MCE Executive Committee
February 3, 2023

SIGNATURE
IN WITNESS WHEREOF, the Parties hereto have executed this Joint Powers Agreement establishing the Marin Energy Authority.

By:

Name: Madeline R. Kellner
Title: Mayor
Date: October 7, 2011
Party: City of Novato
AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement ARTICLE9

SIGNATURE
IN WITNESS WHEREOF, the parties hereto have executed this Joint Powers Agreement establishing Marin Clean Energy (formerly, Marin Energy Authority) Party: City of Oakley
AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement ARTICLE9

SIGNATURE
IN WITNESS WHEREOF, the Parties hereto have executed this Joint Powers Agreement establishing the Marin Energy_ Authority. &~ By: /1/4 ud-UJ J
Name: Michelle Fitzer
---- ------------
Title: ____ City Manager ____________ _
Date:---i-, zf-J.,C~a.,-&- /l-+- 7-----
Party: ____ City of Pinole ___________ _
Approved as to form:

By:

Name: ---Eric Casher
--------------
Title: ___ City Attorney ____________ _
Date: __ ....;.7
_/f_/ _/_r __________ _
AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement ARTICLE 9

SIGNATURE
IN WITNESS WHEREOF, the parties hereto have executed this Joint Powers Agreement establishing Marin Clean Energy (formerly, Marin Energy Authority) Party: City of Pittsburg
AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement ARTICLE9

SIGNATURE
IN WITNESS WHEREOF, the parties hereto have executed this Joint Powers Agreement establishing Marin Clean Energy (formerly, Marin Energy Authority) Title: City Manager
Date: June 14 . 2019
Party: City of Pleasant Hill
AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement ARTICLE9

SIGNATURE
IN WITNESS WHEREOF, the parties hereto have executed this Joint Powers Agreement establishing the Marin Energy Authority
By:

Name:

Party:

AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement ARTlCJ,F. Q
SlGt<AJ(:tu;
AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement ARTTCL'F, 9
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11' WID19iS-WaE-Rl:l~)J,. the,!(/, hcrccc have cxec--utcd tl".ics Joint Power, As,~ement ::··~u7~f~v
Title: Mayor _ ___ ____ _
l~tDUfl'V 9 :!009
P~rty:

AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement ARTICLH\l

SIGNATCRE
l>-1 WITNESS WHEREOF, the parU<.'S h<.relo ha\•e cxc..:ulcd this Juinl Pow.;,~rs :\grc~mcnl cpa~ • 11 F '~l:)' flom1c1ly. Marin l:nc1 gy Au1ho,·,1~ • (' I '<>
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SIC. 'IA TIJRF.

IN V..,rTKtSS "'-·1·If.REOF. t~lC' Partfos 1~:-cto have ,tXt;~lt<l 1t:,~ Jnir;L l'ow:rs ;\;:o,ri:.:01e11~ e~t.:.bii,:;hinf• the \·fo.ri111:m.,r~y A11llrn1il)',
AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement ;\IHICL~;?
SIGNATllRF.

I'.\! v.:rrKES:; \\:'IJl-'.IU~OF, the f)a.1·1i.,;~ hcrao ha.\·..: cxc..:utC'd chis Joioc PlW.'Cf~ ,.,g,e~mC":u )(rune·
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Party: C:t~· uf Sun lfr,n1Ml
AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement ARTICLl,;9

SIGNATURE
J'.\I W ff~bSS \VHE:RF,Of-, Lhe Parlic.,; hereto have executed lhii:1 .T1Jint Po,;,·er.:: Agreemem c-smbEsh.ing the l\forin r:oergy Authodty.
lly:
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Date:

Item: 5A
Meeting Date: _ 11-18-08
Page#: 24
AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement ARTICLE9

SIGNATURE
IN WJiNE;Ss WHEMh<Jf. fhe parties hereco have i::x.c::utcd thi& Joinr Powers /\yccmt:nt CSl.lblishing Marin C:lt1'n l:::ncrgy (form'-'1'1)'. Ma,in Em~r~· Auth<.11ity) ~ G
8)':

Name: -/;"-+J--"-<U'-..>..,,,µ.

J;cJe:
l)3te: -''-1--l--....L.f-'-'(psc.. _ __ _
Parry: Cicy of St. Helena
AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement T:lle: MAYOR
ART!CLE9
SJC:~ATlrRF:

ARTICLE 9

SIGNATURE
IN WITNESS WHEREOF, the parties hereto have executed this Joint Powers Agreement establishing Marin Clean Energy (formerly, Marin Energy Authority) By:

Name:

Title:- - --="Ci"t'y-'--=M=:.=.:..a:=a.g:n: =cr:e.-_ _ _ _ _ _ Date:- - ----=-J=-u=ne::...1..:.2, =2.,,,'"0"'-1"'-9_ _ _ _ _ _ Party: City of Vallejo
AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement A.RTICLE9
.SIG~ATCRF,
1N WTT\'~S,S \VI I ERi :OF, Lhe purLies ht'retll h..1.vc cxccutod this Joint lJo~-c.rs Agreement i:~u:ihfo:hi.n£ Mn1iJ.1 CleJU\ J:ner~• (fonuerJy, ).1mln Tini:rgy Authurity) lly:
\lame: _ /,.JJ/;.l,-'-A _l.),,'-.Sj,t..ft.L.)~- ---
/Ji)A yc"-,<c--=-' _____ _
D111.t: ---'4-f(-"13-"/'--,· _i'-:, _____ _ _ _
AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement ARHCLJ;; !I
SIG:'IIATURE
:N \VJTNTISS \\.'llfiREOf, 1h~ p!nie,, hen::·,.:, rJa,..c ~x~i:.utei.J Lhis.lc,in!. t>cw,er.o. Agr~mcnt i:stsbllsl:ing ~·1arin CJ~"ll f:11crsy (furm~rly, Muill J:::ncr&}' Aur!lotLty) AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement ARTICLE9
N Wll)JESS WHERhOf, :h~ pru-tie.~ h.e(et(l ha,,e executed rhil: ,lofot i\)we<s :\~reement e,;t;1hlisl1i11~ \.hir:n Ch:tin En<.~g)' (furmcr:y. ~:t..•ui.n £:1.C'rg}· A..:thorityj Cnnlm Cu,,;1.it C\,unly
AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement ARTICLE9

SIGNATURE
IN WITNESS WHEREOF, the Parties hereto have executed this Joint Powers Agreement :~ablifilllllg~ ~
Name: (}#/lt&u:[8 r; JtiE~l-/~
Title: 7€.E-S~\\ D"{=
Date: ~o\Je\f\l\_ \5 Zr;;;:s;:8 Party: Cw w:M . 0~ ~~IN AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement ARTTCLF. 9
f); w;nlE:\S WllERl'.Or-, loo, p>or1i-,; h"""" hi,v-, "'°"*'I 1hi, .k•iJJ; Pcwi:,s A~.n:<71:.:n:
c:-1:;iili:,l:i·,E Mu':"iTI Clc.·m~ Enc,·~.y cr~)·::-,,:.Ti.)\ \forin E:·,..:rry Au1hmi1y) AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement ARTICLE9

SIGNATURE
IN WITNESS WHEREOF, the parties hereto have executed this Joint Powers Agreement establishing Marin Clean Energy (formerly, Marin Energy Authority) Name: Birgitta E. Corsello
Title: County Administrator
Date:

Party: County of Solano
APPROVED AS TO FORM:

Solano County Counsel
Exhibit A
To the
Joint Powers Agreement
Marin Energy Authority
-Definitions-
“AB 117” means Assembly Bill 117 (Stat. 2002, ch. 838, codified at Public Utilities Code Section 366.2), which created CCA.
“Act” means the Joint Exercise of Powers Act of the State of California (Government Code Section 6500 et seq.)
“Administrative Services Agreement” means an agreement or agreements entered into after the Effective Date by the Authority with an entity that will perform tasks necessary for planning, implementing, operating and administering the CCA Program or any other energy programs adopted by the Authority.
“Agreement” means this Joint Powers Agreement.
“Annual Energy Use” has the meaning given in Section 4.9.2.2. “Authority” means the Marin Energy Authority.
“Authority Document(s)” means document(s) duly adopted by the Board by resolution or motion implementing the powers, functions and activities of the Authority, including but not limited to the Operating Rules and Regulations, the annual budget, and plans and policies.
“Board” means the Board of Directors of the Authority.
“CCA” or “Community Choice Aggregation” means an electric service option available to cities and counties pursuant to Public Utilities Code Section 366.2. “CCA Program” means the Authority’s program relating to CCA that is principally described in Sections 2.4 and 5.1.
“Director” means a member of the Board of Directors representing a Party. “Effective Date” means the date on which this Agreement shall become effective and the Marin Energy Authority shall exist as a separate public agency, as further described in Section 2.1.
“Implementation Plan” means the plan generally described in Section 5.1.2 of this Agreement that is required under Public Utilities Code Section 366.2 to be filed with the AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement California Public Utilities Commission for the purpose of describing a proposed CCA Program.
“Initial Costs” means all costs incurred by the Authority relating to the establishment and initial operation of the Authority, such as the hiring of an Executive Director and any administrative staff, any required accounting, administrative, technical and legal services in support of the Authority’s initial activities or in support of the negotiation, preparation and approval of one or more Administrative Services Provider Agreements and Program Agreement 1. Administrative and operational costs incurred after the approval of Program Agreement 1 shall not be considered Initial Costs. “Initial Participants” means, for the purpose of this Agreement, the signatories to this JPA as of May 5, 2010 including City of Belvedere, Town of Fairfax, City of Mill Valley, Town of San Anselmo, City of San Rafael, City of Sausalito, Town of Tiburon and County of Marin.
“Operating Rules and Regulations” means the rules, regulations, policies, bylaws and procedures governing the operation of the Authority. “Parties” means, collectively, the signatories to this Agreement that have satisfied the conditions in Sections 2.2 or 3.2 such that it is considered a member of the Authority. “Party” means, singularly, a signatory to this Agreement that has satisfied the conditions in Sections 2.2 or 3.2 such that it is considered a member of the Authority. “Program Agreement 1” means the agreement that the Authority will enter into with an energy service provider that will provide the electricity to be distributed to customers participating in the CCA Program.
“Total Annual Energy” has the meaning given in Section 4.9.2.2.

AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement Exhibit B
To the
Joint Powers Agreement
Marin Energy Authority
-List of the Parties-City of American Canyon
City of Belvedere
City of Benicia
City of Calistoga
City of Concord
Town of Corte Madera
Town of Danville
City of El Cerrito
Town of Fairfax
City of Fairfield
City of Lafayette
City of Larkspur
City of Martinez
Town of Moraga
City of Mill Valley
City of Napa
City of Novato
City of Oakley
City of Pinole
City of Pittsburg
City of Pleasant Hill
City of Richmond
Town of Ross
Town of San Anselmo
City of San Pablo
City of San Rafael
City of San Ramon
City of Sausalito
St. Helena
Town of Tiburon
City of Vallejo
City of Walnut Creek
Town of Yountville
County of Contra Costa
County of Marin
County of Napa
County of Solano
AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement Exhibit C
Marin Clean Energy
This Exhibit C is effective as of November 19, 2020.

MCE Member Communities
- Annual Energy
Use -
This Exhibit C is effective as of November 19, 2020.

MCE Member Community kWh (2019)
City of American Canyon

76,695,933
City of Belvedere

7,577,958
City of Benicia

113,063,212
City of Calistoga

25,994,261
City of Concord

498,162,604
Town of Corte Madera

46,419,358
County of Contra Costa

673,004,355
Town of Danville

159,347,837
City of El Cerrito

57,817,586
Town of Fairfax

17,969,915
City of Fairfield*

452,596,498
City of Lafayette

94,682,154
City of Larkspur

42,611,547
City of Martinez

151,009,009
City of Mill Valley

44,571,991
County of Marin

231,346,718
Town of Moraga

43,994,965
AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement City of Napa

306,136,179
County of Napa 299,606,262
City of Novato

184,366,404
City of Oakley

105,972,646
City of Pinole

64,070,289
City of Pittsburg

404,506,338
City of Pleasant Hill*

125,951,493
City of Richmond

374,022,160
Town of Ross

9,855,768
Town of San Anselmo

32,381,273
City of San Ramon

301,946,012
City of Saint Helena

48,784,002
City of San Pablo

63,337,637
City of San Rafael

218,232,540
City of Sausalito

32,001,734
County of Solano*

176,902,587
Town of Tiburon

29,057,049
City of Vallejo*

332,927,602
City of Walnut Creek

344,139,693
Town of Yountville

30,941,216
MCE Total Energy Use

6,222,004,783
*2019 usage data as provided by PG&E.

All other usage data reflects MCE customer billing records for 2019.

AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement Exhibit D
Marin Clean Energy
- Voting Shares -
This Exhibit D is effective as of November 19, 2020.

MCE Member Community kWh (2019)
Section

4.9.2.1 Section

4.9.2.2 Voting
Share
City of American Canyon 76,695,933 1.35% 0.62% 1.97%
City of Belvedere 7,577,958 1.35% 0.06% 1.41%
City of Benicia 113,063,212 1.35% 0.91% 2.26%
City of Calistoga 25,994,261 1.35% 0.21% 1.56%
City of Concord 498,162,604 1.35% 4.00% 5.35%
Town of Corte Madera 46,419,358 1.35% 0.37% 1.72%
County of Contra Costa 673,004,355 1.35% 5.41% 6.76%
Town of Danville 159,347,837 1.35% 1.28% 2.63%
City of El Cerrito 57,817,586 1.35% 0.46% 1.82%
Town of Fairfax 17,969,915 1.35% 0.14% 1.50%
City of Fairfield* 452,596,498 1.35% 3.64% 4.99%
City of Lafayette 94,682,154 1.35% 0.76% 2.11%
City of Larkspur 42,611,547 1.35% 0.34% 1.69%
City of Martinez 151,009,009 1.35% 1.21% 2.56%
City of Mill Valley 44,571,991 1.35% 0.36% 1.71%
County of Marin 231,346,718 1.35% 1.86% 3.21%
Town of Moraga 43,994,965 1.35% 0.35% 1.70%
City of Napa 306,136,179 1.35% 2.46% 3.81%
County of Napa 299,606,262 1.35% 2.41% 3.76%
City of Novato 184,366,404 1.35% 1.48% 2.83%
City of Oakley 105,972,646 1.35% 0.85% 2.20%
City of Pinole 64,070,289 1.35% 0.51% 1.87%
City of Pittsburg 404,506,338 1.35% 3.25% 4.60%
City of Pleasant Hill* 125,951,493 1.35% 1.01% 2.36%
City of Richmond 374,022,160 1.35% 3.01% 4.36%
Town of Ross 9,855,768 1.35% 0.08% 1.43%
Town of San Anselmo 32,381,273 1.35% 0.26% 1.61%
City of San Ramon 301,946,012 1.35% 2.43% 3.78%
City of Saint Helena 48,784,002 1.35% 0.39% 1.74%
City of San Pablo 63,337,637 1.35% 0.51% 1.86%
City of San Rafael 218,232,540 1.35% 1.75% 3.11%
City of Sausalito 32,001,734 1.35% 0.26% 1.61%
AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement County of Solano* 176,902,587 1.35% 1.42% 2.77%
Town of Tiburon 29,057,049 1.35% 0.23% 1.58%
City of Vallejo* 332,927,602 1.35% 2.68% 4.03%
City of Walnut Creek 344,139,693 1.35% 2.77% 4.12%
Town of Yountville 30,941,216 1.35% 0.25% 1.60%
MCE Total Energy Use 6,222,004,783 50.00% 50.00% 100.00% *2019 usage data as provided by PG&E.

All other usage data reflects MCE customer billing
records for 2019.

AI #09_Att. A: MCE (formerly Marin Clean Energy Authority) Joint Powers Agreement 12660-0002\1109516v1.doc

MARIN ENERGY AUTHORITY

OPERATING RULES AND REGULATIONS
(As Amended)

ARTICLE I

FORMATION
The Marin Energy Authority (the “Authority”) was established on December 19, 2008 pursuant to the execution of the Marin Energy Authority Joint Powers Agreement (the “Agreement”) by the County of Marin, the Town of Fairfax and the Town of Tiburon. The Initial Participants in the Authority who executed the Agreement within 180 days of the establishment of the Authority are the following:
_____________________________________________________________________________ _____________________________________________________________________________.

The members of the Authority are referred to as Party or Parties in these Operating Rules and Regulations. As defined by the Agreement, these Operating Rules and Regulations consist of rules, regulations, policies, bylaws and procedures governing the operation of the Authority.

ARTICLE II

PURPOSES
The Authority is formed to study, promote, develop, conduct, operate, and manage energy and energy-related climate change programs, and to exercise all other powers necessary and incidental to accomplishing this purpose. These programs include but are not limited to the establishment of a Community Choice Aggregation Program known as Marin Clean Energy in accordance with the terms of the Agreement.

ARTICLE III

BOARD OF DIRECTORS
Section 1. The Authority shall be governed by a Board of Directors composed of one representative of each of the Parties. The Board may delegate specified functions or actions to the Executive Committee or other committees that may be established by the Board. The governing body of each Party shall appoint and designate in writing to the Authority one regular Director who shall be authorized to act for and on behalf of the Party on all matters within the power of the Authority. The governing body of each Party also shall appoint and designate in writing to the Authority one alternate Director who may vote on all matters when the regular Director is absent for a Board meeting. Both the Director and the Alternate Director shall be members of the governing body of the Party.

Section 2. Each Director and Alternate Director shall serve at the pleasure of the governing body of the Party that the Director represents and may be removed as Director or Alternate Director by such governing body at any time.

AI #09_Att. B: MCE (formerly Marin Clean Energy Authority) Operating Rules and Regulations 2 12660-0002\1109516v1.doc
Section 3. A Director may be removed by the Board for cause. Cause shall be defined for the purposes of this section as follows:
a. Unexcused absences from three consecutive Board meetings. b. Unauthorized disclosure of confidential information or documents from a closed session or the unauthorized disclosure of information or documents provided to the Director on a confidential basis and whose public disclosure may be harmful to the interests of the Authority.

Written notice shall be provided to the Director proposed for removal and the governing body that appointed such Director at least thirty days prior to the meeting at which the proposed removal will be considered by the Board. The notice shall state the grounds for removal, a brief summary of the supporting facts, and the date of the scheduled hearing on the removal. The Director proposed for removal shall be given an opportunity to be heard at the removal hearing and to submit any supporting oral or written evidence. A Director shall not be removed for cause from the Board unless two-thirds of all Directors (excluding the Director subject to removal) vote in favor of the removal.

Section 4. If at any time a vacancy occurs on the Board, for whatever reason, a replacement shall be appointed by the governing body of the subject Party to fill the position of the previous Director within ninety days of the date that such position becomes vacant.

ARTICLE IV

OFFICERS AND TERMS OF OFFICE
Section 1. There shall be a Chairperson, a Vice-Chairperson, a Secretary and a Treasurer. a. Chairperson. The Chairperson of the Authority shall be a Director. Duties of the Chairperson are to supervise the preparation of the business agenda, preside over Authority meetings, and sign all ordinances, resolutions, contracts and correspondence adopted or authorized by the Board. The term of office of the Chairperson shall be for one year.
b. Vice-Chairperson. The Vice-Chairperson shall be a Director. The Vice-Chairperson shall perform the duties of Chairperson in the absence of such officer. The term of office of the Vice-Chairperson shall be for one year.
c. Secretary. The Secretary will supervise the preparation of the meeting minutes and the maintenance of the records of the Authority. The term of the Secretary shall be for one year. The Secretary does not need to be a Director. d. Treasurer and Auditor. The Treasurer shall have custody of all the money of the Authority and shall have all of the duties and responsibilities specified in Government Code Section 6505.5. The Treasurer shall report directly to the Board and shall comply with the requirements of treasurers of incorporated municipalities. The positions of Treasurer and Auditor may be combined into one position known as the AI #09_Att. B: MCE (formerly Marin Clean Energy Authority) Operating Rules and Regulations 3 12660-0002\1109516v1.doc
Treasurer/Auditor of the Authority. Neither the Treasurer nor the Auditor needs to be a Director. The term of the Treasurer and Auditor shall be for one year. The Board may transfer the responsibilities of the Treasurer and Auditor to any person or entity permitted by law.
e. Initial Terms of Office. Notwithstanding the one-year term generally established for officers above, the terms of the initial officers elected by the Board shall not expire until the annual meeting of the Board held in June 2010. f. No Term Limits. There are no limits on the numbers of terms that an officer of the Authority may serve.
g. Removal. An officer of the Board shall be subject to removal with or without cause at any time by a majority vote of the full Board.
h. Committees. The Executive Committee and all other Committees of the Board shall be selected as provided by Sections 4.6 and 4.7 of the Agreement. Each duly established Committee may establish any Standing or Ad Hoc Committees determined to be appropriate or necessary. The duties and authority of all Committees shall be subject to the approval and direction of the Board. i. Committee of the Whole. To allow full participation by Board members at meetings of Standing Committees, each Standing Committee meeting except the Executive Committee also shall be noticed as a “Committee of the Whole” meeting. In the event that a quorum of Board members are present at a Standing Committee meeting, the Standing Committee will automatically convert into a Committee of the Whole.

Likewise, if there is no longer a quorum of the Board present, then the Committee of the Whole will automatically convert back into a Standing Committee. The chair of the Standing Committee will serve as Chair of the Committee of the Whole. Any item acted upon by the Committee of the Whole will be considered advisory to the Board of Directors and require consideration and action by the Board of Directors at a noticed Board meeting before adoption or approval of the item.

