EXHIBIT LIST FOR Exhibits€¦ · Manitoba Hydro cover letter dated June 21, 2017 re General Rate...

MANITOBA HYDRO (MH) Exhibits

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MH‐9

Manitoba Hydro cover letter dated May 26, 2017 re General Rate

Application

Manitoba Hydro Written Submission on Interim Rates dated June 20, 2017

EXHIBIT LIST FOR

MANITOBA HYDRO

2017/18 & 2018/19 General Rate Application

February 16, 2018

Manitoba Hydro letter to PUB re Timing of Electric GRA dated November

29, 2016


Application

Manitoba Hydro letter to PUB re Intentions in respect of 2017 Rate

Application(s) dated March 24, 2017

Manitoba Hydro letter to PUB re Minimum Filing Requirements & Scope of

the Upcoming General Rate Application


Application

Manitoba Hydro to PUB letter re August 1, 2017 Interim Rates dated June

2, 2017

Manitoba Hydro 2017/18 & 2018/19 General Rate Application

Manitoba Hydro cover letter dated June 21, 2017 re General Rate

Application MFRs

MH‐1

MH‐2

MH‐3

MH‐4

MH‐5

MH‐6

MH‐7

MH‐8

MH‐10

MH‐11 Manitoba Hydro cover letter dated June 23, 2017 re General Rate

Application

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MH‐19

MH‐14‐1

Transcript of Proceedings ‐ Business Operations, Capital and Asset

Management Technical Conference ‐ July 20, 2017

Manitoba Hydro's Comments on the Business Council's Budget Submission

Manitoba Hydro to PUB re Information Requests ‐ August 2, 2017

Presentation by Manitoba Hydro ‐ Business Operations, Capital and Asset

Management Technical Conference ‐ July 20, 2017

Revised Rate Schedules to be Effective August 1, 2017 ‐ Area & Roadway

Lighting (Outdoor Lighting) Light Emitting Diode (LED) Rates ‐ Letter dated

August 24, 2017

Manitoba Hydro ‐ Rate Schedules further to Order 80/17 ‐ August 1, 2017

Proof of Revenues based on 2017 Electric Load Forecast ‐ August 2, 2017

Manitoba Hydro to PUB re City of Winnipeg's Proposed Intervention ‐ letter

dated August 2, 2017

Manitoba Hydro's Comments on Proposed Intervener Budgets dated July

21, 2017

Cost of Service Model ‐ July 26, 2017 email

MH‐23

MH‐25

MH‐26

MH‐21

MH‐22

MH‐24

MH‐13

Manitoba Hydro cover letter dated June 30, 2017 re General Rate

Application

Manitoba Hydro letter dated July 11, 2017 re Updated Financial Forecast

Manitoba Hydro CSI Process Motion ‐ dated July 11, 2017

MH‐12

MH‐14

MH‐18

MH‐20

Manitoba Hydro Interim Rates August 1, 2017 Reply Submission ‐ July 19,

2017

Manitoba Hydro's response to the Coalition's request re Cost of Service

Model ‐ July 20, 2017 email from Counsel

MH‐16

MH‐17

CSI Process Submission Schematic

MH‐15

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Ex. # " " " " " " Summary and Discussion

Ex. # " " " " " " retainer letter for Assembly of

Manitoba Chiefs

Manitoba Hydro to PUB re Revised Information Requests ‐ September 21

2017

Manitoba Hydro to PUB re Independent Expert Consultants Scope of Work ‐

October 2, 2017

Manitoba Hydro CSI Motion ‐ Manitoba Hydro Reply to Intervenor

Submissions ‐ October 6, 2017

Manitoba Hydro to PUB re Round II Information Requests ‐ October 16,

2017

MH‐32

MH‐33

MH‐30

MH‐35

MH‐37

Letter from KA Shepherd of Manitoba Hydro re First Round Information

Requests ‐ September 5, 2017

Manitoba Hydro ‐ CSI Motion ‐ September 7, 2017

Manitoba Hydro to PUB re Remaining Minimum Filing Requirements ‐

September 7, 2017

Manitoba Hydro re Appendix 9.14 Report on Rate Design for the

Residential Class ‐ September 14, 2017

Manitoba Hydro to PUB re IEC Status and Scope ‐ September 18, 2017

MH‐38

MH‐39

MH‐39‐1

MH‐39‐2

Manitoba Hydro to PUB re Revised Round 1 Information Request ‐ October

24, 2017

Manitoba Hydro ‐ Request to Review and Vary Order 112/17 ‐ October 30,

2017

Manitoba Hydro (MH) to AMC Information requests (1‐8)

MH‐36

MH‐34

Manitoba Hydro ‐ CSI Motion ‐ Round 1 Information Requests ‐ September

21 2017

MH‐31

MH‐27

MH‐28

MH‐29

Ex. # " " " " " " impact of .15 kWh and .70kWh

Ex. # " " " " " " MH Application conclusion Mipole III

developed

Ex. # " " " " " " export revenues

Ex. # " " " " " " Icome figures

Ex. # " " " " " " assistance for electricity costs social

assistance

Ex. # " " " " " " Qualifications on report

Ex. #

Ex. # " " " " " " Limitations of Methodology and

modeling

Ex. # " " " " " " Total Input Use

Ex. # " " " " " " Price elasticity of demand

Ex. # " " " " " " zero price elasticity of demand

Ex. # " " " " " " Total employment level

Ex. # " " " " " " Financial Forecast

Ex. # " " " " " " Retainer Letters of Dr. Simpson and

Dr. Compton

Ex. #

Ex. # " " " " " " Retainer letter for Mr. Harper

MH‐41

MH‐41‐1

MH‐40‐3

MH‐40‐4

MH‐40‐5

MH‐40‐6

Manitoba Hydro (MH) to Coalition (ECS) Information Requests

MH‐40‐7

MH‐39‐8

MH‐40‐1

MH‐40‐2

MH‐39‐3

MH‐39‐4

MH‐39‐5

MH‐39‐6

MH‐39‐7

MH‐40 Manitoba Hydro (MH) to Coalition (Compton/Simpson) Information

Requests

Ex. # " " " " " " CFO to CAP/EX ratio

Ex. # " " " " " " Retained earnings

Ex. # " " " " " " Comparative results

Ex. # " " " " " " IFF15 and IFF16

Ex. # " " " " " " DSM deferred asset account

Ex. # " " " " " " Regulatory costs associated with CEC

proceedigngs for Bipole III

Ex. # " " " " " " Total Assets with total number of

customers

Ex. # " " " " " " Regulatory Justifications

Ex. # " " " " " " avoided emission costs

Ex. # " " " " " " Rate Design proposal

Ex. # " " " " " " Assistance from Social Assistance

Ex. # " " " " " " Low‐income assistance funded by all

ratepayers

Ex. # " " " " " " Lost Revenue and Recovery base

Ex. # " " " " " " Zone of reasonableness

Ex. # " " " " " " Ratemaking objectives

Ex. #

Ex. # " " " " " " Stategic asset management system

MH‐42

MH‐41‐8

MH‐41‐9

MH‐41‐10

Manitoba Hydro (MH) to Coalition (METSCO) Information Requests

MH‐41‐2

MH‐41‐3

MH‐41‐4

MH‐41‐5

MH‐41‐6

MH‐41‐11

MH‐41‐12

MH‐41‐13

MH‐41‐14

MH‐41‐15

MH‐41‐7

MH‐41‐16

MH‐42‐1

Ex. # " " " " " " Asset Management plan

Ex. # " " " " " " Regulatory Model

Ex. # " " " " " " oversight recommendations

Ex. # " " " " " " Duties and METSCO retainer letter

Ex. #

Ex. # " " " " " " Identifying energy poor

Ex. # " " " " " " Efficient rate assistance program

Ex. # " " " " " " Efficient Rate Assistance Program

funding

Ex. # " " " " " " Qualifications and Duties for Dr.

Simpson

Ex. #

Ex. # " " " " " " Capital Markets on other financial

metrics

Ex. # " " " " " " Meaning of Costs to MPA

Ex. # " " " " " " Minimize Rate Costs for domestic

customers

Ex. # " " " " " " Debt levels and consequent interest

costs

MH‐44

Manitoba Hydro (MH) to Coalition (Simpson) Information Requests

Manitoba Hydro (MH) to Coalition (MPA) Information Requests

MH‐43

MH‐44‐1

MH‐44‐2

MH‐44‐3

MH‐44‐4

MH‐42‐2

MH‐42‐3

MH‐42‐4

MH‐42‐5

MH‐43‐1

MH‐43‐2

MH‐43‐3

MH‐43‐4

Ex. # " " " " " " Fluctuations

Ex. # " " " " " " Financial Markets

Ex. # " " " " " " Level Rate Increase

Ex. # " " " " " " Financial Distress

Ex. # " " " " " " Financial Metrics

Ex. # " " " " " " Interest Rates declining impact on net

income

Ex. # " " " " " " Cash flow sufficiency

Ex. # " " " " " " Cash Flow Metrics

Ex. # " " " " " " After Keeyask, Cash flow contribution

Ex. # " " " " " " Capital Investors

Ex. # " " " " " " Revenue Requirement formula

Ex. # " " " " " " Financial Reserves

Ex. # " " " " " " Individual peer utilities to their

business model

Ex. # " " " " " " Regulatory Risk

Ex. # " " " " " " Interest Coverage

Ex. # " " " " " " Discount Rates

Ex. # " " " " " " Debt Service Costs

MH‐44‐5

MH‐44‐6

MH‐44‐7

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MH‐44‐13

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MH‐44‐15

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MH‐44‐17

MH‐44‐18

MH‐44‐19

MH‐44‐20

MH‐44‐21

Ex. # " " " " " " Ratepayers contributions

Ex. # " " " " " " Rate‐making Policy

Ex. # " " " " " " Summary Observations contributors

Ex. # " " " " " " Retainer Letters for contributors

Ex. #

Ex. # " " " " " " Retainer letter for Mr. Chernick

Ex. # " " " " " " Order 112/17

Ex. # " " " " " " Rate Design

Ex. # " " " " " " Marginal Costs

Ex. # " " " " " " Marginal distribution costs by class

Ex. # " " " " " " Rate Proposals

Ex. # " " " " " " Excel Calculations

Ex. # " " " " " " LICO 125 customers

Ex. # " " " " " " kWH table figures

Ex. # " " " " " " Rate Proposals

Ex. #

Ex. # " " " " " " Key Findings

Manitoba Hydro (MH) to Green Action Centre (GAC) Information

Requests

MH to GSS/GSM‐KAP Information RequestMH‐46

MH‐44‐22

MH‐44‐23

MH‐44‐24

MH‐44‐25

MH‐45‐1

MH‐45

MH‐45‐2

MH‐45‐3

MH‐45‐4

MH‐45‐5

MH‐45‐6

MH‐45‐7

MH‐45‐8

MH‐45‐9

MH‐45‐10

MH‐46‐1

Ex. # " " " " " " Keystone Agricultureal Producers

(KAP)

Ex. # " " " " " " Average Commercial Rate

Ex. # " " " " " " Rate Increase for jurisdictions

Ex. # " " " " " " Gross Farm Expenditures

Ex. # " " " " " " Declining average operating profit

Ex. # " " " " " " Graph with non zeoro origin

Ex. # " " " " " " US NACS and gas station

Ex. # " " " " " " Smith Travel Research

Ex. # " " " " " " London Economics Report

Ex. # " " " " " " Key Performance Indicators

Ex. # " " " " " " Performance Indicators

Ex. #

Ex. # " " " " " " Retainer of Mr. Bowman

Ex. # " " " " " " Conclussion and Recommendation

Ex. # " " " " " " Actual 1962‐Forecast 2017‐2036 rates

compared to CPI

Ex. # " " " " " " price changes per province

Ex. # " " " " " " Capital Resource Plan

MH to MIPUG (Bowman) 1‐24 Information RequestsMH‐47

MH‐46‐2

MH‐46‐3

MH‐46‐4

MH‐46‐5

MH‐46‐6

MH‐46‐7

MH‐46‐8

MH‐46‐9

MH‐46‐10

MH‐46‐11

MH‐46‐12

MH‐47‐1

MH‐47‐2

MH‐47‐3

MH‐47‐4

MH‐47‐5

Ex. # " " " " " " Investment requirements

Ex. # " " " " " " Hydroelectric project

Ex. # " " " " " " Low Power Pricing

Ex. # " " " " " " Capital Market experience

Ex. # " " " " " " Substantial Reserve

Ex. # " " " " " " Full Net Income

Ex. # " " " " " " Self Sufficiency

Ex. # " " " " " " BCG's views

Ex. # " " " " " " Load Forecast for Gross Firm Energy

Ex. # " " " " " " Interim Hearing

Ex. # " " " " " " Forecast net Debt

Ex. # " " " " " " Net cost to ratepayers

Ex. # " " " " " " O&A costs in current filing

Ex. # " " " " " " ASL method

Ex. # " " " " " " Building Moves and Safety Watches

Ex. # " " " " " " Industrial & Commercial Solutions

Ex. # " " " " " " calculations supporting Figure A‐6

MH‐47‐6

MH‐47‐7

MH‐47‐8

MH‐47‐9

MH‐47‐10

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MH‐47‐14

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MH‐47‐21

MH‐47‐22

Ex. # " " " " " " Figure A‐7

Ex. # " " " " " " Table A‐2

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Ex. # " " " " " " Cv's , retainers, and job descriptions

Ex. # " " " " " " Policy goals in realtion to rates

Ex. # " " " " " " year to year percentage rate changes

Ex. # " " " " " " Maximum Debt

Ex. # " " " " " " Behind the scene contributions

Ex. #

Ex. #

Ex. # " " " " " " Mr. Markowsky's CV and Job

description

Ex. # " " " " " " Price elasticity in direct electricity

costs

Ex. # " " " " " " Past Electricity price increase

Ex. # " " " " " " Direct Electricity Billings chart

Ex. # " " " " " " Indirect Electricity Billing Chart

Ex. # " " " " " " Electricity tax revenue

MH to MIPUG (Osler/Forrest) 1‐5 Information Requests

MH to PUB revised MFR

Manitoba Hydro to City of Winnipeg Information Requests

MH‐48‐5

MH‐48

MH‐50‐1

MH‐50

MH‐47‐23

MH‐47‐24

MH‐48‐1

MH‐48‐2

MH‐48‐3

MH‐48‐4

MH‐49

MH‐50‐2

MH‐50‐3

MH‐50‐4

MH‐50‐5

MH‐50‐6

Ex. # " " " " " " Unsustainable structural deficit

Ex. # " " " " " " Conference Board of Canada's

Metroplitian Outlook

Ex. # " " " " " " Financial Target review

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. # " " " " " " electiricty price elasticity

Ex. # " " " " " " third party priticiate or assitante in

report

Ex. # " " " " " " Scope of Work ‐ retainer documents

Ex. # " " " " " " price elasticity impact on electricity

demand

Ex. # " " " " " " degree price response be attenuated

given MB lower electricity prices

Ex. #

Ex. # " " " " " " consdiered reports in preparation of

Export Pricing Revenue

Ex. # " " " " " " Expencted New Generation Over next

20 years

Manitoba Hydro to Daymark (Export) ‐ Information Requests

Manitoba Hydro ‐ CSI Motion ‐ Round 2 Information Request ‐ November

21, 2017

Manitoba Hydro Rebuttal Evidence ‐ November 22, 2017

Manitoba Hydro letter to PUB re: BCM Budget Variance ‐ November 24,

2017

Manitoba Hydro letter to PUB re: IR of IEC ‐ November 24, 2017

Manitoba Hydro to Dr. Yatchew ‐ Information Requests

MH‐51

MH‐52

MH‐53

MH‐54

MH‐55

MH‐56

MH‐55‐1

MH‐55‐2

MH‐55‐3

MH‐55‐4

MH‐55‐5

MH‐50‐7

MH‐50‐8

MH‐50‐9

MH‐56‐1

MH‐56‐2

Ex. # " " " " " " Retire,emt Assumptions by zone by

2031

Ex. # " " " " " " MTEP Report Book 3, MVP Portfolio

Ex. # " " " " " " Assumed reitrements in MTEP17

Ex. # " " " " " " Statewide RPS renewable Retail Sales

Ex. # " " " " " " NSP applies to North Dakota, separate

North States Power

Ex. # " " " " " " Planning Resource Aution

Ex. # " " " " " " 24 GW resources by 2031

Ex. # " " " " " " Page 50 ‐ CSI

Ex. # " " " " " " probability based forecasting superior

to scenario based forecasting

Ex. # " " " " " " reasonableness definition

Ex. # " " " " " " third party forecasters, P50 P‐value

Ex. # " " " " " " Reference cast forecast to be a P50

case

Ex. # " " " " " " Electricty price foreacst

Ex. # " " " " " " documents in regards to retainer

Ex. # " " " " " " Export Pricing and Revenus Report

authors

Ex. #

Ex. # " " " " " " forecast probability of being acurate

50%

MH‐57

MH‐56‐3

MH‐56‐4

MH‐56‐5

MH‐56‐6

MH‐56‐7

MH‐56‐8

MH‐56‐9

MH‐56‐10

MH‐56‐11

MH‐56‐12

MH‐56‐13

MH‐56‐14

MH‐56‐15

MH‐56‐16

MH‐56‐17

Manitoba Hydro‐Daymark (Load Forcast) ‐ Information Requests

MH‐57‐1

Ex. # " " " " " " forecasting approaches would be

considered loading edge

Ex. # " " " " " " base forecast

Ex. # " " " " " " Electric Load drecese due to natural

gas

Ex. # " " " " " " developing alternative futures

Ex. # " " " " " " suggested price elasticty valyes

incorrectly estimated

Ex. # " " " " " " 2011, 2014, 2015, 2016 Forecast

Values

Ex. # " " " " " " electric price assumption

Ex. # " " " " " " annual HDDs lower than normal HDD

Ex. # " " " " " " Popukation statistics/ population

forecast

Ex. # " " " " " " Key Summary Findings

Ex. # " " " " " " Scope of Work

Ex. # " " " " " " price of elasticity impact on electracity

demands

Ex. #

Ex. #

Ex. # " " " " " " CV Shepherd Kelvin

Ex. # " " " " " " CV McCallum Jamie

Ex. #

MH‐58

MH‐59

MH‐60

MH‐57‐13

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MH‐57‐5

MH‐57‐6

MH‐57‐7

MH‐57‐8

MH‐57‐9

MH‐57‐10

MH‐57‐11

MH‐57‐12

MH‐57‐2

MH‐57‐3

Manitoba Hydro ‐ Policy Panel

Manitoba Hydro letter to PUB Response to Order 120‐17 ‐ November 28,

2017

MH‐59‐1

MH‐59‐2

Manitoba Hydro ‐ Requirement Panel

Ex. # " " " " " " CV Bauerlein Sandy

Ex. # " " " " " " CV Carriere Liz

Ex. # " " " " " " CV Cormie David

Ex. # " " " " " " CV Miles Terry

Ex. # " " " " " " CV Morrison Lois

Ex. # " " " " " " CV Neufeld Gerald

Ex. # " " " " " " CV Steele Chuck

Ex. # " " " " " " CV Stephen Susan

Ex. # " " " " " " CV Swatek David

Ex. # " " " " " " CV Turner Hal

Ex. # " " " " " " CV Wortley Joel

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MH‐63

MH‐64

MH‐65

Opening Statement

Opening Presentation

Manitoba Hydro's Top 10 Irs

Manitoba Hydro letter to PUB re Response to letter of November 30, 2017 ‐

December 4, 2017

Quarterly Report Cover Letter ‐ November 16‐17, 2017MH‐62

MH letter to PUB re Manitoba Hydro Electic Board Report ‐ November 28,

2017 (CSI DOCUMENTS)

MH‐60‐7

MH‐60‐8

MH‐60‐9

MH‐60‐10

MH‐60‐3

MH‐60‐4

MH‐60‐5

MH‐60‐6

MH‐61

MH‐60‐11

MH‐60‐1

MH‐60‐2

MH‐66

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"

Page 29‐1 of Revenue Requirement

Presentation

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"

CV of Greg Barnlund

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"

CV of Paul Chard

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"

CV of Colleen Galbraith

Ex. # " " " " " " " " "

"

