Solicitation Amendment 47PA0422R0003_0001 signed.pdf

Offers must acknowledge receipt of this amendment prior to the hour and date specified in the solicitation or as amended, by one of the following methods:

(a) By completing items 8 and 15, and returning or (c) By separate letter or electronic communication which includes a reference to the solicitation and amendment numbers. FAILURE OF YOUR ACKNOWLEDGMENT TO BE RECEIVED AT THE PLACE DESIGNATED FOR THE RECEIPT OF OFFERS PRIOR TO THE HOUR AND DATE SPECIFIED MAY RESULT IN REJECTION OF YOUR OFFER. If by virtue of this amendment you desire to change an offer already submitted, such change may be made by letter or electronic communication, provided each letter or electronic communication makes reference to the solicitation and this amendment, and is received prior to the opening hour and date specified.

E. IMPORTANT: Contractor is not is required to sign this document and return copies to the issuing office.

AMENDMENT OF SOLICITATION/MODIFICATION OF CONTRACT 1. CONTRACT ID CODE

2. AMENDMENT/MODIFICATION NUMBER 3. EFFECTIVE DATE 4. REQUISITION/PURCHASE REQUISITION NUMBER 5. PROJECT NUMBER (If applicable)

7. ADMINISTERED BY (If other than Item 6) CODE

STANDARD FORM 30 (REV. 11/2016)

Prescribed by GSA FAR (48 CFR) 53.243

FACILITY CODE

9A. AMENDMENT OF SOLICITATION NUMBER

9B. DATED (SEE ITEM 11)

10A. MODIFICATION OF CONTRACT/ORDER NUMBER

10B. DATED (SEE ITEM 13)

11. THIS ITEM ONLY APPLIES TO AMENDMENTS OF SOLICITATIONS

The above numbered solicitation is amended as set forth in Item 14. The hour and date specified for receipt of Offers is extended. is not extended.

12. ACCOUNTING AND APPROPRIATION DATA (If required) copies of the amendment; (b) By acknowledging receipt of this amendment on each copy of the offer submitted;

13. THIS ITEM APPLIES ONLY TO MODIFICATIONS OF CONTRACTS/ORDERS.

IT MODIFIES THE CONTRACT/ORDER NUMBER AS DESCRIBED IN ITEM 14.

CHECK ONE A. THIS CHANGE ORDER IS ISSUED PURSUANT TO: (Specify authority) THE CHANGES SET FORTH IN ITEM 14 ARE MADE IN THE CONTRACT ORDER

NUMBER IN ITEM 10A.

B. THE ABOVE NUMBERED CONTRACT/ORDER IS MODIFIED TO REFLECT THE ADMINISTRATIVE CHANGES (such as changes in paying office, appropriation data, etc.) SET FORTH IN ITEM 14, PURSUANT TO THE AUTHORITY OF FAR 43.103(b).

C. THIS SUPPLEMENTAL AGREEMENT IS ENTERED INTO PURSUANT TO AUTHORITY OF:

D. OTHER (Specify type of modification and authority)

Except as provided herein, all terms and conditions of the document referenced in Item 9A or 10A, as heretofore changed, remains unchanged and in full force and effect.

15C. DATE SIGNED

15A. NAME AND TITLE OF SIGNER (Type or print)

16C. DATE SIGNED

16A. NAME AND TITLE OF CONTRACTING OFFICER (Type or print)

14. DESCRIPTION OF AMENDMENT/MODIFICATION (Organized by UCF section headings, including solicitation/contract subject matter where feasible.)

PAGE OF PAGES

6. ISSUED BY CODE

8. NAME AND ADDRESS OF CONTRACTOR (Number, street, county, State and ZIP Code) (X)

CODE

15B. CONTRACTOR/OFFEROR

(Signature of person authorized to sign)

16B. UNITED STATES OF AMERICA

(Signature of Contracting Officer)

Previous edition unusable

PMAA

Jennifer Smith, Supervisory Contract Specialist

1) GSA has provided responses to questions received in a Questions and Answers document which is hereby incorporated by reference.

2) The Exhibit 1 file has been updated, all updates are listed in the "Updates" sheet of the attached Amendment 1 Exhibit 1.

3) The due date for offers has been extended to March 30, 2022 at 3:00pm Eastern.

PMAA

GSA, Energy Division 1800 F Street, NW, Room 5118 Washington, DC 20405 USA

GSA, Energy Division 1800 F Street, NW, Room 5118 Washington, DC 20405 USA

EQPMAA-22-0041

47PA0422R0003

1 2

3/24/2022

3/9/2022

DocuSign Envelope ID: 1E76AA34-C269-48BA-BF46-6EBC7C12B288

3/24/2022

INSTRUCTIONS (Back Page):

Instructions for items other than those that are self-explanatory, are as follows:

Item 1 (Contract ID Code). Insert the contract type identification code that appears in the title block of the contract being modified.

Item 3 (Effective date).

(1)

(2)

(3)

(4)

(5)

For a solicitation amendment, change order, or administrative change, the effective date shall be the issue date of the amendment, change order, or administrative change.

For a supplemental agreement, the effective date shall be the date agreed to by the contracting parties.

For a modification issued as an initial or confirming notice of termination for the convenience of the Government, the effective date and the modification number of the confirming notice shall be the same as the effective date and modification number of the initial notice.

For a modification converting a termination for default to a termination for the convenience of the Government, the effective date shall be the same as the effective date of the termination for default.

For a modification confirming the contracting officer's determination of the amount due in settlement of a contract termination, the effective date shall be the same as the effective date of the initial decision.

(a)

(b)

(c)

(d)

(e)

(f)

Item 6 (Issued By). Insert the name and address of the issuing office. If applicable, insert the appropriate issuing office code in the code block.

Item 8 (Name and Address of Contractor). For modifications to a contract or order, enter the contractor's name, address, and code as shown in the original contract or order, unless changed by this or a previous modification.