The agenda for each Standing Committee, other than the Executive Committee, shall include the following statement:
“This Committee may be attended by Board Members who do not serve on this Committee. In the event that a quorum of the entire Board is present, this Committee shall act as a Committee of the Whole. Any item acted upon by the Committee of the Whole will be considered advisory to the Board of Directors and require consideration and action by the Board of Directors at a noticed Board meeting before adoption or approval of the item.”
AI #09_Att. B: MCE (formerly Marin Clean Energy Authority) Operating Rules and Regulations 4 12660-0002\1109516v1.doc

ARTICLE V

MEETINGS
Section 1. Commencing in 2010, an annual meeting of the Board shall be held in June of each year to elect the officers of the Authority. The Board by resolution shall establish the date, time and meeting location of all regular meetings of the Board. Special meetings may be called upon the request of a majority of the members of the Board or by the Chairperson.

Section 2. The meetings of the Board, the Executive Committee and all other committees established by the Board shall be governed by the provisions of the Ralph M. Brown Act (Government Code Section 54950 et seq.).

ARTICLE VII
VOTING
Section 1. Voting on Authority matters shall be held in accordance with the requirements of Sections 4.9 and 4.10 of the Agreement.

Section 2. Under Section 4.10 of the Agreement, each member of the Board shall have one vote on general administrative matters and energy programs not involving Community Choice Aggregation unless otherwise provided by the Agreement or these Operating Rules and Regulations. Unless the Agreement or these Operating Rules and Regulations require a two-thirds vote, action on these items shall be determined by a majority vote of the quorum present and voting on the item except for the following matters which shall be approved only by a majority vote of the full membership of the Board:
a. The approval of the issuance of bonds or any other financing even if program revenues pay for such financing.
b. The hiring of an Executive Director and General Counsel. c. The appointment or removal of an officer.
d. The adoption of the Annual Budget.
e. The adoption of an ordinance.
f. The initiation of litigation where the Authority will be the plaintiff, petitioner or cross complainant or cross petitioner.
g. The adoption and amendment of the Operating Rules and Regulations. h. The approval of any program or other activity requiring financial contributions by individual Parties subject to the right of any Party who votes AI #09_Att. B: MCE (formerly Marin Clean Energy Authority) Operating Rules and Regulations 5 12660-0002\1109516v1.doc
against the program or activity to opt-out of such program or activity pursuant to Section 4 of this Article.

Section 3. The approval of an Administrative Services Agreement under Section 4.13 of the Agreement for planning, implementing, operating and administering the CCA Program shall be subject to the voting requirements of Section 4.9 of the Agreement.

Section 4. The Board shall provide at least 45 days prior written notice to each Party before it considers a program or activity for adoption at a Board meeting not involving CCA that requires financial contributions by individual Parties. Such notice shall be provided to the governing body and the chief administrative officer, city manager or town manager of each Party. The Board also shall provide written notice of such program or activity adoption to the above-described officials of each Party within 5 days after the Board adopts the program or activity.

Any Party voting against the approval of such program or activity may elect to opt-out of participation in the program or activity by providing written notice of this election to the Board within 30 days after the program or activity is approved by the Board. Upon timely exercising its opt-out election, a Party shall not have any financial obligation or any liability whatsoever for the conduct or operation of such program or activity.

ARTICLE VIII

DEBTS, LIABILITIES AND OBLIGATIONS
As provided by Section 2.3 of the Agreement, the debts, liabilities and obligations of the Authority shall not be debts, liabilities or obligations of the individual Parties unless the governing board of a Party agrees in writing to assume any of the debts, liabilities or obligations of the Authority. A Party who has not agreed to assume an Authority debt, liability or obligation shall not be responsible in any way for such debt, liability or obligation even if a majority of the Parties agree to assume the debt, liability or obligation of the Authority.

ARTICLE IX

AMENDMENTS
These Operating Rules and Regulations may be amended by a majority vote of the full membership of the Board but only after such amendment has been proposed at a regular meeting and acted upon at the next or later regular meeting of the Board for final adoption. The proposed amendment shall not be finally acted upon unless each member of the Board has received written notice of the amendment at least 10 days prior to the date of the meeting at which final action on the amendment is to be taken. The notice shall include the full text of the proposed amendment.

AI #09_Att. B: MCE (formerly Marin Clean Energy Authority) Operating Rules and Regulations

MARIN CLEAN ENERGY
ADDENDUM NO. 8 TO THE REVISED

COMMUNITY CHOICE AGGREGATION

IMPLEMENTATION PLAN AND

STATEMENT OF INTENT

TO ADDRESS MCE EXPANSION TO

THE CITY OF FAIRFIELD
November 19, 2020
For copies of this document contact Marin Clean Energy in San Rafael, California or visit www.mcecleanenergy.org
AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan MCE Clean Energy
My community. My choice.
i November 2020 – Addendum No. 8
Table of Contents
CHAPTER 1 – Introduction..................................................................................................................................... 2 CHAPTER 2 – Changes to Address MCE Expansion to Fairfield; ..................................................................... 5 Aggregation Process............................................................................................................................................. 7 Program Phase-In ................................................................................................................................................. 7 Sales Forecast......................................................................................................................................................... 9 Financial Plan ...................................................................................................................................................... 13 Expansion Addendum Appendices ................................................................................................................. 13 AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 2 November 2020 – Addendum No. 8
CHAPTER 1 – INTRODUCTION
The purpose of this document is to make certain revisions to the Marin Clean Energy Implementation Plan and Statement of Intent to address the expansion of Marin Clean Energy (“MCE”) to the City of Fairfield. MCE is a public agency that was formed in December 2008 for purposes of implementing a community choice aggregation (“CCA”) program and other energy-related programs targeting significant greenhouse gas emissions (“GHG”) reductions. At that time, the Member Agencies of MCE included eight of the twelve municipalities located within the geographic boundaries of Marin County: the cities/towns of Belvedere, Fairfax, Mill Valley, San Anselmo, San Rafael, Sausalito and Tiburon and the County of Marin (together the “Members” or “Member Agencies”). In anticipation of CCA program implementation and in compliance with state law, MCE submitted the Marin Energy Authority Community Choice Aggregation Implementation Plan and Statement of Intent (“Implementation Plan”) to the California Public Utilities Commission (“CPUC” or “Commission”) on December 9, 2009.

Consistent with its expressed intent, MCE successfully launched the Marin Clean Energy CCA program (“MCE” or “Program”) on May 7, 2010 and has been serving customers since that time.

During the second half of 2011, four additional municipalities within Marin County, the cities of Novato and Larkspur and the towns of Ross and Corte Madera, joined MCE, and a revised Implementation Plan reflecting updates related to that expansion was filed with the CPUC on December 3, 2011.

Subsequently, the City of Richmond, located in Contra Costa County, joined MCE, and a revised Implementation Plan reflecting updates related to that expansion was filed with the CPUC on July 6, 2012.

A revision to MCE’s Implementation Plan was then filed with the Commission on November 6, 2012 to ensure compliance with Commission Decision 12-08-045, which was issued on August 31, 2012. In Decision 12-08-045, the Commission directed existing CCA programs to file revised Implementation Plans to conform to the privacy rules in Attachment B of the aforementioned Decision.

During 2015, the County of Napa and the Cities of Benicia, El Cerrito, and San Pablo joined MCE; service was extended to customers in unincorporated Napa County during February 2015 and to customers in Benicia, El Cerrito and San Pablo during May 2015. To address the anticipated effects of these expansions, MCE filed with the Commission a revision to its Implementation Plan on July 18, 2014 to address expansion to the County of Napa (the Commission subsequently certified this revision on September 15, 2014). Following the Commission’s certification of this revision, MCE submitted Addendum No. 1 to the Revised Community Choice Aggregation Implementation Plan and Statement of Intent to Address MCE Expansion to the City of San Pablo (“Addendum No. 1”) on September 25, 2014 (and the Commission subsequently certified Addendum No. 1 on October 29, 2014); and Addendum No. 2 to the Revised Community Choice Aggregation Implementation Plan and Statement of Intent to Address MCE Expansion to the City of Benicia (“Addendum No. 2”) on November 21, 2014 (the Commission subsequently certified AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 3 November 2020 – Addendum No. 8
Addendum No. 2 on December 1, 2014); and Addendum No. 3 to the Revised Community Choice Aggregation Implementation Plan and Statement of Intent to Address MCE Expansion to the City of El Cerrito (“Addendum No. 3”) on January 7, 2015 (the Commission subsequently certified Addendum No. 3 on January 16, 2015).

On April 21, 2016, MCE’s Board of Directors (the “Board” or “Governing Board”) unanimously adopted Resolution No. 2016-01, which approved the cities of American Canyon, Calistoga, Lafayette, Napa, St. Helena and Walnut Creek as well as the Town of Yountville as members of MCE. On this date, MCE’s Board also approved the related Addendum No. 4 to its Revised Community Choice Aggregation Implementation Plan and Statement of Intent (“Addendum No. 4”), which addressed expansion to such Communities. Addendum No. 4 was submitted to the Commission on April 22, 2016; Addendum No. 4 was certified by the Commission thereafter on May 6, 2016.

On July 20, 2017, MCE’s Board adopted Resolution No. 2017-06, which approved Contra Costa County (unincorporated areas); the cities of Concord, Martinez, Oakley, Pinole, Pittsburg and San Ramon; and the towns of Danville and Moraga as members of MCE. On this date, MCE’s Board also approved the related Addendum No. 5 to its Revised Community Choice Aggregation Implementation Plan and Statement of Intent (“Addendum No. 5”), which addressed expansion to such Communities. Addendum No. 5 was submitted to the Commission on September 25, 2017; Addendum No. 5 was certified by the Commission thereafter on December 21, 2017.

MCE’s Board approved the membership request of Solano County (unincorporated areas) on October 18, 2018 via Resolution No. 2018-12, which also approved the related Addendum No. 6 to MCE’s Revised Community Choice Aggregation Implementation Plan and Statement of Intent (“Addendum No. 6”), addressing service delivery within the unincorporated areas of Solano County. Addendum No. 6 was submitted to the Commission on November 20, 2018; Addendum No. 6 was certified by the Commission thereafter on February 19, 2019.

Following the aforementioned expansions, MCE’s Board approved the membership requests of the cities of Pleasant Hill and Vallejo on November 21, 2019 via Resolution No. 2019-05, which also approved the related Addendum No. 7 to MCE’s Revised Community Choice Aggregation Implementation Plan and Statement of Intent (“Addendum No. 7”), which addressed service delivery within the cities of Pleasant Hill and Vallejo. Addendum No. 7 was submitted to the Commission on December 6, 2019; Addendum No. 7 was certified by the Commission thereafter on March 9, 2020.

More recently, MCE’s Board approved the membership request of the City of Fairfield on November 19, 2020 via Resolution No. 2020-03 (attached hereto as Appendix A), and similarly approved this Addendum No. 8 to MCE’s Revised Community Choice Aggregation Implementation Plan and Statement of Intent (“Addendum No. 8”), which addresses service delivery within the City of Fairfield.

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The MCE program currently provides electric generation service to approximately 484,000 customers, including a cross section of residential and commercial accounts. During its more than ten-year operating history, non-member municipalities have monitored MCE’s progress and operational success, evaluating the potential opportunity for membership, which would enable customer choice with respect to electric generation service. In response to such inquiries, MCE’s Board adopted Policy 007, which established a formal process and specific criteria for new member additions. In particular, this policy identifies several threshold requirements, including the specification that any prospective member evaluation demonstrate financial benefits to MCE’s existing customer base (based on prevailing market prices for requisite energy products at the time of each analysis) as well as environmental benefits (as measured by anticipated reductions in greenhouse gas emissions and increased renewable energy sales to CCA customers) before proceeding with expansion activities, including the filing of related revisions/addenda to this Implementation Plan. As MCE receives new membership requests, staff will follow the prescribed evaluative process of Policy 007 and will present related results at future public meetings, similar to the manner in which the results of prospective expansion to the City of Fairfield were recently presented at the duly noticed public meetings of MCE’s Executive Committee and Governing Board. To the extent that membership evaluations demonstrate favorable results and any new community completes the prescribed process of joining MCE, this Implementation Plan will be revised through a related addendum, highlighting key impacts and consequences associated with the addition of such new community/communities.

In response to public interest and MCE’s successful operational track record, the City of Fairfield requested MCE membership, consistent with MCE Policy 007, and subsequently adopted the requisite ordinance for offering CCA service within the City, which is attached hereto as Appendix C. As previously noted, MCE’s Board approved such membership request at a duly noticed public meeting on November 19, 2020 through the adoption of Resolution No. 2020-03.

This Addendum No. 8 describes MCE’s expansion plans to include the City of Fairfield. MCE intends to enroll such customers in its CCA Program during the month of April 2022, consistent with the Commission’s requirements described in Resolution E-4907, which define relevant timing for Implementation Plan filing in advance of service commencement. According to the Commission, the Energy Division is required to receive and review a revised MCE implementation plan reflecting changes/consequences of additional members. With this in mind, MCE has reviewed its revised Implementation Plan, which was filed with the Commission on July 18, 2014, as well as previously filed and certified Addendums, and has identified certain information that requires updating to reflect the changes and consequences of adding the City of Fairfield as well as other forecast modifications, which reflect the most recent historical electric energy use within MCE’s existing service territory. This Addendum No. 8 reflects pertinent changes that are expected to result from the new member addition as well as updated projections that are considerate of recent operations. This document format, including references to MCE’s most recent Implementation Plan revision (filed with the Commission on July 18, 2014 and certified by the Commission on September 15, 2014), which is incorporated by reference and attached hereto as Appendix D, addresses all requirements identified in Public Utilities Code AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 5 November 2020 – Addendum No. 8
Section 366.2(c)(4), including universal access, reliability, equitable treatment of all customer classes and any requirements established by state law or by the CPUC concerning aggregated service, while streamlining public review of pertinent changes related to MCE’s anticipated expansion.

CHAPTER 2 – CHANGES TO ADDRESS MCE EXPANSION TO THE CITY OF FAIRFIELD As previously noted, this Addendum No. 8 addresses the anticipated impacts of MCE’s planned expansion to the City of Fairfield, as well as other forecast modifications reflecting recent historical electric energy use within MCE’s existing service territory. As a result of this member addition, certain assumptions regarding MCE’s future operations have changed, including customer energy requirements, peak demand, renewable energy purchases, revenues, expenses and various other items. The following section highlights pertinent changes related to this planned expansion. To the extent that certain details related to membership expansion are not specifically discussed within this Addendum No. 8, MCE represents that such information shall remain unchanged relative to the July 18, 2014 Implementation Plan revision.

With regard to the defined terms Members and Member Agencies, the following Communities are now signatories to the MCE Joint Powers Agreement and represent MCE’s current membership:

Member Agencies
City of American Canyon City of Novato
City of Belvedere City of Oakley
City of Benicia City of Pinole
City of Calistoga City of Pittsburg
City of Concord City of Pleasant Hill
County of Contra Costa City of Richmond
Town of Corte Madera Town of Ross
Town of Danville Town of San Anselmo
City of El Cerrito City of Saint Helena
Town of Fairfax City of San Pablo
City of Fairfield City of San Rafael
City of Lafayette City of San Ramon
City of Larkspur City of Sausalito
County of Marin County of Solano
City of Martinez Town of Tiburon
City of Mill Valley City of Vallejo
Town of Moraga City of Walnut Creek
City of Napa Town of Yountville
County of Napa
AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 6 November 2020 – Addendum No. 8
Throughout this document, use of the terms Members and Member Agencies refer to the aforementioned Communities. To the extent that the discussion herein addresses the process of aggregation and MCE organization, each of these communities is now an MCE Member and the electric customers of such jurisdictions have been or will be offered CCA service consistent with the noted phase-in schedule.

AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 7 November 2020 – Addendum No. 8
Aggregation Process
MCE’s aggregation process was discussed in Chapter 2 of MCE’s July 18, 2014 Revised Implementation Plan. This first paragraph of Chapter 2 is replaced in its entirety with the following verbiage:

As previously noted, MCE successfully launched its CCA Program, MCE, on May 7, 2010 after meeting applicable statutory requirements and in consideration of planning elements described in its initial Implementation Plan. At this point in time, MCE plans to expand agency membership to include the City of Fairfield, which has requested MCE membership, and MCE’s Board of Directors subsequently approved this membership request at a duly noticed public meeting on November 19, 2020.

Program Phase-In
Program phase-in was discussed in Chapter 5 of MCE’s July 18, 2014 Revised Implementation Plan. Chapter 5 is replaced in its entirety with the following verbiage:

MCE will continue to phase-in the customers of its CCA Program as communicated in this Implementation Plan. To date, seven complete phases have been successfully implemented. An eighth phase will commence in April 2021 (including service commencement to customers located within the cities of Pleasant Hill and Vallejo), and a ninth phase will commence in April 2022 (including service commencement to customers located within the City of Fairfield), as reflected in the following table.

MCE Phase No. Status & Description of Phase Implementation Date
Phase 1:
8,500 Accounts
Complete: MCE Member (municipal) accounts & a
subset of residential, commercial and/or industrial
accounts, comprising approximately 20 percent of total
customer load within MCE’s original Member Agencies.

May 7, 2010
Phase 2A:
6,100 Accounts
Complete: Additional commercial and residential
accounts, comprising approximately 20 percent of total
customer load within MCE’s original Member Agencies
(incremental addition to Phase 1).

August 2011
Phase 2B:
79,000 Accounts
Complete: Remaining accounts within Marin County. July 2012 Phase 3:
35,000 Accounts
Complete: Residential, commercial, agricultural, and
street lighting accounts within the City of Richmond.

July 2013
Phase 4A:
14,000 Accounts
Complete: Residential, commercial, agricultural, and
street lighting accounts within the unincorporated areas of Napa County, subject to economic and operational
constraints.

February 2015
AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 8 November 2020 – Addendum No. 8
MCE Phase No. Status & Description of Phase Implementation Date
Phase 4B:
30,000 Accounts
Complete: Residential, commercial, agricultural, and
street lighting accounts within the City of San Pablo, the City of Benicia and the City of El Cerrito, subject to
economic and operational constraints.

May 2015
Phase 5:
83,000 Accounts
Complete: Residential, commercial, agricultural, and
street lighting accounts within the Cities of American
Canyon, Calistoga, Lafayette, Napa, Saint Helena,
Walnut Creek and the Town of Yountville.

September 2016
Phase 6:
216,000
Accounts
Complete: Residential, commercial, agricultural, and
street lighting accounts within Contra Costa County
(unincorporated areas); the cities of Concord, Martinez, Oakley, Pinole, Pittsburg and San Ramon; and the
towns of Danville and Moraga.

April 2018
Phase 7:
11,000 Accounts
Complete: Residential, commercial, agricultural, and
street lighting accounts within Solano County
(unincorporated areas).

April 2020
Phase 8:
58,000 Accounts
Pending Customer Enrollment: Residential,
commercial, agricultural, and street lighting accounts
within the cities of Pleasant Hill and Vallejo.

April 2021
(planned)
Phase 9:
38,000 Accounts
Pending Implementation Plan Certification:

Residential, commercial, agricultural, and street lighting accounts within the City of Fairfield.

April 2022
(planned,
pending
Implementation
Plan
Certification)
This approach has provided MCE with the ability to start slow, addressing problems and unforeseen challenges associated with a small, manageable CCA program before offering service to successively larger groups of customers. Following completion of Phase 9 customer enrollments, MCE expects to serve a customer base of approximately 585,000 accounts. This approach has also allowed MCE and its energy suppliers to address all system requirements (billing, collections and payments) under a phase-in approach that was designed to minimize potential exposure to uncertainty and financial risk by “walking” (when serving relatively small account totals) prior to “running” (when serving much larger account totals). The Board may evaluate other phase-in options based on future market conditions, statutory requirements and regulatory considerations as well as other factors potentially affecting the integration of additional customer accounts.

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Resource Plan Overview
With regard to MCE’s resource plan overview, which is addressed in Chapter 6, Load Forecast and Resource Plan, MCE adds the following paragraphs within the sub-section titled “Resource Plan Overview”:

SB 255 (2019) added Section 366.2(c)(3)(H), which requires community choice aggregators to include in their implementation plans “[t]he methods for ensuring procurement from small, local, and diverse business enterprises in all categories, including, but not limited to, renewable energy, energy storage system [sic], and smart grid projects.” As a public agency, MCE is prohibited by Article 1, Section 31 of the California Constitution from granting any preferential treatment to “any individual group on the basis of race, sex, color, ethnicity, or national origin in the operation of public employment, public education, or public contracting.” While these restrictions prevent MCE from “ensuring” procurement from certain diverse businesses, MCE remains committed to local economic development, and has taken several steps to diversify its procurement to the extent possible. MCE will continue to build its strategy and consider new methods for diversifying its procurement as appropriate.

MCE will continue to engage with the diverse business community in its service area and statewide, to inform businesses of the benefits of certification as a diverse business, as well as upcoming Requests for Proposals and other solicitations. While MCE cannot give any preference in the selection process to any business on the basis of race, sex, color, ethnicity, or national origin, MCE can ensure that diverse businesses are aware of upcoming contract opportunities.

