and there is no cap on the number of ZRCs a single Bidder can win.

07-21-2017

FAQ-BE-36
Q: The individual who usually serves as the Officer of the Bidder will be away during the Part 1 Window. Can we have a different Officer sign the certifications required by the Part 1 Proposal and then have the individual who usually serves as Officer of the Bidder sign the certifications required by the Part 2 Proposal? Alternatively, can the individual who usually serves as Officer of the Bidder have another individual sign on their behalf for the certifications required by the Part 1 Proposal?

All representations and certifications required by the Block Energy and Capacity RFP, including those in the Part 1 Proposal and the Part 2 Proposal, must be made by a single individual who is an Officer of the Bidder. An Officer of the Bidder is an individual empowered to undertake contracts and bind the Bidder.

If you expect that the individual who usually serves as the Officer of the Bidder will not be available to make the certifications required by the Part 1 Proposal, please name another individual with the appropriate qualifications to serve as Officer of the Bidder during the Part 1 Window. The individual who usually serves as Officer of the Bidder may not have another individual sign on their behalf when the individual who usually serves as Officer of the Bidder is unavailable. 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 their 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. Alternatively, if possible, you may have the individual who usually serves as Officer of the Bidder make all certifications required by the Part 1 Proposal and the Part 2 Proposal during the Part 1 Window and submit these with the Part 1 Proposal.

07-21-2017

FAQ-BE-37
Q: Can you please confirm that our understanding of the (AIC) Capacity Agreement is correct? First, if we fail to deliver all or a portion of the Zonal Resource Credits (“ZRC””) to AIC (the Buyer), we are responsible for all penalties and/or charges assessed to the buyer regardless of the difference between the (AIC) Capacity Agreement Contract Price and the MISO Compliance Zone Auction Clearing Price (“ACP”). Second, if the Compliance Zone ACP is greater than the Contract Price, we are required to pay the positive difference between the Contract Price and the Compliance Zone ACP multiplied by the days in the Planning Year and the number of ZRCs we fail to deliver.

First, if you fail to deliver all or a portion of the ZRCs which you are required to deliver to the Buyer’s account, then you are responsible for all penalties and/or charges assessed to the Buyer (either directly or through contractual obligation) resulting from such failure regardless of the difference between the Contract Price or the MISO Compliance Zone ACP. Second, you are correct that if the Compliance Zone ACP is greater than the Contract Price, then you are required to pay the positive difference obtained by subtracting the Contract Price from the Compliance Zone ACP multiplied by the days in the Planning Year and multiplying such positive amount by the quantity of ZRCs which you fail to deliver.

07-24-2017

FAQ-BE-38
Q: Is it possible that some of a Bidder’s Bids in the AIC Capacity procurement event are identified as “winning Bids” to the ICC, while others are not? For instance, if a Bidder submits Bids at the same price in $/MW-Day, is it the case that the Procurement Administrator accepts either all of the Bids or none of the Bids?

It is possible that only a portion of a Bidder’s Bids are accepted should the Bidder submit Bids for multiple ZRCs at the highest accepted price in order to exactly fill the ZRC Target for the Planning Year.

07-24-2017

FAQ-BE-39
Q: When should I expect to receive dial-in instructions for the July 26, 2017 Block Energy and Capacity RFP webcast?

Dial-in and WebEx login information will be provided early on the day of the webcast.

07-24-2017

FAQ-BE-40
Q: When should I expect to receive login credentials to access the Block Energy and Capacity RFP Part 1 Form?

Your username and password, as well as instructions for completing the Part 1 Form, will be provided after the July 26, 2017 BEC webcast.

07-24-2017

FAQ-BE-41
Q: For the Ameren Illinois Company (“AIC”) Capacity procurement event, does the full amount of performance assurance required at contract signing remain in place for the full duration of the contract? When would the letter of credit posted as performance assurance expire?

In responding to this question, we assume that Seller is not a counterparty to another supply contract with AIC besides the (AIC) Capacity Agreement. Upon execution of the contract, performance assurance to cover 10% of the contract value (i.e., 10% x contract price x ZRCs x 365 days) will be required.

(a)        If all ZRCs under contract are from the compliance zone, then upon AIC confirming the transfer of all ZRCs to AIC’s account, the exposure will be reduced to zero and the performance assurance may be returned at that point.

(b)        If all or a portion of the ZRCs under contract include ZRCs from outside of the compliance zone, then for that portion of the contract that is associated with ZRCs outside of the compliance zone, AIC will retain 10% of the contract value (regardless of whether such non-compliance zone ZRCs have been transferred or not) until the conclusion of the posting of MISO Planning Resource Auction (“PRA”) results. After the MISO PRA results are provided: (i) if it is determined that Seller does not owe Buyer payments, then performance assurance may be returned at that point; and (ii) if it is determined that Seller owes Buyer payments, then performance assurance for an amount equal to the amount owed will be required at that point and the performance assurance will be fully returned with the last payment by Seller.

If Seller is providing a letter of credit as performance assurance, then the letter of credit must remain valid for the duration for which performance assurance is required, which could be through June 30, 2019. Seller is responsible for providing an amendment to extend the validity of any letters of credit as necessary.

07-25-2017

FAQ-BE-42
Q: We are relying on our own financial standing for purposes of the Part 1 Proposal and are not required to file an SEC Form 10-Q. We do, however, produce our own quarterly financial statements. Where can I find the requirements for financial attestation to indicate that the quarterly information submitted fairly presents in all material respects the financial condition and results of the operations of the Entity on whose financial standing the Bidder relies?

The requirements for financial attestation can be found in Appendix 9 to the BEC RFP Rules posted to the Final Materials page of the procurement website under the “Final Fall 2017 Block Energy and Capacity RFP Documents” heading.

07-27-2017

FAQ-BE-43
Q: Where can I find a list of acceptable modifications to the Standard Pre-Bid Letters of Credit?

Preliminary lists of acceptable modifications to the Standard Pre-Bid Letters of Credit are posted to the Final Materials page of the Fall Block Energy and Capacity section of the procurement website under the heading “Final Fall 2017 Block Energy and Capacity RFP Documents”.

07-31-2017

FAQ-BE-44
Q: What is the process that a Bidder should follow if the information submitted in the Part 1 Proposal changes?

Regardless of the reason, if any information provided in the Part 1 Proposal changes or any previous certification fails to remain valid, it is the sole responsibility of the Bidder to notify the Procurement Administrator. Failing to do so may result in disqualification of the Bidder and of its Proposal. The Procurement Administrator reserves the right to change the assessment of qualifications based on any revised information provided by the Bidder.

07-31-2017

FAQ-BE-45
Q: If the name of the entity that submitted the Part 1 Proposal changes at the time of the Part 2 Proposal, what documentation should we provide to the Procurement Administrator?

We assume that you are referring to a change in name only and not a change to the corporate structure of the entity that submits the Part 1 Proposal. If there is a change in the corporate structure, through a merger for example, and the new entity is no longer the same as the entity that submitted the Part 1 Proposal, then such entity will not be able to continue its participation in the RFP. If this is a change in name only and not a change to the corporate structure of the entity, you will be required to provide documentation of the name change and to provide any information required by the Procurement Administrator to establish that there is no change in corporate structure.

07-31-2017

FAQ-BE-46
Q: Can we use any financial institution to issue the letter of credit or are there specific requirements that such financial institution must meet?

For the Pre-Bid Letter of Credit, the financial institution is a bank that satisfies the credit ratings provided in Paragraph 14. The issuing bank must certify that, as of the date of issuance of the Pre-Bid Letter of Credit, its senior unsecured debt is rated “A” or better by S&P Global Ratings (“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. Furthermore, the issuing bank must certify that its senior unsecured debt is rated by at least two of S&P, Moody’s, and Fitch. The requirements for a financial institution issuing the Post-Bid Letter of Credit appended to each applicable supplier contract are the same and are also stated as part of its terms.

07-31-2017

FAQ-BE-47
Q: Can a Bidder post cash instead of providing a Pre-Bid Letter of Credit for any of the procurement events under the Fall Block Energy and Capacity RFP?

No. With the Part 2 Proposal, a Bidder must submit an executed Pre-Bid Letter of Credit for each procurement event in which it intends to submit Bids.  You must either use the Standard Pre-Bid Letter of Credit for that procurement event in question provided as an appendix to the RFP Rules or you must incorporate only those modifications approved by the Company and posted to the procurement website.

07-31-2017

FAQ-BE-48
Q: Where can I find each applicable supplier contract?

Each applicable supplier contract is posted to the Final Materials page of the Fall Block Energy and Capacity section of the procurement website. These documents are dated July 24, 2017.

07-31-2017

FAQ-BE-49
Q: Where are the presentation materials from the July 26, 2017 webcast posted?

The Procurement Administrator has posted the presentation materials and the audio recording from the bidder information webcast held July 26, 2017 to the Final Materials page of the Fall Block Energy and Capacity section of the procurement website.

07-31-2017

FAQ-BE-50
Q: I understand that Bidders in the AIC Capacity procurement event must submit their Pre-Bid Letters of Credit by August 21, 2017 (instead of by the Part 2 Date of August 16, 2017). What are Bidders in the AIC Capacity procurement event required to submit by the Part 2 Date, if anything?

By noon (CPT) on the Part 2 Date, a Bidder participating in the AIC Capacity procurement event is required to submit all information required by the Part 2 Form as well as Inserts and documents required to support the Part 2 Proposal.

07-31-2017

FAQ-BE-51
Q: What is the required amount for the Pre-Bid Letter of Credit for the AIC Capacity procurement event? Is it $200,000 or $300,000?

The Pre-Bid Letter of Credit for the AIC Capacity procurement event must be $200,000 (regardless of the amount you intend to bid).

07-31-2017

FAQ-BE-52
Q: I understand that 10% of the contract value is due upon signing the AIC Capacity Agreement. Can the $200,000 Pre-Bid Letter of Credit be used for that purpose or are they two separate requirements?

The two requirements are separate. Each Bidder participating in the AIC Capacity procurement event is required to submit a Pre-Bid Letter of Credit in an amount of $200,000 to support its Bids. This Pre-Bid Letter of Credit will expire as part of its terms after contract execution and payment of the supplier fees. This Pre-Bid Letter of Credit cannot be used to meet the performance assurance under the terms of the AIC Capacity Agreement. The performance assurance is 10% of contract price x ZRCs won x 365 days.

07-31-2017

FAQ-BE-53
Q: Can a Bidder that is not relying on the financial standing of a guarantor and that is not rated by any of the rating agencies become a Seller under the terms of the AIC Capacity Agreement?

Yes. An entity that is not rated by S&P Global Ratings, Moody’s Investors Service, or Fitch Ratings may become a Seller under the (AIC) Capacity Agreement.  However, such an entity will not receive any unsecured credit under the terms of the (AIC) Capacity Agreement.

07-31-2017

FAQ-BE-54
Q: Do we need to fill out the fields for Scheduling in the AIC Capacity Contract Insert (also labelled INSERT #P1-9). I do not see that this information is required in the (AIC) Capacity Agreement itself.

Thank you for bringing this to our attention. This information is superfluous and you may leave these fields blank or insert “N/A”.

07-31-2017

FAQ-BE-55
Q: Can we provide the name of the financial institution that will issue our Pre-Bid Letters of Credit for purposes of verifying that the financial institution is acceptable to all the Companies?

Generally you should be able to determine yourself or the financial institution should be able to determine whether the financial institution will be acceptable to the Companies. The issuing bank must certify that, as of the date of issuance of the Pre-Bid Letter of Credit, its senior unsecured debt is rated “A” or better by S&P Global Ratings (“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. Furthermore, the issuing bank must certify that its senior unsecured debt is rated by at least two of S&P, Moody’s, and Fitch.

If for some reason you and the issuing bank cannot make this determination, please submit a question through the Ask a Question page.

07-31-2017

FAQ-BE-56
Q: Where do I find the SEC Form 10-Q?

Securities and Exchange Commission (“SEC”) Form 10-Q is a quarterly report that the SEC requires be filed by publicly traded corporations. The requirements for SEC Form 10-Q, including its submission, may be found here: https://www.sec.gov/files/form10-q.pdf.

As part of the Part 1 Proposal, Bidders are required to provide financial information for the Entity on whose financial standing a Bidder relies, including quarterly financial information. If available, the SEC Form 10-Q should be submitted to fulfil this requirement. If the SEC Form 10-Q is unavailable, the most recent quarterly or monthly financial data must be accompanied by an attestation by an officer of the Entity that the information submitted fairly presents in all material respects the financial condition and results of the operations of the Entity. The requirements for this attestation are more specifically provided in the Appendix of the RFP Rules prepared for this purpose. If the SEC Form 10-Q is unavailable, the Bidder must also either provide a review report from an independent accountant for the most recent quarterly or monthly financial data submitted or state that such a report is not available.

07-31-2017

FAQ-BE-57
Q: Where can I find the banking information needed to complete Paragraph 7 of the Standard Pre-Bid Letters of Credit?

Please send an email to Illinois-RFP@nera.com requesting the banking information. In your email, please specify which utility you would like to receive the banking information for.

08-01-2017

FAQ-BE-58
Q: Can we change the Issuing Bank for the letters of credit after submitting initial documents?

This answer is given in two parts and pertains to the Standard Pre-Bid Letters of Credit and the Standard Post-Bid Letters of Credit separately.

Once your Pre-Bid Letter of Credit for a Company has been found acceptable and once the deadline for submission of the Pre-Bid Letter of Credit has passed, there is neither an opportunity nor a process for changing the Issuing Bank.  The Pre-Bid Letter of Credit will not have expired and the cancellation of the Letter of Credit would require the affirmative action of the Company.

You may change the Issuing Bank for the Standard Post-Bid Letters of Credit as long as you provide notice to the Company for which you have executed a supplier contract. The replacement Letter of Credit is subject to acceptance by the company.  You must use one of the two standard options posted to the Final Materials page of the Fall Block Energy and Capacity section of the procurement website should you choose to change the Issuing Bank for the Standard Post Bid Letter of Credit.

08-01-2017

FAQ-BE-59
Q: Where can I find the final block and ZRC targets for the Fall 2017 Block Energy and Capacity RFP?

Final block and ZRC targets are posted to the Final Materials page of the Fall Block Energy and Capacity section of the procurement website.

08-01-2017

FAQ-BE-60
Q: Can you confirm the docket number in the definition of “Procurement Event” in the Standard Pre-Bid Letters of Credit as well as the mention of June 2017 given that the supply period for the Fall BEC RFP begins in October 2017?

The definition is correct.  The docket number can be found in the ICC Final Order here:

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

The “period starting June 2017” refers to the Procurement Plan and not to specific procurement events.

08-01-2017

FAQ-BE-61
Q: Can we provide comments on the Standard Post-Bid Letter of Credit for the (AIC) Capacity Agreement during the Part 2 Window?

No. Comments will not be solicited on the Standard Post-Bid Letter of Credit for the (AIC) Capacity Agreement during the Fall 2017 Block Energy and Capacity RFP, including during the Part 2 Window.

08-02-2017

FAQ-BE-62
Q: A Company did not accept one of our proposed modifications to the Standard Pre-Bid Letter of Credit. Is there a process for reconsideration?

No.  The Company’s response to your proposed modifications is final.

08-02-2017

FAQ-BE-63
Q: We have multiple guaranties in place with ComEd. Can we consolidate our multiple guaranties into a single guaranty?

Yes, this is possible. You may request this of ComEd during the contract execution process after the approval of the results by the Illinois Commerce Commission.

08-02-2017

FAQ-BE-64
Q: If we are a current supplier to a Company and we have winning bids in a procurement event again this year, will we be required to execute a new Agreement or will we simply be executing a Confirmation under our existing Agreement? Additionally, can we net credit exposures to a Company?

First, if you are a winning bidder in this Fall 2017 BEC RFP, you must execute a new applicable supplier contract(s) regardless of whether you are a winning supplier or not from a prior procurement event. Generally, netting of credit exposures and a shared unsecured credit line across each utility’s supplier contracts is envisaged.

08-02-2017

FAQ-BE-65
Q: Can you provide contact information for the Companies regarding contract execution?

Contact information for the Companies will be provided at the time of contract execution.

08-02-2017

FAQ-BE-66
Q: Where should the Pre-Bid Letters of Credit be sent?

Please see Paragraphs V.2.3, V.3.3, V.4.3, and V.5.2 of the RFP Rules for the Fall 2017 procurement events for the information needed to deliver the Pre-Bid Letters of Credit to the utilities.

08-03-2017

FAQ-BE-67
Q: Can you provide a list of banks that are able issue a Pre-Bid Letter of Credit for a Company on our behalf?

It is the sole responsibility of the Bidder to find an Issuing Bank that meets the requirements of the Pre-Bid Letters of Credit for the BEC RFP and that is able to issue a Pre-Bid Letter of Credit on the Bidder’s behalf.

The Procurement Administrator regrets not being able to provide further assistance in this regard.

08-08-2017

FAQ-BE-68
Q: How does netting of credit exposures across each utility’s supplier contracts get memorialized? Does the IPA leverage a cross master netting agreement across the utilities?

First, the IPA is not a party to the contracts. Each applicable supplier contract is administered by the applicable utility. The netting of credit exposure is memorialized in the calculation of the exposure amounts as well as a single share unsecured credit line provided by the utility to each credit support provider. Each utility also allows for a single guaranty to be provided by seller to cover the exposure across all applicable supply contracts with that utility.

08-09-2017

FAQ-BE-69
Q: If we are a supplier under both the Spring 2017 Block Energy/Standard Products RFP and the Fall 2017 Block Energy and Capacity RFP, are we required to send separate invoices, one for each contract or is an aggregated invoice permissible? Additionally, should we schedule volume from each solicitation separately or is one aggregated schedule preferred?

It is the Procurement Administrator’s understanding that scheduling and invoicing requirements are provided for each contract separately, and the Procurement Administrator is unaware if there are exceptions made to accommodate an aggregate schedule or invoice across supplier contracts with a given utility.

08-09-2017

FAQ-BE-70
Q: What should we put as the Date of Issuance for the Pre-Bid Letter of Credit?

The Date of Issuance of the Pre-Bid Letter of Credit should be the date on which the bank actually issues your Pre-Bid Letter of Credit.

08-10-2017

FAQ-BE-71
Q: Can I propose modifications to the Standard Pre-Bid Letters of Credit after the Part 1 Date?

No. The deadline to provide comments being solicited by the Procurement Administrator on the Standard Pre-Bid Letters of Credit is the Part 1 Date.

The Pre-Bid Letter of Credit submitted for a Company in response to the BEC 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 modifications you seek are in the list of modifications posted in the document with the title that begins “Acceptable Modifications” and that is posted directly underneath the Standard Pre-Bid Letter of Credit for each Company.

08-10-2017

FAQ-BE-72
Q: Is Bidder Training mandatory?

Bidder Training is not mandatory. However, Bidder Training is a good way for Bidders to practice all aspects of the bid submission procedure to be used on the Bid Date as well as to ask the Procurement Administrator questions regarding the completion and encryption of the Bid Forms.

08-11-2017

FAQ-BE-73
Q: Are we required to submit the Part 2 Form if all certifications required by the Part 2 Proposal for the Officer of the Bidder were submitted for early processing with the Part 1 Proposal?

A Bidder is required to log in to the online Part 2 Form and submit a Part 2 Proposal by the Part 2 Date, even when the certifications of the Officer of the Bidder were submitted for early processing with the Part 1 Proposal.  The Part 2 Proposal has a number of additional requirements and compliance with such requirements can only be provided through completion of the online Part 2 Form.

