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2015/2016ANNUAL REPORT BRITISH COLUMBIA UTILITIES COMMISSION

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B R I T I S H C O L U M B I A U T I L I T I E S C O M M I S S I O N2

VISIONTo be a trusted and respected regulator that contributes to the well-being and long-term interests of British Columbians.

MISSIONThe Commission's mission is to ensure that ratepayers receive safe, reliable, and non-discriminatory energy services at fair rates from the utilities it regulates, and that shareholders of those utilities are afforded a reasonable opportunity to earn a fair return on their invested capital.

VALUE STATEMENTSACCESSIBILITY We facilitate fair, transparent and inclusive processes that encourage well represented input from relevant stakeholders who possess the information required to present their views effectively.

INTEGRITY We lead in a straight forward and consistent manner, by making objective and well-reasoned decisions and by treating stakeholders with dignity and respect.

RESPONSIVENESS We deliver efficient regulation, aligned with all relevant legislation and regulations and government policies, that takes into account the business needs of regulated entities and the public interest.

INNOVATION We continually strive to develop new efficiencies and innovative solutions in our internal operations and regulatory processes.

EXCELLENCE We promote excellence by expecting high standards of performance and conduct by regulated entities and by encouraging professional development and excellence in our staff and commissioners.

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2015/2016 CONTENTSORGANIZATIONAL OVERVIEW 05

OPERATIONAL HIGHLIGHTS 10

REPORT ON PERFORMANCE 14

RECOVERIES AND EXPENSES 21

SUMMARY OF DECISIONS, REASONS FOR DECISION 27 AND NEGOTIATED SETTLEMENTS

SUMMARY OF COMMISSION ORDERS 42

DOMESTIC ELECTRICITY, THERMAL ENERGY, GAS SALES 54

DIRECTIONS 56

REGULATED ENTITIES 58


This past year we have had a busy schedule with the completion of the projects described above and with the number and complexity of the applications received from regulated entities. I have included in the 2015/2016 annual report orders and decision summaries we worked on throughout the year. This list reflects a great deal of effort put forth by our employees and commissioners, in addition to the efforts of regulated entities and interveners to ensure regulatory oversight is efficient and effective. We are now moving forward through 2016/2017, which promises to be even busier than the last year.

On a personal note, I have stepped into the role of Chair and CEO, as of December 31, 2015. I look forward to the challenges ahead as I work with staff, commissioners and our stakeholders to ensure that we continue to improve our processes. It is only by striving for regulatory excellence that we can continue to provide the best possible value to all British Columbians.

Message from the Chair

It is my pleasure to submit this report to the Lieutenant Governor in Council in accordance with the Utilities Commission Act and the Budget and Transparency Act. In so doing, I acknowledge our dedicated employees and commissioners, and thank them for all their hard work this past year. I also acknowledge the contributions of our many stakeholders. It is because of the shared commitment to excellence of these individuals and groups that this was a successful year.

As we reported last year, a review of the Commission was conducted by an independent Task Force under the direction of the Minister responsible for Energy and Mines and Core Review. In response to the recommendations made by the Task Force, in 2015/2016 we focused our immediate efforts on the development of performance measures and targets to be implemented in 2016/17, effective April 1, 2016. The Commission also posted decision cycle time results on a quarterly basis on its website, commencing in the first quarter of 2015/2016. In addition, the Task Force recommended the improvement of guidelines, procedures and protocols, including those that describe public participation in Commission proceedings. In response, we completed the development of the Rules of Practice and Procedure in 2015/2016 and worked towards finalizing revised Participant Assistance/Cost Award (PACA) guidelines. Also, as recommended by the Task Force, we have developed a three year rolling Business Plan for 2016/2017 - 2018/2019. All final documents are available on our website.

We continue to work with our stakeholders to implement other key findings of the Task Force. In particular, we have focused on areas of Commission independence and government oversight, challenges with recruitment and competitive compensation of members, an increasingly complex mandate and energy environment while continuing to regulate at a cost per customer that is among the lowest in the country.

David Morton, Chair/CEO

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About UsWe are dedicated to our mission of ensuring ratepayers receive safe, reliable and non-discriminatory energy services at fair rates from the utilities we regulate, and affording shareholders a reasonable opportunity to earn a fair return on their invested capital. Our decisions are made in the public interest and consider all relevant legislation and regulations, as well as government policies and business needs of regulated companies.

The Commission regulates energy utilities in British Columbia as well as the Insurance Corporation of British Columbia’s (ICBC) universal compulsory automobile insurance rates (also referred to as Basic insurance) and intra-provincial pipelines.

The Commission’s governing act is the Utilities Commission Act and it has responsibilities under the Administrative Tribunals Act and the Freedom of Information and Protection of Privacy Act. We take our responsibilities to the public and to the companies we regulate seriously and work to maintain processes that are fair, transparent and inclusive. We are committed to issuing well-reasoned decisions that are based on sound evidence brought forward by well-represented parties.

The Commission:• regulates public utilities within its jurisdiction and in accordance with relevant legislation;

• ensures ICBC’s Basic insurance rates are set in a manner that is adequate, efficient, just and reasonable;

• adopts mandatory reliability standards that are in the public interest and supervises compliance by utilities with these standards;

• reviews questions and complaints about the actions of regulated utilities and ICBC, and adjudicates gas marketing disputes;

• establishes tolls and conditions of service for common carrier intra-provincial pipelines;

• reviews energy-related and automobile Basic Insurance matters referred to it by Cabinet;

• encourages public participation in public processes; and

• ensures stakeholders have the information they need to participate effectively by making all relevant materials publicly available.

ORGANIZATIONAL OVERVIEWThe Commission is an independent agency of the Provincial Government of British Columbia that operates under and administers the Utilities Commission Act.

O R G A N I Z AT I O N A L O V E R V I E W


Organizational StructureReporting to the Chair and CEO, the Commission is organized in the following manner:


Commissioners: Commissioners are independent decision-makers and are appointed by the Lieutenant Governor in Council in consultation with the Commission’s Chair and CEO. The commissioners hold a variety of professional backgrounds and work with staff experts to ensure sound evidentiary reviews are undertaken.

Human Resources and Finance Division: The Human Resources and Finance division is responsible for strategic human resource management and Commission finances. The division implements and administers human resources policies relating to benefits, pay, onboarding, employee relations, training, development, travel and more. The division is also responsible for the Commission’s budget and ensures cost recovery from regulated entities through an annual levy and direct proceeding costs. The division is also responsible for all facility matters.

Information Services Group: The Information Services Group is led by the Commission Secretary who fulfils statutory duties in the Utilities Commission Act and acts as the Commission’s official representative. The Information Services Group manages all administrative functions for the organization, including web services.

Regulatory Divisions: Energy; Infrastructure; Rates; Compliance; and Policy, Planning and Customer Relations make up the Commission’s five regulatory divisions. Staff specialists within these divisions apply professional expertise in areas including accounting, economics, ratemaking, business management, engineering, policy and compliance. Based on the particulars of each matter under review by the Commission, staff from each division form cross-divisional proceeding teams responsible for ensuring the development of a full record of evidence for consideration by commissioners.

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Commissioner Biographies

CAROL A. BROWN Commissioner (Part-time) Appointed in January 2011. Doctor of Philosophy, Organizational Development, Fielding Graduate University; Bachelor of Laws, University of Western Ontario; CPA, Certified General Accountant; Director, Prince George Airport Authority; Canadian Bar Association (BC) Benevolent Society; past member of Environmental Appeal Board and Forest Practices Appeal Commission; Corporate/Commercial Lawyer and Mediator; past Director with the Insurance Corporation of British Columbia.

DENNIS A. COTE Commissioner (Part-time) Appointed in October 2008. Bachelor of General Studies, Simon Fraser University; retired in 2007 as Vice President, Product Development and Support for the British Columbia Automobile Association; held various other executive roles with the British Columbia Automobile Association, including Vice President Sales, Director of Travel Services; Merchandise Investment Manager and Store Manager with the Hudson Bay Company, BC Region; currently a member of the Board of Consumer Protection British Columbia.

DOUGLAS J.ENNSCommissioner (Part-time) Appointed in March 2016. Bachelor of Arts, Economics, University of Manitoba; FCPA, Fellow Chartered Professional Accountants of British Columbia; C.Dir, Chartered Director, McMaster University; MBA, University of Wales; completed Enterprise Risk Management Certificate, Stanford University; President of Upturn Consulting Ltd.; Chair of the Board of Consumer Protection British Columbia; member of the Board of Directors of British Columbia Life Insurance Ltd.; past President of the Institute of Chartered Accountants of British Columbia; former board member of Royal Roads University, the University of Victoria, Medic Alert Foundation and RaxMax Industries Advisory Board.

DAVID M. MORTON Chair and Chief Executive Officer, effective December 31, 2015 Appointed Chair and CEO effective December 31, 2015. Prior to appointment as Chair, served as Commissioner from November 2010 – December 30, 2015. Bachelor of Applied Science, University of Toronto; Professional Engineer (British Columbia); Licentiate in Accounting, Society of Management Accountants Canada; certified with the ICD.D designation in 2013 by the Institute of Corporate Directors; consultant with over 25 years of experience in the Information Technology sector, specializing in project management, business and technical analyst services.

LEONARD F. KELSEY Chair and Chief Executive Officer until December 31, 2015Appointed Chair and CEO in 2008. Prior to appointment as Chair, served as a Commissioner from 2003-2008. Vice President British Columbia Automobile Association (18 years); Chief Operating Officer, BCAA Insurance Corporation, retired in 2002; past member BC Committee, Insurance Bureau of Canada; Public Administrator and past Chair, North Shore Health Region; independent Business Consultant.

WILLIAM M. EVERETT Commissioner (Part-time) Appointed in February 2016. Practiced law at Lawson Lundell LLP primarily in the area of complex litigation with a focus on commercial, construction, engineering, products liability, insurance and regulatory issues for the last 44 years and has appeared as counsel before the Supreme Court of Canada, courts in B.C. and Alberta and regulatory tribunals; Chartered Arbitrator and has mediated and arbitrated numerous disputes; an elected Bencher of the Law Society of B.C. in 1998, served as its President in 2003 – 2004 and is currently an Adjudicator on Law Society Panels hearing disciplinary and credential hearings; has served on many Boards, including the Pacific Alzheimer Research Foundation, Vancouver Art Gallery, Crofton House School, and the Vancouver Playhouse Theatre.

HOWARD G. HAROWITZ Commissioner (Part-time) Appointed in March 2014. Bachelor of Commerce (Economics), University of British Columbia; Master of Business Administration, Stanford University; Partner at PricewaterhouseCoopers; President of two operating companies; principal and director of private consulting firm; Director, Vancouver Coastal Health, Dalai Lama Centre, and Gateway Theatre Society.


IAIN F. MACPHAIL Commissioner (Part-time) Appointed in March 2014. Bachelor of Arts, Economics, University of Western Ontario; CPA, Chartered Accountant, British Columbia and Ontario; over thirty-seven years of experience as a professional accountant focused on taxation and financial advisory services; served as Director, Chief Financial Officer and Advisor to resource companies, charities and not-for- profit organizations.

BERNARD A. MAGNAN Commissioner (Part-time) Appointed in June 2012. Bachelor of Commerce (Economics), Concordia University; Master of Business Administration, Simon Fraser University; Certified Management Consultant; Fellow of Chartered Professional Accountants; previously Assistant Managing Director and Chief Economist, the Vancouver Board of Trade (five years); Managing Director of BMA Ltd., a management consulting and project management firm specializing in project management, strategic planning and corporate turnarounds for several industries including transportation, finance, manufacturing, health care and utilities.

RICHARD I. MASONCommissioner (Part-time) Appointed in March 2016. Bachelor of Arts, mathematics and computing science, University of Cambridge; Master of Business Administration, University of Cambridge; previously held the role of CEO with two information technology businesses and executive leadership roles at Health Insurance BC and Pacific Blue Cross; mentor to entrepreneurs for the Canadian Youth Business Foundation, and to students on the University of Cambridge MPhil. Management program; former member of the BC Medical Association’s Council on Health Promotion.


KAREN A. KEILTYCommissioner (Part-time) Appointed June 2014. Bachelor of Business Administration, Simon Fraser University; FCPA, Fellow Chartered Accountant, Chartered Professional Accountants of British Columbia; completed Directors Education Program and Not-for-Profit Governance Course with the Institute of Corporate Directors; thirty years audit experience with Deloitte, serving as the leader of Deloitte’s BC audit practice prior to retirement in 2014; Director of Great Canadian Gaming Corp.; Member of Executive Committee, Canada’s Energy and Utility Regulators (CAMPUT); served on Council of Institute of Chartered Accounts of BC and as President in 2019/10; past Director of Quest University, Vancouver Social Venture Partners, British Columbia Paraplegic Foundation, Forum for Women Entrepreneurs, Vancouver Enterprise Forum, BC Chamber of Commerce and Women’s Addiction Foundation.

NORMAN E. MACMURCHY Commissioner (Part-time) Appointed in November 2010. Honours Bachelor of Arts, Economics and Commerce, Royal Military College of Canada; Master of Arts, Economics, University of Western Ontario; retired 2006 as Executive Director, Industrial Gas Consumers Association of Alberta; held various positions with the Alberta and federal governments including Chair, Alberta Petroleum Marketing Commission; Assistant Deputy Minister, Sustainable Energy Development Division, Alberta Department of Energy and Natural Resources; and Chief, Policy Analysis and International Division, National Energy Board.

LIISA A. O’HARA Commissioner (Part-time) until March 2016Appointed in January 2005. Master of Sciences, Business Administration (Finance), University of British Columbia; CPA, Certified General Accountant; professional corporate director with ICD.D. designation from the Institute of Corporate Directors since 2006 and a number of board affiliations; over thirty years of corporate infrastructure, transportation and utility expertise in the airline and pipeline industries; former Executive-in-Residence and Faculty Advisory Board member at Sauder School of Business.

RICHARD D. REVEL Commissioner (Part-time) Appointed in December 2011. Bachelor of Science, Notre Dame University of Nelson; Doctor of Philosophy, Plant Ecology, University of British Columbia; currently Professor Emeritus, University of Calgary; retired in 2008 as Professor of Environmental Science at the University of Calgary; specialized in the technical and economic aspects of resource development and management and has held appointments to the National Energy Board of Canada and with the Ministries of Energy and Mines and Environment in Ecuador under the auspices of the United Nations Development Programme.

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Chair and CEO

David Morton Chair and Chief Executive Officer

Human Resources and Finance

Viki Vourlis Director

Kevin Wong Financial Administrator

Sheena Zyp Financial & Contract Administrator

Eleanor Rock Human Resources and Finance Business Analyst

Information Services

Erica Hamilton Commission Secretary and Director

Laura Sharpe Manager, Information Services

Mark Hudson Web/IT Administrator

Constance Smith Senior Administrator

Yvonne Lapierre Administrative Assistant

Daniela Guest Administrative Assistant

Katie Berezan Administrative Assistant

Nhi Do Administrative Assistant

Aisha Quo Vadis Receptionist

Energy

Doug Chong Director

Cathy Marr Manager, Energy Supply

Jackie Ashley Senior Regulatory Analyst

Errol South Regulatory Analyst

Hillary Cheung Regulatory Economist

Rates

Philip W. Nakoneshny Director

Eileen Cheng Senior Economist

Suzanne Sue Senior Regulatory Specialist

Claudia McMahon Senior Regulatory Specialist

Yolanda Domingo Senior Regulatory Specialist

Laurel Ross Seconded, Acting Commission Secretary and Director (effective February 15, 2016)

Sarah Walsh Senior Regulatory Specialist

Lucie Bohan Regulatory Analyst

StaffInfrastructure

J. Todd Smith Director

Chris Garand Senior Engineer

Atalla Buretta Gas Engineer

Joel Ronne Senior Infrastructure Engineer

Ashita AnandSanghera Infrastructure Engineer

Policy, Planning and Customer Relations

Alison Thorson Director

Katherine Carlsen Manager, Gas Marketing Programs

Leon Cheung Senior Regulatory Analyst

Patrick Wruck Customer Relations Analyst

Compliance

Kristine Bienert Director

Ian Homer Senior Compliance Analyst

Marija Tresoglavic Compliance Administrator

Christine Schwab MRS Program Manager


O P E R AT I O N A L H I G H L I G H T S

Business PlanOn March 31, 2016, the Commission issued its first Business Plan for 2016/2017 – 2018/2019 in response to a recommendation from the independent Task Force that conducted a review of the Commission, which was initiated by government and concluded on February 4, 2015. The plan encompasses three years and sets out the Commission’s strategic direction, goals, strategies, initiatives, performance measures and targets to gauge our achievements, and the financial plan to support our work.

Development of the plan began in the fall of 2015 when the Commission undertook its first employee engagement survey. Using the Workplace Environment Survey designed by BC Stats, staff and commissioners were surveyed to assess the overall health of the work environment. In the winter of 2015 the Commission concluded a stakeholder consultation to develop the performance measures and targets the organization will use going forward from April 1, 2016. These data as well as external stakeholder feedback gathered through the government’s Independent Review of the Commission that concluded in February 2015 were considered when developing the Business Plan.

The Commission’s overall strategic direction for 2016/2017 – 2018/2019 is to increase efficiency and effectiveness through a strong employee and commissioner workforce that executes its mandate collaboratively with engaged stakeholders. To achieve this overall direction, the Commission has set three goals: improve efficiency and effectiveness; strengthen internal communication and collaboration; and engage stakeholders. The detailed Business Plan can be found on the Commission’s website at www.bcuc.com/serviceplan.aspx

The Business Plan marks a change in the organization towards more transparent and accountable performance and, as a rolling three-year plan it will be updated every year.

Rules of Practice and ProcedureOn January 7, 2016, the Commission issued Order G-1-16 and adopted the Rules of Practice and Procedure, pursuant to section 2(4) of the Utilities Commission Act and section 11 of the Administrative Tribunals Act. The Rules came into effect on January 15, 2016.

The Commission’s intention for the Rules was to develop standard published requirements for participation in Commission processes in response to recommendations made by the independent Task Force that conducted a review of the Commission. In its Final Report, the independent Task Force recommended, among other recommendations, the Commission formalize its policies on granting intervener status and publish them. Specifically, the Rules clarify:

1. The process for making a request to intervene in a proceeding;

2. How participant information is maintained; and 3. Participation expectations for interveners.

The Rules also pertain to document filing protocols, the treatment of confidential filings and the participation of interested parties and individuals who submit letters of comment.

On June 30 and August 27, 2015, draft Rules were provided to stakeholders for comments and also posted on the Commission’s website. Twelve organizations and individuals, including regulated entities, intervener groups and members of the public submitted comments on the Rules. The comments received represented diverse views and interests.

In undertaking the development of the Rules, the objective of the Commission was to support the transparency and effectiveness of the processes through which individuals and organizations may participate in Commission proceedings, while finding improved administrative and regulatory efficiencies. The Rules place a renewed emphasis on the relevance of submissions and formalize the participation process in order to ensure the Commission can address all the issues that are relevant to a proceeding, and assist in enabling individuals and organizations to present their concerns in the manner that is most appropriate for them. The Rules also provide a single resource for stakeholders, participants and interested members of the public alike, to be able to seek information on the Commission’s processes.

OPERATIONAL HIGHLIGHTS

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Stakeholder Feedback on Commission Information RequestsAs part of the Commission’s continuous improvement efforts we asked stakeholders that regularly participate in Commission proceedings to provide feedback on the Commission’s information requests. Information requests or IRs are the primary method Commission staff have to elicit information on the evidentiary record that is relevant to the issues to be considered by the Commission in a proceeding.

Near the end of summer 2014, Commission staff started following a more structured process to review applications, identify important issues and issue IRs. In August 2015, the Commission sought feedback from stakeholders that regularly participate in Commission proceedings to help us gauge the effectiveness of this structured process. The highlights of the feedback received are below.

• The Commission received a total of eight feedback responses, five from regulated entities and three from individuals who regularly represent intervener groups;

• With respect to any noted improvement in Commission IRs in the last 12 months, half of those providing feedback stated they had noticed an improvement ranging from “yes, higher quality and fewer in number” to “greater focus in 2014.” Several stakeholders commented that the organization of IRs by issue was helpful and none reported a decline; and

• The Commission sought in its feedback a rating for each of the following factors:

• Relevance (focused on relevant and material issues);

• Quantity/type of IRs; and

• Quality (clear, concise, neutral, organized and accurate).