Items 9, (Amendment of Solicitation Number - Dated), and 10, (Modification of Contract/Order Number - Dated). Check the appropriate box and in the corresponding blanks insert the number and date of the original solicitation, contract, or order.

Item 12 (Accounting and Appropriation Data).

When appropriate, indicate the impact of the modification on each affected accounting classification by inserting one of the following entries:

(2) Accounting classification Net decrease $

Include subject matter or short title of solicitation/contract where feasible.

Item 16B. The contracting officer's signature is not required on solicitation amendments. The contracting officer's signature is normally affixed last on supplemental agreements.

(i)

NOTE: If there are changes to multiple accounting classifications that cannot be placed in block 12, insert an asterisk and the words "See continuation sheet".

Item 13. Check the appropriate box to indicate the type of modification. Insert in the corresponding blank the authority under which the modification is issued. Check whether or not contractor must sign this document. (See FAR 43.103.)

Item 14 (Description of Amendment/Modification).

Organize amendments or modifications under the appropriate Uniform Contract Format (UCF) section headings from the applicable solicitation or contract. The UCF table of contents, however, shall not be set forth in this document.

Indicate the impact of the modification on the overall total contract price by inserting one of the following entries:

(i) Total contract price increased by $

(ii) Total contract price decreased by $

(iii) Total contract price unchanged.

State reason for modification.

When removing, reinstating, or adding funds, identify the contract items and accounting classifications.

(g)

(h)

When the SF 30 is used to reflect a determination by the contracting officer of the amount due in settlement of a contract terminated for the convenience of the Government, the entry in Item 14 of the modification may be limited to --

(i) A reference to the letter determination; and

(ii) A statement of the net amount determined to be due in settlement of the contract.

(1)

(2)

(3)

(4)

(5)

(6)

STANDARD FORM 30 (REV. 11/2016) BACK

(1) Accounting classification Net increase $

47PA0422R0003 GSA DC/MD Competitive Electricity Questions and Answers

Received as of 3:00 PM ET Friday March 18, 2022

PER SF30 AMENDMENT 1 AND SECTION C.3 OF THE AMENDMENT 1 VERSION OF THE SOLICITATION, THE DUE DATE

FOR TECHNICAL PROPOSALS HAS BEEN EXTENDED TO 3:00 PM EDT, MARCH 30TH 2022.

ANY CHANGES TO THE SOLICITATION AS A RESULT OF THE QUESTIONS ARE HIGHLIGHTED WITHIN THE ATTACHED

REVISED SOLICITATION.

QUESTIONS RECEIVED IN WRITING

1. Proposer requests the right to withdraw its price(s) at any time prior to bid being awarded.

Answer #1 – Confirmed. While GSA strongly encourages all offerors to hold their prices until 1:30 p.m. per the solicitation requirements, Offerors may withdraw bids up until a notice of award via email is sent to the Offeror.

2. Proposer requests the right to supplement or amend any of the questions, clarifications, or exceptions listed in this document.

Answer #2 – The Question and Answer period regarding solicitation terms and conditions closed at 3:00 PM EDT on March 18, 2022. If suppliers have additional account or data related questions those can be submitted until 5:00 PM EDT on April 6, 2022.

3. Please confirm how the documentation between Proposer, Government, and PPA/developers will look and when these will be completed. There would need to be some documentation governing the resultant transactions to accommodate Government’s request. If not completed prior to April 27th, there could be issues in aligning the Internal Bilateral Transactions (IBTs).

Answer #3 – Please see response to question 23 below.

4. Please provide copies of contracts GS-00P-15-BSD-1148 and GS-00P-14-BSD1016; these could not be located online. These will be instrumental to understanding what is happening and how to implement Government’s handling of the PPAs.

Answer #4 – Please see response to question 23 below.

5. The additional Renewable Power for Facilities appears to be 0% in the RFP, but 50% is listed for WMATA in

Exhibit 1. Please confirm this should be 0% and Section A.12 no longer applies.

Answer #5 – The Amendment 1 version of the Exhibit 1 has been updated to show 50% renewable for WMATA in all sheets. This update is noted in the “Updates” sheet of the Exhibit 1.

6. With respect to Page 4, Section A.12.(b), Renewable Power for Facilities in this Contract. Please verify it is understood that that title to the RECs should pass to the Government through retirement by Contactor once delivery and payment for the RECs have been completed and following the close of the calendar year.

Alternatively, please confirm that this section no longer applies.

Answer #6 – GSA confirms.

7. General clarification if there is Green-e ultimately part of the agreement for any groups: Please confirm that the Government will not offer for sale any RECs delivered by Proposer pursuant to this agreement.

Answer #7- GSA confirms.

8. With respect to Page 6, A. 17, Enel X fee: Proposer clarifies that any payments to Enel X will be pursuant to the terms and conditions of the Master Broker Agreement executed between Proposer and Enel X for any broker or administrative payments being collected or remitted.

Answer #8- Clarification Noted

9. With respect to Page 35, C.2. Price Proposal, subitem (4) – Proposer will accept an award letter on GSA’s letterhead, signed be the Contracting Officer, listing the price and term, referencing the solicitation and list of accounts. Please clarify that this will be the award process.

Answer #9- GSA Confirms

10. With respect to Page 37, D.3., Post Award Requirement for Small Business Subcontracting Plan, please verify it is understood that Proposer will not be utilizing subcontractors pursuant to this RFP.

Answer #10 – Clarification noted

11. Please confirm that damages are limited to direct, actual damages and that Proposer will not be liable for consequential or special damages.

Answer #11 – Solicitation language regarding damages remains unchanged.

