HomeMy WebLinkAboutCOM 0532.001 2002-2004
'~~~Inte rated Resource Plannin
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Presentation to the Hawaii County Council
March 4, 2004
Comm. Wo. S 3 2.1 1
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Decision-making process to determine
how a utility is to meet future energy
demands
~jr Governed by the IRP Framework issued
by the Hawaii PUC in Docket No. 6617,
May 22, 1992
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IRP Framework
Goal
~~The goa I of integrated resource
planning is the identification of the
resources or the mix of resources for
meeting near and long term consumer
energy needs in an efficient and reliable
manner at the lowest reasonable cost."
IRP Framework, Section I.A, Page 3
What is a resource? What is an Integrated
Resource Plan?
3
What are resources?
Supply-Side Demand-Side
(Generation) (Load Control,
Conservation and
Energy Efficiency)
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Customer
Meter
Return to IRP Goal
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What is an Into rated
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Resource Plan?
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eri~''~ab atilo~'
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~ C An Integrated Resource
~S~ Plan is a portfolio of
demand-side and
supply-side resources
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Return to IRP Goal
21
II
IRP Framework
Governing Principles
{ '
"(1) The development of integrated resource plans is
the responsibility of each utility."
"(2) Integrated resource plans shall be developed
upon consideration and analyses of the costs,
effectiveness, and benefits of all appropriate,
available, and feasible supply-side and
demand-side options."
IRP Framework, Section II.B, Pages 3 -4
4
IRP Framework
Governing Principles (continued)
i ~~(3) Integrated resource plans shall give
consideration to the plans' impacts upon the
utility's consumers, the environment,
culture, community lifestyles, the State's
economy, and society."
'~(4) Integrated resource plans shall take into
consideration the utility's financial
integrity, size, and physical capability."
IRP Framework, Section II.B, Page 4
5
I
IRP Framework
Governing Principles (continues)
~~(5) Integrated resource planning shall be an open
public process. Opportunities shall be provided
for participation by the public and governmental
agencies in the development and in commission
~I review of integrated resource plans."
IRP Framework, Section II.B, Page 4
6
i
IRP Framework
Governing Principles (continued)
~~(6) The utility is entitled to recover all appropriate
and reasonable integrated resource planning
and implementation costs. In addition, existing
disincentives should be removed and, as
appropriate, incentives should be established to
I, encourage and reward aggressive utility pursuit
of demand-side management programs.
Incentive mechanisms should be structured so
that investments in suitable and effective
demand-side management programs are at
least as attractive to the utility as
investments in supply-side options."
IRP Framework, Section II.B, Page 4
i
IRP Framework
Submission to the Commission
" The utility shall include in its integrated resource plan a full and II
detailed description of
(1) the needs identified
j, (2) the forecasts made
(3) the assumptions underlying the forecasts
(4) the objectives to be attained by the plan
(5) the measures by which achievement of the objectives is to
be assessed
(6) the resource options or mix of options included in the
plan
(7) the assumptions and the basis of the assumptions
underlying the plan
IRP Framework, Section III.D.1, Page 9
s
IRP Framework
Submission to the Commission (continues)
(8) the risks and uncertainties associated with the plan
(9) the revenue requirements on a present value basis and
on an annual basis
(10) the expected impact of the plan on demand
(11) the expected achievement of objectives
(12) the potential impact of the plan on rates, consumer
bills, and consumer energy use
(13) the plan's external costs and benefits
(14) the relative sensitivity of the plan to changes in
assumptions and other conditions.
The items enumerated should, where appropriate, be described
for the plan as a whole and for each of the resources or mix of
resources included in the plan."
IRP Framework, Section III.D.1, Page 9
9
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IRP Framework
Submission to Commission (Continued)
The integrated resource plan and
implementation schedule approved by
the commission shall govern all utility
expenditures for capital projects,
purchased power, and demand-
side management programs."
IRP Framework, Section III.D.5, Page 12
10
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IRP Framework
Advisor Grou s ~I
Y p
The utility shall organize in each county in which
I, the utility provides service or conducts utility business
a group or groups of representatives of public
and private entities to advise the utility in the
development of its integrated resource plan. A
separate advisory group may be formed for each
stage of the planning process, as appropriate. The
utility shall chair each advisory group."
IRP Framework, Section III.E.i.a, Page 13
ii
IRP Framework
ACIVISOry GrOUpS (continued)
I, "The public and private entities includable in an
advisory group are those that represent
interests that are affected by the utility's
integrated resource plan and that can provide
significant perspective or useful expertise in the
development of the plan. These entities include state
and county agencies and environmental, cultural,
business, and community interest groups. An
advisory group should be representative of as broad
a spectrum of interests as possible, sub'ect to the
limitation that the interests represented'should not
be so numerous as to make deliberations as a
group unwieldy."
IRP Framework, Section III.E.1.b, Page 13
iz
IRP Framework
AdVISOry Groups (continued)
"The utili shall consider the in ut of each advisor
ty p y
group; but the utility is not bound to follow the
advice of any advisory group."
II "All data reasonably necessary for an advisory group
to participate in the utility's integrated resource
planning process shall be provided by the utility,
subject to the need to protect the confidentiality
of customer-specific and proprietary information."
IRP Framework, Section III.E.1.c & d, Page 13
13
I RP Framework
AdVISOry GrOUpS (continued)
The use by the advisory groups of the collaborative
process is encouraged to arrive at a consensus on
j issues."
All reasonable out-of-pocket costs incurred by
participants in advisory groups (other than
governmental agencies) shall be paid for by the
utility, subject to recovery as part of the utility's
cost of integrated resource planning."