MCE will, to the extent possible and reasonable, consider preferences for procurement from diverse business categories that are not prohibited, including but not limited to small and/or local businesses and businesses owned by disabled veterans or lesbian, gay, bisexual and/or transgender individuals (“LGBT”). MCE will consider parallel preferences for prime contractors that demonstrate an intent to contract with diverse subcontractors, as permitted by law.

Sales Forecast
With regard to MCE’s sales forecast, which is addressed in Chapter 6, Load Forecast and Resource Plan, MCE assumes that total annual retail sales will increase to approximately 5,990 GWh following Phase 9 expansion. The following tables have been updated to reflect the impacts of planned expansion to MCE’s new membership.

AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 10 November 2020 – Addendum No. 8
Chapter 6, Resource Plan Overview

Chapter 6, Customer Forecast

2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 MCE Demand (GWh)
Retail Demand -91 -187 -574 -1,116 -1,265 -1,712 -2,241 -2,901 -4,545 -5,543 -5,679 -5,765 -6,253 -6,399 Distributed Generation 0 2 4 5 9 14 135 121 139 472 565 719 827 909 Energy Efficiency 0 0 0 0 1 3 3 5 7 10 16 19 26 33
EV Demand 0 0 0 0 0 0 -22 -29 -38 -75 -95 -357 -445 -534 Losses and UFE -5 -11 -34 -67 -75 -102 -128 -168 -266 -308 -312 -323 -351 -359 Total Demand -97 -197 -604 -1,177 -1,330 -1,797 -2,253 -2,973 -4,703 -5,444 -5,504 -5,707 -6,197 -6,350 MCE Supply (GWh)
Renewable Resources
Generation 0 0 0 0 0 0 0 0 0 0 0 0 0 0
Power Purchase Contracts 23 50 291 566 652 927 1,165 1,631 2,582 3,148 3,199 3,325 3,620 3,725 Total Renewable Resources 23 50 291 566 652 927 1,165 1,631 2,582 3,148 3,199 3,325 3,620 3,725 Conventional/Hydro Resources
Generation 0 0 0 0 0 0 0 0 0 0 0 0 0 0
Power Purchase Contracts 74 147 314 611 678 870 1,088 1,342 2,121 2,296 2,305 2,382 2,576 2,625 Total Conventional/Hydro Resources 74 147 314 611 678 870 1,088 1,342 2,121 2,296 2,305 2,382 2,576 2,625 Total Supply 97 197 604 1,177 1,330 1,797 2,253 2,973 4,703 5,444 5,504 5,707 6,197 6,350 Energy Open Position (GWh) 0 0 0 0 0 0 0 0 0 0 0 0 0 0
Marin Clean Energy
Proposed Resource Plan
(GWH)
2010 to 2023
May-10 Aug-11 Jul-12 Jul-13 Feb-15 May-15 Sep-16 Apr-18 Apr-20 Apr-21 Apr-22 MCE Customers
Residential 7,354 12,503 77,345 106,510 120,204 145,874 225,128 421,325 430,493 485,540 522,629 Commercial & Industrial 579 1,114 9,913 13,098 15,316 17,884 27,274 44,708 46,226 50,627 54,085 Street Lighting & Traffic 138 141 443 748 1,014 1,156 1,866 3,670 3,973 4,470 4,741 Ag & Pumping - <15 113 109 1,467 1,467 1,700 2,051 3,274 3,292 3,314 Total 8,071 13,759 87,814 120,465 138,001 166,381 255,968 471,754 483,966 543,929 584,769 Marin Clean Energy
Enrolled Retail Service Accounts
Phase-In Period (End of Month)
2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 MCE Customers
Residential 7,354 12,503 77,345 106,510 106,510 145,874 225,128 226,254 421,325 423,432 430,493 485,540 522,629 525,242 Commercial & Industrial 579 1,114 9,913 13,098 13,098 17,884 27,274 27,410 44,708 44,932 46,226 50,627 54,085 54,356 Street Lighting & Traffic 138 141 443 748 748 1,156 1,866 1,875 3,670 3,688 3,973 4,470 4,741 4,765 Ag & Pumping - <15 113 109 109 1,467 1,700 1,709 2,051 2,061 3,274 3,292 3,314 3,330 Total 8,071 13,759 87,814 120,465 120,465 166,381 255,968 257,248 471,754 474,113 483,966 543,929 584,769 587,693 Marin Clean Energy
Retail Service Accounts (End of Year)
2010 to 2023
AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 11 November 2020 – Addendum No. 8
Chapter 6, Sales Forecast

Chapter 6, Capacity Requirements

Chapter 6, Renewables Portfolio Standards Energy Requirements

2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 MCE Energy Requirements (GWh)
Retail Demand 91 187 574 1,116 1,265 1,712 2,241 2,901 4,545 5,543 5,679 5,765 6,253 6,399 Distributed Generation 0 -2 -4 -5 -9 -14 -135 -121 -139 -472 -565 -719 -827 -909 Energy Efficiency 0 0 0 0 -1 -3 -3 -5 -7 -10 -16 -19 -26 -33 EV Demand 0 0 0 0 0 0 22 29 38 75 95 357 445 534
Losses and UFE 5 11 34 67 75 102 128 168 266 308 312 323 351 359 Total Load Requirement 97 197 604 1,177 1,330 1,797 2,253 2,973 4,703 5,444 5,504 5,707 6,197 6,350 Energy Requirements
Marin Clean Energy
2010 to 2023
(GWH)
2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 Demand (MW)
Retail Demand 28 46 182 233 234 318 441 682 1,068 1,293 1,445 1,564 1,731 1,835 Distributed Generation - (1) (2) (3) (5) (8) (77) (81) (94) (337) (394) (483) (555) (611) Energy Efficiency - - - - - - (1) (1) (2) (2) (16) (47) (47) (47) EV Load - - - - - - 10 13 18 34 43 92 115 138
Losses and UFE 2 3 11 14 14 19 22 37 59 59 65 68 75 79
Total Net Peak Demand 30 47 191 244 243 328 396 650 1,050 1,048 1,143 1,194 1,319 1,395 Reserve Requirement (%) 15% 15% 15% 15% 15% 15% 15% 15% 15% 15% 15% 15% 15% 15% Capacity Reserve Requirement 4 7 29 37 36 49 59 97 157 157 171 179 198 209 Capacity Requirement Including Reserve 34 55 220 281 279 378 455 747 1,207 1,205 1,314 1,373 1,517 1,604 Marin Clean Energy
Capacity Requirements
(MW)
2010 to 2023
2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 Total Retail Sales (MWh) 91,219 185,493 570,144 1,110,487 1,254,794 1,695,274 2,125,091 2,804,277 4,436,963 5,136,159 5,192,548 5,383,821 5,845,801 5,990,644 RPS Procurement Quantity Requirement (%) 20% 20% 20% 20% 22% 23% 25% 27% 29% 31% 33% 36% 39% 41% Gross RPS Procurement Quantity Requirement (MWh) 18,244 37,099 114,029 222,097 272,290 394,999 531,273 757,155 1,286,719 1,592,209 1,713,541 1,927,408 2,250,633 2,474,136 Marin Clean Energy
2010 to 2023
(MWH)
RPS Requirements
2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 Total Retail Sales (MWh) 91,219 185,493 570,144 1,110,487 1,254,794 1,695,274 2,125,091 2,804,277 4,436,963 5,136,159 5,192,548 5,383,821 5,845,801 5,990,644 Gross RPS Procurement Quantity Requirement (MWh) 18,244 37,099 114,029 222,097 272,290 394,999 531,273 757,155 1,286,719 1,592,209 1,713,541 1,927,408 2,250,633 2,474,136 65% L/T Requirement (2021 Forward) - - - - - - - - - - - 1,252,815 1,462,912 1,608,188 Program Renewable Target (MWh) 24,543 51,525 166,522 364,363 646,619 866,365 1,160,620 1,671,167 2,756,266 3,168,446 3,199,378 3,325,126 3,620,499 3,724,666 Program Target (% of Retail Sales) 27% 28% 29% 33% 52% 51% 55% 60% 62% 62% 62% 62% 62% 62% Voluntary Margin of Overprocurement (MWh) 6,299 14,426 52,493 142,266 374,329 471,366 629,347 914,012 1,469,547 1,576,237 1,485,837 1,397,718 1,369,865 1,250,530 Annual Increase (MWh) 24,543 26,982 114,997 197,841 282,256 219,746 294,255 510,547 1,085,099 412,180 30,932 125,748 295,373 104,167 2010 to 2023
(MWH)
RPS Requirements and Program Renewable Energy Targets
Marin Clean Energy
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Chapter 6, Energy Efficiency
Chapter 6, Demand Response

The “Demand Response” sub-section of Chapter 6 is replaced in its entirety by the following:

Demand response programs provide incentives to customers to reduce demand upon request by the load serving entity (i.e., MCE), reducing the amount of generation capacity that must be maintained as infrequently used reserves. Demand response programs can be cost effective alternatives to capacity otherwise needed to comply with the resource adequacy requirements.

Like energy efficiency, demand response can be a win/win proposition, providing economic benefits to the electric supplier and customer service benefits to the customer.

In an increasingly constrained capacity market, DR programs may assist in suppressing the need for incremental reserve capacity when extreme peak events occur or when capacity is in short supply. MCE continues to explore prospective DR program opportunities, in addition to those currently offered by PG&E, for select customers that may benefit from and are willing to participate in such programs.

Chapter 6, Distributed Generation

2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 MCE Retail Demand 91 187 574 1,116 1,265 1,712 2,241 2,901 4,545 5,543 5,679 5,765 6,253 6,399 MCE Energy Efficiency Goal 0 0 0 0 -1 -3 -3 -5 -7 -10 -16 -19 -26 -33 2010 to 2023
(GWH)
Energy Efficiency Savings Goals
Marin Clean Energy
2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 DG Capacity 1 - 2 3 5 8 77 81 94 337 394 483 555 611
2010 to 2023
(MW)
Distributed Generation Projections
Marin Clean Energy
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Financial Plan
With regard to MCE’s financial plan, which is addressed in Chapter 7, Financial Plan, MCE has updated its expected operating results, which now include projected impacts related to service expansion within the City of Fairfield. The following table reflects updated operating projections in consideration of this planned expansion.

Chapter 7, CCA Program Operating Results

Expansion Addendum Appendices
Appendix A: Marin Clean Energy Resolution No. 2020-03
Appendix B: MCE Joint Powers Agreement
Appendix C: City of Fairfield CCA Ordinance
Appendix D: Marin Clean Energy Revised Implementation Plan and Statement of Intent (July 18, 2014)
CATEGORY 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 I. REVENUES FROM OPERATIONS ($)
ELECTRIC SALES REVENUE 10,610,804 16,454,790 44,052,111 78,782,938 96,577,968 134,474,212 165,289,480 212,418,679 329,232,524 379,396,284 449,235,474 487,861,677 507,195,482 509,251,867 LESS UNCOLLECTIBLE ACCOUNTS (29,176) (140,371) (299,942) (540,077) (662,078) (921,934) (1,126,363) (1,442,225) (2,351,872) (2,642,638) (5,837,119) (6,210,547) (6,747,052) (6,897,804) TOTAL REVENUES 10,581,628 16,314,419 43,752,169 78,242,861 95,915,890 133,552,278 164,163,116 210,976,455 326,880,652 376,753,646 443,398,355 481,651,130 500,448,430 502,354,063 II. COST OF OPERATIONS ($)
(A) ADMINISTRATIVE AND GENERAL (A&G)
STAFFING 321,117 430,659 1,077,759 1,386,303 1,825,000 2,710,500 4,728,650 6,151,600 6,920,156 7,571,804 11,111,500 12,152,413 12,516,985 12,892,494 CONTRACT SERVICES 1,035,333 848,063 3,131,840 4,457,964 4,572,751 4,838,757 6,326,457 7,370,528 9,017,602 9,244,578 14,242,983 15,251,193 16,193,528 16,474,988 IOU FEES (INCLUDING BILLING) 19,548 60,794 287,618 584,729 660,114 877,953 1,124,270 1,261,350 1,775,059 1,873,962 2,117,967 2,364,322 2,641,454 2,766,705 OTHER A&G 191,261 189,204 249,729 302,806 373,125 610,500 791,750 1,284,784 1,398,107 2,057,959 2,201,000 2,433,550 2,506,557 2,581,753 SUBTOTAL A&G 1,567,259 1,528,720 4,746,946 6,731,802 7,430,990 9,037,711 12,971,126 16,068,262 19,110,924 20,748,303 29,673,450 32,201,477 33,858,523 34,715,941 (B) COST OF ENERGY 7,418,662 11,881,494 35,805,704 68,624,319 84,358,061 118,264,445 144,457,641 190,345,081 264,842,182 297,178,130 370,318,597 419,276,178 433,955,787 426,194,534 (C) DEBT SERVICE 654,595 394,777 747,729 1,195,162 1,195,162 2,451,457 458,000 228,875 21,945 82,833 218,000 218,000 218,000 218,000 TOTAL COST OF OPERATION 9,640,516 13,804,991 41,300,380 76,551,283 92,984,212 129,753,613 157,886,767 206,642,218 283,975,051 318,009,266 400,210,047 451,695,654 468,032,310 461,128,474 CCA PROGRAM SURPLUS/(DEFICIT) 941,112 2,509,428 2,451,789 1,691,578 2,931,677 3,798,665 6,276,350 4,334,236 42,905,601 58,744,380 43,188,308 29,955,476 32,416,120 41,225,589 Marin Clean Energy
Summary of CCA Program Phase-In
(January 2010 through December 2023)
AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan RESOLUTION NO. 2020-03

A RESOLUTION OF THE BOARD OF DIRECTORS OF MCE APPROVING THE CITY

OF FAIRFIELD AS A MEMBER OF MCE
WHEREAS, on September 24, 2002, the Governor signed into law Assembly Bill 117 (Stat. 2002, Ch. 838; see California Public Utilities Code section 366.2; hereinafter referred to as the “Act”), which authorizes any California city or county, whose governing body so elects, to combine the electricity load of its residents and businesses in a community-wide electricity aggregation program known as Community Choice Aggregation (“CCA”); and,
WHEREAS, the Act expressly authorizes participation in a CCA program through a joint powers agency, and on December 19, 2008, Marin Clean Energy (“MCE”), (formerly the Marin Energy Authority) was established as a joint power authority pursuant to a Joint Powers Agreement, as amended from time to time (“MCE Joint Powers Agreement”); and,
WHEREAS, on February 2, 2010, the California Public Utilities Commission certified the “Implementation Plan” of MCE, confirming MCE’s compliance with the requirements of the Act; and,
WHEREAS, MCE members include the following communities: the County of Contra Costa, the County of Marin, the County of Napa, the County of Solano, the City of American Canyon, the City of Belvedere, the City of Benicia, the City of Calistoga, the City of Concord, the Town of Corte Madera, the Town of Danville, the City of El Cerrito, the Town of Fairfax, the City of Lafayette, the City of Larkspur, the City of Martinez, the City of Mill Valley, the City of Moraga, the City of Napa, the City of Novato, the City of Oakley, the City of Pinole, the City of Pittsburg, the City of Pleasant Hill, the City of Richmond, the Town of Ross, the Town of San Anselmo, the City of San Pablo, the City of San Rafael, the City of San Ramon, the City of Sausalito, the City of St. Helena, the Town of Tiburon, the City of Vallejo, the City of Walnut Creek, and the Town of Yountville; and
WHEREAS, requested membership in MCE was made by the City of Fairfield, December 17, 2019; and,
WHEREAS, the ordinance approving membership in MCE was approved by the City of Fairfield; and,
WHEREAS, the applicant analysis for the City of Fairfield was completed on October 22, 2020, and yielded a positive result;
NOW, THEREFORE, BE IT RESOLVED AND ORDERED, by the Board of Directors of MCE that the City of Fairfield is approved as a member of MCE.

PASSED AND ADOPTED at a regular meeting of the MCE Board of Directors on the nineteenth day of November, 2020 by the following vote:

DocuSign Envelope ID: 0102F6A6-DF24-471A-A644-A55E2D3E9A30 DocuSign Envelope ID: 62B4AA17-12D3-445F-BEE6-B42A88FADC36 APPENDIX A AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan

AYES NOES ABSTAIN ABSENT
County of Marin X
Contra Costa County X
County of Napa X
County of Solano X
City of American Canyon X
City of Belvedere X
City of Benicia X
City of Calistoga X
City of Concord X
Town of Corte Madera X
Town of Danville X
City of El Cerrito X
Town of Fairfax X
City of Lafayette X
City of Larkspur X
City of Martinez X
City of Mill Valley X
Town of Moraga X
City of Napa X
City of Novato X
City of Oakley X
City of Pinole X
City of Pittsburg X
City of Pleasant Hill X
City of San Ramon X
City of Richmond X
Town of Ross X
Town of San Anselmo X
City of San Pablo X
City of San Rafael X
City of Sausalito X
City of St. Helena X
Town of Tiburon X
City of Vallejo X
DocuSign Envelope ID: 0102F6A6-DF24-471A-A644-A55E2D3E9A30 DocuSign Envelope ID: 62B4AA17-12D3-445F-BEE6-B42A88FADC36 APPENDIX A AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan City of Walnut Creek X
Town of Yountville X

KATE SEARS, CHAIR
ATTEST:
_ _

DAWN WEISZ, SECRETARY
DocuSign Envelope ID: 0102F6A6-DF24-471A-A644-A55E2D3E9A30 DocuSign Envelope ID: 62B4AA17-12D3-445F-BEE6-B42A88FADC36 APPENDIX A AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan CE0288196CE54AS ...

Appendix B: MCE Joint Powers Agreement
Omitted for this February 3, 2023 Executive Committee Packet due to the JPA being provided as a standalone attachment.

AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan APPENDIX C AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan

CITY OF FAIRFIELD
ORDINANCE NO. 2019-11
'

ORDINANCE OF THE CITY COUNCIL OF THE CITY OF FAIRFIELD AUTHORIZING

THE IMPLEMENTATION OF A COMMUNITY CHOICE AGGREGATION PROGRAM

IN THE CITY OF FAIRFIELD AND AUTHORIZING THE CITY MANAGER TO

EXECUTE THE MARIN CLEAN ENERGY JOINT POWERS AGREEMENT
WHEREAS, on September 24, 2002, the Governor of California signed into law Assembly Bill 117 (Statute 2002, Chapter 838; see California Public Utilities Code section 366.2; hereinafter referred to as the "Act"), which authorizes any California city or county, whose governing body so elects, to combine electricity load of its residents and businesses in a Community Choice Aggregation program (CCA); and
WHEREAS, on September 27, 2006, Assembly Bill 32 (AB 32), the Global Warming Solutions Act, was signed into law establishing the goal of reducing California's greenhouse gas (GHG) emissions to 1990 levels by 2020; and WHEREAS, the Act expressly authorizes participation in a CCA through a joint powers agency, and on December 19, 2008, Marin Clean Energy (MCE) was established as a joint powers authority pursuant to a Joint Powers Agreement, as amended from time to time; and
WHEREAS, on February 2, 2010, the California Public Utilities Commission certified the "Implementation Plan" of MCE, confirming MCE's compliance with the requirements of the Act; and
WHEREAS, currently electricity is generated and provided to the residents of the City of Fairfield by Pacific Gas and Electric Company (PG&E) with no alternative provider for the City of Fairfield; and
WHEREAS, although PG&E is currently meeting the 33% renewable ,portfolio standard in its power mix as required by Executive Order-S-14-08, the City of Fairfield is committed to the development of renewable energy generation and energy efficiency improvements, reduction of GHG's, and protection of the environment in supporting MCE's electricity procurement plan that offers customers a minimum energy content of 60% renewable to up to 100% renewable; and
WHEREAS, MCE primarily sources its electrical energy from non-polluting renewables such as solar, wind, geothermal, bioenergy and hydroelectric; and WHEREAS, the City of Fairfield finds it important that its residents, businesses and public facilities have alternative choices to energy procurement beyond PG&E; and APPENDIX C AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan ORD. NO. 2019-11
Page2
WHEREAS, the City of Fairfield finds that joining MCE will offer customers choice in their provider of electric generation and help meet the GHG emission reduction goals of AB 32;and
WHEREAS, the City of Fairfield finds that joining a CCA does not constitute a "project" within the meaning of the Public Resources Code Section 21065, 14 California Code of Regulations Section 15060(c){3), or 14 California Code of Regulations Section 15378 because it has no potential for resulting in either a direct physical change in the environment, or a reasonably foreseeable indirect physical change in the environment, and involves administrative activities that will not result in direct or indirect physical changes in the environment; and
WHEREAS, the MCE Joint Powers Agreement requires the City of Fairfield to individually adopt a resolution requesting membership in the MCE Joint Powers Authority and adopt an ordinance electing to implemen·t a CCA within its jurisdiction. !

NOW THEREFORE, THE COUNCIL OF THE CITY OF FAIRFIELD DOES ORDAIN AS FOLLOWS:

Section 1. The recitals above are true and correct and are incorporated by this reference and constitute findings in this matter.

Section 2. Joining a CCA does not constitute a "project" within the meaning of Public Resources Code Section 21065, 14 California Code of Regulations Section 15060(c)(3), or 14 California Code of Regulations Section 15378.

Section 3. The City Counci_l of the City of Fairfield authorizes the implementation of a Community Choice Aggregation Program in the City of Fairfield and authorizes the City Manager to execute the MCE Joint Powers Agreement.

Section 4. Any portion of this ordinance deemed invalid or unenforceable shall be severed from the remainder, which shall remain in full force and effect.

Section 5. This ordinance shall take effect 30 days after its adoption.