12. Proposer requests the inclusion of the following provisions, which have been acceptable to the Government in connection with prior solicitation responses by Proposer: a. Miscellaneous. If in any circumstance Proposer does not provide notice of, or object to, any default on the Government’s part under this Agreement, such situation will not operate or be construed as a waiver of any future default, whether like or different in character.

b. Miscellaneous (cont’d). If any portion of this Agreement is held legally invalid, the remainder will not be affected and will be valid and enforced to the fullest extent permitted by law and equity, and there will be deemed substituted for the invalid provisions such provisions as will most nearly carry out our mutual intent as expressed in this Agreement.

c. Miscellaneous (cont’d). This Agreement contains the entire agreement between both Parties, supersedes any other agreements, discussions or understandings (whether written or oral) regarding the subject matter of this Agreement, and may not be contradicted by any prior or contemporaneous oral or written agreement.

d. Miscellaneous (cont’d). Proposer is an independent contractor under this Agreement, and nothing in this Agreement will be construed to constitute a joint venture, fiduciary relationship, partnership or other joint undertaking.

Answer #12 – Per solicitation Section C.2(7) The Government will not accept any exceptions to this solicitation which are inconsistent with the terms and requirements of this solicitation.

13. With regards to Attachment 3, which includes a Generator Registration Form as part of the Annual Renewable Report, would submission of this report by the Proposer be duplicative when facilities that are in RTOs submit their attestations to Green-e, and the Proposer’s third-party auditor follows Green-e protocol? In addition to the Proposer providing proof (via M-RETS/ERCOT/applicable EIS) of eligibility of the tracked facilities used to purchase the REC’s. Or does this Section no longer apply?

Answer #13 – The Government’s response is no. The solicitation specifies the awarded Offeror must provide all of the information specified in Attachments three (3), four (4) and five (5) are applicable for Pricing Group #5 so the Government can verify the source, vintage and number of Renewable Energy Credits purchased and retired on the Government’s behalf by the Contractor for the specific accounts included in this contract. See the Amendment 1 Version of the Solicitation and Exhibit 1, this also applies to new Pricing Group 6.

14. Proposer has not submitted data requests to PEPCO as we have not received LOAs. Proposer may have more data questions once this is completed.

Answer #14 – LOA’s can be obtained by reaching out in writing to the contracting officer.

15. We contacted PEPCO regarding cybersecurity as noted in A.21 for AOC. They returned with a question asking what we were referring to. Is all we need access to is historical summary usage, historical interval usage, and summary stats (such as meter cycle, tags, etc.)? What else do we need to work with PEPCO to get? The also implied this would be covered by the existing supplier coordination tariff, no different than any other retail load deal. Is there something unusual that is separate to effectuate this statement in the solicitation?

Answer #15 – Since the Combined Heat and Power (CHP) system was installed approx. May of 2018, the current supplier has not requested electronic access to export meter data log for billing and permit inspection of metering facilities. PEPCO furnishes a modem which transmits from (4) ports, one each primary and back-up for A-Buss and B-Buss. A2A Energy (referred to as the third party) is under contract with AOC to provide this data on a daily basis to PJM’s Power Meter System. AOC’s contract with the third party allows access for

(2) AOC users. This third party provides data to PJM and not the CPP energy supplier. The CPP energy supplier has a PJM settlement account so they can credit CPP. Periodic inspection of meter data would be possible for audit purposes, but this same information should be available to the PJM settlement account holder.

16. There are many kinds of subaccounts, and it is understood a retail load subaccount at an EDC is not required for

Group 1. As a market participant doing many IBTs each day, we have existing accounts at PJM to schedule different facilities already. Further setting up a new subaccount at PJM will take several weeks, which there is no time for given the award in mid-April and power flow in May. Please confirm Proposer can use its existing subaccount and breakout anything specific GSA may need.

Answer #16 – Yes, an existing subaccount is acceptable as long as it is dedicated for GSA’s PPAs. A comingled subaccount is not acceptable. GSA or its authorized agent will need read-only access to the subaccount to verify load, deliveries, and billing. See section A.20 Power Purchase Agreement Transaction Manager Scope of Services for Pricing Group One (1) for all requirements.

17. For Group 1, please confirm the PPA power flow is expected to start May 1 and end April 30, 2023. Please confirm the retail load will start online commensurate with the meter read dates for each service account.

Answer #17 – Correct, the Transaction Manager services will run from July 1, 2022 through April 30, 2023 and retail load will commence with the meter read dates.

18. Please confirm that Groups 2-4 are to be imported/exported on the Day Ahead market. They cannot be split between different markets.

Answer #18 – Imports and Exports are on the Real Time market. The solicitation has been amended, see updated Section A.21 Import / Export Scope of Services for Pricing Groups Two (2), Three (3) And Four (4).

19. Is each account for Groups 2, 3, and 4 expected to be a net consumer of electricity for each billing period? This appears to be the case in the last 12 months.

Answer #19 -

- HOTD is a monthly net consumer of electricity ONLY during our scheduled maintenance in April and October, and during unscheduled interrupts like the one we experienced during the recent December - March period.

For most months of the year we export more than we do import, the end result of which we are a net exporter on an annual basis.

- AOC should be a net importer.

- White Oak should break even on an annual basis. Whether they import or export power on a monthly basis may vary based on a number of factors including downtime for cogen maintenance.

The Contractor’s Supply Service Fee to manage these accounts must be included in the price in $ per kWh for all imported and exported power submitted during the auction for Pricing Groups 2, 3, and 4.

20. For Group 1, please confirm Transaction Manager is not responsible for any margining.

Answer #20 – GSA is unclear to your reference regarding margining, however the language in the solicitation regarding the Transaction’s Managers responsibilities remains unchanged.

21. For Group 1, Proposer’s parent company is a wholesale Market Participant at PJM and a different legal entity that might perform some of the requested services. Please confirm this is not an issue, and if it is, how this can be resolved.

Answer #21 – This is not an issue; however, ultimate responsibility for performance is the contract holder’s.

22. In Group 1, how would a check be presented to the Government if a credit is due? It is Proposer’s understanding that all checks to the Government must be made to the US Department of Treasury.