08-11-2017

FAQ-BE-74
Q: Are there penalties under the (AIC) Capacity Agreement if a Seller fails to deliver ZRCs, but the shortfall is procured in the MISO PRA? For example, say a Bidder wins 50 ZRCs and delivers to AIC 45 ZRCs. Would the 5 ZRC shortfall thus be procured in the MISO PRA? If the MISO PRA clears below the Seller’s contract price, would the Seller owe AIC any additional penalties and charges other than lost performance assurance?

AIC does not expect to purchase replacement ZRCs from another party for submission to MISO prior to the FRAP submission deadline. To meet its requirements, AIC will acquire any additional ZRCs from the MISO PRA. As such, it could be that there are no penalties or charges related to number of ZRCs that the Seller fails to deliver besides any payment due to AIC from the Seller based on the positive difference between the contract price and the compliance zone ACP as specified under the (AIC) Capacity Agreement. However, should there be any penalties or charges related to your failure to deliver the ZRCs, these penalties or charges will be the responsibility of Seller.

08-14-2017

FAQ-BE-75
Q: Which version of Microsoft Excel was used to create the Bid Forms? We want to ensure that we do not have issues with our bid submission on the Bid Date.

Microsoft Excel 2010 was used to create the Bid Forms. You may wish to practice the submission of your Bid Forms during Bidder Training on August 17, 2017. Bidder Training is a good way for Bidders to practice all aspects of the bid submission procedure to be used on the Bid Date as well as to ask the Procurement Administrator questions regarding the completion and encryption of the Bid Forms.

08-16-2017

FAQ-BE-76
Q: What are the Supplier Fees for the Fall 2017 Block Energy and Capacity RFP?

The Supplier Fees are as follows:

$ 164 per off-peak block

$ 246 per on-peak block

$ 60 per ZRC

08-16-2017

FAQ-BE-77
Q: If we win in the upcoming RFP and have an existing Master Agreement in place with ComEd, can we assign trades from the existing Master Agreement to the newly executed Master Agreement?

No. If you are a winning bidder in the procurement event related to block energy for the ComEd portfolio, you will be required to sign the (ComEd) Master Agreement issued for this procurement event.

08-17-2017

FAQ-BE-78
Q: If we win in the upcoming RFP and have an existing Master Agreement in place with ComEd, will ComEd consider a master netting agreement across the new Master Agreement and the Master Agreement already in place?

As indicated in the Section 10.10 of the (ComEd) Master Agreement, as modified in the Coversheet, the Agreement constitutes a “master netting agreement” within the meaning of the Bankruptcy Code.

08-17-2017

FAQ-BE-79
Q: Should we expect a single margin process for netting exposure across all (ComEd) Master Agreements if we have multiple agreements in place with ComEd?

It is the Procurement Administrator’s understanding that each of the (ComEd) Master Agreements will be administered separately such that margining under each contract will be separate. However, there will be a single shared unsecured credit line across the agreements provided by ComEd to the credit support provider.

08-17-2017

FAQ-BE-80
Q: Can we propose modifications to the Standard Post-Bid Letters of Credit?

The Companies are not accepting modifications to the Standard Post-Bid Letters of Credit. Each utility has two options for the Standard Post-Bid Letter of Credit that you may use. Alternatively, you may provide cash as Performance Assurance under the agreements. Any cash held by the Companies will be held at a 0% interest rate and all fees associated with the use of cash as Performance Assurance are to be borne by the Supplier.

08-18-2017

FAQ-BE-81
Q: What is the process for executing the (ComEd) Master Agreement?

First, please note that the contract execution formalities will occur only after the ICC approves the ComEd procurement event results.

The Contract and Confirmation execution process and timeline is described in Section 2.3 of the (ComEd) Master Agreement as modified in the Coversheet. ComEd will prepare all of the necessary contract documents for the Bidder’s execution per the timeline specified.

It is expected that ComEd will provide, for each Month and Segment, the weighted average winning bid price and quantity information in a single confirmation. A sample Confirmation is available on the procurement website.

08-22-2017

FAQ-BE-82
Q: We are an existing supplier and have a question regarding a contract we have in place with a Company. Can you provide contact information for that Company?

Please contact the Procurement Administrator via email at Illinois-RFP@nera.com. In your email, please specify which Company you seek contact information for and we will provide you information for the relevant individual.

08-23-2017

FAQ-BE-83
Q: The Officer of the Bidder that we plan to have sign the contracts is travelling during the planned contract execution period. We have two questions: 1. Is it possible to receive the contracts from the Companies prior to the Illinois Commerce Commission (“ICC”) decision on the results of the procurement events? 2. If not, can we provide scanned copies of the signature pages of the contracts to the Companies?

  1. No, it is not possible to receive the contracts from the Companies prior to the ICC decision on the results of the procurement events.
  2. The Companies do not require signatures in hard copy and will accept scanned documents. It is expected that, if a Bidder has Bids for a procurement event that are approved by the ICC, the Officer of the Bidder named in the Part 1 Proposal would sign the applicable supplier contract. Should the Officer of the Bidder not be available to sign for this purpose, the Bidder will advise the applicable Company of this fact. The Bidder will name another individual to sign and the Bidder will confirm that this individual is empowered to undertake contracts and bind the Bidder.
08-24-2017

FAQ-BE-84
Q: Can you please provide me with instructions for posting Performance Assurance under the (AIC) Capacity Agreement?

First, please note that the contract execution formalities, including the posting of Performance Assurance, will occur only after the ICC approves the AIC Capacity procurement event results.

AIC will prepare all of the necessary contract documents for the Bidder’s execution once the ICC approves the results. The Bidder then has three (3) business days to execute and meet the creditworthiness requirements of the (AIC) Capacity Agreement once it has been notified that the ICC approved the Bidder’s winning bids. The requirements for posting, transferring, holding and using Performance Assurance are set forth in Attachment A of the (AIC) Capacity Agreement.

Additionally, you may ask the individual from AIC who provides you with the contract documents questions at the time of contract execution.

08-29-2017


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

FAQ-DG-117
Q: My understanding is that the Utility DG RFP had a total budget of $46,538,119 (over 5 years), and intended to procure 27,702 RECs per year. Will the RECs procured in the Spring DG procurement event be subtracted from these totals in determining the Target and Budget for the Fall DG procurement event? Are those figures available now?

The DG procurement events for 2017 (both Spring and Fall) had a preliminary Overall Budget of $46,538,119 which spans the five years of the contract. The DG procurement events had a preliminary Overall Target of 27,702 RECs on an annual basis. Of the overall Target of 27,702 RECs, a Spring Target of 19,549 RECs was established, all of which were procured in the Spring Utility DG procurement event.

The number of RECs procured in the Spring DG procurement event and the budget associated with these RECs will be subtracted from the Overall Target and Budget. However, the Overall Target and Budget are subject to revision.  The Target and Budget applicable to the Fall Utility DG procurement event will be announced in the coming weeks.  If you have not done so already, please register to receive our announcements.

07-06-2017

FAQ-DG-118
Q: Would it be possible for a winning bidder in the Spring Utility DG RFP to use the letter of credit it holds with the IPA for purposes of providing the financial guarantees that are required in the Fall Utility DG RFP? What amendment would be required in that case?

Thank you for your comment, which we will incorporate as we finalize the Fall 2017 DG RFP. A Bidder that already holds a letter of credit with the IPA that was submitted under the Spring Utility DG RFP will be able to use this same letter of credit for purposes of providing the financial guarantees required by the Part 2 Proposal under the Fall Utility DG RFP.  Such Bidder will be required to provide an amendment to increase the value of the letter of credit and to change the expiration date.  Detailed instructions will be available from the Procurement Administrator prior to the Part 2 Window.

07-25-2017

FAQ-DG-119
Q: Did the Procurement Administrator make the early information release for the DG RFP?

The Early Information Release for the DG RFP was posted on July 28, 2017 to the Draft Documents page of the procurement website.

08-02-2017

FAQ-DG-120
Q: Does the 2 MW (AC rating) limit apply per building, per account, or per meter? Is it possible to present multiple systems that are in close proximity?

Any individual system presented as part of a Proposal for the Utility DG RFP (“DG RGP”) is limited in size to 2,000 kW nameplate capacity (AC rating).  An individual system is defined by its own separate revenue quality meter and its own identifier in the applicable tracking system (GATS or M-RETS).  Thus, it is possible to present multiple systems that are in close proximity as long as each system has its own revenue quality meter and is separately identified in the applicable tracking system.  Furthermore, any system in this procurement event 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.

08-18-2017

FAQ-DG-121
Q: What was the list of winning suppliers in the Spring 2017 Utility DG procurement event? How can I find the list of winning suppliers for previous DG procurement events?

The list of winning suppliers for the Spring 2017 Utility DG procurement event is as follows:  Ameresco Inc.; Carbon Solutions Group LLC; IL-Solar, Inc; SoCore Installation Services LLC; Solar Star Illinois I, LLC; and SRECTrade, Inc.

Generally, the list of winning suppliers is provided as part of an information release following the Commission decision on the procurement event.  To access these information releases, please go to the procurement website, https://www.ipa-energyrfp.com/, click on “Previous RFPs” in the left-hand navigation bar, then click on the procurement event that interests you.  There were some distributed generation RFPs prior to 2017.  Once on the page of the procurement event of interest, there will be an “RFP Results” heading under which you can find the information release.

08-18-2017

FAQ-DG-122
Q: I am reading the documents and I am seeing various references to systems below 25 kW. Must all systems that we present in the DG RFP be below 25 kW or is there some kind of priority given to smaller systems?

No, systems 25 kW or over can be presented in Proposals for the DG RFP. The limit on the size of a system is a nameplate capacity of 2,000 kW (AC rating).

There are references to systems under 25 kW because there are two (2) “Products” in the DG RFP, each defined by the “Size Class” of the system that generates the RECs. Systems in the “Small Size Class” are systems under 25 kW in nameplate capacity (AC rating). The “Small Size Product” consists of RECs generated from systems in the Small Size Class.  Systems in the “Large Size Class” are systems of at least 25 kW but no more than 2,000 kW in nameplate capacity (AC rating).  The “Large Size Product” consists of RECs generated from systems in the Large Size Class.

To the extent possible, 50% of RECs procured will come from the Small Size Product.

08-18-2017

FAQ-DG-123
Q: Is there a maximum on the number of RECs that a Bidder can bid through the DG RFP?

Yes. There is an “Overall Target” for the procurement event of 8,153 RECs (annually). This “Overall Target” is the sum of a Target for AIC of 1,614 RECs and a Target for ComEd of 6,539 RECs. A 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. Similarly, for the Small Size Class (systems below 25 kW), a Bidder can present systems and a forecast quantity that together produce an annual quantity of RECs up to and including the Overall Target. (A Bidder can bid both up to the Overall Target for the Large Size Class and for the Small Size Class).

08-18-2017

FAQ-DG-124
Q: Are the quantities for future procurement events under the Utility Distributed Generation RFP known at this time? Is it known how many procurement events there will be?

The Illinois Power Agency expects to release a draft Long-Term Renewable Resources Procurement Plan in September 2017, which will be subject to review by the Illinois Commerce Commission. Information about future procurement events under the DG RFP will become available after such review has concluded.

08-18-2017

FAQ-DG-125
Q: Are the final capacity factors available?

The final capacity factors are available in the Parameter and Process Information Release posted to the Final Materials page of the Fall Utility DG section of the procurement website.

08-21-2017

FAQ-DG-126
Q: Has the amount of the Supplier Fee been released?

The Procurement Administrator has released early an estimate of the Supplier Fee, which is $7/REC. The Procurement Administrator does not expect to be able to provide an update to this estimate prior to the submission of the Part 1 Proposals. The exact amount of the Supplier Fee per REC will be announced no later than two (2) business days before the Bid Date.

08-21-2017

FAQ-DG-127
Q: What is the amount of the letter of credit that will be required? Does it depend on the level of the Supplier Fee?

The amount of the Letter of Credit is completely unrelated to the supplier fees. Each Bidder will be required to submit a Letter of Credit in an 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. A Bidder that already holds a letter of credit with the IPA will have the option to provide an amendment to this letter of credit to increase the value of the letter of credit and to change the expiration date instead of having a new letter of credit issued for purposes of providing the financial guarantees required by the Part 2 Proposal.  The final Letter of Credit and initial list of acceptable modifications were posted to the procurement website on August 15, 2017.

08-21-2017

FAQ-DG-128
Q: How are the Annual Quantity and Maximum Contract Quantity calculated? When does rounding occur (when the Annual Quantity is calculated or when the Maximum Contract Quantity is calculated)?

The formula is described in the Parameter and Process Information Release posted to the Final Materials page of the Fall Utility DG section of the procurement website on August 15, 2017.

The Annual Quantity is calculated as the product of (a) the planned installed size of the system in kW divided by 1,000; and (b) the capacity factor associated with the technology of the system; and (c) 8760 hours. The result is rounded to the nearest REC. Thus, rounding occurs in the calculation of the Annual Quantity for a particular system.  The overall Maximum Contract Quantity over the entire term of the applicable supplier contract for a system is obtained by multiplying the Annual Quantity (already rounded to the nearest REC) by five (5) years.

08-21-2017

FAQ-DG-129
Q: How is the nameplate capacity (AC rating) for a system calculated?

The calculation is described in the Parameter and Process Information Release posted to the Final Materials page of the Fall Utility DG section of the procurement website on August 15, 2017. The nameplate capacity (AC rating) for a system is measured by summing the nameplate AC ratings of the project’s inverters.

08-21-2017

FAQ-DG-130
Q: Is the Host Acknowledgement Form required of new systems, existing systems or both? When is the Host Acknowledgment Form due?

The Host Acknowledgement is required only for the new systems and it is due by the Part 1 Date. If the document is not available at that time, the Bidder must justify this omission in the Part 1 Proposal. The Bidder will then be given more time to provide the document within the Part 2 Window. However, in no event will a Bidder be allowed to submit the Host Acknowledgment or to complete any other missing information regarding its systems after 12 PM (noon) CPT on the third business day prior to the Bid Date.

08-21-2017

FAQ-DG-131
Q: Can you clarify whether the total number of solar renewable energy credits (“SRECs”) that will be procured in the procurement event under the Fall 2017 DG RFP, which is 40,765, is an annual number of SRECs or a number of SRECs over the five-year term of the applicable supplier contract?

The annual target for the upcoming procurement event under the Fall 2017 DG RFP is 8,153 RECs. The total number of RECs to be procured over the five (5) year contract term is 40,765 RECs.

The target for the upcoming procurement event is an overall target for all technologies allowed under the DG RFP (solar thermal energy, photovoltaic cells and panels, wind, 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). There is no separate target for solar renewable energy credits.

08-21-2017

FAQ-DG-132
Q: I am about to have a 7kW array installed on my residence. Can I participate in the Adjustable Block Program and/or the procurement event under the Fall 2017 DG RFP?

Details regarding the adjustable block program are not available at this time. The adjustable block program 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 details of the program.

There is a procurement event planned for this Fall under the Distributed Generation RFP. However, there is a minimum bid size requirement of 1 MW. Small systems can participate through an aggregator.  The list of winning suppliers for the Spring 2017 Utility DG procurement event was:  Ameresco Inc.; Carbon Solutions Group LLC; IL-Solar, Inc; SoCore Installation Services LLC; Solar Star Illinois I, LLC; and SRECTrade, Inc. Generally, the list of winning suppliers is provided as part of an information release following the Commission decision on the procurement event.  To access these information releases, please go to the procurement website, https://www.ipa-energyrfp.com/, click on “Previous RFPs” in the left-hand navigation bar, then click on the procurement event that interests you.  There were some distributed generation RFPs prior to 2017.  Once on the page of the procurement event of interest, there will be an “RFP Results” heading under which you can find the information release.

The purpose of this website is to provide information to suppliers participating in the IPA’s procurement event. The Illinois Solar Energy Association has information for homeowners generally: http://www.illinoissolar.org/Procurement.

08-21-2017

FAQ-DG-133
Q: Can you confirm that the document provided in FAQ-DG-64 providing the standards for metering accuracy is still the correct document?

Yes, this is the correct document.

08-31-2017

FAQ-DG-134
Q: For purposes of qualifying a system into the DG RFP, can the system be connected to an electric cooperative?

There is a minimum bid size requirement of 1 MW and thus small systems participate in the Utility DG RFP through an aggregator. A distributed generation system must be interconnected at the distribution level of an electric utility, a municipal utility that owns or operates electric distribution facilities, or a rural electric cooperative as defined in the Public Utilities Act.

08-31-2017

FAQ-DG-135
Q: It is my understanding that if we are presenting a system that qualified in Spring 2017, all we have to do is to email the AC rating size of the system to the Procurement Administrator and to update the letter of credit. How do we update our bids?

We would like to clarify that while you will not have to provide information on the system characteristics anew or to resubmit documents regarding a system presented in the Spring 2017 DG RFP to the extent that all such information remains valid, you will still be required to present a Part 1 Proposal and a Part 2 Proposal that satisfy all the requirements of the Utility DG RFP, including presenting at least 1 MW of systems, making all certifications required, and presenting your bids in accordance with the instructions provided by the Procurement Administrator.  Full requirements will be available when the RFP is issued on September 7, 2017.

08-31-2017

FAQ-DG-136
Q: For the DG RFP, does a Bidder submit a single Proposal for all its Projects or is the Bidder required to submit a separate Proposal for each of its Projects?

Each Bidder submits a single Proposal in the DG RFP and through this Proposal the Bidder provides information about all of its Projects. There is a minimum bid size requirement: the Proposal must include systems that together are the equivalent to at least 1 MW (AC rating) in size.

09-12-2017

FAQ-DG-137
Q: Does each Bidder have a single set of login credentials to access all the online forms for the different RFPs or is there one set of login credentials for each RFP?

Generally Bidders are issued different login credentials to access the online forms for each RFP. If you participated in another RFP in 2017, please request new credentials for access to the online forms for the DG RFP.

09-12-2017

FAQ-DG-138
Q: What documentation can be provided by the Part 2 Date if such documentation is not available during the Part 1 Window?

In the Part 1 Proposal, you are asked to provide all necessary documentation regarding the characteristics of a Project. To the extent that the following documentation is not available during the Part 1 Window:

  • Documentation to demonstrate that the Bidder has ownership or title to the RECs, such as Letters of Intent, for new and existing systems for which the Bidder is not the System Owner;
  • Documentation to demonstrate that the system was energized and registered in GATS or M-RETS as of September 18, 2017 for existing systems;
  • Documentation by which the Host acknowledges installation of the system on the Host’s premises for new systems for which the System Owner is not the Host.

Then the Bidder will be required to provide such documentation by the Part 2 Date.

09-12-2017

FAQ-DG-139
Q: We are providing documentation from GATS to show that a system is existing, i.e., energized and registered through GATS. The size on the GATS documentation is nameplate capacity (DC rating). Is the Bidder required to explain the discrepancy between the DC rating in the GATS documentation and the AC rating provided in the Worksheet Insert?

The Procurement Administrator acknowledges that the system size provided on GATS documentation provided with the Part 1 Proposal is based on nameplate capacity (DC rating) and will not be identical to the system size based on size (AC rating) in the Worksheet Insert (#P1-2). The Procurement Administrator does not require the Bidder to explain the difference between the DC rating and the AC rating.  However, the Procurement Administrator may ask for additional information if the DC and AC ratings do not appear consistent with each other, for example because the ratio of the DC to AC ratings is not consistent with industry norms, which may indicate an error in the AC rating or the documentation provided.

