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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
Manitoba Hydro cover letter dated May 5, 2017 re General Rate
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
Manitoba Hydro cover letter dated May 12, 2017 re General Rate
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. #
Ex. #
Ex. #
Ex. #
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
MH‐44‐8
MH‐44‐9
MH‐44‐10
MH‐44‐11
MH‐44‐12
MH‐44‐13
MH‐44‐14
MH‐44‐15
MH‐44‐16
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
MH‐47‐11
MH‐47‐12
MH‐47‐13
MH‐47‐14
MH‐47‐15
MH‐47‐16
MH‐47‐17
MH‐47‐18
MH‐47‐19
MH‐47‐20
MH‐47‐21
MH‐47‐22
Ex. # " " " " " " Figure A‐7
Ex. # " " " " " " Table A‐2
Ex. #
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
MH‐57‐4
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
Ex. #
Ex. #
Ex. #
Ex. #
Ex. #
Ex. #
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
Ex. #
Ex. #
Ex. # " " " " " " " " "
"
Page 29‐1 of Revenue Requirement
Presentation
Ex. #
Ex. #
Ex. #
Ex. #
Ex. #
Ex. #
Ex. #
Ex. #
Ex. #
Ex. # " " " " " " " " "
"
CV of Greg Barnlund
Ex. # " " " " " " " " "
"
CV of Paul Chard
Ex. # " " " " " " " " "
"
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
Ex. #
Ex. #
Ex. #
Ex. #
Ex. #
Ex. #
Ex. #
Ex. #
Ex. #
Ex. #
Ex. #
Ex. #
Ex. #
Ex. #
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
MH‐92‐10
MH‐92‐11
MH‐92‐12
MH‐92‐13
MH‐92‐14
MH‐92‐15
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
2017/18 & 2018/19 General Rate Application
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
Ex. # " " " " " " Asset Condition Assessment Audit by
Kinetrics
Ex. # " " " " " " Asset Condition Assessment Audit by
Kinetrics
Ex. # " " " " " " Asset Condition Assessment Audit by
Kinetrics
Ex. # " " " " " " Asset Condition Assessment Audit by
Kinetrics ‐ Power Transformers
Ex. # " " " " " " Asset Condition Assessment Audit by
Kinetrics ‐ Power Transformers
Ex. # " " " " " " Asset Condition Assessment Audit by
Kinetrics ‐ Transmission Steel
Structures
Ex. # " " " " " " Asset Condition Assessment Audit by
Kinetrics ‐ Transmission Conductors
Ex. # " " " " " " Asset Condition Assessment Audit by
Kinetrics ‐ Data Availability
Ex. # " " " " " " Asset Condition Assessment Audit by
Kinetrics ‐ Projected Flagged for
Action Plan
Ex. # " " " " " " Asset Condition Assessment Audit by
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 Model
Ex. # " " " " " " PCOSS18 Electronic Model
Ex. # " " " " " " PCOSS18 Electronic Model
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
PUB‐26‐12
PUB‐26‐13
PUB‐26‐14
PUB‐26‐15
PUB‐26‐21
PUB‐26‐16
PUB‐26‐17
PUB‐26‐5
PUB‐26‐6
PUB‐26‐7
PUB‐26‐8
PUB‐26‐9
PUB‐26‐18
PUB‐26‐19
PUB‐26‐20
PUB‐26‐10
PUB‐26‐11
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
PUB‐26‐32
PUB‐26‐33
PUB‐26‐34
PUB‐26‐35
PUB‐26‐36
PUB‐26‐22
PUB‐26‐23
PUB‐26‐24
PUB‐26‐25
PUB‐26‐26
PUB‐26‐27
PUB‐26‐28
PUB‐26‐29
PUB‐26‐30
PUB‐26‐31
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
PUB‐26‐50
PUB‐26‐51
PUB‐26‐52
PUB‐26‐53
PUB‐26‐41
PUB‐26‐42
PUB‐26‐43
PUB‐26‐44
PUB‐26‐45
PUB‐26‐46
PUB‐26‐39
PUB‐26‐40
PUB‐26‐37
PUB‐26‐38
PUB‐26‐47
PUB‐26‐48
PUB‐26‐49
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
Ex. # " " " " " " 2014 Residential Energy Use Survey
(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. # " " " " " " UMS Asset Management Gap
Assessement Report ‐ Findings
Ex. # " " " " " " UMS Asset Management Gap
Assessement Report ‐ Findings
Ex. # " " " " " " UMS Asset Management Gap
Assessement Report ‐ Findings
Ex. # " " " " " " UMS Asset Management Gap
Assessement Report ‐ Findings
Ex. # " " " " " " Corporate Risk Management Report ‐
Infrastructure Risk
PUB‐26‐67
PUB‐26‐68
PUB‐26‐69
PUB‐26‐70
PUB‐26‐66
PUB‐26‐54
PUB‐26‐55
PUB‐26‐56
PUB‐26‐57
PUB‐26‐58
PUB‐26‐59
PUB‐26‐60
PUB‐26‐61
PUB‐26‐62
PUB‐26‐63
PUB‐26‐65
PUB‐26‐64
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