Answer #22 - Upon expiration of this contract, the Transaction Manager and GSA will settle any amounts due from one party to the other as a result of net credits received and charges paid from the PPAs and any unpaid invoicing resulting from the Contract (the “Winding Up Arrangement”). If applicable, within 60 days or another mutually agreed to reasonable period of time following expiration of the contract, the Transaction Manager will present GSA with the Winding Up Arrangement. Prior to this, GSA will provide the Transaction Manager with information on how payments will be made.

23. For Group 1, please provide a redacted sample of the agreement between GSA, the current provider, and the project entities that governs the transactions directed in A.20.

Answer #23 – No, the agreements cannot be posted at this time. However, the winning bidder will be provided with a copy of each agreement immediately after award.

24. Please provide a redacted sample of an invoice/bill/payment for Group 1 from the current Transaction Manager to GSA.

Answer #24 – Billing for Group 1 is consolidated through Pepco.

25. Is the Transaction Manager required to actually exchange funds with the plant owners in accordance with the settlement provisions of the PPAs; in effect the supplier would be sleeving the PPAs on behalf of GSA?

Answer #25 – The Transaction Manager is required to take the PPA power, pay GSA's obligations under each of the PPAs, and then bill GSA for the net of the PPA power prices and value of the PPA power delivered to the Transaction Manager.

Great Bay PPA – GSA shall pay Seller for GSA's Portion of the Renewable Energy delivered to Buyer by Seller to the Point of Delivery at a price equal to the then applicable rate set forth in Exhibit D ("Renewable Energy Payment Rate"). The Renewable Energy Payment Rate includes an annual escalator and is expressed as $/MWh.

Walnut Ridge Wind PPA – GSA shall pay Seller for GSA's Portion of the Renewable Energy delivered to GSA by Seller to the Point of Delivery at a price equal to the then applicable rate set forth in Exhibit D ("Renewable Energy Payment Rate"). The Renewable Energy Payment Rate includes an annual escalator and is expressed as $/MWh.

As stated in A.20 Power Purchase Agreement Transaction Manager Scope of Services for Pricing Group One (1), GSA shall have Walnut Ridge Wind Farm deliver to GSA’s PJM Generation Asset Tracking System (“PJM GATS”) account all RECs generated by the energy resource over the life of this contract. GSA will provide the winning bidder with GSA’s PJM GATS account number immediately after award.

26. Who handles any PPA Settlement dispute resolution? Would the Transaction Manager simply support GSA as may be required in GSA’s efforts to reconcile PPA settlements with the generators, or would the Transaction Manager be required to engage directly with the generators to achieve reconciliation?

Answer #26 – The Transaction Manager will support as needed GSA’s efforts to reconcile PPA settlements with the generators.

27. Can we get basic descriptions of the PPAs (i.e. as-generated?, fixed shape? fixed price, swap with floor price?, or

???). Are there any availability guarantees/penalties, if so what data is required to do the availability penalty calculations?

Answer #27 – See response to questions 25, 42, and 61.

28. Is there any contractual limitation to how much energy GSA might want the dedicated sub-account to absorb (in addition to the PPA related energy)?

Answer #28 – No, there is no contractual limitation to how much energy GSA might want the dedicated sub-account to absorb; however, over the next 12 months GSA does not anticipate any changes.

29. Is there any contractual limitation to how many different bilateral schedules might be required in addition to the

PPA related energy bilateral schedules?

Answer #29 - No, there is no contractual limitation to how many different bilateral schedules might be required in addition to the PPA related energy bilateral schedules; however, over the next 12 months GSA does not anticipate signing any new PPAs that will need to be scheduled into the subaccount.

30. As regards physical delivery using bilateral schedules, sooner or later there will be a mistake (e.g. one party might schedule, but the other will not) and therefore the energy will not flow. In such a case who is responsible for the financial consequence of not scheduling. Can the financial consequence be settled by simply exchanging dollars (as would typically be the case). Or would a scheduling error of this sort be corrected as part of the dollar exchange at the end of the contract?

Answer #30 – Since the power is scheduled by the PPA vendors, any mistake in power scheduling is resolved between the PPA vendor(s) and GSA. Resolution is typically via financially adjusting the applicable bill from the PPA vendor.

31. Would GSA require that the Transaction Manager schedule a greater quantity of outbound energy than inbound energy for any hour?

Answer #31 – No. The PPA vendor schedules all of the power via internal bilateral schedules and the volume scheduled should match resource output.

32. In reference to the “third-party invoiced amount”. Who is the third party and what does the third party have to do with the supplier?

Answer #32 – The third-party referenced in the “third-party invoiced amount” refers to either the Great Bay PPA or Walnut Ridge Wind PPA vendor.

33. What data will the generators provide to the Transaction Manager?

Answer #33 – The PPA vendors will provide information necessary for the Transaction Manager to enter into a standard for PJM wholesale transactions with counterparties agreement and data necessary for the Transaction Manager to perform the required scope of services contained in Section A.20 Power Purchase Agreement Transaction Manager Scope of Services for Pricing Group One (1),

34. Does the retail load associated with GSA also reside in the same dedicated sub-account account?

Answer #34 – GSA does not require that GSA’s retail load reside in a dedicated PJM subaccount nor the same dedicated PJM subaccount as GSA’s PPAs.

35. Section A.20. Will the GSA require the load associated in Group 1 to be enrolled in the same subaccount to be set up for the Transaction Manager?

Answer #35 – See response to question 34.

36. Attachment 2 Component Table Group 1. The Full Scope of Services references section A.21, is that incorrect?

Should the reference be A.20?

Answer #36 – Yes, Attachment 2 Component Table Group 1 should reference section A.20. The solicitation has been amended, see updated Attachment 2.

37. Attachment 2 Component Table Groups 2, 3, 4. The Full Scope of Services references section A.20, is that incorrect? Should the reference be A.21?

Answer #37 – Yes, Attachment 2 Component Table Groups 2, 3, and 4 should reference section A.21. The solicitation has been amended, see updated Attachment 2.