Section 6. A summary of this ordinance will be published within 15 days after its adoption in the Fairfield Daily Republic, a newspaper of general circulation in the City of Fairfield.

APPENDIX C AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan ORD. NO. 2019-11

INTRODUCED at a regular meeting of the City Council of the City of Fairfield on the 3rd day of December, 2019, and
PASSED AND ADOPTED this 17th day of December, 2019, by the following vote:

AYES: COUNCILMEMBERS: PRICE/ BERT/\NI /MOY/ TIMM/ VACCARO NOES: COUNCILMEMBERS: ----ftNtt-O-N-E----------
ABSENT: COUNCILMEMBERS: _ ....... ·B~e_r_f-~~---'-1(_0 -------- ABSTAIN: COUNCILMEMBERS: NONE ----------------
A~t~ CffY ERK

MARIN CLEAN ENERGY

REVISED COMMUNITY CHOICE

AGGREGATION

IMPLEMENTATION PLAN AND

STATEMENT OF INTENT
July 18, 2014
For copies of this document contact Marin Clean Energy in San Rafael, California or visit www.mcecleanenergy.org
APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan MC E Clean Energy
My commun1t . y choice.
i July 2014
Table of Contents
CHAPTER 1 – Introduction ..................................................................................................................................... 3 Organization of this Implementation Plan ........................................................................................................ 6 CHAPTER 2 – Aggregation Process ....................................................................................................................... 8 Introduction ........................................................................................................................................................... 8 Process of Aggregation ........................................................................................................................................ 8 Consequences of Aggregation ............................................................................................................................ 9 Rate Impacts ................................................................................................................................................ 9 Renewable Energy Impacts ....................................................................................................................... 9 Energy Efficiency Impacts ....................................................................................................................... 10 CHAPTER 3 – Organizational Structure ............................................................................................................. 11 Organizational Overview .................................................................................................................................. 11 Governance .......................................................................................................................................................... 12 Officers ................................................................................................................................................................. 12 Committees .......................................................................................................................................................... 12 Addition/Termination of Participation ............................................................................................................ 12 Agreements Overview ....................................................................................................................................... 13 Joint Powers Agreement .................................................................................................................................... 13 Program Agreement No. 1................................................................................................................................. 13 Agency Operations ............................................................................................................................................. 14 Resource Planning .............................................................................................................................................. 14 Portfolio Operations ........................................................................................................................................... 14 Operations & Local Energy Programs ............................................................................................................. 15 Rate Setting .......................................................................................................................................................... 16 Financial Management/Accounting ................................................................................................................. 16 Customer Services .............................................................................................................................................. 16 Legal and Regulatory Representation .............................................................................................................. 17 Roles and Functions ........................................................................................................................................... 17 Staffing ................................................................................................................................................................. 18 CHAPTER 4 – CCA Startup .................................................................................................................................. 20 Staffing Requirements ........................................................................................................................................ 20 CHAPTER 5 – Program Phase-In ......................................................................................................................... 22 CHAPTER 6 - Load Forecast and Resource Plan ............................................................................................... 23 Introduction ......................................................................................................................................................... 23 Resource Plan Overview .................................................................................................................................... 24 Supply Requirements ......................................................................................................................................... 25 Customer Participation Rates ............................................................................................................................ 25 Customer Forecast .............................................................................................................................................. 26 Sales Forecast ....................................................................................................................................................... 27 Capacity Requirements ...................................................................................................................................... 27 Renewable Portfolio Standards Energy Requirements ................................................................................. 28 Basic RPS Requirements .......................................................................................................................... 28 MCE’s Renewable Portfolio Standards Requirement.......................................................................... 29 Resources ............................................................................................................................................................. 29 Purchased Power ................................................................................................................................................ 30 Renewable Resources ......................................................................................................................................... 30 APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan ii July 2014
Medium and Long-Term Renewable Potential .................................................................................... 31 Energy Efficiency ................................................................................................................................................ 31 Baseline Energy Efficiency Potential Estimates .................................................................................... 32 CCA Program Energy Efficiency Goals ................................................................................................. 32 Demand Response .................................................................................................................................... 33 Distributed Generation ...................................................................................................................................... 34 CHAPTER 7 – Financial Plan ................................................................................................................................ 36 Description of Cash Flow Analysis .................................................................................................................. 36 Cost of CCA Program Operations .................................................................................................................... 36 Revenues from CCA Program Operations ...................................................................................................... 36 Cash Flow Analysis Results .............................................................................................................................. 37 CCA Program Implementation Feasibility Analysis ..................................................................................... 37 Marin Clean Energy Financings ....................................................................................................................... 38 CCA Program Start-up and Working Capital (Phases 1 and 2) ................................................................... 38 CCA Program Working Capital (Phase 3) ....................................................................................................... 38 CCA Program Working Capital (Phase 4) ....................................................................................................... 39 Renewable Resource Project Financing ........................................................................................................... 39 CHAPTER 8 - Ratesetting and Program Terms and Conditions ...................................................................... 40 Introduction ......................................................................................................................................................... 40 Rate Policies ......................................................................................................................................................... 40 Rate Competitiveness ......................................................................................................................................... 40 Rate Stability ........................................................................................................................................................ 41 Equity among Customer Classes ...................................................................................................................... 41 Customer Understanding .................................................................................................................................. 41 Revenue Sufficiency ........................................................................................................................................... 41 Rate Design .......................................................................................................................................................... 42 Net Energy Metering .......................................................................................................................................... 42 Disclosure and Due Process in Setting Rates and Allocating Costs among Participants ......................... 42 CHAPTER 9 – Customer Rights and Responsibilities ....................................................................................... 44 Customer Notices ............................................................................................................................................... 44 Termination Fee .................................................................................................................................................. 45 Customer Confidentiality .................................................................................................................................. 46 Responsibility for Payment ............................................................................................................................... 46 Customer Deposits ............................................................................................................................................. 46 CHAPTER 10 - Procurement Process ................................................................................................................... 48 Introduction ......................................................................................................................................................... 48 Procurement Methods ........................................................................................................................................ 48 Key Contracts ...................................................................................................................................................... 48 Electric Supply Contract .......................................................................................................................... 48 Data Management Contract .................................................................................................................... 49 Electric Supply Procurement Process .................................................................................................... 50 Shell Energy North America ................................................................................................................... 50 CHAPTER 11 – Contingency Plan for Program Termination .......................................................................... 51 Introduction ......................................................................................................................................................... 51 Termination by Marin Clean Energy ............................................................................................................... 51 Termination by Members .................................................................................................................................. 52 CHAPTER 12 – Appendices .................................................................................................................................. 53 APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 3 July 2014
CHAPTER 1 – Introduction
Marin Clean Energy (“MCE”; MCE was formerly known as the “Marin Energy Authority” or “MEA”), a public agency, was formed in December 2008 for the purposes of implementing a community choice aggregation (“CCA”) program and other energy-related programs targeting significant greenhouse gas emissions (“GHG”) reductions. At that time, the Member Agencies of MCE included eight of the twelve municipalities located within the geographic boundaries of Marin County: the cities/towns of Belvedere, Fairfax, Mill Valley, San Anselmo, San Rafael, Sausalito and Tiburon and the County of Marin (together the “Members” or “Member Agencies”). In anticipation of CCA program implementation and in compliance with state law, MCE submitted the Marin Energy Authority Community Choice Aggregation Implementation Plan and Statement of Intent (“Implementation Plan”) to the California Public Utilities Commission (“CPUC” or “Commission”) on December 9, 2009. Consistent with its expressed intent, MCE successfully launched its CCA program, Marin Clean Energy (“MCE” or “Program”), on May 7, 2010 and has been successfully serving customers since that time.

During the second half of 2011, four additional municipalities within Marin County, the cities of Novato and Larkspur and the towns of Ross and Corte Madera, joined MCE, and a revised Implementation Plan reflecting updates related to said expansion was filed with the CPUC on December 3, 2011.

Subsequently, the City of Richmond, located in Contra Costa County, joined MCE, and a revised Implementation Plan reflecting updates related to this expansion was filed with the CPUC on July 6, 2012.

A revision to MCE’s Implementation Plan was then filed with the Commission on November 6, 2012 to ensure compliance with Commission Decision 12-08-045, which was issued on August 31, 2012. In Decision 12-08-045, the Commission directed existing CCA programs to file revised Implementation Plans to conform to the privacy rules in Attachment B of this Decision.

Since its expansion to the City of Richmond, numerous communities have contacted MCE regarding membership opportunities, including specific requests to join MCE and initiate related CCA service within these respective jurisdictions. In response to these inquiries, MCE’s governing board adopted Policy 007, which establishes a formal process and specific criteria for new member additions. In particular, this policy identifies several threshold requirements, including the specification that any prospective member evaluation demonstrate rate-related savings (based on prevailing market prices for requisite energy products at the time of each analysis) as well as environmental benefits (as measured by anticipated reductions in greenhouse gas emissions and increased renewable energy sales to CCA customers) before proceeding with expansion activities, including the filing of related revisions to this Implementation Plan. As MCE receives new membership requests, staff will follow the prescribed evaluative process of Policy 007 and will present related results at future public meetings. To the extent that membership evaluations demonstrate favorable results and any new community completes the process of joining MCE, this Implementation Plan will be APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 4 July 2014
revised through an amendment to highlight key impacts and consequences related to the addition of the new community/communities.

Also, consistent with MCE’s mission statement, MCE launched its first energy efficiency portfolio in late 2012, initially providing multi-family energy efficiency services to MCE customers only. In early 2013, MCE launched a portfolio of energy efficiency programs available to all ratepayers in its service territory, not just MCE customers. Energy efficiency and other local programs continue to be a robust and growing portion of MCE’s operating activities.

MCE gives electric customers of the Member Agencies an opportunity to procure electricity from competitive suppliers, with such electricity being delivered over PG&E’s transmission and distribution system. To date, the electricity delivered to MCE customers has included over 27 percent Renewables Portfolio Standard (“RPS”) qualifying renewable energy, an amount which has surpassed all reporting entities, including the incumbent utility. Over the course of MCE’s phased implementation schedule, all current PG&E customers within MCE’s service area will receive information describing the Program and will have multiple opportunities to express their desire to remain bundled customers of PG&E, in which case they will not be enrolled in the Program. Thus, participation in the CCA Program is completely voluntary; however, customers, as provided by law, will be automatically enrolled unless they affirmatively elect to opt-out of the CCA Program.

The MCE program has received considerable interest from other communities in response to its innovative, environmentally-focused energy service alternative, which now provides electric generation service to approximately 120,000 customers, including a cross section of residential and commercial accounts. During its four-year operating history, non-member municipalities have monitored MCE progress, evaluating the potential opportunity for membership, which would enable customer choice with respect to electric generation service. In response to public interest and MCE’s successful operational track record, the County of Napa has requested MCE membership, consistent with MCE Policy 007, and adopted the requisite ordinances for joining MCE. MCE’s Board of Directors approved the County of Napa’s membership request at a duly noticed public meeting on June 5, 2014 (through the approval of Resolution No. 2014-03) and the County of Napa’s Board of Supervisors completed its final reading of the requisite CCA ordinance (Ordinance No. 1391) on July 15, 2014.

This revision of the Marin Clean Energy Community Choice Aggregation Implementation Plan and Statement of Intent (“Revised Implementation Plan”) describes MCE’s expansion plans to include the County of Napa. According to the Commission, the Energy Division is required to receive and review a revised MCE implementation plan reflecting changes/consequences of additional members. With this in mind, MCE has reviewed its revised Implementation Plan, which was filed with the Commission on November 6, 2012, and has identified certain information that requires updating to reflect the changes and consequences of adding the new member and to address MCE’s name change (from MEA to MCE), which occurred via Resolution No. 2013-11 of MCE’s Governing Board on December 5, 2013. This Revised Implementation Plan reflects such changes and includes related projections that account for MCE’s planned expansion.

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 5 July 2014
Implementation of MCE has enabled customers within MCEs service area to take advantage of the opportunities granted by Assembly Bill 117 (“AB 117”), the Community Choice Aggregation Law. MCE’s primary objective in implementing this Program continues to focus on increased utilization of renewable energy supplies for the purpose of promoting significant GHG emissions reductions. To date, MCE has achieved this objective by offering customers two energy supply options: 1) a minimum 50 percent renewable content, which will be the default service option for participating customers1; or 2) 100 percent renewable content. The prospective benefits to consumers include a substantial increase in renewable energy supply, stable and competitive electric rates, public participation in determining which technologies are utilized to meet local electricity needs, and local/regional economic benefits.

To ensure successful operation of the MCE program, MCE has received assistance from experienced energy suppliers and contractors in providing energy services to Program customers. As a result of a competitive solicitation process and subsequent contract negotiations, a highly qualified firm, Shell Energy North America (“SENA”) was selected as MCE’s initial energy services provider and scheduling coordinator. Since this initial solicitation, MCE has completed numerous procurement activities in an effort to accommodate the increasing electric energy requirements of a growing customer base, including the execution of various power purchase agreements with new and existing renewable energy projects. Such purchases have served to diversify MCE’s energy supply portfolio, reflecting the use of multiple fuel sources, contract term lengths and resource locations, among other considerations. To serve the increasing energy requirements resulting from expanded membership MCE anticipates that its existing supply agreement with SENA may be amended and/or supplemented with additional purchases from other qualified suppliers of requisite energy products to reflect the Program’s increased future needs. Information regarding SENA is contained in Chapter 10.

MCE’s Implementation Plan reflects a collaborative effort among MCE, its Members, and the private sector to bring the benefits of competition and choice to Member residents and businesses. By exercising its legal right to form a CCA Program, MCE has enabled its Members’ constituents to access the competitive market for energy services and obtain access to increased renewable energy supplies and resultant reductions in GHG emissions. Absent action by MCE or its individual Members, most customers would have no ability to choose an electric supplier and would remain captive customers of their incumbent utility.

The California Public Utilities Code provides the relevant legal authority for MCE to become a Community Choice Aggregator and invests the California Public Utilities Commission (“CPUC” or “Commission”) with the responsibility for establishing the cost recovery mechanism that must be in place before customers can begin receiving electrical service through MCE’s CCA Program. The CPUC has also registered MCE as a Community Choice Aggregator and continues to ensure compliance with basic consumer protection rules. The Public Utilities Code requires that an Implementation Plan be adopted at a duly noticed public hearing and

1 MCE customers received nearly 29 percent RPS-qualifying renewable energy in 2013. The default renewable energy content, which includes RPS-qualifying renewable energy and supplemental renewable energy credit purchases, was voluntarily increased from 25% to 50% beginning in January, 2012.

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 6 July 2014
that it be filed with the Commission in order for the Commission to determine the cost recovery mechanism to be paid by customers of the Program in order to prevent shifting of costs. Each of these milestones has been accomplished. The Commission has established the methodology that will be used to determine the cost recovery mechanism, and PG&E now has approved tariffs for imposition of the cost recovery mechanism. Finally, each of MCE’s Members has adopted an ordinance to implement a CCA program through its participation in MCE (copies of the ordinance adopted by MCE’s newest member, the County of Napa, is included as Appendix D). Following the CPUC’s certification of its receipt of this Revised Implementation Plan and resolution of any outstanding issues, MCE will take the final steps needed to expand CCA service to MCE’s new member, including customer notification and enrollment.

Organization of this Implementation Plan
The content of this Revised Implementation Plan complies with the statutory requirements of AB 117. Because MCE has already successfully implemented its CCA program, this Revised Implementation Plan includes narrative discussion, updates and projections focused on on-going operation and expansion of the MCE program rather than previously completed implementation efforts. As a result, certain sections of this document are now substantially abbreviated. Consistent with requirements identified in PU Code Section 366.2(c)(4), this Revised Implementation Plan addresses:
 Universal access;
 Reliability;
 Equitable treatment of all customer classes; and
 Any requirements established by state law or by the CPUC concerning aggregated service.

To promote consistency with MCE’s original January 25, 2010 Implementation Plan, the remainder of this Revised Implementation Plan is organized as follows:

Chapter 2: Aggregation Process
Chapter 3: Organizational Structure
Chapter 4: CCA Startup
Chapter 5: Program Phase-In
Chapter 6: Load Forecast and Resource Plan
Chapter 7: Financial Plan
Chapter 8: Ratesetting
Chapter 9: Customer Rights and Responsibilities
Chapter 10: Procurement Process
Chapter 11: Contingency Plan for Program Termination
Appendix A: Marin Clean Energy Resolution 2014-03
Appendix B: County of Napa, Resolution 2014-59
Appendix C: Joint Powers Agreement
Appendix D: County of Napa, CCA Ordinance – Ordinance No. 1391 The requirements of AB 117 are cross-referenced to Chapters of this Implementation Plan in the following table.

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 7 July 2014
AB 117 Cross References
AB 117 REQUIREMENT IMPLEMENTATION PLAN CHAPTER
Process and consequences of aggregation Chapter 2: Aggregation Process Organizational structure of the program,
its operations and funding
Chapter 3: Organizational Structure
Chapter 4: Startup Plan and Funding
Chapter 7: Financial Plan
Ratesetting and other costs to participants Chapter 8: Ratesetting Chapter 9: Customer Rights and
Responsibilities
Disclosure and due process in setting rates
and allocating costs among participants
Chapter 8: Ratesetting
Methods for entering and terminating
agreements with other entities
Chapter 10: Procurement Process
Participant rights and responsibilities Chapter 9: Customer Rights and Responsibilities
Termination of the program Chapter 11: Contingency Plan for Program Termination
Description of third parties that will be
supplying electricity under the program,
including information about financial,
technical and operational capabilities
Chapter 10: Procurement Process
Statement of Intent Chapter 1: Introduction
APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 8 July 2014
CHAPTER 2 – Aggregation Process
Introduction
As previously noted, MCE successfully launched its CCA Program, MCE, on May 7, 2010 after meeting applicable statutory requirements and in consideration of planning elements described in its January 25, 2010 Implementation Plan. At this point in time, MCE plans to expand agency membership to include the County of Napa. This community has requested MCE membership, and MCE’s Board of Directors subsequently approved the membership request at a duly noticed public meeting.

As planned, the residents and businesses within MCE’s expanded service territory will be offered electric generation service from MCE’s currently operating CCA program, MCE, which represents a culmination of planning efforts that are responsive to the expressed needs and priorities of the citizenry and business community within the region. Through the MCE program eligible customers have received expanded energy choices, including the creation of a 100% renewable energy product and 100% local solar product. In effect, MCE provides Marin residents and businesses with four electric service options, which include: 1) the default 50% (minimum) renewable energy service option – Light Green; 2) a 100% renewable energy service option – Deep Green – which can be chosen on a voluntary basis; 3) a 100% local solar energy service option – Sol Shares – in which customers can enroll on a voluntary basis2; or 4) bundled energy service from the incumbent utility. It remains MCE’s long-term goal to supply its customers entirely with clean, renewable energy, subject to economic and operational constraints.

Each of the Member Agencies has adopted an ordinance to implement a CCA program through its participation in MCE. A Revised Implementation Plan was adopted at a duly noticed public hearing of MCE on June 5, 2014.

Process of Aggregation
All customers currently enrolled in the MCE program were appropriately noticed. Before additional phases of customers are enrolled in the Program, MCE will mail at least two written notices to customers, beginning at least two calendar months, or sixty days, in advance of the date of commencing automatic enrollment, that will provide information needed to understand the Program’s terms and conditions of service and explain how these customers can opt-out of the Program, if desired. All customers that do not follow the opt-out process specified in the customer notices will be automatically enrolled, and service will begin at their next regularly scheduled meter read date at least one calendar month, or thirty days following the date of automatic enrollment, subject to the service phase-in plan described in Chapter 5. At least two follow-up opt-out notices will be mailed to these customers within the first two calendar months, or sixty days, of service.

2 The Sol Shares program is currently accepting customer enrollments but will not begin delivering electric power to participating customers until the 2015 calendar year. In the meantime, Sol Shares enrollees may continue taking MCE service under the Light Green or Deep Green service options.

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 9 July 2014
Customers enrolled in the Program will continue to have their electric meters read and be billed for electric service by the distribution utility (PG&E). The electric bill for Program customers will show separate charges for generation procured by the Program and all other charges related to delivery of the electricity and other utility charges that will continue to be assessed by PG&E.

After service cutover, customers will be given two additional opportunities to opt-out of the Program and return to the distribution utility (PG&E) following receipt of their first and second bills. Customers that opt-out between the initial cutover date and the close of the post enrollment opt-out period will be responsible for program charges for the time they were served by MCE but will not otherwise be subject to any penalty for leaving the program.

Customers that have not opted-out within thirty days of the fourth opt-out notice will be deemed to have elected to become a participant in the Program and to have agreed to the Program’s terms and conditions, including those pertaining to requests for termination of service, as further described in Chapter 8.

Consequences of Aggregation
Rate Impacts
Customers will pay the generation charges set by MCE and no longer pay the costs of PG&E generation. Customers enrolled in the Program will be subject to the Program’s terms and conditions, including responsibility for payment of all Program charges as described in Chapter

9. MCE’s rate setting policies are described in Chapter 7. MCE will establish rates sufficient to recover all costs related to operation of the Program, and actual rates will be adopted by MCE’s governing board.

Information regarding current Program rates will be disclosed along with other terms and conditions of service in the pre-enrollment opt-out notices sent to potential customers.

Program customers are not expected to be responsible in any way for costs associated with the utilities’ future electricity procurement contracts or power plant investments that are made on behalf of utility bundled service customers. Certain pre-existing generation costs will continue to be charged by PG&E to CCA customers through a separate rate component, called the Cost Responsibility Surcharge or CRS. This charge is shown in PG&E’s tariff, which can be accessed from the utility’s website.