IRP Framework, Section III.E.1.e and f, Pages 13 & 14
14
IRP Framework
AdVISOry GrOUpS (continued)
III ' .
The AG s Role is to Provide the Following.
1. Policy-level advice on IRP ob~ectwes &
measures, and on resource plan concepts
2. Policy-level advice on preferred plan selection
3. Written portions of the final report
4. General comments throughout the process
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IRP Framework
Public Hearings
"The utili is encoura ed to conduct ublic
tY g p
hearings or provide public forums at the various,
discrete phases of the planning process for the
purpose of securing the input of those members of
the public who are not represented by entities
constituting advisory groups."
IRP Framework, Section III.E.2.a, Page 14
16
IRP Framework
Public Participation
Tentative Plans for HELCO's IRP-3 Public
Participation:
IRP web site to be established for posting information
IRP a-mail address for comments from the public
Public informational meetings to be held with
opportunities for public comments
Portions of Advisory Group meetings may be open
to the public
Speakers Bureau w/involvement from AG Members
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I RP Framework
Planning Considerations
"The utility shall rank the various plans, based on
such criterion as it may establish with the advice of
its advisory groups. The utility shall designate
one of these plans as its preferred plan and
submit to the commission the preferred plan as its
integrated resource plan."
IRP Framework, Section IV.I.4, Page 24
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~~'Inte rated Resource Plannin
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A FRAN,EWORK FOR INTEGRATED RESOURCE PLANNING
Revised Nay 22, 1992
PUBLIC UTILITIES COMMISSION
STATE OF HAWAII
TABLE OF CONTENTS
Fage
I. Definitions 1
II. Introduction 3
A. Goal of Integrated Resource Planning 3
B. Governing Principles (Statements of Policy). 3
C. Utility's Responsibility 4
D. Commission's Responsibility. 5
E. Consumer A.dvocate's Responsibility 5
III. The Planning Context 6
A. Major Steps 6
B. The Planning Cycle 7
C. The Docket 8
D. Submissions to the Commission 9
E. Public Participation 13
1. Advisory groups 13
2. Public hearings 14
3. Intervention 14
4. Intervenor funding 15
F. Cost Recovery and Incentives 16
IV. Planning Considerations 19
A. Forecast 19
B. Objectives 20
C. Effectivene=_s Measures 20
D. Resource Options 20
E. Data Collection 21
i
F. la sumptions; Ri si:s; Uncertaint~e=_ 22
G. Models 22
H. Lnalyses 22
I. Resource Optimization 23
J. Sensitivity Anaiysi=_ 24
V. Pilot Demand-Side Maraaement Progra,~~s 24
A. Purposes 24
B. Utility Pilot Frograms 24
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PUBLIC UTILITIES COMMISSION
STATE OF HAWAII
A FRAMEWORK FOR INTEGRATED RESOURCE PLANNING
N.arch 9, 1992
I. Definitions
Unless otherwise clear from the context, as used in this
framework:
"Capital investment costs" means costs associated with capital
improvements, including planning, the acquisition and
development of land, the design and construction of new
facilities, the making of renovations or additions to existing
facilities, the construction of built-in equipment, and
consultant and staff services in planning, design, and
construction. Capital investment costs for a program are the
sum of the program's capital improvement project costs.
"Costs" means the full and life cycle costs of a resource
option.
"Cost categories" means the major types of costs and includes
research and development costs, investment costs, and
operating and maintenance costs.
"Cost elements" means the major subdivisions of a cost
category. For the category "investr,,ent costs," it includes
capital investment costs, initial equipment and furnishing
costs, and initial education and trainina_ costs. For the
categories "research and development ccsts" and "operating and
maintenance costs," it includes labor costs, fuel tests,
materials and supplies costs, and other current
expenses.
"Demand-side management programs" means programs designed to
influence utility customer uses of energy to produce desired
changes in demand. It includes conservation, load management,
and efficiency resource programs.
"Design costs" means the costs related to the preparation of
architectural drawings for capital improvements, from
schematics to final construction drawings.
"Effectiveness measure" means the criterion for measuring the
degree to which the objective sought is attained.
1
"External benefits" means external economies; benefits to or
positive impacts on the activities of entities outside the
utility and its ratepayers. External benefits include
environmental, cultural, and general economic benefits.
"External costs" means external diseconomies; costs to or
negative impacts on the activities of entities outside the
utility and its ratepayers. External costs include
environmental, cultural, and general economic costs.
"Full cost" means the total cost of a program, system, or
capability, including research and development costs, capital
investment costs, and operating and maintenance costs.
"Investment costs" means the one-time costs beyond the
development phase to introduce a new system, program, or
capability into use. It includes capital investment costs,
initial equipment acquisition tests, and initial education and
training costs.
"Life cycle costs" means the total cost impact over the life
of the program. Life cycle costs include research and
development cost, investment cost (the one-time cost of
instituting the program), and operating and maintenance (O&M)
cost.
"Objective" means a statement of the end result, product, or
condition desired, for the accomplishment of which a course of
action is taken.
"Operating and maintenance costs" or "O&M costs" means
recurring costs of operating, supporting, and maintaining
authorized programs, including tests for labor, fuel,
materials and supplie=_, and other current expenses.
"Participant impact" mean=_ the impact on participants in a
demand-side management proeram in terms of the costs borne and
the direct, economic benefits received by the participants.
"Program" means a combination of resources and activities
designed to achieve an objective or objectives.
"Program size" means the r,~agnitude of a program, such as the
number of persons serviced by the program, the amount of a
commodity, the time deiavs, the volume of service in relation
to population or area, etc.