The rating ranged from 1-Very dissatisfied to 5-Very satisfied with a 3 being Neutral. The average of the results was a score of 3.8 with each factor broken down as follows:

Relevance 3.8 Quantity 3.4

Quality 4.1 Average 3.8

The lowest rating received was a rating of 2 (Dissatisfied) for both Relevance and Quantity. This rating was provided by an individual representing an intervener group with comments that it was concerned that Commission staff IRs were too few and that “interveners rely heavily on the Commission staff’s resources and expertise to cover much of the detailed ground in proceedings.”

Three ratings of 5 (Very satisfied) were received in the category of Quality, two by regulated entities and one by an individual representing an intervener group. Additional comments and suggestions were reported and shared with commission staff for further action.

The Commission intends to continue with its structured IR process and to seek feedback from stakeholders on how to continuously improve the effectiveness and efficiency of our regulatory review processes.

BC Mandatory Reliability Standards DevelopmentsThe past year has seen some key developments in the Mandatory Reliability Standards (MRS) program for the bulk electric system in British Columbia. In November 2015, the BC provincial government approved amendments to section 125.2 of the Utilities Commission Act, which deals with the adoption of reliability standards, rules or codes for the province. In addition to maintaining the Commission’s existing mandate to determine whether a reliability standard is in the public interest and should be adopted in British Columbia and to supervise compliance with adopted standards, the changes to section 125.2 grant the Commission the authority to determine the applicability of adopted reliability standards to “a specified person, a class of persons or a person in respect of specified equipment.” To support this expanded mandate will require the Commission to develop criteria and update registration procedures in the future.

Ongoing updates to the BC MRS Rules of Procedure included a Find Fix Track (FFT) process to more effectively respond to Possible Violations perceived to be of lesser risk to the bulk electric system and the incorporation the North American Electric Reliability Corporation’s risk and severity factors and BC penalty matrices into the BC Penalty Guidelines.




Utility Customer Complaints The Commission receives complaints about regulated electricity or natural gas utilities and ICBC’s basic automobile insurance rates and works to resolve complaints that are within the Commission’s jurisdiction under the Utilities Commission Act. Most complaints are resolved through discussions between the customer and the utility concerned. Unresolved issues may be referred to the Commission.

Some examples of the types of complaints received by the Commission are:

• Billing • Metering and meter reading • Application of standard charges and rates • Tariff related customer service matters • Power quality• Maintenance of power lines, equipment, etc. • Information requests about service or regulation

The number of written complaints this year decreased to 475 from 1119 reported last year. The table on the left provides a breakdown of the complaints received per utility; those utilities with no complaints to the Commission are not included.

The significant decrease in the number of complaints from last year is largely due to the over 400 complaints received last year regarding BC Hydro’s Meter Choices Program and the replacement of several thousand legacy meters. While the Commission continued to receive complaints from BC Hydro Meter Choices Program customers regarding the replacement of legacy meters, these complaints have declined significantly this year.

There was a decrease in complaints from FortisBC Inc. customers regarding the two-step Residential Conservation Rate. The Commission received a letter from the Minister of Energy and Mines dated July 6, 2015, requesting the Commission to investigate concerns about the rate structure. Specifically, five questions were posed by the Minister and a proceeding has been established to respond to the five questions. This process is ongoing.

The Commission also continued to receive complaints about FortisBC Inc.’s Advanced Metering Infrastructure Program. The installation process is largely complete and the complaints declined towards the end of 2015/2016.

Complaints Received Number Total

BCHydroandPowerAuthority 321 GeneralComplaints 76 Billing 60 Rates 42 SmartMeters 110 Disconnection 33

FortisBCInc.(electric) 100 GeneralComplaints 17 Billing 9 Rates 13 AdvancedMeteringInfrastructure 49 Disconnection 12

FortisBCEnergyInc.(gas) 39 GeneralComplaints 14 Billing 12 Rates 8 Disconnection 5

InsuranceCorporationofBritishColumbia 8

PacificNorthernGasLtd. 3

NelsonHydro 2

PortAliceGas 1

ThermalEnergySystems 1

Total 475

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The Natural Gas Customer Choice Program Natural Gas Marketers have been authorized to market natural gas to commercial customers since 2003 and to residential customers since 2006 through the Customer Choice program. The Commission’s role in this program is to license the gas marketers, establish the Rules and Code of Conduct gas marketers must follow and adjudicate disputes and complaints customers file against gas marketers.

Gas Marketer Participation In the 2015/2016, the Commission licensed eight gas marketers under the Customer Choice program, listed below.

• Access Gas Services Inc. • AltaGas Ltd. • Bluestream Energy Inc. • Direct Energy (BC) Ltd. • Just Energy (BC) LP • Planet Energy (BC) Corp. • Summitt Energy BC LP • Superior Energy Management

Seventh Annual General MeetingOn June 9, 2015, licensed gas marketers, FortisBC Energy Inc., the BC Old Age Pensioners’ Organization et al., and Commission staff attended the seventh Customer Choice Annual General Meeting (AGM) in Vancouver.

On September 24, 2015, the Commission issued Order A-12-15, the accompanying Decision and an updated version of the Code of Conduct for Gas Marketers. A significant change that resulted from the AGM was the Panel’s decision to remove spouse as a listed signing authority which came into effect immediately upon issuance of Order A-12-15.


Disputes and Complaints The Commission adjudicates those disputes and complaints that customers are not able to resolve directly with the gas marketer.

The Commission’s complaint process is available for members of the public with a general complaint or concern about a gas marketer’s customer service, salesperson conduct or marketing practices, or about the Customer Choice program administration. Complaints can be from members of the public who may or may not have entered into an agreement with a gas marketer. In 2015/2016, the Commission reviewed a total of 44 written complaints.

The Commission’s dispute process is available for customers who have signed a contract with a gas marketer and wish to dispute their contract. Contracts may be disputed for a number of reasons including contract term, contract price, validity of the contract and non-compliance with the Code of Conduct. In the 2015/2016, the Commission received 207 disputes through the dispute resolution process. This figure includes disputes adjudicated by the Commission and non-contested disputes in which the gas marketer agreed to cancel a customer’s contract of their own accord, without a Commission determination.


R E P O RT O N P E R F O R M A N C E

REPORT ON PERFORMANCEAs part of the Commission’s commitment to transparency and accountability, we provide our annual report on performance for 2015/2016.

Consistent with the Commission’s 2013/14 and 2014/15 annual reports, the Commission is reporting data on cycle times and total duration of review for both hearing and non-hearing applications; total cost of regulation; and cost of regulation per customer. For 2015/16 the Commission developed a one year Implementation Plan which set out the initiatives the Commission would undertake to improve its efficiency and effectiveness. This report on performance includes an update on the Commission’s achievements related to the Implementation Plan.

Cycle Times The below representation of cycle times shows the amount of time the Commission has taken to review various proceedings through various methods. It is important to note that there are a number of circumstances that affect the amount of time it takes to review an application or complete an inquiry, including utility-requested or Commission-initiated adjournments due to low or higher priority items. A review of specific proceedings on the Commission’s website is the best way to ascertain what circumstances have had the greatest impact on timing.

Streamlined Review Process Cycle Times

G-104-15APacificNorthernGasLtd.ApplicationforNoChangesto2015DeliveryRates andChangestothe2015RSAMRiderforthePNG-WestServiceArea

G-215-15 CorixMulti-UtilityServicesInc.ApplicationforaCertificateofPublic ConvenienceandNecessityforAdditionalCapitalandAmendedRates forUniverCityNeighbourhoodUtilityServiceonBurnabyMountain

n Number of Days from Application to Reply Argument/SRP n Number of Days from Reply Argument/SRP to Decision

202 15

84 14

Oral Hearing Cycle Times

C-12-15 CreativeEnergyVancouverPlatformsInc. ApplicationforaCertificateofPublicConvenienceandNecessityforaLow CarbonNeighborhoodEnergySystemforNortheastFalseCreekand ChinatownNeighborhoodsofVancouver

n Number of Days from Application to Reply Argument n Number of Days from Reply Argument to Decision

235 64

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Written Hearing Cycle Times

C-10-15A PacificNorthernGasLtd.ApplicationforaCertificateofPublicConvenience andNecessitytoConstructandOperateanInterconnectingPipelinebetween KitimatandDouglasChannel

C-11-15 FortisBCEnergyInc.CertificateofPublicConvenienceandNecessity ApplicationfortheLowerMainlandIntermediatePressureSystem UpgradeProjects

G-71-15 BritishColumbiaSustainableEnergyAssociationandtheSierraClubofBritish ColumbiaApplicationforReconsiderationofOrderF-1-15

G-81-15 InsuranceCorporationofBritishColumbia2014Revenue RequirementsApplication

G-84-15 CorixMulti-UtilityServicesInc.FinalRateApplicationforPhase1–Wesbrook oftheUniversityofBritishColumbiaNeighbourhoodDistrictEnergySystem

G-86-15 FortisBCEnergyInc.AnnualReviewof2015DeliveryRatespursuanttothe Multi-YearPerformanceBasedRatemakingPlanapprovedfor2014through 2019byOrderG-138-14

G-97-15 FortisBCEnergyInc.ApplicationforApprovalof2015-2016Revenue RequirementsandRatesfortheFortNelsonServiceArea

G-98-15 CreativeEnergyVancouverPlatformsInc.2015-2017Revenue RequirementsApplication

G-106-15 FortisBCEnergyInc.ProposaltoincludeFortisBCEnergy(VancouverIsland) Inc.andFortisBCEnergy(Whistler)Inc.inthe2014-2019Multi-Year PerformanceBasedRatemakingPlan

G-107-15 FortisBCInc.ApplicationforApprovalof2015RatesPursuanttothe Multi-YearPerformanceBasedRatemakingPlanApprovedfor2014through 2019byOrderG-139-14

G-111-15 BCHydroandPowerAuthorityApplicationforApprovalofShorePowerRate, RateSchedules1280,1891andShorePowerAgreementElectricTariff SupplementNo.86

G-120-15 FortisBCEnergyInc.andFortisBCInc.Multi-YearPerformanceBased RatemakingPlansfor2014through2019-ApprovedbyDecisionsandOrders G-138-14andG13914-CapitalExclusionCriteriaunderPBR –ComplianceFiling

G-133-15 SuperiorPropaneStatusasStatusasPublicUtilityinBritishColumbiaforthe OperationofaPropaneDistributionSystematSeascapesDevelopmentLtd.

G-135-15 FortisBCEnergyInc.AnApplicationforReconsiderationofOrderG-187-14, AmendingtheBalancingGasChargesforRateSchedules23,25,26and27

G-144-15 SilversmithPowerandLightCorporation2015Revenue RequirementsApplication

G-146-15 FortisBCAlternativeEnergyServicesInc.ApplicationforApprovaloftheFiscal 2015/16RevenueRequirementsandCostofServiceRatesforThermalEnergy ServicetoDeltaSchoolDistrictNumber37

G-154-15 PacificNorthernGas(N.E.)Ltd.-DawsonCreekDivisionApplicationfor ApprovalofAltaGasLtd.IndustrialFirmTransportationServiceAgreement andProposedRS7IndustrialLNGFirmTransportationServiceTariff


69 16

238 63

23 / 34

216 47

73 31

85 48

155 34

164 29

166 55

82 55

62 14

84 89

100 7

51 34

83 29

100 42

79 21


Notes:

(1) The FortisBC Energy Utilities Application for Removal of the Restriction on the Location of Data and Servers Providing Service to the FEU, currently restricted to Canada required 368 days from application to reply argument and 70 days from reply argument to decision. This is because the utility filed an alternative proposal (the alternative relief) in the first round of argument. This alternative relief acted as an alternative application for which evidence was filed and tested, and argument was presented.

(2) The FortisBC Inc. 2015 Self-Generation Policy Application presents as 164 days from application to reply argument and 256 days from reply argument to decision. This is because although the application was filed on January 9, 2015, the Panel started its deliberations on December 9, 2015, when the final order and accompanying decision on the BC Hydro Contracted GBL Application was issued.

(3) The FortisBC Inc. Application for Stepped and Stand-by Rates for Transmission Voltage Customers was decided by way of six decisions. These decisions are all linked to one application and are counted from the previous decision. For example, for the Stage IV decision, days from application to reply argument is counted from the Stage III decision to the Stage IV decision.

Written Hearing Cycle Times cont'd

G-155-15 PacificNorthernGas(N.E.)Ltd.2015ResourcePlanfortheFortSt.John, DawsonCreekandTumblerRidgeDistributionSystems

G-161-15 FortisBCEnergyUtilitiesApplicationforRemovaloftheRestrictiononthe LocationofDataandServersProvidingServicetotheFEU,currently RestrictedtoCanada1

G-174-15 BCHydroandPowerAuthorityApplicationforApprovalofContracted GeneratorBaselineGuidelinesandReconsiderationandVarianceof OrderG-19-14

G-193-15 FortisBCEnergyInc.AnnualReviewof2016RatesApplication

G-202-15 FortisBCInc.AnnualReviewof2016RatesApplication

G-203-15APacificNorthernGasLtd.AndPacificNorthernGas(N.E.)Ltd.2015 ConsolidatedEnergyManagementandEfficiencyProgramFundingPlan

C-2-16 FortisBCInc.ApplicationforaCertificateofPublicConvenienceand NecessityfortheKootenayOperationsCentre

E-3-16 FortisBCEnergyInc.ApplicationforAcceptanceoftheBiomethanePurchase AgreementbetweenFEIandtheCityofSurrey–Section71Filingand ApprovaloftheMonthlyFacilityFee

G-25-16 BCHydroandPowerAuthorityApplicationforIndirectInterconnection ServicesforTransmissionVoltageLoadCustomers

G-27-16 FortisBCInc.2015Self-GenerationPolicyApplication2

G-39-16 FortisBCMidstreamInc.ApplicationfortheAcquisitionoftheSharesof AitkenCreekGasStorageULC

G-42-16 BCHydroandPowerAuthorityApplicationforApprovalofDebtManagement RegulatoryAccount

G-93-15 FortisBCInc.ApplicationforSteppedandStand-ByRatesforTransmission VoltageCustomers-StageIII-Decision3

G-149-15 FortisBCInc.ApplicationforSteppedandStand-byRatesforTransmission VoltageCustomers-StageIV-Stand-byBillingDemandforZellstoffCelgar LimitedPartnership3

G-168-15AFortisBCInc.ApplicationforSteppedandStand-byRatesforTransmission VoltageCustomers-Non-EmbeddedCostPowerRateRider3

G-214-15 FortisBCInc.ApplicationforSteppedandStand-byRatesforTransmission VoltageCustomers-StageV3


90 76

368 70

251 71

76 19

73 21

115 58

155 84

73 24

116 55

164 256

63 29

79 26

31 / 35

56 60

23 / 6

116 6


A N N U A L R E P O R T 2 0 1 5 / 1 6 17

Non-Hearing Applications Cycle Times

n Non-Hearing Applications Dealt with in Fiscal Period n Average Duration of Review (Days)

218 228 22440 40 58 2013-2014 2014-2015 2015-2016

* This measure includes MRS items which follow the Commission’s Rules of Procedure for MRS under the supervision of an external Administrator (WECC). In 2015-16 two significant and long-standing MRS items were completed, in accordance with these processes, resulting in the increase in average duration of review for this year.

* Total Costs is comprised of Commission costs.


Total Cost of Regulation and Cost of Regulation per Customer

$0.00

$0.20

$0.40

$0.60

$0.80

$1.00

$1.20

$1.40

$0

$1,000,000

$2,000,000

$3,000,000

$4,000,000

$5,000,000

$6,000,000

$7,000,000

$8,000,000

$9,000,000

$/CustomerTotal Costs

Total Cost of Regulation Cost of Regulation per Customer

2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16


Implementation Plan Initiatives The Commission’s 2015/16 Implementation Plan set out twelve initiatives towards five goals aimed at improving overall efficiency and effectiveness. The Commission is pleased to report that we have achieved all the initiatives set out for this past year that are within our control and we are working towards the achievement of the remaining initiatives in partnership with government. The Commission’s achievement of the twelve Implementation Plan initiatives is reported below.

Goal 1: Improve the regulatory efficiency and effectiveness of the Commission, especially as it relates to regulatory processes, information requests, policies and guidelines.

Initiatives Completion Deliverables

RevisedCPCNFilingGuidelines February2015 CPCNGuidelinesavailableatwww.bcuc.com/guidelines.aspx

MediumSizeUtilityRevenueRequirementFilingGuidelines

February2016IssuanceofguidelinesdirectedatmediumsizeutilityPacificNorthernGas.

StrategicInformationRequestsProcess

September2015 Internalprocessimplemented.

August2014Stakeholderfeedbacksurveyoninformationrequestquality,numberandrelevancecompleted.

IntervenerAcceptanceandApplicationGuidelines

December2015CommissionRulesofPracticeandProcedure,includinginterveneracceptanceandapplicationprovisions,availableatwww.bcuc.com/guidelines.aspx

InternalProcessImprovementAugust2015 Internalprocessguidecompleteforexemptionapplications.

March2016 Internalprocessguidecompleteforcomplianceactions.

Goal 2: Improve the operational efficiency and effectiveness of the Commission, especially as it relates to business planning and internal performance measurement.


ImprovetheSearchabilityoftheCommission’sPublicDatabaseofOrdersandDecisions

September2015NewordersanddecisionsdatabaseontheCommission’swebsite.AvailablebyclickingOrdersandDecisionstabontheCommission’swebpageorat:www.ordersdecisions.bcuc.com/bcuc/en/nav.do

ImplementaBusinessPlanningCycle

July2015 Internalbusinessplanningcycledesigned.

October2015 Internalemployeeengagementsurveycompleted.

March20162016-19BusinessPlanissuedandavailableat:www.bcuc.com/serviceplan.aspx

DevelopPerformanceMeasuresandTargets

December2015FinalPerformanceMeasuresandTargetsreportissuedandavailableat:www.bcuc.com/serviceplan.aspx

June2015Quarterlyupdatesonspecificperformancemeasurescompletedandavailableat:www.bcuc.com/annualreport.aspx


A N N U A L R E P O R T 2 0 1 5 / 1 6 19

Goal 4: Optimize the Commission’s performance monitoring, conduct and compliance activities.


ReviewcurrentCompliancedivisionactivitiesanddeterminetheoptimalorganizationalstructure

August2015 InternalComplianceReviewFinalReportcompleted.

Reviewallcompliancereportsandeliminateunnecessaryones

July2015Stepimplementedincompliancereviewprocesstoconsidernecessityofreport.

Goal 5: Support government to implement legislative and compensation changes.


Provideinformationandsupportasrequestedbygovernment

OngoingCommissionstaffprovideinformationandsupportasrequestedbygovernmentstaff.

Goal 3: Address commissioner and staff resourcing.


Workwithgovernmenttoaddresscompensationissues

Note: This initiative was set out with the intention that the Commission would work with government to address staff and commissioner compensation and then recruit for additional commissioners and a Chief Operating Officer. This sequence was set out because the Commission had difficulties recruiting at the existing compensation ranges.

March2016

TherehasbeennomovementintheTreasuryBoardcompensationrangesforcommissionersorthePSECcompensationrangesforCommissionstaff.Despitethis,3part-timecommissionerswererecruitedandcommencedtheirtermsinMarch2016.

Incompleteduetocircumstances

unforeseenatthetimethe

ImplementationPlanwasdeveloped

RecruitmentforaChiefOperatingOfficerwasnotcompletedbecauseofchangestotheUtilitiesCommissionActregardingthepositionthatwereimplementedinlate2015andthechangeinChair’spositiononDecember31,2015.RecruitmentofaCOOisincludedinthe2016-19BusinessPlanfor2016/2017.




Future Reporting On Performance During the course of 2015/16 the Commission developed a three-year Business Plan and, with input from stakeholders, decided on the seven performance measures in the table below.

The Final Report detailing the development of the performance measures was completed on December 14, 2015, and can be found on the “Business Plan and Performance Measures” page of the Commission’s website www.bcuc.com/serviceplan.aspx. The Commission will collect data on these seven measures next year and report on the Commission’s performance, as well as our achievement of our Business Plan initiatives, in our 2016/17 annual report.

No. Performance Measure Target

A.CycleTime

1. DecisionCycleTime 90%issuedin90calendardaysorless 2. OtherProceedingsTotalCycleTime Maximumannualaverageof40calendardays

B.CustomerandStakeholderExperience

3. ComplaintandEnquiryResponseTime 85%in5businessdaysorless4. ParticipantAssistance/CostAwardCycleTime 100%issuedin60calendardaysorless

C.OrganizationalandFinancialPerformance

5. EmployeeEngagement Baseline/Benchmark6. TotalExpenditureperCapita($/capita) None(IndicativeMeasure)7. EnergyRegulationExpenditureperGigajoule($/GJ) None(IndicativeMeasure)

Performance Measures

A N N U A L R E P O R T 2 0 1 5 / 1 6 21

R E C O V E R I E S A N D E X P E N S E S

RECOVERIES AND EXPENSES



RECOVERIES AND EXPENSES The Commission is authorized to recover its costs from regulated entities by fixing levies according to section 125 of the Utilities Commission Act and parameters set out in Levy Regulation, BC Reg. 283/88.