09-12-2017

FAQ-DG-140
Q: What is the total capacity procured in the Fall 2017 DG RFP?

The Overall Target for the Fall 2017 DG RFP is 8,153 RECs. This represents approximately 5.5 MW using the capacity factor for solar photovoltaic cells and panels (fixed mount), of which approximately 4.4 MW is for ComEd’s portfolio, and the rest for AIC’s . However, the actual capacity procured may differ from these figures as the Targets can be met by procuring RECs from various resources, with varying capacity factors.

09-18-2017

FAQ-DG-141
Q: A requirement of the DG RFP is that systems installed after June 1, 2017 be installed by “qualified persons.” Where is “qualified person” defined?

The term “qualified person” is defined by subsection (i) of Section 1-56 of the Illinois Power Act. It is the responsibility of the Bidder to review the requirements for the installation by qualified person in the Act.

09-18-2017

FAQ-DG-142
Q: What is the required minimum bid size?

The required minimum bid size is 1 MW (AC rating).

09-18-2017

FAQ-DG-143
Q: The Procurement Administrator converts the capacity of the system into an annual quantity of RECs. Does the Procurement Administrator use the AC or DC rating to make that calculation?

The size of the system (AC rating) is used in all calculations and references in the DG RFP.

09-18-2017

FAQ-DG-144
Q: Do the Bid Participation Fee and the Supplier Fees go towards covering the costs for the procurement event? When is the Letter of Credit required?

The Bid Participation Fee and the Supplier Fees are used to cover the costs of the procurement event. All Bidders must pay a Bid Participation Fee once during the year to participate in the IPA procurement events. The Supplier Fees are levied only on Bidders that have Bids approved by the ICC. Each Bidder is required to post a Letter of Credit with the Part 2 Proposal. This Letter of Credit serves as bid assurance collateral and also remains in place during the term of the applicable supplier contracts until all Forecast Quantities are converted into identified systems and all identified systems have delivered at least one REC.

09-18-2017

FAQ-DG-145
Q: After the term of the contract expires, who owns the RECs for the systems that were under contract? Can RECs from those systems be bid into other procurement events?

During and after the term of the applicable supplier contract, the Owner of the systems owns the RECs from the system. During the term of the applicable supplier contract, the Seller delivers and transfers the RECs to the Company or Companies in quantities sufficient to satisfy its obligations. After the term of the contract ends, the Owner of the system is free to avail itself of other opportunities to sell the RECs from the systems.

09-18-2017

FAQ-DG-146
Q: Will previously qualified Bidders be required to provide the P1-1 Representative Insert if it was provided in the last procurement event?

A Bidder that successfully completed the Part 1 Proposal for a prior procurement event under a Distributed Generation RFP is said to have “previously qualified”. A previously qualified Bidder must review the contact information for the Bidder and the representative of the Bidder and must update this information accordingly. All Bidders, whether previously qualified or not, will need to provide the Representative Insert (#P1-1) if such Bidder wishes to designate additional Representatives to be copied on all communications from the Procurement Administrator.

09-18-2017

FAQ-DG-147
Q: If we are amending a Letter of Credit that we currently have with the IPA, what should be the new expiration date?

The expiration date specified in the amendment should be 364 days or one year from the date of the issuance of the amendment.

09-18-2017

FAQ-DG-148
Q: We adopted an acceptable modification for the Letter of Credit that we currently have with the IPA and it is unclear to us how to modify the expiration date. Can you provide guidance on this issue?

We understand that the language in an existing Letter of Credit may be different across Bidders, as some Bidders may have elected to use an acceptable modification in the prior procurement event. Bidders can contact the Procurement Administrator for instructions related to the specific language of their Letter of Credit.

09-18-2017

FAQ-DG-149
Q: Should the bid assurance collateral be sent to the Companies (AIC and ComEd but not MEC)?

The bid assurance collateral must be in the form of a Letter of Credit with the IPA as beneficiary. Bid assurance collateral is NOT sent to the Companies that are purchasing through this procurement event. It is correct that AIC and ComEd but not MEC are purchasing RECs through this procurement event.

09-18-2017

FAQ-DG-150
Q: Is it possible to be a winner for a portion of a Block that we bid? If so, will the bidder be able to select the systems that would be under contract?

Yes, it is possible that a winning bid that is identified and approved by the ICC is for just a fraction or portion of the RECs bid in a Block. If this does happen, a Bidder will be asked to select the systems that will be part of the applicable supplier contract to the extent that the Bidder chooses to accept the partial award.

09-18-2017

FAQ-DG-151
Q: If production from the systems falls short of the contracted Annual REC quantity, does the contract extend into an additional year to provide an opportunity for the seller to make up the deliveries?

No, there is no opportunity to make up deliveries if the systems fail to deliver the contracted quantities. Please review the terms under each applicable supplier contract posted to the Final Materials page of the Fall Utility DG section of the IPA procurement website for additional information regarding consequences of being unable to deliver the annual quantity of RECs under each contract.

09-18-2017

FAQ-DG-152
Q: What is the relationship between the Fall DG RFP and the IPA’s long-term renewable plan?

The Fall 2017 DG RFP relates to the IPA’s Procurement Plan filed on September 27, 2016 and approved by the Illinois Commerce Commission in Docket No. 16-0453. Additional information regarding the long-term renewable plan will be posted to the IPA’s website as it becomes available. Please see:

https://www.illinois.gov/sites/ipa/Pages/Plans-Under-Development.aspx

09-26-2017

FAQ-DG-153
Q: How many RECs were procured in the Spring 2017 DG RFP?

19,549 RECs were procured in the Spring 2017 DG RFP. The complete results are available here:

https://www.ipa-energyrfp.com/2017-distributed-generation-rfp/

09-26-2017

FAQ-DG-154
Q: Where can I get information about the IPA’s procurement plans for 2018?

The information for the IPA’s procurement plans under development is posted here:

https://www.illinois.gov/sites/ipa/Pages/Plans-Under-Development.aspx

09-26-2017

FAQ-DG-155
Q: Is it correct that the Fall 2017 DG RFP will only procure RECs for AIC and ComEd and not for MEC?

Correct. The Fall 2017 DG RFP seeks to procure RECs for AIC and ComEd; RECs will not be procured for MEC in this procurement event.

09-26-2017

FAQ-DG-156
Q: Given that RECs will only be procured for AIC and ComEd through the Fall 2017 DG RFP, does it mean that Bidders only need to provide bid assurance collateral to these two Companies?

In the DG RFP, bid assurance collateral is provided to the IPA in the form of a Letter of Credit. Please refer to Article V of the RFP Rules.

09-26-2017

FAQ-DG-157
Q: Why is a 17% capacity factor used for solar (fixed mount) to calculate the expected REC production? Why isn’t 100% used?

The capacity factor is used to convert the size of the system in MW to the expected REC production. The capacity factor would only be 100% if a system were to produce at full capacity in every hour of the year.

09-26-2017

FAQ-DG-158
Q: Will the Procurement Administrator consider late proposals to the DG RFP?

No. No late proposals are considered for the DG RFP.

09-26-2017

FAQ-DG-159
Q: Is the original executed Letter of Credit due at the IPA’s office by 12PM (noon) CPT on Wednesday, October 4, 2017?

Yes.  A requirement of the Part 2 Proposal, which is due by noon (central) on Wednesday, October 4, 2017 (except for your bids), is to provide an original executed Letter of Credit in an amount sufficient to support your Bids.  If the Letter of Credit is not received by that time, your Part 2 Proposal will be automatically deficient. You will receive a deficiency notice from the Procurement Administrator that will include a deadline for curing such deficiency.  If such notice is your first deficiency notice regarding your Part 2 Proposal, you will have generally two (2) business days to provide the Letter of Credit.  Additional deficiency notices generally provide less time for providing additional information or curing deficiencies.

10-04-2017

FAQ-DG-160
Q: If a Bidder has no Bids that are approved by the Commission, when will the Letter of Credit be released?

If a Bidder has no Bids that are approved by the Commission, the Letter of Credit will be cancelled as soon as practicable after the Commission decision on the results of the procurement event. The ICC is expected to decide whether to accept or reject the results of the procurement event within four (4) business days of the Bid Date.  This response assumes that that Bidder is providing a new Letter of Credit for purposes of this procurement event and not an amendment to a Letter of Credit currently held by the IPA.

10-04-2017

FAQ-DG-161
Q: If a Bidder chooses not to bid all of the systems that were qualified through its Part 1 Proposal, is the Bidder still required to provide a Letter of Credit for the full amount in the notification from the Procurement Administrator?

No.  The Letter of Credit must be at least in an amount equal to $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. The Letter of Credit does not need to be in an amount sufficient to support all of the RECs from the systems qualified in the Part 1 Proposal, but it must support at least 1 MW worth of RECs.

10-04-2017

FAQ-DG-162
Q: If only some and not all of the Bidder’s Bids are identified as winning Bids, does the Letter of Credit stay in place as it is or is the Bidder required to provide a new Letter of Credit to reflect the number of RECs in the winning Bids?

If a Bidder has Bids that are identified as winning Bids, the Letter of Credit issued during the Part 2 Window 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 the Bidder has a winning bid on a Forecast Quantity so that some systems in the Small Size Class have not yet been identified.  After the Bidder pays the Supplier Fees, the Letter of Credit will be reduced on a prorated basis based upon the number of RECs in the winning Bids as soon as practicable.  During the supply period, at the end of each quarter, the Letter of Credit is further reduced as systems demonstrate that they have accumulated metered deliveries of renewable energy.  The Letter of Credit will be returned once its amount is reduced or drawn down to zero.

10-04-2017

FAQ-DG-163
Q: What are the consequences if one of our identified systems does not begin accumulating metered deliveries by the required deadline? Do amounts not spent because the systems failed get rolled over to the next DG procurement?

If a system that was identified does not begin accumulating deliveries by the required deadline and it is clear that the system will not be built, the Bidder will forfeit the collateral ($4 x the number of RECs associated with this system x 5 years) associated with the RECs from such system.  Furthermore, the maximum quantity of RECs that can be delivered under the contract will be reduced by the quantity of RECs associated with the project and the project will be removed from the contract.

The details of how budgets for future DG procurement event will be set are not yet available.  Please note that under the terms of the contract, if a system does not begin accumulating metered deliveries by the required deadline, an extension may be granted at the IPA’s sole discretion for limited circumstances such as demonstrated delays in a utility approving interconnection of a system, or failure by the PJM EIS GATS or M-RETS to process registration in a timely manner.

10-04-2017

FAQ-DG-164
Q: Is the data provided by the Procurement Administrator and posted to the procurement website the only data available regarding the results of the DG procurement events?

The data provided by the Procurement Administrator is the only data available regarding the results of the Spring DG procurement event.

10-04-2017

FAQ-DG-165
Q: What happens if a Bidder wins several Forecast Quantities at different prices?

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.  As you identify systems from your Forecast Quantities, the RECs associated with such systems become eligible for delivery under the applicable supplier contract.

10-04-2017

FAQ-DG-166
Q: If there are deficiencies to the Letter of Credit, is it sufficient to provide an electronic copy of the amendment?

An original hardcopy of the executed amendment is required. The amendment should be sent via overnight delivery service to the same address where the original Letter of Credit was sent. We appreciate but do not require that you provide a tracking number by email to Illinois-RFP@nera.com.

10-11-2017

The Letter of Credit is unrelated to the supplier fees.  If the ICC approves some or all of the Bidder’s Bids, the Bidder will have seven (7) business days after ICC approval to pay to the IPA the Supplier Fees associated with those winning Bids. The ICC decision is expected on Thursday, October 19, 2017.

The Supplier Fee for the Fall 2017 DG RFP is $7 per REC for the quantity of RECs associated with winning Bids across all Delivery Years. The Supplier Fee of $7 per REC is applicable to RECs associated with identified systems and forecast quantities.

10-13-2017

FAQ-DG-168
Q: Where can I find the final budgets from the Spring 2017 DG RFP?

The final budgets for the Spring 2017 DG RFP are available on the Announcements Page of the procurement website here:

https://www.ipa-energyrfp.com/2017/04/25/dg-rfp-announcement-final-spring-budgets-for-dg-rfp/

10-13-2017

FAQ-DG-169
Q: Can you please provide an example of the calculation of the payments to the supplier under the applicable supplier contracts, the amount of the Letter of Credit, and the amount paid by the supplier for the Supplier Fees? Please assume, strictly for purposes of this example: (i) a 250 kW solar system producing 372 RECs each and every year; and (ii) a bid price of $200.

The payment for the RECs under contract would be 372 RECs/year * $200/REC * 5 years = $372,000. The amount of the Letter of Credit would be 372 RECs/ year * $4/REC * 5 years = $7,440.  The amount of the Supplier Fees would be 372 RECs/year * $7/REC * 5 years = $13,020.

10-13-2017


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

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 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.

Revised 8-01-2017 first posted 6-09-2017

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-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-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-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-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-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-8
Q: Are replacement RECs allowed under the terms of the REC 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.

Revised 8-01-2017 first posted 6-09-2017

06-09-2017

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

Yes, a separate webcast was held to explain the RFP process and requirements. This webcast was held on July 19, 2017 after the final contract was posted.

Revised 8-1-2017 first posted 6-09-2017

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

The comment process ended on July 10, 2017.  During the comment process you could provide comments on the entire draft REC Contract.

Revised 8-01-2017 first posted 6-09-2017

06-09-2017

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.

Revised 8-1-2017 first posted 6-09-2017

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-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.

Revised 8-01-2017 first posted 6-09-2017

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-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-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-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.

Revised 8-1-2017 first posted 6-09-2017

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.

Revised 8-1-2017 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-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-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-29
Q: How long was the webcast on the draft REC contract on June 6, 2017 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.

Revised 8-01-2017 first posted 6-13-2017

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, was provided during the webcast on July 19.

Revised 8-01-2017 first posted 6-13-2017

06-13-2017

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-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-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-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-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-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-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-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-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-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-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-44
Q: Will the Letter of Credit to support the bid 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.

Revised 8-1-2017 first posted 6-25-2017

06-25-2017

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-47
Q: How does the Letter of Credit provided with the Part 2 Proposal convert into the Letter of Credit to meet the Collateral Requirement under the REC Contract?

The Letter of Credit provided with the Part 2 Proposal to support the bid will expire as part of its terms and does not convert to covering the Collateral Requirement during the term of the REC Contract.  If the bidder is a winning bidder in the RFP and uses a Letter of Credit to meet the Collateral Requirement during the term of the REC Contract, this Letter of Credit is a separate instrument that has different terms from the Letter of Credit provided with the Part 2 Proposal.

Revised 8-01-2017 first posted 6-28-2017

06-28-2017

FAQ-W&S-48
Q: Do bidders commit to a firm in-service date for a project? How is the start of the delivery term determined?

There is no commitment to a particular in-service date required of the bidder.  Please note, however, that the Date of First Operation of the Project cannot be on or before June 1, 2017 and that at least one REC must be delivered from the Project by June 1, 2021.  The delivery term under the REC Contract begins the later of June 1, 2019 and the date at which the first REC from the Project is issued by PJM EIS GATS or M-RETS.

Revised 8-01-2017 first posted 6-28-2017

06-28-2017

FAQ-W&S-52
Q: When was the call-in and WebEx login information for the webcast provided to registrants? Where are the materials posted?

The call-in and WebEx login information for the second webcast for the Wind & Solar RFP were provided to all webcast registrants early on June 28, 2017, the day of the webcast.  If you were unable to join the webcast, 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 28, 2017.

07-05-2017

FAQ-W&S-53
Q: If a bidder is a winning bidder in the RFP, but does not move forward to sign a REC contract with a Company, is the bid assurance collateral forfeited?

Yes. As a part of your Proposal, you will be required to certify, among other things, that you agree to sign the REC Contract within the required timeframe if your project is selected and approved by the Illinois Commerce Commission (“ICC”). Should you fail to execute the REC Contract, then your Bid Assurance Collateral would be forfeited.

07-05-2017

FAQ-W&S-54
Q: Projects will be evaluated based on if they “meet or beat the benchmarks”. What are these benchmarks? Is additional consideration given to those projects that beat the benchmarks, or do projects simply need to meet them and then each project will be evaluated on price alone?

The benchmarks and the process by which the benchmarks are developed are confidential under the Act.

Benchmarks are applied in the first step of the evaluation of bids. Bids that fail to meet or beat the benchmarks are eliminated.  The bids that remain are, within a resource category, evaluated on the basis of price alone.

Revised 8-01-2017 first posted 7-05-2017

07-05-2017

FAQ-W&S-55
Q: What does Part 1 Window mean?

The Proposal for a Project is submitted in two parts, with specific requirements for each part, and which are referred to as the Part 1 Proposal and the Part 2 Proposal.  The Part 1 Window refers to the time during which Bidders can provide materials to respond to the requirements of the Part 1 Proposal.  Under the revised schedule, the Part 1 Window will open on July 20 and close on August 7, 2017.

For more information about the specific requirements for the Part 1 Proposal, please review Article IV of the RFP Rules.

Revised 8-01-2017 first posted 7-05-2017

07-05-2017

FAQ-W&S-56
Q: Is it possible that a bidder will have to sign contracts with more than one utility for RECs from a single project?

Yes.  The Procurement Administrator will allocate to each utility the number of RECs that the winning bidder will deliver to that utility, with the same REC price for all utility contracts.  Winning bidders are not able to choose their counterparties to the REC Contract. Please note that for this procurement, the contract terms have largely been harmonized among the utilities.

07-05-2017

FAQ-W&S-59
Q: Can we submit a bid with an escalating REC pricing where the REC price for one Delivery Year is different than the REC price for prior Delivery Year?

No, bidders can only submit a flat price per REC so that the REC price is the same in every Delivery Year during the term of the REC Contract.

07-05-2017

FAQ-W&S-60
Q: We understand that the Collateral Requirements is 50% until June 1, 2019. If we build and begin operating before June 1, 2019, how would the Collateral Requirement change?

If a project is built and begins operation before June 1, 2019, the Collateral Requirement does not change.  The Collateral Requirement is only tied to the date certain of June 1, 2019. Upon contract execution, the Collateral Requirement is 50% of the Annual Contract Value.  The Collateral Requirement increases to 100% of the Annual Contract Value on June 1, 2019. The increase happens regardless of when the project becomes operational or when the first REC is delivered.

Revised 8-01-2017 first posted 7-05-2017

07-05-2017

FAQ-W&S-61
Q: Why can’t the failure to deliver the first REC by June 1, 2019 be excused by Force Majeure?

The requirement to deliver at least one (1) REC is not due by June 1, 2019, but by June 1, 2021, which is a date certain required by law (See Section 1-75(c)(1)(G) of the Illinois Power Agency Act). As envisioned under the statute, this leaves project developers with somewhere between three and four years from contract execution until the project is built, interconnected, and able to deliver its first REC.

07-05-2017

FAQ-W&S-62
Q: What is the purpose of the Collateral Requirement? Why is there a Collateral Requirement during the project’s operation when the project itself is an asset that is worth much more than the Collateral Requirement required under the REC Contract?

Collateral Requirements can have many purposes depending on the context and the Product that is traded.  One such purpose is to ensure that the Seller has an additional incentive to perform under the Contract even when conditions change and the Seller could potentially receive a higher price for the Product elsewhere in the market.

07-05-2017

FAQ-W&S-63
Q: Can you provide an example from another state with a comparable Collateral Requirement?