"Program size indicator" Weans a measure to indicate the
magnitude of a program.
2
"Ratepayer impact" means the impact on ratepayers in terms of
the utility rates that ratepayers must pay.
"Research and development costs" means costs associated with
the development of a new system, program, or capability to the
point where it is ready for introduction into operational use.
It includes the costs of prototypes and the testing of the
prototypes. It includes the costs of research, planning, and
testing and evaluation.
"Societal cost" means the total direct and indirect costs to
society as a whole. Society includes the utility and, in a
demand-side management program, the participants.
"Societal cost-benefit assessment" means an assessment of the
costs and benefits to society as a whole.
"Supply-=ide orocrams" means programs designed to supply
power. It includes renewable energy.
"Total resource cost" means the total cost of a demand-side
management program, including both the utility and
participant=-' costs.
"Utility cost" means the cost to the utility (including
ratepayers), excluding cests incurred by participants in a
demand-=_ide management program.
"Utility cost-benefit assessment" means an assessment of the
costs and benefits to the utility.
II. Introduction
A. Goai of Integrated Resource Flanning
The coal of integrated resource planning is the
identification of the resources or the mix of resources
for meeting near and long term consumer energy needs in
an efficient and reliable manner at the lowest reasonable
cost.
B. Governing Principles (Statements of Policy)
1. The development of integrated resource plans is the
responsibility of each utility.
3
2. Integrated resource plans shall comport with state
and county environmental, health, and safety laws
and formally adopted state ar.d county plans.
3. Integrated resource plans shall be developed upon
consideration and analyses of the costs,
effectiveness, and benefits of all appropriate,
available, and feasible supply-side and demand-side
options.
4. Integrated resource plans shall dive consideration
to the plans' impacts upon the utility's consumers,
the environment, culture, community lifestyles, the
State's economy, and society.
5. Integrated resource plans shall take into
consideration the utility = financial integrity,
size, and physical capabilit}'.
6. Integrated resource planning shall be an open
public process. Opportunities shall be provided
for participation by the public and governmental
agencies in the development and in commission
review of integrated resource plans.
7. The utilit}> is entitled to recover all appropriate
and reasonable integrated resource planning and
implementation ccsts. Zn addition, existing
disincentives should be removed and, as
appropriate, incentives should be established to
encourage and reward aggressive utility pursuit of
demand-side ,;,anagement programs. Incentive
mechanis,~.s should be structured so that investments
in suitable and effective remand-side management
programs are at least as attractive to the utility
as investment_ in supply-side options.
C. Utility's Responsibility
1. Each utility is responsible for developing a plan
or plans for meeting the energy needs of its
customers.
c. The utility =-hall prepare and submit to the
commission for commission approval at the time or
times =_pecified in this framework the utility'=_
integrated resource plan and program implementation
schedule.
4
3. The utility shall execute the commission approved
plan in accordance with the program implementation
schedule.
4. The utility shall annually examine and evaluate its
achievements in attaining its objectives.
D. Commission's Responsibility
1. The commi=_sion's responsibility, in general, is to
determine whether the utility's plan represents a
reasonable course for meeting the energy needs of
the utility's customers and is in the public
interest and consistent with the coals and
objectives of integrated resource planning.
2. Specifically, the commission will review the
utility's integrated resource plan, its program
implementation schedule, and its evaluations, and
generally monitor the utility's implementation of
its plan. Upon review, the commission may approve,
reject, approve in part and reject in part, or
require modifications of the utility's integrated
resource plan and program implementation schedule.
3. The parties shall cooperate in expediting
commission hearings on the utility's integrated
resource plan and program implementation schedule.
To the extent possible, the commission will hear
the utility's application for approval of its
integrated resource plan within six months of the
plan's filing, and the commission will render its
decision shortly thereafter.
E. Consumer Advocate's Responsibility
1. The director of commerce and consumer affairs, as
the consumer advocate and through the division of
consumer advocacy, has the statutory responsibility
to represent, protect, and advance the interest of
consumers of utility services. The consumer
advocate, therefore, has the duty to ensure that
the utility's integrated resource plan promotes the
interest of utility consumers.
2. The consumer advocate shall be a party to each
utility's integrated resource planning docket and a
member of any and all advisory groups established
by the utility in the development of its integrated
resource plan. The consumer advocate shall also
participate in all public hearings and other
sessions held in furtherance of the utility's
efforts in integrated resource planning.
III. The Planning Context
A. Major Steps
There are four major steps in the integrated resource
planning process: planning, programming, implementation,
and .valuation.
1. Plannin? is that process .n which the utility's
needs are identified; the utility's objectives are
formulated; measures by 'Which effectiveness in
attaining objectives are specified; the
alternatives by which the objectives may be
attained are identified; the full cost,
effectiveness, and benefit implications of each
alternative are determined; the assumptions, risks,
and uncertainties are clarified; the cost,
effectivene=_s, and benefit tradeoffs of the
alternatives are made; the resource options are
chosen; and program chcices are subjected to
sensitivity analyse. The product of this process
is the utility's integrated resource plan. The
planning horizon for utility integrated resource
plans is 20 years. Unless otherwise ordered by the
commi=_sion, the 20-year period begins on January 1
following the completion cf the plan.