38. Is one dedicated PJM subaccount sufficient to accommodate the two separate PPA agreements?

Answer #38 – Yes, one dedicated PJM subaccount for both of GSA’s PPAs is acceptable. Please see response to questions 16, 34, and 54.

39. Can an existing PJM subaccount be used for Transaction Manager services, or does a new dedicated subaccount have to be created?

Answer #39 - Yes, an existing subaccount is acceptable as long as it is dedicated for GSA’s PPAs. That can be a new account or an existing account. A comingled subaccount is not acceptable. GSA or its authorized agent will need read-only access to the subaccount to verify load, deliveries, and billing. See Section A.20 Power Purchase Agreement Transaction Manager Scope of Services for Pricing Group One (1) for all requirements.

40. Will the projects be participating in the capacity auctions? If so, who will be bidding the capacity? Is the Transaction Manager expected to manage the projects’ participation in capacity auctions?

Answer #40 – No, the Transaction Manager is not expected to manage the projects’ participation in capacity auctions.

41. Will RPM credits/charges flow through the subaccount?

Answer #41 – No, reliability pricing model (RPM) credits will not flow through to the dedicated PJM subaccount. The Transaction Manager will not have to deal with RPM credits resulting from the 2 PPA resources as these are associated with the capacity market and GSA does not own capacity rights from the 2 resources.

42. Who will be scheduling the solar projects? Is scheduling part of the Transaction Manager duties?

Answer #42 - PPA loads are scheduled to the Transaction Manager’s (i.e., winning bidder's) separate/segregated PJM subaccount via internal bilateral transactions (IBTs).

Great Bay Solar PPA - GSA’s Portion of Renewable Energy shall be transferred to GSA or GSA's Transaction Manager via bilateral transactions scheduled through PJM's "InSchedule" system or its successor or replacement systems.

Great Bay Solar PPA - Seller agrees to cooperate with GSA or GSA's Transaction Manager with respect to the scheduling of delivery of the Renewable Energy hereunder so that potential PJM penalties and similar charges may be reduced; provided, however, that such cooperation shall not (i) reduce or adversely affect Seller's ability or rights to deliver Renewable Energy to the Point of Delivery or GSA's obligation to accept and pay for same; (ii) require Seller to incur any costs and expenses; and (iii) cause any increase in electrical line losses for the Facility.

Walnut Ridge Wind PPA – GSA’s Portion of Renewable Energy shall be transferred to Buyer or Buyer's Transaction Manager via bilateral transactions scheduled through PJM's "InSchedule" system or its successor or replacement systems.

Walnut Ridge Wind PPA - Seller agrees to cooperate with GSA or GSA's Transaction Manager with respect to the scheduling of delivery of the Renewable Energy hereunder so that potential PJM penalties and similar charges may be reduced; provided, however, that such cooperation shall not (i) reduce or adversely affect Seller's ability or rights to deliver Renewable Energy to the Point of Delivery; (ii) require Seller to incur any costs and expenses and (iii) cause any increase in electrical line losses for the Facility.

43. Our understanding of the import/export services is that the three accounts in groups 2 to 4 are Net Metering accounts where they will be generating electricity and expecting to be paid when they are net exporters and to pay when they are net importers. Is that interpretation correct?

Answer #43 – Yes, that is correct.

44. Per A.21 The contractor is to purchase 100% of the electricity exports. What pricing mechanism will be used to determine the prices for those purchases? PJM LMPs – day ahead or real time?

Answer #44 – See response to question 18.

45. The supplier fee (including Enel X’s fee) is a $ per kWh rate. Will this be applied to the net consumption? If so, how will the fee be collected if the accounts are net exporters?

Answer #45 – Enel X’s fee must be included in the Contractor’s Supply Service Fee to manage these accounts.

The Service Fee is in $ per kWh is assessed against all imported and exported power for Pricing Groups 2, 3, and 4.

46. Are the accounts expected to be net exporters or net importers?

Answer #46 - See response to question 19.

47. Will the historical generation (export) data for the accounts in groups 2-4 be made available?

Answer #47 - Currently, Exhibit 1 only contains the usage data (imported electricity) for Price Groups 2, 3, and 4 is not provided in Exhibit 1. As part of Amendment 1, GSA is providing separate files with historical generation (export) data for the accounts in Groups 2 -4.

48. Relative to historical generation, are there any expected changes to the generation (exports) going forward?

Answer #48 –

- HOTD – No expected major changes to generation (exports) at this time for the 24 month term that will be included in the new contract.

- AOC – No expected major changes to generation (exports) at this time for the 24 month term that will be included in the new contract.

- White Oak – No expected major changes to generation (exports) at this time for the 24-month term that will be included in the new contract.

49. Can you please confirm that the data under “historical usage” provided in Exhibit 1 for Pricing Groups 2 through 4 is the net metered usage (load minus exports)?

Answer #49 – See response to question 47.

50. Is the current 12-month HU reflective of any COVID impacts?

Answer #50 – GSA currently does not have past or future estimates regarding load reduction for our facilities at this time but it can be expected to see reduced demand in buildings that have closed or operating at reduced occupancy. A full list of GSA closures and operating status can be found: https://www.gsa.gov/governmentwide-initiatives/emergency-response/facilities-status-and-information-overview "

51. Are there any expected COVID impacts going forward? If so, what’s the estimated usage reduction?

Answer #51 – See response to question 50.

52. Does GSA expect to utilize any onsite generation during the duration of the contract? If so, what is the expected usage impact and for what accounts?

Answer #52 – GSA is not aware of any additional behind the meter generation assets planned for the installations included in this solicitation other than those noted in the Exhibit 1 file.

53. Group 1, will you provide the PPA pricing and expected output so we can bid an auction price for the firm power? Or the PPAs are settled against the firm price we provide as a CFD?

Answer #53 – Yes, as part of Amendment 1, historical output for the PPAs is being provided in a separate file.