Ex. # " " " " " " Asset Condition Assessment Audit ‐
Kinetrics
Ex. # " " " " " " Asset Condition Assessment Audit ‐
Kinetrics
Ex. # " " " " " " Asset Condition Assessment Audit ‐
Kinetrics
Ex. # " " " " " " Asset Condition Assessment Audit ‐
Kinetrics
Ex. # " " " " " " Asset Condition Assessment Audit ‐
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
PUB‐26‐85
PUB‐26‐86
PUB‐26‐87
PUB‐26‐84
PUB‐26‐71
PUB‐26‐72
PUB‐26‐73
PUB‐26‐74
PUB‐26‐75
PUB‐26‐76
PUB‐26‐77
PUB‐26‐78
PUB‐26‐79
PUB‐26‐80
PUB‐26‐81
PUB‐26‐82
PUB‐26‐83
Ex. # " " " " " " Comparison of Class RCC Results
Ex. # " " " " " " PCOSS18
Ex. # " " " " " " PCOSS18
Ex. # " " " " " " Planned GILT
Ex. # " " " " " " Rate Design
Ex. # " " " " " " Rate Design
Ex. # " " " " " " Rate Design
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) ‐
Information Requests
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
PUB‐33‐10
PUB‐33‐11
PUB‐33‐12
PUB to Coalition Information requestsPUB‐33
PUB‐32‐4
PUB‐33‐13
PUB‐33‐14
PUB‐33‐15
PUB‐33‐1
PUB‐33‐2
PUB‐33‐3
PUB‐33‐8
PUB‐33‐6
PUB‐33‐7
PUB‐33‐4
PUB‐33‐5
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
PUB‐33‐28
PUB‐33‐29
PUB‐33‐30
PUB‐33‐31
PUB‐33‐32
PUB‐33‐33
PUB‐33‐17
PUB‐33‐18
PUB‐33‐19
PUB‐33‐20
PUB‐33‐21
PUB‐33‐22
PUB‐33‐23
PUB‐33‐24
PUB‐33‐25
PUB‐33‐26
PUB‐33‐27
PUB‐33‐16
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. # " " " " " " Rate Design
Ex. #
Ex. # " " " " " " LEI evidence analysis
PUB‐34‐13
PUB‐34‐14
PUB‐35‐1
PUB‐34‐3
PUB‐34‐4
PUB‐34‐5
PUB‐34‐6
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
PUB‐35‐14
PUB‐35‐15
PUB‐35‐16
PUB‐35‐17
PUB‐36‐1
PUB‐35‐5
PUB‐35‐6
PUB‐35‐7
PUB‐35‐8
PUB‐35‐9
PUB‐35‐10
PUB‐35‐11
PUB‐35‐12
PUB‐35‐13
PUB‐35‐2
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
PUB‐36‐15
PUB‐36‐16
PUB‐36‐17
PUB‐37‐1
PUB‐36‐6
PUB‐36‐7
PUB‐36‐8
PUB‐36‐9
PUB‐36‐10
PUB‐36‐11
PUB‐36‐12
PUB‐36‐13
PUB‐36‐14
PUB‐36‐2
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
PUB‐38‐17
PUB‐38‐18
PUB‐38‐19
PUB‐38‐20
PUB‐38‐21
PUB‐38‐22
PUB‐38‐23
PUB‐38‐24
PUB‐38‐25
PUB‐38‐26
PUB‐38‐27
PUB‐38‐15
PUB‐38‐28
PUB‐38‐29
PUB‐38‐30
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
PUB‐38‐33
PUB‐38‐34
PUB‐39‐1
PUB‐39‐2
PUB‐39‐3
PUB‐39‐4
PUB‐39‐5
PUB‐39‐6
PUB‐39‐7
PUB‐39‐8
PUB‐39‐9
PUB‐39‐10
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) ‐
Information Requests
PUB‐46‐9
PUB‐46‐10
PUB‐46‐11
PUB‐46‐12
PUB‐46‐13
PUB‐46‐14
PUB‐46‐15
PUB‐46‐16
PUB‐46‐17
PUB‐46‐18
PUB‐46‐19
PUB‐46‐20
PUB‐46‐21
PUB‐46‐22
PUB‐46‐23
PUB‐46‐24
PUB‐46‐25
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
PUB‐50‐1
PUB‐50‐2
PUB‐50‐3
PUB‐50‐4
PUB‐50‐5
PUB‐47‐3
PUB‐47‐4
PUB‐47‐5
PUB‐47‐1
PUB‐47‐2
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
2017/18 & 2018/19 General Rate Application
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
Information Requests
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
Ex. # " " " " " " 2017 Residential Energy Use Survey
(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. # " " " " " " Energy Poverty
Ex. # " " " " " " Energy Poverty
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
Ex. # " " " " " " Bill affordability impact on Manitoba
Hydro revenues
Ex. # " " " " " " Bill affordability impact on Manitoba
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
Information Requests
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
Ex. # " " " " " " Risk of Credit downgrade of MB by
Moodys
Ex. # " " " " " " Risk of Credit downgrade of MB by
Standard & Poor's
EXHIBIT LIST FOR
MANITOBA HYDRO
2017/18 & 2018/19 General Rate Application
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
Ex. # " " " " " " risk of credit downgrade
Ex. # " " " " " " risk of credit downgrade
Ex. # " " " " " " risk of credit downgrade
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. # " " " " " " risk of credit downgrade
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 downgrade risks
Ex. # " " " " " " Credit downgrade risks