2. Programming is that process by which the utility's
long-ranoe resource program plans are scheduled for
implementation over a five-year period. In this
process, a determination i=_ made as to the crder in
which the selected program options are to be
implemented; the phases cr steps in which each
program is to be implemented; the expected target
group and the annual size of the target group or
annual level of penetration of demand-=_ide
manacement programs; the expected annual
supply-side capacity additicr.s; the expected annual
level_ cf effectivene=_s in achieving integrated
resource planning cb~ect.•.%es; and the annual
expenditures, by cost catea_cries and cost elements,
required to be made by t7e utility to support
implementation of the crocrams. The result of this
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process is a program implementation schedule or
action plan. The schedule represents an
implementation strategy or timetable for program
implementation.
3. Implementation is that process by which the
resource program options to be implemented are
acquired and instituted in accordance with the
utility's program implementation schedule.
4. Evaluation is that process by which the results of
the resource program options are measured in light
of the utility's objectives. In this process the
actual costs, effectiveness, and benefits of the
resource options and the attainment of the
utility's objectives are ~,easured against those
that were projected in the planning and programming
stages of the planning cycle.
B. The Planning Cycle
1. Each utility shall complete its initial integrated
resource plan and implementation schedule and
submit them for commission approval by the
following dates:
a. Kauai Electric Division of Citizens Utilities
Company: May 1, 1993.
b. Gasco, Inc.: May 1, 1993.
c. Hawaiian Electric Company, Inc.: July 1,
1993.
d. Hawaii Electric Light Company, Inc.:
September 1993.
e. Maui Electric Company, Limited: November 1,
1993.
2. Each utility shall conduct a major review of its
integrated resource plan every three years. In
such a review, a new 20-year time horizon shall be
adopted, the planning proce=_=_ repeated, and the
utility's resource programs re-analyzed fully. The
first major review, following the submission of
each utilit}~'=_ initial integrated resource plan to
the commi=_sicn in 1993, =_hall commence in 1995 so
as to result in the submission to the ccmmission of
a new (second) integrated resource plan and
implementation schedule in 1996 as follows:
a. Hawaiian Electric Company, Inc.: ,7anuary 1,
1996.
b. Kauai Electric Division of Citizens Utilities
Company: April 1, 1956.
c. Gasco, Inc.: F.pril 1, 1996.
d. Hawaii Electric Light Company,Inc.: June 1,
1996.
e. Maui Electric Company, Limited: October 1,
1996.
Thereafter, each utility shall conduct a major
review, resulting in the submission to the
commission of a new integrated resource plan and
implementation schedule on the same day every three
years.
C. The Docket
1. Each planning cycle for a utility will commence
with the issuance of an order by the commission
opening a docket for integrated resource planning.
2. The docket will be maintained throughout the
planning cycle for the filing of documents, the
resolution of procedural disputes, and other
purpcses related to the utility'=_ integrated
resource plan.
3. Within 30 days after the opening of the docket, the
utility shall prepare, in consultation with the
consumer advocate, and file with the commission a
schedule that it intends to follow in the
development cf its integrated resource plan. The
schedule may be amended upon the formation of an
advisory group or croups and thereafter as
appropriate.
4. The utility shall complete its integrated resource
plan and program implementation schedule within one
year of the commencement cf the planning cycle.
S
D. Submi_sions to the Commission
1. The utility shall submit its integrated resource
plan as follows.
a. The utility shall include in its integrated
resource plan a full and detailed description
of (1) the needs identified; (2) the forecasts
made; (3) the assumptions underlying the
forecasts; (4) the objectives to be attained
by the plan; (5) the measures by which
achievement of the objectives is to be
assessed; (6) the resource options or mix of
options included in the plan; (7) the
assumptions and the tasis of the assumptions
underlying the plan; (8) the risks and
uncertainties associated with the plan;
(9) the revenue requirements on a present
value basis and on an annual basis; (10) the
expected impact of the plan on demand;
(11) the expected achievement of objectives;
(12) the potential impact of the plan on
rates, consumer bills, and consumer energy
use; (13) the plan's external costs and
benefits; and (14) the relative sensitivity of
the plan to chances in assumptions and other
conditions. The items enumerated should,
where appropriate, be described for the plan
as a whole and for each of the resources or
mix of resources included in the plan.
b. The utility shall file with the integrated
resource plan a full and detailed description
of the analysis er analyses upon which the
plan is based. The utility .shall fully
describe, among other things, (1) the data
(and the source of the rata) upon which needs
were identified and forecasts made; (2) the
methodologies used in forecasting; (3) the
various objectives and measures of assessing
attainment of objectives that were considered,
but rejected, and the reasons for rejecting
any objective or measure; (4) the resource
options that were identified, but screened out
and not considered and the reasons for the
rejection of any resource option; (5) the
assumptions and the oasis of the assumptions,
the risks and uncertainties, the costs,
effectiveness, and benefits (including
external costs and benefits), and the impacts
9
on demand, rates, consumer bills, and consumer
energy uses associated with each resource
option or mix of options that was considered;
(6) the comparisons and the cost,
effectiveness, and benefit tradeoffs and
optimization made of the options and mixes of
options; (7) the models used in the
comparisons, tradeoffs, and optimization; (8)
the criteria used in any ranking of options
and mixes of cptions; and (9) the sensitivity
analyses ccnducted for the options and mixes
of options.
c. The utility shall also file with the
integrated resource plan a description of all
alternate plans that the utility developed,
the ranking it accorded the various plans, the
criteria used in such ranking, and a full and
detailed explanation of the analysis upon
which it decided its preferred integrated
resource plan.
d. The submissions_hould be simply and clearly
written and, to the extent possible, in
non-technical language. Charts, graphs, and
other visual devices may be utilized to aid in
understanding its plan and the analyses made
by the utility. The utility shall provide an
executive summary of the plan and of the
analyses and appropriately index its
submissions.