CV of Greg Mason

Ex. #

MH‐72

MH‐73

MH‐74

MH‐69

MH‐70

MH‐68

MH‐71

MH‐75

MH‐76

MH‐77

MH‐78

MH‐77‐1

MH‐77‐2

MH‐77‐3

MH‐77‐4

Manitoba Hydro Undertaking 3 ‐ 2018 DBRS Canadian Provincial

Government Outlook Report

Manitoba Hyrdo Undertaking 1 ‐ IFF models to MH Electric Board

Supplement to PUB‐MH I‐56a‐c with Attachments

Manitoba Hydro Speaking Notes for Mr. Riley's Public Information Session

Presentation from October 2016

Manitoba Hydro Undertaking 2 ‐ IFF Models

Manitoba Hydro Undertaking from transcript page 507 ‐ Performance

Targets re: Colaition/MH I‐144

Manitoba Hydro Question from PUB Board‐ Cost of Heating with Carbon

Levy

Maniotba Hydro Question from PUB Board ‐ DSM Costs

Manitoba Hydro ‐ Cost of Service and Rate Design Panel

Manitoba Hydro Undertaking 5 ‐ Operating and Administravie Costs

Manitoba Hydro ‐ Revenue Requirements Presentation

MH‐68‐1

Manitoba Chambers of Commerce ‐ Our Plan to Restore Manitoba Hydro

and Protect Manitobans

MH‐67

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Ex. #

Ex. #

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Ex. # " " " " " " " " "

"

CV's from MGF Report

Ex. # " " " " " " " " "

"

Management Improvements on

Capital Expenditure

Ex. # " " " " " " " " "

"

Target Price Contract

MH‐92

MH‐79

MH‐80

MH‐81

MH‐82

MH‐83

MH‐86

MH‐87

MH‐88

Manitoba Hydro Undertaking 6 ‐ Updated PUB MFR 55 and MIPUG‐MH I‐

14b

Manitoab Hydro Undertaking 9 ‐ Updated Chart from MIPUG 23‐2 page 83

Maximum Net debt

Manitoba Hydro Undertaking 15 ‐ Avoided Infrastructure cost for

Gneration marginal value calculation

Manitoba Hydro Undertaking 19 ‐ change in methodology and why the

change was made

Manitoba Hydro ‐ MGF ‐ Information Requests

Manitoba Hydro Undertaking 10 ‐ 12 year WATM

Manitoba Hydro Undertaking 11 ‐ 20 year WATM

MH‐PUB Rebuttal Evidence re Daymark load and export Reports

Manitoba Hydro Undertaking 7 ‐ MH‐68 Slide 72

Manitoba Hydro Undertaking 8 ‐ 1990 on MH‐68 Slide 72

Manitoba Hydro Undertaking 12 ‐ IFF without payments to Government

Manitoba Hydro Undertaking 4 ‐ Provincial Equity Injection

Manitoba Hydro Cost of Service, Rate Design and Bill Affordability Panel

Presentation

Manitoba Hydro Undertaking 28 ‐ Appendix 3.8 updated with 3.36 %

interim, effective August 1, 2016

MH‐84

MH‐85

MH‐89

MH‐90

MH‐91

MH‐92‐1

MH‐92‐2

MH‐92‐3

Ex. # " " " " " " " " "

"

Project Schedule

Ex. # " " " " " " " " "

"

Labour Costs

Ex. # " " " " " " " " "

"

KCN and Local employment

Ex. # " " " " " " " " "

"

Cost Increases

Ex. # " " " " " " " " "

"

Increase to GCC ‐ quantities

Ex. # " " " " " " " " "

"

Keeyask Cost Estimate

Ex. # " " " " " " " " "

"

escalation calculations

Ex. # " " " " " " " " "

"

Project Execution Reporting and

Financial Reporting

Ex. # " " " " " " " " "

"

Governance

Ex. # " " " " " " " " "

"

Misaligened Estimates

Ex. # " " " " " " " " "

"

Trends from 2017 Basis of Estimate

Document

Ex. # " " " " " " " " "

"

Monitoring and Managing

Ex. # " " " " " " " " "

"

Work Breakdown Structure Summary

Ex. # " " " " " " " " "

"

Control Budget

Ex. # " " " " " " " " "

"

BBE Construction Drawings (IFC)

Ex. # " " " " " " " " "

"

410‐day magnitude

Ex. # " " " " " " " " "

"

work with BBC and Voith to align

schedules

MH‐92‐4

MH‐92‐5

MH‐92‐6

MH‐92‐7

MH‐92‐8

MH‐92‐9

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MH‐92‐11

MH‐92‐12

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MH‐92‐16

MH‐92‐17

MH‐92‐18

MH‐92‐19

MH‐92‐20

Ex. # " " " " " " " " "

"

Extra Work Orders

Ex. # " " " " " " " " "

"

Procurement of equipment of General

Civil Work Contractor

Ex. # " " " " " " " " "

"

craft to foreman ratio

Ex. # " " " " " " " " "

"

Keeyask Transmission Project

Ex. # " " " " " " " " "

"

Contingency

Ex. # " " " " " " " " "

"

Capital Review

Ex. # " " " " " " " " "

"

Correction to Response to MGF ‐

Keeyask

Ex. # " " " " " " " " "

"

survey of earthwork

Ex. # " " " " " " " " "

"

scaffold costs

Ex. # " " " " " " " " "

"

concretet productivity

Ex. # " " " " " " " " "

"

Productivity and lower cost

Ex. # " " " " " " " " "

"

Schedule of Cost

Ex. # " " " " " " " " "

"

internal labour costs budgeted beyond

project

Ex. # " " " " " " " " "

"

Bipole III Converter Station Porject

Controls Report

Ex. # " " " " " " " " "

"

Keewatinohk 230kV AV Switchyard

behind scheudle

Ex. # " " " " " " " " "

"

lump sum Variations

Ex. # " " " " " " " " "

"

P50 Coporate Standard

MH‐92‐21

MH‐92‐22

MH‐92‐23

MH‐92‐24

MH‐92‐25

MH‐92‐26

MH‐92‐27

MH‐92‐28

MH‐92‐29

MH‐92‐30

MH‐92‐31

MH‐92‐32

MH‐92‐33

MH‐92‐34

MH‐92‐35

MH‐92‐36

MH‐92‐37

Ex. # " " " " " " " " "

"

Stanley Constultants

Ex. # " " " " " " " " "

"

Rokstad Contact

Ex. # " " " " " " " " "

"

Distribution Line Crossing and

Transmission Line Contraction Yard

Ex. # " " " " " " " " "

"

Risk Regster

Ex. # " " " " " " " " "

"

Contracts listing

Ex. # " " " " " " " " "

"

variation log/summaries

Ex. # " " " " " " " " "

"

Rokstad Power completeion date

Ex. # " " " " " " " " "

"

Recovery Plan for Rokstad

Ex. # " " " " " " " " "

"

Basis of Estimate

Ex. # " " " " " " " " "

"

Industry Standard Project Cost

Ex. # " " " " " " " " "

"

Klohn Crippen Berger

Ex. # " " " " " " " " "

"

Hydroelectric power Projects in

Northern Canada

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Manitoba Hydro Follow‐up Undertaking Nos 7 & 8 ‐MH 68 Slide 72

Updated

Manitoba Hydro Undertaking 24 ‐2014 Residential Energy Survey

Manitoba Hydro Undertaking 16 ‐ Other Countries bill affordability

programs

Manitoba Hydro Undertaking 20 ‐ explanation why marginal values

changed under new methodology

Manitoba Hydro Undertaking 29 ‐ 10,000 payments to accounts of First

Nation customers receiving socail assistance

MH‐93

MH‐94

MH‐95

MH‐96

MH‐97

MH‐92‐38

MH‐92‐39

MH‐92‐40

MH‐92‐41

MH‐92‐49

MH‐92‐42

MH‐92‐43

MH‐92‐44

MH‐92‐45

MH‐92‐46

MH‐92‐47

MH‐92‐48

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. # " " " " " " " " "

"

MH‐92‐1

Ex. # " " " " " " " " "

"

MH‐92‐3

Ex. # " " " " " " " " "

"

MH‐92‐38

MH‐111‐1

MH‐111‐2

MH‐111‐3

Manitoba Hyro Undertakings 21‐23 ‐ Figure 7 of AMC/MH II‐23, LICO‐125 6

percent threshold

MH‐100

MH‐98

MH‐99

MH‐101

MH‐102

MH‐103

MH‐104

MH‐105

MH‐106

MH‐107

MH‐108

MH‐109

MH‐110

MH‐111

Manitoba Hydro Undertaking 17 ‐ Meter Maintenance Subfunctionalizing

distribution of poles, wires and substations

Manitoba Hydro Undertaking from transcript page 2396 ‐Updated Figure

8.14 (Tab 8)

Manitoba Hydro Undertaking 18 ‐ Performance Optimization Programs

Manitoba Hydro Undertaking 27 ‐20 year levelized marginal values

Manitoba Hydro Undertaking 14 ‐ Rate Increases for different jurisdictions

in Canada

Manitoba Hydro Projected Annual Residential Eletric Bills

Manitoba Hydro Undertaking 37 ‐ Updated of Slide 15 from MH 88

Manitoba Hydro letter to Public Utilies Board re Daymark Saskpower

Report redactions ‐ January 5, 2018

Maniotba Hydro letter to Public Utilities Board re Withdrawl of R & V on

Daymark Saskpower Report ‐ January 9, 2018

Manitoba Hydro Undertaking 32 ‐ Single Detached Homes Electricity Heat

on and off reserve

Manitoba Hydro Undertaking 38 ‐ Geothermal Program

Manitoba Hydro Undertaking 34 ‐ Actual Expenditures for 2016/17 year for

Load Displacement Program

MH to MGF (KCB) Information Requests

Ex. # " " " " " " " " "

"

MH‐92‐48

Ex. # " " " " " " " " "

"

MH‐92‐49

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. # " " " " " " " " "

"

CV of Lorne Midford

Ex. # " " " " " " " " "

"

CV of Glenn Penner

Ex. # " " " " " " " " "

"

CV of Dave Bowen

Ex. # " " " " " " " " "

"

CV of Jeff Strongman

Ex. # " " " " " " " " "

"

CV of Alastair Fogg

MH‐111‐4

MH‐111‐5

MH‐116‐1

MH‐116‐3

MH‐116‐4 Manitoba Hydro Book fo Documents 4 ‐ Cross Examination of MGF

Manitoba Hydro Book fo Documents 3 ‐ Cross Examination of London

Economics International

MH‐118‐5

MH‐117

MH‐118

MH‐118‐1

MH‐118‐2

MH‐118‐3

MH‐118‐4

MH‐116‐2 Manitoba Hydro Book of Documents 2 ‐ Cross Examination of MIPUG

MH‐112

MH‐113

MH‐114

MH‐115

Manitoba Hydro Undertaking 35 ‐ DSM Expenditures

Manitoba Hydro Undertaking 25 ‐ MKO First Nation Revenue

Manitoba Hydro Undertaking 26 ‐ MKO Revenue at 7.9% increase

Manitoba Hydro Undertaking 30 & 31 ‐ Geneneration Marginal Value

Manitoba Hydro Book of Documents for Cross Examination of Morrison

Park Advisors

Manitoba Hydro Rebuttal of MGF Evidence ‐ January 16, 2018

Manitoba Hydro ‐ Major Capital Projects Panel

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Terms of Reference for NFAT

Manitoba Hydro Letter to Public Utilities Board re MGF Report Redactions ‐

January 19, 2018

Manitoba Hydro ‐ Major Capital Projects Presentation

Manitoba Hydro ‐ Major Capital Projects Panel Presentation ‐ Confidential

Manitoba Hydro Undertaking 33 ‐ MH variatoin with respect to Order

116/08

Manitoba Hydro Undertaking 36 ‐ Projections for Load Displacement

Program

Manitoba Hydro Undertaking from Transcript page 3088 ‐ Status Update

from page 220 of Order 5/12

Manitoba Hydro Undertaking 54 ‐ Presentation of Dr. Swatek ‐ Needs for

Bipole III

Manitoba Hydro Undertaking 58 ‐ Estimated Costs of Bipole III

Manitoab Hydro Undertaking 59 ‐ Road Costs Attributed to Conawapa

MH‐131 Manitoba Hydro Undertaking 55 ‐ Manitoba Hydro Control Schedule

MH‐123

MH‐124

MH‐125

MH‐126

MH‐127

MH‐128

MH‐129

MH‐130

MH‐132

MH‐133

MH‐134

MH‐135

MH letter to all parties re Legal Argument ‐ January 29, 2018

MH letter to PUB re CSI in MFG Report and Rebuttal Evidence

Manitoba Hydro Undertaking from Transcript Page 2640 ‐ Solar and other

Non‐Utility Generation system credits

Manitoba Hydro Undertaking 56 ‐ payments to KPMG

MH‐119

MH‐120

MH‐121 CSI

MH‐122

Manitoba Hydro Undertaking 63 ‐ % of First Nations and Indigenous person

working on Keeyask

Manitoba Hydro Rebuttal Presentation

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

MH‐140‐1 Manitoba Hydro additional MH16 Update with Interim Scenarios with

Redacctions

MH‐137

MH‐138

MH‐139

MH‐140

MH‐135‐1 Morrison Park Advisors Analysis

MH‐141

MH‐142

MH‐136

Manitoba Hydro Reply Presentation

Manitoba Hydro Undertaking 57 ‐ Keeyask Termination Costs

Manitoba Hydro Oral Argument ‐ February 5, 2018

Manitoba Hydro Written Argument

Manitoba Hydro Undertaking 60 ‐ Most Recent Monthly Report

Manitoba Hydro Undertaking 53 ‐ Distance between Bipole I and Bipole II

Manitoba Hydro additional MH16 Update with Interim Scenarios

PUBLIC UTILITIES BOARD (PUB) Exhibits

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

EXHIBIT LIST FOR

MANITOBA HYDRO


February 16, 2018

PUB Letter to Manitoba Hydro dated March 17, 2017 re 2017 Rate

Applications

Order in Council 92/2017 dated April 5, 2017

PUB‐1

PUB‐2

PUB‐3

PUB‐4

PUB Rules of Practice and Procedure

PUB Letter to Manitoba Hydro and Interveners of Record dated April 24,

2017 re Intervener Proposed MFR & Additional PUB MFRs

PUB Cover Letter for Public Notice ‐ dated May 9, 2017

PUB Leter to Manitoba Hydro and Interveners of Record dated March 31,

2017 re Planning Meeting and Minimum Filing Requirements (MFRs)

PUB to MH and Interveners of Record re August 1, 2017 interim rate

request and GRA process matters dated May 17, 2017

PUB to all Parties re Process Matters dated May 26, 2017

PUB‐8

PUB‐10

PUB to MH re Revised Minimum Filing Requirements of the Public Utilities

Board dated May 23, 2017

PUB‐5

PUB‐6

PUB‐9

PUB‐7 PUB Public Notice ‐ Manitoba Hydro's rate application

PUB‐11

PUB‐12

PUB to Potential New Interveners re Process Matters dated May 26, 2017

PUB to All Parties re August 1 2017 Interim Rates dated June 9, 2017

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. # PUB to MH ‐ First Round Irs Updated MIPUG MFR 5, MH16

Ex. # " " " " " " Present value of proposed annualized

revenue increase requested

Ex. # " " " " " " Updated table ‐ PUB MFR12

Ex. # " " " " " " KMPG's update to the report based on

MH16 Update

Ex. # " " " " " " Update to BCG Report

Ex. # " " " " " " BCG Report ‐ Keeyask recovery plan

Ex. # " " " " " " Generation peak demand, generation

sources & capacities, and import

capacities for the summer and winter

season

Ex. # " " " " " " Affordable Utility Rate Accountability

Act

PUB‐19

PUB‐18 PUB Order No. 85/17 ‐ Order Approving Manitoba Hydro's Rate Filings for

August 1, 2017 Rates ‐ August 3, 2017

PUB Order No. 80/17 ‐ An Order in Respect of Manitoba Hydro's

Application for a 7.9% Interim Rate Increase Effective August 1, 2017 ‐ July

31, 2017

PUB‐19‐1

PUB‐19‐2

Public Utilities Board to Manitoba Hydro ‐ First Round Information

Requests

PUB‐19‐3

PUB‐19‐4

PUB‐19‐5

PUB‐19‐6

PUB‐19‐7

PUB‐19‐8

PUB‐13

PUB‐14

PUB‐15

PUB‐16

PUB‐17

PUB to all parties re Interim Rate Request Oral Hearing ‐ dated June 15,

2017

PUB Order 70/17 ‐ Procedural Order in Respect of Manitoba Hydro's

2017/18 and 2018/19 General Rate Application ‐ June 30, 2017

PUB Response to the Coalition's letter re Access to COS Model ‐ July 21,

2017

PUB Order No. 82/17 ‐ An Order in Respect of Manitoba Hydro's Process

Motion for Confidential and Commercially Sensitive Documents Requested

in Manitoba Hydro's 2017/18 & 2018/19 General Rate Application ‐ July 28,

2017

Ex. # " " " " " " 2016/17 Vacancy allowance and

assumed vacancy allowance for

2017/18 & 2018/19

Ex. # " " " " " " OM&A Expense Analysis

Ex. # " " " " " " EFT staffing level information (MFR

34) ‐ utlizing MH16 Update &

voluntary take‐up

Ex. # " " " " " " MFR 35 ‐ Utilizing MH16 update and

incorporating known voluntary take‐

up

Ex. # " " " " " " Position Reductions

Ex. # " " " " " " Operating & administrative costs by

cost elements

Ex. # " " " " " " Operating and administrative

expenses by division

Ex. # " " " " " " Capitalized OM&A costs by business

unit

Ex. # " " " " " " Operating and administrative costs

(MH16 vs MH15)