Southern California Edison Company’s 2014 REC RFP had a Collateral Requirement of up to 20% of the total contract value (over the entire term of the contract).  The Collateral Requirement of 100% of the Annual Contract Value in the REC Contract is equivalent to less than 7% of the total contract value.  In addition, Pennsylvania Power Company’s SPAEC RFP had a Collateral Requirement equivalent to 200% of the annual contract value.

Revised 7-21-2017 first posted 7-5-2017

07-05-2017

FAQ-W&S-64
Q: Is there a comment process for the preliminary proposal requirements?

There is no comment process on the Preliminary Proposal Requirements.  However, the “Ask a Question” page of the procurement website has a space for your question or comment.

07-05-2017

FAQ-W&S-65
Q: While changes to sec. 2.2 are appreciated, it remains unclear whether a contract that makes payment to seller contingent on the buyer’s cost recovery can be financed. Have you explored whether this revised section is financeable?

Yes. A similar provision was included in the IPA’s 2010 long-term procurement of renewable resources.  Furthermore, those contracts  (the 2010 LTPPAs)  included a provision under which the number of RECs purchased under the contract could be curtailed in case of insufficient budget, which could (and did) occur if load migrated from the utilities to alternative retail electric suppliers.  Similar provisions are used in REC contracts used by the utilities in the New England states such as by the Connecticut Light and Power Company and the United Illuminating Company as well as contracts used by the utilities in Pennsylvania such as PPL Electric Utilities Corporation, PECO Energy Company and Pennsylvania Power Company, and there may be other contracts with similar provisions of which the Procurement Administrator is unaware.

Revised 7-21-2017 first posted 7-5-2017

07-05-2017

FAQ-W&S-66
Q: The regulatorily continuing provision of the REC Contract will make it difficult to finance projects. Could this provision be changed?

While some changes have been made to these provisions from the initial draft contract to the final REC Contract, the general concept of a regulatorily continuing clause in the contract will not be changed.  From Public Act 099-0906 (“Act”), the objective of the initial forward procurements is the purchase of RECs to satisfy the Illinois Renewable Portfolio Standards over a period of 15 years.  To meet this objective, the RECs delivered by the Sellers must satisfy the Renewable Portfolio Standards as may be amended from time to time.  The Illinois Power Agency, as the Agency tasked with implementing the Renewable Portfolio Standards through the development of its Long-Term Renewable Resources Plan, will strive to ensure that any such changes are handled fairly and equitably and take into account the interests and needs of all relevant parties.

Revised 8-01-2017 first posted 7-05-2017

07-05-2017

FAQ-W&S-68
Q: Other than the deadline in which projects must deliver their first REC before June 2021, will suppliers be required to submit a date in which the first REC will be delivered, or can REC delivery start at any point between June 2019 and June 2021 with limited notice as to when the first REC is delivered?

Suppliers will not be required to submit a date at which the first REC will be delivered. However, suppliers do not have complete flexibility to start deliveries in the June 2019 to June 2021 window.  The Delivery Term under the terms of the REC Contract begins on the later of June 1, 2019 and the date at which the first REC is issued by PJM EIS GATS or M-RETS for the project regardless of when the initial date of REC delivery occurs. Once the Delivery Term starts, the supplier must comply with the delivery obligations under the REC Contract.

07-06-2017

This is a legal requirement from Public Act 099-0906, which states: “renewable energy credits shall not be eligible to be counted toward the renewable energy requirements […] if they are sourced from a generating unit whose costs were being recovered through rates regulated by this State or any other state or states on or after January 1, 2017. Each contract executed to purchase renewable energy credits under this subsection (c) shall provide for the contract’s termination if the costs of the generating unit supplying the renewable energy credits subsequently begin to be recovered through rates regulated by this State or any other state or states; and each contract shall further provide that, in that event, the supplier of the credits must return 110% of all payments received under the contract.”

07-06-2017

FAQ-W&S-70
Q: The Part 1 Proposal requirements include that the party signing the REC Contract (“Seller”) be identified. Would this requirement be satisfied by saying that the Seller will be a “Project company” to be formed in the future as a subsidiary of the parent company or do you require that the Project company be formed ahead of the Part 1 Proposal?

The Project company must be formed ahead of the Part 1 Proposal as the Seller must be identified in the Part 1 Proposal.

07-06-2017

FAQ-W&S-72
Q: Where can I find the dates of the main events for the Wind and Solar RFP now that a second round of comments on the REC Contract has been added?

The entire schedule has changed including the Bid Date, which will now be on August 31, 2017 (instead of August 10, 2017). Please consult the Wind and Solar Calendar posted to the Calendar page of the procurement website for the new dates.

07-11-2017

FAQ-W&S-73
Q: Are the “Pre-bid Letters of Credit” available for review?

The Pre-Bid Letters of Credit for the Wind and Solar RFP have been posted to the Final Materials page of the Wind and Solar Section of the procurement website on July 14, 2017.

07-14-2017

FAQ-W&S-74
Q: Prior procurement events have assumed a capacity factor of 14.38% when calculating RECs produced by a solar system. Is there a similar capacity factor associated with this event or are there no capacity factor assumptions?

There is no capacity factor pre-designated for the Wind and Solar RFP. A participant in the RFP will provide the annual quantity of RECs that the project will deliver under the terms of the REC Contract as part of its bid.

07-14-2017

FAQ-W&S-75
Q: The REC Contract states that the seller will be in default if “the project fails to meet the delivery year requirement 3 or more times AND the cumulative shortfall amount is greater than the annual quantity.” Does this mean, hypothetically and in an extreme case, that a project with an annual quantity obligation of 5,000 RECs could be short 300 RECs every year of the 15 year contract and still not be in default since the cumulative shortfall quantity of 300*15 = 4,500 RECs is less than the annual obligation of 5,000?

Yes, your understanding is correct.

Revised 8-01-2017 first posted 7-14-2017

07-14-2017

FAQ-W&S-76
Q: When will the amount of the Supplier Fees be announced? Can you provide details on how the Supplier Fees will be paid?

The Supplier Fees are levied only on bidders that have bids approved by the Illinois Commerce Commission (“ICC”). An estimate of the Supplier Fees, which will be in $/REC, will be provided during the webcast planned for July 19.  The timing of the announcement of the final Supplier Fee amount will also be provided at that time.

Instructions for payment of the Supplier Fee is typically provided to winning bidders only once the ICC renders a decision on the results of the procurement event.  Details are not available at this time.

07-14-2017

FAQ-W&S-77
Q: Is there further guidance at this time on the public interest criteria that a Project outside of Illinois must meet? What are the requirements in the Proposal if a Project is outside Illinois?

Please see FAQ-W&S-1. No further guidance on the public interest criteria is available at this time.

Revised 7-25-2017; first posted 7-20-2017.

07-20-2017

FAQ-W&S-78
Q: Can Projects from any state participate in the Wind and Solar RFP?

No. The project must be located in Illinois or a state adjacent to Illinois.

07-20-2017

FAQ-W&S-79
Q: What are the fees for participation in the Wind and Solar RFP?

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.

Additionally, there is a Supplier Fee, which is levied only on those participants that have bids approved by the Illinois Commerce Commission. 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 July 19.

07-20-2017

FAQ-W&S-80
Q: Is the Bid Assurance Collateral due on the Part 2 Date or on the Bid Date?

The Bid Assurance Collateral is due on the Part 2 Date, August 23, 2017.

07-20-2017

FAQ-W&S-81
Q: Is there a carve-out for brownfield site photovoltaic projects so that utility-scale solar projects and brownfield site photovoltaic projects are evaluated separately, each with its own Target?

No, there is no carve-out for brownfield site photovoltaic projects. There is a Target for each category (i.e., a Target for wind and a Target for solar) but there is no separate Target or maximum for brownfield site photovoltaic projects. All RECs from utility-scale solar projects and from brownfield site photovoltaic projects will be evaluated together.

The evaluation first eliminates the bids that fail to meet or beat the benchmarks. Second, bids are ranked in order of price per REC until the target for the category in this procurement event is met (on an annual basis) or until all bids have been ranked. The lowest priced projects thus selected are identified by the Procurement Administrator to the Commission as winning projects.

07-20-2017

FAQ-W&S-82
Q: Can a winning Project be located in ComEd’s service territory while the RECs from the Project are allocated to AIC and MEC? Can Projects be located in an electric cooperative’s territory?

A Project may be located in the territory of an electric cooperative in Illinois as defined in Section 3-119 of the Public Utilities Act. The Procurement Administrator will allocate the RECs among the utilities without regard to where the Project is located. As such, it is possible for AIC and MEC to receive RECs from a winning Project that is located in ComEd’s territory.

07-24-2017

FAQ-W&S-83
Q: Can the bid participation fee be paid online?

The bid participation fee cannot be paid through the application website that Bidders use to submit the Part 1 Proposal. However, payment of the bid participation fee can be made online through e-pay.  You may request a complete set of instructions from the Procurement Administrator via email at Illinois-RFP@nera.com.

07-24-2017

FAQ-W&S-84
Q: Is there a limit on the number of RECs that can be delivered on June 1, 2019? For example, if the Project is completed and starts generating RECs from June 1st 2018, can the Seller deliver an annual quantity of RECs on June 1, 2019?

There is no limit to the number of RECs that may be delivered on June 1, 2019. However, it would not be possible for the Project to deliver all RECs from the year prior to June 1, 2019 because RECs delivered under the REC Contract must be based on electricity generation that occurred no earlier than April 1, 2019.

07-24-2017

FAQ-W&S-85
Q: Will you be trying to meet the annual target of 200,000 RECs for solar projects exactly? For example, suppose the lowest priced Project has an annual quantity of 160,000 RECs, the second lowest priced Project has an annual quantity of 90,000 RECs, and the third lowest priced Project has an annual quantity of 40,000 RECs. Will the evaluation select the lowest priced and third lowest priced Projects in order to achieve the annual target of 200,000 RECs? Or is it the case instead that it is possible that only a portion of the annual quantity for a Project will be taken as a winning Bid?

Projects of a given type (wind or solar) will be selected on the basis of price. In the example you provide, the lowest and the second lowest priced projects would be selected. The second lowest priced project would win only a portion of the RECs bid (40,000 of the 90,000 RECs).  If the results are approved by the Commission, the Bidder would have the option to accept or reject the partial award.

07-24-2017

FAQ-W&S-86
Q: Is it the case that if a Project meets all the requirements of the Part 1 Proposal, it is guaranteed to be invited to submit a Part 2 Proposal? Or is it the case instead that there will be a selection made from among the Projects that satisfy the Part 1 Proposal requirements such that only those that demonstrate the greatest benefits are invited to submit a Part 2 Proposal?

Projects from all submissions that meet the qualification standards of the Part 1 Proposal will be invited to submit a Part 2 Proposal. Please note that the requirements of the Part 1 Proposal are not only requirements regarding the Project.  The Part 1 Proposal also requires providing information about the Seller and requires specific representations by the Seller.  Please see Article IV of the RFP Rules.

07-24-2017

FAQ-W&S-87
Q: Can a Bidder offer RECs without a specific Project associated with those RECs?

No. The RECs bid into the Wind and Solar RFP and purchased through the REC Contract are associated with a specific Project.  Providing specific information about the Project is a requirement of the Part 1 Proposal of the Wind and Solar RFP.

07-24-2017

FAQ-W&S-88
Q: Are the presentation and recording from the July 19 webcast available on the procurement website?

The webcast presentation and recording are posted to the Final Materials page of the Wind and Solar section of the procurement website. These documents are dated July 19, 2017.

07-24-2017

FAQ-W&S-89
Q: Is the contract price in the REC Contract the Bidder’s bid price for that Project or is it the highest winning Bid price?

The price in the REC Contract will be the Bidder’s bid price for the Project.

07-24-2017

FAQ-W&S-90
Q: Please confirm that there will be Collateral Requirement due prior to June 1, 2019 (the earliest that the Delivery Term can start).

Confirmed. The Collateral Requirement due before June 1, 2019 is 50% of the Annual Contract Value from the effective date of the REC Contract and will increase to 100% of the Annual Contract Value on June 1, 2019. The Annual Contract Value is the purchase price multiplied by the annual quantity specified in Table 1 of the REC Contract.

07-24-2017

FAQ-W&S-91
Q: In terms of Seller’s REC Delivery obligation, there are two conditions for an event of default to be triggered: (1) there are 3 or more shortfall years; and (2) the cumulative shortfall amount equals or exceeds the annual quantity. Will a Seller be in default if only one of the conditions occurs?

No, both conditions must be triggered for such event of default to occur.

07-24-2017

FAQ-W&S-92
Q: Where can I find the details of the Proposal requirements?

Proposal requirements are provided in the RFP Rules posted on the Final Materials page of the Wind and Solar section of the procurement website. These documents are dated July 19, 2017.

07-24-2017

FAQ-W&S-93
Q: Where can I find the specific public interest criteria for a Project that is located in a state that is adjacent to Illinois?

For renewable energy credits to qualify for the Illinois RPS for projects located in a state adjacent to Illinois, 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.

07-25-2017

FAQ-W&S-94
Q: If an interconnection agreement has not been executed for a Project, what are the requirements on the Bidder regarding the project milestones?

As explained in Section IV.2.3. of the RFP Rules, if an Interconnection Agreement has not been executed for a Project, the Bidder must provide contact information for owners, demonstrate exclusive control of the project site, and describe the stage of development. The Bidder is required to describe the stage of development of the Project appropriate to the point of interconnection and to the size of the Project. The Bidder must:  (i) indicate the utility or Regional Transmission Organization (e.g., PJM or MISO) to which the Seller has applied or will apply for interconnection; and (ii) if an application for interconnection has been made, indicate the specific milestones toward interconnection that have been met at this time or (iii) if an application for interconnection has not yet been made, provide other milestones in the development of the Project that have been reached to date.  For brownfield site photovoltaic projects, the Bidder must additionally describe the status of remediation of the site.

07-25-2017

FAQ-W&S-95
Q: Do Bidders have the opportunity for comments on the Pre-Bid and the Post-Bid Letters of Credit?

Yes. Bidders may, with the Part 1 Proposal, submit comments to the Pre-Bid Letter of Credit and/or the Post-Bid Letter of Credit.  The Bidder provides comments and proposes modifications exclusively by submitting a redline of the document in Microsoft Word format.  This document is provided by email or by upload to the application website.

07-25-2017

FAQ-W&S-96
Q: Is there a price escalation over the term of the contract?

No, the purchase price under the REC Contract will be fixed throughout the term of the REC Contract and will be the bid price that you have offered in the RFP for RECs for that winning project.

07-25-2017

FAQ-W&S-97
Q: Can the guarantor be an owner of the Seller?

Yes, the guarantor can be the parent of the Seller. The guarantor must meet the minimum credit rating requirement as provided in Table A of Section 4.3 of the Master REC Agreement as modified in the Cover Sheet, and must deliver and execute the guaranty in accordance with the REC Contract.

07-25-2017

FAQ-W&S-98
Q: Is there a draft of a letter of intent or memorandum of understanding that bidders can use for purposes of showing site control? If not, are there minimum requirements that such a document must satisfy?

There is no draft or sample letter of intent or memorandum of understanding available to bidders. Bidders can use the documents that they would use in their normal course of business as long as those documents satisfy the list of requirements provided as Appendix 4 of the RFP Rules.  These requirements include: (1) the owner must be identified by its legal name and the document must be signed by the owner; (2) the project must be identified; (3) the Seller (or Bidder) must be identified by its legal name and the document must be signed by the Seller (or Bidder); (4) the land over which the owner has control must be identified and described; (5) either: the owner must state its intent to give the Seller (or Bidder) site control or the owner must state its intent to enter into an agreement on a lease, an easement, an exclusive option for the period of REC Contract; or: the Owner must state that it has entered into exclusive discussions with the Seller (or Bidder) for purposes of coming to an agreement on a lease, an easement, an exclusive option or a sale; (6) the owner must state that it understands that the document will be used for purposes of presenting a Proposal in the IPA procurement events.  Please see Appendix 4 to the RFP Rules for further information.

07-25-2017

FAQ-W&S-99
Q: Is there a minimum milestone required for a Project to qualify under the Wind and Solar RFP?

No, there is no minimum milestone required; however, in the Part 1 Proposal the Officer of the Seller must certify that the Project has reached the appropriate development milestones to fully expect that the Project will deliver its first REC on or before June 1, 2021. Furthermore, as explained in Section IV.2.3 of the RFP Rules, if an Interconnection Agreement has not been executed for a Project, the Bidder must provide contact information for owners, demonstrate exclusive control of the project site, and describe the stage of development. Please see FAQ-W&S-94.

07-25-2017

FAQ-W&S-100
Q: Can we submit multiple bids for our projects that would all add up to the same overall quantity but that would be different in the price and quantities offered for each of our projects?

The Project has or will have a single revenue quality meter that satisfies the requirements of the applicable regional transmission organization, transmission provider, or distribution company and that measures or will measure its generation output.  For a Project, you must submit a single Bid, which has two elements: (i) a quantity of RECs that represents the annual quantity to be delivered in a delivery year under the terms of the REC Contract; and (ii) a price per REC that represents the price at which the Seller is willing to deliver RECs.

07-25-2017

FAQ-W&S-101
Q: The Part 1 Form requires an Owners Insert (#P1-2) be filled out for each Owner. Our Project has a large number of Owners. Will you accept a spreadsheet containing all Owners’ contact information required by the Part 1 Proposal?

Yes, you may submit the information in a Microsoft Excel spreadsheet. The spreadsheet must provide all of the required information from the Owner’s Insert (#P1-2) for each of the Owners. If an Owner is an individual, you must provide a phone number and email address.  If the Owner is an entity, you must provide the name, title, phone number, and email address for a representative of such Owner.  Since there are multiple Owners, you must indicate the proportion of the project site controlled by each owner.

While you are required to identify all Owners, for purposes of submitting documentation to demonstrate exclusive control of the Project site, you must provide documentation for Owners that together control at least 50% of the Project site.

07-25-2017

FAQ-W&S-102
Q: If a Seller has a winning Bid for a Project and the winning bid is $10/year, and if the Annual Quantity bid is 1,000 RECs, does that mean that the Seller would receive $10,000/year over the term of the contract?

A Seller that has a winning Bid for a Project of $10/REC associated with an Annual Quantity of 1,000 RECs will be paid $10,000/year for 15 years as long as the Seller delivers 100% of the Annual Quantity in each year.

07-25-2017

FAQ-W&S-103
Q: Can a special purpose vehicle/project entity be the Seller under the REC Contract? As the company is new, it will not have a rating or any discernible financial information. Is that a problem in terms of fulfilling the requirements of the Wind and Solar RFP?

Yes, there are no restrictions that would prevent a special purpose or project entity to be the Seller under the REC Contract.  However, the company must be formed before the Proposal is submitted.  The Project and company can fulfill the requirements of the Wind and Solar RFP even if there is no financial information regarding the entity.

07-25-2017

FAQ-W&S-104
Q: I understand that the amounts of the bid assurance collateral have been revised and that there is now a different requirement for each Company. Can you please explain?

The amount of bid assurance collateral required for a Project by AIC is $4,000/MW for Solar Projects and $1,600/MW for Wind Projects subject to a minimum of $35,000. The amount of bid assurance collateral tendered to AIC across all Projects presented by a Bidder need not exceed $120,000. The amount of bid assurance collateral required for a Project by ComEd is $10,000/MW for Solar Projects and $4,000/MW for Wind Projects subject to a minimum of $35,000. The amount of bid assurance collateral tendered to ComEd across all Projects presented by a Bidder need not exceed $300,000. The amount of bid assurance collateral required by MEC is $30,000 regardless of the size of the Project or the number of Projects presented by a Bidder.