The utility shall_ubmit its program implementation
schedule as follows.
a. The utility shall include in the schedule by
year: the programs or phases of programs to
be implemented in the year; the expected level
of achievement of objectives; the expected
size of the target croup or level of
penetration of any demand-side management
program; the expected supply-side capacity
addition; the expenditures, by cost categories
and cost elements, required to be made by the
utility to support implementation of each
program or phase of a program.
b. The utility shall file with its program
implementation schedule a full and detailed
description of the analysis upon which the
10
schedule is based. The utility shall fully
describe, among other things:
(1) The steps required to realize and
implement the supply-side~,nd demand-side
resource programs included in the
schedule.
(2) How the target groups were selected and
how program penetration for demand-side
management programs and the expected
levels of effectiveness in achieving
integrated resource planning objectives
were derived.
(3) The expected annual effects of program
implementation on the utility and its
system, the ratepayers, the environment,
public health and safety, cultural
interests, the state economy, and society
in general.
c. The program implementation schedule shall also
be accompanied by the utility's proposals on
cost and revenue less recovery and incentives,
as appropriate.
3. The utility shall submit its annual evaluation as
follows.
a. The utility shall include in its annual
evaluation, an assessment of the continuing
validity of the forecasts and a_sumptions upon
which its integrated resource plan and its
p gram implementation schedule were
fashioned.
b. The utility shall also include for each
program or phase of prooram included in the
program implementation schedule for the
immediately preceding year a comparison of:
(1) The expenditures anticipated to be made
and the expenditures actually made, by
cost cateoories and ccst elements.
(2) The level of achievement of objectives
anticipated and *_he level actually
attained.
11
(3) The target group size or level of
penetration anticipated for each demand-
side management program and the size or
level actually realized.
(4) The effects of program implementation
anticipated and the effects actually
experienced.
c. The utility shall provide an assessment of all
substantial differences between original
estimates and actual experience and of what
the actual experience portends for the future.
d. Together with its annual evaluation, the
utility shall submit a revised program
implementation plan t:;at drops the immediately
preceding year from the schedule and includes
a new year. The procram implementation plan
must always reflect a five-year time span.
4. The utility may at any time, as a result of its
annual evaluation or change in conditions,
circumstances, or assumptions, revise or amend its
integrated resource plan or its program
implementation schedule. All revisions and
amendments must conform to the appropriate
requirements of this part D.
5. The integrated resource plan and program
implementation schedule approved by the commission
shall govern all utility expenditures for capital
proiects, purchased power, and demand-side
management programs. Notwithstanding approval of
an integrated resource plan: (a) an expenditure for
any capital project in excess of $500,000 shall be
submitted to the ccmmi=_sion for review as provided
in paragraph 2.3.g.2 of General Order No. 7; and
(b) no obligation under any purchased power
contract shall be undeztaken and no expenditure for
any specific demand-side .management program
included in an integrated resource plan or a
program implementation schedule shall be made
without prior commission approval. All power
purchases from qualifying facilities and
independent power producer=_ shall be subject to
statute and commission rules.
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E. Public Farticipation
To maximize public participaticn in each utility's
integrated resource planning process, opportunities for
such participation shall be provided through advisory
groups to the utility, public hearings, and interventions
in formal proceedings before the commission.
1. Advisory groups
a. The utility shall organize in each county in
which the utility provides service or conducts
utility business a group or groups of
representatives of public and private entities
to advise the utility in the development of
its integrated resource plan. A separate
advisory croup may be formed for each stage of
the planning process, as appropriate. The
utility shall chair each advisory group.
b. The public and private entities includable in
an advisory group are those that represent
interests that are affected by the utility's
integrated resource plan and that can provide
significant perspective or useful expertise in
the development of the plan. These entities
include state and county agencies and
envircnmental, cultural, business, and
community interest groups. An advisory group
should be representative of as broad a
spectrum of interests as possible, subject to
the limitation that the interests represented
should not be so numerous as to make
deliberations as a croup unwieldy.
c. The utility shall consider the input of each
advisory group; but the utility is not bound
to follow the advice of any advisory group.
d. All data reasonably necessary for an advisory
group to participate in the utility's
integrated resource planning process shall be
provided by the utility, subject to the need
to protect the confidentiality of
customer-specific and proprietary information.
e. The use by the advisory groups of the
collaborative process i=_ encouraged to arrive
at a consensus on issues.
13
f. All reasonable out-of-pocket costs incurred by
participants in advisory groups (other than
governmental agencies) shall be paid for by
the utility, subject to recovery as part of
the utility's cost of integrated resource
planning.
2. Public hearings
a. The utility is encouraged to conduct public
hearings or provide public forums at the
various, discrete phases of the planning
process for the purpose of securing the input
of those members of the public who are not
represented by entities constituting advisory
groups.
b. Upon the filing of requests for approval of an
integrated resource plan or projects, the
commission may, and it shall where required by
statute, conduct public hearings for the
purpose of securing public input on the
utility's proposal. The commission may also
conduct such informal public meetings as it
deems advisable.