Ex. # " " " " " " Credit downgrade risks
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
2017/18 & 2018/19 General Rate Application
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
Ex. # " " " " " " Load Forecast ‐ GS Top Consumers Forecast ‐
major changes & effects
Ex. # " " " " " " Load Forecast ‐ GS Top Consumers Forecast ‐
Potential Large Industrial Loads Forecast
Ex. # " " " " " " Load Forecast ‐ GS Top Consumers 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
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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
Ex. # " " " " " " Cash Flow for Sustaining and Reliability
Projects ‐ Calculation of Cash Flow
Ex. # " " " " " " Cash Flow for Sustaining and Reliability
Projects ‐ Calculation of Cash Flow
Ex. # " " " " " " Cash Flow for Sustaining and Reliability
Projects ‐ Break Even Period/Requirement
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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. # " " " " " " Economic outlook
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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CC‐10‐97
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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CC‐10‐99
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
Ex. # " " " " " " understanding basis for allocating common
costs
Ex. # " " " " " " understanding basis for allocating common
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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CC‐12‐7
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
CC‐11
CC‐12
CC‐12‐1
CC‐12‐2
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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CC‐12‐22
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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CC‐12‐52
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
provided by applicant
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
provided by applicant
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
residential customers
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
CC‐12‐83
CC‐12‐84
CC‐12‐85
CC‐12‐86
CC‐12‐87
CC‐12‐88
CC‐12‐89
CC‐13
CC‐14
CC‐14‐1
CC‐15
CC‐15‐1
CC‐15‐2
CC‐16
CC‐17
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
CC‐22
CC‐23
CC‐18
CC‐19
CC‐20
CC‐21
CC‐22‐1
CC‐22‐2
CC‐22‐3
CC‐22‐4
CC‐17‐1
CC‐23‐1
CC‐23‐2
CC‐23‐3
CC‐23‐4
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
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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
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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
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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
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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
2017/18 & 2018/19 General Rate Application
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
2017/18 & 2018/19 General Rate Application
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
residential customers
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
2017/18 & 2018/19 General Rate Application
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
2017/18 & 2018/19 General Rate Application
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
2017/18 & 2018/19 General Rate Application
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
2017/18 & 2018/19 General Rate Application
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
2017/18 & 2018/19 General Rate Application
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
2017/18 & 2018/19 General Rate Application
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
2017/18 & 2018/19 General Rate Application
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
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