Renewable Energy Impacts
The MCE program has substantially increased the proportion of energy generated and supplied to its customers by renewable resources. The resource plan includes procurement of renewable energy sufficient to meet a minimum of 50 percent of the Program’s electricity needs.

Customers of MCE may voluntarily participate in a 100 percent renewable supply option. To the extent that customers choose to participate in this voluntary program, the renewable content of MCE’s power supply would increase. The renewable energy requirements of MCE customers are being supplied through contractual arrangements, but may be delivered, at an indeterminate point in the future, by new renewable generation resources developed by or for APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 10 July 2014
MCE subject to then-current considerations (such as development costs, regulatory requirements and other concerns).

Energy Efficiency Impacts
Energy efficiency is an important component of the MCE mission statement. MCE currently administers over $4 million in ratepayer funded energy efficiency programs under the purview of the California Public Utilities Commission. MCE launched energy efficiency programs in late 2012 under the authority of Public Utilities Code section 381.1 (e-f). This 2012 plan focused specifically on providing multi-family energy efficiency services to MCE customers only. In early 2013, MCE launched a full portfolio of energy efficiency services, available to all ratepayers in MCE service territory, under the authority in PUC 381.1 (a-d). Energy efficiency is included in the MCE Integrated Resources Plan, and both local energy efficiency potential and energy efficiency accomplishments are utilized to inform future estimates of procurement needs. This relationship is described further in Chapter 6.

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 11 July 2014
CHAPTER 3 – Organizational Structure
This section provides an overview of the organizational structure of MCE Organizational Overview
The MCE program is governed by MCE’s Board of Directors (“Board”), appointed by the Members. MCE is a joint powers agency created in December 2008 and formed under California law. Originally, the County of Marin and eight municipalities within the geographic boundaries of the County became Members of MCE and elected to offer the Program to their constituents. Since that time, the remaining four municipalities within Marin, which include the cities of Novato and Larkspur and the towns of Ross and Corte Madera, have requested and received approval for MCE membership as has the City of Richmond and, most recently, the County of Napa. MCE (formerly known as “The Marin Energy Authority”) is the CCA entity that has registered with the CPUC and has been responsible for implementing and managing the program pursuant to MCE’s Joint Powers Agreement (“JPA Agreement” or “Agreement”).

The Program is operated under the direction of an Executive Officer, who has been appointed by the Board. The Executive Officer reports to the Board comprised of one representative from each participating Member of MCE. Those who are eligible to serve as representatives on the Board include elected officials from the then-current County Board of Supervisors representing Marin County as well as the County of Napa (one Board representative has been selected from the Marin County Board of Supervisors; another Board representative, who will soon begin serving on MCE’s governing board, has been selected by the County of Napa’s Board of Supervisors) and the City and Town Councils (one representative has been selected from each of the City and Town Councils) of the Members.

The Board’s primary duties are to establish program policies, set rates and provide policy direction to the Executive Officer, who has general responsibility for program operations, consistent with the policies established by the Board. The Board has also determined necessary staffing levels, individual titles and related compensation ranges for the organization. The Board may also adjust staffing levels and compensation over time in response to varying workloads, specific programs and/or general responsibilities of MCE.

The Executive Officer is an employee of MCE, and the Board is responsible for evaluating the Executive Officer’s performance.

The Board has established a Chairman and other officers from among its membership and has established an Executive Committee and Technical Committee and may establish other committees and sub-committees as needed to address issues that require greater expertise in particular areas (e.g., finance or contracts). MCE may also establish an “Energy Commission” formed of Board-selected designees. The Energy Commission would have responsibility for evaluating various issues that may affect MCE and its customers, including rate setting, and would provide analytical support and recommendations to the Board in these regards.

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 12 July 2014
The Executive Officer has responsibilities over the functional areas of Finance, Regulatory Affairs, and Operations. In performing these responsibilities, the Executive Officer utilizes a combination of internal staff and contractors. Certain specialized functions needed for program operations, namely the electric supply and customer account management functions described below, are performed by experienced third-party contractors.

Governance
MCE has a Board of Directors consisting of one representative from each Member. Following satisfaction of certain administrative conditions, the Board will soon add an additional representative from the County of Napa. The Board meets at regular intervals to provide the overall management and guidance for MCE. All Board meetings are public and held in accordance with the Ralph M. Brown Act.

Decisions by MCE are under voting procedures defined in the JPA Agreement, attached hereto as Appendix C. All votes on a particular matter are subject to the two-tiered approval process described in the JPA Agreement.

Officers
MCE has a Chair and Vice-Chair elected to one-year terms by the Board of Directors. Both the Chair and Vice-Chair must be members of the Board. In addition, MCE has a Board Clerk and Auditor; neither of which will be members of the Board of Directors. The JPA Agreement provides further detail with respect to each of these positions.

Committees
MCE may form various committees comprised of Board designees from the Member communities. Appointments would be made based on various skill sets and expertise that will be useful in evaluating matters affecting MCE and its customers, specifically issues related to rate setting, procurement of energy products and other technical matters. These committees would provide the Board with recommendations and related analysis to support policy-level decisions of the Board. MCE may elect to have additional committees or working groups to address various topics. Any additional committees and their functions will be determined by the Board of Directors at the time each committee is created. At present, MCE has formed the following standing committees: 1) the Executive Committee; and 2) the Technical Committee.

MCE also utilizes Ad Hoc Committees from time to time on an as-needed basis.

Addition/Termination of Participation
The JPA Agreement provides for the addition of new participants subject to the affirmative vote of MCE’s Board of Directors pursuant to the voting structure described in the Agreement. The Board has determined the specific terms and conditions under which new Members can be admitted and has recently approved the membership request received from the County of Napa. Following the satisfaction of certain administrative requirements determined by the APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 13 July 2014
Board, a representative from the new Member will be added to the Board and will begin participating in governance activities.

A JPA Member can withdraw itself from the JPA subject to the specific terms and conditions contained in the JPA Agreement.

Agreements Overview
There are two principal agreements that govern MCE and the initial operation of its CCA Program: the JPA Agreement and Program Agreement No. 1 (PA-1). Each of these agreements and its functions are discussed below.

Joint Powers Agreement
The JPA Agreement created MCE and delineates a broad set of powers related to the study, promotion, development, and conduct of electricity-related projects and programs. The JPA Agreement describes MCE as having broad powers, but a very limited role without implementing agreements (“program agreements”) to carry out specific programs. This structure is intended to provide flexibility for MCE to undertake other programs in the future that may be unrelated to CCA on behalf of all or a subset of MCE’s Members. The Board has limited decision making authority regarding land use within the Member communities. Any issues involving land use within Member communities will be raised with the potentially affected Member. The land use and building regulations of each Member shall apply to any JPA facilities located within the jurisdiction of that Member. Any amendments to the JPA Agreement will be subject to prior approval by the Board.

The first program agreement or PA-1, discussed in greater detail below, provides for electric generation service to customers of the CCA Program. At MCE’s Members’ discretion, future program agreements could provide for other energy related programs or subsequent energy transactions.

Program Agreement No. 1
PA-1 consists of three components: 1) the Edison Electric Institute (“EEI”) Master Power Purchase & Sale Agreement (“Master EEI Agreement”), which is a standard industry contract used by public and private utilities across the United States; 2) the EEI Master Power Purchase & Sale Agreement Cover Sheet, which provides additional detail related to MCE’s specific transaction, identifying exceptions, clarifications and areas of applicability that modify the standard terms and conditions of the Master EEI Agreement; and 3) one or more Confirmations, inclusive of any amendments thereto, which is referenced in the Master EEI Agreement and defines the commercial terms of MCE’s transaction. PA-1 is the agreement under which MCE currently procures a significant portion of the electric supply services for MCE customers. PA-1 specifies a five year delivery period, which commenced on May 7, 2010 and ends on May 6, 2015. PA-1 specifies a full requirements energy product, including electric energy, renewable energy, capacity, ancillary services and scheduling coordination services. Based on contract negotiations, PA-1 specifies fixed annual prices for each year of the delivery period and APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 14 July 2014
insulates municipal funds/budgets of the Member Agencies before, during and after the delivery period. PA-1 was executed by MCE and its energy supplier, SENA, on February 5, 2010 and has since incorporated a series of amendments to accommodate Program expansion.

It is MCE’s intent to provide for the additional energy requirements of future MCE customers by negotiating other contracts for requisite energy products and/or subsequent amendments to PA-1, which will be completed prior to commencement of service to CCA customers located within the unincorporated areas of the County of Napa. MCE anticipates that SENA will continue in its role as MCE’s primary energy supplier and scheduling coordinator over the near-term (through December 31, 2016) but will also pursue supply arrangements with renewable energy generators to supplement planned renewable energy deliveries from SENA.

Agency Operations
MCE conducts program operations through its own internal staff and through contracts for services with third parties. MCE has its own General Counsel to manage its legal affairs.

MCE’s Executive Officer will have responsibility for day-to-day operations of the Program. To assist the Executive Officer, MCE has hired a full-time Administrative Assistant and a Clerk.

Other staff positions may be added as necessary to include positions in finance, customer services, energy efficiency and other local energy programs, and operations.

Major MCE functions that are performed and managed by the Executive Officer are summarized below.

Resource Planning
MCE is charged with developing both short (one and two-year) and long-term resource plans for the program. The Executive Officer manages staff and contractors to develop the resource plan under the guidance provided by the Board and in compliance with California Law, and other requirements of California regulatory bodies (CPUC and CEC).

Long-term resource planning includes load forecasting and supply planning on a ten- to twenty-year time horizon. MCE’s technical team develops integrated resource plans that meet program supply objectives and balance cost, risk and environmental considerations. Integrated resource planning considers demand side energy efficiency and demand response programs as well as traditional supply options. The CCA Program requires an independent planning function despite day-to-day supply operations being contracted to a third party energy supplier. Plans are updated and adopted by the Board on an annual basis.

Portfolio Operations
Portfolio operations encompass the activities necessary for wholesale procurement of electricity to serve end use customers. These highly specialized activities include the following:
 Electricity Procurement – assemble a portfolio of electricity resources to supply the electric needs of program customers.

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 15 July 2014
 Risk Management – standard industry techniques are employed to reduce exposure to the volatility of energy markets and insulate customer rates from sudden changes in wholesale market prices.
 Load Forecasting – develop accurate load forecasts, both long-term for resource planning and short-term for the electricity purchases and sales needed to maintain a balance between hourly resources and loads.
 Scheduling Coordination – scheduling and settling electric supply transactions with the CAISO.

MCE has initially contracted with an experienced and financially sound third party, SENA, to perform most of the portfolio operation requirements for the CCA Program. These requirements include the procurement of energy and ancillary services, scheduling coordinator services, and day-ahead and real-time trading. PA-1 is the contractual instrument that has been developed for this purpose; additional detail related to PA-1 is provided in the preceding discussion.

MCE will approve and adopt a set of Program Controls that will serve as the risk management tools for the Executive Officer and any third party involved in the program’s portfolio operations. Program Controls will define risk management policies and procedures and a process for ensuring compliance throughout the organization. During initial operations, SENA will bear the majority of program operational risks, pursuant to the terms and conditions of PA-1.

Operations & Local Energy Programs
A key focus of the CCA Program will be the development and implementation of local energy programs for its Members, including energy efficiency programs, net energy metering, distributed generation programs and other energy programs responsive to Member interests.

The Executive Officer is responsible for further development of these Programs. To assist the Executive Officer in this regard, MCE has hired additional staff to oversee program operations and local energy program administration as well as develop energy efficiency marketing strategies, perform customer outreach and conduct related analyses to support chosen courses of action. As experience is gained from the retail energy side of the CCA Program, MCE will continue enhancing its local energy programs to achieve MCE’s desired goals and objectives.

MCE is currently administering energy efficiency and distributed (solar) generation programs that can be used as alternatives to procurement of supply-side resources. MCE may also implement demand response programs in the future. For the time being, MCE has launched various small-scale pilot projects to explore demand response opportunities within its service territory. MCE will attempt to consolidate existing demand side programs into this organization and leverage the structure to expand energy efficiency offerings to customers throughout its service territory.

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 16 July 2014
Rate Setting
The Board of Directors has the ultimate responsibility for setting the electric generation rates for the Program’s customers. The Executive Officer in cooperation with technical staff and appropriate advisors, consultants and committees of the Board is responsible for developing proposed rates and options for the Board to consider before finalization. The final approved rates must, at a minimum, meet the annual revenue requirement developed by the Executive Officer, including any reserves or coverage requirements set forth in electric supply agreements and/or bond covenants. The Board has the flexibility to consider rate adjustments within certain ranges, provided that the overall revenue requirement is achieved; this provides an opportunity for economic development rates or other rate incentives.

Financial Management/Accounting
The Executive Officer in cooperation with technical staff, advisors and consultants is responsible for managing the financial affairs of MCE, including the development of an annual budget and revenue requirement; managing and maintaining cash flow requirements; potential bridge loans and other financial tools; and a large volume of billing settlements. The Executive Officer uses contractors and/or staff in support of these activities, as appropriate.

The Finance function arranges financing for capital projects, prepares financial reports, and ensures sufficient cash flow for the Program. This function also plays an important role in risk management by monitoring the credit of suppliers so that credit risk is properly understood and mitigated by the Program. In the event that changes in a supplier’s financial condition and/or credit rating are identified, the Program will be able to take appropriate action, as would be provided for in the electric supply agreement. The Finance function establishes credit policies that the program must follow.

The retail settlements (customer billing) is contracted out to an organization with the necessary infrastructure and capability to handle in excess of 138,000 accounts during full Program phase-in and near-term expansion (to the County of Napa), which is scheduled to occur in February 2015. This function is described under Customer Services, below.

Customer Services
In addition to general program communications and marketing, a significant focus on customer service, particularly representation for key accounts, is necessary. This includes both a call center designed to field customer inquiries and routine interaction with customer accounts. The Executive Officer is responsible for the Customer Services function and uses staff and/or contractors in support of these activities as appropriate.

The Customer Account Services function performs retail settlements-related duties and manages customer account data. It processes customer service requests and administers customer enrollments and departures from the Program, maintaining a current database of customers enrolled in the Program. This function coordinates the issuance of monthly bills through the distribution utility’s billing process and tracks customer payments. Activities APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 17 July 2014
include the electronic exchange of usage, billing, and payments data with the distribution utility and MCE, tracking of customer payments and accounts receivable, issuance of late payment and/or service termination notices, and administration of customer deposits in accordance with MCE credit policies.

The Customer Account Services function also manages billing related communications with customers, customer call centers, and routine customer notices. MCE has initially contracted with a third party, Noble Americas Energy Solutions (“Noble”), which has demonstrated the necessary experience and administers appropriate computer systems (customer information system), to perform the customer account and billing services functions.

MCE conducts Program marketing and key customer account management functions. These responsibilities will include the assignment of account representatives to key accounts, which will ensure high levels of customer service to these businesses, and implementation of a marketing strategy to promote customer satisfaction with the CCA Program. Effectively administering communications, marketing messages, and delivering information regarding the CCA Program to all customers is critical for the overall success of the CCA Program.

Legal and Regulatory Representation
The CCA Program requires ongoing regulatory representation to file resource plans, resource adequacy, compliance with California RPS, and overall representation on issues that will impact MCE, its Members and MCE customers. MCE maintains an active role at the CPUC, CEC, and, as necessary, FERC and the California legislature. Day-to-day analysis and reporting of pertinent legal and regulatory issues is completed by the Program’s in-house legal and regulatory staff and/or qualified contractors.

MCE also retains legal services, as necessary, to administer MCE, review contracts, and provide overall legal support to the activities of MCE.

Roles and Functions
The Board performs the functions inherent in its policy-making, management and planning roles. MCE is the public face of the Program and has a direct role in marketing, communications and customer service. Other highly specialized functions, such as energy supply and data management, are contracted out to third parties with sufficient experience, technical and financial capabilities. The functions that are currently being performed by MCE’s Board of Directors, the Executive Officer and third parties are specified below:

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 18 July 2014
Organization Roles/Functions/Activities
MCE Board of Directors Executive/Policy/Legal
Executive Officer Finance
Legal and Regulatory
- Legal support
- Participation in regulatory proceedings
- Regulatory reporting
Marketing/Communications
Rates & Support
- Rate policy
- Rate design
- Cost-of-service planning
Resource Planning
- Load research
- Load forecasting
- Supply-side/Demand side portfolio planning
Supply Operations
- Procurement
- Contract Negotiation
- Invoice Reconciliation
Contract Management
- RFP/RFQ Administration
- Invoice Reconciliation & Issue Resolution
- Project Development Status Monitoring
Customer Service
- Account representatives
- Energy efficiency/DG program management
Energy Suppliers Supply Operations
- Procurement
- Scheduling coordination
- Settlements (ISO/Wholesale)
- Short-term load forecasting
Customer Account Services
Provider/Data Manager (Noble)
Account Management (Customer Information System)
- Customer switching
- New customer processing
- Data exchange (EDI)
- Payment processing (AR/AP)
- Billing and retail settlements
- Call center
Staffing
Staffing requirements for the above MCE functions will be approximately ten full time equivalent positions, once the customer phase-in is complete and the program is fully operational. These staffing requirements are in addition to the services provided by the third party energy suppliers and the data manager. The Executive Officer will have discretion whether to internally staff these required functions or to contract for these services.

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 19 July 2014
The following table shows the staffing plan for Marin Clean Energy at initial full-scale operational levels, following full phase-in. Customer service for the mass market residential and small commercial customers will be provided by the Program’s third party customer account services provider.

Current Staffing for the Marin Clean Energy
Community Choice Aggregation Program
Longer-term staffing needs will include additional energy efficiency and distributed generation activities and potentially the creation of an internal organization to perform the portfolio operations and account services functions that are currently performed under contract arrangements.

Position Staff (Full Time Equivalents)
Executive Officer 1
Director of Internal Operations 1
Business Analyst 1
Clerk 1
Human Resources Coordinator 0.5
Administrative Associate 1
Communications Director 1
Manager of Account Services 1
Account Manager 1 2
Community Affairs Coordinator 1
Communications Associate 1
Energy Efficiency Director 1
Energy Efficiency Specialist 2
Legal Director 1
Regulatory Counsel 1
Regulatory Analyst 1
Regulatory Assistant 1
Director of Power Resources 1
Program Specialist 1
Special Assignment Intern 0.5
Total Staffing 21
Internal Operations
Public Affairs
Energy Efficiency
Legal & Regulatory
Electric Supply
APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 20 July 2014
CHAPTER 4 – CCA Startup
As previously noted, MCE successfully launched the MCE program on May 7, 2010. To ensure successful operation during the implementation and start-up period, MCE utilized a mix of staff and contractors in its CCA Program implementation. The following table illustrates start-up responsibilities as well as expectations for near-term (two to five years), and long-term staffing roles.

Expectations for Staffing Roles
Function Start-Up
Near-Term
(2 to 5 Years) Long-Term
Program Governance MCE Board MCE Board MCE Board
Program Management MCE EO MCE EO MCE EO
Outreach MCE EO MCE EO MCE EO
Customer Service MCE EO MCE EO MCE EO
Key Account Management MCE EO MCE EO MCE EO
Regulatory Third Party
(MCE EO support)
MCE EO
(Regulatory Analyst
support)
MCE EO
(Regulatory
Analyst support)
Legal MCE EO MCE EO MCE EO
Finance MCE EO MCE EO MCE EO
Rates: Develop & Approve MCE EO
(third Party support)
MCE Board
MCE EO
(third Party support)
MCE Board
MCE EO
(third party
support)
MCE Board
Resource Planning Third Party
(MCE EO support)
MCE EO (third
party support)
MCE EO (third
party support)
Energy Efficiency MCE EM
(third Party
Support)
MCE EO (Program
Energy Efficiency
Staff)
MCE EO (Program
Energy Efficiency
Staff)
Resource Development MCE EO (third
party support)
MCE EO (third
party support)
MCE EO (third
party support)
Portfolio Operations Third Party Third Party
(MCE EO support)
MCE EO (third
party support)
Scheduling Coordinator Third Party Third Party Third Party (potentially MCE
EO)
Data Management Third Party Third Party Third Party
(potentially MCE
EO)
Staffing Requirements
Staff will be added incrementally to match workloads involved in forming the new organization, managing contracts, and initiating customer outreach/marketing during the pre-operations period. Actual staff will be dependent upon several factors, including the ability to APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 21 July 2014
recruit and hire qualified staff and personnel policies ultimately established by the Executive Officer and the Board of Directors.

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 22 July 2014
CHAPTER 5 – Program Phase-In
MCE will continue to phase-in the customers of its CCA Program as communicated in this Implementation Plan. To date, four phases have been successfully implemented, and a fifth phase will commence in February 2015.

Phase 1. Complete: MCE Member (municipal) accounts & a subset of residential, commercial and/or industrial accounts, comprising approximately 20 percent of total customer load.

Phase 2. Complete: Additional commercial and residential accounts, comprising an approximately 20 percent of total customer load (incremental addition to Phase 1).

Phase 3. Complete: Remaining accounts within Marin County.

Phase 4. Complete: Residential, commercial, agricultural, and street lighting accounts within the City of Richmond.

Phase 5. February 2015: Residential, commercial, agricultural, and street lighting accounts within the unincorporated areas of Napa County, subject to economic and operational constraints.