3. Intervention
a. Upon the filing of its integrated resource
plan, the utility shall cause to be published
in a newspaper of general circulation in the
State a notice informing the general public
that the utility has filed its proposed
integrated re=_ource plan with the commission
for the commission's approval.
b. To encourage public awareness of the filing of
a proposed utility plan, a copy of the
proposed plan and the supporting analysis
shall be available for public review at the
commission's office and at the office of the
commission's representative in the county
serviced by the utility. In the case of Maui
Electric Company, Limited, the utility shall
also make a copy of its proposed plan and the
supporting analysis available at a public
library on each of the islands of Molokai and
Lanai. Zn the case of Hawaii Electric Light
Company, Inc., the utility shall also make a
copy of its proposed plan and the supporting
1S
analysis available at a public library in
Kona. Each utility shall note the
availability of the documents for public
review at these locations in its published
notice. The utility s'r,all make copies of the
executive summary of the plan and the analysis
available to the general public at no cost,
except the cost of duplication.
c. Applications to intervene or to participate
without intervention in any proceeding in
which a utility seeks commission approval of
its integrated resource plan are subiect to
the rules prescribed in part IV of the
commission's General Order No. 1 (Practice and
Procedure before the Public Utilities
Cemmission); except that such applications may
be filed with the ccmmission not later than
20 days after the publication by the utility
of a notice informing the general public of
the filing of the utility's application for
commission approval of its integrated resource
plan, notwithstanding the opening of the
docket before such publication.
d. r. person's status as an intervenor or
participant shall continue through the life of
the docket, unless the person voluntarily
withdraws or is dismissed as an intervenor or
participant by the commission for
cause.
4. Intervenor funding
a. upon the issuance of the commission's final
order on a utility's integrated resource plan
or any amendment to the plan, the commission
may grant an intervener or participant (other
than a governmental agency, a for-profit
entity, and an association of for-profit
entities) recovery cf all or part of the
intervenor's or participant's direct
out-of-pocket tests reasonably and necessarily
incurred in intervention or participation.
Any recovery and the amount of such recovery
are in the sole di=_cretion of the commission.
15
b. To be eligible for such recovery:
(1) The intervenor or participant must show a
need for financial assistance;
(2) The intervenor or participant must
demonstrate that it has made reasonable
efforts to secure funding elsewhere,
without success;
(3) The intervenor or participant must
maintain accurate and meaningful books of
account on the expenditures incurred; and
(4) The commi=_sion must find that the
intervenor or participant made a
substantial contribution in assisting the
commission in arriving at its decision.
c. The intervenor's or participant's books of
account are subject to audit, and the
commission ray impose other requirements in
any specific case.
d. Such allowance may be made only upon the
application of the intervenor or participant
within 20 days after the issuance of the
commission's final order, together with
justificaticn and documented proof of the
costs incurred.
e. The costs of intervener funding shall be paid
for by the utility, subject to recovery as
part of its costs of integrated resource
planning.
F. Cost Recovery and Incentives
1. The utility is entitled to recover its integrated
resource planning and implementation costs that are
reasonably incurred, including the costs of
planning and implementing pilot and full-scale
demand-side management programs.
a. The ccst recovery r,~ay be had through the
following mechanisms:
16
(1) Base rate recovery--the inclusion of
costs in the utility's base rate during
each rate case. A balancing account may
be appropriate in this instance to
reconcile, with interest, c:he ut.i.lity's
recovered expenditures with its actual
expenditures. It may also be appropriate
to consider the utility's under-
expenditure of authorized cost to limit
recovery, unless program objectives are
met or exceeded.
(2) Adjustment clause--the recovery of costs
incurred between rate cases in excess of
the baseline integrated resource
planning-related costs that are included
in the utility's base rates.
(3) Fatebasinq--the inclusion of costs that
are capital in character (i.e.,
expenditures considered to produce
long-term savings or benefits, such as
appliance rebates, loans, etc.), with
accumulated AFUDC, in the utility's rate
base at its next rate case. The costs
are to be amortized over a period set by
the commission.
(4) Escrow accounting--the accumulation, with
interest, of costs, not capital in
character, incurred between rate cases
and not otherwise recovered through the
utility's base rates, adjustment clause,
or rate base, in a deferred account, to
be amortized over a period set by the
commission.
b. The commission will determine the appropriate
mechanism for the recovery of ccsts associated
with demand-side management programs when
specific demand-side management programs are
submitted for commission approval. Cost
recovery for other integrated resource
programs generally will be addressed in each
utility's rate case.
2. tinder appropriate circumstances, the utility may
recover the net less in revenues sustained by the
utility as a result of successful implementation of
17
full-scale demand-side management programs
sponsored or instituted by the utility.
a. The net revenue less is the revenue lost less
the variable fuel and operating expenses saved
by the utility as a result of not having to
generate the unsold energy.
b. The commission will determine whether the
utility will be permitted to recover the net
revenues lost as a result of successful
implementation of a full-scale demand-side
management program and the form of the
recovery mechanism. The determination will be
made when an application is filed for approval
of the demand-side management program.
3. Under appropriate circumstances, the commission may
provide the utility with incentives to encourage
participation in and promotion of full-scale
demand-=_ide management programs.
a. The incentives may take any form approved by
the commission. Among the possible forms are:
(1) Granting the utility a percentage share
of the gross or net benefits attributable
to demand-side management programs
(shared savings).
(2) Granting the utility a percentage of
certain specific expenditures it makes in
demand-side r.,anagement programs (mark-
up).
(3) Allowing the utility to earn a greater
than normal return on equity for
ratebased demand-side management
expenditures (rate base bonus).
(4) Adjusting the utility's overall return on
equity in response to quantitative or
qualitative evaluation of demand-side
management program performance (e.g.,
adjusting the return upward for achieving
a certain level of kilowatt or
kilowatt-hour savings) (ROE adjustment).
18
b. The commission will determine whether the
utility will be provided with incentives and
the form of such incentives, if any, when
specific demand-side management programs are
submitted for approval. The utility r..ay
propose incentive forms for a particular
program, based on the particular attributes of
the program and the results to be attained.
c. The commission may terminate any and all
incentives whenever circumstances or
conditions warrant such termination.