The Commission recovers most of its costs by way of a “per gigajoule” levy assessed on each regulated utility, based on the amount of energy the utility sold in the previous calendar year (calculation is provided below). Entities that do not sell power, such as ICBC, are billed by way of a set rate. The rate is reviewed to ensure appropriate annual regulatory costs are applied. Recoveries are also collected from intra-provincial pipeline companies, upstream gas processors and natural gas marketers.

The Commission also recovers proceeding costs directly from regulated entities for Commission expenditures attributable to public hearings and other proceedings under the Utilities Commission Act. Direct recoveries have varied significantly from year to year, depending on the number and duration of regulatory hearings and inquiries.

Summary of 2015/2016 Recoveries and ExpensesTotalRecoveries $ 8,534,789.41LessExpenses $ 7,192,785.20

OverRecovery $ 1,342,004.211

While many initiatives were successfully completed during 2015/2016, some financially significant items, such as the recruitment and hiring of a Chief Operating Officer, were deferred pending the appointment of a new Chair and CEO and some larger proceedings moved into 2016/2017.

RecoveriesCommission revenues recovered are listed on the following pages. Corresponding levy orders for the figures are G-64-14 for 2014/2015 and G-73-15 and G-108-15 for 2015/2016. If applicable, over recoveries, deferred recoveries or expenses are applied as a credit or debit to the regulated entities in the levy order the following fiscal year.

Levy Calculation for 2015/20162015/2016ForecastedExpenses $ 8,314,415.502015/2016ForecastedStrategicInitiatives $ 445,255.75Less2015/2016ForecastedDirectRecoveries $ -1,400,000.00Less2014/2015OverRecovery $ -760,958.01

$ 6,598,713.24

LessFixedAnnualFees:NaturalGasMarketers $ -9,000.00Intra-ProvincialPipelineCompanies&UpstreamGasProcessors $ -20,000.00InsuranceCorporationofBritishColumbia $ -700,000.00

2015/2016NetForecastedExpensestoberecoveredthroughthelevy $ 5,869,713.24

Dividedbygigajoulesofenergysoldincalendaryear2015 399,580,102Levy: =$0.0146897035/GJ

1TobecarriedforwardandreturnedtotheregulatedutilitiesbywayoftheF2017Levyasacredit.

A N N U A L R E P O R T 2 0 1 5 / 1 6 23


Commission Recoveries Amounts Recovered ($) Amounts Recovered ($) 2014/2015 2015/2016

BritishColumbiaHydroandPowerAuthority $ 2,851,791.83 2,693,533.42

Cal-GasInc. 346.74 324.88

CentralHeatDistributionLimited 21,367.04 18,473.54

CorixMulti-UtilityServicesInc. Gas 1,071.73 929.14 Electric 898.36 852.00 UniverCityNUS 126.09 155.99

CorporationoftheCityofNelson 3,546.16 3,363.94

DocksideGreenEnergy 110.33 92.03

FortisBCAlternativeEnergyServicesInc. 142.29 254.82

FortisBCInc. 142,760.60 137,436.87

FortisBCEnergyInc. Revelstoke 3,183.67 3,070.15 LowerMainlandDivision 1,882,129.35 1,672,173.02 InlandDivision 778,926.28 751,628.06 ColumbiaDivision 155,652.87 139,831.29 FortNelsonDivision 10,134.14 9,636.45

FortisBCEnergy(VancouverIsland)Inc. 311,463.34 283,702.24

FortisBCEnergy(Whistler)Inc. 11,127.07 10,576.59

HemlockUtilityServicesLimited 94.56 88.14

InsuranceCorporationofBritishColumbia 700,000.00 700,000.00

PacificNorthernGas(includesGranisleGrid) 93,524.11 58,415.85

PacificNorthernGas(N.E.)Ltd. DawsonCreekandFortSt.John 69,835.75 71,647.81 TumblerRidge 12,829.23 12,171.20

PortAliceGasInc. 201.02 156.25

RiverDistrictEnergyLimitedPartnership 63.04 65.00

BigWhiteGasUtilityLtd. 614.67 506.57

StargasUtilitiesLtd. 617.06 582.76

SunPeaksUtilitiesCo.,Ltd. 1,166.29 1.16

SunPeaksUtilitiesCo.,LtdLevyCorrection2 1,159.10

TheYukonElectricalCompanyLimited 47.28 44.07

$ 7,053,770.90 6,570,872.34

2SunPeaksUtilitiesCo.,LtdcostswerereassessedafterLevyOrderG-108-15for2015/2016toaccountforthedifferenceingigajoules,whichamountedto$1,159.10


Natural Gas Licences Amounts Recovered ($) Amounts Recovered ($) 2014/2015 2015/2016

AccessGasServices $ 1,000.00 1,500.00

ActiveEnergyULC - -

ActiveEnergyULC - -

AGEnergyCo-Operative/FireflyEnergy - -

AltaGasLtd. 1,000.00 1,000.00

BluestreamEnergyInc. 1,000.00 1,500.00

ConnectEnergy - -

ConstellationNewEnergyCanadaInc. - -

DirectEnergy 1,000.00 1,500.00

JustEnergy(BC)Limited 1,000.00 1,500.00

PlanetEnergyCorp 1,000.00 1,500.00

SmartEnergy(BC)Ltd. 1,000.00 -

SummittEnergyBCLP 1,000.00 1,000.00

SuperiorEnergy 1,000.00 1,500.00

$ 9,000.00 11,000.00


A N N U A L R E P O R T 2 0 1 5 / 1 6 25

Intra-Provincial Pipelines Amounts Recovered ($) Amounts Recovered ($)

& Upstream Gas Processors 2014/2015 2015/2016

AltaGasLtd.-BlairCreekGasPlant $ - -

CanadianNaturalResourcesLimited 1,000.00 1,000.00

CanadianNaturalResourcesLimited-IngaOilPipeline 1,000.00 1,000.00

KeyeraEnergyLtd. 1,000.00 -

TransMountain(JetFuel)Inc. 1,000.00 1,000.00

PlateauPipeline-Blueberry 1,000.00 1,000.00

PlateauPipeline-NortheastBC&BoundaryLake 1,000.00 1,000.00

PlateauPipeline-SunsetPrairie 1,000.00 1,000.00

PlateauPipeline-TaylortoDawsonCreek 1,000.00 1,000.00

PlateauPipeline-WesternSystem 1,000.00 1,000.00

SpectraEnergy-BoundaryLake 1,000.00 1,000.00

SpectraEnergy-JedneyI 1,000.00 1,000.00

SpectraEnergy-JedneyII 1,000.00 1,000.00

SpectraEnergy-Midwinter 1,000.00 1,000.00

SpectraEnergy-Peggo 1,000.00 1,000.00

SpectraEnergy-Sunrise 1,000.00 1,000.00

SpectraEnergy-Sunrise 1,000.00 1,000.00

SpectraEnergy-Tooga 1,000.00 1,000.00

SpectraEnergy-WestDoe&HwyProcessing&PipelineFacilities 1,000.00 1,000.00

SpectraEnergy-WestDoe&HwyTransportation&ProcessingFacilities 1,000.00 1,000.00

$ 19,000.00 18,000.00



Miscellaneous & Total Recoveries Amounts Recovered ($) Amounts Recovered ($) 2014/2015 2015/2016

CommissionRevenuesRecovered $ 7,053,770.90 6,570,872.34

NaturalGasLicenses 9,000.00 11,000.00

Intra-ProvincialOilPipelines&OtherCompanies 19,000.00 18,000.00

RecoveryofProceedingCostsfromUtilities 960,511.14 1,192,351.53

Less:GSTTransferredtoProvincialGovernment -21,157.28 -18,534.07

Less:Repaymentof2013/2014Deficit -$698,589.71 -

PreviousYearOverorUnderRecovery - 760,958.01

MiscellaneousCrownCorporationEmployer’sAssociationDuesRebate 47.22 141.60

TotalRecoveries $ 7,322,582.27 8,534,789.41

Commission Expenditures 2014/2015 2015/2016

Salaries&Benefits $ 4,107,975.16 4,513,507.82

OperatingCosts 1,784,141.23 1,896,349.19

ProfessionalServices 669,507.87 782,928.19

TotalExpenditures $ 6,561,624.26 7,192,785.20

OverorUnderRecoveryCarriedForwardtoNextFiscalYear 760,958.01 1,342,004.21


A N N U A L R E P O R T 2 0 1 5 / 1 6 27

S U M M A RY O F D E C I S I O N S , R E A S O N S F O R D E C I S I O N A N D N E G O T I AT E D S E T T L E M E N T S

SUMMARY OF DECISIONS, REASONS FOR DECISION AND NEGOTIATED SETTLEMENTS

ACTIVE ENERGY CORP. British Columbia Pensioners’ and Seniors’ Organization, et al. Application for Reconsideration of Order A-1-13 in the Matter of the Active Energy Corp. Compliance Inquiry – Order A-5-15 and Reasons for Decision dated July 15, 2015

On March 8, 2012, the Commission, by Order A-5-12, established a compliance inquiry into 24 commercial customer disputes against Active Renewable Marketing Ltd. (Active Energy). As part of that inquiry, the Business Practices and Consumer Protection Authority (Consumer Protection BC) was retained to complete an inquiry report (report). At the conclusion of the compliance inquiry, on January 30, 2013, the Commission issued Order A-1-13, which states in Directive 3: “[t]he Consumer Protection BC Report dated June 18, 2012 is expunged from the record of this Proceeding and will not be made public.”

On February 5, 2013, the British Columbia Pensioners’ and Seniors’ Organization et al. (BCOAPO) (then known as BCPSO) submitted a letter to the Commission making the following two applications:

a. Pursuant to section 5 of the Freedom of Information and Protection of Privacy Act (FOIPPA) for a copy of the report; and

b. Pursuant to section 99 of the Utilities Commission Act (UCA) for reconsideration of the portion of Order A-1-13 which provides that the Consumer Protection BC Report will not be made public.

Access to the report was appealed by Active Energy in accordance with FOIPPA, resulting in the access request being adjudicated by the Office of the Information and Privacy Commissioner (OIPC). This process concluded with the release of Order F15-06 from the OIPC on February 19, 2015.

On May 26, 2015, the Commission requested additional comments from Active Energy and BCOAPO regarding whether BCOAPO has made a prima facie case warranting moving to the second phase of reconsideration given the contents of the order from the OIPC.

On July 15, 2015, by Order A-5-15, the Commission determined that reconsideration of Order A-1-13 was not warranted as BCOAPO did not establish: a prima facie case that the Commission erred; or that one or more of the alleged errors had material implications. As such, the Commission denied BCOAPO’s application for reconsideration.

BRITISH COLUMBIA HYDRO AND POWER AUTHORITY Application for Approval of Shore Power Rate, Rate Schedules 1280, 1891 and Shore Power Service Agreement Electric Tariff Supplement No. 86 – Order G-111-15 and Reasons for Decision dated June 25, 2015

On April 10, 2015, BC Hydro filed an application pursuant to subsection 61(1) of the Utilities Commission Act for approval of Rate Schedules 1280 and 1891, and the Shore Power Service Agreement (Electric Tariff Supplement No. 86). This application sought to expand the provision of non-firm and interruptible shore power by Port Metro Vancouver for cruise ships docked at Canada Place wharf to Port Customers for use by eligible vessels and, at the same time, expand the availability of service from the cruise season to year round service. The application was reviewed by way of a written proceeding with five interveners.

The Commission found that the need for a new shore power rate had been established and approved Rate Schedule 1280, 1891 and Tariff Supplement No. 86 and related Electric Tariff amendments as proposed.


Application for Approval of Contracted Generator Baseline Guidelines and Reconsideration and Variance of Order G-19-14 – Order G-174-15 and Decision dated October 30, 2015

This decision addressed an application by BC Hydro for approval of Contracted Generator Baseline (GBL) Guidelines (Guidelines) and reconsideration of Commission Order G-19-14, Directive 2 regarding Tariff Supplement No. 74 (Reconsideration of TS 74). The purpose of the Guidelines is to outline the framework that BC Hydro uses in setting a Contracted GBL for customers with new or incremental self-generation facilities who are considering entering into a prospective Electricity Purchase Agreement or Load Displacement Agreement with BC Hydro.

The Commission found that in the case of customers with existing self-generation, the Guidelines do establish a satisfactory framework to mitigate the risk to other ratepayers. The Commission determined that the Guidelines will apply on a prospective basis to transmission and distribution customers with existing self-generation. However, the Commission did not approve BC Hydro’s request that the Guidelines apply to customers who currently do not have any existing self-generation or new customers with self-generation.

The Commission determined that in order for the Guidelines to effectively inform the self-generating customers, Commission approval of the Guidelines was necessary.

With regard to the Reconsideration of TS 74, the Commission determined that the purpose of the Guidelines will be adequately met if they are appended to the order concluding this proceeding. In addition, the Commission directed that the Guidelines reside in the additional six places identified by BC Hydro, such as BC Hydro’s website, package materials provided to prospective customers and as an attachment to future section 71 and 44.2 Utilities Commission Act filings.

By Order G-194-15 dated December 9, 2015 the Commission approved BC Hydro’s Contracted GBL Guidelines.

Application for Indirect Interconnection Services for Transmission-Voltage Load Customers – Order G-25-16 and Reasons for Decision dated March 3, 2016

On September 14, 2015, BC Hydro applied for approval of Tariff Supplements 87 and 88 and corollary amendments to its Electric Tariff to enable the provision of transmission-voltage service to customers via the transmission facilities owned and operated by third parties.

The application was reviewed through a written hearing process that concluded with the filing of intervener arguments on December 22, 2015, and BC Hydro’s reply argument on January 8, 2016.

On March 3, 2016, the Commission issued Order G-25-16 with reasons for decision wherein it approved Tariff Supplements 87 and 88 and corollary amendments to BC Hydro’s Electric Tariff. BC Hydro was directed to provide the name and contact information of all third party owners and operators (as applicable) of shared facilities that it enters into commercial and regulatory arrangements with under subsection 3(e) of Tariff Supplement 88 prior to commencing service.

Application for Approval of Debt Management Regulatory Account – Order G-42-16 and Reasons for Decision dated March 30, 2016

On December 16, 2015, BC Hydro submitted an application for approval of a Debt Management Regulatory Account (DMRA) and for the Commission’s endorsement of BC Hydro’s debt management strategy (Application). By Order G-2-16 dated January 8, 2016, the Commission established a regulatory timetable with a workshop and one round of information requests, and sought written submissions on the review process.

The Commission reviewed the Application, evidentiary record and submissions of all parties and on March 30, 2016, issued Order G-42-16 with reasons. The Commission made the following determinations:

1. The Debt Management Regulatory Account (DMRA) as proposed by BC Hydro in its application is approved, effective the date of the order. If BC Hydro does not go forward with its proposed Debt Management Strategy within the next 12 months, this account must be automatically closed;

2. The gains or losses from Future Debt Hedges recorded in the DMRA will be amortized over the remaining term of the associated long-term debt issuances, commencing at the beginning of the test period subsequent to the test period in which the long-term debt to which the Future Debt Hedge is associated is issued;

3. Amounts amortized to finance charges from the DMRA are also eligible to be included in the calculation of Interest During Construction; and

4. BC Hydro is directed to work with Commission staff to determine the contents and timing of future reporting of the DMRA.


A N N U A L R E P O R T 2 0 1 5 / 1 6 29


BRITISH COLUMBIA SUSTAINABLE ENERGY ASSOCIATION AND THE SIERRA CLUB OF BRITISH COLUMBIA Application for Reconsideration of Order F-1-15 – Order G-71-15 and Reasons for Decision dated May 5, 2015

On January 21, 2015, the British Columbia Sustainable Energy Association and the Sierra Club of British Columbia (BCSEA-SCBC) applied for a reconsideration of Participant Assistance/Cost Award Order F-1-15. BCSEA-SCBC alleged, among other things, that:

a. the Commission failed to examine whether there was a prima facie case to warrant reconsideration;

b. the Panel presiding over Order F-1-15 was not impartial in reviewing its previous decision;

c. the Panel’s restated decision to reduce the award by $100,000 was and/or is arbitrary and excessive, warranting reconsideration; and

d. Order F-1-15 has significant material implications warranting reconsideration.

By Order G-25-15 dated February 27, 2015, the Commission established Phase Two of the reconsideration process and limited the scope of the reconsideration to whether the $100,000 reduction is arbitrary.

By Order G-71-15 dated May 5, 2015, the Commission determined that the $100,000 reduction as outlined in Orders F-28-14 and F 29-14 was not arbitrary. The reconsideration request from BCSEA-SCBC was therefore denied.

CORIX MULTI-UTILITY SERVICES INC. Final Rate Application for Phase 1 – Wesbrook of the University of British Columbia Neighbourhood District Energy System – Order G-84-15 and Reasons for Decision dated May 25, 2015

On February 10, 2015, Corix Multi-Utility Services Inc. (Corix) filed a rate application for Phase 1 – Wesbrook, which included revenue requirements, rate design and final rates. By Order G-24-15 dated February 19, 2015, the Commission established a written hearing process and a regulatory timetable.

Following a written hearing, the Commission made the following determinations:

1. Corix is directed to exclude the University of British Columbia’s 2014 project development costs totalling $298,277 from rate base and is denied approval to recover these costs from ratepayers. Corix is approved to capitalize $1.216 million of project development costs for recovery from ratepayers and is approved to amortize these costs into rates over a 30-year period;

2. The rate base for Phase 1 – Wesbrook is approved, subject to the adjustment to the project development costs;

3. The 20-year levelized rate structure for Phase 1 – Wesbrook, through which a portion of the annual revenue requirements is deferred in the early stages of development, is approved;

4. The following components of the revenue requirement for Phase 1 – Wesbrook, as outlined in the Final Rates Application, are approved:

a. deemed capital structure of 57.5 percent debt and 42.5 percent equity;

b. Long term debt financing costs estimated at 4.0 percent;

c. A return on equity of 9.5 percent; and

d. Operating costs;

5. The accounting treatment of the revenue deficiency deferral account is approved;

6. Corix’s categorization of controllable and non-controllable costs, as outlined in the Final Rates Application, is approved;

7. Corix's proposed rate design and schedule of residential rates is approved, subject to any changes to the residential rate schedule which may arise as a result of the adjustment to the project development costs;

8. Corix is directed to recalculate the levelized rate based on the adjustment to project development costs; and

9. Corix is directed to file a report to the Commission showing the balance of the revenue deficiency deferral account and the supporting calculations.


Application for a Certificate of Public Convenience and Necessity for Additional Capital and Amended Rates for UniverCity Neighbourhood Utility Service on Burnaby Mountain – Order G-215-15 and Reasons for Decision dated December 30, 2015

On October 7, 2015, Corix filed a CPCN and rates application, based on its interpretation of the Thermal Energy Systems Regulatory Framework Guidelines, for additional capital and amended rates for UniverCity Neighbourhood Utility Service on Burnaby Mountain (Application). In its Application, Corix requested approval under sections 45, 56, 60 and 61 of the Utilities Commission Act (UCA) for expenditures to replace and expand the capacity of the existing temporary natural gas facilities with a larger capacity natural gas boiler plant. Corix also requested approval of amended levelized rates. The project is to replace the existing 2.3 mega-Watt temporary boiler plant with a larger 8 mega-Watt natural gas boiler plant and distribution piping to allow connections to new buildings.

By Order G-173-15, the Commission established a regulatory timetable that provided for intervener and interested party registration, one round of Commission and intervener information requests, and a Streamlined Review Process (SRP). Following the December 16, 2015 SRP, the Commission issued Order G-215-15 with accompanying Reasons for Decision and dismissed Corix’s request for a CPCN under section 45 of the UCA on the grounds that the request was not necessary under the Thermal Energy Systems Regulatory Framework Guidelines. Approval of the rate base was granted under sections 60 and 61 of the UCA conditional on Corix removing the 2.3 mega-Watt temporary energy centre from the rate base when the new 8 mega-Watt temporary energy centre is in service. The revenue requirement and the accounting treatment for the updated revenue deferral account and rate design were approved as requested in Corix's Application.