Ex. # " " " " " " Depreciation and Amortization

breakdown

Ex. # " " " " " " Water flow

Ex. # " " " " " " Deviations in the MH hydraulic energy

Ex. # " " " " " " Payments to Government for Keeyask

and Bipole III

Ex. # " " " " " " Treatment of costs incurred for

Conawapa GS

Ex. # " " " " " " Debt Management ‐ Free cash flow

Ex. # " " " " " " Capitalized Interest

PUB‐19‐20

PUB‐19‐21

PUB‐19‐22

PUB‐19‐23

PUB‐19‐24

PUB‐19‐9

PUB‐19‐19

PUB‐19‐10

PUB‐19‐11

PUB‐19‐12

PUB‐19‐13

PUB‐19‐14

PUB‐19‐15

PUB‐19‐16

PUB‐19‐17

PUB‐19‐18

Ex. # " " " " " " Updated PUB MFR 59 ‐ Financing

plans, weighted average of

outstanding debt, principal amount

and proportions of debt maturing

Ex. # " " " " " " Proforma basis for Bipole III ‐ cash

negative

Ex. # " " " " " " Interest Rate Forecasting

Ex. # " " " " " " Consolidated Borrowing

Requirements & Maturity Schedule

Ex. # " " " " " " Debt Maturities

Ex. # " " " " " " Benchmark GoC and Manitoba 10

Year+ Bond yields

Ex. # " " " " " " PUB MFR 52 Update

Ex. # " " " " " " PUB MFR 57 & 58 ‐ Debt Issuances

and corresponding interest rates

Ex. # " " " " " " Reconciliation of values used in the

determination of forecast financial

ratios with the values in the IFF

Ex. # " " " " " " Electric operations only‐IFF scenarios

Ex. # " " " " " " References to credit rating reports

Ex. # " " " " " " PUB MFR 51 ‐ exclusion of Bipole III‐

related capitalized interest from the

adjustment

Ex. # " " " " " " Utilities utilizing a CFO to CAPEX ratio

Ex. # " " " " " " Major New Generation and

Transmission projects in CFO to Capex

ratio

Ex. # " " " " " " Keeyask ‐ Capitalized interests

PUB‐19‐31

PUB‐19‐32

PUB‐19‐33

PUB‐19‐34

PUB‐19‐25

PUB‐19‐26

PUB‐19‐27

PUB‐19‐28

PUB‐19‐29

PUB‐19‐30

PUB‐19‐35

PUB‐19‐36

PUB‐19‐37

PUB‐19‐38

PUB‐19‐39

Ex. # " " " " " " KMPG recommended metrics

Ex. # " " " " " " Impact of provincial credit rating

downgrade to MH's borrowing costs

Ex. # " " " " " " Manitoba Hydro's capital structure

Ex. # " " " " " " Risks insured by third parties

Ex. # " " " " " " Bipole ‐ Infrastructure risk

Ex. # " " " " " " Key variable sensitivity impacts to

MH16 Retained earnings

Ex. # " " " " " " Updated Additional Interest Rate

Forecast Information

Ex. # " " " " " " Uncertainty analysis

Ex. # " " " " " " Financial Impact of Drought

Ex. # " " " " " " Composition of flow cases

Ex. # " " " " " " Dependable energy premiums and

capacity premium

Ex. # " " " " " " Export commitments

Ex. # " " " " " " Export sale contracts made with

American Electric Power, NextEra and

Basin Electric

Ex. # " " " " " " 2017 Load Forecast

Ex. # " " " " " " Potential Large Industrial Load

Ex. # " " " " " " 20 year IFF scenario ‐ Efficiency

Manitoba

Ex. # " " " " " " Load Forecast

PUB‐19‐46

PUB‐19‐47

PUB‐19‐48

PUB‐19‐49

PUB‐19‐50

PUB‐19‐51

PUB‐19‐40

PUB‐19‐41

PUB‐19‐42

PUB‐19‐52

PUB‐19‐53

PUB‐19‐54

PUB‐19‐55

PUB‐19‐56

PUB‐19‐43

PUB‐19‐44

PUB‐19‐45

Ex. # " " " " " " Forecasts accuracies

Ex. # " " " " " " Power Resource Plan

Ex. # " " " " " " Potential increase in interest rates &

borrowing costs if further credit rating

downgrades occurs

Ex. # " " " " " " Credit rating reports

Ex. # " " " " " " Communications between Manitoba

Hydro and credit rating agencies

Ex. # " " " " " " Progression of project costs

Ex. # " " " " " " Major capital G&T project for year

2008/09 to 2016/17

Ex. # " " " " " " Asset management technology

Ex. # " " " " " " Change in definition of Major New

Generation and Transmission

Ex. # " " " " " " Capital expenditure cost savings

Ex. # " " " " " " Corporate value framework

Ex. # " " " " " " Corporate risk standards, tolerance

levels and risk assessments

Ex. # " " " " " " Corporate risk

Ex. # " " " " " " Asset‐level risk assessment process

and process of assessing non‐

monetary risks

Ex. # " " " " " " UMS Group ‐ Asset Management Gap

Assessment Report ‐ addressing gaps

Ex. # " " " " " " Risk assessments ‐ aging electric

infrastructure

PUB‐19‐67

PUB‐19‐68

PUB‐19‐69

PUB‐19‐70

PUB‐19‐71

PUB‐19‐72

PUB‐19‐58

PUB‐19‐59

PUB‐19‐60

PUB‐19‐61

PUB‐19‐62

PUB‐19‐63

PUB‐19‐64

PUB‐19‐65

PUB‐19‐66

PUB‐19‐57

Ex. # " " " " " " Reputational risk

Ex. # " " " " " " Risk tolerance thresholds

Ex. # " " " " " " Manitoba Hydro Corporate Risk

Management Report

Ex. # " " " " " " Manitoba Hydro's Corporate Risk

Rating Criteria scale

Ex. # " " " " " " Impact of lower domestic load growth

Ex. # " " " " " " EFT staffing level information

Ex. # " " " " " " Target overtime levels

Ex. # " " " " " " Risk and cost replacement to inform

transformer refurbishment vs

replacement decisions

Ex. # " " " " " " HVDC Bipole III Valve Hall Wall

Bushing Replacement

Ex. # " " " " " " Sustaining and major capital

assessment

Ex. # " " " " " " Sustaining and major capital ‐

operational risk evaluation

Ex. # " " " " " " Capital Planning Model

Ex. # " " " " " " System assets and investments

Ex. # " " " " " " Asset Investment Process

Improvements ‐ roadmap

Ex. # " " " " " " Asset Health Indices

Ex. # " " " " " " System Average Interruption Duration

Index (SAIDI) and System Average

Interruption Frequency Index (SAIFI)

PUB‐19‐85

PUB‐19‐86

PUB‐19‐87

PUB‐19‐76

PUB‐19‐77

PUB‐19‐78

PUB‐19‐73

PUB‐19‐74

PUB‐19‐75

PUB‐19‐80

PUB‐19‐81

PUB‐19‐82

PUB‐19‐79

PUB‐19‐83

PUB‐19‐84

PUB‐19‐88

Ex. # " " " " " " Implementation plan re Table of

Concordance of Past Board Orders

related to Asset Management and

Asset Condition Assessments

Ex. # " " " " " " Asset Condition Assessment Audit by

Kinetrics


Kinetrics


Kinetrics


Kinetrics


Kinetrics ‐ Power Transformers


Kinetrics ‐ Power Transformers


Kinetrics ‐ Transmission Steel

Structures


Kinetrics ‐ Transmission Conductors


Kinetrics ‐ Data Availability


Kinetrics ‐ Projected Flagged for

Action Plan


Kinetrics ‐ Condition Based Flagged for

Action Plan

Ex. # " " " " " " Age Availability data for all assets

Ex. # " " " " " " Asset Condition Assessment ‐ Flagged

for Action

Ex. # " " " " " " Asset Condition Assessment ‐ Flagged

for Action

PUB‐19‐95

PUB‐19‐96

PUB‐19‐97

PUB‐19‐98

PUB‐19‐92

PUB‐19‐93

PUB‐19‐91

PUB‐19‐89

PUB‐19‐90

PUB‐19‐94

PUB‐19‐99

PUB‐19‐100

PUB‐19‐101

PUB‐19‐102

PUB‐19‐103

Ex. # " " " " " " Asset Condition Assessment ‐ Results

for Each Asset Category

Ex. # " " " " " " Asset Condition Assessment ‐ UG HV

Oil Cables

Ex. # " " " " " " Asset Condition Assessment ‐

Conclusions and Recommendations

Ex. # " " " " " " Asset Condition Assessment ‐ Age

Limiting Factor

Ex. # " " " " " " Asset Condition Assessment ‐ Station

Breakers

Ex. # " " " " " " HVDC Converter Station Assets

Ex. # " " " " " " Asset Condition Assessment Scoring &

Replacement Requirements

Ex. # " " " " " " Asset Condition Assessment Scoring &

Replacement Requirements

Ex. # " " " " " " Asset Condition Assessment ‐

projected footing replacements

Ex. # " " " " " " Asset Condition Assessment ‐ circuit

breakers

Ex. # " " " " " " Qualitative Condition Assessment

Report

Ex. # " " " " " " Manitoba Hydro Report for Slave Falls

G.S. Powerhouse Mechanical

Condition Assessment Report:

Turbines & Generators

Ex. # " " " " " " Manitoba Hydro Capital Project

Justification

Ex. # " " " " " " Electric Business Operational Capital

10 Year Forecast by Investment

Category

Ex. # " " " " " " Planning criteria ‐ capacity hot spots

PUB‐19‐104

PUB‐19‐105

PUB‐19‐106

PUB‐19‐107

PUB‐19‐108

PUB‐19‐109

PUB‐19‐110

PUB‐19‐111

PUB‐19‐112

PUB‐19‐113

PUB‐19‐114

PUB‐19‐115

PUB‐19‐116

PUB‐19‐117

PUB‐19‐118

Ex. # " " " " " " Capital Program budget

Ex. # " " " " " " Distribution wood pole replacements

Ex. # " " " " " " Skewing of typical useful life values

Ex. # " " " " " " Capital Investment Justifications (CIJ)

Ex. # " " " " " " Reduction of volitional capital

expenditures to mitigate the rate

impacts of Major Project costs

Ex. # " " " " " " Customer preferences

Ex. # " " " " " " 2014 Residential Energy Use Survey

(REUS)

Ex. # " " " " " " Affordable Energy Program Annual

Report

Ex. # " " " " " " DSM measures ‐ residential customers

Ex. # " " " " " " Dunsky Energy Consulting Reports

Ex. # " " " " " " Fuel Switching

Ex. # " " " " " " LED street lighting rates

Ex. # " " " " " " Marginal values ‐ Rate design & DSM

cost effectiveness evaluations

Ex. # " " " " " " Additional General Consumers

Revenue ‐ rate increase

Ex. # " " " " " " Calendar year hourly marginal cost

study

Ex. # " " " " " " Customer related charges from

PCOSS18

Ex. # " " " " " " Customer impacts ‐ models & data

PUB‐19‐119

PUB‐19‐120

PUB‐19‐121

PUB‐19‐122

PUB‐19‐123

PUB‐19‐124

PUB‐19‐125

PUB‐19‐126

PUB‐19‐127

PUB‐19‐128

PUB‐19‐129

PUB‐19‐130

PUB‐19‐131

PUB‐19‐132

PUB‐19‐133

PUB‐19‐134

PUB‐19‐135

Ex. # " " " " " " Rate design

Ex. # " " " " " " Comparison of Class RCC Results

Ex. # " " " " " " Bipole III reserve account

Ex. # " " " " " " Bipole III reserve account

Ex. # " " " " " " Regulatory Referral

Ex. # " " " " " " Metering Transformer

Ex. # " " " " " " PCOSS18

Ex. # " " " " " " Interprovincial interconnections

Ex. # " " " " " " AC Transmission Facilities

Ex. # " " " " " " Other non‐energy revenue

Ex. # " " " " " " General Service Small ‐ meters

Ex. # " " " " " " C27 Service Drops

Ex. # " " " " " " Revenue cost allocation

Ex. # " " " " " " Cost of service and rate design for

diesel rates

Ex. # " " " " " " Allocation of common costs

Ex. # " " " " " " Bill Comparisons

Ex. # " " " " " " Bipole III reserve funds

Ex. # " " " " " " MFRs and Application Updates

PUB‐19‐136

PUB‐19‐137

PUB‐19‐138

PUB‐19‐139

PUB‐19‐149

PUB‐19‐150

PUB‐19‐151

PUB‐19‐152

PUB‐19‐153

PUB‐19‐140

PUB‐19‐141

PUB‐19‐142

PUB‐19‐143

PUB‐19‐144

PUB‐19‐145

PUB‐19‐146

PUB‐19‐147

PUB‐19‐148

Ex. # " " " " " " PCOSS18 Electronic Model





Ex. # " " " " " " PCOSS18 Electronic Modle, Operating

Costs

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. # " " " " " " Schedule of regulatory deferral

account balances

Ex. # " " " " " " Depreciation Expense

Ex. # " " " " " " Net present value of the proposed

annualized rate increases

Ex. # " " " " " " Change management

Public Utilities Board to Manitoba Hydro ‐ Round 2 Information Requests

PUB‐20

PUB‐21

PUB‐19‐159

PUB letter re City of Winnipeg's Request to intervene ‐ August 25, 2017

PUB letter dated August 18, 2017 to Manitoba Hydro re Round 1

Information Requests

PUB letter dated August 25, 2017 re Intervener Budgets

PUB letter dated September 11, 2017 re Rule 13 Motion by Manitoba

Hydro

PUB letter dated September 15, 2017 re GSS/GSM and KAP Request to

Intervene and Intervener Budgets

PUB letter dated September 26, 2017 re Manitoba Hydro's Round 1

Information Requests Rule 13 Motion

PUB‐22

PUB‐23

PUB‐24

PUB‐25

PUB‐26

PUB‐26‐1

PUB‐26‐2

PUB‐26‐3

PUB‐26‐4

PUB‐19‐154

PUB‐19‐155

PUB‐19‐156

PUB‐19‐157

PUB‐19‐158

Ex. # " " " " " " Other expenses ‐ previously in CWIP

that are no longer providing future

economic benefit

Ex. # " " " " " " Voluntary Departure Program

Ex. # " " " " " " OM&A Expenditures by cost element

Ex. # " " " " " " Change in OM&A costs

Ex. # " " " " " " Electric O&A

Ex. # " " " " " " Mitigation measures

Ex. # " " " " " " Total interest forecast to be

capitalized by year through Keeyask

full in‐service

Ex. # " " " " " " Conawapa expenditures

Ex. # " " " " " " Manitoba Hydro debt

Ex. # " " " " " " Forecast interest rates

Ex. # " " " " " " Updates to 2014 Depreciation Study

Ex. # " " " " " " Canada 30‐year Bond yield, Manitoba

30 Year Bond yield

Ex. # " " " " " " Debt management strategy

Ex. # " " " " " " Restated scenario analyses ‐ Bipole III

Ex. # " " " " " " Credit rating agencies calculation of

cash flow to capex ratio

Ex. # " " " " " " Bipole III Reliability Project

Ex. # " " " " " " KMPG recommended metrics

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Ex. # " " " " " " Capital Structure

Ex. # " " " " " " Interest rate change scenarios

Ex. # " " " " " " Cashflow to capex ratio

Ex. # " " " " " " Corporate Strategic Plan

Ex. # " " " " " " Alternative scenario IFF16 Update

with interim based on a 32 month

delay

Ex. # " " " " " " Capital construction EFTs

Ex. # " " " " " " PUB MFR 55 & 56 based on Appendix

3.4 and Appendix 3.7 scenario 3

Ex. # " " " " " " Cash surplus beyond 2035

Ex. # " " " " " " Forecast cash flow from Operations

and capital expenditures

Ex. # " " " " " " Debt Management ‐ Free cash flow

Ex. # " " " " " " Contracts that require newly

constructed generation resources

Ex. # " " " " " " Status update of Manitoba Hydro's

implementation of BCG's suggestions

to mitigate impacts of continuing with

the completion of Bipole III and

Keeyask

Ex. # " " " " " " Load Forecast

Ex. # " " " " " " Implementation of BCG's suggestions

to address sourceable spending

Ex. # " " " " " " Capacity

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Ex. # " " " " " " Hydraulic generation

Ex. # " " " " " " Hydraulic generation

Ex. # " " " " " " Key variable sensitivity impacts

Ex. # " " " " " " Drought sensitivities

Ex. # " " " " " " Comparison of the Annual Equity

Ratio Variability

Ex. # " " " " " " Deduct Capitalized Interest on Major

Projects

Ex. # " " " " " " Major New Generation and

Transmission projects in CFO to Capex

ratio

Ex. # " " " " " " Minimum acceptable debt to equity

ratio

Ex. # " " " " " " Selkirk Generating Station

Ex. # " " " " " " Dependable energy premiums and

capacity premium

Ex. # " " " " " " Long term Potential Large Industrial

Load

Ex. # " " " " " " Top Consumers Load forecast

Ex. # " " " " " " Top Consumers Load forecast

Ex. # " " " " " " Pipeline loads

Ex. # " " " " " " Winter peak demand or dependable

energy requirements

Ex. # " " " " " " Electric heat rate design

Ex. # " " " " " " DSM meetings ‐ presentations made

to external stakeholder group

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Ex. # " " " " " " Degree Day Heating (DDH) map of

Manitoba

Ex. # " " " " " " Annual incremental capital taxes and

water rental fees from Keeyask

Ex. # " " " " " " Electricity for space heating in

Manitoba

Ex. # " " " " " " Updated Generation and combined

marginal values


(REUS)

Ex. # " " " " " " Insulation upgrades under Affordable

Energy Program or the Indigenous

Power Smart Program

Ex. # " " " " " " Directional change in economic

impacts based on IFF‐16

Ex. # " " " " " " Residential customer data

Ex. # " " " " " " Breakdown of CEF16 and CEF15

Ex. # " " " " " " Project management of Keeyask and

Bipole III ‐ tendering

Ex. # " " " " " " Keeyask Risk Registry

Ex. # " " " " " " UMS Asset Management Gap

Assessement Report ‐ Findings









Ex. # " " " " " " Corporate Risk Management Report ‐

Infrastructure Risk

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Ex. # " " " " " " Load growth projections ‐ hot spots

Ex. # " " " " " " Capital Expenditures

Ex. # " " " " " " Bipole II Valve Hall Bushing

Replacements

Ex. # " " " " " " Ratio of distribution to transmission to

generation capital investment levels

Ex. # " " " " " " SAIDI values

Ex. # " " " " " " Asset Condition Assessment Audit ‐

Kinetrics


Kinetrics


Kinetrics


Kinetrics


Kinetrics


Kinetrics

Ex. # " " " " " " Asset Condition Assessment

Methodology Standards & Results

Update

Ex. # " " " " " " Capital Project Justification

Ex. # " " " " " " Business Operations Capital and Asset

Management Technical Conference

presentation

Ex. # " " " " " " Capital investment requirements

Ex. # " " " " " " Bill frequency data for all non

residential rate classes

Ex. # " " " " " " RCC cost parity issues

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Ex. # " " " " " " Comparison of Class RCC Results

Ex. # " " " " " " PCOSS18

Ex. # " " " " " " PCOSS18

Ex. # " " " " " " Planned GILT




Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. # " " " " " " Annual income apply to on‐reserve FN

individuals/households

Ex. # " " " " " " Rate increase within bounds, view of

maximum rate increase for non‐lower

income and non‐FN

Ex. # " " " " " " Appropriate to reduce RCC for

Residential class

PUB‐26‐94

PUB‐28

PUB‐26‐88

PUB‐26‐89

PUB‐26‐90

PUB‐26‐91

PUB‐26‐92

PUB‐26‐93

Public Utilities Board (PUB) to Assembly of Manitoba Chiefs (AMC) ‐


PUB to all parties re Independent Expert Consultants Report Deadlines and

Revised MGF Scope of Work ‐ October 5, 2017

Business Council of Manitoba's Application to Review and Vary Pulbic

Utilities Board decision of August 25, 2017 ‐ October 16, 2017

PUB Order 112/17 ‐ Motions by Manitoba Hydro seeking confidential

treatment of information in the 2017/18 and 2018/19 General Rate

Application and Motion by the Consumers Coalition seeking access to

document claimed as confidential

PUB to all parties re Independent Expert Consultants' Scope of Work ‐

October 25, 2017

PUB Order 120/17 ‐ An Application by Manitoba Hydro to Review and Vary

Order 112/17

PUB‐32

PUB‐32‐1

PUB‐32‐2

PUB‐32‐3

PUB‐27

PUB‐29

PUB‐30

PUB‐31

Ex. # " " " " " " Mr. Raphal's conclusi9on with

statement of Mr. Orle in Interim Rate

Request

Ex. #

Ex. # PUB to Coalition (METSCO) IRs Business Operations Capital

interferring with threshold

Ex. # " " " " " " Asset

Ex. # " " " " " " transmission and generation asset

renewal and system enhancement

Ex. # " " " " " " Minimize capital expenditures

Ex. # " " " " " " Transmission and Generation outages

Ex. # " " " " " " defective equipment constituting third

outage with other utlities

Ex. # " " " " " " Planned renewal investments

Ex. # " " " " " " Reliability Performance

Ex. # PUB to Coalition (Simpson) IRs Statistical analysis of energy poverty

Ex. # " " " " " " unchaged debt effect on energy

poverty

Ex. # " " " " " " income inforamtion for AEP or rate

assistnace

Ex. # " " " " " " fund rcommended assistance

Ex. # " " " " " " ehancements of AEP

Ex. # PUB to Coalition (ECS Harper) IRs updated Schedule 18 from Appendix

3.8

Ex. # " " " " " " Gains and Losses on disposal of assets

PUB‐33‐9

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PUB‐33‐12

PUB to Coalition Information requestsPUB‐33

PUB‐32‐4

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Ex. # " " " " " " Definitions of exonomic impacts