ZV. Planning Considerations
A. Forecast
1. The utility shall develop a range of forecasts of
the amount of energy consumers will need over the
planning horizon. It shall develop forecasts for
multiple scenarios that are necessary or
appropriate in the development of its integrated
resource plan. Among the scenarios are the base
case scenario (a scenario based on the most likely
assumptions), a high-growth scenario, and a
low-growth scenario.
2. Each forecast shall identify the significant demand
and use determinants; describe the data, the
sources of the data, the assumptions (including
assumptions about fuel prices, energy prices,
economic conditions, demographics, population
growth, technological improvements, and end-use),
and the analysis upon which the forecast is based;
indicate the relative sensitivity of the forecast
result to changes in assumptions and varying
conditions; and describe the procedures,
methodologies, and models used in the forecast,
together with the rationale underlying the use of
such procedure=_, methodologies, and models.
3. Amonq the data to be considered are historical data
on energy sale=_, peak demand, system load factor,
system peaks, and such other data of sufficient
duration to provide a reasonable basis for the
utility's estimates of future demand.
4. As feasible and appropriate, the forecast shall be
by the system as a whole and by customer classes.
19
5. The utility shall use all reasonable mer.hodologies
in forecasting, including, as practicable and
economically feasible, the disaggreaated end-use
methodology.
B. Objectives
1. The ultimate objective of a utility's integrated
resource plan is meeting the energy needs of the
utility's customers over the ensuing 20 years.
2. The utility may specify any other utility-specific
objective that it seeks to achieve through its
integrated resource plan. For example, given the
parameter of the State acal of less dependence on
imported oil, the utility may set as an objective
the achievement of lowering to a specified level
the use of imported oil.
3. The commission may =_pecify other objectives for the
utility. Such specifications, if any, shall be
included in the order opening a docket for
integrated resource planning at the commencement of
each planning cycle-
C. Effectiveness Measures
1. The utility shall specify the measures by which
attainment of the objective or objectives is to be
determined.
2. Where direct, quantifiable measures are not
available, the utility may utilize proxy measures.
D. Resource Options
1. In the development of its integrated resource plan,
the utility shall con=_ider all feasible supply-side
and demand-side resource options appropriate to
Y.awaii and available within the years encompassed
by the integrated resource planning horizon to meet
the stated objectives.
2. The utility shall include among the options the
supply-side and demand-side resources or mixes of
options currently in use, promoted, planned, or
programmed for imp]ementation by the utility.
20
Supply-side and demand-side resource options
include those resources that are or may be supplied
by persons other than the utility.
3. The utility shall initially identify all cussible
supply-side and demand-side resource options. The
utility may, upon review, screen out those options
that are clearly infeasible. An option may be
deemed infeasible where the option's life cycle
costs clearly outweigh its benefits or
effectiveness under both societal cost-benefit and
utility cost-benefit assessments. The utility,
with the advice of the advisory groups, may
establish such other criteria for screening out
clearly infeasible options.
E. Data Collection
1. For each feasible resource option, the utility
shall determine its life cycle costs and benefits
and its potential level of achievement of
objectives. The utility shall identify the
option's total costs and benefits--the costs to the
utility and its ratepayers and the indirect,
including external (spillover), costs and benefits.
External costs and benefits include the cost and
benefit impact on the environment, people's
lifestyle and culture, and the State's economy.
2. To the extent helpful in analysis, the utility
shall distinguish between fixed costs and variable
costs and between sunk costs and incremental costs;
and the utility =hall identify any opportunity
costs.
3. The costs and benefits shall, to the extent
possible and feasible, be (a) quantified and
(b) expressed in dollar terms. when it is neither
possible nor feasible to quantify any cost or
benefit, such cost or benefit shall be
qualitatively measured. The methodology used in
quantifying or in qualitatively stating costs and
benefits shall be detailed.
21
F. Assumptions; Risks; Uncertaintie_
1. The utility shall identify the assumptions
underlying any resource option or the cost or
benefit of any option or any analysis performed.
2. The utility shall also identify the risks and
uncertainties associated with each resource option.
3. The utility shall further identify any
technological limitations, infrastructural
constraints, legal and governmental policy
requirements, and other constraints that impact on
any option or the utility's analysis.
G. Models
1. The utility may utilize any reasonable model or
models in comparing resource options and otherwise
in analyzing the relative values of the various
options or combinations of options.
2. Each model used must be fully described and
documented.
H. Analyses
1. The utility shall conduct cost-benefit and
cost-effectiveness analyses to compare and weigh
the various options and various alternative mixes
of options. Alternative mixes of options include
variously integrated supply-side and demand-side
management programs.
2. The utility shall conduct such analyses from
varying perspectives, including the utility cost
perspective, the ratepayer impact perspective, the
participant impact perspective, the total resource
cost perspective, and the societal cost
perspective.
3. The utility shall anal}~ze all options on a
consistent and comparable basis. It shall give the
costs, effectiveness, and benefits of demand-side
management options consideration equal to that
given to the costs, effectiveness, and benefits of
supply-side options. The utility may use any
reasonable and appropriate means to assure that
such equal consideration is given.
22
4. The utility shall compare the cptions on the
present value basis. For this purpose, the utility
shall discount the estimated annual costs (and
benefits, as appropriate) at an appropriate rate.
The utility shall fully explain tr.e rationale: for
its choice of the discount rate.
5. The utility may rank, as appropriate, the various
options and mixes of options upon such reasonable
criterion as it may establish with the advice of
its advisory groups.