CREATIVE ENERGY VANCOUVER PLATFORMS INC. 2015 – 2017 Revenue Requirements Application – Order G-98-15 and Decision dated June 9, 2015

On November 28, 2014, Creative Energy Vancouver Platforms Inc. (Creative Energy) filed its 2015–2017 Revenue Requirements application (RRA) seeking approval, among other things, of an increase in the Steam Tariff portion of the rates. The proposed rate increases were updated on February 27, 2015, and also through various responses to information requests by the Commission resulting in revised proposals for rate adjustments of 13.3 percent, 4.0 percent, and -0.9 percent, to be effective January 1, 2015, January 1, 2016 and January 1, 2017 respectively.

The application was reviewed through a written public hearing that concluded with the filing of Creative Energy’s reply argument on May 11, 2015. On June 9, 2015, the Commission issued its Decision, which included the following key approvals:

1. Final delivery rates for all steam customers effective January 1, 2015 of 10.0 percent, subject to the filing of the adjustments to the 2015 revenue requirements outlined in the Decision and the subsequent approval of the compliance filing dated July 30, 2015. Rate adjustments for 2016 and 2017 were denied on the basis that Creative Energy was in a period of transition and the evidence filed was found to be inconsistent and incomplete in certain areas;

2. Recognition of the After-tax Pension Asset in rate base effective January 1, 2015 by addition of $414,012, which represents the mid-year Regulatory Pension Asset;

3. A Regulatory Transitional Adjustment Deferral Account (pension related) to amortize the balance of $301,777 over a three-year period, commencing January 1, 2015;

4. The creation of a Pension Expense Deferral Account to capture the variance between the forecast Pension Expense recovered in rates and the Pension Expense reported in financial statements;

5. The amortization of the 2013/2014 Generic Cost of Capital (GCOC) Deferral Account to incorporate the impact of the 9.5 percent return on equity on the 42.5 percent equity component approved in the GCOC Stage 2 proceeding. The balance of $333,012 is to be amortized and recovered from customers over two years commencing January 1, 2016; and

6. The 2015 load forecast is accepted. However, Creative Energy is directed to consider other methods of load forecasting in its next RRA.

Application for a Certificate of Public Convenience and Necessity for a Low Carbon Neighborhood Energy System for Northeast False Creek and Chinatown Neighborhoods of Vancouver – Order C-12-15 and Decision dated December 8, 2015

Creative Energy filed an application on April 17, 2015, seeking approval for a CPCN for Phase 1 of a Low Carbon Neighbourhood Energy System (NES) for Northeast False Creek (NEFC) and Chinatown Neighbourhoods of Vancouver and a new Neighbourhood Energy Agreement (NEA) between Creative Energy and the City of Vancouver (Application). The Application also sought approval of a new Connection Agreement and various rate parameters, which define a methodology upon which a future rate application will be based.


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The Application was reviewed through two rounds of Commission and intervener information requests, a Panel information request, intervener evidence and rebuttal evidence submissions, one round of information requests on intervener evidence, an oral hearing and written argument.

The Commission approved the CPCN limited to the NEFC area for $9,345,400 plus PST, interest during construction and capitalized development costs. The Commission found there was not sufficient certainty about the load in Chinatown and there was no firm plan to connect it to the NEFC network. The Commission denied the NEA because of reasons related to denying a Carbon Reduction Rider, a Benchmark Rate, a Cost Premium Cap and potential linkage to mandatory connection policies. The Commission did not approve the Connection Agreement due to lack of information. For various reasons, the Commission approved certain aspects of the proposed rate design methodology while it deferred other aspects to future proceedings. Creative Energy also requested that a portion of the hearing costs be allocated to certain interveners. That request was denied.

FORTISBC ALTERNATIVE ENERGY SERVICES INC. Application for Approval of the Fiscal 2015/16 Revenue Requirements and Cost of Service Rates for Thermal Energy Service to Delta School District Number 37 – Order G-146-15A and Reasons for Decision dated September 18, 2015; Order G-213-15 dated December 24, 2015

On April 29, 2015, FortisBC Alternative Energy Services Inc. (FAES) filed its application for Approval of the Fiscal 2015/16 Revenue Requirements and Cost of Service Rates for Thermal Energy Service to Delta School District Number 37 (Application).

The Application was reviewed through a written review process. On September 18, 2015, the Commission issued Order G-146-15A, directing FAES to file additional information and submissions on various issues as outlined in the Reasons for Decision and attached as Appendix A to the order. On November 17, 2015, FAES submitted its compliance filing with the additional requested information and submissions.

On December 24, 2015, the Commission issued Order G-213-15 with Reasons for Decision. The Commission approved the forecast cost of service rate of $0.185/kWh for the contract year from July 1, 2015 to June 30, 2016, and accepted FAES’ proposed wording change to the Rate Development Agreement.

The Commission also indicated that the utility’s action of retrospectively adjusting all of the forecasts to actual costs incurred rendered the Commission’s annual approval of the forecast costs to be moot. Accordingly, the Commission urged FAES to apply for a variance and reconsideration amending the requirement to provide annual revenue requirement filings to the Commission, until such time that a fundamental change in rate structure or rate methodology exists or if a complaint has been received by the Commission.

In addition, FAES was directed to provide, at the time of filing the next annual rate filing, a report detailing the following:

1. The amount spent on specialized contractors during the 2014/2015 and 2015/2016 fiscal periods;

2. The status of the heat pump issues identified in this fiscal period; and

3. The forecast cost, if any, to resolve the heat pump issue.

FORTISBC INC. Application for Stepped and Stand-by Rates for Transmission Voltage Customers – Stage III Stand-by Rates – Order G 93 15 and Decision dated May 29, 2015

The Stage III of FortisBC Inc’s (FortisBC) Stepped and Stand-by Rates Decision addressed Rate Schedule 37 Stand-by Rates (RS 37) for FortisBC and represents the final step in reviewing the Stepped and Stand-by Rate. Certain aspects of the Rate were already addressed in Stages I and II. The Stage III Decision addressed the remaining issue regarding a penalty piece and certain outstanding Celgar specific issues.

In Order G-93-15 and the accompanying decision, the Commission approved the final form of RS 37 subject to the changes directed in the Decision with regard to the Celgar specific issues. The Commission also approved Celgar’s RS 31 Contract Demand at 3 MVA and its Stand-by Demand Limit at 42 MVA and urged the parties to continue to negotiate and agree on a Stand-by Billing Demand.


Application for Approval of 2015 Rates Pursuant to the Multi-Year Performance Based Ratemaking Plan Approved for 2014 through 2019 by Order G-139-14 – Order G-107-15 and Reasons for Decision dated June 23, 2015

On February 6, 2015, FortisBC submitted an application for its annual review of 2015 rates (Application). The Application was reviewed through a written hearing process and on June 23, 2015, the Commission issued Order G-107-15 with Reasons for Decision approving the following:

1. FortisBC’s existing interim rates as permanent effective January 1, 2015;

2. The establishment of the following two non-rate base deferral accounts:

a. Residual Capacity Agreement Tariff Supplement 10 and Rate Schedule 111, financed at FortisBC’s short term interest rate, to be amortized in 2015; and

b. 2015 – 2016 Demand Side Management Plan Application, financed at FortisBC’s short term interest rate, to be amortized in 2015;

3. The establishment of the proposed deferral account for the 2016 Long Term Electric Resource Plan Development costs subject to certain conditions;

4. A three year amortization period for the Interim Rate Variance deferral account, with amortization of 20 percent of the opening balance in 2015; and

5. The inclusion of the Pension and OPEB Funding Liability deferral account in rate base.

In addition to these approvals, FortisBC was also directed to:

1. Update its short term interest rate forecast to reflect more recent information;

2. Include a discussion on whether the Generator Forced Outages Rate should be moved from an informational Service Quality Indicator (SQI) and added to the list of measurable SQIs in its next Annual Review Application; and

3. Provide the complete engineering root cause analysis reports for the South Slocan Unit 1 and Corra Linn Unit 2 generator outages along with supplemental documentation.

The general rate increase was approved effective August 1, 2015, to be applied to the Residential Conservation Rate (Rate Schedule 1) in accordance with the pricing principles set out in Order G-3-12.

Application for Stepped and Stand-by Rates for Transmission Voltage Customers - Stage IV - Stand-by Billing Demand for Zellstoff Celgar Limited Partnership – Order G-149-15 and Decision dated September 22, 2015

In the Stage IV of FortisBC’s Stepped and Stand-by Rates Decision, the Commission determined a Stand-by Billing (SBBD) Demand for Zellstoff Celgar Limited Partnership (Celgar), as FortisBC and Celgar were not able to agree on one.

In arriving at its determination, the Commission recognized that there was no single, correct approach to setting a SBBD for Celgar. After considering a variety of approaches, the Commission set the SBBD at 40 percent of Celgar’s Stand-by Demand Limit or 16.8 MVA. The Commission concluded that the resultant wires charge would not lead to a rate that was unjust, unreasonable, unduly discriminatory or unduly preferential.

The Commission also directed the parties to attempt to negotiate a resolution on the retroactive billing determination due to the interim nature of service provided by FortisBC to Celgar since March 25, 2011.

Application for Stepped and Stand-by Rates for Transmission Voltage Customers - Stage V – Order G-214-15 and Decision dated December 24, 2015

The Stage V of FortisBC’s Stepped and Stand-by Rates Decision reviewed a joint request by FortisBC and Zellstoff Celgar Limited Partnership (Celgar) to approve: (i) a negotiated refund of $7.65 million plus interest to Celgar for billing charges over an interim period which commenced on March 25, 2011; and (ii) a request to create a deferral account to recover these amounts from ratepayers.

The Commission approved the negotiated refund and interest amounts on the basis that they were less that the estimated billing charges calculated in accordance with Commission approved RS 31 and RS 37, which are just and reasonable rates in accordance with the Utilities Commission Act. The Commission also approved FortisBC’s request for deferral account treatment.


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Annual Review of 2016 Rates Application - Order G-202-15 dated December 14, 2015 and Reasons for Decision dated January 7, 2016

On September 11, 2015, FortisBC submitted an application for its annual review of 2016 rates (Application) seeking approval for an interim rate increase of 1.98 percent, effective January 1, 2016, pending the outcome of the FEI application for a Common Equity Component and Return on Equity for 2016 proceeding. On October 21, 2015, FortisBC submitted an evidentiary update to the Application amending the requested interim rate increase to 3.12 percent. The Application was reviewed by way of a written proceeding.

By Order G-202-15, dated December 14, 2015, FortisBC’s permanent rate increase effective January 1, 2016, was approved subject to other adjustments. The approvals granted include:

• FortisBC’s proposed depreciation and net salvage rates;

• The z-factor or exogenous treatment of FortisBC’s incremental costs relating to the changes to BC’s Mandatory Reliability Standards program; and

• The requested amortization of FortisBC’s 2015 closing balance of the 2014 Interim Rate Variance deferral account.

FortisBC’s request to recover from all customers the Advanced Metering Radio-off shortfall amounts, estimated at $0.168 million and $0.392 million for 2015 and 2016 respectively, was denied. Instead, FortisBC was directed to record the shortfall amounts in a deferral account the disposition of which will be determined in the future. FortisBC was also directed to file its 2015 actual All Injury Frequency Rate Service Quality Indicator (SQI) results as soon as the results are available.

Application for a Certificate of Public Convenience and Necessity for Construction of the Kootenay Operations Centre – Order C-2-16 and Reasons for Decision dated March 4, 2016

On July 9, 2015, FortisBC applied to the Commission for a CPCN, pursuant to sections 45 and 46 of the Utilities Commission Act, for approval of the construction of the Kootenay Operations Centre (KOC or Project) and associated land costs. The scope of the Project as outlined in the application included:

• construction of a new operations centre located in the Castlegar area,

• the demolition of the end-of-life South Slocan Generation Administration Office and Warehouse building and relocation of the associated functions to the KOC,

• a new central and dedicated Emergency Operations Centre for the Kootenay region,

• the elimination of functional concerns and risks associated with the System Control Centre and the Backup Control Centre; and

• relocation of the Kootenay Station Services group to the more centralized KOC location.

During the written hearing process, FortisBC requested the scope of the Project to be expanded to include the removal of the near end-of-life Castlegar District Office from service and the relocation of the associated functions to the KOC. FortisBC estimated the total capital cost of the revised Project in as-spent dollars to be approximately $22.355 million.

The Commission granted the CPCN for the revised Project and determined that the cost of the project will be recovered from ratepayers separately from FortisBC’s capital spending envelope previously established by the Performance Based Ratemaking formula. FortisBC was also directed to file several reports with the Commission concerning project reporting and asset change of use.

2015 Self-Generation Policy Application – Order G-27-16 and Stage I Decision dated March 4, 2016

On January 9, 2015, FortisBC filed a self-generation policy application (Application) in compliance with Directive 5 of Order G-60-14, in the BC Hydro Application for a New Power Purchase Agreement between BC Hydro and FortisBC under Rate Schedule 3808 (New PPA Decision).

Following a procedural conference held on February 5, 2015, attended by FortisBC and all seven interveners, the Commission found that there was merit in having a two staged approach whereby in Stage I the Commission makes certain findings on the High Level Policy Statement and Supporting Policies put forward in the Application, to establish building blocks for Stage II. To assist the Commission in making its findings, it sought submissions from the parties to obtain their positions on the relevance and applicability of past decisions as well as certain other issues identified by the Panel.


The Commission considered the Application and submissions from the parties and issued its decision concurrently with Order G-27-16, on March 4, 2016. The Commission found that the High Level Policy Statement and Supporting Policies were not comprehensive enough to form an overarching self-generation policy that would result in the eventual removal of the Section 2.5 Restrictions as set out in the New PPA and directed FortisBC to make, within 120 days of the date of the Decision, a Stage II filing that includes a comprehensive self-generation policy and an application for generator baseline guidelines. The remainder of the Decision provided FortisBC with guidance and recommendations it needs to consider in the Stage II filing.

FORTISBC ENERGY INC. Annual Review of 2015 Delivery Rates pursuant to the Multi-Year Performance Based Ratemaking Plan approved for 2014 through 2019 by Order G-138-14 – Order G-86-15 and Decision dated May 27, 2015

On January 14, 2015, FortisBC Energy Inc. (FEI) submitted its application for the annual review of 2015 delivery rates (Application). By Order G-6-15, the Commission established a regulatory timetable that provided for intervener and interested party registration, one round of Commission and intervener information requests, a workshop to review FEI’s 2014 performance results and 2015 revenue requirements, a response by FEI to undertakings arising from the workshop, and written final and reply submissions.

The Commission considered the Application, evidence and submissions from the parties and, on May 27, 2015, the Commission issued its Decision concurrently with Order G-86-15. The Commission made the following determinations:

1. FortisBC Energy Inc.’s requested permanent delivery rates for all non-bypass customers effective January 1, 2015, representing an increase of 2.03 percent compared to 2014 common delivery rates, are not approved as filed. Permanent delivery rates for all non-bypass customers effective January 1, 2015, as modified by the directives in the Decision, were approved;

2. FortisBC Energy Inc. is directed to re-calculate 2015 delivery rates and file revised financial schedules with the Commission reflecting the changes outlined in the Decision by June 30, 2015;

3. FortisBC Energy Inc. is directed to collect from/refund to customers the difference between the 2015 interim rates and permanent rates, including the Earnings Sharing rate rider for Mainland customers, with interest at the average prime rate of the Company’s principal bank, by way of a bill adjustment reflecting customers’ consumption from January 1, 2015.

Application for Approval of 2015-2016 Revenue Requirements and Rates for the Fort Nelson Service Area – Order G-97-15 and Decision dated June 10, 2015

On December 3, 2014, FEI submitted its 2015-2016 revenue requirements and rates application for the Fort Nelson service area. By Order G-192-14, the Commission approved, on an interim and refundable basis, the delivery rates and Revenue Stabilization Adjustment Mechanism rate rider as set forth in the application, effective January 1, 2015. The Commission also established a regulatory timetable that provided for intervener and interested party registration and one round of Commission and intervener information requests, followed by written submissions from all parties on further regulatory process. By letter dated February 17, 2015, the Commission established the remainder of the Regulatory Timetable, which included a second round of information requests and final written and reply submissions.

The Commission reviewed the application, evidence and submissions from the parties and on June 10, 2015, issued its Decision concurrently with Order G-97-15. The Commission made the following determinations:

1. FortisBC Energy Inc.’s requested permanent delivery rate increases for 2015 and 2016 for the Fort Nelson service area are not approved as filed. Permanent 2015 and 2016 delivery rate increases, as modified to reflect the directives in the Decision, are approved;

2. The Revenue Stabilization Adjustment Mechanism rate rider is approved on a permanent basis at $0.039 per gigajoule, effective January 1, 2015; and

3. FortisBC Energy Inc. is directed to collect from/refund to customers as soon as possible the difference between the 2015 interim rates and permanent rates, with interest at the average prime rate of the Company’s principal bank, by way of a bill adjustment reflecting customers’ consumption from January 1, 2015.


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Proposal to include FortisBC Energy (Vancouver Island) Inc. and FortisBC Energy (Whistler) Inc. in the 2014-2019 Multi-Year Performance Based Ratemaking Plan – Order G-106-15 and Decision dated June 23, 2015

On November 14, 2014, FEI filed its application to include FortisBC Energy (Vancouver Island) Inc. (FEVI) and FortisBC Energy (Whistler) Inc. (FEW) in the Performance Based Ratemaking Plan and requested approval of the following:

• An increase to its 2014 Base Operations and Maintenance (O&M) by $39.295 million, which includes an increase of $36.564 million to reflect the O&M required for FEVI and FEW, and a further increase of $2.731 million to reflect projected FEVI 2014 Company Use Gas;

• An increase to its 2014 Base Capital by $28.222 million to reflect the Capital Expenditures required for FEVI and FEW (Application).

On November 24, 2014, Order G-183-14 established a preliminary regulatory timetable that included a procedural conference on December 17, 2014. By Order G-202-14 dated December 19, 2014, the Commission established a regulatory timetable that provided for FEI’s filing of an Evidentiary Update, one round of Commission and intervener information requests, followed by written submissions from all parties on further regulatory process. On March 23, 2015, the Commission, by Order G-41-15, amended the Regulatory Timetable to include a second round of information requests to complete the evidentiary record.

The Commission reviewed the Application, evidence and submissions from the parties and issued its decision concurrently with Order G-106-15, on June 23, 2015. The Commission made the following determinations:

1. FEI is approved to increase its 2014 O&M by $38.498 million ($35.213 million for FEVI O&M, $696 thousand for FEW O&M and $2.589 million to reflect the re-classification of FEVI’s Company Use Gas and gas control management fees from cost of gas to O&M).

2. FEI is also approved to increase its 2014 Base Capital by $21.964 million ($21.564 million for FEVI capital expenditures and $400 thousand for FEW capital expenditures).

An Application for Reconsideration of Order G-187-14, Amending the Balancing Gas Charges for Rate Schedules 23, 25, 26 and 27 – Order G-135-15 and Reasons for Decision dated August 13, 2015

On May 20, 2015, FEI filed an application to reconsider Commission Order G-187-14 in regard to FEI’s request to amend the charges for Balancing Gas incurred under FEI’s monthly balanced transportation service provided under Rate Schedules 23, 25, 26 and 27 (Reconsideration Application). In particular, FEI sought to reconsider and vary Directive No. 2 of Order G-187-14, and requested that the deadline for the filing of the Monthly Balancing Rate Design application be extended to December 31, 2016, and that FEI have the option of either filing it as part of the Comprehensive Rate Design application or as a separate application filed along with the Comprehensive Rate Design application.

On June 3, 2015, the Commission issued Order G-94-15 accepting that FEI established a prima facie case to warrant proceeding to Phase 2 of the reconsideration process and set out a regulatory timetable.