This approach has provided MCE with the ability to start slow, addressing any problems or unforeseen challenges on a small manageable program before gradually building to full program integration for an expected customer base of approximately 138,000 accounts, following service commencement to customers within the unincorporated areas of the County of Napa. This approach has also allowed MCE and its energy supplier(s) to address all system requirements (billing, collections, payments) under a phase-in approach to minimize potential exposure to uncertainty and financial risk by “walking” prior to ultimately “running”.

MCE will offer service to all customers on a phased basis expected to be completed within twenty four to thirty six months of initial service to Phase 1 customers, which occurred on May 7, 2010. Phase 2 was implemented in August, 2011. Phase 3 of the Program began in July, 2012.

Phase 4 was implemented in July, 2013 and included all residential, commercial, agricultural, and street lighting customers within the City of Richmond. Phase 5 is planned to begin in February 2015 and will include all residential, commercial, agricultural, and street lighting customers within the unincorporated areas of Napa County. The Board may evaluate other phase-in options based on then-current market conditions, statutory requirements and regulatory considerations as well as other factors potentially affecting the integration of additional customer accounts.

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CHAPTER 6 - Load Forecast and Resource Plan
Introduction
This Chapter describes MCE’s proposed ten-year integrated resource plan, which will create a highly renewable, diversified portfolio of electricity supplies capable of meeting the electric demands of MCE’s retail customers, plus sufficient reliability reserves.

This integrated resource plan reflects a progression towards MCE’s long-term, programmatic goal of 100 percent renewable energy supply. Within five years of program commencement (2015), this significant commitment to renewable resources is projected to result in MCE meeting approximately 52 percent of its total electric needs through renewable resources. As the Program moves forward, incremental renewable supply additions will be made based on resource availability as well as economic goals of the Program. MCE’s aggressive commitment to renewable generation adoption may involve both direct investment in new renewable generating resources through partnerships with experienced public power developers/operators, significant purchases of renewable energy from third party suppliers and the purchase of Renewable Energy Certificates (“RECs”) from the market. The resource plan also sets forth ambitious targets for improving customer side energy efficiency as well as for potential deployment of approximately 14 MW of new distributed solar capacity within the jurisdictional boundaries of MCE by 2019 (year ten of Program operations).

The plan described in this section would accomplish the following by 2019:
 Procure energy needed to offer two generation rate tariffs: 100 percent Deep Green and 50 percent (minimum) Light Green.
 Increase the aggregate RPS-eligible renewable energy supply of the Program to a minimum 33 percent by 2020.
 Continue increasing renewable energy supplies of the Program to approximately 52 percent by 2015 based on resource availability and economic goals of the program.  Develop partnership(s) with experienced public power developer(s) to responsibly evaluate development opportunities for Program-owned/controlled renewable generating capacity.
 Achieve significant reductions in greenhouse gas emissions within the Member Agencies.

MCE is responsible for complying with regulatory rules applicable to California load serving entities. MCE has arranged for the scheduling of sufficient electric supplies to meet the hour-by-hour demands of its customers. MCE has adhered to capacity reserve requirements established by the CPUC and the CAISO designed to address uncertainty in load forecasts and potential supply disruptions caused by generator outages and/or transmission contingencies.

These rules also ensure that physical generation capacity is in place to serve the Program’s customers, even if there were to be a need for the Program to cease operations and return customers to PG&E. In addition, MCE is responsible for ensuring that its resource mix contains sufficient production from renewable energy resources needed to comply with the statewide APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 24 July 2014
renewable portfolio standards. The resource plan will meet or exceed all of the applicable regulatory requirements related to resource adequacy and the renewable portfolio standard.

Resource Plan Overview
The criteria used to guide development of the proposed resource plan included the following:
 Environmental responsibility and commitment to renewable resources;  Price/rate stability;
 Reliability and maintenance of adequate reserves; and  Cost effectiveness.

To meet these objectives and the applicable regulatory requirements, MCE’s resource plan includes a diverse mix of power purchases, renewable energy, new energy efficiency programs, demand response, and distributed generation. A diversified resource plan minimizes risk and volatility that can occur from over-reliance on a single resource type or fuel source. The ultimate goal of MCE’s resource plan is to maximize use of renewable resources subject to economic and operational constraints. The result is a resource plan that will source approximately 52 percent of MCE’s resource mix from renewable resources by 2015. The planned resource mix is initially comprised of power and renewable energy credit purchases from third party electric suppliers and, in the longer-term, may also include renewable generation assets owned and/or controlled by MCE.

Eventually, MCE may begin evaluating opportunities for investment in renewable generating assets, subject to then-current market conditions, statutory requirements and regulatory considerations. Any renewable generation owned by MCE or controlled under long-term power purchase agreement with a proven public power developer, could provide a portion of MCE’s electricity requirements on a cost-of-service basis. Electricity purchased under a cost-of-service arrangement should be more cost-effective than purchasing renewable energy from third party developers, which will allow the Program to pass on cost savings to its customers through competitive generation rates. Any investment decisions will be made following thorough environmental reviews and in consultation with the Marin Communities’ financial advisors, investment bankers, attorneys, and potentially with customer input.

As an alternative to direct investment, MCE may consider partnering with an experienced public power developer and enter into a long-term (20-to-30 year) power purchase agreement that would support the development of new renewable generating capacity. Such an arrangement could be structured to greatly reduce the Program’s operational risk associated with capacity ownership while providing Program customers with all renewable energy generated by the facility under contract. This option may be preferable to MCE as it works to achieve increasing levels of renewable energy supply to its customers.

MCE’s resource plan will integrate supply-side resources with programs that will help customers reduce their energy costs through improved energy efficiency and other demand-side measures. As part of its integrated resource plan, MCE will actively pursue, promote and ultimately administer a variety of customer energy efficiency programs that can cost-effectively APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 25 July 2014
displace supply-side resources. Included in this plan is a targeted deployment of over 14 MW of distributed solar by 2019.

MCE’s proposed resource plan for the years 2010 through 2019 is summarized in the following table:

Supply Requirements
The starting point for MCE’s resource plan is a projection of participating customers and associated electric consumption. Projected electric consumption is evaluated on an hourly basis, and matched with resources best suited to serving the aggregate of hourly demands or the program’s “load profile”. The electric sales forecast and load profile will be affected by MCE’s plan to introduce the Program to customers in phases and the degree to which customers choose to remain with PG&E during the customer enrollment and opt-out periods. It is anticipated that MCE’s contracted energy supplier will bear a portion of the financial risks associated with deviations from the electric sales forecast during the initial operating period. It will be the obligation of this energy supplier to appropriately reflect these risks in the full requirements energy price. MCE’s phased roll-out plan and assumptions regarding customer participation rates are discussed below.

Customer Participation Rates
Customers will be automatically enrolled in MCE’s electricity program unless they opt-out during the customer notification process conducted during the 60-day period prior to enrollment and continuing through the 60-day period following commencement of service.

MCE anticipated an overall customer participation rate of approximately 80 percent during Phase 1, when service is being offered to the service accounts that are affiliated with MCE’s participating members (municipal accounts) and a subset of residential, commercial and/or industrial customers, totaling approximately 20 percent of total customer load. The actual participation rate for Phase 1 was very similar to MCE’s projection. Participation rates for 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019
MCE Demand (GWh)
Retail Demand -91 -185 -570 -1,110 -1,294 -1,545 -1,582 -1,582 -1,582 -1,582 Distributed Generation 0 1 1 5 12 16 22 23 25 25
Energy Efficiency 0 0 0 6 6 4 8 12 16 16
Losses and UFE -5 -11 -34 -66 -77 -91 -93 -93 -92 -92
Total Demand -96 -196 -603 -1,166 -1,353 -1,616 -1,646 -1,640 -1,634 -1,634 MCE Supply (GWh)
Renewable Resources
Generation 0 0 0 0 0 0 0 219 219 219
Power Purchase Contracts 23 50 291 566 673 803 838 635 651 667 Total Renewable Resources 23 50 291 566 673 803 838 854 870 886 Conventional Resources
Generation 0 0 0 0 0 0 0 0 0 0
Power Purchase Contracts 73 146 312 599 680 813 807 786 764 748 Total Conventional Resources 73 146 312 599 680 813 807 786 764 748 Total Supply 96 196 603 1,166 1,353 1,616 1,646 1,640 1,634 1,634 Energy Open Position (GWh) 0 0 0 0 0 0 0 0 0 0
2010 to 2019
Marin Clean Energy
Proposed Resource Plan
(GWH)
APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 26 July 2014
Phase 2 were approximately 80 percent of bundled service customers and 0 percent of direct access customers. Participation rates for Phases 3 and 4 are projected to range from 70 percent to 80 percent, with the lower figure used as the basis for load projections contained in this plan.

The participation rate is not expected to vary significantly among customer classes, in part due to the fact that MCE will offer two distinct rate tariffs that will address the needs of cost-sensitive customers within the Marin Communities as well as the needs of both residential and business customers that prefer a highly renewable energy product. The assumed participation rates will be refined as MCE’s public outreach and market research efforts continue to develop.

Customer Forecast
Once customers enroll in each phase, they will be switched over to service by MCE on their regularly scheduled meter read date over an approximately thirty day period. The number of accounts served by MCE at the end of each phase is shown in the table below.

Marin Clean Energy
Enrolled Retail Service Accounts
Phase-In Period (End of Month)
May-10 Aug-11 Jul-12 Jul-13 Feb-15
MCE Customers
Residential 7,354 12,503 77,345 106,510 120,204
Small Commercial 522 605 8,934 11,829 13,761
Medium And Large
Commercial And
Industrial
57 509 949

1,269 1,555
Street Lighting & Traffic 138 141 443 748 1,014
Ag & Pump. - < 15 113 109 1,467
Total 8,071 13,759 87,814 120,465 138,001

MCE assumes that MCE customer growth will generally offset customer attrition (opt-outs) over time, resulting in a relatively stable customer base over the noted planning horizon.

Because MCE is the first program of its kind within California, it is very difficult to anticipate with any precision the actual levels of customer participation within this CCA program. MCE believes that its assumptions regarding the offsetting effects of growth and attrition are reasonable in consideration of the limited build-out potential within a significant portion of MCE’s service territory and the observed rate of customer opt-outs following mandatory customer notification periods. The forecast of service accounts (customers) served by MCE for each of the referenced ten-year planning periods is shown in the following table:

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 27 July 2014
Marin Clean Energy
Retail Service Accounts (End of Year)
2010 to 2019
2010 2011 2012 2013 2014 2015 2016 2017 2018 2019
MCE Customers
Residential 7,354 12,503 77,345 106,510 106,510 120,204 120,204 120,204 120,204 120,204 Small Commercial 522 605 8,934 11,829 11,829 13,761 13,761 13,761 13,761 13,761 Medium And Large Commercial And
Industrial

57 509

979

1,269

1,269

1,555

1,555

1,555

1,555

1,555
Street Lighting & Traffic 138 141 443 748 748 1,014 1,014 1,014 1,014 1,014 Ag & Pump. - < 15 113 109 109 1,467 1,467 1,467 1,467 1,467 Total 8,071 13,759 87,814 120,465 120,465 138,001 138,001 138,001 138,001 138,001

Sales Forecast
MCE’s forecast of kWh sales reflects the roll-out and customer enrollment schedule shown above. The annual electricity needed to serve MCE’s retail customers increases from approximately 200 GWh in 2011 to approximately 1,600 GWh at full roll-out, which includes planned expansion to the County of Napa. Annual energy requirements are shown below.

Capacity Requirements
The CPUC’s resource adequacy standards applicable to MCE require a demonstration one year in advance that MCE has secured physical capacity for 90 percent of its projected peak loads for each of the five months May through September, plus a minimum 15 percent reserve margin.

On a month-ahead basis, MCE must demonstrate 100 percent of the peak load plus a minimum 15 percent reserve margin.

A portion of MCE’s capacity requirements must be procured locally, from the Greater Bay area as defined by the CAISO and another portion must be procured from local reliability areas outside the Greater Bay Area. MCE must also meet requirements for flexible capacity such that a portion of MCE’s resource adequacy requirements are met from qualifying flexible resources.

MCE is required to demonstrate its local and flexible capacity requirements for each month of the following calendar year. MCE must demonstrate compliance or request a waiver from the 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019
MCE Energy Requirements (GWh)
Retail Demand 91 185 570 1,110 1,294 1,545 1,582 1,582 1,582 1,582 Distributed Generation 0 -1 -1 -5 -12 -16 -22 -23 -25 -25 Energy Efficiency 0 0 0 -6 -6 -4 -8 -12 -16 -16
Losses and UFE 5 11 34 66 77 91 93 93 92 92
Total Load Requirement 96 196 603 1,166 1,353 1,616 1,646 1,640 1,634 1,634 2010 to 2019
Marin Clean Energy
Energy Requirements
(GWH)
APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 28 July 2014
CPUC requirement as provided for in cases where local capacity is not available. MCE complies with the forward and monthly resource adequacy requirements administered by the state regulatory agencies.

MCE’s plan ensures sufficient reserves are procured to meet its peak load at all times. MCE’s annual peak capacity requirements are shown in the following table:

MCE will continue to coordinate with PG&E and appropriate state agencies to manage the transition of responsibility for resource adequacy from PG&E to MCE following load migration to CCA service. For system resource adequacy requirements, MCE will make month-ahead showings for each month that MCE plans to serve load, and any load migration issues will be addressed through the CPUC’s approved procedures. MCE will work with the California Energy Commission and CPUC prior to commencing service to additional customers to ensure it meets its local, system and flexible resource adequacy obligations through its agreements with its chosen electric suppliers.

Renewable Portfolio Standards Energy Requirements
Basic RPS Requirements
As a CCA, MCE is required by law and ensuing CPUC regulations to procure a certain minimum percentage of its retail electricity sales from qualified renewable energy resources.

For purposes of determining MCE’s renewable energy requirements, the same standards for RPS compliance that are applicable to the distribution utilities are assumed to apply to MCE.

California’s RPS program is currently undergoing reform. On April 12, 2011, Governor Jerry Brown signed SB x1 2, requiring public and private utilities as well as community choice aggregators to obtain 33 percent of their electricity from renewable energy sources by December 31, 2020. MCE is familiar with California’s new RPS, including certain procurement quantity 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019
Demand (MW)
Retail Demand 28 46 182 233 233 286 286 286 286 286
Distributed Generation (0) (1) (4) (8) (11) (15) (15) (17) (17) (17) Energy Efficiency - - - (1) (1) (1) (2) (3) (3) (3)
Losses and UFE 2 3 11 13 13 16 16 16 16 16
Total Net Peak Demand 30 47 189 237 235 287 285 283 282 282 Reserve Requirement (%) 15% 15% 15% 15% 15% 15% 15% 15% 15% 15% Capacity Reserve Requirement 4 7 28 36 35 43 43 42 42 42 Capacity Requirement Including Reserve 34 55 218 273 270 330 328 325 324 324 2010 to 2019
Marin Clean Energy
Capacity Requirements
(MW)
APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 29 July 2014
requirements identified in D.11-12-020 (December 1, 2011). To date, MCE has significantly exceeded California’s RPS, providing MCE customers with over 29 percent RPS-eligible renewable energy delivered to MCE customers in 2012. A similar renewable energy percentage, approximating 28.7 percent, was supplied to MCE customers in 2013.

MCE’s Renewable Portfolio Standards Requirement
MCE’s annual RPS requirements are shown in the table below. When reviewing this table, it is important to note that MCE projects increases in energy efficiency savings as well as increases in locally situated distributed generation capacity (an additional 14 MW by 2019), resulting in a slight downward trend in projected retail electricity sales.

Based on planned renewable energy procurement objectives, MCE anticipates that it will significantly exceed the minimum RPS requirements as shown below.

Resources
MCE has begun evaluating opportunities for future investment in renewable generating assets.

Such opportunities will be evaluated on a case by case basis in consideration of resource location, market conditions, statutory requirements and regulatory considerations. Any renewable generation owned by MCE or controlled under long-term power purchase agreement with a proven public power developer, could provide a portion of MCE’s electricity 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019
Retail Sales 185,493 91,219 570,144 1,110,487 1,293,681 1,544,971 1,581,999 1,581,999 1,581,999 1,581,999 Baseline 18,244 - 114,029 37,099 222,097 280,729 359,978 395,500 427,140 458,780 Incremental Procurement Target 18,244 18,855 108,069 76,930 58,631 79,249 35,522 31,640 31,640 31,640 Annual Procurement Target 18,244 114,029 37,099 222,097 280,729 359,978 395,500 427,140 458,780 490,420 % of Current Year Retail Sales 20% 20% 20% 20% 22% 23% 25% 27% 29% 31% 2010 to 2019
Marin Clean Energy
RPS Requirements
(MWH)
2010 2011 2012 2013 2014 2015 2016 2017 2018 2019
Retail Sales (MWh) 91,219 185,493 570,144 1,110,487 1,293,681 1,544,971 1,581,999 1,581,999 1,581,999 1,581,999 Annual RPS Target (Minimum MWh) 18,244 37,099 114,029 222,097 280,729 359,978 395,500 427,140 458,780 490,420 Program Target (% of Retail Sales) 25% 27% 51% 51% 52% 52% 53% 54% 55% 56% Program Renewable Target (MWh) 22,805 50,083 290,773 566,348 672,714 803,385 838,459 854,279 870,099 885,919 Surplus In Excess of RPS (MWh) 4,561 12,984 176,745 344,251 391,985 443,407 442,960 427,140 411,320 395,500 Annual Increase (MWh) 22,805 27,278 240,690 275,575 106,366 130,671 35,075 15,820 15,820 15,820 2010 to 2019
Marin Clean Energy
RPS Requirements and Program Renewable Energy Targets
(MWH)
APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 30 July 2014
requirements on a cost-of-service basis. Electricity purchased under a cost-of-service arrangement should be more cost-effective than purchasing renewable energy from third party developers, which will allow the Program to pass on cost savings to its customers through competitive generation rates. Any investment decisions will be made following thorough environmental reviews and in consultation with MCE’s financial advisors, investment bankers, attorneys, and potentially with customer input.

As an alternative to direct investment, MCE may consider partnering with an experienced public power developer and enter into a long-term (20-to-30 year) power purchase agreement that would support the development of new renewable generating capacity. Such an arrangement could be structured to greatly reduce the Program’s operational risk associated with capacity ownership while providing Program customers with all renewable energy generated by the facility under contract. This option may be preferable to MCE as it works to achieve increasing levels of renewable energy supply to its customers.

Purchased Power
Power purchased from utilities, power marketers, public agencies, and/or generators will likely be the predominant source of supply from 2010 to 2015 (MCE may consider the development of certain renewable energy projects, subject to Board approval, which may supply electric generation to MCE customers as soon as January 2016) and may still remain a significant source of power in the event that MCE considers the development of its own renewable generation assets. During the period from 2010 – 2016, MCE plans to contract with SENA for a substantial portion of its electricity needs under a full requirements power supply agreement, and SENA will be responsible for procuring a mix of power purchase contracts, including specified renewable energy targets, to provide a stable and cost-effective resource portfolio for the Program. Deliveries under this agreement have been supplemented with purchases of other energy products from qualified renewable project developers, asset owners and power marketers. Based on terms established in this third-party contract, MCE will continue to substitute electric energy generated by MCE-owned/controlled renewable resources for contract quantities in the event that such resources become operational during the delivery period.

Renewable Resources
MCE will initially secure necessary renewable power supply from SENA. MCE has supplemented the renewable energy provided under the initial full requirements contract with direct purchases of renewable energy from renewable energy facilities.

For planning purposes, MCE should anticipate procurement from the following types of large scale renewable resources in the near to midterm, which would require little or no transmission expansion to ensure deliverability:
 Local resources (solar, wind, biogas, biomass);
 Wind resources in Solano County;
 Existing Qualifying Facilities with expiring PG&E contracts;  Expansion and re-powering of wind resources in Alameda County;  Geothermal in Lake and Sonoma Counties;
 Local biomass projects; and
APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 31 July 2014
 Renewable Energy Certificates.

Medium and Long-Term Renewable Potential
For mid and long term planning purposes, MCE should anticipate procurement from the following types of large scale renewable resources3:
 Wind imports from the Tehachapi Area;
 Wind imports from the Pacific Northwest;
 Geothermal imports from Nevada;
 Geothermal imports from the Imperial Valley;
 Photovoltaic solar imports from California’s Central Valley; and  Solar CSP imports from Southern California (Riverside and San Bernardino Counties).

Although this resource plan identifies likely resource types and locations, it is not possible to predict what projects might be proposed in response to MCE’s future solicitations for renewable energy or that may stem from discussions with other public agencies. Renewable projects that are located virtually anywhere in the Western Interconnection can be considered as long as the electricity is deliverable to the CAISO control area, as required to meet the Commission’s RPS rules and any additional guidelines ultimately adopted by MCE’s Board of Directors. The costs of transmission access and the risk of transmission congestion costs would need to be considered in the bid evaluation process if the delivery point is outside of MCE’s load zone, as defined by the CAISO.