For the last 12 months, the output of the solar PPA is approximately 130,000 MWhs per year and the wind PPA output is approximately 534,000 MWhs per year.

The PPAs are settled against the firm fixed prices contained in the PPAs.

54. Group 1 being if the retail meters in Group 1 are required to be in the special subaccount where the generation settlement activity occurs? Or can the retail load sit in a different subaccount from the generation?

Answer #54 – GSA does not require that GSA’s Group 1 retail load reside in a dedicated PJM subaccount nor the same dedicated PJM subaccount as GSA’s PPAs. Only, GSA’s PPAs must reside in a dedicated PJM subaccount.

55. Group 1, What is the type of contract for the PPAs from each project (include names). 1. Unit contingent busbar delivery 2. Virtual Power Purchase agreement 3. Firm 12x24 shaped schedule?”

Answer #55 – The Great Bay and Walnut Ridge contracts are firm fixed price contracts and are for unit contingent busbar delivery. See responses to questions 25, 42, and 61.

56. Who does GSA expect to schedule the IBT into the dedicated subaccount in Group 1? The Transaction Manager or the PPA asset party.

Answer #56 – The PPA vendors are expected to schedule the Internal Bilateral Transaction (IBT) into the Transaction Manager's dedicated PJM subaccount.

57. For Group 2-4, what is the nameplate capacity in MW of the cogen and what was its maximum peak load in

2019, 2020 and 2021 at each site (pre-covid, covid, post-covid)?

Answer #57 –

DocuSign Envelope ID: 1E76AA34-C269-48BA-BF46-6EBC7C12B288 https://urldefense.com/v3/__https:/www.gsa.gov/governmentwide-initiatives/emergency-response/facilities-status-and-information-overview__;!!OjemSMKBgg!wecLIABE6A1xPq1zsEQLFAhM4fWiEKAKqWZZSesJ8gjb2_GvxDLtN8Ty0YlTrpxLKQ$ https://urldefense.com/v3/__https:/www.gsa.gov/governmentwide-initiatives/emergency-response/facilities-status-and-information-overview__;!!OjemSMKBgg!wecLIABE6A1xPq1zsEQLFAhM4fWiEKAKqWZZSesJ8gjb2_GvxDLtN8Ty0YlTrpxLKQ$

- White Oak – Nameplate capacity is 55 MW spread over 9 different generators. This capacity includes N+1 redundancy.

- AOC – Nameplate capacity is 7.5 MW.

- HOTD - Plant has 2 Solar Turbines with nameplate capacity of 5.2MW each.

Maximum peak loads:

- White Oak – Summer peak is 21 MW historically. 2020 and 2021 data are not good indicators of future capacity due to reduced occupancy during Covid. The cogen plant is contractually obligated to maintain zero capacity charge through load management during potential PLC days.

- AOC –

Maximum Date

FY2019

* Cogen Electricity Generated (kWh) 199,122 February 3, 2019

Delivered to Grid MWh 80 January 21, 2019

Received from Grid kWh 272,194 June 20, 2019

FY2020

* Cogen Electricity Generated (kWh) 206,176 May 13, 2020

Delivered to Grid MWh 77 February 15, 2020

Received from Grid kWh 218,910 July 20, 2020

FY2021

* Cogen Electricity Generated (kWh) 198,512 January 29, 2021

Delivered to Grid MWh 77 January 23, 2021

Received from Grid kWh 210,025 August 27, 2021

* calculation based on manually collected data reports

- HOTD – Data provided in separate file.

58. For Groups 2-4: In A.21 (f) , , 'Supplemental Pricing', is it acceptable to the GSA to only transact fixed price block purchases of power in the event of an extended cogen outage or shortage? Also, would the GSA accept Supplemental Pricing at only one location throughout the contract term: either (a) PEPCO zone or (b) West Hub?

Answer #58 - No, GSA will not limit fixed price block purchases of power to just an event of an extended cogen outage or shortage. Yes, GSA will accept Supplemental Pricing at only the PEPCO zone throughout the contract term.

59. For Groups 2-4: If there is a monthly export, what is the expected formula for reimbursement of export power, and at Day-Ahead or Real-Time Pricing?

Answer #59 - Please refer to A.21 Import / Export Scope of Services for Pricing Groups Two (2), Three (3) And Four (4) for the reimbursement formula. Pricing is based on the Real Time LMP. The solicitation has been amended, see updated Section A.21 Import / Export Scope of Services for Pricing Groups Two (2), Three (3) And Four (4).

60. For Groups 2-4: If there is import load, does GSA expect to be billed on Day-Ahead or Real-Time Pricing throughout the contract term? Also, in an import load month with a Supplemental Pricing transaction, is it acceptable to GSA if both are in Day-Ahead or both are in Real-Time for the duration of the contract?

Answer #60 - GSA will be billed for all imports using Real Time LMP pricing, the same as for any exports. In an import load month with a Supplemental Pricing transaction, both will be in the Real-Time for the duration of the contract.

61. Can GSA clarify if Pricing Group 1 requires settlement based on day ahead or real time pricing?

Answer #61 – Great Bay PPA – Seller shall schedule GSA's Portion of Renewable Energy to be delivered to GSA at the Day Ahead LMP. See previous responses for additional information.

Walnut Ridge Wind PPA – Seller shall schedule GSA's Portion of Renewable Energy to be delivered to GSA at the Real Time LMP. See previous responses for additional information.

62. Are additional agreements between winning supplier and PPA developers necessary?

Answer #62 - Yes, the transaction manager will be required to execute any agreements required by PJM for wholesale transactions.

63. For the export/import accounts are the energy import changes based on day ahead or real time LMP prices?

Answer #63 - As per Section A.21, the Energy Charge (see Section A.7 Payment and Billing) for electricity imports is defined as: Hourly On-Peak and Off-Peak load following electric service in the amount of Buyer's Electricity Purchase Requirements. Hourly Energy Service includes Real Time LMP and/or day ahead. The requirement is for Real Time LMP delivered to the Pepco DC or MD Zone.