Following a written hearing process, the Commission granted the reconsideration with the following determinations:

1. The deadline for FEI to file a Monthly Balancing Rate Design application is extended to December 31, 2016;

2. FEI shall apply for a rate design on Monthly Balanced Transportation Service either as part of a broader rate design application as ordered by G-21-14, or as a separate filing along with the broader rate design application no later than December 31, 2016;

3. FEI is directed to add the following to the list of issues to be reviewed in the rate design on Monthly Balanced Transportation Service:

a. The appropriateness of the business practice of allowing transfers of imbalances between daily balanced and monthly balanced accounts; and

b. The extent of FEI’s use of core gas cost resources to balance the overall transportation service imbalances for each day and the cost to the core customers; and

4. All other directives and determinations in the decision and Order G-187-14 dated December 1, 2014 remain effective.


Certificate of Public Convenience and Necessity Application for the Lower Mainland Intermediate Pressure System Upgrade Projects – Order C-11-15 and Decision dated October 16, 2015

On December 19, 2014, FEI filed its application for a CPCN for the Lower Mainland Intermediate Pressure System Upgrade (LMIPSU) Projects, which sought approval to construct and operate two intermediate pressure (IP) pipeline segments in the BC Lower Mainland to replace two existing segments (Application). The two projects are described as follows:

• A Nominal Pipe Size (NPS) 30” pipeline of approximately 20 km operating at 2070 kPa between Coquitlam Gate Station and the East 2nd Avenue and Woodland Station in East Vancouver to replace an existing NPS 20” pipeline (Coquitlam Gate IP Project);

• A small segment of NPS 30” pipeline between the Fraser Gate Station and East Kent Avenue and Elliot Street (Fraser Gate IP Project).

The Application was reviewed through a written public hearing process that included a workshop and procedural conference. The hearing process concluded with the filing of FEI’s reply argument on August 14, 2015.

The Commission issued Order C-11-15 and accompanying decision on October 16, 2015, approving the construction and operation the Fraser Gate and Coquitlam Gate IP Projects as outlined in the Application and subsequent evidentiary update. Other considerations addressed within the decision included environmental, archaeological and socio-economic assessments, provincial government energy objectives, consultation processes and performance based ratemaking (PBR) base capital and O&M considerations.

FEI is required to report on construction related issues set out under Sections 2.3.3, 2.3.5, 2.3.6 and route change updates under Section 2.3.4, as well as filing Quarterly Progress Reports starting in March 2016, Material Change Reports, and a Final Report on the projects.

Annual Review of 2016 Rates Application - Order G-193-15 dated December 7, 2015 and Reasons for Decision dated December 21, 2015

On September 3, 2015, FEI submitted its application for the annual review of 2016 rates (Application). By Order G-138-15, the Commission established a regulatory timetable that provided for intervener and interested party registration, one round of Commission and intervener information requests, a workshop to review FEI’s 2015 performance results and 2016 revenue requirements, a response by FEI to undertakings arising from the workshop, and written final and reply submissions.

The Commission considered the Application, evidence and submissions from the parties and on December 7, 2015, issued Order G-193-15 with Reasons for Decision to follow. The Commission made the following determinations:

1. FEI’s requested interim delivery rates for 2016 are not approved as filed.

2. FEI’s requested changes to depreciation and net salvage rates are denied and FEI is directed to maintain existing depreciation and net salvage rates until otherwise directed by the Commission.

3. FEI is further directed to submit additional information and analysis on depreciation and net salvage rate changes, as outlined in the Reasons for Decision, by February 29, 2016.

4. Interim delivery rates for all non-bypass customers effective January 1, 2016, as modified by the adjustments to FEI’s 2016 revenue requirements resulting from the Commission’s determinations on depreciation and net salvage rates, are approved.

5. FEI’s request for 2016 delivery rates to remain interim pending the outcome of the FEI cost of the capital proceeding is approved and the Commission determined that FEI’s existing capital structure and return on equity is made interim effective January 1, 2016, and will remain in force until otherwise directed by the Commission in the cost of capital proceeding.

On December 21, 2015, the Commission issued the Reasons for Decision corresponding to Order G-193-15.

Application for Acceptance of the Biomethane Purchase Agreement between FEI and the City of Surrey – Section 71 Filing and Approval of the Monthly Facility Fee – Order E-3-16 and Reasons for Decision dated February 29, 2016

On November 24, 2015, FEI filed an application for acceptance of an executed Biomethane Purchase Agreement between FEI and the City of Surrey dated September 16, 2015 (Agreement), and for approval of a Monthly Facilities Fee (together, the Application). The Agreement is a 25-year agreement under which the City of Surrey will sell biomethane to FEI. In connection with the Agreement, the City of Surrey will re-purchase notional renewable natural gas that it produces from FEI. The Agreement also enables FEI to recover all costs of the interconnection facilities.


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By Orders G-186-15 and G-3-16, the Commission established a written hearing process and a regulatory timetable for the review of the Application. On January 19, 2016, FEI filed an Amending Agreement with the City of the Surrey dated January 19, 2016. The Commission found that the Agreement as amended by the Amending Agreement is in the public interest under section 71 of the Utilities Commission Act and the Monthly Facilities Fee is just and reasonable under sections 59 to 61 of the Utilities Commission Act.

FORTISBC ENERGY INC. AND FORTISBC INC. Multi-Year Performance Based Ratemaking Plans for 2014 through 2019 - Approved by Decisions and Orders G-138-14 and G 139 14 - Capital Exclusion Criteria under PBR – Compliance Filing – Order G-120-15 and Reasons for Decision dated July 22, 2015

On January 30, 2015, FortisBC and FEI filed the capital exclusion criteria compliance filing in accordance with Commission Orders G-138-14 and G-139-14 and accompanying Decisions on the FortisBC and FEI Performance Based Ratemaking (PBR) Plans for 2014 through 2019.

The review process for the compliance filing was established on pages 180 and 181 of the FEI PBR Decision and pages 174 and 175 of the FortisBC PBR Decision. Submissions on FortisBC’s proposed changes to the Capital Exclusion thresholds and criteria were received from the British Columbia Old Age Pensioners’ Organization et al., the Commercial Energy Consumers Association of British Columbia, and the Industrial Customers Group. FortisBC filed its reply on April 24, 2015.

On July 22, 2015, the Commission issued Order G-120-15 with reasons for decision wherein for the purpose and duration of the current PBR Plans for FortisBC and FEI the following determinations are made, pursuant to section 60 of the Utilities Commission Act:

• FortisBC’s and FEI’s PBR materiality thresholds are set at $20 million and $15 million, respectively. These materiality thresholds shall be used to determine whether capital costs are eligible for exclusion from FortisBC’s and FEI’s formula-driven capital spending.

• The Certificate of Public Convenience and Necessity (CPCN) dollar threshold will be maintained at $20 million dollars for FortisBC and increased from $5 to $15 million dollars for FEI. However, the Commission may require a CPCN review for projects below this threshold if it finds that pursuant to section 45 of the Utilities Commission Act it is in the public interest to do so.

• For any capital project applications that exceed the PBR materiality threshold, FortisBC and FEI are directed to demonstrate to the Commission that the project applied for is not the result of combining smaller projects and that the actual costs fall above the PBR materiality threshold.

• Should the dead-band for annual capital expenditures approved in the PBR Plans be exceeded FortisBC or FEI are directed to include in its next Annual Review filing, recommendations as to any adjustment to base capital (re-basing) for Commission approval.

FORTISBC ENERGY UTILITIES Application for Removal of the Restriction on the Location of Data and Servers Providing Service to the FEU, currently Restricted to Canada - Order G-161-15 and Decision dated October 13, 2015

On August 1, 2014, the FortisBC Energy Utilities (FEU) filed an application for the removal of a restriction on the location of FEU’s data and servers. FEU were restricted from locating their data and servers outside of Canada unless the Commission consents to a specific application by FEU to do so. FEU’s request included a requirement that specific data be encrypted or de-identified, as a security and privacy measure, if stored outside of Canada. The keys to the encryption and de-identification would be stored in Canada.

The Commission considered FEU’s application pursuant to section 44 of the Utilities Commission Act and used a benefit-risk assessment to determine whether the proposal was in the public interest. The Commission focused on the differences between the status quo under the restriction and the FEU application. Given that the risks of data being stored outside of Canada are adequately mitigated, the Commission considered that it is in the public interest for FEU to be given the opportunity to pursue the potential benefits. The Commission approved FEU’s request subject to the company remaining a Canadian owned and controlled company located in Canada.


FORTISBC MIDSTREAM INC. Application for the Acquisition of the Shares of Aitken Creek Gas Storage ULC – Order G-39-16 and Reasons for Decision dated March 18, 2016

On December 17, 2015, FortisBC Midstream Inc. (FMI) applied to the Commission pursuant to section 54 of the Utilities Commission Act, for approval of the acquisition by FMI of the issued and outstanding shares of Aitken Creek Gas Storage ULC (ACGS) from Chevron Canada Properties Limited (Application). Approval of the acquisition will result in ACGS becoming a wholly owned direct subsidiary of FMI.

FMI is a wholly owned subsidiary of FortisBC Holdings Inc., which is a wholly owned subsidiary of Fortis Inc. ACGS owns a 93.8 percent interest in the underground reservoir and contained natural gas, wells, on-site equipment and other components of the natural gas storage facility at Aitken Creek, as they may be modified or expanded from time to time and owns 100 percent of the rights to the undeveloped North Aitken Creek gas storage site.

The Commission reviewed the Application through a written hearing process and by Order G-39-16 approved the Application with the following conditions:

1. ACGS must file with the Commission a Code of Conduct and a Transfer Pricing Policy, which covers the interactions between ACGS and its affiliated natural monopoly utilities, and interactions between ACGS and its affiliated non-regulated businesses, and ACGS and its affiliated regulated businesses operating in a non-natural monopoly environment;

2. FMI must require all ACGS/FMI directors and executives who also have management roles with FortisBC Energy Inc. to execute non-disclosure agreements;

3. FMI must file with the Commission an Action Plan within 30 days of the share acquisition date; and

4. ACGS is to file an Implementation Assessment Report within 60 days following the one year anniversary of the share acquisition date.

INSURANCE CORPORATION OF BRITISH COLUMBIA 2014 Revenue Requirements Application – Order G-81-15 and Decision dated May 19, 2015

On August 29, 2014, the Insurance Corporation of British Columbia (ICBC) filed its Revenue Requirements application (Application) for Universal Compulsory Automobile Insurance (Basic insurance) for the policy year commencing November 1, 2014, seeking a 5.2 percent rate increase as set out in the Application. ICBC also sought approval of a revised New Money Rate to be used in the determination of investment income to calculate the investment component of the Basic insurance rate indication for Policy Year 2014.

The Application was reviewed by way of a written public hearing process, which included two rounds of information requests and an intervener evidence process. Upon consideration of the actuarial and non-actuarial components of the Policy Year 2014 indicated rate change, the Commission approved the 5.2 percent requested rate increase. The Commission also approved the revised New Money Rate formula to align with the current ICBC Statement of Investment Policy and Procedures.

PACIFIC NORTHERN GAS LTD. Application for No Changes to 2015 Delivery Rates and Changes to the 2015 RSAM Rider for the PNG-West Service Area – Order G-104-15A and Reasons for Decision dated June 18, 2015

On November 28, 2014, Pacific Northern Gas Ltd. (PNG) filed its application for No Changes to 2015 Delivery Rates and Changes to the Revenue Stabilization Adjustment Mechanism (RSAM) rate rider for its West division, pursuant to sections 59 to 61 of the Utilities Commission Act.

On March 9, 2015, PNG filed an updated application with actual 2014 results. The updated application requested Commission approval to retain the 2014 approved delivery rates and increase the RSAM rate rider effective January 1, 2015. On April 28, 2015, the Commission issued Order G-66-15 amending the Regulatory Timetable established by Order G-195-14, and establishing a Streamlined Review Process (SRP) for the review of the application. The SRP was held on June 3, 2015.

Following the SRP, the Commission issued its Decision concurrently with Order G-104-15A, approving the requests to maintain the current 2014 delivery rates approved by Order G-87-14 on a permanent basis, effective January 1, 2015 and change to the annualized RSAM rider to $0.243/GJ, effective January 1, 2015. Among other things, the Decision also varied Order G-87-14 to eliminate the requirement to amortize the LNG Partners Option Fee deferral account in 2015 and directed PNG to establish a 2015 revenue deficiency regulatory account for the adjusted revenue deficiency, which is $175,000, less the adjustments as directed by the Commission in Order G-104-15A.


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Application for a Certificate of Public Convenience and Necessity to Construct and Operate an Interconnecting Pipeline between Kitimat and Douglas Channel Order C-10-15A and Decision dated October 9, 2015

On July 16, 2015, PNG applied for a CPCN to construct and operate an interconnecting natural gas transportation pipeline of either 10-inch or 30-inch diameter from Kitimat extending approximately eight kilometers along the west side of Douglas Channel. PNG also requested approval of two transportation reservation agreements for service on the proposed pipeline, one with EDF Trading Limited in relation to the proposed Douglas Channel LNG project and the other with Triton LNG Limited Partnership in relation to the proposed Triton LNG project.

The application was reviewed through a written hearing process. On October 9, 2015, the Commission issued its Decision concurrently with Order C-10-15A which:

1. granted a CPCN to construct and operate either: a 10-inch diameter transmission pipeline and related compression and metering facilities; or a 30-inch diameter transmission pipeline, related metering facilities and electrically-driven compression facilities;

2. ordered PNG to apply for a new CPCN for the compression facilities with justification and consideration of the British Columbia energy objectives in Part 1, section 2 of the Clean Energy Act should PNG proceed with the 30-inch option and wish to utilize a non-electric compression drive; and

3. granted approval of both transportation reservation agreements.

PACIFIC NORTHERN GAS (N.E.) LTD. – DAWSON CREEK DIVISION Application for Approval of AltaGas Ltd. Industrial Firm Transportation Service Agreement and Proposed RS 7 Industrial LNG Firm Transportation Service Tariff Order G-154-15 and Reasons for Decision dated September 24, 2015

On June 16, 2015, Pacific Northern Gas (N.E.) Ltd. [PNG (N.E.)] applied to the Commission for approval of an Industrial Firm Transportation Service Agreement (TSA) between PNG (N.E.) and AltaGas Ltd. as well as a proposed new Rate Schedule 7 Industrial Liquefied Natural Gas (LNG) Firm Transportation Service Tariff (RS 7) (together, the Application), with a target in-service date of October 1, 2015.

By Order G-117-15, the Commission established a regulatory timetable that included one round of information requests followed by written final and reply arguments. As part of Order G-117-15, the Commission also directed PNG (N.E.) to file certain additional information to supplement the Application. On July 28, 2015, the Commission issued Order G-128-15, which directed PNG (N.E.) to re-submit part of its supplemental filing related to the calculation of AltaGas Ltd.’s cost to bypass PNG (N.E.)’s service area. The Commission also amended the Regulatory Timetable to provide for a separate round of information requests focused solely on PNG (N.E.)’s re-submitted information on AltaGas Ltd.’s bypass costs.

The Commission reviewed the Application, evidence and submissions from the parties and on September 24, 2015, issued Order G-154-15 and accompanying Reasons for Decision. The Commission made the following determinations:

1. The TSA between PNG (N.E.) and AltaGas Ltd., and the negotiated rate to be charged to AltaGas Ltd., was approved.

2. The proposed RS 7 was denied. PNG (N.E.) must file with the Commission by no later than 30 days from the date of the order a revised tariff and rate schedule that establishes term and conditions of service under which other customers in addition to AltaGas Ltd. may take service. As part of the filing, PNG (N.E.) must address the concerns outlined by the Panel in the Reasons for Decision attached as Appendix A to the order regarding the structure of the proposed RS 7.

PACIFIC NORTHERN GAS (N.E.) LTD. 2015 Resource Plan for the Fort St. John, Dawson Creek and Tumbler Ridge Distribution Systems Order G-155-15 and Decision dated September 30, 2015

On April 17, 2015, PNG (N.E.) filed its 2015 Resource Plan for its Fort St. John, Dawson Creek and Tumbler Ridge distribution pipeline systems. Following a written hearing, the Commission accepted the PNG (N.E.) 2015 Resource Plan pursuant to section 44.1(6) of the Utilities Commission Act. The Commission confirmed the directive in Order G-140-14 for PNG-West and PNG (N.E.) to file their resource plans on a consolidated basis no later than April 8, 2019.


PACIFIC NORTHERN GAS LTD. AND PACIFIC NORTHERN GAS (N.E.) LTD. 2015 Consolidated Energy Management and Efficiency Program Funding Plan – Order G-203-15A and Decision dated December 16, 2015

On June 26, 2015, Pacific Northern Gas Ltd. and Pacific Northern Gas (N.E.) Ltd. (collectively, PNG) filed an application for acceptance of the 2015 Consolidated Energy Management and Efficiency Program Funding Plan (Application). In the Application, PNG requested acceptance of demand side measure (DSM) expenditures of up to $67,000 for 2015, up to $400,203 for 2016, up to $362,639 for 2017, and up to $410,424 for 2018. PNG also requested flexibility in the reallocation of expenditures amongst DSM programs and between program years, and approval for all DSM expenditures to be recorded in a rate base regulatory asset deferral account with an amortization period of ten years.

By Order G-115-15 dated July 7, 2015, the Commission established a written hearing process and a regulatory timetable, with two rounds of information requests to review the Application. Following a written hearing, the Commission accepted PNG’s 2015–2018 DSM expenditure schedule as an initial first step only. The Commission encouraged PNG to file supplemental DSM expenditure schedules during the 2015–2018 period to expand the scope and breadth of PNG’s DSM programs and improve the cost effectiveness of the portfolio. The Commission also approved the requested flexibility in the reallocation of expenditures amongst DSM programs and between years, and the creation of a rate base regulatory asset deferral account to capture DSM expenditures with an amortization period of five years (as opposed to the ten year period requested).

SILVERSMITH POWER AND LIGHT CORPORATION 2015 Revenue Requirements and Rates Application – Order G-144-15 and Decision dated September 3, 2015

On May 12, 2015, Silversmith Power and Light Corporation (Silversmith) filed an application seeking, among other things, approval to change electricity rates and tariff terms and conditions for electrical service (Application). In the Application, Silversmith also requested approval of a flow-through rate adjustment mechanism to match rates to those of BC Hydro.

The Application was reviewed through a written hearing process. Order G-144-15 was issued on September 3, 2015, wherein the Commission approved some, but not all, of the requested changes to electricity rates and tariff terms and conditions, and the use of a flow-through rate adjustment mechanism.

SOBEYS WEST INC. Application for Reconsideration of Order G-69-15 – Order G-136-15 dated August 14, 2015

On October 31, 2014, Sobeys West Inc.(Sobeys), a BC Hydro General Service customer, filed a complaint with the Commission concerning the treatment of new customers under the BC Hydro Electric Tariff and Medium General Service (MGS) and Large General Service (LGS) rate.

After acquiring several Safeway stores through an asset purchase, Sobeys was treated as a new customer which caused Sobeys to be billed approximately $900,000 more than if they were not treated as a new customer. Since Sobeys acquired the Safeway stores, they did not change the operations of the Safeway stores and thus the electricity consumption did not change. In the complaint, Sobeys felt they should inherit the Safeway LGS baselines and requested an amendment to the Tariff so that the new customer treatment would not apply to situations like theirs. The Commission issued Order G-69-15 denying the relief sought by Sobeys because the new customer treatment was specifically contemplated for asset purchases in the 2009 LGS rate proceeding.

On June 5, 2015, Sobeys filed for reconsideration of Order G-69-15. In Phase 1 of the reconsideration process, BC Hydro suggested the Commission could provide relief to Sobeys by waiving charges under section 63 of the Utilities Commission Act. The Commission concluded that relief should be provided given that both parties were amenable to a waiver, that Sobeys was not trying to game the rate, and that BC Hydro ratepayers would not be impacted by waiving the charges. The Commission issued Order G-136-15 directing BC Hydro to waive approximately $900,000 pursuant to section 63 of the UCA.

By Order G-142-15 dated August 27, 2015 the Commission varied the directive in Order G-136-15 and directed BC Hydro to waive the difference in the amount Sobeys is to be billed under the MGS 85/15 Rate and the LGS 85/15 Rate for the first 12 months following Sobeys acquisition of Safeway, as compared to the billing under the MGS rate and the LGS rate using the Safeway General Service baselines (approximately $900,000).


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SUPERIOR PROPANE Status as Public Utility in British Columbia for the Operation of a Propane Distribution System at Seascapes Development Ltd. – Order G-133-15 and Reasons for Decision dated August 7, 2015

On February 26, 2014 and March 25, 2014, the Commission received complaints from the Property Manager of a 100-unit strata development property called Seascapes, located in West Vancouver, British Columbia, and a resident of Seascapes, regarding propane services supplied by a division of Superior Plus LP doing business under the name Superior Propane. The Commission established a written hearing process to review Superior Propane’s status as a public utility in British Columbia for the operation of a Propane Distribution System at Seascapes Development Ltd.

By Order G-133-15, the Commission determined that Superior Propane is a public utility as defined in section 1 of the Utilities Commission Act and is therefore providing a regulated service of delivering and selling gaseous propane to the strata development property at Seascapes. The Commission ordered Superior Propane to either apply for an exemption from regulation or file rates with the Commission for approval. The current rates that Superior Propane charges to its customers at Seascapes were approved as interim as of August 7, 2015 and are subject to adjustment with short-term interest subsequent to the Commission’s further review.