07-26-2017

FAQ-W&S-105
Q: Why are the bid assurance collateral amounts different across the three Companies?

The different bid assurance collateral amounts among the three Companies reflects the differences in their budgets to procure RECs and thus in the expected number of RECs that would be allocated to each Company.

07-26-2017

FAQ-W&S-106
Q: When will the bid assurance collateral be returned?

If a Project is not selected and the Bid is not approved by the Commission, the bid assurance collateral can be returned as soon as practicable after the Commission decision. The Commission decision is expected four business days after the Bid Date.  If the Project is selected and the Bid is approved by the Commission, the bid assurance collateral can only be returned once all REC Contracts are executed, any Collateral Requirement under the REC Contract is posted, and the Supplier Fees are paid.  Supplier fees are due seven business days after the Commission decision.

Please note that if bid assurance collateral is provided in the form of a letter of credit, the letter of credit will expire on the date stated as part of its terms. The Bidder must provide special instructions in its Part 2 Proposal for the return of the letter of credit at an earlier date.  If bid assurance collateral is provided in the form of cash, the prompt return of the bid assurance collateral is predicated on the Bidder providing full instructions on the letterhead of the entity to which cash must be returned.

07-26-2017

FAQ-W&S-107
Q: My understanding is that under Public Act 099-0906, there is a 2% carve-out for brownfield site photovoltaic projects for the program overall. What is the specific carve-out for brownfield site photovoltaic projects within the Target of 200,000 RECs?

For purposes of the initial forward procurement, there is no carve-out for brownfield site photovoltaic projects.  The first procurement event Target of 200,000 RECs is thus for brownfield site photovoltaic projects and utility-scale solar projects combined, each of which is eligible to participate in this procurement process under Section 1-75(c)(1)(G)(ii) of the IPA Act.  Both types of projects are evaluated together on the basis of price alone.

You are correct that there is a 2% requirement for brownfield site photovoltaic projects in the Illinois RPS (20 ILCS 3855/1-75(c)(1)(C)).  Depending on the results of the initial forward procurements, the IPA will adjust future targets through procurements proposed in its long-term renewable resources procurement plan, currently under development, to meet that 2% brownfield site photovoltaic requirement.  Thus, if brownfield site photovoltaic projects are selected through the initial forward procurements in a manner that exceeds the 2% requirement, then the future targets for brownfield site photovoltaic projects will be set lower than they otherwise would have been (and vice versa with future targets representing more than the 2% overall requirement if less than this percentage is procured through the initial forward procurements) for future procurements proposed in the IPA’s long-term renewable resources procurement plan.

07-26-2017

FAQ-W&S-108
Q: Suppose that I have a 10 MW solar project with an annual quantity of 13,000 RECs. Could I please confirm the fees that I will have to pay for that Project? My understanding is that I will have to pay: (i) A bid participation fee of $500; (ii) supplier fees of: $1 x 13,000 = $13,000; (iii) assuming a winning REC price of $10, bid assurance collateral of 50% of annual contract value, namely 50% of (13,000 x $10) = $65,000. Can you confirm that my total fees in this example would be $78,500 and that there are no other charges or fees to be paid to IPA or the utilities?

Your understanding of fees associated with your project is not completely correct. We take each fee that you mention in turn.

Your understanding of the Bid Participation Fee is correct. 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 a prior 2017 procurement event). A participant that presents several projects is only required to pay a single Bid Participation Fee.

Your understanding of the Supplier Fee is correct based on the estimate of the Supplier Fee of $1 for each REC of the annual quantity provided during the webcast of July 19. Please note that this is an estimate only and that the final level of the Supplier Fee will be announced no later than two business days prior to the Bid Date.  Please also note that the Supplier Fee is levied only on those projects with bids approved by the Illinois Commerce Commission.

Your understanding of the bid assurance collateral requirement is incorrect. The bid assurance collateral for a Project consists of either cash or a letter of credit to each AIC, ComEd, and MidAmerican as a requirement of the Part 2 Proposal. The amount of bid assurance collateral required for a Project is determined separately for each Company.  For a 10 MW solar project:

  • The amount of bid assurance collateral required for a Solar Project by AIC is $4,000/MW for a total of $40,000.
  • The amount of bid assurance collateral required for a Solar Project by ComEd is $10,000/MW for a total of $100,000.
  • The amount of bid assurance collateral required by MEC is $30,000 regardless of the size of the Project.

Thus the total bid assurance collateral required is $170,000. Please note that this is not a “fee” to the project as bid assurance collateral is returned to the bidder or expires after completion of the procurement event.

The calculation in your question at 50% of the annual contract value is not the level of the bid assurance collateral but rather the Collateral Requirement that is due upon contract execution. The Collateral Requirement increases to 100% of the Annual Contract Value on June 1, 2019. The increase happens regardless of when the project becomes operational or when the first REC is delivered. In your example above, the Collateral Requirement would be equal to 50% of (13,000 x $10.00) = $65,000 until June 1, 2019 when it increases to $130,000. The Collateral Requirement, like the bid assurance collateral, is not a “fee” as the Collateral Requirement is returned to the seller or expires at the end of the contract.

We confirm that there are no other fees due to the IPA or the utilities under the terms of the RFP Rules or the terms of the REC Contract. We do not itemize any fee or costs associated with the development of the project or with interconnection.

07-28-2017

FAQ-W&S-109
Q: Suppose that we pay the bid participation fee and post the bid assurance collateral for our Project but for some reason outside our control we are unable to proceed with the Project. Will the bid participation fee and bid assurance collateral be refunded if we do not present a bid?

A Bidder that has paid the Bid Participation Fee will not be reimbursed, even if all Projects presented by the Bidder fail to meet the requirements of the Part 1 Proposal or the Part 2 Proposal or if the Bidder decides not to continue its participation in the RFP.

If you are unable to proceed and you do not present a bid, and if the bid assurance collateral is provided in the form of a letter of credit, the letter of credit will expire on the date stated as part of its terms (unless you provided special instructions with the Part 2 Proposal, in which case the bid assurance collateral can be returned as soon as practicable after the Commission decision). If you are unable to proceed and you do not present a bid, and if the bid assurance collateral is provided in the form of cash, such amounts will be returned as soon as practicable after the Commission decision (assuming that the Bidder provided full instructions on the letterhead of the entity to which cash must be returned).

07-28-2017

FAQ-W&S-110
Q: Can you please summarize the collateral requirements associated with participation in the Wind and Solar RFP?

The bid assurance collateral requirement for a Project consists of either cash or a letter of credit to each AIC, ComEd, and MidAmerican. The amount of bid assurance collateral required for a Project is determined separately for each Company. The method for calculating the amount of bid assurance collateral that will be required given the aggregate size of the Projects you are presenting are provided in Paragraphs V.2.2 and V.2.3 of the RFP Rules.   Also see FAQ-104.

If a Project has a winning bid that is approved by the Commission, upon contract execution, the Collateral Requirement required is 50% of the annual contract value. The annual contract value is the winning bid price times the annual quantity.  The Collateral Requirement under the terms of the REC Contract increases to 100% of the Annual Contract Value on June 1, 2019. The increase occurs regardless of when the project becomes operational or when the first REC is delivered.

07-28-2017

FAQ-W&S-111
Q: Can cash be provided for bid assurance collateral? Can cash be provided as Performance Assurance under the REC Contract?

Yes. Bid assurance collateral, due with the Part 2 Proposal, may be submitted in the form of cash or a letter of credit. Cash is also an acceptable form of Performance Assurance under the REC Contract.

07-28-2017

FAQ-W&S-112
Q: Are the webcast presentation and webcast recording posted to the procurement website?

The webcast presentation and webcast recording are posted to the Final Materials page of the Wind and Solar Section of the procurement website.

07-28-2017

FAQ-W&S-113
Q: If a Bidder successfully completes the requirements of the Part 1 Proposal for a Project, is the Bidder required to present the Part 2 Proposal for the Project?

A Bidder that successfully completes the requirements of a Part 1 Proposal for a Project may, but is not required to, submit a Part 2 Proposal for the Project.

07-28-2017

FAQ-W&S-114
Q: Are the awards for the Wind and Solar RFP expected to be made public? When would that occur?

The Bid Date for the 2017 Wind and Solar RFP is August 31, 2017. The Commission decision to either accept or reject the results of the procurement event is expected four (4) business days after the Bid Date. If the ICC accepts the results of the procurement event, the names of winning bidders and the average of the winning bid prices are expected to be made public at that time. Public Act 99-0906 states that participants in the procurement process will maintain the confidentiality of all other supplier and bidding information.

07-28-2017

FAQ-W&S-115
Q: The RFP Rules state that the Procurement Administrator allocates bids in proportion to the Company’s Budget and may take other factors into account in determining the allocation across the Companies. Is there a budget for this procurement event? Will further information be made available to Bidders?

Please note that there is no budget for this procurement event. The renewable resource budget for each Company will be used as proxy of its size for purposes of allocating RECs from winning Projects to the Companies. The Procurement Administrator will provide information to bidders regarding the allocation procedure at a later time, including the budget for each Company and the other factors that may be taken into account in the implementation of the procedure.

07-28-2017

FAQ-W&S-116
Q: Can you clarify whether the targets for the initial forward procurements are in terms of annual RECs or in terms of the total RECs to be delivered during the fifteen years of the REC Contract? Have the targets for future procurement events been developed, either in terms of RECs or in terms of MW?

The initial forward procurements under Public Act 99-0906 (“Act”) are for the procurement of 1,000,000 RECs annually from utility-scale wind projects and 1,000,000 RECs annually from utility-scale solar projects or brownfield site photovoltaic projects. The Act specifies that there will be a single procurement event for utility-scale wind projects and there will be multiple procurement events for utility-scale solar projects and brownfield site photovoltaic projects.  For this first procurement event, the targets are the procurement of 1,000,000 RECs annually from utility-scale wind projects and the procurement of 200,000 RECs annually from utility-scale solar projects or brownfield site photovoltaic projects.  At this point, the targets for future procurement events for solar projects have not been developed.

There is no capacity target for this procurement events; only targets of annual RECs.

07-28-2017

FAQ-W&S-117
Q: The solar target is 200,000 RECs for this first procurement event. What does this represent?

A REC represents all the environmental attributes corresponding to one megawatt-hour of energy generated from renewable energy resources. The Fall 2017 Wind and Solar RFP seeks to procure 200,000 RECs from utility-scale solar projects or brownfield site photovoltaic projects. This quantity represents an annual quantity of RECs to be delivered in aggregate to all three (3) Companies (Ameren Illinois Company, Commonwealth Edison Company, and MidAmerican Energy Company).

07-28-2017

FAQ-W&S-118
Q: By our calculation, the bid assurance collateral for solar projects is capped at $450,000 and this corresponds to 30 MW (i.e., 30MW*($4,000/MW+$10,000/MW)+$30,000=$450,000). Is this calculation correct? Does this mean that a Bidder presenting solar projects with aggregate capacity of 30 MW and a Bidder presenting solar projects with aggregate capacity of more than 30 MW are required to post the same total amount of bid assurance collateral?

That is correct. For a Solar Project, the bid assurance collateral required by a Bidder is capped at $450,000 across the three Companies ($120,000 for AIC, $300,000 for ComEd, and $30,000 for MEC).  This cap corresponds to 30 MW of Solar Projects.  A Bidder presenting one or several Projects with capacity totalling 30 MW will be required to post a total of $450,000 in bid assurance collateral and a Bidder presenting one or several Projects with aggregate capacity over 30 MW will also be required to post a total of $450,000 in bid assurance collateral.

07-28-2017

FAQ-W&S-119
Q: Is the bid assurance collateral for solar projects capped on a per project basis or on a per Bidder basis?

The amount of bid assurance collateral is capped on a per Bidder basis. If a Bidder proposes multiple solar projects (with one or with several different Sellers), the total amount of bid assurance collateral for solar Projects need not exceed $450,000.

07-28-2017

FAQ-W&S-120
Q: In fifteen years’ time, will the IPA conduct another procurement event for RECs from utility-scale wind projects?

Information regarding the procurement of RECs that the IPA may conduct in 15 years’ time is not currently available. The upcoming procurement event pursuant to Public Act 99-0906 is for 1,000,000 RECs annually from utility-scale wind projects for a term of 15 years.

07-28-2017

FAQ-W&S-121
Q: If the project is short of its annual quantity in a delivery and the project has RECs in excess of its annual quantity in the next delivery year, can I use those excess RECs to “cure” the shortfall of the prior year?

We address your question in two parts. First, under the terms of the REC Contract, it is an event of default if (a) Seller fails to meet the delivery year requirement in 3 or more delivery years and (b) the Shortfall Amount equals or exceeds the annual quantity. If you cannot meet the delivery year requirement in a delivery year, then this will count as a year in which you have failed to meet the delivery year requirement regardless of whether or not you have RECs in excess of your delivery year requirement in a subsequent year.  Please see Section 3(g) of the Cover Sheet and Section 5.1(b) of the Master REC Agreement as modified in the Cover Sheet for more information.

Second, while a Seller cannot deliver RECs in excess of the Delivery Year Requirement in a given delivery year, the REC Contract provides for an exception in the last Delivery Year.  In the last Delivery Year,  the Seller may deliver excess RECs from prior years for payment provided that cumulatively the quantity does not exceed the Maximum Contract Quantity under the REC Contract. Please see Section 3(i) of the Cover Sheet and Section 2.2 of the Master REC Agreement as modified in the Cover Sheet for more information.

07-28-2017

FAQ-W&S-122
Q: Can a Seller propose changes to the standard REC Contract at this point (now that the REC Contract has been posted as “final” on July 18, 2017)?

No.  All Sellers as part of their Proposal will have to accept the terms of the REC Contract as posted on July 18, 2017.

07-28-2017

FAQ-W&S-123
Q: Will there be a distinction made between RECs generated by a Project in MISO versus RECs generated by a Project in PJM?

No, there is no distinction made depending on whether the Project is located in the MISO or the PJM footprint.

07-28-2017

FAQ-W&S-124
Q: Is the Part 1 Date for the Wind and Solar RFP August 7 or September 18? Is September 18 the Part 1 Date for a subsequent procurement event under the Wind and Solar RFP?

The Part 1 Date for the current procurement event under the Wind and Solar RFP is August 7, 2017. September 18 is the Part 1 Date for the Utility Distributed Generation RFP.  Information and documents for this other RFP will be released at a later time.

07-28-2017

FAQ-W&S-125
Q: We do not have a signed interconnection agreement and thus we have to demonstrate exclusive control of the Project site. If there are multiple Owners with which we have agreements, are we required to provide all such agreements in the Part 1 Proposal?

No, while you are required to identify all Owners, for purposes of submitting documentation to demonstrate exclusive control of the Project site, you must provide documentation for Owners that together control at least 50% of the Project site.

07-28-2017

FAQ-W&S-126
Q: The Seller for the Project is in good financial standing and can produce financial statements. However, the Seller is not rated by any of the rating agencies. How should we proceed to respond to the financial requirements in the Part 1 Proposal?

If the Seller is not rated by any one of the rating agencies, then it does not meet the Minimum Rating and the Seller will not be granted unsecured credit under the REC Contract. In such a case, you will not be asked to provide financial statements.  Please be assured that the Seller not being rated will not impede the qualification of the Project for continued participation in the RFP.

07-28-2017

FAQ-W&S-127
Q: We have multiple projects with different Sellers that are affiliated entities. Can you please explain the instruction to identify the Bidder “by naming all such affiliated entities together”?

The name of Bidder should be provided as a list of all the names of the affiliated entities with each name separated by a comma or semicolon.  For example, if there are two Projects and two Sellers with the same parent company, and if the Sellers are called Solar Project I and Solar Project II, then the Bidder should be identified as “Solar Project I, Solar Project II”.

07-28-2017

FAQ-W&S-128
Q: Can Bidders comment on the standard form of Pre-Bid Letter of Credit to the website?

Yes, a Bidder may, in its Part 1 Proposal, provide comments on or propose modifications to each Pre-Bid Letter of Credit. The Bidder provides comments and proposes modifications exclusively by submitting a redline of a Pre-Bid Letter of Credit in Microsoft Word format.  This document is provided by email or by upload to the application website.

07-31-2017

FAQ-W&S-129
Q: What are the required documents to demonstrate site control and where can I find the information of such required documents?

Please see Paragraph IV.2.3. of the RFP Rules. The Bidder must provide one of the following to demonstrate the exclusive control of the project site: (i) document showing that Bidder or Seller owns the Project site; or (ii) an executed lease agreement or easement between the Bidder or the Seller and the Owner or Owners; or (iii) an executed option, between the Bidder or Seller and the Owner or Owners, with a unilateral right to lease or purchase the Project site; or (iv) a memorandum of understanding between the Owner or Owners and the Bidder or Seller regarding a lease, easement, exclusive option, or sale of the Project site; or (v) a letter of intent executed by the Owner or Owners stating the intention to deal exclusively with the Bidder or the Seller to enter into an agreement for a lease, an easement, an exclusive option, or the sale of the Project site; or (vi) other document demonstrating a right to develop the Project on the site.

07-31-2017

FAQ-W&S-130
Q: How expansive is the description of stage of development expected to be?

The description can be a few words or a short paragraph. The Bidder should first indicate whether an application for interconnection has been made.  If it has, the Bidder indicates the utility or Regional Transmission Organization (“RTO”, i.e., PJM or MISO) to which the Seller has applied and the Bidder can state which of the utility’s/RTO’s milestones for interconnection the Project has met.  If an application for interconnection has not yet been made, the Bidder can indicate the utility or RTO to which the application is expected to be made and provide any other milestones in the development of the Project that have been reached to date.  For brownfield site photovoltaic projects, the Bidder additionally describes the status of remediation of the site.

07-31-2017

FAQ-W&S-131
Q: Is the “collateral requirement” different from the “bid assurance collateral”? If so, how much bid assurance collateral and collateral requirement does a 2 MW solar project need to provide assuming that the annual quantity is 12,597 RECs?

Please note that to qualify as “utility-scale”, a Project must have a nameplate capacity GREATER than 2,000 kilowatts.

The bid assurance collateral is required with the Part 2 Proposal. The amount required for a Project where the size is rounded down to 2 MW is:  $35,000 to AIC in the form of cash or a Pre-Bid Letter of Credit; $35,000 to ComEd in the form of cash or a Pre-Bid Letter of Credit; and $30,000 to MEC in the form of cash or a Pre-Bid Letter of Credit.  The collateral requirement is a requirement of the REC Contract and will depend on the winning bid price for the project.  The collateral requirement would be in an amount of 50% of the annual contract value (50% of 12,597 x winning bid price).

07-31-2017

FAQ-W&S-132
Q: What happens if a Bidder does not submit a Bid for a Project on the bid date?

If a Bidder does not submit a Bid on the bid date, the Project will not be considered in selecting the winning Projects. There is no penalty for not submitting a Bid.

07-31-2017

FAQ-W&S-133
Q: What does it mean that 50% of the Project must be on the Project site as identified in the Proposal?

It means that at least 50% of the Project must be located within the physical location identified in the Proposal. With each REC delivery, the Seller will be required to represent this is the case.

07-31-2017

FAQ-W&S-134
Q: The current RFP is for 200,000 solar RECs and states that multiple procurement events will be held to reach the goal of 1,000,000 RECs. Could you kindly advise on the timing of the next anticipated procurement event for solar RECs?