Ex. # " " " " " " areas COSS evolving

Ex. # " " " " " " MH Guidelines and Board of

Commissions decision opinions

Ex. # " " " " " " ratemarking proceedings on use of

block rates

Ex. # " " " " " " adjustments to generation marginal

costs

Ex. # " " " " " " LICO‐125 targeted subset for rate

assistance

Ex. # " " " " " " merits and drawbacks on rate design

options

Ex. # " " " " " " research undertaken with Alternative

Rate Designs Specifically

Ex. # PUB to Coalition

(Compton/Simpson) IRs

Percentage change in spending

allocated

Ex. # " " " " " " Direct effect of fall in damand by

Industy Affected, leakage

Ex. # " " " " " " Tax Revenue Impact

Ex. # " " " " " " Carbon Pricing

Ex. # PUB to Coalition (MPA) IRs Metric v Free Cash Flow or

Discretionary Free Cash Flow metric

Ex. # " " " " " " Metric

Ex. # " " " " " " Capital Structure odf 75:25

Ex. # " " " " " " Drought fund

Ex. # " " " " " " Economic efficiency

Ex. # " " " " " " Debt Servicing ratemaking formula

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Ex. #

Ex. # " " " " " " Lower Income Rates

Ex. # " " " " " " Electric Space Heating

Ex. # " " " " " " Increase in energy rate

Ex. # " " " " " " Recovery Rates

Ex. # " " " " " " Revenue to Cost Coverage Ratios

Ex. # " " " " " " Lost Revenue and Recovery Rates

Ex. # " " " " " " Home Insulation Program and AEP

Ex. # " " " " " " Customer Class or Classes Implement

time of use rates apply

Ex. # " " " " " " demand metered customers, and

changes

Ex. # " " " " " " Electric Utilities adopted residential

rate structure

Ex. # " " " " " " customers charges based

Ex. # " " " " " " Calculation and Assumption additional

payment

Ex. # " " " " " " Calculation performed to support

marginal costs


Ex. #

Ex. # " " " " " " LEI evidence analysis

PUB‐34‐13

PUB‐34‐14

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PUB‐34‐3

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PUB‐34‐7

PUB‐34‐8

PUB‐34‐9

PUB‐34‐10

PUB‐34‐11

PUB‐34‐1

PUB‐34‐2

PUB‐34‐12

Public Utilities Board (PUB) to Green Action Centre (GAC) Information

Requests

Public Utilities Board (PUB) to General Service Small/General Service

Medium/Keystone Agricultural Producers (GSS‐GSM‐KAP) Information

requests

PUB‐34

PUB‐35

Ex. # " " " " " " LEI Evidence

Ex. # " " " " " " LEI Evidence asset management

Ex. # " " " " " " LEI Evidence change in operating

profits

Ex. # " " " " " " LEI Evidence MB Convenience store

gross margins

Ex. # " " " " " " LEI Evidence reduction in grid

reliability

Ex. # " " " " " " LEI Evidence gas generation

alternatives

Ex. # " " " " " " LEI Evidence real discount rate

Ex. # " " " " " " LEI Evidence number of empoloyees

Ex. # " " " " " " LEI Evidence Crown Corportations

Ex. # " " " " " " LEI Evidence escalted rate in other

jurisdictions

Ex. # " " " " " " LEI Evidence IMPLAN

Ex. # " " " " " " LEI Evidence economic impacts

Ex. # " " " " " " LEI Evidence Economic Impacts

Ex. # " " " " " " LEI Evidence Sector exomonic impacts

Ex. # " " " " " " LEI Evidence Sector exomonic impacts

Ex. # " " " " " " LEI Evidence Key Performance

Indicator Analysis

Ex. #

Ex. # " " " " " " DSM High Keeyask scenario

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PUB‐35‐3

PUB‐35‐4

Public Utilities Board (PUB) to Manitoba Industrial Power Users Group

(MIPUG) Information Requests (1‐17)

PUB‐36

Ex. # " " " " " " US and Saskatchewan

Ex. # " " " " " " Marginal Value

Ex. # " " " " " " Histrorical RCC

Ex. # " " " " " " COS Methodology

Ex. # " " " " " " Revenue Loss

Ex. # " " " " " " Time of use Rate

Ex. # " " " " " " financial reporting

Ex. # " " " " " " Peer Canadian hydroelectric

generation companies

Ex. # " " " " " " revise debt terming stategy

Ex. # " " " " " " MIPUG contention O&A

Ex. # " " " " " " Provincially Owned Utilties

Ex. # " " " " " " Proposal to recognized gain

Ex. # " " " " " " Minimum Retained Earning Targe

Ex. # " " " " " " define rate shock

Ex. # " " " " " " deferral in charges

Ex. # " " " " " " rate trajectory

Ex. #

Ex. # " " " " " " rate increase over 10 years, water

rates, sewer rates, basic

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PUB‐36‐3

PUB‐36‐4

PUB‐36‐5

Public Utilities Board (PUB) ‐ City of Winnipeg (COW) Information

Requests

PUB‐37

Ex. # " " " " " " Markowsky Evidence

Ex. #

Ex. # " " " " " " Export

Ex. # " " " " " " Export

Ex. # " " " " " " Export Revenue, Minn Hub or MHEB

Hub

Ex. # " " " " " " Export Revenue, Minnesota Power

Ex. # " " " " " " Export Revenue, Northern States

Power

Ex. # " " " " " " Export Revenue, Minnesota and

Wisconsin's Renewable Portfolio

StandardsEx. # " " " " " " Export Revenue, MISO forward

capacity market

Ex. # " " " " " " Export Revenue, nuclear plants in

Minnesota

Ex. # " " " " " " Export Revenue, actual forecast prices

Ex. # " " " " " " Export Revenue, source of actual

forecast

Ex. # " " " " " " Export Revenue, natural gas forecasts

Ex. # " " " " " " Export Revenue, pricing locations

Ex. # " " " " " " Export Revenue, adjustments of

forecasters Minn Hub appropraite

Ex. # " " " " " " Export Revenue, surplus dependable

energy opportunity energy

Ex. # " " " " " " Export Revenue, energy premium

Ex. # " " " " " " Export Revenue, natural gas price

forecasts

PUB‐38‐10

PUB‐38‐11

PUB‐38‐12

PUB‐38‐13

PUB‐37‐2

Public Utilities Board (PUB) ‐ Daymark Energy Advisors Information

Requests

PUB‐38

PUB‐38‐CSI‐1

PUB‐38‐CSI‐2

PUB‐38‐1

PUB‐38‐2

PUB‐38‐3

PUB‐38‐4

PUB‐38‐5

PUB‐38‐6

PUB‐38‐7

PUB‐38‐8

PUB‐38‐9

PUB‐38‐14

Ex. # " " " " " " Export Revenue, revenue forecast

carryover

Ex. # " " " " " " Load Forecast, Top customers load

forecast

Ex. # " " " " " " Load Forecast, methodology changes

Ex. # " " " " " " Load Forecast, periodfs and secotrs

forecasts

Ex. # " " " " " " Load Forecast, lagged electricity price

GSL, non‐lagged GSS/GSM

Ex. # " " " " " " Load Forecast, Top Customers to

General Service Mass Market

Ex. # " " " " " " Load Forecast, forecasting monthly

peaks

Ex. # " " " " " " Load Forecast, gas to electricity prices

Residential forecast

Ex. # " " " " " " Load Forecast, population forecasting

Ex. # " " " " " " Load Forecast, price elasticity

estimates

Ex. # " " " " " " Load Forecast, alternative load

forecast scenarios

Ex. # " " " " " " Load Forecast, load forecast accuracy

Ex. # " " " " " " Load Forecast, impact of load forecast

using lower CDD and HDD coefficients

Ex. # " " " " " " Load Forecast, normal weather

Ex. # " " " " " " Load Forecast, DSM in load forecast

problematic

Ex. # " " " " " " Load Forecast, Load forecast

methodologies reasonable and

appropriateEx. # " " " " " " Load Forecast, Potential Large

Industries load

Ex. # " " " " " " Load Forecast, in‐come, GDP,

population

PUB‐38‐32

PUB‐38‐16

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PUB‐38‐18

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PUB‐38‐31

Ex. # " " " " " " Load Forecast, blended GDP variarle in

GSMM and Top Customer forecasts

Ex. # " " " " " " Load Forecast, estimate transmission

and distribution losses

Ex. #

Ex. # " " " " " " Oil and Natural Gas Market and

Exports

Ex. # " " " " " " Grid Parity

Ex. # " " " " " " Provincial Energy Intensity Trends

Ex. # " " " " " " Cost of living and wages in Manitoba

vs. other Provinces

Ex. # " " " " " " long term electricity demand growth

Ex. # " " " " " " efficencies to increasing rates

Ex. # " " " " " " Energy Poverty

Ex. # " " " " " " Market Snapshot: Fuel Poverty Across

Canada

Ex. # " " " " " " Rate Shock in rate trajevtory

Ex. # " " " " " " Carbon Leakage Problem

Ex. # " " " " " " Effect of Proposed Hydro Rate

Increase on MB Economy

Ex. #

Ex. #

Ex. #

Ex. # " " " " " " Volume 1 ‐ Corporate Overview

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PUB‐42

PUB‐41

PUB‐40

PUB‐39

Public Utilities Board to W. Gardner re: MGF Project Extension Request ‐

November 29, 2017

Public Utilties Board Letter to all parties re Rule 13 Motion and CSI in

Daymarks Report ‐ November 30, 2017

Board Counsel's Book of Documents

Public Utilities Board ‐ Dr. Yatchew Information Requests

PUB‐42‐1

PUB‐39‐11

Ex. # " " " " " " Volume 2 ‐ Financiel Targets

Ex. # " " " " " " Volume 3 ‐ Credit and Debt and

Financiel Expenses

Ex. # " " " " " " Volume 4‐ Payment, Depreciation,

Load Forecast

Ex. # " " " " " " Volume 5 ‐ Cost of Service and Rate

Design

Ex. # " " " " " " Summary of Approved August 1, 2017

Rates

Ex. # " " " " " " Volume 6 ‐ Major New Capital

Projects

Ex. #

Ex. #

Ex. #

Ex. #

Ex. # " " " " " Productivity in original GCC

Ex. # " " " " " Construction Management Methods

Ex. # " " " " " Aboriginal Labour Availability

Ex. # " " " " " Trends and Delay Estimate

Ex. # " " " " " risk related to geotechnical issues

Ex. # " " " " " management system for developing

cost estimates

Ex. # " " " " " early contractor invovement

Ex. # " " " " " BBC Contract

PUB‐42‐5

PUB‐46

PUB‐45

PUB‐44

PUB‐43 PUB letter to BCoM re Budget Variance ‐ December 5, 2017

PUB letter to all parties re Motion 13 Moodys Report ‐ December 5, 2017

PUB letter to all parties re Motion 13 MGF Report Redactions ‐ December

19, 2017

PUB‐42‐6

PUB‐42‐2

PUB‐42‐3

PUB‐42‐4

PUB‐42‐5‐1

Public Utilities Board to MGF ‐ Information Requests

PUB‐46‐1

PUB‐46‐2

PUB‐46‐3

PUB‐46‐4

PUB‐46‐5

PUB‐46‐6

PUB‐46‐7

PUB‐46‐8

Ex. # " " " " " Concrete Productivity Factor

Ex. # " " " " " contract Management and cost

control system

Ex. # " " " " " foreman to craft labour

Ex. # " " " " " self performing contractor

Ex. # " " " " " mitigation measures

Ex. # " " " " " Order of Magnitude Estimate Range

Ex. # " " " " " heightened levels of risk and

recommend risk mitgation

Ex. # " " " " " conrete and earthworks productivity

Ex. # " " " " " KCB Historicial coperative unit price

Ex. # " " " " " P75 contingency

Ex. # " " " " " Basis of Estimate

Ex. # " " " " " Scope of work conclusion of forecast

completion costs

Ex. # " " " " " Scope of Work Conclusion schedule

estimates

Ex. # " " " " " Manitoab Minnesota Transmission

Project

Ex. # " " " " " Bipole III applied to Manitoba ‐

Minnestora Transmission

Ex. # " " " " " page 132 higher than whose costs

Ex. # " " " " " Great Northern Tramission Line

Ex. # PUB‐47 Public Utilties Board to Daymark Energy Advisors (Saskpower) ‐


PUB‐46‐9

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Ex. # " " " " " 35‐ contract revenues from 1 day

delay

Ex. # " " " " " 36‐ Facilities Contruction Agreement ‐

in‐service date

Ex. # " " " " " 37 ‐ MH 2016 Sales Evaluation

Ex. # " " " " " CSI‐3 ‐ Saskpower Report Page 23

Ex. # " " " " " CSI‐4 ‐ Saskpower Report Page 24

Ex. #

Ex. #

Ex. #

Ex. # " " " " " PUB‐46‐5

Ex. # " " " " " PUB‐46‐6

Ex. # " " " " " PUB‐46‐7

Ex. # " " " " " PUB‐46‐8

Ex. # " " " " " PUB‐46‐17

Ex. #

PUB‐MGF (KCB) Information Requests

PUB letter to all partires re: Rul 13 Motionn re CSI in MGF Rebuttal

PUB letter to all partires re: Rule 13 Motion CSI in Daymark Saskpower

Report dated January 3, 2018

PUB letter to Consumers Coalition re Public Presentations dated January 5,

2018

PUB‐51

PUB‐48

PUB‐49

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PUB‐50‐2

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PUB‐50

Assembly of Manitoba Chiefs (AMC) Exhibits

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. # AMC to MH ‐ Round 1 Irs Rate Increase ‐ Customer Impacts ‐

Residential Electric Customers

Ex. # " " " " " " Rate Increase ‐ Customer Impacts ‐

General Service Customers

Ex. # " " " " " " Cumulative number of participating

customers in First Nation Power Smart

Program

Ex. # " " " " " " Program enhancements ‐ First Nations

households affected by energy

poverty

EXHIBIT LIST FOR

MANITOBA HYDRO


February 16, 2018

AMC‐1 Assembly of Manitoba Chiefs letter re Manitoba Hydro's Interim Rate

Request dated July 14, 2017

AMC‐2 Assembly of Manitoba Chiefs' Budget Submission

AMC‐3 Assembly of Manitoba Chiefs' Reply to Manitoba Hydro's Comments on

Proposed Intervener Budgets ‐ July 24, 2017

AMC‐4‐1

Assembly of Manitoba Chiefs (AMC) to Manitoba Hydro (MH) ‐ Round 1


AMC‐2‐1 Attachment 1 ‐ Issues List

AMC‐3‐1 CV of Philip Raphals

AMC‐4‐2

AMC‐4‐3

AMC‐4‐4

AMC‐4

Ex. # " " " " " " Indigenous & Northern Affairs Canada

(INAC) ‐ April 5, 2016 letter re

jurisdiction over Manitoba Hydro

Rates


(REUS)

Ex. # " " " " " " Bad debts expenses for electricity

Ex. # " " " " " " Existing bill affordability programs for

low‐income customers

Ex. # " " " " " " Estimates of Electricity costs by INAC

Ex. # " " " " " " Affordable Energy Program ‐ First

Nations' participation

Ex. # " " " " " " Bill Affordability ‐ PRA report



Ex. # " " " " " " Proposal to direct a portion of

incremental capital taxes & water

rental fees ‐ Keeyask Project

Ex. # " " " " " " Status of Manitoba Hydro

Ex. # " " " " " " Non‐rate programs/interventions

offered by Manitoba Hydro

Ex. # " " " " " " Neighbours Helping Neighbours

Ex. # " " " " " " Results of Collaborative Process ‐

effectiveness for on‐reserve First

Nations households

Ex. # " " " " " " Equivalent data for MH rate increases

in constant (inflation‐adjusted) dollars

AMC‐4‐14

AMC‐4‐15

AMC‐4‐16

AMC‐4‐17

AMC‐4‐18

AMC‐4‐19

AMC‐4‐5

AMC‐4‐6

AMC‐4‐7

AMC‐4‐8

AMC‐4‐9

AMC‐4‐10

AMC‐4‐11

AMC‐4‐12

AMC‐4‐13

Ex. # " " " " " " Results of Collaborative Process ‐

Profile of MH customers

Ex. # " " " " " " Percent of on‐reserve First Nations

households sampled

Ex. # " " " " " " Factors affecting energy consumption ‐

analysis for on‐reserve First Nations

households

Ex. # " " " " " " Bill affordability ‐ Electricity

consumption

Ex. # " " " " " " Agreements with INAC establishing

the "Social Process"

Ex. # " " " " " " EIA program in paying utility bills

Ex. # " " " " " " Latitude and average annual heating

degree days for each First Nations

community

Ex. # " " " " " " Status of housing in First Nations

communities

Ex. # " " " " " " Factors in energy poverty and arrears

among First Nations

Ex. # " " " " " " Arrears in First Nations communities ‐

Administrative (short‐term) issues

Ex. # " " " " " " Power Smart First Nations Program

Ex. # " " " " " " Estimated impact of potential rate

increases on customers

Ex. # " " " " " " Household incomes on First Nations

reserves

Ex. # " " " " " " Excel versions of data used for Figures

7 & 8 of the PRA Report

Ex. # " " " " " " Excel versions of data used on the

impact of rate increases on energy

burdens experiend by energy‐poor

and non‐energy poor households

AMC‐4‐20

AMC‐4‐21

AMC‐4‐22

AMC‐4‐23

AMC‐4‐24

AMC‐4‐25

AMC‐4‐26

AMC‐4‐27

AMC‐4‐28

AMC‐4‐29

AMC‐4‐30

AMC‐4‐31

AMC‐4‐32

AMC‐4‐33

AMC‐4‐34

Ex. # " " " " " " Impact of rate increase upon the

proportion of LICO‐125 households

Ex. # " " " " " " Proportion of LICO‐125 households

with energy burdens exceeding 6%

Ex. # " " " " " " Copies of the External Review of the

AEP by Dunsky and Affordable Energy

Program & Neighbours Helping

Neighbours by Galbraith

Ex. # " " " " " " Benefits and barriers to enrollment in

the AEP

Ex. # " " " " " " Current uptake of bill affordability

programming

Ex. # " " " " " " AEP program's current offering for

electric baseboard heating customers

Ex. # " " " " " " Percentage of on‐reserve First Nations

households considered as tenants

Ex. # " " " " " " Reports by Ross (2014) and Kuczeck,

Morrison, Barnlund, Chard & Galbraith

(2015)

Ex. # " " " " " " Estimated impact of bill affordability

options on MH and its customers

Ex. # " " " " " " Bill affordability impact on Manitoba

Hydro revenues


Hydro revenues


Hydro revenues

Ex. # " " " " " " Fixed Credit Approach

Ex. # " " " " " " Conservation Rates ‐ Distribution of

monthly billed kWh

Ex. # " " " " " " Conservation Rates ‐ Distribution of

monthly billed kWh

AMC‐4‐35

AMC‐4‐36

AMC‐4‐37

AMC‐4‐38

AMC‐4‐39

AMC‐4‐40

AMC‐4‐41

AMC‐4‐42

AMC‐4‐43

AMC‐4‐44

AMC‐4‐45

AMC‐4‐46

AMC‐4‐47

AMC‐4‐48

AMC‐4‐49

Ex. # " " " " " " Energy usage in MKO communities

Ex. # " " " " " " Percentage of electrically heated on‐

reserve First Nations households

Ex. # " " " " " " Alternative Rate Design Proposal

Ex. # " " " " " " Diesel General Service rate increase

Ex. # " " " " " " Energy‐effeciency & weatherization

initiatives

Ex. # " " " " " " Fair & equitable rates

Ex. # " " " " " " General ratemaking principles ‐

marginal costs

Ex. #

Ex. #

Ex. # " " " " " " data on‐reserve FN Residentail

customers only

Ex. # " " " " " " table for each FN in provice for 2016

Ex. # " " " " " " impediments to using Indian Status as

a criterion

Ex. # " " " " " " tax treatment available to person with

Indian Status under Indian Act

Ex. # " " " " " " customers participaing in FN Power

Smart Program

Ex. # " " " " " " responses of customers who are

resident on FN reserves

Ex. # " " " " " " clarify insulation upgrades,

commercial Geothermal Program,

Community Geothermal Program

AMC‐6 Assembly of Manitoba Chiefs (AMC) to Manitoba Hydro (MH) ‐ Round 2


AMC‐6‐2

AMC‐6‐3

AMC‐6‐4

AMC‐6‐5

AMC‐6‐6

AMC‐6‐7

AMC‐5 Letter by Assembly of Manitoba Chiefs in response to Manitoba Hydro's

August 2, 2017 letter re Information Requests ‐ dated August 4, 2017

AMC‐6‐1

AMC‐4‐54

AMC‐4‐55

AMC‐4‐56

AMC‐4‐50

AMC‐4‐51

AMC‐4‐52

AMC‐4‐53

Ex. # " " " " " " AEP program available to Indigenous

ratepayers

Ex. # " " " " " " General Service customers in

Indigenous communities, or covered

by Indigenous or FN PSPEx. # " " " " " " FN home meet all criteria to be

eligible for insulation upgrades

Ex. # " " " " " " Non‐Electric apply to all 3 zones

(urban, rural, Indigenous)