Energy Efficiency
This section addresses the treatment of energy efficiency as a component of MCE’s integrated resource plan. As described below there are opportunities for significant cost effective energy efficiency programs within the region, and MCE will seek to maximize end-use customer energy efficiency to the greatest extent practical. MCE first received funding to implement energy efficiency programs through the ‘elect to administer’ portion of the Public Utilities Code (section 381.1 e-f), wherein MCE has the authority to collect funds which have already been collected from MCE customers to support an energy efficiency plan that complies with the legislative intent. MCE submitted a plan for the use of 2012 program funding, focusing exclusively on multi-family customers; this plan was certified by the Commission in August, 2012.4

On a parallel track, MCE submitted an application to administer funds as an independent program administrator, an option which was clarified by SB 790 (2011) and reinforced in a recent CPUC Decision on CCA and Energy Efficiency5. This suite of programs offers energy efficiency services for multi-family, small commercial and single family sectors with financing

3 In the long term, new technologies such as wave or tidal energy may become economically feasible as well. 4 Resolution E-4815 California Public Utilities Commission. August 23, 2012. 5 Decision 14-01-033. Decision Enabling Community Choice Aggregators to Administer Energy Efficiency Programs.

January 16, 2014.

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 32 July 2014
programs available to support all programs. MCE plans to grow the energy efficiency and local program department over time.

Baseline Energy Efficiency Potential Estimates
The National Action Plan for Energy Efficiency states among its key findings “consistently funded, well-designed efficiency programs are cutting annual savings for a given program year of 0.15 to 1 percent of energy sales.”6
The American Council for an Energy-Efficient Economy
(ACEEE) reports for states already operating substantial energy efficiency programs energy efficiency goals of one percent, as a percentage of energy sales, is a reasonable level to target.7 Forecast achievable energy efficiency equal to one percent of the CCA’s forecast energy sales, as indicated in the table below, appears to be a reasonable and conservative baseline for the demand-side portion of CCA’s resource plan. Targeted program savings would be in addition to the savings achieved by PG&E administered programs.

CCA Program Energy Efficiency Goals
The Program’s energy efficiency goals reflect a strong commitment to increasing energy efficiency within the County and expanding beyond the savings achieved by PG&E’s programs.

MCE’s goal is to increase annual savings through energy efficiency programs to two percent (combined MCE and PG&E programs) of annualized electric sales, as has been adopted by the State of New York, by the end of 2018. Achieving this goal would mean at least a doubling of energy savings relative to the status quo situation without the CCA program. MCE programs will focus on closing the gap between the vast economic potential of energy efficiency within MCE’s service territory and what is actually achieved, while designing programs based on community input that align with MCE’s mission statement.

The following table summarizes the estimated energy efficiency potential for each type of energy efficiency initiative:8

6 National Action Plan for Energy Efficiency, July 2006, Section 6: Energy Efficiency Program Best Practices (pages 5- 6)
7 Energy Efficiency Resource Standards: Experience and Recommendations, Steve Nadel, March 2006, ACEEE Report E063 (pages 28 - 30).
8 California Energy Efficiency Potential Study Volume 1, California Measurement Advisory Council (CALMAC) Study ID: PGE0211.01, May 24, 2006, Figure 12-2: Distribution of Electric Energy Market Potential, Existing Incentive Levels through 2016.
2010 2011 2012 2013 2014 2015 2016 2017 2018 2019
MCE Retail Demand 91 185 570 1,110 1,294 1,545 1,582 1,582 1,582 1,582 MCE Energy Efficiency Goal 0 0 0 -6 -6 -4 -8 -12 -16 -16 Energy Efficiency Savings Goals
(GWH)
2010 to 2019
Marin Clean Energy
APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 33 July 2014
California Energy Efficiency Market Potential
EXISTING RESIDENTIAL 53.0%
Existing Commercial 18.0%
Existing Industrial 14.0%
Residential New Construction 1.0%
Commercial New Construction 6.0%
Industrial New Construction 1.0%
Emerging Technologies 7.0%
The retrofit of existing buildings represents 85 percent of the total forecast energy efficiency market potential. Studies show that the residential customer sector presents the largest untapped efficiency gains.

MCE has ramped up the Energy Efficiency department since the first funding authorization in late 2012. MCE’s energy efficiency department continues to refine energy savings estimates and develop portfolios in line with customer expectations and local patterns of energy use.

Additional details of MCE’s energy efficiency plans are set forth in a separate planning document.9
Demand Response
Demand response programs provide incentives to customers to reduce demand upon request by the load serving entity (i.e., MCE), reducing the amount of generation capacity that must be maintained as infrequently used reserves. Demand response programs can be cost effective alternatives to capacity otherwise needed to comply with the resource adequacy requirements.

The programs also provide rate benefits to customers who have the flexibility to reduce or shift consumption for relatively short periods of time when generation capacity is most scarce. Like energy efficiency, demand response can be a win/win proposition, providing economic benefits to the electric supplier and customer service benefits to the customer.

In its ruling on local resource adequacy, the CPUC found that dispatchable demand response resources as well as distributed generation resources should be allowed to count for local capacity requirements. MCE has launched several small scale pilots to explore the possibilities for local DR programs. This resource plan anticipates that MCE’s demand response programs would partially offset its local capacity requirements beginning in 2016.

PG&E offers several demand response programs to its customers, and MCE intends to recruit those customers that have shown a willingness to participate in utility programs into MCE’s demand response programs.10 The goal for this resource plan is to meet 5 percent of the Program’s total capacity requirements (by 2018) through dispatchable demand response

9 Marin Energy Authority’s Proposal to Administer Energy Efficiency Programs Pursuant to Public Utilities Code 381.1(e) and (f) for 2012, June 22, 2012.
10 These utility programs include the Base Interruptible Program (E-BIP), the Demand Bidding Program (E-DBP), Critical Peak Pricing (E-CPP), Optional Binding Mandatory Curtailment Plan (E-OBMC), the Scheduled Load Reduction Program (E-SLRP), and the Capacity Bidding Program (E-CBP). MCE has started to develop and implement its own demand response programs on a pilot basis.

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 34 July 2014
programs that qualify to meet local resource adequacy requirements. This goal translates into approximately 13 MW of peak demand enrolled in MCE’s demand response programs.

Achievement of this goal would displace approximately 32 percent of MCE’s local capacity requirement within the Greater Bay Area.

MCE’s initial DR pilots offer the opportunity to explore DR programs and develop administrative capabilities related to this component of the MCE service offering. MCE plans to leverage experiences and lessons learned from these initial pilots to develop a demand response program that enables it to request customer demand reductions during times when capacity is in short supply or spot market energy costs are exceptionally high. The level of customer payments should be related to the cost of local capacity that can be avoided as a result of the customer’s willingness to curtail usage upon request.

Appropriate limits on customer curtailments, both in terms of the length of individual curtailments and the total number of curtailment hours that can be called should be included in MCE’s demand response program design. It will also be important to establish a reasonable measurement protocol for customer performance of its curtailment obligations. Performance measurement should include establishing a customer specific baseline of usage prior to the curtailment request from which demand reductions can be measured. MCE will likely utilize experienced third party contractors to design, implement and administer its demand response programs.

Distributed Generation
Consistent with MCE’s environmental policies and the state’s Energy Action Plan, clean distributed generation is a significant component of the integrated resource plan. MCE will work with state agencies and PG&E to promote deployment of photovoltaic (PV) systems within MCE’s jurisdiction, with the goal of maximizing use of the available incentives that are funded through current utility distribution rates and public goods surcharges. MCE has also implemented an aggressive net energy metering program to promote local investment in distributed generation.

There are significant associated environmental benefits and strong customer interest in distributed PV systems. The economics of PV should improve over time as utility rates continue to increase and the costs of the systems decline with technological improvements and added manufacturing capacity. MCE can also promote distributed PV without providing direct financial assistance by being a source of unbiased consumer information and by facilitating customer purchases of PV systems through established networks of pre-qualified vendors. It may also provide direct financial incentives from revenues funded by customer rates to further support use of solar power within the Marin Communities. As previously noted, MCE has 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019
Total Capacity Requirement (MW) 34 55 218 273 270 330 328 325 324 324 Demand Response Target - - - - - - 4 12 16 16
Percentage of Local Capacity Requirment 0% 0% 0% 0% 0% 0% 8% 24% 32% 32% Marin Clean Energy
Demand Response Goals
(MW)
2010 to 2019
APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 35 July 2014
provided direct incentives for PV by offering an aggressive net metering rate to customers who install PV systems so that customers are able to sell excess energy to MCE.

MCE’s CCA customers will contribute funds to the California Solar Initiative (CSI) through the public goods charge collected by PG&E, and will be eligible for the incentives provided under that program for installation of PV systems. The California Solar Initiative provides $2.2 billion of funding to target installation of 1,940 MW of solar systems within the investor owned utility service areas by 2017. All electric customers of PG&E, SCE, and SDG&E are eligible to apply for incentives. Approximately 44 percent of program funding is allocated to the PG&E service territory. Assuming solar deployment would be proportionate to funding, the program is intended to yield approximately 775 MW of solar within the PG&E service area. A minimum of 17 MW should be deployed within the service territory of MCE.

MCE will work to ensure that customers within its jurisdiction take full advantage of this solar incentive and will develop programs of its own with the goal of doubling the CSI deployment targets shown above.
2010 2011 2012 2013 2014 2015 2016 2017 2018 2019
IOU Territory Target (MW) 705 882 1,058 1,235 1,411 1,587 1,764 1,940 1,940 1,940 Total Funding ($Millions) 240 240 240 160 160 160 5 0 0 0 PG&E Funding ($Millions) 105 105 105 70 70 70 2 0 0 0
PG&E Incentives Share 44% 44% 44% 44% 44% 44% 40% 40% 40% 40% PG&E Area Deployment (MW) 309 386 463 540 617 694 705 776 776 776 MCE Share of PG&E Load 0.1% 0.3% 0.8% 1.5% 1.8% 2.1% 2.1% 2.1% 2.1% 2.1% MCE Solar Deployment (MW) 0 1 4 8 11 15 15 17 17 17
California Solar Initiative Deployment
APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 36 July 2014
CHAPTER 7 – Financial Plan
This Chapter examines the monthly cash flows expected during the phase-in period of the CCA Program and identifies the anticipated financing requirements for the overall CCA Program by MCE. It also describes the requirements for working capital and long-term financing for the potential investment in renewable generation, consistent with the resource plan contained in Chapter 6.

Description of Cash Flow Analysis
This cash flow analysis estimates the level of working capital that will be required during the phase-in period. In general, the components of the cash flow analysis can be summarized into two distinct categories: (1) Cost of CCA Program Operations, and (2) Revenues from CCA Program Operations. The cash flow analysis identifies and provides monthly estimates for each of these two categories. A key aspect of the cash flow analysis is to focus primarily on the monthly costs and revenues associated with the CCA Program phase-in period, and specifically account for the transition or “Phase-In” of CCA Customers from PG&E’s service territory described in Chapter 5.

Cost of CCA Program Operations
The first category of the cash flow analysis is the Cost of CCA Program Operations. To estimate the overall costs associated with CCA Program Operations, the following components were taken into consideration:
 Electricity Procurement;
 Ancillary Service Requirements;
 Exit Fees;
 Staffing Requirements;
 Contractor Costs;
 Infrastructure Requirements;
 Billing Costs;
 Scheduling Coordination;
 Grid Management Charges;
 CCA Bond Premiums;
 Interest Expense; and
 Franchise Fees.

The focus of this cash flow analysis is during the phase-in period.

Revenues from CCA Program Operations
The cash flow analysis also provides estimates for revenues generated from CCA operations or from electricity sales to customers. In determining the level of revenues, the cash flow analysis assumes the customer phase-in schedule noted above, and assumes that MCE’s CCA Program provides a Light Green Tariff at comparable generation rates to those of the existing distribution utility for each customer class and a 100 percent Green Tariff at a premium reflective of APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 37 July 2014
incremental renewable power costs. A third service option, which is planned to begin serving customers during the 2015 calendar year, is Sol Shares. The voluntary Sol Shares service option will supply participating customers with 100 percent locally generated solar electricity – MCE is currently accepting enrollments in the Sol Shares program.

Over time, MCE’s preference for renewable energy will significantly reduce its exposure to volatile input costs (fuel – natural gas) associated with natural gas-fired generation, which are expected to increase steadily, and potentially significantly, for the foreseeable future. Because a significant portion of MCE’s power supply will be from renewable energy sources, upward price pressures on its power supply should be significantly reduced over long-term operations.

Projected long-term cost savings can be passed on to Program customers in the form of lower generation rates or can be applied to the procurement of additional renewable energy supplies (moving the program’s renewable energy supply closer to its 100 percent goal), energy efficiency programs or other energy/climate initiatives within the scope of broad-based powers established for MCE. Ultimately, MCE will have flexibility when making these decisions and can respond to the evolving needs of local residents and businesses when developing rate tariffs and energy/climate-focused programs.

Cash Flow Analysis Results
The results of the cash flow analysis provide an estimate of the level of working capital required for MCE to move through the CCA phase-in period. This estimated level of working capital is determined by examining the monthly cumulative net cash flows (revenues from CCA operations minus cost of CCA operations) based on assumptions for payment of costs by MCE, along with an assumption for when customer payments will be received. This identifies, on a monthly basis, what level of cash flow is available in terms of a surplus or deficit.

With the assumptions regarding payment streams, the cash flow analysis identifies funding requirements while recognizing the potential lag between payments received and payments made during the phase-in period. The estimated financing requirements for the phase-in period, including working capital, based on the phase-in of customers as described above is approximately $3 million. Working capital requirements reach this peak immediately after enrollment of the Phase 3 customers.

CCA Program Implementation Feasibility Analysis
In addition to developing a cash flow analysis which estimates the level of working capital required to get MCE through full CCA phase-in, a summary analysis that evaluates the feasibility of the CCA program during the phase-in period has been prepared. The difference between the cash flow analysis and the CCA feasibility analysis is that the feasibility analysis does not include a lag associated with payment streams. In essence, costs and revenues are reflected in the month in which service is provided. All other items, such as costs associated with CCA Program operations and rates charged to customers remain the same.

The results of the feasibility analysis are shown in the following table. Under these assumptions, over the entire phase-in period the CCA program is projected to accrue a reserve account balance of approximately $17 million.

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 38 July 2014
The surpluses achieved during the phase-in period serve as operating reserves for MCE in the event that operating costs (such as power purchase costs) exceed collected revenues for short periods of time.

Marin Clean Energy Financings
It is anticipated that three financings may be necessary in support of the CCA Program. The anticipated financings are listed below and discussed in greater detail.

CCA Program Start-up and Working Capital (Phases 1 and 2) As previously discussed, the start-up and working capital requirements for the CCA Program were approximately $2 million. These costs are currently being recovered from retail customers through retail rates.

CCA Program Working Capital (Phase 3)
Working capital for Phase 3 was $3 million financed through a short term credit agreement from a commercial bank.

CCA Program Working Capital (Phase 4)
MCE utilized existing, internally generated funds to cover costs associated with the Phase 4 customer expansion.

CATEGORY 2010 2011 2012 2013 2014 2015
I. REVENUES FROM OPERATIONS ($)
ELECTRIC SALES REVENUE 10,610,804 16,454,790 44,052,111 79,097,747 100,075,912 125,116,985 LESS UNCOLLECTIBLE ACCOUNTS (102,807) (21,453) (220,261) (395,489) (500,380) (625,585) TOTAL REVENUES 10,589,351 16,351,983 43,831,851 78,702,259 99,575,532 124,491,400 II. COST OF OPERATIONS ($)
(A) ADMINISTRATIVE AND GENERAL (A&G)
STAFFING 321,117 1,077,759 430,659 1,386,303 1,825,000 1,993,875 CONTRACT SERVICES 1,035,333 3,131,840 848,063 4,457,964 4,611,420 4,898,007 IOU FEES (INCLUDING BILLING) 19,548 60,794 287,618 584,729 660,114 745,569 OTHER A&G 191,261 189,204 249,729 302,806 373,125 398,084 SUBTOTAL A&G 1,567,259 1,528,720 4,746,946 6,731,802 7,469,659 8,035,535 (B) COST OF ENERGY 7,418,662 11,881,494 35,566,066 69,037,682 85,826,553 111,605,979 (C) DEBT SERVICE 654,595 394,777 1,195,162 747,729 1,195,162 1,151,494 TOTAL COST OF OPERATION 9,640,516 13,804,991 41,060,742 76,964,646 94,491,374 120,793,009 CCA PROGRAM SURPLUS/(DEFICIT) 2,546,992 948,835 2,771,109 1,737,613 5,084,158 3,698,392 Marin Clean Energy
Summary of CCA Program Phase-In
(January 2010 through December 2015)
APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 39 July 2014
CCA Program Working Capital (Phase 5)
MCE anticipates it will have sufficient internally generated funds to fund the Phase 5 customer expansion. If additional funds are required, a short term credit agreement would be used to support the expansion.

Renewable Resource Project Financing
MCE’s CCA Program may consider large project financings for renewable resources (likely wind, solar, biomass or geothermal), which may total as much as $375 million (combined).

These financings would only occur after a sustained period of successful Program operation and after appropriate project opportunities are identified and subjected to appropriate environmental review. Such financing would likely occur after several successful years of operating history have been observed and following MCE’s receipt of an institutional credit rating. In the event that such financing becomes necessary, funds would include any short-term financing for the renewable resource project development costs, and would extend over a 20- to 30-year term.

The security for such bonds would likely be a hybrid of the revenue from sales to the retail customers of MCE, including a Termination Fee as described in Chapter 9, and the renewable resource project itself.

The following table summarizes the potential financings in support of the CCA Program:

Proposed Financing Estimated Total
Amount
Estimated Term Estimated Issuance
Start-Up and Working
Capital
$2 million No longer than 7 years Early 2010
Working Capital Phase 3 $3 million No longer than 5 years Mid 2012 Potential Renewable
Resource Project Financings
$375 million
(aggregate)
20 to 30 years Undetermined
APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 40 July 2014
CHAPTER 8 - Ratesetting and Program Terms and Conditions Introduction
This Chapter describes MCE’s rate setting policies for electric aggregation services. These include policies regarding rate design, objectives, and provision for due process in setting Program rates. Program rates are ultimately approved by the Board. The Board would retain authority to modify program policies from time to time at its discretion.

Rate Policies
MCE has established rates sufficient to recover all costs related to operation of the program, including any reserves that may be required as a condition of financing and other discretionary reserve funds that may be approved by the Board of Directors. As a general policy, rates will be uniform for all similarly situated customers enrolled in the Program throughout the service area of MCE, comprised of the jurisdictional boundaries of its members.

The primary objectives of the ratesetting plan are to set rates that achieve the following:
 100 percent renewable energy supply option – Deep Green Tariff;  100 percent local solar energy supply option – Sol Shares Tariff  Rate competitive tariff option – Light Green Tariff (at 50 percent renewable energy);  Rate stability;
 Equity among customers in each tariff;
 Customer understanding; and
 Revenue sufficiency.

Each of these objectives is described below.

Rate Competitiveness
The goal is to offer competitive rates for the electric services MCE provides to participating customers. For Deep Green participants, the goal is to offer the lowest possible customer rates with an incremental monthly cost premium of approximately 10 percent. For Sol Shares customers, the goal is to offer rates that are generally reflective of local, small utility scale solar development costs, which will initially relate to prices paid under MCE’s Feed-In Tariff.

Competitive rates will be critical to attracting and retaining key customers. As discussed above, the principal long-term Program goal is to achieve 100 percent renewable energy supply subject to economic and operating constraints. As previously discussed, the Program will significantly increase renewable energy supply to Program customers, relative to the incumbent utility, by offering two distinct rate tariffs. The default tariff for Program customers will be the Light Green service option, which will maximize renewable energy supply (minimum 50 percent) while maintaining competitive generation rates to those currently offered by PG&E. MCE will also offer its customers a voluntary Deep Green Tariff, which will supply participating APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 41 July 2014
customers with 100 percent renewable energy supply at rates that reflect the Program’s cost for procuring necessary energy supplies. As previously noted, MCE will be offering a third service option, Sol Shares, which is planned to begin serving customers during the 2015 calendar year.

The voluntary Sol Shares service option will supply participating customers with 100 percent locally generated solar electricity – MCE is currently accepting enrollments in the Sol Shares program.

As previously suggested, the default tariff for Program customers will be the Light Green Tariff.

Consistent with this MCE policy, participating qualified low- or fixed-income households, such as those currently enrolled in the California Alternate Rates for Energy (CARE) program, will be automatically enrolled in the Light Green Tariff and will continue to receive related discounts on monthly electricity bills. Based on projected participation in each tariff, the amount of renewable energy supplied to Program customers as a percentage of the Program’s total energy requirements is projected to approximate 52 percent in 2015.

Rate Stability
MCE will offer stable rates by hedging its supply costs over multiple time horizons. Rate stability considerations may mean that program rates relative to PG&E’s may differ at any point in time from the general rate targets set for the Program. Although MCE’s rates will be stabilized through execution of appropriate price hedging strategies, the distribution utility’s rates can fluctuate significantly from year-to-year based on energy market conditions such as natural gas prices, the utilities’ hedging strategies, and hydro-electric conditions; and from rate impacts caused by periodic additions of generation to utility rate base. MCE will have more flexibility in procurement and ratesetting than PG&E to stabilize electricity costs for customers.

Equity among Customer Classes
MCE’s policy will be to provide rate benefits to all customer classes relative to the rates that would otherwise be paid to the local distribution utility. Rate differences among customer classes will reflect the rates charged by the local distribution utility as well as differences in the costs of providing service to each class. Rate benefits may also vary among customers within the major customer class categories, depending upon the specific rate designs adopted by the Board of Directors.

Customer Understanding
The goal of customer understanding involves rate designs that are relatively straightforward so that customers can readily understand how their bills are calculated. This not only minimizes customer confusion and dissatisfaction but will also result in fewer billing inquiries to MCE’s customer service call center. Customer understanding also requires rate structures to make sense (i.e., there should not be differences in rates that are not justified by costs or by other policies such as providing incentives for conservation).