The schedule for future procurements is not available at this time. Please register here:

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

to receive further announcements from us including when the next initial forward procurement for solar RECs will be held.

07-31-2017

FAQ-W&S-135
Q: Is it possible that we will win less than the annual quantity that we bid for our Project?

Please see FAQ-W&S-85. Yes, the evaluation of Bids can result in a Bidder having winning Bids for only a portion of the annual quantity from a Project. Should the Bid be approved by the Commission, such Bidder will have the option to reject the partial award of a portion of the annual quantity for a Project.

07-31-2017

FAQ-W&S-136
Q: Paragraph I.2.6 of the RFP Rules states that “A Bidder may present Bids for various Projects as long as the aggregate number of RECs from all such Projects on an annual basis does not exceed either the Wind Target or the Solar Target.” Given that the Solar Target equals 200,000 RECs for this solicitation, are we to understand that we can bid a maximum of 200,000 RECs into this solicitation inclusive of all our proposed projects?

Yes. We note that there will be additional procurement events for solar projects.

07-31-2017

FAQ-W&S-137
Q: Do we need to register our projects with M-RETS and/or PJM EIS GATS before the Bid Date? Is there a specific date by which such registration must occur under the REC Contract?

Registration of the Projects with PJM EIS GATS or M-RETS is not a requirement of the Wind and Solar RFP and thus such registration need not occur prior to the Bid Date of August 31, 2017. The Delivery Term under the terms of the REC Contract begins on the later of June 1, 2019 and the date at which the first REC is issued by PJM EIS GATS or M-RETS for the Project regardless of when the initial date of REC delivery occurs. Once the Delivery Term starts, the Seller must comply with the delivery obligations under the REC Contract.  There is no specific date for registration of the Project with PJM EIS GATS or M-RETS under the REC Contract.

07-31-2017

FAQ-W&S-138
Q: If we have a wind farm that has several phases, can we bid each phase into the RFP separately or do we have to present all phases in a single Proposal and Bid?

A “Project” has or will have a single revenue quality meter that satisfies the requirements of the applicable regional transmission organization, transmission provider, or distribution company, and that measures or will measure its generation output. The answer to your question depends on how many meters are installed and thus how many accounts are or will be registered in PJM EIS GATS or M-RETS.  To the extent that, for example, each phase has its own single revenue quality meter and account with PJM EIS GATS or M-RETS, then each phase is a “Project” for which a Proposal and Bid may be submitted.  To the extent that the output from all phases is measured by a single meter and the output is reflected in a single account with PJM EIS GATS or M-RETS, then the wind farm consists of a single Project for which you may submit a single Proposal and Bid.

07-31-2017

FAQ-W&S-139
Q: A Seller could execute the REC Contract with all three utilities (AIC, ComEd, and MEC). Given that ComEd is in PJM, for which the REC tracking system is PJM EIS GATS, while AIC and MEC are in MISO, for which the tracking system is M-RETS, does that mean a Project has to be registered in both GATS and M-RETS for purposes of delivering the RECs?

No. Each utility has an account with both PJM EIS GATS and M-RETS.  Thus, any one Project only needs to be registered with either PJM EIS GATS or M-RETS, but NOT both.  The Seller can transfer RECs from its account to each of the utilities either from PJM EIS GATS or from M-RETS.

07-31-2017

FAQ-W&S-140
Q: If I have two 20 MW adjacent facilities, would that be considered one Project or two?

A “Project” has or will have a single revenue quality meter that satisfies the requirements of the applicable regional transmission organization, transmission provider, or distribution company, and that measures or will measure its generation output.  The answer to your question depends on whether the two adjacent facilities have one or two meters installed and thus whether there are one or two accounts registered in PJM EIS GATS or M-RETS.  If each facility has its own single revenue quality meter and account with PJM EIS GATS or M-RETS, then each facility is a “Project” for which a Proposal and Bid may be submitted.  To the extent that the output from both facilities is measured by a single meter and the output is reflected in a single account with PJM EIS GATS or M-RETS, then the two facilities together consists of a single Project for which you may submit a single Proposal and Bid.

07-31-2017

FAQ-W&S-141
Q: What is the deadline for submitting the Part 1 Proposal?

The deadline for submitting the Part 1 Proposal is 12PM (noon) CPT on August 7, 2017. The calendar with all of the deadlines for the Wind and Solar RFP is available on the calendar page of the procurement website here:

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

07-31-2017

FAQ-W&S-142
Q: When is bid assurance collateral due? When will the final Supplier Fee be announced?

Bid assurance collateral in the form of cash or of a letter of credit to each of AIC, ComEd, and MEC is due with the Part 2 Proposal by 12PM (noon) CPT on August 23, 2017. In regards to the Supplier Fee, which is due after the Commission decision, the Procurement Administrator will inform Bidders of the amount required on a per REC basis no later than 6 PM two (2) business days before the Bid Date on August 31, 2017.

The calendar with all of the deadlines for the 2017 Wind and Solar RFP is available on the calendar page of the procurement website here:

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

07-31-2017

FAQ-W&S-143
Q: Paragraph I.3.9. of the RFP Rules states that “If the ICC approves the results of the procurement event, each Seller with a Bid approved for a Project will execute the REC Contract with two (2) or more of the Companies within three (3) business days of the ICC decision.” Does this mean that the REC Contract has to be executed within three (3) business days with only two (2) of the three (3) utilities even if the RECs from our Project are allocated to all three (3) Companies? What would then be the deadline for execution of the REC Contract with the last Company?

This paragraph of the RFP Rules means that a given Seller with a Project selected through this RFP will have its RECs allocated to either two (2) or three (3) of the Companies. The Seller will be required to execute the REC Contract within three (3) business days of the Commission decision with all Companies to which its RECs are allocated (either two (2) or three (3) Companies).  The Paragraph that you quote in no way says or implies that the REC Contract will have to be executed within three (3) business days with only two (2) of the three (3) Companies in the event that the RECs from the Project are allocated to all three (3) Companies.  The Companies are not of the same size so that it may not be the case that all Companies will have contracts with all Sellers selected through the RFP.

07-31-2017

FAQ-W&S-144
Q: Where can I find the comments on the RFP?

The comments solicited as part of the IPA workshop on the Initial Forward Procurement are available at https://www.illinois.gov/sites/ipa/Pages/WorkshopComments.aspx.  The comments on standard contracts prepared by the Procurement Administrator are made available to the Commission but are not publicly posted. There was no comment process for other aspects of the RFP.

07-31-2017

FAQ-W&S-145
Q: For a utility-scale wind project or a utility-scale solar project, is there flexibility for the Project’s actual capacity once it is built to be different from the capacity that was named in the Proposal, as long as 1) the Project’s nameplate capacity remains above 2 MW and 2) the annual quantity of RECs remains unchanged?

Yes.

07-31-2017

FAQ-W&S-146
Q: If we have an executed lease for the Project site, do we enter our own company information in the Owners Insert since we have control of the land?

If an Interconnection Agreement has not been fully executed for the Project, you are required to provide each Owner’s legal name and contact information as well as to provide documentation that you have control of the Project site. If you have a lease for the Project site, you have control of the Project site but you do not have ownership of the Project site.  You are expected then: (i) to provide in the Owners Insert the legal name and contact information of the entity or individual with whom you have entered into the lease and that has ownership of the Project site; (ii) to provide a copy of the executed lease agreement or easement between you and the Owner or Owners.  If there are multiple Owners of the Project site, you must provide documentation for Owners that together control at least 50% of the Project site.

07-31-2017

FAQ-W&S-147
Q: Will the Procurement Administrator be amending or archiving FAQs based on a preliminary information release rather than the final documents?

The Procurement Administrator will archive or update the FAQs to be consistent with the release of the final documents.

07-31-2017

FAQ-W&S-148
Q: On page 20 of the document with the filename “2_WS_Part-1-Illustrative-Form_04-JUL-2017.pdf”, it states that a bidder must submit at least on Pre-Bid Letter of Credit. Can you explain?

The DRAFT Part 1 Illustrative Form dated July 4, 2017 and posted to DRAFT documents page is entirely superseded by “Appendix 2: Illustrative Part 1 Form” dated July 19, 2017 and posted to the Final Materials page. Please consult the Final Materials page for any document related to the Proposal submission process.

Bid assurance collateral must be provided to each Company. A Bidder may provide the bid assurance collateral by posting cash or by providing an executed Pre-Bid Letter of Credit.

07-31-2017

FAQ-W&S-149
Q: Are the amounts of wind RECs procured through the initial forward procurement expected to meet the full requirements for all three utilities for the next fifteen years or are additional procurement events for wind RECs expected to occur in the future?

Yes, assuming budget availability, the IPA expects to conduct additional wind REC procurements.  Section 1-75(c)(1)(C) contains quantitative requirements for the procurement of RECs from “new wind projects,” and the amounts procured through the initial forward procurements are not expected to meet the full requirements for all three utilities for 2020, let alone for the next fifteen (15) years.

Additional procurement events may be proposed as part of the IPA’s long term renewable resources procurement plan, the first draft of which is required to be published within 120 days after June 1, 2017.  That plan is subject to Illinois Commerce Commission approval, with such approval expected in March 2018.   As that Plan has not yet been finalized, information regarding any additional procurements is not currently available.

07-31-2017

FAQ-W&S-150
Q: We expect to bid one Project in this upcoming procurement event and another Project in a future procurement event. Does the requirement that the Bidder and Seller must be the same entity when submitting a Proposal for only one Project apply to us?

Yes, the requirement applies to each procurement event separately. If the Bidder is submitting a Proposal for a single Project in this procurement event, the Bidder and the Seller must be the same entity.

07-31-2017

FAQ-W&S-151
Q: The Part 1 Form asks for information for a Guarantor. Is it required that we name a Guarantor even if we intend to meet the Collateral Requirement under the REC Contract with a Letter of Credit?

Naming a Guarantor is not required but is an option that is offered to each Seller. If you wish to rely on the financial standing of another entity for purposes of the REC Contract, if this entity meets the minimum rating, then this entity is a Guarantor, and the Guarantor may provide a Guaranty to meet some or all of the Collateral Requirement under the REC Contract.  Alternatively, the Collateral Requirement may be met with cash or with a Letter of Credit.

07-31-2017

FAQ-W&S-152
Q: What is the last date for signing the REC Contract for the Wind and Solar RFP?

The REC Contracts must be fully executed within three business days of the Commission decision. With the Commission decision expected on Thursday, September 7, 2017, the REC Contracts would be fully executed by Tuesday, September 12, 2017.

The process is expected to be as follows. By 12 PM CPT (noon) on the first business day after the ICC decision, the Company sends a partially executed electronic copy of the REC Contract and related documents to the Seller. By 12 PM CPT (noon) on the second business day after the ICC decision, the Seller executes the signature pages and sends such fully executed signature pages to the Company electronically.  The creditworthiness requirements of the REC Contract must be met by the Seller within five (5) business days of such ICC decision.

07-31-2017

FAQ-W&S-153
Q: I have a single Project in ComEd’s territory. Can I just submit bid assurance collateral to ComEd only?

No. The Procurement Administrator will allocate among the utilities the RECs from Projects with Bids approved by the Commission.  The location of the Project is NOT a factor that will be considered in the allocation.  Even if your Project is in ComEd’s territory, it is entirely possible that, should your Project have a Bid that is approved by the Commission, the RECs would be delivered to AIC and/or MEC.  A Bidder does not choose its counterparty under the REC Contract.

You must submit bid assurance collateral for all three (3) Companies as required by the RFP Rules. If a Bidder does not submit bid assurance collateral to each of the Companies in an amount that is sufficient given the capacity and Type of the Project, the Bid on the Project will be rejected.

07-31-2017

FAQ-W&S-154
Q: What would happen if our Project is selected and the bid is approved by the Commission but the Project fails? I assume this will be an event of default. Is there a penalty?

You are correct that this is an event of default and there is a penalty. If the Project fails to deliver at least one REC by June 1, 2021, this is an event of default and such failure will not be excused by force majeure. For such an event of default, the Seller will be required to pay the Buyer an amount equal to the Collateral Requirement.

08-01-2017

FAQ-W&S-155
Q: What happens if it is not the case that 50% of the Project, once it is built, is located within the physical location identified in the REC contract? Are there circumstances for which the Buyer can make exceptions to this requirement?

Section 5(f) of the Coversheet of the REC Contract requires that “at least 50% of the Project is located within the physical location identified.” Failure to comply with this requirement is an event of default. For such an event of default, the Seller will be required to pay the Buyer an amount equal to the Collateral Requirement.  There are no exceptions to this requirement.

08-01-2017

FAQ-W&S-156
Q: We have both Wind and Solar Projects. Can you clarify the maximum number of RECs that we can bid for our Wind Projects, for our Solar Projects, and for all Projects combined?

There is a Target for each of the two Categories of Projects (i.e., wind Projects and solar Projects) because Projects are evaluated separately in each of these two Categories. You can bid up to the Solar Target of 200,000 RECs for all of your Solar Projects and you can bid up to the Wind Target of 1,000,000 RECs for all of your Wind Projects. There is no separate cap on the number of RECs across all Projects combining Wind and Solar (or, to put it another way, you can bid up to the sum of the Targets of 1,200,000 RECs from all your Projects, both Wind and Solar).

08-01-2017

FAQ-W&S-157
Q: Can you confirm that, regardless of the circumstances (e.g., location of the Project, registration of the Project in GATS or M-RETS), every Bidder is required to submit bid assurance collateral to all three utilities? There are no exceptions?

Correct. There are no exceptions.

08-01-2017

FAQ-W&S-158
Q: Do we post the bid assurance collateral separately for each Project or do we post bid assurance collateral for all Projects together?

Bid assurance collateral is posted for all Projects together. A Bidder with multiple Projects that elects to provide bid assurance collateral in the form of a letter of credit for a Company may present a single letter of credit to that Company for all Projects. A Bidder presenting Proposals for multiple Projects and that elects to provide bid assurance collateral in the form of cash for a Company may effect a single wire transfer to provide to that Company the required bid assurance collateral for all Projects.

08-01-2017

FAQ-W&S-159
Q: Is assignment possible under the REC Contract?

Assignments are possible under the REC Contract.   Generally, the Seller may not assign the REC Contract without the prior written consent of the Buyer, which shall not be unreasonably withheld.  However, consent of the Buyer is not required for transfer or assignment to an Affiliate of the Seller if the Affiliate’s creditworthiness is equal to or higher than that of the Seller on the Effective Date.  The full conditions under which an assignment can occur are provided in Section 9.2, as amended on the cover sheet (page 18 of the REC Contract as posted on July 18).

08-02-2017

FAQ-W&S-160
Q: We have three Projects. Do I submit one Part 1 Proposal or do I submit the Part 1 Proposal three times? Do I have to submit the information for all three Projects together or can I submit the information one Project at a time?

If one Bidder has three Projects, the Bidder submits a Part 1 Proposal three times, using login credentials from three different accounts from which you will access the online Part 1 Form. Some information, such as information regarding the Bidder and Sellers, is only required to be submitted once.  After you submit the Part 1 Proposal for your first Project, you will be able to indicate in the Proposals for the second and third Projects that this information has already been submitted.

You do not need to wait to submit all Proposals at one time. You may submit one Proposal for one Project before the others.  In fact, the review of the first Proposal by the Procurement Administrator may assist you in avoiding deficiencies in your Proposals for your other Projects.

08-03-2017

FAQ-W&S-161
Q: Our Project has a large number of executed leases for the site. Can we submit a spreadsheet with information about the Owners? Can we provide one typical lease?

Regarding providing information about the Owners, Please see FAQ-WS-101. You may submit the information in a Microsoft Excel spreadsheet. The spreadsheet must provide all of the required information from the Owner’s Insert (#P1-2) for each of the Owners. If an Owner is an individual, you must provide a phone number and email address.  If the Owner is an entity, you must provide the name, title, phone number, and email address for a representative of such Owner.  Since there are multiple Owners, you must indicate the proportion of the project site controlled by each owner.

While you are required to identify all Owners, for purposes of submitting documentation to demonstrate exclusive control of the Project site, you must provide documentation for Owners that together control at least 50% of the Project site. If this would still require you to provide a large number of leases, if you are using a small number of standard documents across all Owners, you may: (i) present one complete sample of each such document (as used with and signed by one of the Owners), (ii) provide a representation that the documents not presented are substantially of the same form; and (iii) provide the signature pages for other leases for which a complete document is not presented.

08-03-2017

FAQ-W&S-162
Q: There are two options for the Post-Bid Letter of Credit attached to the REC Contract. Is a winning bidder allowed to use either of the two forms, for any of the Companies?

Yes.

08-03-2017

FAQ-W&S-163
Q: If our Project is selected but we don’t execute the REC Contract, do we lose our bid assurance collateral? Are we in default under the terms of the REC Contract?

A Company may draw upon the bid assurance collateral if a Seller has failed to execute the REC Contract for a Project within three (3) business days of being notified that the ICC has approved the bid on the Project. Failing to execute the REC Contract is not considered an event of default.

08-03-2017

FAQ-W&S-164
Q: We have accounts for multiple projects and intended the Bidder and Sellers to be different entities. If I submit a single Part 1 Proposal for one Project, will the Bidder and Seller be required to be the same? If I submit multiple Proposals for multiple Projects but later decide only to bid one Project, will I retroactively be required to make the Bidder and Seller the same?

If you decide to submit a single Part 1 Proposal for a Project, the Bidder and the Seller must be the same entity. If you submit two Part 1 Proposals, each for a different project, then the Bidder and the Seller may be different entities. In the latter case, if you decide not to bid on one of the two Projects, the Bidder and the Seller will remain different entities and no retroactive change to the identity of the Bidder or Seller will be required.

08-03-2017

FAQ-W&S-165
Q: Can a surety bond be provided as bid assurance collateral or to fulfill the Collateral Requirement under the REC Contract?

No. Bid assurance collateral, due with the Part 2 Proposal, may be submitted in the form of cash or a letter of credit. The Collateral requirement under the REC Contract must also be in the form of cash or a letter of credit.

08-03-2017

FAQ-W&S-166
Q: With reference to FAQ-W&S-85, in the event that a bidder is only awarded a portion of RECs that they bid, if the bidder decides to reject this partial award, will the bidder forfeit its bid assurance collateral?

If a Bidder is given the option to accept or reject a partial award, the Bidder will not forfeit its bid assurance collateral in the event that the Bidder decides to reject the award.

08-03-2017

FAQ-W&S-167
Q: Where can I find the Pre-Bid Letters of Credit?

The Pre-Bid Letters of Credit for AIC, ComEd and MEC are provided as Appendices 5, 6 and 7, respectively, under the FINAL Wind and Solar RFP Documents header on the Final Materials page of the procurement website.

08-03-2017

FAQ-W&S-168
Q: There is some information that is required by the Part 1 Proposal and that we cannot provide. How do we proceed?

For any information required by the Part 1 Proposal that you cannot provide, please fill in the field with “unavailable” or “n/a” as appropriate, and provide an explanation for any such missing information in the justification of omissions.

08-03-2017

FAQ-W&S-169
Q: Will you allow minor revisions to the certification inserts?

Bidders must use the Certification Inserts as prepared by the Procurement Administrator and posted to the procurement website. No revisions to these inserts, even minor, are permitted.

08-03-2017

FAQ-W&S-170
Q: The LOI for site control names one of our affiliates rather than ourselves. What additional document do you require in this case?