S U M M A RY O F C O M M I S S I O N O R D E R S

SUMMARY OF COMMISSION ORDERS A Gas Marketer LicenceC Certificates of Public Convenience and NecessityE Energy Supply ContractsF Participant Assistance / Cost AwardsG General OrdersL Commission LettersR Mandatory Reliability Standards

Order No. Description

Access Gas Services Inc.A-6-15 Special Application for One-Time Licence Amendment for the Vancouver Island, Sunshine Coast and Whistler Resort Service AreasA-20-15 Application for Gas Marketer Licence Renewal - November 1, 2015 thru October 31, 2016

Active Renewable Marketing Ltd.A-5-15 Application for Reconsideration by the British Columbia Old Age Pensioners Organization et al. of Order A-1-13 in the matter of the Active Energy Corp. Compliance Inquiry - Reasons for Decision

AltaGas Ltd.A-13-15 Application for Gas Marketer Licence Renewal - November 1, 2015 thru October 31, 2016

ATCO Electric Ltd.G-140-15 Application for Exemption from Part 3 of the UCA Regulation of Public Utilities, Except for Certain Sections for Electrical Distribution Lines supplying Alberta/British Columbia Border Customers

Bakerview EcoDairy Ltd.G-205-15 Application for Exemption from Part 3 of the Utilities Commission Act for Electric Vehicle Charging Service Providers

British Columbia Hydro and Power AuthorityC-5-15 Application for the Certificate of Public Convenience and Necessity for Jade City and Good Hope Lake Electrification Project - Final OrderE-11-15 Filing of the Transfer Pricing Agreement Amending Agreement with PowerexE-14-15 Filing of Electricity Purchase Agreements with Kwoiek Creek and Sakwi CreekF-14-15A Application for a Shore Power Rate - Participant Assistance / Cost Awards - Final Order with Reasons for DecisionF-26-15 Application for Contracted Generator Baseline Guidelines and Reconsideration and Variance of Order G-19-14 - Participant Assistance / Cost AwardsG-54-15A Customer Complaint - T.M. (Residential Customer) - Reasons for DecisionG-55-15 Approval of Electric Tariff Supplement No. 85, Special Contract between BC Hydro and FortisBC Inc. to Supply Electrical Service under BC Hydro's Electric TariffG-58-15 Application for Shore Power Rate - Rate Schedules 1280, 1891 and Shore Power Service Agreement Electric Tariff Supplement No. 86 - Regulatory TimetableG-64-15 Application for Contracted Generator Baseline Guidelines and Reconsideration and Variance of Order G-19-14G-69-15 Customer Complaint - Sobeys West Inc. - Reasons for DecisionG-90-15 Application to Replace Tariff Supplement No. 7 - Interruptible Electricity Supply Agreement with Boralex Ocean Falls Limited PartnershipG-91-15 Customer Billing Complaint - J.B. - Reasons for DecisionG-92-15 Customer Billing Complaint - P.M. - Reasons for DecisionG-96-15 Application for Contracted Generator Baseline Guidelines and Reconsideration and Variance of Order G-19-14 - Regulatory Timetable

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G-111-15 Application for Shore Power Rate - Rate Schedules 1280, 1891 and Shore Power Service Agreement - Electric Tariff Supplement No. 86 - Reasons for DecisionG-116-15 Application to Amend Rate Schedule 1289 for Net Metering ServiceG-136-15 Sobeys West Inc. Application for Reconsideration of Order G-69-15 - Reasons for DecisionG-142-15 Request for Variance of Order G-136-15 Regarding Sobeys West Inc.’s Application for Reconsideration of Order G-69-15G-148-15 Application to Defer Operating Costs Variance between Forecast and Actual F2016 Post-Employment Benefits Current Pension Cost Arising from a Change in the Actuarial Discount RateG-156-15 2015 Rate Design Application - Regulatory Timetable and Notice of ApplicationG-157-15 Application for Indirect Interconnection Services for Transmission-Voltage Load Customers (Tariff Supplements 87 and 88) - Regulatory TimetableG-158-15 Application for Amendments to Tariff Supplement No. 80 of the Open Access Transmission Tariff G-166-15 2015 Rate Design Application - Amended Regulatory TimetableG-174-15 Application for Contracted Generator Baseline Guidelines and Reconsideration and Variance of Order G-19-14 - Final OrderG-175-15 2015 Rate Design Application - Reasons for Decision on Submissions to Appendix B of Order G-156-15G-182-15 W.A.C. Bennett Riprap Upgrade Project - Regulatory TimetableG-183-15 Overwaitea Food Group LP Complaint - Reasons for DecisionG-185-15 Application for Indirect Interconnection Services for Transmission-Voltage Load Customer - Regulatory TimetableG-194-15 Application for Contracted Generator Baseline Guidelines and Reconsideration and Variance of Order G-19-14 G-199-15 Application for Relief from Directive 3 of Order G-78-10 regarding the Lake Buntzen 2 Generating Station Cease of Operations Activities Update ReportsL-17-15 Application to Extend the Filing date for amended tariff pages in the Application to Replace Mid-Columbia Electricity Price Indices in the Electric Tariff and Open Access Transmission TariffL-20-15 Application to Waive Charges - Customer Complaint M.T.L-31-15 Request for Relief from filing the F2016 First Quarterly Progress Report No. 27 for the Interior to Lower Mainland Project R-33-15 Mandatory Reliability Standard Assessment Report No. 8 - Regulatory TimetableR-38-15 Mandatory Reliability Standards Assessment Report No. 8 R-45-15 Request for Extension for providing Mandatory Reliability Standards Assessment Report No. 9F-7-16 Application for Indirect Interconnection Services for Transmission-Voltage Load Customers - Participant Assistance / Cost AwardsG-2-16 Application for Approval of the Debt Management Regulatory AccountG-5-16 2015 Rate Design Application - Reasons for Decision regarding Sharon Noble interventionG-9-16 Application for a Debt Management Regulatory Account - Amended TimetableG-12-16 2015 Rate Design Application - Regulatory Timetable and Reasons for DecisionG-15-16 Application for the W.A.C. Bennett Dam Riprap Upgrade Project - Regulatory Timetable and Reasons for DecisionG-16-16 2015 Rate Design Application - Medium General Service and Large General Service 100 Percent Part 1 Pricing Reasons for DecisionG-17-16 2015 Rate Design Application - Transmission Service Rate Pilot Reasons for DecisionG-20-16 2015 Rate Design Application - Approval of Transmission Service Rate Schedules 1852, 1827, 1853 and 1253 Reasons for DecisionG-22-16 2015 Rate Design Application - Role of Commission Staff in the Cost of Service Study Negotiated Settlement Process - Reasons for DecisionG-25-16 Application for Indirect Interconnection Services for Transmission-Voltage Load Customer Application - Reasons for DecisionG-31-16 Application for the W.A.C. Bennett Dam Riprap Upgrade Project - Regulatory TimetableG-34-16 Request for Approval of Tariff Supplement 90 regarding the Mining Customer Payment PlanG-36-16 Application for Transmission Service Rate Customer Baseline Loads for F2015 and F2016G-40-16 Application for F2017-2019 Revenue Requirements - Interim RatesG-42-16 Application for Approval of Debt Management Regulatory Account - Reasons for DecisionR-10-16 Mandatory Reliability Standard BAL-001-2 Assessment Report - Regulatory Timetable

British Columbia Utilities CommissionG-73-15 Recovery of Commission Costs for the 2015/2016 Fiscal Year - First Quarter CostsG-108-15 Recovery of Commission Costs for the 2015/2015 Fiscal Year - Second, Third and Fourth Quarter CostsL-42-15 Review of Entity Registration under the BC MRS ProgramL-45-15 Annual Reporting Requirements for Public Utilities



R-34-15 Revisions to the Rules of Procedure for Reliability Standards in British Columbia - Reasons for DecisionR-53-15 2016 Implementation Plan for Monitoring Compliance with the BC Mandatory Reliability Standards ProgramF-4-16 British Columbia Utilities Commission Residential Inclining Block Rate Report Phase I - Participant Assistance / Cost Awards Applications - Reasons for DecisionG-1-16 Rules of Practice and Procedure

Bluestream Energy Inc.A-11-15 Special Application for One-Time Licence Amendment for the Vancouver Island, Sunshine Coast and Whistler Resort service areasA-14-15 Application for Gas Marketer Licence Renewal - November 1, 2015 thru October 31, 2016

Canadian Forest Products Ltd.G-141-15 Application for an Exemption from Part 3 of the Utilities Commission Act Regulation of Public Utilities for Electrical Distribution Lines supplying Canfor’s NOS substation customers

CanexusR-12-15 Application to Deregister for Certain Functions Required for Compliance with Mandatory Reliability Standards in British Columbia

Cape Scott Wind LPR-31-15 Confirmation of Alleged Violation of PRC-005-1a_R2R-32-15 Confirmation of Alleged Violation of VAR-002-1.1b_R2_R3R-35-15 Mitigation Plan Acceptance for VAR-002-1.1b_R3R-46-15 Mitigation Plan Acceptance for VAR-002-1.1b_R1_R2

Catalyst PaperR-10-15 Mitigation Plan Acceptance for PRC-017-0_R1 for the Port Alberni Division

Chetwynd Mechanical Pulp Inc.R-41-15 Application to Deregister for Certain Functions Required for Compliance with Mandatory Reliability Standards in British Columbia

Clowhom Power L.P.R-13-15 Application to Deregister for certain functions required for Compliance with Mandatory Reliability Standards in British Columbia

Corix Multi Utility Services Inc.E-15-15 Application for a Propane Supply Agreement for Deliveries to Panorama Mountain VillageG-78-15 Application for Electric Rate Increase for Sonoma Pines and Sun Rivers effective June 1, 2015G-84-15 Final Rate Application for Phase 1 - Wesbrook of the University of British Columbia Neighbourhood District Energy SystemG-102-15 Application for Stream A Thermal Energy System Registration for Sun Rivers Resort Community Talasa Central Energy PlantG-103-15 Application for Stream A Thermal Energy System Registration for Sun Rivers Resort Community Belmonte Central Energy PlantG-132-15 Application to Amend the Gas Cost Recovery Charge for Propane Service at Panorama Mountain Resort effective August 1, 2015G-173-15 Application for a Certificate of Public Convenience and Necessity for Additional Capital and Amended Rates for UniverCity Neighbourhood Utility Service on Burnaby Mountain - Regulatory TimetableG-215-15 Application for a Certificate of Public Convenience and Necessity for Additional Capital and Amended Rates for UniverCity Neighbourhood Utility Service on Burnaby Mountain - Reasons for DecisionL-25-15 Filing of the Annual Contracting Plan for Propane Supply to Panorama Mountain VillageF-5-16 Application for a Certificate of Public Convenience and Necessity for Additional Capital and Amended Rates for UniverCity Neighbourhood Utility Service on Burnaby Mountain - Participant Assistance / Cost AwardsG-7-16 Application for Variance of Orders C-7-11 and G-84-15 related to Reporting Requirements for Deferral AccountsG-30-16 Application for a Certificate of Public Convenience and Necessity for Additional Capital and Amended Rates for UniverCity Neighbourhood Utility Service on Burnaby Mountain - Regulatory Timetable

Creative Energy Vancouver Platforms Inc.C-12-15 Application for a Certificate of Public Convenience and Necessity for a Low Carbon Neighborhood Energy System for Northeast False Creek and Chinatown Neighborhoods of Vancouver - DecisionE-20-15 Section 71 Filing of the 2015-2016 Natural Gas Energy Supply Contract


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E-21-15 Section 71 Filing of the 2015-16 Natural Gas Energy Supply Contracts - Two Amending AgreementsE-22-15 Section 71 Filing of a 2015-16 Natural Gas Energy Supply Contract F-12-15 Application for 2015-2017 Revenue Requirements - Participant Assistance / Cost AwardG-56-15 Application for 2015-2017 Revenue Requirements - Regulatory TimetableG-75-15 Application for a Certificate of Public Convenience and Necessity for Northeast False Creek and Chinatown Neighbourhood Energy System - Regulatory Timetable and Public NoticeG-82-15 Compliance filing to Order G-47-14 and Final Determination of the 2016 and 2017 Permanent Rates in the 2015- 2017 Revenue Requirements ApplicationG-95-15 Application for a Certificate of Public Convenience and Necessity for Northeast False Creek and Chinatown Neighbourhood Energy System - Regulatory TimetableG-98-15 Application for 2015-2017 Revenue Requirements - DecisionG-101-15 Application for Stream A Thermal Energy System Registration for 188 Keefer StreetG-118-15 Application for a Certificate of Public Convenience and Necessity for Northeast False Creek and Chinatown Neighbourhood Energy System - Regulatory Timetable and ScopeG-119-15 Application for a Certificate of Public Convenience and Necessity for Northeast False Creek and Chinatown Neighbourhood Energy System - Procedural Conference and Regulatory Timetable - Reasons for DecisionG-123-15 Application for a Certificate of Public Convenience and Necessity for Northeast False Creek and Chinatown Neighbourhood Energy System - Regulatory TimetableG-195-15 Application for Approval of Credit Facilities AgreementL-33-15 Compliance Filing pursuant to Order E-3-15 - 2015/2016 Annual Contracting PlanF-2-16 Application for a Certificate of Public Convenience and Necessity for a Low Carbon Neighbourhood Energy System for Northeast False Creek and Chinatown Neighbourhoods of Vancouver - Participant Assistance / Cost Awards - Reasons for DecisionG-23-16 Restated and Amended Northeast False Creek and Chinatown Neighbourhood Energy Agreement - Regulatory TimetableG-29-16A Restated and Amended Northeast False Creek and Chinatown Neighbourhood Energy Agreement - Regulatory Timetable and Scope - Reasons for Decision on Scope

Direct Energy (B.C.) LimitedA-7-15 Special Application for One-Time Licence Amendment for the Vancouver Island, Sunshine Coast and Whistler Resort service areasA-15-15 Application for Gas Marketer Licence Renewal - November 1, 2015 thru October 31, 2016

Domtar KamloopsR-44-15 Application to Deregister for Certain Functions Required for Compliance with Mandatory Reliability Standards in British Columbia

FortisBC Alternative Energy Services Inc.G-74-15 Application for Stream A Thermal Energy System Registration for Seylynn Thermal Energy System G-85-15 Application for Fiscal 2015/16 Revenue Requirements and Cost of Service Rate for Thermal Energy Services to Delta School District Number 37 Regulatory TimetableG-113-15 Application for Fiscal 2015/16 Revenue Requirements and Cost of Service Rate for Thermal Energy Services to Delta School District Number 37 - Regulatory TimetableG-129-15A Application for Stream A Thermal Energy System Registration for SOLO Phase 1 - Final OrderG-146-15A Fiscal 2015/16 Revenue Requirements and Cost of Service Rates for Thermal Energy Service to Delta School District Number 37 - Reasons for DecisionG-172-15 Application for Stream A Registration of the Marine Gateway Thermal Energy System - Final OrderG-176-15 Application for Stream A Registration of the Empire at Queen Elizabeth Park Thermal Energy System - Reasons for DecisionG-213-15 Application for the Fiscal 2015/16 Revenue Requirements and Cost of Service Rates for Thermal Energy Service to Delta School District Number 37 - Reasons for DecisionL-32-15 Stream A Thermal Energy Systems Registration for SOLO Phase 1 Advance Copy of Notice to be Sent to Affected Parties - Compliance Filing pursuant to Order G-129-15A

FortisBC Inc.E-7-15 Filing of an Energy Supply Contract with Powerex Corporation for Winter 2015-2016E-10-15 Section 71 Application for Acceptance of the Capacity and Energy Purchase and Sale Agreement between FortisBC Inc. and Powerex Corp.E-19-15 Section 71 Fiing of Energy Supply Contracts for 2015 and 2016 with Powerex Corp.




F-8-15 Section 71 Application for Acceptance of the Capacity and Energy Purchase and Sale Agreement between FBC and Powerex Corp. - Participant Assistance / Cost Awards F-11-15 Application for 2015 Rates pursuant to the Multi-Year Performance Based Ratemaking Plan approved for 2014 through 2019 by Order G-138-14 - Participant Assistance / Cost Awards F-16-15 Application for Stepped and Stand-By Rates for Transmission Voltage Customers (Stages II and III) - Participant Assistance / Cost AwardsF-24-15 Application for 2015 Rates pursuant to the Multi-Year Performance Based Ratemaking Plan approved for 2014 through 2019 by Order G-138-14 - Participant Assistance / Cost Awards G-93-15 Application for Stepped and Stand-by Rates for Transmission Voltage Customers - Stage III - DecisionG-107-15 Application for 2015 Rates Pursuant to the Multi-Year Performance Based Ratemaking Plan Approved for 2014 through 2019 by Order G-139-14 - Reasons for DecisionG-124-15 Application for a Certificate of Public Convenience and Necessity for Construction of the Kootenay Operations Centre - Regulatory Timetable and Public NoticeG-139-15 Annual Review of 2016 Delivery Rates - Regulatory TimetableG-149-15 Application for Stepped and Stand-by Rates for Transmission Voltage Customers - Stage IV - Decision G-153-15 Application for Tariff Supplement No. 4(v) - Agreement for the Supply of Electricity Wholesale Service with the District of SummerlandG-167-15 Application for Amendment to Electric Tariff Rate Schedule 50 Lighting - All AreasG-168-15A Application for Stepped and Stand-by Rate for Transmission Voltage Customers - Non-Embedded Cost Power Rate RiderG-179-15 Application for Amendments to Electric Tariff Rate Schedule 50 Lighting - All AreasG-184-15 Disconnection/Reconnection Customer Complaint by M.W. - Reasons for DecisionG-187-15 Application for Reconsideration and Clarification of Order G-149-15 by the British Columbia Old Age Pensioners Organization and Seniors’ Organization et al. regarding an Application by FortisBC Inc. for Stepped and Stand-by Rates - Reasons for DecisionG-192-15 Application for Stepped and Stand-by Rate for Transmission Voltage Customers - Regulatory Timetable - Reasons for DecisionG-202-15 Application for 2016 Rates Pursuant to the Multi-Year Performance Based Ratemaking Plan Approved for 2014 through 2019 by Order G-139-14 - Reasons for DecisionG-214-15 Application for Stepped and Stand-by Rate for Transmission Voltage Customers - Stage V DecisionL-16-15 Section 71 Application for Acceptance of the Capacity and Energy Purchase and Sale Agreement between FortisBC Inc. and Powerex Corp. - ICG Reply submissionL-18-15 Application for Acceptance of the 2015/2016 Annual Electric Contracting PlanL-41-15 Filing of the Annual Cost Benefit Tracking Report for the Advanced Metering Infrastructure ProjectC-2-16 Application for a Certificate of Public Convenience and Necessity for the Construction of the Kootenay Operations Centre - Reasons for DecisionE-2-16 Section 71 Filing of Energy Supply Contracts with Powerex Corporation for 2016 and 2017 F-3-16 Application for 2016 Delivery Rates pursuant to the Multi-Year Performance Based Ratemaking Plan approved for 2014 through 2019 by Order G-139-14 - Participant Assistance / Cost AwardsF-6-16 Application for Stepped and Stand-by Rates for Transmission Voltage Customers - Stage IV and V - Participant Assistance / Cost AwardsG-27-16 Self-Generation Policy - Stage I DecisionG-43-16 Application to Extend the Filing Date of the Long Term Electric Resource PlanL-1-16 Application for the Termination of the Remote Meter Connection ChargeR-6-16 Application to Change Registration Footprint required for Compliance with Mandatory Reliability Standards

FortisBC Energy Inc.A-3-15 Customer Choice Seventh Annual General Meeting - Issues List and Regulatory TimetableA-4-15 Customer Choice Seventh Annual General Meeting - Regulatory TimetableA-12-15 Customer Choice Seventh Annual General Meeting - Final OrderC-3-15 Application to Collect Operating or Franchise Fees from Customers in the Town of View Royal, District of Saanich, and District of HighlandsC-4-15 Application for an Amending Agreement to the Franchise Agreement with the District of Logan LakeC-6-15 Application for Approval of Operating Agreements with 26 Municipalities on Vancouver Island, the Sunshine Coast and the City of Powell RiverC-7-15 Application for Approval of Operating Agreements with 26 Municipalities on Vancouver Island, the Sunshine Coast and the City of Powell River