Revenue Sufficiency
MCE’s rates must collect sufficient revenue from participating customers to fully fund MCE’s annual budget. Rates will be set to collect the adopted budget based on a forecast of electric APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 42 July 2014
sales for the budget year. Rates will be adjusted as necessary to maintain the ability to fully recover all of MCE’s costs, subject to the disclosure and due process policies described later in this chapter.

Rate Design
MCE will generally match the rate structures from the utilities’ standard rates to avoid the possibility that customers would see significantly different bill impacts as a result of changes in rate structures when beginning service in MCE’s program. MCE may also introduce new rate options for customers, such as rates designed to encourage economic expansion or business retention within MCE’s service area.

Net Energy Metering
Customers with on-site generation eligible for net metering from PG&E will be offered a net energy metering rate from MCE. Net energy metering allows for customers with certain qualified solar or wind distributed generation to be billed on the basis of their net energy consumption. The PG&E net metering tariff (E-NEM) requires the CCA to offer a net energy metering tariff in order for the customer to continue to be eligible for service on Schedule E-NEM. The objective is that MCE’s net energy metering tariff will apply to the generation component of the bill, and the PG&E net energy metering tariff will apply to the utility’s portion of the bill. MCE will pay customers for excess power produced from net energy metered generation systems in accordance with the rate designs adopted by the MCE Board.

Disclosure and Due Process in Setting Rates and Allocating Costs among Participants The Executive Officer, with support of appropriate staff, advisors and committees, will prepare an annual budget and corresponding customer rates and submit these as an application for a change in rates to the Board of Directors. The rates will be approved at a public meeting of the Board of Directors no sooner than thirty one (31) days following public posting of the proposed rates (which shall occur on MCE’s website) - during this thirty one-day review period, affected customers will be able to provide comment on the proposed rate changes.

MCE will initially adopt customer noticing requirements similar to those the CPUC requires of PG&E. These notice requirements are described as follows:

Notice of rate changes will be published at least once in a newspaper of general circulation within the respective jurisdictions of MCE’s Member Agencies. This notice will be published within ten days of MCE’s public posting of the subject rate change. Such notice will state that a copy of said application and related exhibits may be examined at the offices of MCE and shall include the locations of such offices
MCE will furnish notice of its application to its customers affected by the proposed increase, either by including such notice as an on-bill message with the regular bill for charges transmitted to such customers or by mailing such notice postage prepaid to such customers.

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 43 July 2014
The notice will state the amount of the proposed increase expressed in percentage terms, a brief statement of the reasons the increase is required or sought, and the mailing address of MCE to which any customer inquiries relative to the proposed increase, including a request by the customer to receive notice of the date, time, and place of any hearing on the application, may be directed.

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 44 July 2014
CHAPTER 9 – Customer Rights and Responsibilities
This chapter discusses customer rights, including the right to opt-out of the CCA Program and the right to privacy of customer energy usage information, as well as obligations customers undertake upon agreement to enroll in the CCA Program. All customers that do not opt out within 30 days of the fourth opt-out notice will have agreed to become full status program participants and must adhere to the obligations set forth below, as may be modified and expanded by the MCE Board from time to time.

By adopting this Implementation Plan, the MCE Board approved the customer rights and responsibilities policies contained herein to be effective at Program initiation. The Board retains authority to modify program policies from time to time at its discretion.

Customer Notices
As part of the customer enrollment process, at least four notices will be provided to customers describing the Program, informing them of their opt-out rights to remain with utility bundled generation service, and containing a simple mechanism for exercising their opt-out rights. MCE will mail at least two written notices to customers, beginning at least two calendar months, or sixty days, in advance of the date of commencing automatic enrollment. MCE will likely use its own mailing service for requisite opt-out notices rather than including the notices in PG&E’s monthly bills. This is intended to increase the likelihood that customers will read the opt-out notices, which may otherwise be ignored if included as a bill insert. Customers may opt out by notifying MCE using MCE’s designated, telephone-based opt out processing service. Should customers choose to initiate an opt-out request by contacting PG&E, they will be transferred to MCE’s call center to complete the opt-out request. Consistent with CPUC regulations, notices returned as undelivered mail would be treated as a failure to opt out, and the customer would be automatically enrolled.

Following automatic enrollment, at least two notices will be mailed to customers within the first two calendar months, or sixty days, of service. Opt-out requests made on or before the sixtieth day following start of MCE service would result in customer transfer to bundled utility service with no penalty. Such customers will be obligated to pay MCE’s charges for electric services provided during the time the customer took service from the Program, but will otherwise not be subject to any penalty or transfer fee from MCE.

New customers who establish service within the Program service area will be automatically enrolled in the Program. Such customers will be mailed two opt-out notices within two calendar months, or sixty-days, of enrollment. MCE’s Board of Directors will have the authority to implement entry fees for customers that initially opt out of the Program, but later decide to participate. Entry fees, if deemed necessary, would help prevent potential gaming, particularly by large customers, and aid in resource planning by providing additional control over the Program’s customer base. Entry fees would not be practical to administer, nor would they be necessary, for residential and other small customers.

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 45 July 2014
Termination Fee
Customers that are automatically enrolled in the Program can elect to transfer back to the incumbent utility without penalty within the first two months of service. After this free opt-out period, customers will be allowed to terminate their participation subject to payment of a Termination Fee. The Termination Fee may apply to all Program customers that elect to return to bundled utility service or elect to take “direct access” service from an energy services provider. Program customers that relocate within the Program’s service territory would have their CCA service continued at the new address. If a customer relocating to an address within the Program service territory elected to cancel CCA service, the Termination Fee may apply.

Program customers that move out of the Program’s service territory would not be subject to the Program’s Termination Fee.

The Termination Fee will consist of two parts: an Administrative Fee set to recover the costs of processing the customer transfer and other administrative or termination costs and a Cost Recovery Charge (“CRC”) that would apply in the event MCE is unable to recover the costs of supply commitments attributable to the customer that is terminating service. PG&E will collect the Administrative Fee from returning customers as part of the final bill to the customer from the CCA Program and will collect the CRC as a lump sum or on a monthly basis pursuant to a negotiated servicing agreement between MCE and PG&E.

The Administrative Fee would vary by customer class as set forth in the table below.

Administrative Fee for Service Termination
Customer Class Fee
Residential $5
Non-Residential $25
The customer CRC will be equal to a pro rata share of any above market costs of MCE’s actual or planned supply portfolio at the time the customer terminates service. The proposed CRC is similar in concept to the Cost Responsibility Surcharge charged by PG&E, and it is designed to prevent shifting of costs to remaining Program customers. The CRC will be set on an annual basis by MCE’s Governing Board as part of the annual ratemaking process. At this time, MCE’s CRC is set to zero.

If customers terminate service, MCE anticipates it will re-market the excess supply and recover all or the majority of its costs. Depending upon market conditions, the CRC may not be needed for recovery of stranded costs. However, MCE’s ability to assess a Cost Recovery Charge, if necessary, can be an important condition for obtaining financing for MCE’s power supply. The low cost financing will, in turn, enable MCE to charge rates that are competitive with PG&E’s.

The Termination Fee will be clearly disclosed in the four opt-out notices sent to customers during the sixty-day period before automatic enrollment and following commencement of APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 46 July 2014
service. The fee could be changed prospectively by MCE’s Board of Directors, subject to MCE’s customer noticing requirements. As previously noted, customers that opt-out during the statutorily mandated notification period will not pay the Termination Fee that may be imposed by MCE.

Customers electing to terminate service after the initial notification period that provided them with at least four opt-out notices would be transferred to PG&E on their next regularly scheduled meter read date if the termination notice is received a minimum of fifteen days prior to that date. Customers who voluntarily transfer back to PG&E after the initial notification period that provided them with at least four opt-out notices would also be liable for the nominal reentry fees imposed by PG&E as set forth in the applicable utility CCA tariffs. Such customers would also be required to remain on bundled utility service for a period of one year, as described in the utility tariffs.

Customer Confidentiality
MCE has established policies covering confidentiality of customer data. These policies are fully compliant with the California Public Utility Commission’s required privacy protection rules for CCA customer energy usage information detailed within Decision D.12-08-045. MCE’s policies will maintain confidentiality of individual customer data. Confidential data includes individual customers’ name, service address, billing address, telephone number, account number and electricity consumption. Aggregate data may be released at MCE’s discretion or as required by law or regulation.

Responsibility for Payment
Customers will be obligated to pay MCE charges for service provided through the date of transfer including any applicable Termination Fees. Pursuant to current CPUC regulations, MCE will not be able to direct that electricity service be shut off for failure to pay MCE’s bill.

However, PG&E has the right to shut off electricity to customers for failure to pay electricity bills, and Rule 23 mandates that partial payments are to be allocated pro rata between PG&E and the CCA. In most circumstances, customers would be returned to utility service for failure to pay bills in full and customer deposits would be withheld in the case of unpaid bills. PG&E would attempt to collect any outstanding balance from customers in accordance with Rule 23 and the related CCA Service Agreement. The proposed process is for two late payment notices to be provided to the customer within 30 days of the original bill due date. If payment is not received within 45 days from the original due date, service would be transferred to the utility on the next regular meter read date, unless alternative payment arrangements have been made.

Consistent with the CCA tariffs, Rule 23, service cannot be discontinued to a residential customer for a disputed amount if that customer has filed a complaint with the CPUC, and that customer has paid the disputed amount into an escrow account.

Customer Deposits
Customers may be required to post a deposit equal to two months’ estimated bills for MCE’s charges to obtain service from the Program. MCE has adopted a related policy, Rule No. 002, which specifies the circumstances under which a customer deposit will be required. This policy APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 47 July 2014
specifies that “An applicant who previously has been a customer of PG&E or MCE and whose electric service has been discontinued by PG&E or MCE during the last twelve months of that prior service because of nonpayment of bills, may be required to reestablish credit by depositing the amount prescribed in Rule 003 (Deposits) for that purpose.” Rule No. 002 also states that, “A customer who fails to pay bills before they become past due as defined in PG&E Electric Rule 11 (Discontinuance and Restoration of Service), and who further fails to pay such bills within five days after presentation of a discontinuance of service notice for nonpayment of bills, may be required to pay said bills and reestablish credit by depositing the amount prescribed in Rule 003 (Deposits). This rule will apply regardless of whether or not service has been discontinued for such nonpayment11
.” Rule 003 specifies that the amount of deposit for such a customer shall be equal to two months’ estimated charges for MCE service. Failure to post deposit as required would cause the account service transfer request to be rejected, and the account would remain with PG&E. To date, MCE has not collected any customer deposits.

11 A customer whose service is discontinued by MCE is returned to PG&E generation service.

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 48 July 2014
CHAPTER 10 - Procurement Process
Introduction
This Chapter describes MCE’s initial procurement policies and the key third party service agreements by which MCE has obtained operational services for the CCA Program. By adopting the original Implementation Plan, MCE’s Board of Directors approved general procurement policies to be effective at Program initiation. The Board retains authority to modify Program policies from time to time at its discretion.

Procurement Methods
MCE has entered into agreements for a variety of services needed to support program development, operation and management. It is anticipated MCE will utilize Competitive Procurement, Direct Procurement or Sole Source Procurement, depending on the nature of the services to be procured. Direct Procurement is the purchase of goods or services without competition when multiple sources of supply are available. Sole Source Procurement is generally to be performed only in the case of emergency or when a competitive process would be an idle act.

MCE utilized a competitive solicitation process to enter into agreements with SENA, which provides electrical services for the program. Agreements with entities that provide professional legal or consulting services, and agreements pertaining to unique or time sensitive opportunities, may be entered into on a direct procurement or sole source basis at the discretion of MCE’s Executive Officer or Board of Directors.

The Executive Officer periodically reports (e.g., quarterly) to the Board a summary of the actions taken with respect to the delegated procurement authority.

Authority for terminating agreements will generally mirror the authority for entering into the agreements.

Key Contracts
Electric Supply Contract
MCE successfully negotiated an electricity supply contract with SENA (through December 31, 2016). For the initial years of program operations (, SENA will supply a significant portion of the electricity delivered to MCE customers. For the post-2016 period, MCE will be obligated to complete additional solicitations to secure its resource requirements. In anticipation of this future obligation, MCE has initiated procurement efforts, focusing on necessary renewable energy supply and resource adequacy capacity, to facilitate the transition from full requirements service to a managed portfolio of contracts/resources. This proactive, ongoing approach will avoid dependence on market conditions existing at any single point in time.

Under the initial full requirements contract, SENA has committed to serving the composite electrical loads of customers in the Program. SENA also serves as MCE’s certified Scheduling APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 49 July 2014
Coordinator and will schedule the loads of all customers in the Program, providing necessary electric energy, capacity/resource adequacy requirements, renewable energy and ancillary services. SENA is wholly responsible for the Program’s portfolio operations functions and managing the predominant supply risks for the term of the contract. SENA must also meet the Program’s renewable energy goals and comply with all applicable resource adequacy and regulatory requirements imposed by the CPUC or FERC.

Certain financial risks related to changes in Program loads during the term of the agreement are borne by SENA, within the ranges specified in the electric supply agreement. The supplier has also committed to deliver a specific quantity of RPS-eligible renewable energy, as determined by MCE, during each year of the agreement term. The supplier is also required to procure sufficient renewable energy to meet the requirements of serving customers enrolled in the Deep Green MCE service option.

Data Management Contract
Noble Americas Energy Solutions will provide the retail customer services of billing and other customer account services (electronic data interchange or EDI with PG&E, billing, remittance processing, and account management). Recognizing that some qualified wholesale energy suppliers do not typically conduct retail customer services whereas others (i.e., direct access providers) do, the data management contract is separate from the electric supply contract...12 The data manager is responsible for the following services:
 Data exchange with PG&E;
 Technical testing;
 Customer information system;
 Customer call center;
 Billing administration/retail settlements; and
 Reporting and audits of utility billing.

Utilizing a third party for account services eliminates a significant expense associated with implementing a customer information system. Such systems can cost from five to ten million dollars to implement and take significant time to deploy. A longer term contract is appropriate for this service because of the time and expense that would be required to migrate data to a new system. Separation of the data management contract from the energy supply contract gives MCE greater flexibility to change energy suppliers, if desired, without facing an expensive data migration issue.

12 The contractor performing account services may be the same entity as the contractor supplying electricity for the program.

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 50 July 2014
Electric Supply Procurement Process
As previously noted, MCE selected SENA as its energy supplier through a competitive solicitation process, which was administered in mid-2009. Additional information regarding SENA is provided below.

Shell Energy North America
Shell Energy North America (US), L.P. (SENA) is a leading supplier of energy and associated services in North America. SENA provides natural gas, electrical energy and capacity, scheduling and asset optimization, risk management, and renewable energy and environmental products to a wide variety of customers. SENA is 100% owned by Royal Dutch Shell Company and its subsidiaries. SENA owns and manages a variety of energy assets in the West, including generation, a portfolio of renewable energy, transmission capacity, natural gas production, liquefied natural gas capacity, natural gas storage capacity, and natural gas pipeline capacity.

SENA’s West Region operation includes regional offices in San Diego, Portland, Spokane, Berkeley, Salt Lake City, Denver and Mexico City, with 7 X 24 power and gas operations in San Diego and Spokane.

SENA has an extensive list of public and privately owned customers in the West, including all WECC region investor-owned utilities, twenty-five publicly owned (municipal) electric utilities/other public agencies in California, and publicly owned utilities/public agencies in neighboring states. SENA’s West Region full requirements power experience includes provision of retail electric service, including provision of resource adequacy, for direct access customers in California.

Renewable energy products offered by SENA include renewable energy, bundled renewable energy, landfill gas, biogas and renewable energy credits. SENA states it is actively developing renewable portfolios and provides related services such as scheduling and shaping of intermittent energy. SENA’s affiliate, Shell WindEnergy, develops and owns wind generation in California and other parts of North America. SENA also offers a variety of environmental products including emission offsets and other carbon reducing products.

SENA is rated A- by S&P and A2 by Moody’s.

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 51 July 2014
CHAPTER 11 – Contingency Plan for Program Termination
Introduction
This Chapter describes the process to be followed in the case of Program termination. By adopting the original Implementation Plan, MCE’s Board of Directors approved the general termination process contained herein to be effective at Program initiation. In the unexpected event that MCE would terminate the Program and return its customers to PG&E service, the proposed process is designed to minimize the impacts on its customers and on PG&E. The proposed termination plan follows the requirements set forth in PG&E’s tariff Rule 23 governing service to CCAs. The Board retains authority to modify program policies from time to time at its discretion.

Termination by Marin Clean Energy
MCE will offer services for the long term with no planned Program termination date. In the unanticipated event that the majority of the Member’s governing bodies (County Board of Supervisors and/or City/Town Councils) decide to terminate the Program, each governing body would be required to adopt a termination ordinance or resolution and provide adequate notice to MCE consistent with the terms set forth in the JPA Agreement. Following such notice, MCE would vote on Program termination subject to a two-tiered vote, as described in the JPA Agreement. In the event that the Board affirmatively votes to proceed with JPA termination, the Board would disband under the provisions identified in its JPA Agreement.

After any applicable restrictions on such termination have been satisfied, notice would be provided to customers six months in advance that they will be transferred back to PG&E. A second notice would be provided during the final sixty-days in advance of the transfer. The notice would describe the applicable distribution utility bundled service requirements for returning customers then in effect, such as any transitional or bundled portfolio service rules.

At least one year advance notice would be provided to PG&E and the CPUC before transferring customers, and MCE would coordinate the customer transfer process to minimize impacts on customers and ensure no disruption in service. Once the customer notice period is complete, customers would be transferred en masse on the date of their regularly scheduled meter read date.

MCE will post a bond or maintain funds held in reserve to pay for potential transaction fees charged to the Program for switching customers back to distribution utility service. Reserves would be maintained against the fees imposed for processing customer transfers (CCASRs).

The Public Utilities Code requires demonstration of insurance or posting of a bond sufficient to cover reentry fees imposed on customers that are involuntarily returned to distribution utility service under certain circumstances. The cost of reentry fees are the responsibility of the energy services provider or the community choice aggregator, except in the case of a customer returned for default or because its contract has expired. MCE will post financial security in the APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 52 July 2014
appropriate amount as part of its registration materials and will maintain the financial security in the required amount, as necessary.

Termination by Members
The JPA Agreement defines the terms and conditions under which Members may terminate their participation in the program.

APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan 53 July 2014
CHAPTER 12 – Appendices
Appendix A: MCE Resolution 2014-03
Appendix B: County of Napa, Resolution 2014-59
Appendix C: Marin Clean Energy Joint Powers Agreement
Appendix D: County of Napa, CCA Ordinance – Ordinance No. 1391 APPENDIX D AI #09_Att. C: MCE Revised Community Aggregation Implementation Plan DRAFT

Board of Directors Meeting
Thursday, February 16, 2023
7:00 P.M.

This Meeting will be conducted via teleconference pursuant to the requirements of Assembly Bill No. 361. By using teleconference for this meeting, MCE continues to promote social distancing measures recommended by local officials.

Members of the public who wish to observe the Meeting and/or offer public comment may do so telephonically via the following teleconference call-in number and meeting ID:

For Viewing Access Join Zoom Meeting:
https://us02web.zoom.us/j/86784992940?pwd=SDF1NUpjbWZVRy9BRnBTSFJYcXZpUT09 Dial: (669) 900-9128
Webinar ID: 867 8499 2940
Passcode: 314955

Agenda Page 1 of 2

1. Roll Call/Quorum

2. Board Announcements (Discussion)

3. Public Open Time (Discussion)

4. Board Introductions (Discussion)

5. Report from Chief Executive Officer (Discussion)

6. Consent Calendar (Discussion/Action)
C.1 Approval of 12.15.22 Meeting Minutes
C.2 Approved Contracts For Energy Update

7. McGlashan Award Presentation (Discussion)

8. Climate Action Leadership Awards (Discussion)
AI #10: Draft 2.16.23 Board Agenda
MCE ~r::ri~~~ng Energy Future

CONTRA COSTA I MARIN I NAPA I SOLANO

MARIN COUNTY I NAPA CO UNTY I UNINCORPORATED CONTRA COSTA COUNTY I UNINCORPORATED SOLANO COUNTY

BENICIA I CONCORD I DANVILLE I EL CERRITO I FAIRFIELD I LAFAYETTE I MARTINEZ I MORAGA I OAKLEY

PINOLE I PITTSBURG I PLEASANT HILL I RICHMOND I SAN PABLO I SAN RAMON I VALLEJO I WALNUT CREEK Agenda Page 2 of 2

9. Election of Vice Chair and Addition of Board Members to Committees (Discussion/Action)

10. Policy Update (Discussion)

11. In Person Meetings and Teleconferencing Options Under the Brown Act and AB 2449 (Discussion)

12. Next Steps for Concord Office Space (Discussion)

13. Form 700 - Statements of Economic Interest (Discussion)

14. Board Matters & Staff Matters (Discussion)

15. Adjourn

The Board may discuss and/or take action on any or all of the items listed on the agenda irrespective of how the items are described.

DISABLED ACCOMMODATION: If you are a person with a disability which requires an accommodation or an alternative format, please call MCE at 1 (888) 632-3674 at least 72 hours before the meeting start time to ensure arrangements for accommodation.

AI #10: Draft 2.16.23 Board Agenda