Please see Appendix 4: Minimum Requirements for Letter of Intent or Memorandum of Understanding posted under the FINAL Wind and Solar RFP Documents header on the Final Materials page of the procurement website. The Seller or Bidder must be identified by its legal name and the name of a representative for the Seller or Bidder must be provided along with the representative’s title and email address.

If the LOI names an affiliated company of the Bidder/Seller rather than the Bidder/Seller themselves, then the terms of the LOI must make it clear that the counterparty to the lease, easement, or option, may be the named company or its affiliates. Furthermore, an explanation or documentation must be provided to the Procurement Administrator to link the company named on the LOI to the Bidder or Seller.

08-03-2017

FAQ-W&S-171
Q: Will the financial information submitted as part of a Part 1 proposal ever be filed to a commission or made public record?

Please see FAQ-W&S-175. Any information provided by a Bidder or Seller in its Part 1 Proposal and its Part 2 Proposal is provided on a confidential basis to the Procurement Administrator, and may be provided on a confidential basis to the Procurement Monitor, to the IPA, or to ICC Staff.

Additionally, the Procurement Administrator, the Procurement Monitor, representatives from the IPA, the ICC Staff, and representatives of each Company as applicable who are involved in the evaluation of Proposals will consider all data and information provided by Bidders and Sellers in response to this RFP to be confidential and will attempt to limit its disclosure to the public. Additional information is provided in Section VI.3. (Personnel and Confidentiality) of the RFP Rules posted on the Final Materials page of the procurement website.

Please note that financial information is requested but not required for the Part 1 Proposal.

Revised 8-4-2017; first posted 8-3-2017.

08-03-2017

FAQ-W&S-172
Q: Can you confirm that an agency agreement is required in the case that the Bidder is a parent company and the Seller for each Project are special-purpose, affiliated entities?

We confirm that an agency agreement is neither required nor expected in the case where the Bidder is a parent company and the Seller is a special-purpose entity.  An agency agreement is a specific relationship whereby a first party, the “principal”, agrees that specific actions by a second party, the “agent” can bind the principal.  It is expected by the RFP Rules that in the case of a Bidder presenting proposals for multiple projects with different Sellers, the Bidder and the Sellers are affiliated entities.

08-03-2017

FAQ-W&S-173
Q: If the Seller is a newly formed entity, can we respond to the questions in regards to the number of years in business or the website address using the Bidder’s information (instead of the Seller’s)?

If providing the information in regards to the Seller, please provide the information for the Seller and not the Bidder, even if the Seller is newly formed.  You may explain any omissions or information that is not available for the Seller in the Justification of Omissions.

08-03-2017

FAQ-W&S-174
Q: What are you looking for as proof that we paid the bid participation fee?

The Bid Participation Fee is due by the Part 1 Date and a Bidder must provide evidence of compliance with this requirement with the Part 1 Proposal. Such evidence includes a photocopy of the check, a confirmation page from the e-check website, or a receipt from the Illinois Power Agency (“IPA”). Please provide this evidence by upload to the online Part 1 Form or by email to Illinois-RFP@nera.com.

The Procurement Administrator will confirm with the IPA that the payment of the Bid Participation Fee has been received before the Part 1 Proposal can be considered complete.

08-03-2017

FAQ-W&S-175
Q: We have concerns about the confidentiality of the documents that we provide in response to the requirements of the Part 1 Proposal. What assurances do we have that these will be kept confidential?

For a procurement event held by a Procurement Administrator on behalf of the Illinois Power Agency, the Commission makes public only the names of the successful bidders and the average of the winning bid prices.  As required by Section 16-111.5(h) of the Public Utilities Act, “all participants in the procurement process shall maintain the confidentiality of all other supplier and bidding information.” Participants include the Procurement Administrator, the Procurement Monitor, the Commission, and the Illinois Power Agency. As further provided for in that section, any such confidential information “shall not be made publicly available and shall not be discoverable by any party in any proceeding, absent a compelling demonstration of need.”  Additionally, for any confidential information shared with the Illinois Power Agency, the IPA is subject to a separate, standalone requirement found in Section 1-120 of the IPA Act (20 ILCS 3855); this Section requires that the Agency “shall provide adequate  protection for confidential and proprietary information furnished,  delivered, or filed by any person, corporation, or other entity.” This requirement to provide protection for third-party confidential information submitted to the Agency includes, but is not limited to, situations in which that information is provided to the Agency as part of a competitive procurement process.

08-04-2017

FAQ-W&S-176
Q: What is the maximum file size for uploads? Are zip files acceptable as a file type?

Documents are limited to a file size of 30Mb. Zip files are acceptable.

If your document is larger than 30Mb, please email the Procurement Administrator at Illinois-RFP@nera.com for further instructions.

08-04-2017

FAQ-W&S-177
Q: Are Representatives automatically put on the lists to receive all announcements, reminders, notices, and other correspondence coming from the Procurement Administrator? One of our Representatives would prefer only to receive the notices directly related to our Proposal.

The Procurement Administrator will send all notices related to your Proposal to the Representatives, including documents such as the confidential information required to submit Bids on the Bid Date. The Procurement Administrator does not “sign up” the Representative to receive all announcements and reminders; however, the Procurement Administrator would send to the Representatives final reminders regarding bidder training and the Bid Date for the Wind and Solar RFP. You may request that a Representative be excluded from these reminders if you wish.

08-04-2017

FAQ-W&S-178
Q: How do we submit cash to the Companies for purposes of bid assurance collateral?

Bid Assurance Collateral in the form of cash must be provided via wire transfer to the Companies (AIC, ComEd and MEC). Full instructions and the W-9 forms for the Companies are available from the Procurement Administrator upon request.

08-04-2017

FAQ-W&S-179
Q: Can I use exactly the same return of cash letter for all Companies (AIC, ComEd, and MEC)?

The “form” of the return of cash letter can be the same for each Company. However, each letter should be addressed to each Company separately, including contact information for an individual at the Company, and thus three separate, different return of cash letters are required.

08-18-2017

FAQ-W&S-180
Q: I see redlines in Insert #P2-5. Where can I find the final version?

The Contract Insert (#P2-5) posted to the procurement website is in final form. The Contract Insert purposefully contains marked deletions and additions starting on page 5 in the section dealing with optional changes to the Form of Guaranty. A Bidder that is relying on a Guarantor that wishes to elect optional changes provided in this document should review each such modification and then indicate by checking “yes” or “no” whether it wishes to adopt the change.

08-18-2017

FAQ-W&S-181
Q: If the same individual is both the Officer of the Seller and a representative of the Bidder, is it acceptable for that single individual to sign the P2 Certifications Insert on behalf of both entities?

Yes, this is acceptable.

08-18-2017

FAQ-W&S-182
Q: We are requesting that the Procurement Administrator release a sample of a “return of cash letter”.

A sample template for the return of cash for each Company was distributed to Bidders by the Procurement Administrator on August 17, 2017. If you did not receive these templates, please request them from the Procurement Administrator via email at Illinois-RFP@nera.com.

The return of cash letters for AIC and ComEd should be uploaded in Section 2 of the online Part 2 Form and the return of cash letter for MEC should be uploaded Section 6 of the online Part 2 Form. These letters can also be submitted to the Procurement Administrator via email.

08-18-2017

FAQ-W&S-183
Q: Is there a cap on the Collateral Requirement under the terms of the REC Contract?

There is no cap on the Collateral Requirement as it depends on the Annual Contract Value. Upon contract execution, the Collateral Requirement is 50% of the Annual Contract Value.  The Collateral Requirement increases to 100% of the Annual Contract Value on June 1, 2019. The Annual Contract Value is the number of RECs to be delivered annually under the contract times the winning bid price for the system. The Collateral Requirement is subject to a $50,000 minimum through the first 10 delivery years.

08-21-2017

FAQ-W&S-184
Q: When is the Procurement Administrator issuing the Cash Certifications Inserts for each Company?

All Inserts required for the Part 2 Proposal, including the Cash Certifications Inserts, are posted on the Final Materials page of the Wind and Solar section of the procurement website. Click on the “P2 Form: P2 Inserts” to download the file; it is dated July 31, 2017.

08-21-2017

FAQ-W&S-185
Q: Will the Procurement Administrator issue instructions to Bidders for posting of cash as bid assurance collateral, including wire transfer information and a W-9 for each Company (AIC, ComEd, and MEC)?

The Procurement Administrator provided bid assurance collateral instructions upon request prior to the Part 1 Notification date.  The Procurement Administrator provided bid assurance collateral instructions to all Bidders with the Part 1 Notification on August 14, 2017.  If you did not receive these documents or if the documents have been misplaced, please make a request by email at Illinois-RFP@nera.com to receive bid assurance collateral instructions and the W-9s for each Company.

08-21-2017

FAQ-W&S-186
Q: Where can I find the glossary referred to in the online forms?

The Glossary is posted on the Final Materials page of the Wind and Solar Section of the procurement website under the Illustrative Part 2 Form.

08-21-2017

FAQ-W&S-187
Q: What is due on August 23, 2017, the Part 2 Date?

The Part 2 Proposal includes a completed online Part 2 Form, including all required Inserts, and the submission of bid assurance collateral to each Company in the form of a Pre-bid Letter of Credit or cash.

The online Part 2 Form is accessible on the Qualification Forms page of the procurement website. Bid Assurance Collateral Instructions and W-9s for each company were provided with the Part 1 Notification sent on Monday, August 14. All Inserts required for the Part 2 Proposal, including the Cash Certifications Inserts, are posted on the Final Materials page of the Wind and Solar section of the procurement website. Click on the “P2 Form: P2 Inserts” to download the file; it is dated July 31, 2017.

08-21-2017

FAQ-W&S-188
Q: Can you confirm that an affiliated entity of the Bidder is able to post cash as bid assurance collateral on behalf of the Bidder? If so, what can we do to make sure that the Bidder is properly credited with fulfilling this requirement of the Part 2 Proposal?

Yes, we confirm that an affiliate entity of the Bidder may post cash as bid assurance collateral on behalf of the Bidder. If such is the case, i.e., the Bidder is posting cash as bid assurance collateral, and the entity posting cash is not the Bidder, please include a note with the wire transfer to identify the Bidder on behalf of whom the bid assurance collateral is posted. We would appreciate, but do not require, that you also advise the Procurement Administrator by email that bid assurance collateral has been posted.  This will make it easier for the Procurement Administrator to confirm receipt with the Companies and to ensure that proper credit is given for fulfilling this requirement of the Part 2 Proposal.

08-21-2017

FAQ-W&S-189
Q: Has the Procurement Administrator made available to Bidders sample letters for the return of cash provided as bid assurance collateral?

The Procurement Administrator provided to Bidders a sample letter for the return of cash for each Company on August 17, 2017. If you did not receive these documents or if the documents have been misplaced, please make a request by email at Illinois-RFP@nera.com for the sample return of cash letters to be sent to you.

08-21-2017

FAQ-W&S-190
Q: Do the representations in Section 3.1(d) of the Master REC Agreement require the Seller to have all permitting for the proposed project completed as of the Effective Date?

No, it is not intended or required (and may not be practical) for Seller to have all permitting for the proposed project completed as of the Effective date, or for Seller to have all necessary permits filed as of the Effective Date. As envisaged by Public Act 99-0906, the initial forward procurement is for the procurement of RECs from only “new” renewable energy projects (energized after June 1, 2017) and contemplates a period of time for the development and construction of these projects such that RECs generated from such projects may be delivered starting no earlier than June 1, 2019 and no later than June 1, 2021.

Section 5 of the Coversheet sets forth select requirements related to the development of the proposed project and Section 3 of the Coversheet sets forth select requirements related to the delivery of RECs from the proposed project. It is expected that as of the Effective Date of REC Contract, Seller has obtained or submitted all necessary approvals and authorizations appropriate for this stage of development of the project and has made all necessary investigations to determine that there are no impediments for it to obtain any further approvals and authorizations required to meet its obligations under the REC Contract.

08-21-2017

FAQ-W&S-191
Q: Can you describe when the delivery of RECs begins under the REC Contract? Is the Seller either required or permitted to deliver a quantity of RECs up front?

The delivery term under the REC Contract begins the later of June 1, 2019 and the date at which the first REC from the Project is issued by PJM EIS GATS or M-RETS. Please note that the Date of First Operation of the Project cannot be on or before June 1, 2017 and that at least one REC must be delivered from the Project by June 1, 2021.

The Seller is not required and is not permitted to provide the RECs up front. In each delivery year, the Seller must deliver a quantity of RECs that meets the Delivery Year Requirement as defined in the REC Contract.

08-21-2017

FAQ-W&S-192
Q: If a Bidder does not provide information for a guarantor in its Part 1 Proposal, is it then precluded from using a guarantor during the term of the REC Contract?

A Bidder that does not provide information for a guarantor in the Part 1 Proposal may nevertheless rely on the financial standing of a creditworthy guarantor during the term of the REC Contract. The Bidder would make a request to each Company to assess the creditworthiness of the entity that is to serve as guarantor.  As provided in Table A of Section 4.3, the guarantor must be rated by at least one of S&P, Moody’s and Fitch, and the guarantor’s credit rating must be at least BBB- (if from S&P or Fitch) or Baa3 (if from Moody’s).

08-21-2017

FAQ-W&S-193
Q: Are we asked to provide contact information for landowners because the Procurement Administrator and the IPA expect to need to contact landowners directly?

The Procurement Administrator and the IPA do not expect to need to contact landowners directly.

08-21-2017

FAQ-W&S-194
Q: If our Part 1 Proposal is missing information, does that mean that our Proposal will be considered null and void?

If the Part 1 Proposal is incomplete it does not mean that the Proposal is null and void.   If the Part 1 Proposal is incomplete or requires clarification, the Procurement Administrator sends a deficiency notice to the Bidder.  If the Bidder receives a first deficiency notice from the Procurement Administrator regarding any item of the Part 1 Proposal, the Bidder has until 12 PM (noon) on the Part 1 Date, or until 6 PM on the second business day following the business day during which a first deficiency notice is sent to the Bidder, whichever comes later, to respond.

08-21-2017

FAQ-W&S-195
Q: If a Seller under the REC Contract first meets the Collateral Requirement in cash, can this be changed to a Letter of Credit at a later date?

Yes, the Seller can choose how it chooses to meet the Collateral Requirement. However, if a Letter of Credit is used, this Letter of Credit must be acceptable to the Company.

08-21-2017

FAQ-W&S-196
Q: Is the cap on the bid assurance collateral per Project or per Bidder?

The amount of bid assurance collateral is capped on a per Bidder basis. The amount of bid assurance collateral tendered for all Projects presented by a Bidder need not exceed $120,000 for AIC, $300,000 for ComEd, and $30,000 for MEC. If a Bidder is only presenting brownfield site photovoltaic projects and all such projects total less than 2 MW in capacity (AC rating), the amount of bid assurance collateral required is $20,000 for AIC, $20,000 for ComEd, and $10,000 for MEC.

08-21-2017

You do not need to register for Bidder Training. The Bidder Training consists of time set aside for Bidders to practice completing and submitting their Bid Forms.  The Procurement Administrator is available at that time to evaluate the Bid Forms and to answer questions.

The schedule for Bidder Training is provided in attachment 3a – Confidential Information for Training provided to you with the attachment to your Part 1 Notification entitled “Invitation to Bidder Training”. Instructions for completing and submitting the Bid Form are provided in the Bid Form Guide, also provided as an attachment to your Part 1 Notification. Finally, you must use the confidential information provided in the attachment 3a (with the green border) for access to the secure file transfer interface that you will use to submit your Bids.

08-22-2017

FAQ-W&S-198
Q: Who can sign the Cash Inserts and the Request for Return of Cash Letters? Is it only the Officer of the Seller?

The Cash Inserts for each Company (#P2-1 for AIC, #P2-2 for ComEd, and #P2-3 for MEC) must be duly signed by a representative of the Bidder.  If the Bidder and Seller are the same entity, the individual can be the Officer of the Seller or another representative named in the Part 1 Proposal.  If the Bidder is presenting Proposals for multiple Projects, the individual must be a representative of the Bidder.  The representative of the Bidder can be any individual from the Bidder named in the Part 1 Proposal.  The representative of the Bidder can also be an officer of the Bidder not named in the Part 1 Proposal; if that is the case, please explain that this individual can bind the Bidder in a note included in the Justification of Omissions.

08-22-2017

FAQ-W&S-199
Q: The Contract Insert (#P2-5) asks “Is the Seller relying on the financial standing of a Guarantor?” I would like to confirm that this is asking if Seller intends to rely on a Guaranty and that we should answer “no” if we intend to post a Letter of Credit to meet the Collateral Requirement.

This question in the Contract Insert strictly is asking whether the Seller intends to rely on a Guaranty. You should say “no” if you intend to meet the Collateral Requirement under the REC Contract with a letter of credit or cash.

08-22-2017

FAQ-W&S-200
Q: Our understanding is that the Pre-Bid Letters of Credit require same day payment. Is it acceptable to modify the timing to allow three days for payment?

The Pre-Bid Letters of Credit require same day payment for a drawing that is presented prior to 11 AM (Eastern Prevailing time). Payment at the opening of the next business day is required for drawings presented after 11 AM (Eastern Prevailing Time).  There is no acceptable modification to this paragraph (Paragraph 5) that allows three business days for payment.

Please note that if you elect to submit your bid assurance collateral as a Pre-Bid Letter of Credit for a Company, you must use the Standard Pre-Bid Letter of Credit for that Company provided as an appendix to these RFP Rules or include only those modifications to the Standard Pre-Bid Letter of Credit acceptable to that Company and posted to the procurement website. The final list of acceptable modifications is posted to the Final Materials page of the Wind and Solar section of the procurement website.

08-22-2017

FAQ-W&S-201
Q: Is the Collateral Threshold Amount of $2,500,000 on a per Company and per contract basis?

The Collateral Threshold Amount is on a per Company but not on a per contract basis. The Collateral Requirement is $2,500,000 across all REC Contracts with a Company.

08-22-2017

FAQ-W&S-202
Q: Has an estimate of the Supplier Fee been announced? When will the final Supplier Fee be announced?

An estimate of the Supplier Fee was provided to bidders during the webcast on July 19, 2017. This estimate is $1 times the annual quantity of RECs (or approximately $0.07 per REC across the 15-year delivery term).  The final Supplier Fee will be announced no later than two (2) business days prior to the Bid Date.

08-22-2017

FAQ-W&S-203
Q: Our bank may be slower than anticipated issuing the letter of credit. Can we submit a scan via email? Will that be sufficient for submission of the Part 2 Proposal by noon (central) on Wednesday, August 23, 2017?

Bid assurance collateral is due by noon (central) on Wednesday, August 23, 2017. If bid assurance collateral is not submitted at that time, any information you can provide on the timing of submission would be appreciated.  If you submit scans then the Companies can evaluate whether the Pre-Bid Letters of Credit are acceptable.  Nevertheless, your Part 2 Proposal will be deficient if bid assurance collateral in its final executed form is not provided by the deadline.  You will receive a deficiency notice from the Procurement Administrator that will include a deadline for curing such deficiency.

08-22-2017

FAQ-W&S-204
Q: The P2 Certifications Insert (#P2-4) requests a signature of a “Representative of the Bidder” if the Bidder is a different entity than the Seller. Can this Representative of the Bidder be one of the named representatives from the Part 1 Proposal or should we use an officer of the Bidder?

The Representative of the Bidder can be any individual from the Bidder named in the Part 1 Proposal. The Representative of the Bidder can also be an officer of the Bidder not named in the Part 1 Proposal; if that is the case please explain that this individual can bind the Bidder in a note included in the Justification of Omissions.