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C-8-15 Application for Approval of Operating Agreements with 26 Municipalities in the Vancouver Island, the Sunshine Coast and the City of Powell RiverC-9-15 Application for Approval of an Operating Agreement with the District of Logan Lake C-11-15 Application for a Certificate of Public Convenience and Necessity for the Lower Mainland Intermediate Pressure System Upgrade Projects - DecisionE-8-15 Filing for Approval of the Transportation Agreement Extension with Northwest Pipeline LLCE-9-15 Section 71 Filing of the Remaining Natural Gas Supply Contracts for the Period April 1, 2015 to October 31, 2015E-12-15 Filing for Approval of the Transportation Agreement with IGI Resources Inc. E-13-15 Filing of Deferred Exchange Agreement Huntingdon Gas Supply with Avista CorporationE-16-15 Section 71 Filing of a Six-Year Baseload Gas Purchase Agreement with TD Energy Trading Inc., effective November 1, 2015E-17-15 Section 71 Filing of a Three-Year Baseload Gas Purchase Agreement with AltaGas Ltd., effective November 1, 2015E-18-15 Section 71 Filing of a Three-Year Baseload Gas Purchase Agreement with Progress Energy Canada Ltd., effective November 1, 2015E-23-15 Filing of Natural Gas Supply Contracts for the Commodity and Midstream Portfolios for the 2015-2016 Contract YearE-25-15 Filing of a Storage Agreement between FortisBC Energy Inc. and Aitken Creek Gas Storage ULCE-26-15 Section 71 Filing of a GasEDI Base Contract with Citadel NGPE LLCF-10-15 Application for 2015 Delivery Rates pursuant to the Multi-Year Performance Based Ratemaking Plan approved for 2014 through 2019 by Order G-138-14 - Participant Assistance / Cost Awards F-15-15 Application for 2015-2016 Revenue Requirements for the Fort Nelson Service Area - Reasons for Decision - Participant Assistance / Cost AwardsF-18-15 Proposal by FortisBC Energy Inc. to Include FortisBC Energy (Vancouver Island) and FortisBC Energy (Whistler) Inc. into the 2014-2019 Multi Year Performance Based Ratemaking Plan - Reasons for Decision - Participant Assistance / Cost AwardsF-19-15 Application for Reconsideration of Order G-187-14 - Amend the Balancing Charges for Rate Schedules 23, 25, 26 and 27 - Participant Assistance / Cost AwardsF-22-15 Customer Choice Program Seventh Annual General Meeting - Participant Assistance / Cost AwardsF-28-15 Application for a Certificate of Public Convenience and Necessity for the Lower Mainland Intermediate Pressure System Upgrade Projects - Participant Assistance / Cost AwardsF-31-15 Application for a Certificate of Public Convenience and Necessity for the Lower Mainland Intermediate Pressure System Upgrade Projects - Participant Assistance / Cost AwardsG-53-15 Application for Expenditures for the Expanded Compressed Natural Gas Fueling Station for Waste Management of Canada Corporation - Interim RatesG-57-15 Approval of Rates and Contract for Liquefied Natural Gas Supply from the Arrow Transportation Systems Inc. LNG Fueling Station for Denwill Enterprises Inc.G-62-15 Application to issue Common Shares to maintain the approved Capital StructureG-65-15 Application for Code of Conduct and Transfer Pricing Policy for Affiliated Regulated Businesses Operating in a Non- Natural Monopoly Environment Compliance Filing pursuant to Commission Order G-31-15G-79-15 Application for Rates and Contract for Liquefied Natural Gas Supply from the Vedder Transport Ltd. LNG Fueling Station for Wheeler Transport Inc. - Permanent RatesG-80-15 Application for Rates and Contract for Liquefied Natural Gas Supply from the Vedder Transport Ltd. LNG Fueling Station for Denwill Enterprises Inc. - Permanent RatesG-86-15 Application for 2015 Delivery Rates pursuant to the Multi-Year Performance Based Ratemaking Plan approved for 2014 through 2019 by Order G-138-14 - DecisionG-94-15 Application for Reconsideration of Order G-187-14 Amend the Balancing Charges for RS 23, 25, 26 and 27 - Regulatory Timetable G-97-15 Application for 2015-2016 Revenue Requirements and Rates for the Fort Nelson Service Area - DecisionG-99-15 Filing of 2015 Second Quarter Gas Cost Report and Propane Commodity Charges effective July 1, 2015 for the Revelstoke Service AreaG-105-15 Application for Rate Design and Rates for Constructing and Operating a Compressed Natural Gas Refueling Station under the Province’s Greenhouse Gas Reduction Regulation for the City of Vancouver - Permanent RatesG-106-15 Proposal to Include FortisBC Energy (Vancouver Island) Inc. and FortisBC Energy (Whistler) Inc. into 2014-2019 Multi-Year Performance Based Ratemaking Plan - DecisionG-109-15 Application to Terminate the FEVI Term Credit Agreement and Amend and Extend the FEI Term Credit AgreementG-110-15 Application for Rates and Contract for Compressed Natural Gas fueling Service from the CNG Fueling Station, Located at FEI's Victoria Regional Office facility in Langford, for the Corporation of the City of Victoria




G-112-15 Rescinding Order G-110-15 - Application for Rates and Contract for Compressed Natural Gas Fueling Service from the CNG Fueling Station, Located at FEI's Victoria Regional Office facility in Langford, for the Corporation of the City of Victoria - Application WithdrawnG-125-15 Application for Amended Rates for Compressed Natural Gas Fueling Service between For Less Disposal Inc. and FortisBC Energy Inc.G-126-15 2015 System Extension Application - Regulatory Timetable and Public NoticeG-135-15 Application for Reconsideration of Order G-187-14 to Amend the Balancing Gas Charges for Rate Schedules 23, 25, 26 and 27 - Final OrderG-138-15 Application for the Annual Review of 2016 Delivery Rates - Regulatory TimetableG-143-15 Application for the 2015 System Extension - Regulatory Timetable G-145-15 Filing of the 2015 Third Quarter Gas Cost Report and Propane Commodity Charges effective October 1, 2015 for the Revelstoke Service AreaG-147-15 Application for Biomethane Energy Recovery Charge Rate Methodology - Regulatory Timetable and Supplementary Information RequestG-150-15 Application for Rates for Compressed Natural Gas Fueling Service to the Corporation of the City of Victoria from the CNG Fueling Station, Located at FEI’s Victoria Regional Office Facility in Langford - Interim RatesG-151-15 Application for Rates for Constructing and Operating a Liquefied Natural Gas Fueling Station under the Province's Greenhouse Gas Reduction (Clean Energy) Regulation for the Teck Coal Ltd. - Interim RatesG-162-15 Application for Rates for Compressed Natural Gas Fueling Service to the Corporation of the City of Victoria from the CNG Fueling Station, Located at FEI’s Victoria Regional Office Facility in Langford - Final RatesG-163-15 Application for Rates for Compressed Natural Gas Fueling Service to Waste Management of Canada Corporation from the CNG Fueling Station, Located at FEI’s Victoria Regional Office Facility in Langford - Final RatesG-164-15 Application for Rates for Compressed Natural Gas Fueling Service to Wilson’s Transportation Ltd. from the CNG Fueling Station, Located at FEI’s Victoria Regional Office Facility in Langford - Final RatesG-165-15 Application for Rates for Compressed Natural Gas Fueling Service to Emterra Group from the CNG Fueling Station, Located at FEI’s Victoria Regional Office Facility in Langford - Final RatesG-170-15 Application for the 2015 System Extension - Regulatory TimetableG-177-15 Application for the Common Equity Component and Return on Equity for 2016 - Regulatory Timetable and Public NoticeG-178-15 Application for Rates for Constructing and Operating a Liquefied Natural Gas Fueling Station under Province’s Greenhouse Gas Reduction Regulation for Vedder Resources Ltd. at Cool Creek Energy Ltd.G-181-15 Application for the Biomethane Energy Recovery Charge Rate Methodology - Regulatory TimetableG-186-15 Application for Biomethane Purchase Agreement with City of Surrey and Monthly Facility Fee - Regulatory TimetableG-188-15 Filing of the 2015 Fourth Quarter Gas Cost Report/Commodity Cost Reconciliation Account and Midstream Cost Reconciliation Quarterly Gas Costs for the Mainland, Vancouver Island, and Whistler Service AreasG-189-15 Filing of the 2015 Fourth Quarter Gas Cost Report/Gas Cost Reconciliation Account and Gas Cost Recovery Rates for the Fort Nelson Service AreaG-190-15 Filing of the 2015 Fourth Quarter Report on the Biomethane Variance Account and Biomethane Energy Recovery ChargeG-193-15 Application for the Annual Review of 2016 Delivery Rates - Reasons for DecisionG-204-15 Application for the Common Equity Component and Return on Equity for 2016 - Interim RatesL-15-15 Compliance Filing for the 2013-2016 Gas Supply Mitigation Incentive Program (GSMIP) Revised Term SheetL-19-15 Application for Approval of Code of Conduct and Transfer Pricing Policy for Affiliated Regulated Businesses Operating in a Non-Natural Monopoly Environment Compliance Filing Pursuant to Commission Order G-31-15L-21-15 Filing of the 2015 Second Quarter Gas Cost Report for Mainland, Vancouver Island and Whistler Service AreasL-22-15 Filing of the 2015 Second Quarter Gas Cost Report for the Fort Nelson Service AreaL-23-15 Filing of the 2015 Second Quarter Report on the Biomethane Variance Account and Biomethane Energy Recovery ChargeL-26-15 Notice of Change to Filing Date for the 2015 Biomethane Energy Recovery Charge Rate Methodology ApplicationL-27-15 Filing of the Revelstoke Service Area 2015-2016 Annual Contracting PlanL-28-15 Filing of the 2015 - 2016 Annual Contracting PlanL-30-15 Application for the Annual Review of 2016 Delivery Rates, Forecasting Directive - Request for ExtensionL-34-15 Filing of the 2015 Third Quarter Gas Cost Report for Mainland, Vancouver Island and Whistler Service AreasL-35-15 Filing of the 2015 Third Quarter Gas Cost Report for the Fort Nelson Service AreaL-36-15 Filing of the 2015 Third Quarter Report on the Biomethane Variance Account and Biomethane Energy Recovery ChargeL-40-15 Application to Revise Receipt Point Fuel Gas Percentages effective November 1, 2015


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L-43-15 Filing of an Amendment to the 2015/2016 Annual Contracting PlanL-44-15 Filing of the 2015 Fourth Quarter Gas Cost Report for the Revelstoke Service AreaR-15-15 Application to Deregister for certain functions required for Compliance with Mandatory Reliability Standards in British ColumbiaA-1-16 Customer Choice Program Seventh Annual General MeetingE-1-16 Section 71 Filing of a GasEDI Base Contract with Aux Sable Canada LPE-3-16 Section 71 Filing of a Biomethane Purchase Agreement Between FortisBC Energy Inc. and the City of Surrey and Approval of the Monthly Facility Fee Application - Reasons for DecisionE-4-16 Application for Proposed Propane Supply Agreement for April 2016 to March 2018 with Superior Gas Liquids for the Revelstoke service areaF-1-16 Annual Review of 2016 Delivery Rates - Participant Assistance / Cost AwardsG-3-16 Section 71 Filing - Biomethane Purchase Agreement with City of Surrey - Regulatory TimetableG-6-16 Application for Rates and Contract for Liquefied Natural Gas Supply from the Vedder Transport Ltd. LNG Fueling Station for Ledcor Resources and Transportation L.P. G-8-16 Application regarding the 2016 Core Market Administration Expense BudgetG-10-16 2015 Price Risk Management Application - Regulatory TimetableG-11-16 Application for Detailed Plans for New Energy Efficiency and Conservation ProgramsG-19-16 Application to Revise Rate Schedule 30, effective February 1, 2016G-26-16 A Filing regarding its 2016 First Quarter Report on the Biomethane Variance Account and Biomethane Energy Recovery Charge Rate effective April 1, 2016 for the Mainland Service AreaG-32-16 Annual Main Extension and Vertical Subdivision Report - Request to defer filing of the 2015 Annual Main Extension ReportG-33-16 Filing of the 2016 First Quarter Gas Cost Report and Propane Commodity Charges effective April 1, 2016 for the Revelstoke Service AreaG-37-16 Filing of the 2016 First Quarter Gas Cost Report and Commodity Cost Recovery Rate change effective April 1, 2016 for the Mainland, Vancouver Island and Whistler Service Areas - Reasons for DecisionG-38-16 2015 Price Risk Management Application - Regulatory TimetableG-41-16 Proposal for Depreciation and Net Salvage Rate Changes - Regulatory TimetableL-2-16 Gas Supply Mitigation Incentive Program Year End Report (November 2014 - October 2015)L-3-16 Filing of the 2016 First Quarter Gas Cost Report for the Forth Nelson Service AreaL-6-16 Application for proposed changes to the New Code of Accounts Activity View

FortisBC Energy Inc./FortisBC Inc.F-21-15 Multi-Year Performance Based Ratemaking Plans for 2014 through 2019 Approved by Decision and Orders G-138- 14 and G-139-14 Capital Exclusion Criteria under PBR - Compliance Filing - Participant Assistance / Cost Awards F-27-15 Multi-Year Performance Based Ratemaking Plans for 2014 through 2019 Approved by Decision and Orders G-138- 14 and G-139-14 Capital Exclusion Criteria under PBR - Compliance Filing - Participant Assistance / Cost AwardsF-30-15 Application for Removal of the Restriction on the Location of Data and Servers Providing Service to the FEU, Currently Restricted to Canada - Participant Assistance / Cost AwardsG-71-15 British Columbia Sustainable Energy Association and the Sierra Club of British Columbia - Application for Reconsideration of Order F-1-15G-120-15 Application for Multi-Year Performance Based Ratemaking Plans for 2014 through 2019 approved by Decisions and Orders G-138-14 and G-139-14 Capital Exclusion Criteria under PBR - Compliance Filing - Reasons for DecisionG-152-15A Application for the Rental Apartment Efficiency Program Business Case pursuant to Directive 148 of FEI 2014-2018 Performance Based Ratemaking Plan Application Order G-138-14 and Decision

FortisBC Energy Utilities (Electric and Gas) G-161-15 Application for Removal of the Restriction on the Location of Data and Servers Providing Service to the FEU currently Restricted to Canada - Decision

FortisBC Midstream Inc.G-210-15 Application for the Acquisition of the Shares of Aitken Creek Gas Storage ULC - Regulatory Timetable and Public NoticeG-39-16 Application for the Acquisition of the Shares of Aitken Creek Gas Storage ULC Application - Reasons for Decision

Insurance Corporation of British ColumbiaF-13-15 Application for the Revenue Requirements for Universal Compulsory Automobile Insurance for the Policy Year Commencing November 1, 2014 - Reasons for Decision - Participant Assistance / Cost AwardsG-81-15 Application for the Revenue Requirements for Universal Compulsory Automobile Insurance for the Policy Year Commencing November 1, 2014 - Decision




G-127-15 Application for Approval of Basic Insurance Tariff AmendmentsG-169-15 Application for Revenue Requirements for Universal Compulsory Automobile Insurance effective November 1, 2015 - Regulatory Timetable and Public NoticeG-191-15 Application for the Addition of 2016 Genesys Upgrade to the List of Evergreening ProjectsG-200-15 Application for Basic Insurance Tariff Amendment to remove the Fee for the Application for Claim-Rated Scale DiscountG-201-15 Application for Revenue Requirements for Universal Compulsory Automobile Insurance effective November 1, 2015 - First Round Information Request DisputeG-212-15 Application for Revenue Requirements for Universal Compulsory Automobile Insurance effective November 1, 2015 - Regulatory Timetable

Innergex Renewable Energy Inc.R-11-15 Mitigation Plan Acceptance for EOP-005-1_R1R-17-15 Confirmation of Alleged Violation of EOP-005-1_R1_R6R-18-15 Confirmation of Alleged Violation of FAC-008-1_R1R-19-15 Confirmation of Alleged Violation of PRC-001-1_R1_R3R-20-15 Confirmation of Alleged Violation of PRC-005-1_R1_R2R-21-15 Confirmation of Alleged Violation of PRC-017-0_R1_R2R-22-15 Mitigation Plan Acceptance for EOP-005-1_R6R-23-15 Mitigation Plan Acceptance for FAC-008-1_R1R-24-15 Mitigation Plan Acceptance for PRC-001-1_R1_R3R-25-15 Mitigation Plan Acceptance for PRC-005-1_R1_R2R-26-15 Mitigation Plan Acceptance for PRC-017-0_R1_R2R-29-15 Contesting Alleged Violation of: EOP-008-0 R1; PER-002-0 R1_R2_R3_R4; PER-003-0_R1 R-48-15 Mitigation Plan Acceptance for EOP-008-0_R1R-50-15 Mitigation Plan Acceptance for PER-003-0_R1R-52-15 Mitigation Plan Acceptance for PER-002-0_R1_R2_R3_R4

Just Energy (B.C.) Limited PartnershipA-8-15 Special Application for One-Time Licence Amendment for the Vancouver Island, Sunshine Coast and Whistler Resort service areasA-16-15 Application for Gas Marketer Licence Renewal - November 1, 2015 thru October 31, 2016

Mackenzie Pulp MillR-14-15 Application to Deregister for certain functions required for Compliance with Mandatory Reliability Standards in British Columbia

Nelson Hydro/City of NelsonG-24-16 Application for Rate Increase - Electrical Utility Amendment Bylaw No. 3327, 2016 and the Solar Garden Fees & Charges Bylaw Amendment Schedule F - No. 3325

Planet Energy (B.C.) Corp.A-10-15 Special Application for One-Time Licence Amendment for the Vancouver Island, Sunshine Coast and Whistler Resort service areasA-17-15 Application for Gas Marketer Licence Renewal - November 1, 2015 thru October 31, 2016

Plateau Pipe Line Ltd.G-89-15 Application for Revised Tolls on the Western Pipeline System G-159-15 Application for Revised Tolls on the Western Pipeline System G-171-15 Application for Revised Tolls on the Northeast BC Pipeline System

Pacific Northern Gas Ltd.C-10-15A Application for a Certificate of Public Convenience and Necessity to Construct and Operate an Interconnecting Pipeline between Kitimat and Douglas Channel - DecisionE-24-15 Section 71 Filing of 2015/2016 Natural Gas Energy Supply ContractsF-7-15 Application for the Assignment and Amendment of a Firm and Interruptible Gas Transportation Service Agreement - Participant Assistance / Cost AwardsF-17-15 Application for No Changes to 2015 Delivery Rates and Changes to the 2015 Revenue Stabilization Adjustment Mechanism Rider for the PNG-West Service Area - Participant Assistance / Cost Awards


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F-20-15 Application for Reconsideration of Order G-104-15A - No Changes to 2015 Delivery Rates and Changes to the 2015 Revenue Stabilization Adjustment Mechanism Rider for the PNG-West Service Area - Participant Assistance / Cost AwardsF-29-15 Application for a Certificate of Public Convenience and Necessity to Construct and Operate an Interconnecting Pipeline between Kitimat and Douglas Channel - Participant Assistance / Cost AwardsG-66-15 Application for 2015 Delivery Rates and Revenue Stabilization Account Mechanism Rider - Regulatory TimetableG-76-15 Application for Credit Agreement Extension and AmendmentG-87-15 Application for the Sale of Pacific Northern Gas Transition Ltd.G-88-15 Application for the Sale of Interests in the Narrows Inlet ProjectG-100-15 Application for Natural Gas Commodity Charges effective July 1, 2015 for the PNG-West and Granisle service areasG-104-15A Application for No changes to 2015 Delivery Rates and Changes to the 2015 Revenue Stabilization Adjustment Mechanism Rider for the PNG-West Service Area - Reasons for DecisionG-115-15 Application for Consolidated Energy Management and Efficiency Program Funding PlanG-121-15 Application for Reconsideration of Order G-104-15A - No Changes to 2015 Delivery Rates and Revenue Stabilization Adjustment Mechanism Rider - Regulatory TimetableG-122-15 Application for a Certificate of Public Convenience and Necessity to Construct and Operate an Interconnecting Pipeline between Kitimat and Douglas Chanel - Regulatory Timetable and Public NoticeG-134-15 Application for Reconsideration of Order G-104-15A - No Changes to 2015 Delivery Rates and Changes to the 2015 Revenue Stabilization Adjustment Mechanism Rider for the PNG-West Service Area - Application WithdrawnG-137-15 Application for a Certificate of Public Convenience and Necessity to Construct and Operate an Interconnecting Pipeline between Kitimat and Douglas Channel - Amended Regulatory Timetable G-160-15 Application for the Sale of Interests in the McNair Creek ProjectG-197-15 Application for Natural Gas Commodity Charges effective January 1, 2016 for the PNG-West and Granisle Service AreasG-207-15 Application for 2016-2017 Revenue Requirements for the PNG West Service Area - Regulatory Timetable and Public NoticeL-38-15 Filing of the 2015 Third Quarter Report on Gas Supply Costs for the PNG-West and Granisle Service AreasC-1-16 Application for Renewal and Amendment of the 1993 Franchise Agreement with the City of Prince RupertC-3-16 Application for the Franchise Agreement between PNG and the Village of Fraser LakeG-13-16 Application for 2016-2017 Revenue Requirements for the PNG West Service Area - Regulatory Timetable and Reasons for DecisionL-4-16 Filing of the 2016 First Quarter Report on Gas Supply Costs for PNG-West and Granisle Grid Service Areas