Ex. # " " " " " " table for FN participants only

Ex. # " " " " " " MH decididing in what order to offer

programs to FN Communities

Ex. # " " " " " " contribution from Band Counsil for

paying MH Bills vs. non assistance

Ex. # " " " " " " 1/3 of all on‐reserve FN households,

spend 10% or more of total income on

engeryEx. # " " " " " " explain FN owned service and

infrastructure

Ex. # " " " " " " simulation model used by PRA, how it

models household on and off reserve

Ex. # " " " " " " updated tables of PRA reports

Ex. # " " " " " " members of Bill Affordability Working

Group, other than MH and

Government entitiesEx. # " " " " " " weather‐adjusted electricity twice as

great for FN residential customers

Ex. # " " " " " " FN in province, repairs

Ex. # " " " " " " Indigenous Energy Advisors for each

FN community

Ex. # " " " " " " revisde table, PRA report

Ex. # " " " " " " household income on FN reserve grow

rate

AMC‐6‐20

AMC‐6‐21

AMC‐6‐22

AMC‐6‐23

AMC‐6‐24

AMC‐6‐11

AMC‐6‐12

AMC‐6‐13

AMC‐6‐14

AMC‐6‐15

AMC‐6‐16

AMC‐6‐17

AMC‐6‐18

AMC‐6‐19

AMC‐6‐8

AMC‐6‐9

AMC‐6‐10

Ex. # " " " " " " formuals, of calculations used to

produce figures in PRA figures 7‐8

Ex. # " " " " " " formuals, of calculations used to

produce figures in PRA figures 9‐10

Ex. # " " " " " " updated Figure 1 account application

of rate increase to fixed change

Ex. # " " " " " " update Tables 1 and 2, application of

rate increase to fixed change

Ex. # " " " " " " lost revenues to MH various

affordability measures

Ex. # " " " " " " rate impacts on non‐energy‐poor

residential customers

Ex. # " " " " " " MH to access data on customer‐

specific basis all on‐reserve FN

householdsEx. # " " " " " " table for each FN in province

regarding if gas is available

Ex. # " " " " " " version of Figure 5 from on‐reserve

customers only

Ex. #

Ex. #

Ex. #

Ex. # " " " " " " Annual Income

Ex. # " " " " " " Paul Chernick Testimony

Ex. #

Ex. #

Ex. #

AMC‐6‐29

AMC‐6‐30

AMC‐6‐31

AMC‐6‐32

AMC‐6‐33

AMC‐6‐25

AMC‐6‐26

AMC‐6‐27

AMC‐6‐28

AMC‐7 Implications of Manitoba Hydro's General Rate Application by Philip

Raphals Executive Director of Helios Centre

AMC‐8 AMC to GAC Information Requests

AMC‐9 Truth and Reconciliation Commision of Canada ‐ Call to Action

AMC‐10 United Nations Declaration of Rights of Indigenous Peoples

AMC‐8‐1

AMC‐8‐2

AMC‐11 AMC to MH ‐ Executive Panel Written Interrogation

AMC‐7‐1 Implications of Manitoba Hydro's General Rate Application by Philip

Raphals Executive Director of Helios Centre Revised

Ex. # " " " " " " Action Plan/ Written Policy includes

TRC Calls to Action

Ex. # " " " " " " Plan

Ex. # " " " " " " MH Implement TRC Call to Action

Ex. # " " " " " " redress Indigenous Peopls in

accordance with UNDRIP

Ex. # " " " " " " budgetary impact of plans on Financial

Position

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

AMC‐11‐1

AMC‐14 Philip Raphals Presentation

AMC‐15 Senate Interim Report On‐Reserve Housing Chanllanges and Sccuesses

AMC‐16 AMC letter to all parties re Legal Argument ‐ January 29, 2018

AMC‐12 Book of Documents ‐ Revenue Requirement Panel

AMC‐13 Senate Report On‐Reserve Housing and Infrastructure

AMC‐11‐2

AMC‐11‐3

AMC‐11‐4

AMC‐11‐5

AMC‐20 Book of Authorities ‐ Closing Submisions

AMC‐21 AMC Final Written Submissions

AMC‐22 AMC Final Submissions ‐ Presentation

AMC‐17 AMC Undertaking 71 ‐ Electrical Power and Control Act Newfoundland and

Labrador

AMC‐18 AMC Undertaking 70 ‐ Ontario Energy and Poverty Tax Credit

AMC‐19 AMC Undertaking 69 ‐ First Nation Bill Assistance

Business Council of Manitoba (BCoM) Exhibits

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. # " " " " " " Risk of credit downgrade of MH by

DBRS

Ex. # " " " " " " Risk of Credit downgrade of MH by

Moodys

Ex. # " " " " " " Risk of Credit downgrade of MH by

Standard & Poor's

Ex. # " " " " " " Risk of Credit downgrade of MB by

DBRS


Moodys


Standard & Poor's

EXHIBIT LIST FOR

MANITOBA HYDRO


February 16, 2018

BCoM‐1 Submission re Manitoba Hydro's Interim Rate Request (email dated July 12,

2017)

BCoM‐4 Business Council of Manitoba's Review and Vary Application re Intervener

Budget Decision ‐ September 25, 2017

BCoM‐5 BCM to Coalition (Simpson/Compton)

BCoM‐2 Business Council of Manitoba's Intervener Budget Submission

BCoM‐3 Business Council of Manitoba's letter to PUB re Issues and Expert Evidence ‐

September 15, 2017

BCoM‐5‐1

BCoM‐5‐2

BCoM‐5‐3

BCoM‐5‐4

BCoM‐5‐5

BCoM‐5‐6

Ex. # " " " " " " Credit Rating Reports

Ex. # " " " " " " DBRS statement

Ex. # " " " " " " Recover costs Increased rates

Ex. # " " " " " " Debt financial burden re: cash flow

Ex. # " " " " " " Self Supporting Status

Ex. # " " " " " " Standard and Poor statement

Ex. # " " " " " " MH debt load

Ex. # " " " " " " Gov support Utility in event of

financial distress

Ex. # " " " " " " Standard and Poor

Ex. # " " " " " " MH credit rating agencies

Ex. # " " " " " " credit rating downgrades, on rate

increase

Ex. # " " " " " " Borrowing costs affect credit rating

downtrades

Ex. # " " " " " " DBRS Combining MH debt with MB

debt

Ex. # " " " " " " Moody combining debt

Ex. # " " " " " " Sel supporting status contributing

factor to downgrade

Ex. # " " " " " " Self Supporting Status increased

borrowing costs

Ex. # " " " " " " Debt/Equity ratio target

BCoM‐5‐7

BCoM‐5‐8

BCoM‐5‐9

BCoM‐5‐10

BCoM‐5‐11

BCoM‐5‐12

BCoM‐5‐13

BCoM‐5‐14

BCoM‐5‐15

BCoM‐5‐16

BCoM‐5‐17

BCoM‐5‐18

BCoM‐5‐19

BCoM‐5‐20

BCoM‐5‐21

BCoM‐5‐22

BCoM‐5‐23

Ex. # " " " " " " payind debt down and increasing rates

Ex. # " " " " " " Debt Situation

Ex. # " " " " " " Cash flow

Ex. # " " " " " " Cash flow change over 10 years

Ex. # " " " " " " Cash Flow with credit agencies

Ex. # " " " " " " Increase in borrowing costs

Ex. # " " " " " " Interest rate increase on cash flow

Ex. # " " " " " " Debt/Equity ratio compare to other

utilities

Ex. # " " " " " " Rate Increase on Economy

Ex. # " " " " " " Job reduction

Ex. # " " " " " " economy and job impact on credit

rating downgrade

Ex. #

Ex. # " " " " " " risk of credit downgrade





BCM to MIPUG (1‐32) Information Requests

BCoM‐5‐24

BCoM‐5‐25

BCoM‐5‐26

BCoM‐5‐27

BCoM‐5‐28

BCoM‐5‐29

BCoM‐5‐30

BCoM‐5‐31

BCoM‐5‐32

BCoM‐5‐33

BCoM‐5‐34

BCoM‐6‐1

BCoM‐6‐2

BCoM‐6‐3

BCoM‐6‐4

BCoM‐6‐5

BCoM‐6


Ex. # " " " " " " Credit Ratings

Ex. # " " " " " " Credit Ratings

Ex. # " " " " " " Credit Rating downgrade

Ex. # " " " " " " Credit Rating downgrade

Ex. # " " " " " " Rate Increase on Credit rating

Ex. # " " " " " " Rate Increase on Credit rating

Ex. # " " " " " " Debt/Equity ration monitored

Ex. # " " " " " " Debt on structure and operations

Ex. # " " " " " " Financial Indicators monitored

Ex. # " " " " " " Paying down debt and increasing rates

Ex. # " " " " " " Credit downgrade risks





Ex. # " " " " " " Credit ratings

BCoM‐6‐6

BCoM‐6‐7

BCoM‐6‐8

BCoM‐6‐9

BCoM‐6‐10

BCoM‐6‐11

BCoM‐6‐12

BCoM‐6‐13

BCoM‐6‐14

BCoM‐6‐15

BCoM‐6‐16

BCoM‐6‐17

BCoM‐6‐18

BCoM‐6‐19

BCoM‐6‐20

BCoM‐6‐21

BCoM‐6‐23

Ex. # " " " " " " Credit ratings

Ex. # " " " " " " Borrowing costs affect credit rating

downtrades

Ex. # " " " " " " Credit Rating downgrades

Ex. # " " " " " " Debt for credit rating

Ex. # " " " " " " Debt for credit rating

Ex. # " " " " " " Debt/Equity ratio target

Ex. # " " " " " " Debt on structure and operations

Ex. # " " " " " " Financial Indicators monitored

Ex. # " " " " " " Debt payment and Increasing rate

Ex. #

Ex. #

Ex. # " " " " " " MH Future earnings

Ex. # " " " " " " Electric Operations Projected

Operating Statement

Ex. # " " " " " " reduced net earnings result in bond

raters concluding MH no longer self‐

supportingEx. # " " " " " " level of reduced net earnings, result in

reduction of bond rating

Ex. # " " " " " " downgrade of credit rating of Prov or

utilties relates to interest rates or

borrowing costsEx. # " " " " " " increase borrowing costs exposed

from ineterest rate

BCoM‐7 Business Council of Manitoba letter to PUB dated November 23, 2017

BCoM‐8 Business Council of Manitoba ‐ Dr. Yatchew ‐ Inforamtion Requests

BCoM‐8‐1

BCoM‐8‐2

BCoM‐8‐3

BCoM‐8‐4

BCoM‐8‐5

BCoM‐8‐6

BCoM‐6‐26

BCoM‐6‐27

BCoM‐6‐28

BCoM‐6‐29

BCoM‐6‐30

BCoM‐6‐31

BCoM‐6‐32

BCoM‐6‐24

BCoM‐6‐25

Ex. # " " " " " " borrowing costs exposed absolute

dollar cost prescpective credit

downgradeEx. # " " " " " " macroeconomic prescpective

expected impact on MH or Prov MB

credit downgradeEx. # " " " " " " risk of credit downgrade for MH and

MB

Ex. # " " " " " " credit downgrade increased or

decreased

BCoM‐8‐7

BCoM‐8‐8

BCoM‐8‐9

BCoM‐8‐10

CONSUMER ASSOCIATION OF CANADA (MANITOBA) and WINNIPEG HARVEST (COALITION)

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

EXHIBIT LIST FOR

MANITOBA HYDRO


February 16, 2018

CC‐1 Consumer Coalition letter dated March 28, 2017 re Manitoba Hydro's March 24,

2017 letter

CC‐2 Minimum Filing Requirements (MFRs) of the Consumer Coalition

CC‐4

CC‐5

Appendix B ‐ Interim Rate Request

"Rate Shock and Malleable Metrics: Avoiding an Unreasonable Rush to

Judgment" ‐ Submission of the Consumers Coalition re Interim Rate Request

Budget Submission dated July 14, 2017

CC‐4‐1

CC‐4‐2

Revised July 17, 2017 ‐ "Rate Shock and Malleable Metrics: Avoiding an

Unreasonable Rush to Judgment" ‐ Submission of the Consumers Coalition re

Interim Rate Request

Revised July 18, 2017 ‐ "Rate Shock and Malleable Metrics: Avoiding an

Unreasonable Rush to Judgment" ‐ Submission of the Consumers Coalition re

Interim Rate Request

Attachment A ‐ Draft Budget and Workplan

Attachment B ‐ Issues List

CC‐5‐1

CC‐5‐2

CC‐3

CC‐3‐1

Coalition Letter re Manitoba Hydro's Interim Rate Application dated May 26,

2017

Appendix A ‐ An Interim Rate Addition Table

CC‐3‐2

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. # Coalition to MH ‐ Round 1 Irs Ten year target ‐ 75:25 equity ratio

Ex. # " " " " " " Need to improve equity level

Ex. # " " " " " " Uncertainty analysis ‐ equity ratio results

Ex. # " " " " " " Change in underlying assumptions

Ex. # " " " " " " 2016 Financial Statement values ‐ Property,

Plant and Equipment

Ex. # " " " " " " Intangible Assets ‐ Remaining Useful Life

Ex. # " " " " " " Property, Plant and Equipment ‐ Remaining

Useful Life

Ex. # " " " " " " Full set of financial statements generation

for each of the scenarios in Figure 4.4 ‐ Key

variable sensitivity impacts to MH16

retained earnings

Ex. # " " " " " " Uncertainty analysis ‐ Water flow variability

CC‐8 Coalition re COSS Model ‐ July 20, 2017

CC‐6 "Avoiding a Rate Shock Rush to Judgement" ‐ Presentation by the Consumer

Coalition ‐ July 18, 2017

CC‐7 Coalition's letter dated July 18, 2017 re Revised Interim Rate Submission

CC‐10‐2

CC‐10‐3

CC‐10‐4

CC‐10‐5

Coalition's response to Manitoba Hydro's comments on Interverner Budgets ‐

July 24, 2017

Consumers Coalition (Coalition) to Manitoba Hydro ‐ Round 1 Information

Requests

CC‐6‐1 Revised "Avoiding a Rate Shock Rush to Judgement" ‐ Presentation by the

Consumer Coalition ‐ July 18, 2017

CC‐10

CC‐10‐6

CC‐10‐7

CC‐10‐8

CC‐9

CC‐10‐1

CC‐10‐9

Ex. # " " " " " " Uncertainty analysis ‐ Export Revenue

Ex. # " " " " " " Uncertainty analysis ‐ equity ratio

Ex. # " " " " " " Uncertainty analysis ‐ net debt

Ex. # " " " " " " Uncertainty analysis ‐ retained earnings

Ex. # " " " " " " Uncertainty analysis ‐ Interest coverage

ratio & capital coverage ratio

Ex. # " " " " " " Credibility of equity ratio plan

Ex. # " " " " " " Inadequacy of previous financial plans

Ex. # " " " " " " Corporate strategic plan and dashboard

Ex. # " " " " " " Manitoba Clean Environment Commission ‐

Lake Winnipeg Regulation Report ‐ Nelson

& Churchill River systems

Ex. # " " " " " " Debt Management Strategy

Ex. # " " " " " " Debt Management Strategy ‐ Interest rate

information

Ex. # " " " " " " Debt Management Strategy ‐ Debt

retirement

Ex. # " " " " " " Debt Management Strategy

Ex. # " " " " " " Lower Electric Load Forecast and Domestic

Revenues

Ex. # " " " " " " Manitoba Hydro Climate Change Report

CC‐10‐10

CC‐10‐11

CC‐10‐12

CC‐10‐13

CC‐10‐14

CC‐10‐15

CC‐10‐16

CC‐10‐17

CC‐10‐18

CC‐10‐19

CC‐10‐20

CC‐10‐21

CC‐10‐22

CC‐10‐23

CC‐10‐18

Ex. # " " " " " " Electric Load Forecast 2016 ‐ Prime drivers

of growth

Ex. # " " " " " " Electric Load Forecast 2016 ‐ General

Service Top Customers

Ex. # " " " " " " Electric Load Forecast 2016 ‐ Load

Sensitivities and extreme events

Ex. # " " " " " " Load Forecast ‐ Price Elasticities ‐

Reasonableness of value estimated

Ex. # " " " " " " Load Forecast ‐ Forecast of residential

dwellings

Ex. # " " " " " " 2017 Energy Price Outlook

Ex. # " " " " " " Load Forecast ‐ GS Top Consumers Forecast ‐

short term vs long term forecast


major changes & effects


Potential Large Industrial Loads Forecast


Potential Large Industrial Loads Forecast

Ex. # " " " " " " Economic Outlook ‐ Changes in Outlook ‐

Population Forecasts

Ex. # " " " " " " Load Forecast ‐ Residential Customer Count ‐

Basis for Forecast

Ex. # " " " " " " Load Forecast ‐ Multiple Customer Sectors ‐

Potential Distributed Generation

Ex. # " " " " " " Load Forecast ‐ Adjustments made for IFF16

Ex. # " " " " " " Load Forecast ‐ Load Forecast Uncertainty

CC‐10‐35

CC‐10‐36

CC‐10‐37

CC‐10‐38

CC‐10‐33

CC‐10‐34

CC‐10‐31

CC‐10‐32

CC‐10‐29

CC‐10‐30

CC‐10‐24

CC‐10‐25

CC‐10‐26

CC‐10‐27

CC‐10‐28

Ex. # " " " " " " Load Forecast ‐ Definitions ‐ Domestic Sales

Ex. # " " " " " " Load Forecast ‐ DSM and forecast savings

Ex. # " " " " " " Load Forecast ‐ Residential forecast ‐ Input

Assumptions and Methodology Used

Ex. # " " " " " " Load Forecast ‐ Residential ‐ Changes from

previous forecasts

Ex. # " " " " " " Load Forecast ‐ General Service Forecast ‐

Forecast Methodology

Ex. # " " " " " " Load Forecast ‐ GS Mass Market ‐ Changes

from previous forecasts

Ex. # " " " " " " Load Forecast ‐ Top Consumers ‐ Forecast

methodology

Ex. # " " " " " " Load Forecast ‐ Plug‐in electric vehicles ‐

changes in forecasts

Ex. # " " " " " " DSM Metrics ‐ Basis for Calculation

Ex. # " " " " " " Load Forecast ‐ DSM Savings

Ex. # " " " " " " Load Forecast ‐ Impact of DSM ‐ Changes

between IFFs

Ex. # " " " " " " Supply and Demand Balance ‐ System Firm

Energy Demand and Resources ‐ Impact of

2017 Load Forecast

Ex. # " " " " " " Export Price Forecast Modelling

Ex. # " " " " " " Export Price Forecast Modelling

Ex. # " " " " " " Closures of coal facilities ‐ delayed under

the Trump Administration in MISO or SPP

markets

CC‐10‐39

CC‐10‐40

CC‐10‐41

CC‐10‐42

CC‐10‐43

CC‐10‐44

CC‐10‐45

CC‐10‐46

CC‐10‐47

CC‐10‐48

CC‐10‐49

CC‐10‐50

CC‐10‐51

CC‐10‐52

CC‐10‐53

Ex. # " " " " " " Export Price Forecast ‐ Capacity Prices

Ex. # " " " " " " Export Price Forecast ‐ Carbon Prices and

Restrictions

Ex. # " " " " " " Export Price Forecast

Ex. # " " " " " " Consultant Export Price Forecasts

Ex. # " " " " " " Approvals sought ‐ interim rate orders

Ex. # " " " " " " Regulatory deferral accounts

Ex. # " " " " " " Deterioration in Financial Outlook

Ex. # " " " " " " Reason for a rate increase ‐ need to

complete Keeyask

Ex. # " " " " " " Favourable water flows

Ex. # " " " " " " Favourable interest rates

Ex. # " " " " " " Cash Flow for Sustaining and Reliability

Projects

Ex. # " " " " " " Interest Costs Calculation of Cash Flow


Projects ‐ Calculation of Cash Flow


Projects ‐ Calculation of Cash Flow


Projects ‐ Break Even Period/Requirement

CC‐10‐54

CC‐10‐55

CC‐10‐56

CC‐10‐57

CC‐10‐58

CC‐10‐59

CC‐10‐60

CC‐10‐61

CC‐10‐62

CC‐10‐63

CC‐10‐64

CC‐10‐65

CC‐10‐66

CC‐10‐67

CC‐10‐68

Ex. # " " " " " " Alternative Cash Flow Calculation

Ex. # " " " " " " Capital Expenditures in Calculation of Cash

Flow

Ex. # " " " " " " Cash Flow for Keeyask

Ex. # " " " " " " Need to improve equity level

Ex. # " " " " " " Forecast equity ratio

Ex. # " " " " " " Forecast cash flow surplus/deficit

Ex. # " " " " " " Comparison of net income from operations

Ex. # " " " " " " Economic outlook



Ex. # " " " " " " Long Term Interest Rates

Ex. # " " " " " " Bank of Canada interest rates

Ex. # " " " " " " Committed Resource assumptions

Ex. # " " " " " " Actual/forecast financial statements

2016/17

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Ex. # " " " " " " Other revenue