I. Resource Optimization
1. Based on its analyses, the utility shall select
those resource options or mix of resource options
that achieve that level of effectiveness or that
level of benefits specified in the objectives at
the least cost. The utility shall also identify
those resource options or mix of resource options
that achieve the highest level of effectiveness or
level of benefits at various levels of cost.
a. The options or mix of options shall be
selected in a fashion as to achieve an
integration of supply-side and demand-side
options.
b. The selection of options or mix of options
constitutes the utility's integrated resource
plan.
2. The utility shall develop a number of alternative
plans, each repre_enting optimization from a
differing perspective, including the perspective of
the utility, the ratepayers, the non-participant,
and society. It shall also develop alternate plans
to meet the needs identified by each demand
forecast scenario.
3. For each plan, the utility shall identify the
revenue requirements on a present value and annual
basis. It shall note the risks and uncertainties
associated with the plan. It shall also describe
the plan's impact on rates, customer energy use,
customer bills, and the utility system. It shall
also describe the plan's impact on external
elements--the environment, people's lifestyle and
23
culture, the State's economy, and srciety in
general.
4. The utility shall rank the various plans, based on
such criterion as it may establish with th=~ e;ivice
of its advisory croups. The utility shall
designate one of these plans as its preferred plan
and submit to the commission the preferred plan as
its integrated resource plan.
J. Sensitivity Analysis
The utility shall subject its selection of resource
options to sensitivity analysis by altering assumptions
and other parameters.
V. Pilot Demand-Side Management Programs
A. Purposes
1. A purpose of piloting demand-side management
programs is to ascertain whether a giver. program,
not yet proven in Hawaii, is cost-effective--
whether it will have the penetration and will
achieve accomplishment of the utility's objectives
as originally believed.
2. A second purpose of piloting demand-side management
programs is to determine whether the program design
and configuration (including how it is managed and
promoted) are such as to permit implementation of
the program as efficiently and effectively as
desired.
B. Utility Pilot Programs
1. A utility may implement on a full-scale basis
(without pilot testing) any demand-side management
program that has been proven cost effective as a
result of a full-scale or pilot implementation of
the program in another comparable utility service
territory or as a result of pilot testing by a
utility in Hawaii. In all other cases, the utility
shall pilot test a demand-side management program
before implementing it on a full-scale basis.
2S
2. Each utility shall develop appropriate pilot
demand-side management programs for implementation
without awaiting commission approval of its initial
integrated resource plan. For each program, the
utility shall clearly articulate the parameters of
the program, the objectives to be attained by the
program, the expected level of achievement of the
objectives, the measures by which the attainment of
the objectives is to be assessed, the data to be
gathered to assist in the evaluation of the pilot
program, and the expenditure it proposes to make by
appropriate ccst components.
3. All proposed pilot demand-side management programs
are subject to commission approval.
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25
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E J Ma. GX AMrta Ere CaKemlbnAre OBEOT% Xhdln6ke D'n%bn %AwY5aed 01018 Hb %T10 9]]-0]12 9]J-0]1J
E J Mr. Go i Tom Ere LaciYlaY 1185Abka Pkm Mib %]20 ~ 0% %9d%J BOB %1E020
E Mr. HocYer Lpn V'rs Prasbed OnW Com talon 25 HN SOeH Hb %120 9]5-03% %16210
J SW alNanai.rPWb UMtiea -
E J Me. Leila bM PUC Dbu'va Re ®raaB.e fnmmkabn 6%KYmb 50ee1 Hb %]2p B)NS]J e)HSJd
urbn0 KeMA PaM1. hWU}kn MalaBer,
Mr. Mhun B GererdM Pw GmtlelmM VenWe P.O ROa]0 Paba %))B mlz p3rpawal m WB BS562]] BOB 965 i25d _ Qd2, arF Nuwafmm
Colatl YNa atleMiq (%14530 Eark Am
E Or. HOkda1~ Fre0 Courcinan Hawn CO Loud 25A Sull02% Hb %]30 %16225 %16812 SMan)
E J Mr. Obn bas B' Ielartl Railo2d Apbn Gm 15BJ1 Leith Arane Paroa %TB' 965E09J 8655451
E / Ma. VanLam Cart) Gereral Ma Pram KOlb Plaza 111 E. PUSUko Slreel Hb %T20 mn. m
LOUiid HuaY CepL d Wdu
E Mt Y C 5 JdS KeFwnaoa Blieel Hb %IIO %1-0]%
11
2
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1 Beet Ca0a Ma 1LUdwrer $ensc Haws EbdnOl MLan be NELLONG c lei.mm %B41J1 %90t%
1 Mwre Paud Mnk~ffir N3PiEre Serv'Qa Hias Etlmc plGpll Yc HELC0.NLR %841]6 _ _ %BOI]5 _
1 M adwe Tamm AOmin AiOe Comer Berieos Hawal Ebmk ' dCwn Yc HELLDMCB Mi m %90118 ~ %BOt15 _
1 Sao 5@ren P E r NP XawwnEYanc Lx WA}YP 800 54})981 0% 51})518
1 Bomei Wifam VP GOrommeNOCamm Mai6 Maraim EkOh Yc N54]V B%511.60i _
1 Nupio G pFeCbr Iqp Haaaian EkpR Io, Wp1YP 809 N1776] BOB 51}]518
1 Ltt WanGn PresMed Hawes Ekdril'MLdn bG HELC0.SP 9680121 %901%
1 Foffir BeNna V'2 Prezwd GbONE Pacers ]]SW AYMnaN SVeeI KaNUKOw %)10q 009122-3111 BM 6165429
1 J Ma r DiM~ipulbn Hawdi EkprbL MCom Yc HELCONW %94121 %90303
22