64. Please confirm the Black Start and Reactive Supply and Voltage Control (RSVC) are NOT to be treated as pass-through charges (Economic Price Adjustment charges).

Answer #64 - Black Start and Reactive Supply and Voltage Control (RSVC) associated costs are ancillary charges. Per the solicitation, ancillary charges are to be included in bid prices.

QUESTIONS RECEIVED DURING MARCH 15TH CALL

65. The comment for PEPCO account # 0550195159197001814288 in the Account Notes sheet of the Exhibit 1 states, “Based on the period of time the PV has been inactive, the kWh volumes provided in this Exhibit 1 reflect usage with the PV operating.” Should that be without?

Answer #65 – Yes. The Amendment 1 version of the Exhibit 1 changes “with” to “without”.

66. The WMATA sub-metered accounts sheet in the Exhibit 1 shows 7/26/22 as the meter read start date for all of these accounts but the solicitation and other Exhibit 1 sheets show the start date for WMATA’s accounts as the first meter read in June 2022. Is this accurate?

Answer #66 – The meter read start date of 7/26/22 for the WMATA sub-metered accounts is accurate. The Amendment 1 version of the solicitation has been updated to show the start date for WMATA’s accounts will be the July 2022 utility meter read start date.

67. The Summary and All Data sheets in the Exhibit 1 show 50% renewable for WMATA accounts in Pricing Group 5 but the solicitation and Auction Schedule show 0%. Which is correct?

Answer #67 - The Amendment 1 version of the Exhibit 1 has been updated to show 50% renewable for WMATA accounts in all sheets.

68. Could you explain a little more about Pricing Group 1 and whether there will need to be some type of agreement between the PPA contract owners, the winning supplier and GSA?

Answer #68 – There agreements in place between the current contractor and the PPA developers. The agreements are standard for PJM wholesale transactions with counterparties. The winning supplier will need to enter into similar agreements.

69. Is the subaccount referred to in the solicitation for Pricing Group 1 a PJM subaccount? If yes, can suppliers use an existing subaccount or do they need to set up a new dedicated subaccount per the solicitation?

Answer #66 – See responses to questions 16 and 39.

70. Does the reference to transaction manager in A.20 reference scheduling the PPA power into PJM?

Answer #70 – See responses to questions 42 and 56.

71. Can GSA confirm Pricing Group 1 requires a firm fixed price regardless of load shape that includes all services specified in this section and the Attachment 2 – Price Component Confirmation Table for this pricing group?

Answer #71 – Yes, GSA can confirm.

72. Do GSA’s current PPAs have a fixed price or are those settled on the market?

Answer #72 - The Transaction Manager (i.e., winning bidder) pays GSA’s PPA contract prices and GSA pays the Transaction Manager.

- Great Bay PPA – See response to questions 25 and 61.

- Walnut Ridge Wind PPA – See response to questions 25 and 61.

Table of Contents

SECTION A: SCOPE OF WORK

A.1 GENERAL

A.2 DELIVERY POINT

A.3 NOMINATING AND BALANCING RESPONSIBILITIES

A.4 CREDIT FOR DEFAULT SUPPLY SERVICE

A.5 RISK OF LOSS

A.6 PROTECTION OF CONTRACT INFORMATION

A.7 PAYMENT AND BILLING

A.8 RESERVED

A.9 RESERVED

A.10 ADDING AND DELETING FACILITIES TO THIS CONTRACT

A.11 RESERVED

A.12 RENEWABLE POWER FOR FACILITIES IN THIS CONTRACT

A.13 LOAD CHANGES DURING THE TERM OF THE CONTRACT

A.14 ELECTRICITY REGULATORY CHANGES

A.15 CONTRACT ADMINISTRATION

A.16 AUCTION PROCESS FOR PRICING USING Enel X

A.17 ENEL X FEE

A.18 DAMAGES FOR MISSING CONTRACT START DATE

A.19 FIXED PRICE WITH ECONOMIC PRICE ADJUSTMENT SCOPE OF SERVICES FOR PRICING

GROUPS ONE (1), FIVE (5) AND SIX (6)

A.20 POWER PURCHASE AGREEMENT TRANSACTION MANAGER SCOPE OF SERVICES FOR

PRICING GROUP ONE (1)

A.21 IMPORT / EXPORT SCOPE OF SERVICES FOR PRICING GROUPS TWO (2), THREE (3) AND FOUR

(4) 9

SECTION B: FEDERAL ACQUISITION REGULATION (FAR) CLAUSES

B.1 CLAUSES INCORPORATED BY REFERENCE

B.2 CLAUSES IN FULL TEXT

C.1 EVIDENCE OF TECHNICAL ACCEPTABILITY

C.2 PRICE PROPOSAL

C.3 SUBMISSION OF PROPOSALS

SECTION D: EVALUATION FACTORS FOR AWARD:

D.1 EVALUATION

D.2 BASIS FOR AWARD

D.3 POST AWARD REQUIREMENT FOR SERVICE START DATE REPORTING

SECTION E: REPRESENTATIONS AND CERTIFICATION

TECHNICAL PROPOSAL CHECKLIST

ATTACHMENT 1: CONTRACTOR INFORMATION

ATTACHMENT 2: PRICE COMPONENT CONFIRMATION TABLE

ATTACHMENT 3: VERIFICATION FROM RENEWABLE ENERGY SUPPLIER

ATTACHMENT 4: RENEWABLE POWER/RENEWABLE ENERGY CERTIFICATE NOTIFICATION

ATTACHMENT 5: RENEWABLE POWER/RENEWABLE ENERGY CALCULATIONS

ATTACHMENT 6: 52.204-24 REPRESENTATION REGARDING CERTAIN TELECOMMUNICATIONS AND VIDEO

SURVEILLANCE SERVICES OR EQUIPMENT

ATTACHMENT 7: SAMPLE FEDERAL CONTRACTOR VETERANS’ EMPLOYMENT REPORT VETS-4212 FORM 74

ATTACHMENT 8: SUBCONTRACTING PLANS

NOTE: ALL QUESTIONS MUST BE SUBMITTED IN WRITING AND CAN BE SENT VIA:

ELECTRONIC MAIL AT jennifer.smith@gsa.gov

SECTION A: SCOPE OF WORK

A.1 GENERAL

The U.S. General Services Administration (GSA or Government) is requesting proposals for the supply of all electricity supply commodity components up to the Delivery Point as specified in Attachment 2 of this solicitation for Federal facilities located in various Local Distribution Utility (LDU) service territories within the District of

Columbia and State of Maryland. Pricing is to the Delivery Point and shall include all cost components referenced in Attachment 2 of this solicitation. The price shall also include transmission and distribution line losses to the end-use meter. The Contractor shall supply the full requirements of such electricity for a term of up to thirty-six (36) monthly billing cycles for accounts included in this contract, as specified in Section C.2. The Government has placed its requirements into six (6) pricing groups. The service start date for each account shall begin with the first utility meter read date specified by the applicable utility for the month listed in Exhibit 1 for each account.

All quantities required to be supplied to facilities included in this contract shall be considered firm requirements

(“firm” means electric supply that will not be interrupted except as permitted under this contract) for delivery by the Contractor to the Delivery Point. The Contractor shall be liable for all costs assessed to facilities arising out of or relating to the non-delivery of firm requirements. The electricity provided under this contract shall conform to the tariff of the interstate/intrastate transmitting utility and the LDU at the Delivery Point for the accounts specified in Exhibit 1. The Government has organized its requirements for this solicitation in Exhibit 1 as described below.

Additional requirements for Pricing Group one (1), as well as for Pricing Groups two (2), three (3), and four (4) are detailed below in Sections A.20 and A.21, respectively.

Exhibit 1 consists of an Excel spreadsheet that specify the accounts included in this contract and provides aggregate estimated totals. For each account, the following information is provided if available:

(a) LDU rate schedule;

(b) LDU account number;

(c) Agency/account holder;

(d) General Service Location;

(e) LDU;

(f) Monthly consumption (kWh);

(g) Registered monthly on-peak demand (KW) per LDU tariff definition;

(h) Registered monthly maximum demand (KW) per LDU tariff definition;

(i) Monthly on-peak KWH per LDU tariff definition;

(j) Monthly interim KWH per LDU tariff definition;

(k) Monthly off-peak KWH per LDU tariff definition;

(l) Monthly billing days;

(m) Monthly load factor;

(n) Range of meter read dates throughout the year;

(o) Weather hourly interval data is provided for the account (information on separate spread sheets).

A.2 DELIVERY POINT

The Delivery Point for such electricity shall be the ISO/utility interconnect for the specific facilities identified in

Exhibit 1 of this contract. The utility will then distribute the electricity to the Government’s individual meters.

A.3 NOMINATING AND BALANCING RESPONSIBILITIES

It is the Contractor’s responsibility to conduct all required nominations on behalf of the facilities specified in Exhibit

1. The Contractor shall be fully familiar with the imbalance, transmission grid loss and line loss policies of both mailto:jennifer.smith@gsa.gov the LDU and the interstate/intrastate transmission companies. The Contractor shall be liable for all costs arising out of or relating to these items.

A.4 CREDIT FOR DEFAULT SUPPLY SERVICE

If at any time, unless as a result of an Excusable Delay (see FAR 52.212-4(f)), an account covered by this contract is forced to accept default supply service from the LDU serving in its capacity as the utility supplier of last resort solely as a result of action/inaction by the Contractor, the Contractor shall be responsible for payment of any additional costs incurred.

A.5 RISK OF LOSS

Risk of loss of electricity supplied under this contract shall remain with the Contractor prior to the Delivery Point and shall pass to the Government at and after the Delivery Point specified for each facility.

A.6 PROTECTION OF CONTRACT INFORMATION

The Government will take the necessary and usual steps to maintain the confidentiality of information submitted by offerors prior to award of the contract. The Contractor is advised that the Government will make all contract prices publicly available for the full contract period.

A.7 PAYMENT AND BILLING

The Contractor expressly agrees and acknowledges that each Government facility to which supplies or services are provided pursuant to this contract will be separately responsible for and liable to pay for any such supplies or services. For the avoidance of doubt, GSA will be the responsible party for purposes of making payments for the accounts only where GSA is listed as the Agency on Exhibit 1.

Section C.2 and Exhibit 1 specifies which accounts require dual billing and which require consolidated billing through the applicable utility.

For dual billed accounts, the Contractor will submit a monthly invoice to the Government facility for supplies and services rendered the previous month. The invoice should include the amount of kWhs measured at each meter and must be consistent with the rules of the Public Service Commission of the District of Columbia (DCPSC) or

Maryland Public Service Commission (MDPSC) regarding issuance and format of bills. The Contractor shall use the LDU's meters, meter readings, and billing cycles for the computation of bills. The Contractor must establish a unique supplier account number for each end-use Government account and provide the corresponding LDU account number on each monthly bill. The Contractor also expressly agrees and acknowledges they will be required to submit invoices in accordance with each end use agency’s billing requirements and systems which can include requirements for invoices to be submitted through online systems. It shall be the Contractor’s responsibility to know and understand the specific details and requirements for monthly billing, reporting, and coordination with the LDU.

Payment shall be in accordance with FAR 32.9 (Prompt Payment). If payment is to be made by electronic funds transfer, the provisions of FAR 32.11 (ELECTRONIC FUNDS TRANSFER), including the clause at 52.232-33 shall apply. Contractor’s invoices must match the company name as specified in Attachment 1 and payment information for the Contractor in relation to invoices rendered must match the DUNS number, Tax Identification

Number and Cage Code specified in Attachment 1.

For consolidated billing accounts, the Government…