Ex. # " " " " " " Recent outlook for 2016/17 Other revenue

Ex. # " " " " " " IFRS vs CGAAP

Ex. # " " " " " " Water rentals

Ex. # " " " " " " Fuel and Power purchased costs

Ex. # " " " " " " Fuel and Power purchased costs

Ex. # " " " " " " Transmission charges

Ex. # " " " " " " Power purchased

Ex. # " " " " " " Capital taxes

Ex. # " " " " " " Other expense under CGAAP

Ex. # " " " " " " Other expense under CGAAP

Ex. # " " " " " " Projected financial statement

Ex. # " " " " " " Regulatory deferral accounts

Ex. # " " " " " " Long term debt and net debt values

Ex. # " " " " " " Weighted average interest rate

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Ex. # " " " " " " Export Revenue

Ex. # " " " " " " Mix of exports

Ex. # " " " " " " Export Revenue

Ex. # " " " " " " PUB MFR 83

Ex. # " " " " " " Average unit revenue/cost schedule

Ex. # " " " " " " Merchant purchases

Ex. # " " " " " " Additions to Regulatory deferral accounts

Ex. # " " " " " " Conawapa costs

Ex. # " " " " " " MIPUG MFR 5 ‐ IFF16 Updates

Ex. # " " " " " " Supply chain management initiatives

Ex. # " " " " " " Asset management strategies and supply

chain management initiatives

Ex. # " " " " " " EFT information

Ex. # " " " " " " EFT information

Ex. # " " " " " " Voluntary Departure Program

Ex. # " " " " " " External costs to the Boston Consulting

Group's engagement

Ex. # " " " " " " Hydro One's 2018‐2022 Distribution Rate

Application

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Ex. # " " " " " " Compensation paid to executives

Ex. # " " " " " " Hay Consulting

Ex. # " " " " " " Post 2018/19 Operating & Administative

Expense forecast

Ex. # " " " " " " Reserve margin

Ex. # " " " " " " Rate making objectives

Ex. # " " " " " " Maximum bill impacts

Ex. # " " " " " " Case equity scenario

Ex. # " " " " " " Energy poverty based on common use

Ex. # " " " " " " Logit regressions ‐ energy poverty

Ex. # " " " " " " Low income energy efficiency and

weatherization initiatives

Ex. # " " " " " " Neighbours Helping Neighbours

Ex. # " " " " " " Affordable Energy/Bill Affordability Advisory

Committee

Ex. # " " " " " " Equal Payment Plan

Ex. # " " " " " " Bill payment/matching program

Ex. # " " " " " " 2016/17 Annual Report ‐ Affordable Energy

Fund

Ex. # " " " " " " Affordable Energy Fund

Ex. # " " " " " " Residential Electric Heating customers

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Ex. # " " " " " " Conservation rates

Ex. # " " " " " " DSM Supplemental Report

Ex. # " " " " " " SCC Costs in evaluating DSM and other

resources program

Ex. # " " " " " " GS Small and Medium customers

Ex. # " " " " " " 150W LED rates

Ex. # " " " " " " Sentinel metered rates

Ex. # " " " " " " Limited Use of Billing Demand Report

Ex. # " " " " " " Depreciation

Ex. # " " " " " " Deferral Account

Ex. # " " " " " " Settlement Agreements

Ex. # " " " " " " Independent Benchmark

Ex. # " " " " " " Electric Business Operations Capital

Ex. # " " " " " " Annual Spending Forecast

Ex. # " " " " " " Forecast Capital Spending

Ex. # " " " " " " 20 year outlook of capital expenditures

Ex. # " " " " " " Business Operations capital spending 2018‐

2027

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Ex. # " " " " " " Diesel GS in Lac Brochet

Ex. # " " " " " " SAIDI and SAIFI forecasts

Ex. # " " " " " " UMS Group's engagement

Ex. # " " " " " " Decision‐making criteria for asset

replacement

Ex. # " " " " " " CIJ/CPJ ‐ Other investment

Ex. # " " " " " " Investment categories in Capital

Expenditures Table

Ex. # " " " " " " Business Operations capital targets

Ex. # " " " " " " Capital planning process and assumptions

Ex. # " " " " " " Business Operations Support capital

expenditures

Ex. # " " " " " " Capital spending related to system load

capacity

Ex. # " " " " " " System Load Capacity project

Ex. # " " " " " " Capacity & Growth project, with hot spots

Ex. # " " " " " " Growth in Number of Customers by Class

Ex. # " " " " " " status update on Kinectrics work

Ex. # " " " " " " Asset Condition Assessment Audit,

Kinectrics, May 12, 2016, for each asset

classEx. # " " " " " " MH Electrical Infrastructure Condition

Assessment Summary Report

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Ex. # " " " " " " Flagged for Auction Plan

Ex. # " " " " " " Rationale for replacement criteria

Ex. # " " " " " " Age Limiter defined by Age Limiter Curve

Ex. # " " " " " " Functional Failure curve

Ex. # " " " " " " Major System Renewal Projects

Ex. # " " " " " " Risk Assessment study, forced outages

Ex. # " " " " " " consequence costs will reduce with Bipole

III

Ex. # " " " " " "

Risk Assessment study, Pine Falls Units

Ex. # " " " " " " failure probability and impact Dorsey HVDC

Synchronous Condenser refurbishment

Ex. # " " " " " " safety and aging infrastructure conerns of

King Station

Ex. # " " " " " " Capital Planning assumption

Ex. # " " " " " " CIJ/CPJ all 2017‐2018 projects

Ex. # " " " " " " Portfolio Adjuestments for MH's capital

ependitures

Ex. # " " " " " " MH Assumptoin/expectation impact of

large scale asset replacement maintenace

costsEx. # " " " " " " Asset Management partices at MH

Ex. # " " " " " " UMS assessment for subcomponent within

ten AM domains

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Ex. # " " " " " " Policy, Strategy and Objectives Documents

Ex. # " " " " " " Asset Management competency level

Ex. # " " " " " " Asset Management Roadmap/Strategies

developed by the Business Unit

Ex. # " " " " " " Asset Management improvement plan

Ex. # " " " " " " Asset Management Practice

Ex. # " " " " " " portion of operating expenditures directed

at servicing

Ex. # " " " " " " MH capital planning, implementation and

cost allocation practices

Ex. # " " " " " " MH effects to optimize the allocatin of

labour force across planned capital

Ex. # " " " " " " MH decision‐making assumpotions

underlaying asset replacement strategies

Ex. # " " " " " " Consequence categories

Ex. # " " " " " " Asset Management planning assumptions

Ex. # " " " " " " Replacement capital budget and year of

replacment

Ex. # " " " " " " Slave Falls project Asset Management

planning assumptions

Ex. # " " " " " " planned schedule for HVDC BP2 Value Hall

Wall Bushing replacement

Ex. # " " " " " " Capital Budget planning assumptions

Ex. # " " " " " " Assumptions underlaying the model

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Ex. # " " " " " " RCM analysis to date

Ex. # " " " " " " Asset Investment Planning software

Ex. # " " " " " " Assess MH utilization of copperleaf

software for capital program planning

Ex. # " " " " " " MH capital budget planning assumptions

Ex. # " " " " " " Assess effectiveness and efficiency of MH

supply chain function

Ex. # " " " " " " Assess MH capital budget planning

assumptions

Ex. # " " " " " " Assess scope and nature of anticipated

changes to MH asset Management

practicesEx. # " " " " " " understand Asset Management objectives

Ex. # " " " " " " undestand current asset management

pratices

Ex. # " " " " " " Process of setting target level of capital

expenditures

Ex. # " " " " " " Population risk is forecasted

Ex. # " " " " " " Keeyask project full and complete analysis

and understanding

Ex. # " " " " " " review new revised costs/dates for Keeyask

project considered

Ex. # " " " " " " Keeyask Recovery Plan, improved

cost/schedule performance Keeyask

Gerneration ProjectEx. # " " " " " " Bipole III Reliability Project contact

management arrangement

Ex. # " " " " " " Bipole III project full and complete analysis

and understanding

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Ex. # " " " " " " Manitoba‐Minnesota Transmission Project

full and complete analysis and

understandingEx. # " " " " " " Saskatchewan commences in 2020/21

Ex. # " " " " " " unredacted version of latest CPJ/CIJ

Manitoba‐Saskatchewan Tranmission

Ex. # " " " " " " scope and nature of applicant's efforts to

justify re‐evaluate Keeyask and Bipole III

Ex. # " " " " " " planning processes BCG review

Ex. # " " " " " " role of ZOR in light of Order 164/16

Ex. # " " " " " " other factors considered besides results of

Cost of Service Study

Ex. # " " " " " " reconcile Compliance filing with Board

Order 164/16

Ex. # " " " " " " compliance filing Average Rate Base for Sub‐

Transmission

Ex. # " " " " " " Average Rate Base for Distribution has

increased slightly

Ex. # " " " " " " basis for allocating Common Costs

Ex. # " " " " " " test the appropriateness of allocator used

for EMS.SCDA portion Communications

Ex. # " " " " " " understanding basis for allocating common

costs


costs


costs

Ex. # " " " " " " understanding allocation factor used for

Net Export Revenue

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Ex. # " " " " " " clarify treatment of distribution service

costs

Ex. # " " " " " " undestand basis for Meter Investment

weighting factors

Ex. # " " " " " " Reconcile Revenue Requirement

components with cost categories used in

Cost of ServiceEx. # " " " " " " clarify appropriate starting point for

adjustments

Ex. # " " " " " " clarify the Revenue Reconciliation

adjustments included in Cost of Service

StudyEx. # " " " " " " clarify treatment of other Revenue

Ex. # " " " " " " clarify Treatment of Capital and other Taxes

Ex. # " " " " " " understand Cost of Service treatment of

Corporate Allocation

Ex. # " " " " " " understannd treatment of Net Movement

in Regulatory Deferrals

Ex. # " " " " " " complete COSS analysis and clarify

portential misunderstandings

Ex. # " " " " " " understand derivation of Operating Costs

used to functionalize Buildings, Gereral

Equipment and CommunicationsEx. # " " " " " " understand basis for sub‐functionalization

of costs

Ex. # " " " " " " understand basis for functionalization of

Communications and Control Systems costs

Ex. # " " " " " " understand how SEP costs are established

Ex. # " " " " " " determine how MH addressed issue of

MISO fees as noted in PUB's April 3, 2017

letterEx. # " " " " " " understand treatment of Wind and Water

Rental costs

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Ex. # " " " " " " understand the functionalization of

Common Costs

Ex. # " " " " " " determine MH response to Board's

Directives from Order 164/16

Ex. # " " " " " " understand Manitoba Hydro's

functionalization of facilities

Ex. # " " " " " " understand MH Functionalization of these

costs

Ex. # " " " " " " understand MH allocation of Customer

Service Costs

Ex. # " " " " " " Understand MH allocation of Services costs

Ex. # " " " " " " MH plans for future study

Ex. #

Ex. #

Ex. # " " " " " " 20 year information for MIPUG

Ex. # " " " " " " full raw output for 918 model

Ex. # " " " " " " Electric Operations Project Operating

statement 104 Water flow

Ex. # " " " " " " Electric Operations Project Operating

statement 102 Water flow

Ex. # " " " " " " calculations and modeling results if

domestic rates increases allowed from

2019/29Ex. # " " " " " " Electric Operations Projected Operating

Statement

Ex. # " " " " " " rate increase in every year after 2028/29

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Consumers Coalition to Business Council of Manitoba re Request for Information

on Proposed Evidence ‐ September 18, 2017

Consumers Coalition to Manitoba Hydro ‐ Round 2 Information Requests

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Ex. # " " " " " " Assuming climate change, affecting trent

and variability of streamflow over time

Ex. # " " " " " " price growth contributor to load growth

Ex. # " " " " " " reasonablity of residential forecast

Ex. # " " " " " " historical proportions of dwellings, by type

and area

Ex. # " " " " " " Energy prices used as inputs to load

forecast

Ex. # " " " " " " impacts in two sectors result one increasing

and other decreasing

Ex. # " " " " " " basis for impact of changes in

determiantion of PLIL

Ex. # " " " " " " clarify the impact of changes in approach to

determining PLIL

Ex. # " " " " " " understand basis for MH decision that

premium was not appropriate at this time

for long term planning purposesEx. # " " " " " " response to initial information request

Ex. # " " " " " " implication of not allowing balances to be

amortized

Ex. # " " " " " " understand implications of MH regulatory

accounting assumptions

Ex. # " " " " " " clarify financial forecasts used in response

Ex. # " " " " " " understand implications of Voluntary

Departure Program

Ex. # " " " " " " implication of actual capital spending in‐

service additions for 2016/17

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Ex. # " " " " " " understand consequences of approved Aug

1, 2017 interim rate increase

Ex. # " " " " " " calrify basis for cash clow calculation

Ex. # " " " " " " understand how forecast load requirements

used determining investment needs aligns

with overall load forecastEx. # " " " " " " clarify categories of customers used in

response

Ex. # " " " " " " clarify basis for deriving marginal costs and

portention variation by TOU

Ex. # " " " " " " Clarify relevant PCOSS18 results for use in

rate design

Ex. # " " " " " " undestand how items captured in Net

Movement are functionalized

Ex. # " " " " " " reconcile values reported in response

Ex. # " " " " " " understand change in treatment of

Buildings and General Equipment with

respect to DieselEx. # " " " " " " Clarify basis for tables presented in

response

Ex. # " " " " " " Clarify applicability of principle cited in

question to non‐TOU circumstances

Ex. # " " " " " " Clarify basis for transmission component of

marginal costs

Ex. # " " " " " " Clarify basis for distribution component of

marginal costs

Ex. # " " " " " " Clarify basis for labour allocator used in

PCOSS18

Ex. # " " " " " " Clarify basis for determination of System

Load Factor as used in PCOSS18

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Ex. # " " " " " " Clarify cash flow calculations provided in

response

Ex. # " " " " " " Understand financial implication of load

shifting due to TOU rates

Ex. # " " " " " " Clarify circumstances under MH oversees

work near eletric plant

Ex. # " " " " " " understand likelihood of risk indetified in

response

Ex. # " " " " " " update change in financial outlook from

MH14

Ex. # " " " " " " Treatment bolumes associated with

Merchant Sales

Ex. # " " " " " " scatter diagram with annual hydro bill

percentage of income

Ex. # " " " " " " basis for evaluating DSM and generation

resource options

Ex. # " " " " " " determine appropriateness of propsed

rates

Ex. # " " " " " " Clarify basis for results of benchmarking

study prepared in BCG

Ex. # " " " " " " change in forecast capital spending and in‐

service additions

Ex. # " " " " " " Business Operations Capital

Ex. # " " " " " " annual Business Operations Capital

spending for 2027/28 through 2033/34

Ex. # " " " " " " reconcile 2016/17 capital contribution

Ex. # " " " " " " Keeyask project not possible has Bipole III

not been committed to

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Ex. # " " " " " " basis for determining probability of failure

v. consequences of failure

Ex. # " " " " " " gain clarification on incremental evidence

provided by applicant

Ex. # " " " " " " clarify use of asset age in determining asset

replacement

Ex. # " " " " " " understand the effect of the re‐

prioritization process discussed in response

Ex. # " " " " " " clarification on incremental evidence


Ex. # " " " " " " Capital and Operating savings, forecast

savings

Ex. # " " " " " " incremental evidence provided by applicant

Ex. # " " " " " " increase/decrease spending outlook over

the years

Ex. # " " " " " " System Capacity Process

Ex. # " " " " " " Capacity Planning Process

Ex. # " " " " " " Incremental evidence provided by

Application CEMI/CELID

Ex. # " " " " " " further detail on incremental evidence


Ex. # " " " " " " Methodology used to estimate the portfolio

adjustment forecast values for the test year

Ex. # " " " " " " formal mandate, objectives, timelines and

milestones for division over following 3

yearsEx. # " " " " " " correspondence between MH and UMS

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Ex. # " " " " " " Summary Report on Current Maintenace

Plan

Ex. # " " " " " " itemized breakdown of Other category for

Pointe Du Bois Spillway and Riel 230/500 KV

StationEx. # " " " " " " MH attempted to quantify magnitude of

avoided costs

Ex. # " " " " " " Keeyask Project complete analysis and

understanding of project

Ex. # " " " " " " expect Keeyask Recovery Plan result in

improved cost/schedule performances for

Generation ProjectEx. # " " " " " " Bipole Project complete analysis and

understanding of project

Ex. # " " " " " " Gas Generation Service evaluated

alternative to Keeyask and Bipole III

Ex. # " " " " " " Major Project Business Unit associated with

Generation or Tranmission using MH SAP

Ex. # " " " " " " Other Revenue, Other Expenses and

Corporate Allocation are functionalized

Ex. # " " " " " " nature of direction or conclussion from the

PUB

Ex. # " " " " " " readily know which of the illustrative rates

would apply to them

Ex. # " " " " " " Residential Diesel customers considered

Basic Standard

Ex. # " " " " " " MH use of Eletric Heat Billed classification

Ex. # " " " " " " load profiles for Eletric Heat Billed and Non

Heat Billed customers

Ex. # " " " " " " why necessary to achieve revenue for class

as a whole

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Ex. # " " " " " " Electric Billed Customers and Non Heat

Billed Customers, of Figure 5

Ex. # " " " " " " Mertis of illustrative rate design set out by

MH

Ex. # " " " " " " Implications/Impact of removal of URA

from COSS Study on Residential rates

Ex. # " " " " " " basis for 2 % as increase energy charge for

Non Heat Billed customers

Ex. # " " " " " " need for COSS revisions

Ex. # " " " " " " how bills assigned to each of four seasons

for purposes of responding

Ex. # " " " " " " heating requirements vary across Manitoba


Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Consumers Coalition to PUB re Proposed Scope of Work for the Independent

Expert Consultants retained by the PUB ‐ September 22, 2017

Consumers Coalition response to Manitoba Hydro's September 7, 2017 CSI

Motion ‐ September 26, 2017

Appendices to Consumers Coalition CSI Motion response

Consumers Coalition re Revised Budget for Dr. Gotham ‐ September 26, 2017

Revised Budget and Workplan for Dr. Gotham ‐ Blackline

Revised Budget and Workplan for Dr. Gotham ‐ Clean

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Letter from Coalition dated October 31, 2017 re Filing of Consumers Coalition

Evidence

Review of Manitoba Hydro Financial Targets: Report to the Manitoba PUB ‐ by

Morrison Park Advisors (MPA)

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. # " " " " " " Definition of Low‐Income customers

Ex. # " " " " " " Peer‐Reviewed and Literature reviewed in

preparation of Mr. Raphal's evidence

Ex. # " " " " " " Consumer engagement conducts

preparation of Mr. Raphal's evidence

Ex. # " " " " " " elements considered in deciding bill

affordability measures

Ex. #

Ex. # " " " " " " Net Income

Ex. # " " " " " " Societal Cost Test, Total Resource Cost Test

Ex. # " " " " " " Class Load factors

Ex. # " " " " " " Annual Savings for customer

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The Effect of the Proposed Hydro Rate Increase on the Manitoba Economy ‐ by

Dr. Janice Compton and Dr. Wayne Simpson

Review of Manitoba Hydro's 2017/18 and 2018/19 GRA Sustainment Capital ‐ by

METSCO Energy Solutions Inc.