08-22-2017

FAQ-W&S-205
Q: Please summarize the amount of the Collateral Requirement that must be posted with each Company under the REC Contract as well as the timing of when such Collateral Requirement is due.

If a Project has a winning bid that is approved by the Commission, upon contract execution with a Company, the Collateral Requirement required for that Company is 50% of the annual contract value. The annual contract value is the winning bid price times the annual quantity.  The Collateral Requirement under the terms of the REC Contract increases to 100% of the Annual Contract Value for a Company on June 1, 2019. The increase occurs regardless of when the project becomes operational or when the first REC is delivered.

The REC Contracts must be fully executed with all companies within three business days of the Commission decision to approve the results of the procurement event. The creditworthiness requirements of the REC Contract must be met by the Seller within five (5) business days of such ICC decision.  If the Seller or its Guarantor does not qualify for an unsecured line of credit under the REC Contract, then the amount of the Collateral Requirement must be provided in the form of cash or a letter of credit within five (5) business days of the Commission decision to approve the results of the procurement event.

08-29-2017

FAQ-W&S-206
Q: Will the names of the winning bidders and the average of the winning bid prices be made public if there is only one or two winning bidders?

The Act requires that the names of the successful bidders and the average of the winning bid prices be made public at the time of Commission approval of a procurement event. However, the Act also requires that individual bidding information be kept confidential.  At times such requirements may conflict and, in such cases, decision on the information to be released is made on a case-by-case basis.

An Order of the Commission in Docket 08-0519 also requires that information related to winning quantities be released at the time of Commission approval as long as there are at least three winning bidders in a procurement event. The condition of at least three winning bidders applies to the release of winning quantities and does not apply to the release of information about winning bid prices or the names of the winning Bidders.

08-29-2017

FAQ-W&S-207
Q: Are winning bidders required to provide the Collateral Requirement under the REC Contract as a condition of the return of the bid assurance collateral?

Yes, it is one of the conditions. If the Project is selected and is approved by the Commission, the bid assurance collateral can only be returned once all REC Contracts are executed, any Collateral Requirement under each REC Contract is posted, and the Supplier Fees are paid.  Supplier fees are due seven business days after the Commission decision.

08-29-2017

FAQ-W&S-208
Q: Does the $450,000 cap apply to both bid assurance collateral and the Collateral Requirement?

The $450,000 cap that you reference is a maximum that applies solely to bid assurance collateral. As stated in FAQ-W&S-183, there is no cap on the Collateral Requirement under the REC Contract as it depends on the Annual Contract Value. The annual contract value is the winning bid price times the annual quantity.  The Collateral Requirement under the terms of the REC Contract increases to 100% of the Annual Contract Value for a Company on June 1, 2019. The increase occurs regardless of when the project becomes operational or when the first REC is delivered.

08-29-2017

FAQ-W&S-209
Q: At the Part 1 stage we were presenting Proposals for multiple Projects. We are moving to the Part 2 stage with a single Project. Does the requirement for the Bidder and Seller names to be the same if presenting a single Project apply retroactively to the Part 2 Proposal so that we have to change the Bidder name?

The name of the Bidder provided in the Part 1 Proposal must be maintained in the Part 2 Proposal even if there is a change in circumstances whereby the Bidder is now presenting a single Project and the Seller is different from the Bidder.

08-29-2017

FAQ-W&S-210
Q: We were presenting Proposals for several Projects at the Part 1 stage and we are not proceeding to all those Projects at the Part 2 stage. How can I make sure that I am using the right account numbers corresponding to the Projects that we want to present at the Part 2 stage?

Please contact the Procurement Administrator directly by email for instructions.

08-29-2017

FAQ-W&S-211
Q: Can we use cash posted as bid assurance collateral toward meeting the Collateral Requirement under the REC Contract?

The return of cash tendered as bid assurance collateral can only occur after the REC Contract is fully executed, the Collateral Requirement has been met, and the Supplier Fees have been paid. If the cash posted as bid assurance collateral were used for the Collateral Requirement, there would be no bid assurance collateral to serve as guarantee for payment of the Supplier Fees by the Bidder or Seller.  In other words, the Collateral Requirement must be posted prior to the time when the bid assurance collateral can be fully released.  For that reason, a Bidder that submitted cash as bid assurance collateral also was required to submit a request for each Company for the return of cash for the full amount of the bid assurance collateral.

08-30-2017

FAQ-W&S-212
Q: Suppose a Bidder is submitting Proposals for multiple Projects and the Bidder posts a single pre-bid letter of credit for each Company or provides a single deposit to each Company as bid assurance collateral. The amount of bid assurance collateral is at the maximum. What happens if a draw is required on the bid assurance collateral because of an issue with a single Project, for example because the Seller for that Project fails to execute the REC Contract? What happens if draws are required for multiple Projects – would it be possible that, after draws for the first Projects, there would be no more bid assurance collateral left for a later draw for another Project?

If bid assurance collateral provided for multiple Projects was at the maximum for each Company and a draw is required on the bid assurance collateral for one of the Projects, the amount of the draw would not exceed the amount that would have been required as bid assurance collateral for that Project alone. If draws are required for multiple Projects, it would be known before the draws are made that multiple draws are required for multiple Projects.  In that case, the entire amount of the bid assurance would be drawn and assigned to each Project proportionately (proportionately to the amounts that would have been required as bid assurance collateral for each Project separately).

To the extent that the reason for the draw on the letter of bid assurance collateral is a failure of the Seller to execute the REC Contract, we remind you that in the P2 Certifications Insert (#P2-4), required by the Part 2 Proposal, the Officer of the Seller has acknowledged and certified that if the Seller’s Bid on the Project is approved by the Commission, the Seller WILL execute the REC Contracts with the Companies as instructed by the Procurement Administrator. Failure to do so is a failure to abide by one of the central representations and requirements of the Proposal.

Please also note that there could well be other consequences to the Seller of failing to execute a contract for a Project selected through an IPA procurement event and approved by the Commission (in addition to forfeiture of bid assurance collateral). The Procurement Administrator expects that such a Project could not be bid again in a future initial forward procurement event.  Furthermore, the IPA expects to release a draft Long-Term Renewable Resources Procurement Plan in September 2017, which will be subject to review by the Illinois Commerce Commission. It is possible that eligibility criteria for procurement events or programs under this Long-Term Renewable Resources Procurement Plan would be proposed to include whether a Bidder or Seller has previously failed to execute a contract for a Project that was selected through an IPA procurement event and approved by the Commission.

08-30-2017

FAQ-W&S-213
Q: Suppose a Bidder is submitting Proposals for multiple Projects and the Bidder posts a single pre-bid letter of credit for each Company or provides a single deposit to each Company as bid assurance collateral. The amount of bid assurance collateral is at the maximum. If a draw is required on the bid assurance collateral because of an issue with a single Project, how is the refund of bid assurance collateral handled for the other Projects?

If bid assurance collateral provided for multiple Projects was at the maximum and a draw is required on the bid assurance collateral for one of the Projects, the amount of the draw would not exceed the amount that would have been required as bid assurance collateral for that Project alone. The rest of the bid assurance collateral could be returned.  If submitted as cash, the Seller would be required to submit a new request for return of cash to each Company for the appropriate amount (given that the return of cash letters provided with the Part 2 Proposal are for the full amount of the cash deposit).

08-30-2017

FAQ-W&S-214
Q: Is each Company going to definitely be allocated some amount of the RECs, regardless of whether the RECs come from Projects in MISO or PJM? I understand the evaluation is on price only, but I am wondering if there is there any distinction between PJM and MISO RECs.

Whether the Project is in PJM or MISO, the tracking system for the RECs of the system in no way affects the allocation of RECs to the Companies.  As announced by the Procurement Administrator on August 29, the RECs from a Project that is selected through the Wind and Solar RFP and that is approved by the Illinois Commerce Commission will be allocated to the Companies in the following proportions:  29.33% to AIC, 70.34% to ComEd, and 0.33% to MEC.  Thus, there will be three REC Contracts for each selected Project, one with each of the three Companies.

08-30-2017

FAQ-W&S-215
Q: Are the Annexes supposed to be included with the Pre-Bid Letters of Credit that we send to the Companies? If so, how should we complete Paragraph 3 of Annex 1 (asking for the “reason” from conditions (a) – (d) of Paragraph 2 of the Pre-Bid Letter of Credit)?

The Annexes are an integral part of the Pre-Bid Letter of Credit and must be included. However, the Annexes should not be filled out.  For example, Paragraph 3 in Annex 1 should be left blank at this time. This paragraph would be completed by the Company if drawing under the Pre-Bid Letter of Credit.

08-30-2017

FAQ-W&S-216
Q: Where does the bidder training take place?

There is no venue for the bidder training. There is time set aside for bidder training during which the Procurement Administrator is available to answer questions from Bidders regarding the bid submission procedure.  Technical assistants are available to go over all aspects of the bid submission procedure with Bidders.

You may provide a specific time at which you wish a member of the Procurement Administrator team to phone you for this training. Instructions on the bid submission procedures and confidential information necessary to submit your Bids were provided with your Part 1 Notification.

08-30-2017

FAQ-W&S-217
Q: The entity to which we wanted the cash to be returned is newly formed and cannot get a W-9. Would it be acceptable to have the cash returned to another entity or alternatively would it be acceptable for the W-9 to be provided at a later date?

If providing bid assurance collateral in the form of cash for a Company, a Bidder must provide a W-9 with the Part 2 Proposal, for the entity to which will be returned the cash tendered as bid assurance collateral. A W-9 must be provided for the same entity and cannot be supplied at a later date.  If the Seller (or Bidder) is newly formed and a W-9 cannot be obtained for that entity, the return of cash letter can name another entity (such as the parent company of the Bidder) as long as the W-9 is provided for that same entity with the Part 2 Proposal.

08-30-2017

FAQ-W&S-218
Q: Do we have the opportunity to make changes to the Contract Insert if our Project is selected?

If the Procurement Administrator notifies the Bidder that the Bid on the Project is being identified as a winning Bid to the Commission, the Bidder will have until 12PM (noon) on the day after the Bidder is notified to provide any changes to the information required by the Contract Insert (#P2-5). The Procurement Administrator expects to notify the Bidder whether its Bids on the Projects are identified as winning Bids by 6 PM on the Bid Date.

08-30-2017

FAQ-W&S-219
Q: We are providing cash as bid assurance collateral but we are also working with a bank to issue the Pre-Bid Letters of Credit. If we are successful in issuing the Pre-Bid Letters of Credit, can we have the previously posted cash returned to us?

If you submitted cash to a Company, including the request for return of cash, and you later provide a Pre-Bid Letter of Credit that is acceptable to the Company, you may request that the Procurement Administrator forward your request for return of cash to the Company.

08-30-2017

FAQ-W&S-220
Q: We have received the results of the Companies’ assessment of our proposed modifications to the Post-Bid Letter of Credit. Can we provide further modifications for review?

The window to propose modifications to the Post-Bid Letter of Credit is the period for submission of the Part 1 Proposals.  The Wind and Solar RFP does not contemplate multiple rounds of comments provided by Bidders, and the Companies will not consider additional modifications that are submitted outside of the Part 1 Window.

Please consult the final list of modifications to the Post-Bid Letter of Credit that are acceptable to the Companies on an optional basis, posted to the Final Materials page of the Wind and Solar section of the procurement website.

08-30-2017

FAQ-W&S-221
Q: Can you confirm that the letters of credit that we should use during the REC Contract are those that were posted on July 18, 2017?

No, there was an update to the letters of credit posted on July 18, 2017.  Please use the Post-Bid Letters of Credit posted to the Final Materials page of the Wind and Solar section of the procurement website and dated August 29, 2017.  These versions include an update to the definition of S&P.  You may also use any of the modifications acceptable to the Companies and posted to the top of the same page of the procurement website.

08-30-2017

FAQ-W&S-222
Q: Can you confirm that the beneficiary information for the Companies have not changed from the instructions provided for the Pre-Bid Letters of Credit?

The Procurement Administrator is in the process of determining whether the beneficiary information is the same as for the Pre-Bid Letters of Credit and will provide a further communication in this regard as soon as the information is available.

08-30-2017

FAQ-W&S-223
Q: Is it possible that the IPA will be awarding more than 200,000 RECs for solar Projects?

No, the IPA will not be awarding more than 200,000 RECs for solar Projects.  The IPA will be awarding up to 200,000 RECs but not exceeding 200,000 RECs for solar Projects.

08-30-2017

FAQ-W&S-224
Q: Is the counterparty under the REC Contract required to have a Dun and Bradstreet number? Can you please contact me? I have other questions regarding the Contract Insert.

The counterparty under the REC Contract is not required to have a Dun and Bradstreet number. We will contact you regarding your additional questions regarding the completion of the Contract Insert if the Bid on your Project is identified as a winning Bid to the Commission.

08-30-2017

FAQ-W&S-225
Q: Can a solar Project offer more than 200,000 RECs in this first initial forward procurement?

The offer needs to be capped at 200,000 RECs for a solar Project.  An offer greater than 200,000 RECs will be rejected.

08-30-2017

FAQ-W&S-226
Q: Can you please clarify whether all Projects with winning bids selected through the current procurement event under Wind and Solar RFP will have three contracts or only some of them?

ALL PROJECTS with winning bids selected through the current procurement event under the Wind and Solar RFP and that are approved with the Commission will have three contracts, one with each Company (AIC, ComEd, and MEC).  The REC Contract is the same for all Companies.

08-30-2017

FAQ-W&S-227
Q: When will we receive payment instructions for the Supplier Fees?

Payment instructions will be sent to winning Bidders at the time of the Commission decision.

08-30-2017

FAQ-W&S-228
Q: Will the IPA consider repowered facilities as “new” projects for purposes of the upcoming procurement event under the Wind and Solar RFP?

No.  Section 1-75(c)(1)(G) of the IPA Act (20 ILCS 3855) provides statutory authority only for the IPA to conduct “initial forward procurements” of RECs from “new utility-scale wind projects” and “new utility-scale solar projects and brownfield site photovoltaic projects.”  Section 1-75(c)(1)(C)(iii) defines new wind and solar “projects” as “renewable generating facilities,” while Section 1-10 of the IPA Act defines a “facility” 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 many repowered facilities would feature a substantial portion of what by law constitutes the “facility” as something other than “new,” they would be disqualified from participation in the initial forward procurements.  However, as any repowered facilities (even those with entirely new components) would be competing for selection on the basis of price with facilities representing entirely incremental generation first “energized” after the effective date of Public Act 99-0906, the IPA does not consider repowered projects with “new” components to be “new” projects that qualify for the initial forward procurement.  Providing an incentive for existing generation to simply repower more efficiently would be inconsistent with statutory authority encouraging the development of “new” projects to “to diversify Illinois electricity supply, avoid and reduce pollution, reduce peak demand, and enhance public health and well-being of Illinois residents” (20 ILCS 3855/1-75(1-5)(6)), as the incremental benefits offered to Illinois residents by a repowered project would be significantly less than those offered by an entirely new facility.

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.

08-30-2017

FAQ-W&S-229
Q: We would like to request the ability to make further changes to the Pre-Bid Letters of Credit based on a request from our issuing bank. What is the process to have those further changes considered out-of-time (i.e., after the Part 1 Proposal process is complete and the final document containing the acceptable modifications has been posted)?

The final document containing the acceptable modifications to the Pre-Bid Letter of Credit for each Company includes all modifications reviewed and accepted during the Part 1 Proposal process. No further modifications will be considered by the Companies.  This document is posted to the Final Materials page of the Wind and Solar section of the procurement website.

If you elect to submit your bid assurance collateral as a Pre-Bid Letter of Credit for a Company, you must use the Standard Pre-Bid Letter of Credit for that Company provided as an appendix to these RFP Rules or include only those modifications to the Standard Pre-Bid Letter of Credit acceptable to that Company and posted to the procurement website.

08-31-2017

FAQ-W&S-230
Q: Our bank is not entirely comfortable with certain provisions of the Letter of Credit. Can you provide some examples of banks that have accepted the current form?

The Procurement Administrator is not able to provide this information but appreciates the feedback. The Procurement notes that there are modifications acceptable to the utilities and posted on the procurement website. A winning supplier always has the option to post cash as security for the period during which it is finding an Issuing Bank for its Letter of Credit.

10-11-2017

FAQ-W&S-231
Q: If we win a partial award, how much time do we have to accept or reject the award?

A Bidder with a partial award can expect to be notified that its Bids are identified as winning Bids to the Commission on the Bid Date. Should the Commission accept the results of the procurement event, which typically would occur four (4) business days after the Bid Date, the Bidder at that time would have the option to accept or reject the partial award and must notify the Procurement Administrator of its decision.

10-11-2017

FAQ-W&S-232
Q: If we bid on some but not all of our Projects, will the Projects for which we do not submit Bids automatically be pulled from further consideration in the W&S RFP? Will the bid assurance collateral for the Projects that were not bid be returned first?

A Project for which a Bid is not submitted is automatically pulled from further consideration in the W&S RFP. Bid assurance collateral is returned for all Projects presented at once and not on a project-by-project basis.

10-11-2017

FAQ-W&S-233
Q: What is the collateral requirement due to each utility? Is it $1.2M and if so how is it divided among the utilities?

As noted in the announcement to Bidders on August 29, the RECs from a Project that is selected through the Wind and Solar RFP and that is approved by the Illinois Commerce Commission will be allocated to the Companies in the following proportions:  29.33% to AIC, 70.34% to ComEd, and 0.33% to MEC.

The Collateral Requirement due upon contract execution with a utility is 50% of the annual contract value for that utility. The contract value is the winning bid price times that number of RECs for that utility.

10-11-2017

FAQ-W&S-234
Q: Should we contact the utilities directly with questions about the eligibility of our guarantor?

Yes, representatives from the utilities, during the contract execution process, can respond to your questions regarding the eligibility of your guarantor.

10-11-2017


Zero Emission Credits FAQs
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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

FAQ-Gen-18
Q: Are the questions submitted via this portal public or private?

The Procurement Administrator responds to questions directly to the questioner. The question and answer are then posted to the FAQs page of the procurement website so that all interested parties have access to the same information. Aspects of the question and/or answer that might identify the questioner are removed before posting, to the extent practicable.

08-04-2017

FAQ-Gen-19
Q: Does the Procurement Administrator make available the slides from bidder information webcasts?

Yes, for each procurement event for which a bidder information webcast is held, the presentation and audio recording are posted to the Final Materials page of the applicable section of the website.

09-18-2017

FAQ-Gen-20
Q: Are the responses for questions asked during the bidder information webcast posted to the website?

Yes, questions received during the bidder information webcast and responses provided are posted to the FAQ page of the IPA procurement website under the appropriate section for the RFP.

09-18-2017

FAQ-Gen-21
Q: Has a schedule been announced for future procurements of utility-scale solar? If not how can I get information in the future?

No schedule has yet been announced for future procurements of utility-scale solar. The Fall Utility DG RFP is for systems limited in size to 2 MW.  Please see:

https://www.illinois.gov/sites/ipa/Pages/Plans-Under-Development.aspx

for information about the IPA’s plan under development. You may also register to receive announcements from the Procurement Administrator by registering here:

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

09-26-2017

FAQ-Gen-22
Q: If we are unable to meet a deadline set by the Procurement Administrator because of special, extraordinary circumstances, how should we proceed?

Please contact the Procurement Administrator if you will not be able to meet a deadline because of special and extraordinary circumstances.

10-04-2017

FAQ-Gen-23
Q: How can I register to receive announcements about upcoming RFPs?

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

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

10-11-2017