Manitoba Public Utilities Board: Manitoba Hydro's 2017/18 and 2018/19

General Rate Application ‐ by William Harper, Econalysis Consulting Services

Energy Poverty in Manitoba and the Impact of the Proposed Hydro Rate

Increase: An Assessment of the Bill Affordability Study in the Manitoba Hydro

GRA ‐ by Dr. Wayne Simpson

Consumers Coalition to AMC Information Requests

Coalition to GAC

Errata to Morrison Park Avidors Report

Ex. # " " " " " " LICO‐125 residential customers

Ex. # " " " " " " Customers Inclining rate structure applies

Ex. # " " " " " " Low‐income customers

Ex. # " " " " " " Peer‐Reviewed and Literature reviewed

Ex. # " " " " " " consumer engagement conducted in prep

of Mr. Chernick's tetimony

Ex. # " " " " " " Rate proposals

Ex. #

Ex. # " " " " " " LEI Evidence ‐ Macroeconomic Impact

Ex. #

Ex. # " " " " " " US and Saskatchewan utility supply

Ex. # " " " " " " DSM costs in IFF16 than in NFAT

Ex. # " " " " " " Hydro Uncertainty Analysis

Ex. #

Ex. #

Ex. # " " " " " " Conference Board of Canada report

CC‐25

CC‐26

CC‐27

CC‐27‐1

CC‐24

CC‐24‐1

CC‐25‐1

CC‐25‐2

CC‐25‐3

CC‐23‐5

CC‐23‐6

CC‐23‐7

CC‐23‐8

CC‐23‐9

CC‐23‐10

Coalition to GSS‐GSM‐KAP

Coalition to City of Winnipeg

Coalition to MIPUG

Letter to PUB dated November 16, 2017 re Responses to Irs on Intervener

Evidence (Coalition & MIPUG)

Ex. # " " " " " " Risk Analysis

Ex. # Coalition‐Daymank (export) Information Requests

Ex. # " " " " " " Mr Chernicks Assessment of US (MISO)

supply mix

Ex. # " " " " " " forecast and actual values, Export Price

Forecast

Ex. # " " " " " " on‐peak and off‐peak export prices

Ex. # " " " " " " key inputs into export energy price

forecast: Natural Gas, Carbon and Capacity

Ex. # " " " " " " MH market view and Consultants market

view

Ex. # " " " " " " MH adjustments

Ex. # " " " " " " IFF16 actual inflows

Ex. # " " " " " " export revenues determinted by average

revenues across inflow conditions

Ex. # " " " " " " appropriateness of preium for surples

dependable energy and capacity

Ex. # " " " " " " implications of findings regarding MHs

forecast export revenue

Ex. # " " " " " " extaprovincial revenue forecast

Ex. # " " " " " " implications on MH export price forecast

Ex. # " " " " " " reasonableness of assumption

CC‐28

CC‐27‐2

CC‐28‐1

CC‐28‐2

CC‐28‐3

CC‐28‐4

CC‐28‐5

CC‐28‐6

CC‐28‐7

CC‐28‐8

CC‐28‐9

CC‐28‐10

CC‐28‐11

CC‐28‐12

CC‐28‐13

Ex. # " " " " " " magnitude of significance on MH export

price forecast

Ex. # " " " " " " high and low price cases developed by

changing natural gas price

Ex. # Coalition‐Yatchew Information Requests

Ex. # " " " " " " Price Elasticities

Ex. # " " " " " " Measuring Energy poverty

Ex. # " " " " " " mechanism for assisting low income

households

Ex. # " " " " " " Economic Outlook‐ GDP

Ex. # " " " " " " Economic Outkook ‐ Exchange Rate

Ex. # " " " " " " Impact of Rate Increase

Ex. # " " " " " " lower rate increase

Ex. # " " " " " " electricity price increases in Ontario

affected rate of growth

Ex. # " " " " " " incorrectly estimated price elasticities

Ex. # Coalition‐Daymark (Load Forecast) Inforamtion Requests

Ex. # " " " " " " Price Elasticity, Accuracy of price elasticity

values

Ex. # " " " " " " Stochasitc Risk Assessment, Impact of

Multicollinearity on Stochiastic Risk

Assessment

CC‐30‐1

CC‐30‐2

CC‐29

CC‐30

CC‐29‐9

CC‐28‐14

CC‐28‐15

CC‐29‐1

CC‐29‐2

CC‐29‐3

CC‐29‐4

CC‐29‐5

CC‐29‐6

CC‐29‐7

CC‐29‐8

Ex. # " " " " " " Statistical concerns in models, MH testing

for statistical concerns

Ex. # " " " " " " Multicollinearity, Impact of Variance

Inflation Factors

Ex. # " " " " " " Definition of 50/50 Forecast

Ex. # " " " " " " Forecasting top consumers, Implication of

approach to forecasting

Ex. # " " " " " " Population trends, Under‐forecasting

population trends

Ex. # " " " " " " Load Forecast to high or low

Ex. # " " " " " " Growth Rate in Load Forecast

Ex. # " " " " " " Average use forecast

Ex. # " " " " " " Customers excluded from PLIL analysis

Ex. # " " " " " " 2014 Methodologu based on MH current

electricty price forecast

Ex. # " " " " " " upward or downward trends, transmission

and distribution loss

Ex. # " " " " " " DSM program savings

Ex. # " " " " " " weather tempature

Ex. # " " " " " " differences between 2014 and 2017

forecasts

Ex. # " " " " " " historicial average use

CC‐30‐3

CC‐30‐4

CC‐30‐5

CC‐30‐6

CC‐30‐16

CC‐30‐17

CC‐30‐7

CC‐30‐8

CC‐30‐9

CC‐30‐10

CC‐30‐11

CC‐30‐12

CC‐30‐13

CC‐30‐14

CC‐30‐15

Ex. # " " " " " " DSM savings are adjusted via PLIL Model for

Top Customer category

Ex. # Opening Statement

Ex. # Book of Documents ‐ Sustaining Capital

Ex. # Book of Documents ‐ Revenue Requirement Panel

Ex. # Book of Documents ‐ COSS and Rate Design and Bill Affordability Panel

Ex. # " " " " " " Energy Poverty Figures

Ex. # Coalition‐MGF ‐ Information Requests

Ex. # " " " " " " Overall Keeyask Project Management

Ex. # " " " " " " Keeyask Project Cost Overrun ‐GCC

Ex. # " " " " " " Keeyask Project Cost Overrun ‐ Generating

Station

Ex. # " " " " " " Keeyask Project Cost Estimating

Ex. # " " " " " " Keeyask Estimate Adjustments

Ex. # " " " " " " Keeyask Basis of Schedule

Ex. # " " " " " " Keeyask Schedule Baseline

Ex. # " " " " " " Keeyask ‐BBE Schedule Negatice Float

CC‐32‐2

CC‐31

CC‐33

CC‐32‐1

CC‐32‐3

CC‐32‐3‐1

CC‐33‐1

CC‐33‐2

CC‐33‐3

CC‐33‐4

CC‐33‐5

CC‐30‐18

CC‐33‐6

CC‐33‐7

CC‐33‐8

Ex. # " " " " " " Keeyask ‐ BBE Forecast Completion Date

Ex. # " " " " " " Keeyask Contract Management

Ex. # " " " " " " Keeyask Craft to Foreman Ratio

Ex. # " " " " " " Keeyask Board Recommendation

Ex. # " " " " " " Keeyask Estimated Final Cost Range

Ex. # " " " " " " Keeyask Cost Contingency

Ex. # " " " " " " Keeyask Concrete Quantity and Earthwork

fill Reporting

Ex. # " " " " " " Keeyask Contruction ‐ Various Items

Ex. # " " " " " " HVDC Converter Stations ‐ Risk

Management

Ex. # " " " " " " Bipole III Transmission Line Risk Register

Ex. # " " " " " " Bipole III Transmission Line ‐ Rokstad Power

Company Schedule

Ex. # Coalition Letter to PUB re Public Presentations dated December 22, 2017

Ex. # Chart of Rate Increases and Bill Impact

Ex. # Comsumers Coalition to MGF (KCB) Information Requests

Ex. # " " " " " " CC‐33‐3

CC‐34

CC‐35

CC‐36

CC‐33‐12

CC‐33‐14

CC‐33‐13

CC‐33‐18

CC‐33‐19

CC‐36‐1

CC‐33‐9

CC‐33‐10

CC‐33‐11

CC‐33‐15

CC‐33‐16

CC‐33‐17

Ex. # Load Forecasting In Electric Utiltiy Integrated Resource Planning

Ex. # What are the Effects of Muticollinearity and when can I Ignore them Article

Ex. # NERC ‐ Long Term Reliability Asssessment

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

MMTP ‐ NEP Application

Correction to Mr. Bill Harper (Ecoalysis) Testimony

British Columbia DSM Regulations

CC‐37

CC‐38

CC‐39

CC‐40

CC‐41

CC‐42

CC‐43

CC‐44

CC‐45

CC‐46

CC‐47

CC‐48

CC‐49

CC‐45‐1

CC‐50

Debt Ratios Calculation ‐ from MPA Presentation

London Economics ‐ Ontario Power Report

US Energy Information Administration ‐ Assumptions to the Annual Energy

Outlook 2017

US Federal Energy Regulatory Commission Decision

Alberta's Renewable Electricity Program

Presentation of Dr. Compton and Dr. Simpson ‐ Rate Impacts on Manitoba

Economy

Presentation of Dr. Simpson ‐ Rate Increases and Energy Poverty

Presentation of Morrison Park Advisors (MPA)

William Harper of Econalysis Presentation

Ex. #

Ex. #

Ex. # Comsumers Coalition letter to all parties re Legal Argument ‐ January 29, 2018

Ex. # Consumers Coalition Closing Submission Presentation

Ex. # Book of References for Closing Submissions

Ex. # Legal Sources

CC‐53

CC‐54

CC‐55

CC‐56

METSCO Presentation

CC‐51

CC‐52

Consumers Coalition Undertaking 51‐ of Janice Compton and Wayne Simpson

CITY OF WINNIPEG (CoW) Exhibits

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

EXHIBIT LIST FOR

MANITOBA HYDRO


February 16, 2018

CoW‐1 Email from the City of Winnipeg dated April 7, 2017 re Manitoba Hydro's

Intentions in Respect of 2017 Rate Application

Report by the City of Winnipeg ‐ October 31, 2017CoW‐2

CoW‐3

CoW‐4

CoW‐5 City of Winnipeg Closing Submissions Presentation

Tyler Markowsky Presentation on behalf of City of Winnipeg

City of Winnipeg Undertakings 66‐68

GREEN ACTION CENTRE (GAC) Exhibits

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. # " " " " " " Bill Frequency for residential class

Ex. # " " " " " " Average Bill for residential customer

by moth, tariff subclass past 5 years

GAC‐7‐1

GAC‐7‐2

GAC‐3‐1 Attachment to GAC letter dated May 26, 2017

EXHIBIT LIST FOR

MANITOBA HYDRO


February 16, 2018

GAC‐1 Green Action Centre letter dated April 7, 2017 re Scope of Proposed 2017

General Rate Application

Green Action Centre to Manitoba Hydro ‐ Round 1 Information Requests

GAC‐2

GAC‐3

GAC‐4

GAC‐5

GAC‐6

GAC‐7

GAC's Minimum Filing Requirements (MFRs)

GAC Position on Interim Rate Increase dated May 26, 2017

Interim Rate Request Submission ‐ July 18, 2017

Green Action Centre to PUB re Budget Submission dated July 14, 2017

GAC's response to Coalition's letter re Cost of Service Model

GAC‐5‐1

GAC‐5‐2

GCH Budget

Budget RII Estimate

Ex. # " " " " " " Basic, Low‐income, non‐low‐income

customers with and without electric

heat

Ex. # " " " " " " Domestic and Export Revenue,

Forecast and Actual

Ex. # " " " " " " Billing demand by month for each rate

year

Ex. # " " " " " " Proofs of Revenue

Ex. # " " " " " " Number of billing units assumed,

source, total revenue and any

adjustments

Ex. # " " " " " " Number of test year billing Units

Ex. # " " " " " " Bill Comparision

Ex. # " " " " " " Domestic Rate Clas, demand, energy,

customer and other charges under

existing and propsed rates

Ex. # " " " " " " Analysis of Seasonal Variation in

Marginal Costs

Ex. # " " " " " " Seasonally‐differentiated rates for

Resdidential and General Service no‐

demand rates

Ex. # " " " " " " Seasonally‐differentiated rates for

Gereral Service Small and Medium

demand rates

Ex. # " " " " " " demand‐related costs in peak period

energy charge rather than demand

charge

Ex. # " " " " " " metering in place by class

Ex. # " " " " " " Plan for upgrading metering by class

GAC‐7‐10

GAC‐7‐11

GAC‐7‐12

GAC‐7‐13

GAC‐7‐14

GAC‐7‐15

GAC‐7‐16

GAC‐7‐3

GAC‐7‐4

GAC‐7‐5

GAC‐7‐6

GAC‐7‐7

GAC‐7‐8

GAC‐7‐9

Ex. # " " " " " " Appendix 8.4‐8.7

Ex. # " " " " " " explain common bus total energy is

greater than sum of class total energy

Ex. # " " " " " " basis for the selection of time periods

Ex. # " " " " " " estimate of each component of the

avoided cost used to screen DSM

programs

Ex. # " " " " " " Derivation of the avoided costs used

to screen DSM programs

Ex. # " " " " " " avoided distribution costs in its Power

Smart cost effective metrics

Ex. # " " " " " " Value to avoided T&D used by MH for

screening DSM at any time since

January 2010

Ex. # " " " " " " MH Current estimates of avoided T&D

costs and basis of the estimates

Ex. # " " " " " " Distribution planning Guidelines

Ex. # " " " " " " Percentage of Transmission,

subtransmission and distributoin plant

that is drive by customer's individual

Ex. # " " " " " " Marginal cost study

Ex. # " " " " " " SEP prices aggregated by season and

time of period for the past 5 years

Ex. # " " " " " " Estimate of Marginal Energy Costs by

season and time period

Ex. # " " " " " " Derivation the marginal energy cost

estimates

GAC‐7‐28

GAC‐7‐29

GAC‐7‐30

GAC‐7‐19

GAC‐7‐20

GAC‐7‐21

GAC‐7‐22

GAC‐7‐23

GAC‐7‐24

GAC‐7‐25

GAC‐7‐26

GAC‐7‐27

GAC‐7‐17

GAC‐7‐18

Ex. # " " " " " " Current forecast of average hourly

export price by season and time

period

Ex. # " " " " " " Prices for firm export sales under each

existing MH contact

Ex. # " " " " " " Prices negotiation with Wisconsin

Public Service, Minnesota Power and

any other extra‐provincial

Ex. # " " " " " " Derivation of estimate of marginal

generation cost

Ex. # " " " " " " Estimate of marginal Geratio cost

Ex. # " " " " " " Projected annual revenue

requirements of Keeyask Project and

assumptions and calculations

Ex. # " " " " " " Estimate of costs per kW.h for power

supply from Keeyask

Ex. # " " " " " " Keeyask Project cost‐effective

Ex. # " " " " " " Derivation of Company's estimates of

marginal T&D costs

Ex. # " " " " " " Fixed and Variable O&M cost

estimates included in marginal T&D

cost estimates

Ex. # " " " " " " Demand and energy loss factors

applied to generation, tramission and

distribution marginal cost

Ex. # " " " " " " Justification for each system load

capactity tranmission or distribution

project

Ex. # " " " " " " Description of Project and explanation

of justification

Ex. # " " " " " " categories of projects included in

Customer Connections‐Residential

Commercial & Industrial

GAC‐7‐37

GAC‐7‐38

GAC‐7‐39

GAC‐7‐40

GAC‐7‐41

GAC‐7‐42

GAC‐7‐43

GAC‐7‐44

GAC‐7‐31

GAC‐7‐32

GAC‐7‐33

GAC‐7‐34

GAC‐7‐35

GAC‐7‐36

Ex. # " " " " " " Estimate of portion of ependitures on

Customer Connetions‐Residential,

Commerical & Industrial yearly

Ex. # " " " " " " Nature of Portfolio Adjustments

Ex. # " " " " " " Justification documents for each

project

Ex. # " " " " " " Purpose of expenditure of each

project

Ex. # " " " " " " Cause of reliability problem

Ex. # " " " " " " Table 2.2.1.1 System Load Capacity

Ex. # " " " " " " Revisions directed by Board in Order

164//16 not reflected in updated

PCOSS14 or PCOSS18

Ex. # " " " " " " Modifications made to PCOSS14 and

PCOSS18 not explained in Tab 8

Ex. # " " " " " " Why is PCOSS18 referred to as

Rudimentary

Ex. # " " " " " " MH Modification listed, supporting

work

Ex. # " " " " " " PCOSS14 Reflecting Order

Ex. # " " " " " " Revision of labour allocator to reflect

refunctionalization of Gerneration

Outlet Transmission

Ex. # " " " " " " Eliminated assignment of NEB fees to

export

Ex. # " " " " " " AEF assigned to exports why decresed

Ex. # " " " " " " Assignment of Water Rental and

variable O&D to exports

GAC‐7‐55

GAC‐7‐56

GAC‐7‐57

GAC‐7‐58

GAC‐7‐59

GAC‐7‐46

GAC‐7‐47

GAC‐7‐48

GAC‐7‐49

GAC‐7‐50

GAC‐7‐51

GAC‐7‐52

GAC‐7‐53

GAC‐7‐54

GAC‐7‐45

Ex. # " " " " " " Calculation work of System Load

Factor in PCOSS14 and PCOSS18

Ex. # " " " " " " Basis of updated Operating and

Depreciation reflect additional

Generation Outlet Transmission

Ex. # " " " " " " How MH updated Gernation pool

costs for classified on SLF, and cost

classified as 100% Energy

Ex. # " " " " " " How MH updated Tranmission costs

for 100% Demand, and US interface

costs calssified on SLF

Ex. # " " " " " " Adjustment to C10 cost directly

assigned to GSL 30‐100 classes

Ex. # " " " " " " Functionalization of additional

Generation Outlet Tranmission

Ex. # " " " " " " Functionalization of additional

Generation Outlet Tranmission

Ex. # " " " " " " Revision of Revenue to include

forecast Late Payment & Adjustment

revenue allocated based on actual

Ex. # " " " " " " Basis of customer weights

Ex. # " " " " " " Basis of multi‐family adjustment to

C27 Service Drop allocator

Ex. # " " " " " " PCOSS18 changes

Ex. # " " " " " " Modification to inputs and

methodology reflected in PCOSS18

but not in the updated PCOSS14

Ex. #

Ex. #

Ex. # " " " " " " Number of Bills by month of LICO 125

customers

GAC‐9‐1

GAC‐7‐64

GAC‐7‐65

GAC‐7‐66

GAC‐7‐67

GAC‐7‐68

GAC‐7‐69

GAC‐7‐70

GAC‐7‐71

GAC‐7‐60

GAC‐7‐61

GAC‐7‐62

GAC‐7‐63

Green Action Centre to Manitoba Hydro ‐ Round 2 Information RequestsGAC‐9

Green Action Centre letter re Rate Design for Affordability ‐ July 31, 2017GAC‐8

Ex. # " " " " " " Description of Survey sample as

requested

Ex. # " " " " " " Average Bill size in kW.h residential

customers by month

Ex. # " " " " " " Sample of Estimated total LICO‐125

customers

Ex. # " " " " " " 2017 System Load Forecast

Ex. # " " " " " " Historical Load Factor Data

Ex. # " " " " " " Proof of Revenue

Ex. # " " " " " " Mariginal Generation Capacity Cost

Ex. # " " " " " " Common Bus Total Energy

Ex. # " " " " " " Calculation of customer class total

energy for common bus total energy

Ex. # " " " " " " Changes in planned expenditures and

calcautaion of avoided transmission

costEx. # " " " " " " Derivation of Company's 2010

estimate of avoided tranmission cost

Ex. # " " " " " " MH estimates of avoided T&D

Ex. # " " " " " " Transmission, subtransmission and

distribution plant capacity, other than

service dropsEx. # " " " " " " non fuel O&M cost reflected in

estimate of merginal generation

capacity cost per kW yrEx. # " " " " " " benefirs of Keeyask project equal or

exceed total revenue requirements

Ex. # " " " " " " estimates of marginal T&D cost

Ex. # " " " " " " Study Reports SPD2010/02 and SPD

04/05

GAC‐9‐10

GAC‐9‐11

GAC‐9‐12

GAC‐9‐13

GAC‐9‐14

GAC‐9‐15

GAC‐9‐16

GAC‐9‐17

GAC‐9‐18

GAC‐9‐2

GAC‐9‐3

GAC‐9‐4

GAC‐9‐5

GAC‐9‐6

GAC‐9‐7

GAC‐9‐8

GAC‐9‐9

Ex. # " " " " " " Growth‐related expenditures

Ex. # " " " " " " Marginal Transmission cost

Ex. # " " " " " " decommissioning would be needed if

there were no load growth in Stanley

areaEx. # " " " " " " Marginal distribution cost

Ex. # " " " " " " Demand and energy loss factors

applied to derive marginal gernation

costEx. # " " " " " " marginal generation cost component

includes 14% loss factor

Ex. # " " " " " " Calcultions of Illustrative rates

Ex. # " " " " " " Illustrative Proof of Revenue

Ex. # " " " " " " Concerns about customer confusion

would be resolved

Ex. # " " " " " " Bill Affordability Working Group

criterea not part of rationale

Ex. # " " " " " " Revenue shift from all‐electirc to

standard customers

Ex. #

Ex. #

Ex. #

Ex. # " " " " " Export and Client

Ex. # " " " " " Expert concerns

Ex. # " " " " " Expert view on Fairness and Equity

GAC‐9‐28

GAC‐9‐29

GAC‐9‐19

GAC‐9‐20

GAC‐9‐21

GAC‐9‐22

GAC‐9‐23

GAC‐9‐24

GAC‐9‐25

GAC‐9‐26

GAC‐9‐27

GAC to Coalition (Harper)

GAC‐11

GAC's position re Manitoba Hydro's CSI Motion ‐ September 27, 2017

Direct Testimony of Paul Chernick on behalf of Green Action Centre

GAC‐10

GAC‐12

GAC‐12‐1

GAC‐12‐2

GAC‐12‐3

Ex. #

Ex. # " " " " " Basis of assertion

Ex. # " " " " " Bowman basis of assertion

Ex. # " " " " " Coal generation

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

GAC‐13

GAC‐14

GAC‐15

GAC‐18 GAC letter to all parties re Legal Argument ‐ January 29, 2018

GAC‐16 Space Heating Annual Operating Cost Comparison Chart

GAC to MIPUG

Green Action Centre Book of Documents

GAC‐19

GAC‐17 Oral Evidence of Paul Chernick

GAC Undertaking 40 ‐ Transmission and Distribution Costs

GAC‐21 GAC Undertaking 41‐ Northern Allowance

GAC‐25 Green Action Centre Final Argument

GAC‐26 Green Action Centre Closing Submissions

GAC‐13‐1

GAC‐13‐2

GAC‐13‐3

Opening Statement

GAC‐22 GAC Undertaking 42 ‐ PUB/GAC 6(a) Response

GAC Undertaking 39 ‐ Electric Space Heating for on‐reserve customers

GAC‐23 GAC Undertaking 43 ‐ Cost Impact of Rate Design Proposal for on‐reserve


GAC‐24 GAC Undertking 44 ‐ Rate Design if on‐reserve customers eligible for low‐

income rates

GAC‐20

General Service Small Customers and General Service Medium Customer Classes (GSS/GSM)

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. # " " " " " " Utilization rates of Bipole I and II over

the past 5 years

Ex. # " " " " " " export contacts taken place absence

of Bipole III

Ex. # " " " " " " breakdown of cost on Keeyask

Ex. # " " " " " " Breakdown of Cancellation cost

estimate

EXHIBIT LIST FOR

MANITOBA HYDRO


February 16, 2018

GSS/GSM‐1 Submission on Interim Rate Request Application

GSS/GSM‐3

GSS/GSM‐4

GSS/GSM‐4‐1

GSS/GSM‐4‐2

GSS/GSM‐4‐3

GSS/GSM‐4‐4

GSS/GSM‐2

Email re MH's Comments on Intervener Budgets ‐ July 26, 2017

Letter to PUB re Budget dated July 14, 2017

GSS/GSM‐2‐1 London Economics International LLC (LEI) Proposed Budget

GSS/GSM‐2‐2 AJ Goulding ‐ Curriculum Vitae

General Service Small/General Service Medium to Manitoba Hydro ‐ Round

1 Information Requests

Ex. # " " " " " " BCG Bipole III, Keeyask and Tie‐Line

summed demand growth

Ex. # " " " " " " Bipole III, Keeyask and Tie‐Line

aggregate basis instead of individually

Ex. # " " " " " " Variable hyraulic operateion and

matintenance costs

Ex. # " " " " " " Assigned export costs

Ex. # " " " " " " RCC schedule for all customer classes

after each class NER revenue

deducted from total

Ex. #

Ex. #

Ex. #

Ex. #

Ex. # " " " " " " Impact of Bipole III on Bipole I and

Bipole II levels of utilization

Ex. # " " " " " " Nature of costs included in Other

Gernerating Station costs

Ex. # " " " " " " Cost of each cancellation cost item

Ex. #

Ex. #

GSS/GSM‐8‐1

GSS/GSM‐8‐2

GSS/GSM‐8‐3

GSS/GSM‐9 Review of Manitoba Hydro's General Rate Application on behalf of the

Small and Medium General Service Customer Classes and Keystone

Agricultural Producers by London Economics

GSS/GSM‐8

GSS/GSM‐5

GSS/GSM‐6

GSS/GSM‐7

GSS/GSM‐4‐9

GSS/GSM‐4‐5

GSS/GSM‐4‐6

GSS/GSM‐4‐7

GSS/GSM‐4‐8

General Service Small/General Service Medium to Manitoba Hydro ‐ Round

2 Information Requests

GSS/GSM Letter re Combined Intervention with KAP ‐ letter dated August

22, 2017

GSS/GSM Revised Budget for London Economics International ‐ September

6, 2017

GSS/GSM Legal Budget ‐ September 7, 2017

GSS/GSM‐9‐1 London Economics International‐ Letter Summary of Errata

Ex. #

Ex. #

Ex. # " " " " " " Effects of Propsed Hydro Rate

Increase on Economy

Ex. #

Ex. # " " " " " " DSM Recommendations and TOU

Ex. #

Ex. # " " " " " " debt service coverage

Ex. # " " " " " " interest rates and export prices

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. # GSS/GSM‐18

London Economics International Presentation

GSS/GSM‐15

GSS/GSM‐10

GSS/GSM‐11

GSS/GSM‐12

GSS/GSM‐13

GSS/GSM‐14 GSS Letter to all parties re Legal Argument ‐ January 29, 2018

LEI Undertaking 72 ‐ Hydro Values re‐calculated from LEI Report

GSS/GSM‐16

GSS/GSM‐17

Supplementary Book of Documents

January 26th Transcript Corrections

GSS/GSM Book of Documents

GSS/GSM‐12‐1

GSS/GSM‐12‐2

GSS‐GSM to Coalition

GSS‐GSM to MIPUG

GSS‐GSM to Coalition (MPA)

GSS/GSM‐10‐1

GSS/GSM‐11‐1

GSS/GSM‐9‐2 London Economics International Report with Errata

Keystone Agricultural Producers (KAP) Exhibits

Ex. #

Ex. #

Ex. #

EXHIBIT LIST FOR

MANITOBA HYDRO


February 16, 2018

KAP‐1 KAP Budget Submission dated July 14, 2017

Attachment ‐ Draft Budget

KAP‐2

Interim Rate Request Submission dated July 14, 2017

KAP‐1‐1

MANITOBA INDUSTRIAL POWER USERS GROUP (MIPUG)

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. # " " " " " " Model scenario for Keeyask costs

Ex. # " " " " " " Financial forecasts to recover to target

level over 20 year period

MIPUG to Manitoba Hydro ‐ Round 1 Information RequestsMIPUG‐7

EXHIBIT LIST FOR

MANITOBA HYDRO


February 16, 2018

MIPUG‐1 MIPUG's Minimum Filing Requirements

MIPUG‐2‐1 Attachment 1 to MIPUG's letter dated May 25, 2017

MIPUG‐7‐1

MIPUG‐7‐2

MIPUG's Interim Rate Response letter dated May 25, 2017

MIPUG‐3 MIPUG Budget Submission

MIPUG‐4

MIPUG‐5

MIPUG‐6

Submission on Interim Rate Request dated July 14, 2017

2017/18 Interim Rate Supporting Materials ‐ July 18, 2017 Presentation

MIPUG's response to Manitoba Hydro's comments on Budgets ‐ July 25,

2017

MIPUG‐2

Ex. # " " " " " " Export Price and Interest Rate

Probabilities

Ex. # " " " " " " RCC Range History

Ex. # " " " " " " Time of Use rates for industrial

customers

Ex. # " " " " " " Efficienct Manitoba Act ‐ net

Movement in Regulatory Deferral

AccountsEx. # " " " " " " Total Debt

Ex. # " " " " " " S&P rating methodology financial risk

Ex. # " " " " " " breakdown of increase in financial

expense between 2014/15 and

2016/17Ex. # " " " " " " Long‐term dependable forecast prices

Ex. # " " " " " " Reconciliation of Revenue

Ex. # " " " " " " PCOSS14 Compliance filing without

deducting Net Export Revenue (NER)

Ex. # " " " " " " Chart back to actual results to

1986/87

Ex. # " " " " " " Calculations for Interest Allocated to

Construction by year

Ex. # " " " " " " Credit rating agencies in rating reports

and recommendations

Ex. # " " " " " " extend to show 20 year financial

forecast

Ex. # " " " " " " CV's for HM Staff

Ex. # " " " " " " 5 year and 7 year drought impacts for

MH16

MIPUG‐7‐7

MIPUG‐7‐8

MIPUG‐7‐9

MIPUG‐7‐10

MIPUG‐7‐11

MIPUG‐7‐12

MIPUG‐7‐13

MIPUG‐7‐14

MIPUG‐7‐15

MIPUG‐7‐3

MIPUG‐7‐4

MIPUG‐7‐5

MIPUG‐7‐6

MIPUG‐7‐16

MIPUG‐7‐17

MIPUG‐7‐18

Ex. # " " " " " " Extended Table for forecast years

Ex. # " " " " " " cash flow requirements regarding

further borrowing and debt

management plansEx. # " " " " " " compare 2016‐2017 Load Forecast

Ex. # " " " " " " 20 year financial forecast schedule for

MH16

Ex. # " " " " " " schedule of rate increases to target

customer class TCC

Ex. #

Ex. #

Ex. # " " " " " " Interm rate Increases, annual values

Ex. # " " " " " " Retaining earnings needed to achieve

target specified targeted date

Ex. # " " " " " " Figure 3‐1 from Appendix 4.1 updated

Ex. # " " " " " " DBRS Retained Earnings as mesaure of

equity, AOCI effectively not included

as offsetEx. # " " " " " " GSL 30‐11kV and GSL>100kV revenue

forecase for 2017/18 and 2018/19

Ex. # " " " " " " Calculates Marginal Costs

Ex. # " " " " " " Additions of regulatory deferral

accounts for loss on disposal of assets

Ex. # " " " " " " Breakdowns of Allocation, Customer

Class share for non energy revenue

Ex. # " " " " " " Interest rate used for Keeyask

borrowings

Ex. # " " " " " " Deferred overheasd blance by year to

Major New Generation and

Transmission v Capital Projects

MIPUG‐7‐19

MIPUG‐9‐9

MIPUG‐9‐10

MIPUG re Scope of Work for Independent Expert Consultants ‐ August 9,

2017

MIPUG‐7‐20

MIPUG‐7‐21

MIPUG‐7‐22

MIPUG‐7‐23

MIPUG to Manitoba Hydro ‐ Round 2 Information RequestsMIPUG‐9

MIPUG‐9‐1

MIPUG‐9‐2

MIPUG‐9‐3

MIPUG‐9‐4

MIPUG‐9‐5

MIPUG‐9‐6

MIPUG‐8

MIPUG‐9‐7

MIPUG‐9‐8

Ex. # " " " " " " Supplemental Filing Loss on Disposal

of Assets

Ex. # " " " " " " DSM Deferral

Ex. # " " " " " " Evaluate proposed ELG Amortixation

Approach

Ex. # " " " " " " Gains on disposal and on retirement

Ex. # " " " " " " change to ELG, and net effects of higer

cost

Ex. # " " " " " " amortization of ELG/ASL difference

Ex. # " " " " " " Financial Structure and Regulatory

framework

Ex. # " " " " " " offset to cost and cost impacts of

Bipole III

Ex. # " " " " " " Weighted Average Term to Maturity

Ex. # " " " " " " Considerated Borrowing requirements

& Maturity Schedule

Ex. # " " " " " " Contact Centre ‐ Outages and

Marketing R&D use and importance

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

MIPUG re Scope of Work for Independent Expert Consultants ‐ Daymark

Consultants ‐ September 21, 2017

MIPUG to Business Council of Manitoba re Issues and Proposed Evidence ‐

September 21, 2017

MIPUG response to Manitoba Hydro's September 7, 2017 CSI Motion ‐

September 27, 2017 and October 4, 2017

Prefiled Testimony of Patrick Bowman

Prefiled Testimony of Cameron Osler and Gerry Forrest

Supplementary Background Papers

MIPUG‐9‐11

MIPUG‐9‐12

MIPUG‐9‐13

MIPUG‐9‐14

MIPUG‐9‐15

MIPUG‐9‐16

MIPUG‐9‐17

MIPUG‐9‐18

MIPUG‐9‐19

MIPUG‐9‐20

MIPUG‐9‐21

MIPUG‐10

MIPUG‐11

MIPUG‐12

MIPUG‐13

MIPUG‐14

MIPUG‐15

Ex. #

" " " " " " Shortfall arising from Low Income

Program

Ex. #

" " " " " " Carbon Pricing

Ex. #

" " " " " " improving regulatory review of Capital

Plan

Ex. #

" " " " " " Marginal Cost Estimates, weaknesses

Ex. #

Ex. # " " " " " " Base load forecast and Price Elasticity

Ex. #

Ex. # " " " " " " Effect of Proposed Hydro Rate

Increase on Manitoba Economy

Ex. # " " " " " " Impact on Industry

Ex. # " " " " " " Provincial electricity demand

Ex. # " " " " " " Economic Impact ‐ taxes

Ex. #

Ex. #

MIPUG to AMC Information Request

MIPUG to Coalition (Simpson) Information Request

MIPUG to Coalition (Harper) Information Request

MIPUG to GAC Information Request

MIPUG to Daymark (Load Forecast) Information Request

MIPUG to Dr. Adonis Yatchew Inforamtion Request

Opening Statement

MIPUG Book of Documents 1 ‐ Policy Panel

MIPUG‐16

MIPUG‐17

MIPUG‐18

MIPUG‐19

MIPUG‐20

MIPUG‐21

MIPUG‐22

MIPUG‐23‐1

MIPUG‐16‐1

MIPIUG‐20‐1

MIPUG‐21‐1

MIPUG‐21‐2

MIPUG‐21‐3

MIPUG‐21‐4

Ex. #

Ex. #

Ex. #

Ex. # " " " " " " General MGF Report

Ex. # " " " " " " General Prudence

Ex. # " " " " " " Executive Summary ‐GCC

Ex. # " " " " " " Cost Estimates

Ex. #

Ex. # " " " " " " MIPUG‐25‐2

Ex. # " " " " " " MIPUG‐25‐3

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

MIPUG to MGF ‐ Information Requests

MIPUG to MGF (KCB) Information Requests

MIPUG Presentation ‐ Patrick Bowman, Cam Osler and Gerry Forest

Reference Documents for MIPUG Presentation

MIPUG to all parties re Legal Argument ‐ January 29, 2018

2013 Electirc Load Forecast

MIPUG Undertaking 65 ‐ Water Rentals

MIPUG‐24

MIPUG‐25

MIPUG‐26

MIPUG‐27

MIPUG‐28

MIPUG‐29

MIPUG‐30

MIPUG‐31

MIPUG‐32

MIPUG‐23‐2 MIPUG Book of Documents 2 ‐ Revenue Requirement Panel

Figures for Cross of MH Rebuttal ‐ for Identification

MIPUG‐23‐3 MIPUG Book of Documents 3 ‐ Rate Design and COSS Panel

MIPIG ‐24 ‐1

MIPIG ‐24 ‐2

MIPIG ‐24 ‐3

MIPIG ‐24 ‐4

MIPUG‐25‐1

MIPUG‐25‐2

MIPUG Undertaking Transcript Page 6469‐6470 ‐ Unit Costs Hdyro

Domestic System

Ex. # Final Argument with AttachmentsMIPUG‐33

MANITOBA KEEWATINOWI OKIMAKANAK (MKO)

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. # " " " " " " MKO FN communities Customer

Accounts

Ex. # " " " " " " Number of low‐income customers

Ex. # " " " " " " Residential Customer accounts

Ex. # " " " " " " Removal of Mirigation cot from rates

Ex. # " " " " " " Natural Gas Services

Ex. # " " " " " " filing next Diesel Community rate

Application

Ex. # " " " " " " DSM program in MKO

MKO ‐2 MKO's Submission on Interim Rates dated May 26, 2017

MKO‐5‐1

MKO‐5‐2

MKO‐5‐3

MKO‐5‐4

MKO‐5‐5

MKO‐5‐6

MKO‐5‐7

MKO ‐3 MKO Comment on Interim Rate Request ‐ email dated July 14, 2017

MKO ‐4

MKO ‐5

EXHIBIT LIST FOR

MANITOBA HYDRO


February 16, 2018

MKO ‐1 MKO's suggested Minimum Filing Requirements (MFRs)

Detailed Budget Submission

MKO to MH Round 1 Information Requests

Ex. # " " " " " " Percentage increase in use

Ex. #

Ex. #

MKO ‐6 MKO Letter to all parties re Legal Argument ‐ January 29, 2018

MKO‐5‐8

MKO ‐7 MKO Final Submission

Daymark Energy Advisors (DEA) Exhibits

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. # " " " " " " CV of Kathleen Kelly

Ex. # " " " " " " CV of Suman Gautam

Ex. #

Ex. #

Ex. # " " " " " " CV of Dan Peaco

W. Haight to R. Peters and D. Steineld Letter re IEC Reports ‐ CSI Process

dated November 23, 2017

DEA‐4 Daymark Energy Advisors Report ‐ Saskpower

DEA‐8 Daymark Energy Advisors Export CVs

DEA‐8‐1

DEA‐2‐1 Daymark Energy Advisors Report ‐ Forecast Revised November 28, 2017

DEA‐2‐2 Daymark Energy Advisors Errata to Load Forecast Report Review

DEA‐6‐1

DEA‐6‐2

EXHIBIT LIST FOR

MANITOBA HYDRO


February 16, 2018

DEA‐ 1 Daymark Energy Advisors Report ‐ Exports

DEA‐5 Daymark Energy Advisors Load Forecast Presentation

DEA‐6 Daymark Energy Advisors Load Forecast CVs

DEA‐7 Daymark Energy Advisors Export Presentation

DEA‐3

Ex. # " " " " " " CV of Doug Smith

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

DEA‐12 Daymark Energy Advisors Load Forecast Undertakings 45‐47

DEA‐13 Daymark Energy Advisors Exports Undertaking 48 ‐ Carbon Values

DEA‐9 CSI Daymark Energy Advisors Export Revenue Presentation ‐ Confidential

DEA‐10 Daymark Energy Advisors Saskpower Presentation

DEA‐11 CSI Daymark Energy Advisors Saskpower Presention ‐ Confidential

DEA‐8‐2

Dr. Adonis Yatchew (AY) Exhibits

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

AY‐2 Dr. Yatchew's Presentation

AY‐3 Dr. Yatchew CV

AY‐4 Dr. Yatchew Undertaking 1 ‐ CO2 per Capita

AY‐5 Dr. Yatchew Undertaking 2 ‐ per capita debt in Manitoba

EXHIBIT LIST FOR

MANITOBA HYDRO


February 16, 2018

AY‐1 Yatchew's Report

MGF Exhibits

Ex. #

Ex. #

Ex. #

Ex. # " " " " " " " MGF Kieran Flanagan

Ex. # " " " " " " " MGF Jim Potter

Ex. # " " " " " " " MGF Campbell Adams

Ex. # " " " " " " " MGF Phillips Duane

Ex. # " " " " " " " MGF Ryan Devereux

Ex. # " " " " " " " Amplitude ‐ Les Brand

Ex. # " " " " " " " KCB ‐ Dan Campbell

Ex. # " " " " " " " MGF Valerie Musfelt

MGF‐2 MGF Report

MGF‐3 IEC Capital Review Panel CVs

MGF‐3‐1

MGF‐3‐2

MGF‐3‐3

MGF‐3‐4

MGF‐3‐5

MGF‐3‐6

MGF‐3‐7

MGF‐3‐8

EXHIBIT LIST FOR

MANITOBA HYDRO


February 16, 2018

MGF‐1 MGF letter to Bob Peters re Extention Request ‐ November 28, 2017

Ex. #

Ex. # " " " " " " " " MGF ‐Keeyask Estimated Project

Values

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

Ex. #

MGF‐4‐1

MGF‐8 CSI Amplitude Confidential Presentation

MGF‐9 CSI KCB Confidential Presentation

MGF‐10 MGF Undertakings 73 and 74

MGF‐4 MGF Presentation

MGF‐5 Amplitude Presentation

MGF‐6 KCB Presentation

MGF‐7 CSI MGF Confidential Presentation

EXHIBIT LIST FOR Exhibits€¦ · Manitoba Hydro cover letter dated June 21, 2017 re General Rate...

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