Pacific Northern Gas (N.E.) Ltd.F-9-15 Application for Changes to the 2015 Revenue Stabilization Adjustment Mechanism Rate Riders for the Fort St. John/Dawson Creek and Tumbler Ridge Divisions - Participant Assistance / Cost AwardsF-23-15 Application for AltaGas Ltd. Industrial Firm Transportation Service Agreement and Proposed RS 7 Industrial LNG Firm Transportation Service Tariff - Participant Assistance / Cost AwardsF-25-15 Application for Acceptance of the 2015 Resource Plan - Participant Assistance / Cost AwardsG-52-15 Application for Fort St. John/Dawson Creek Division 2015 Revenue Requirements - Final RateG-67-15 Application for Acceptance of the 2015 Resource Plan - Regulatory TimetableG-70-15 Application for Changes to the 2015 Revenue Stabilization Adjustment Mechanism Rate Riders for the Fort St. John/Dawson Creek and Tumbler Ridge Divisions - Variance of Orders G-49-15 and G-50-15G-77-15 Application for Credit Agreement Extension and AmendmentG-117-15 Application for AltaGas Ltd. Industrial Firm Transportation Service Agreement and Proposed Rate Schedule 7 Industrial LNG Firm Transportation Service Tariff - Regulatory TimetableG-128-15 Application for AltaGas Ltd. Industrial Firm Transportation Service Agreement and Proposed Rate Schedule 7 Industrial LNG Firm Transportation Service Tariff - Regulatory TimetableG-154-15 Application for AltaGas Ltd. Industrial Firm Transportation Service Agreement and Proposed Rate Schedule 7 Industrial LNG Firm Transportation Service Tariff - Reasons for DecisionG-155-15 Application for Acceptance of the 2015 Resource Plan for the Fort St. John, Dawson Creek and Tumbler Ridge Distribution Systems - DecisionG-198-15 Application for Natural Gas Commodity Charges effective January 1, 2016 for the Fort St. John/Dawson Creek and Tumbler Ridge Service AreasG-208-15 Application for 2016 - 2017 Revenue Requirements - Regulatory Timetable and Public NoticeG-209-15 Application to Amend Rate Schedule 7 Industrial LNG Firm Transportation Service Tariff for the Dawson Creek Division pursuant to - Order G-154-15 Compliance FilingL-24-15 Filing of the Second Quarter 2015 Gas Supply Costs for the Fort St. John/Dawson Creek and Tumbler Ridge Divisions




L-37-15 Filing of the 2015 Third Quarter 2015 Gas Supply Costs for the Fort St. John/Dawson Creek and Tumbler Ridge Service AreasG-14-16 Application for 2016 - 2017 Revenue Requirements - Regulatory TimetableL-5-16 Filing of the 2016 First Quarter Report on Gas Supply Costs for the Fort St. John/Dawson Creek and Tumbler Ridge service areas

Pacific Northern Gas Ltd./Pacific Northern Gas (N.E.) Ltd.F-32-15 Application for Acceptance of the 2015 Consolidated Energy Management and Efficiency program Funding Plan - Participant Assistance / Cost AwardsG-203-15A 2015 Consolidated Energy Management and Efficiency Program Funding Plan Application - Final OrderL-29-15 Filing of the 2015 Annual Contracting Plan (November 2015 - October 2016)

Port Alice Gas Inc.G-211-15 Application to Increase the Basic Charge and Facility Charge - Interim RatesG-4-16 Application to Increase the Basic Charge and Facility Charge - Regulatory TimetableG-18-16 Application to Increase the Basic Charge and Facility Charge - Regulatory Timetable

Powell River Energy Inc.R-39-15 Mitigation Plan Acceptance for TOP-003-0_R3R-43-15 Application to Deregister from the BC Mandatory Reliability Standards Program

Rio Tinto AlcanR-36-15 Confirmation of Alleged Violation of FAC-003-1_R2R-49-15 Mitigation Plan Acceptance for FAC-003-1_R2R-51-15 Mitigation Plan Acceptance for PER-002-0_R3 and Dismissal of PER-002-0_R3

Shannon Wall Centre Rental Apartments Limited PartnershipL-39-15 Application for Stream A Registration for Shannon Estates Development Thermal Energy SystemG-28-16 Application for a Certificate of Public Convenience and Necessity for the Shannon Estates Thermal Energy Systems - Regulatory Timetable

Silversmith Power & Light CorporationG-83-15 Application for Revenue Requirements and Rates - Regulatory TimetableG-144-15 Application for Revenue Requirements and Rates - Decision

Skookumchuck Pulp Inc.R-28-15 Application to Deregister for certain functions required for Compliance with Mandatory Reliability Standards in British Columbia

Stargas Utilities Ltd.G-180-15 Application to Alter the Commodity Component of RatesL-46-15 Application Seeking Approval for 2016/2017 and 2017/2018 Winter Purchase Plan

Summitt Energy BC LPA-9-15 Special Application for One-Time Licence Amendment for the Vancouver Island, Sunshine Coast and Whistler Resort service areasA-18-15 Application for Gas Marketer Licence Renewal - November 1, 2015 thru October 31, 2016

Sun Peaks Utilities Co. Ltd.G-114-15 Application for a Gas Commodity Rate Decrease effective July 1, 2015G-206-15 Application for a Gas Commodity Rate Decrease effective January 1, 2016

Superior Energy Management Gas LPA-19-15 Application for Gas Marketer Licence Renewal - November 1, 2015 thru October 31, 2016 - and the Assignment of Superior Energy Management Gas LP’s Contracts

Superior PropaneG-60-15 Status as Public Utility in British Columbia for the Operation of a Propane Distribution System at Seascapes Development Ltd. - Regulatory TimetableG-72-15 Status as Public Utility in British Columbia for the Operation of a Propane Distribution System at Seascapes Development Ltd. - Regulatory Timetable and Reasons for DecisionG-133-15 Status as Public Utility in British Columbia for the Operation of a Propane Distribution System at Seascapes Development Ltd. - Decision


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G-21-16 Application for Rates for the Seascapes Grid System - Regulatory Timetable and Public NoticeG-35-16 Application for rates for the Seascapes Grid System - Request for Confidentiality

Teck CoalR-42-15 Application to Deregister for certain functions required for Compliance with Mandatory Reliability Standards in British Columbia

Teck Metals LimitedR-47-15 Mitigation Plan Acceptance for TOP-002-2_R11R-54-15 Dismissal of Alleged Violation of Mandatory Reliability Standard PER-002-0_R1R-55-15 Dismissal of Alleged Violation of Mandatory Reliability Standard PRC-001-1_R1R-56-15 Confirmation of Alleged Violation of EOP-005-1_R1_R6R-57-15 Confirmation of Alleged Violation of EOP-008-0_R1R-58-15 Confirmation of Alleged Violation of PER-002-0_R2_R3R-59-15 Confirmation of Alleged Violation of PRC-005-1_R1_R2R-60-15 Confirmation of Alleged Violation of TOP-002-2_R11R-2-16 Mitigation Plan (Version 2) for EOP-008-0_R1R-3-16 Mitigation Plan (Version 2) for EOP-005-1_R1_R6R-7-16 Mitigation Plan (Version 2) for PER-002-0_R2R-8-16 Mitigation Plan (Version 2) for PER-002-0_R3

Templeton DOC Limited PartnershipG-68-15 Application for Exemption Pursuant to Section 88(3) of the Utilities Commission Act for the Resale of Natural Gas - Regulatory TimetableG-130-15 Application for Exemption Pursuant to Section 88(3) of the Utilities Commission Act for the Resale of Natural Gas - Application WithdrawnG-131-15 Application for Exemption under section 88(3) of the Utilities Commission Act for its Proposed Supply of Electricity at McArthurGlen Designer Outlet Vancouver Airport

Tolko Industries Ltd.G-59-15 Application for Exemption pursuant to section 88(3) of the Utilities Commission Act - Regulatory TimetableG-196-15 Application for Exemption pursuant to section 88(3) Utilities Commission Act R-9-16 Mitigation Plan (Version 2) for PRC-008-0_R1

Zeballos Lake Hydro Limited PartnershipR-16-15 Application to Deregister for certain functions required for Compliance with Mandatory Reliability Standards in British Columbia



2015 DOMESTIC SALES Customers Revenue ($) Sales (KwH) Sales Converted Domestic Electricity Sales # Actual Actual to (GW.h)

Crown-Owned Electric Utility

BCHydroandPowerAuthority 1,955,072 4,257,280,438.00 49,549,458,312.00 49,549.00 Municipally-Owned Electric Utilities

CityofGrandForks 2,153 4,123,897.90 38,201,589.00 38.20CityofNelson(urban) 5,983 9,728,264.94 90,848,789.26 90.85CityofNelson(rural) 4,142 6,250,564.19 60,781,670.61 60.78CityofNewWestminster 33,249 41,987,000.00 423,881,000.00 423.88CityofPenticton 17,487 41,214,672.00 328,823,058.00 328.82DistrictofSummerland 5,596 9,805,918.00 82,653,928.00 82.65

TotalMunicipally-OwnedUtilities 68,610 113,110,317.03 1,025,190,034.87 1,025.18

Investor-Owned Electric Utilities

FortisBCInc. 131,877 279,416,909.00 2,534,951,714.00 2,535.00HemlockUtilityServicesLimited 249 222,673.23 1,509,857.00 1.51KyuquotPowerLtd. 39 373,904.58 1,486,573.00 1.49SilversmithLightandPowerCorporation 10 34,062.56 1,571,343.00 1.57CorixMulti-UtilityServicesInc. SunRivers 795 1,373,738.00 12,445,756.00 12.45SonomaPines 493 421,817.00 4,132,624.00 4.13YukonElectricalCompanyLimited-LowerPostBC 78 125,400.00 798,390.00 0.80

TotalInvestor-Owned 133,541 281,968,504.37 2,556,896,257.00 2,556.95

TotalAllElectricUtilities 2,157,223 4,652,359,259.40 53,131,544,603.87 53,131.13

D O M E S T I C S A L E S

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D O M E S T I C S A L E S

Domestic Thermal Energy Sales Customers # Revenue ($) Actual Sales (GJ) Actual

Stream B Thermal Energy Utilities

FortisBCAlternativeEnergyServicesInc. TsawwassenSprings 1 58,362.00 NotavailableDeltaSchoolDistrict#37 1 347,232.00 19,204.00GlenValley 1 59,868.00 NotavailableBrant 1 16,986.00 NotavailableCamdenGreen 1 30,363.00 NotavailableHelenGorman 1 22,229.00 NotavailableArtemisia 1 35,464.00 1,317.00TelusGardens 3 0.00 0.00Sovereign 3 264,834.00 8,513.00

CorixMulti-UtilityServicesInc. UniverCityNUS 6 455,921.00 14,399.00UBCNES-Phase1Westwood 1 25,459.00 643.00

CreativeEnergyVancouverPlatformsInc. Downtown(Steam) 199 7,352,630.00 1,156,760.00

DocksideGreenEnergy 5 183,619.00 5,914.00RiverDistrictEnergy 2 230,000.00 7,000.00

TotalAllStreamBThermalEnergyUtilities 226 9,082,967.001,213,750.00

Domestic Gas Sales Customers # Revenue ($) Actual Sales (GJ) Actual

Investor-Owned Natural Gas or Propane Gas Utilities

FortisBCEnergyInc. Mainland,VancouverIsland,Whistler,Revelstoke 979,243 1,255,805,000.00 185,836,000.00 FortNelsonDivision 2,446 3,828,000.00 561,000.00

PacificNorthernGas(N.E.)Ltd. FortSt.John/DawsonCreekDivision 19,547 25,951,767.00 4,359,230.00 TumblerRidgeDivision 1,247 1,958,570.00 944,517.00

PacificNorthernGasLtd.(includesGranisleGrid) 20,511 44,478,080.00 4,115,753.00

CorixMulti-UtilityServicesInc. SunRivers 506 159,349.00 10,657.00 SonomaPines 492 238,605.00 20,601.00 Panorama 229 775,469.00 32,242.00

CalgasInc. Kickinghorse 135 146,579.02 17,464.85 CanyonRidge 26 12,552.37 1,849.74

BigWhiteGasUtilityLtd. 362 680,178.51 38,010.40

PortAliceGasInc. 231 181,858.00 8,266.00

SunPeaksUtilitiesCo.Ltd. 900 1,607,502.00 72,264.00

StargasUtilitiesLtd. 285 232,894.84 37498.00

TotalAllGasUtilities 1,026,160 1,336,056,404.74 196,055,352.99


D I R E C T I O N S

DIRECTIONS The following is a general description of the Directions received from the Provincial Government during 2015/2016. The complete text is available on the Commission’s website at www.bcuc.com/SpecialDirection.aspx

Order in Council 297Approved June 3, 2015 – Amendments to the Greenhouse Gas Reduction (Clean Energy) Regulation.

Order in Council 404Approved July 14, 2015 – Direction to the British Columbia Utilities Commission respecting British Columbia Hydro and Power Authority’s TMP Program.

Order in Council 405Approved July 14, 2015 – Section 9 of Direction No. 7 to the British Columbia Utilities Commission is amended by adding subsection (3) respecting the setting of British Columbia Hydro and Power Authority’s rates for F2017, F2018, and F2019.

Order in Council 454Approved July 27, 2015 – Approval to grant an exemption to Templeton Designer Outlet Centre Limited Partnership for its proposed supply of electricity at McArthurGlen Design Outlet Vancouver Airport.

Order in Council 455Approved July 27, 2015 – Approval to grant an exemption to ATCO Electric Ltd. for its distribution facilities used to supply electric service to its Alberta/British Columbia Border Customers from the requirements of Part 3 of the Utilities Commission Act, except for sections 25, 38, 42, and 43.

Order in Council 456Approved July 27, 2015 – Approval to grant an exemption to Canadian Forest Products Ltd. from Part 3 of the Utilities Commission Act, except for sections 25, 38, 42, and 43, for its electrical distribution lines supply Canfor’s NOS Substation customers.

Order in Council 596Approved October 14, 2015 – Approval to transfer $450 million of optional vehicle insurance capital to the universal compulsory vehicle insurance business after December 31, 2016 and on or before January 15, 2016.

Order in Council 597Approved October 14, 2015 – Amendments to Special Direction IC2 to the British Columbia Utilities Commission.

Order in Council 731Approved November 25, 2015 – Approval to grant an exemption for Tolko Industries Ltd. and the portion of its Lavington substation distribution facilities used to supply electric service to Lavington Pellet Limited Partnership from the requirements of Part 3 of the Utilities Commission Act except for sections 25, 38, 42, and 43.

Order in Council 824Approved December 17, 2015 – Approval of the Security for Costs (Administrative Tribunals) Regulation.

Order in Council 825Approved December 17, 2015 – Approval of the Administrative Tribunals Reporting Regulation.

Order in Council 123Approved February 29, 2016 – Approval of the Direction to the British Columbia Utilities Commission Respecting mining Customers.

A N N U A L R E P O R T 2 0 1 5 / 1 6 57

D I R E C T I O N S

EXEMPTIONS

Order G-131-15 (OIC 454) Issued August 4, 2015 Exemption for Templeton Designer Outlet Centre Limited Partnership from Part 3 of the Utilities Commission Act except for sections 25, 38, 41 and 42 for the purpose of resale of electricity to its Lessees at the Regional Designer Outlet Centre located at Vancouver International Airport in Richmond, British Columbia. The order also exempts from section 71 of the Utilities Commission Act, Templeton LP and its Lessees provided that the Lessees are not reselling electricity.

Order G-140-15 (OIC 455) Issued August 27, 2015 Exemption for ATCO Electric Ltd. for its distribution facilities used to supply electric service to its Alberta/British Columbia Border Customers from the requirements of Part 3 of the Utilities Commission Act, except for sections 25, 38, 42, and 43.

Order G-141-15 (OIC 456) Issued: August 27, 2015 Exemption for Canadian Forest Products Ltd. from the requirements of Part 3 of the Utilities Commission Act, except for sections 25, 38, 42, and 43, for its NOS Substation distribution facilities used to supply electric service to its customers. The order also exempts Canfor and any person that receives energy from Canfor’s NOS Substation distribution facilities from section 71 of the Utilities Commission Act provided the person is not re-selling energy to others.

Order G-196-15 (OIC 731) Issued: December 10, 2015Exemption for Tolko Industries Ltd. and the portion of its Lavington substation distribution facilities used to supply electric service to Lavington Pellet Limited Partnership from the requirements of Part 3 of the Utilities Commission Act except for sections 25, 38, 42, and 43.


R E G U L AT E D E N T I T I E S

REGULATED ENTITIES Crown-Owned Electric UtilitiesBritish Columbia Hydro and Power AuthorityLower Mainland, Vancouver Island, Central and Northern BC and East Kootenay Regions

Investor-Owned Electric Utilities Corix Multi Utility Services Inc. Lot 152, CLSR Plan 78619 Kamloops

Hemlock Utility Services Ltd. Hemlock Valley

Silversmith Power & Light CorporationSandon

FortisBC Inc.West Kootenay and Okanagan Regions of BC, Princeton, Osprey Lake and Missezula Lake Areas and Kelowna

Kyuquot Power Ltd.Kyuquot

The Yukon Electrical Company Limited(operating as ATCO Electric Yukon) Lower Post

Thermal Energy District SystemsCorix Multi-Utility Services Inc.UBC NES- Phase 1 Westwood UniverCity NUS

Creative Energy Vancouver Platforms Ltd.Downtown Vancouver (steam, formerly Central Heat Distribution Limited)Northeast False Creek

Dockside Green Energy LLP.District Energy System, Victoria

FortisBC Alternative Energy Services Inc.Tsawwassen Springs Development, Delta School District No. 37, Telus Garden Development, Glen Valley, Brant, Camden Green, Helen Gorman, Artemisia and Sovereign

River District Energy LPDistrict Energy Utility at the River District, Vancouver, BC

Investor-Owned Natural Gas, or Propane UtilitiesBig White Gas UtilityBig White Ski Resort

Cal-Gas Inc.Canyon Ridge and Kicking Horse

Corix Multi Utility Services Inc.Panorama, Sonoma Pines and Sun Rivers

FortisBC Energy Inc.Lower Mainland, Fort Nelson, Central and Northern Interior, the Kootenays, the Okanagan, Whistler, Sunshine Coast, Powell River, and Vancouver Island north to Campbell River, west to Port Alberni, and south to Victoria

Pacific Northern Gas Ltd. Summit Lake to Prince Rupert and Kitimat and Granisle (Propane Grid System)

Pacific Northern Gas (N.E.) Ltd.Dawson Creek, Rolla, Pouce Coupe, Tumbler Ridge and Fort St. John

Port Alice Gas Inc.Port Alice (Propane Grid System)

Stargas Utilities Ltd.Silver Star resort community

Sun Peaks Utilities Co., Ltd.Resort area north of Kamloops

Compulsory Automobile InsuranceInsurance Corporation of British ColumbiaProvince of BC

Municipally-Owned Electric UtilitiesMunicipally-owned electric utilities are not regulated under the Utilities Commission Act. Only the City of Nelson’s electric utility with service outside of the Municipal boundaries is subject to regulation by the British Columbia Utilities Commission.

City of Grand ForksCity of Nelson (also known as Nelson Hydro)City of New Westminster City of Penticton District of Summerland

Stream A Thermal Energy SystemsFortisBC Alternative Energy Services Inc.Marine Gateway 400 SW Marine Dr., Vancouver, BC Order G-172-15

Queen Elizabeth Park Thermal Energy System Order G-176-15

Seylynn Village Development (geo-exchange system (GES) loop field) Order G-74-15

Creative Energy Vancouver Platforms Inc.188 Keefer Street Order G-101-15

Corix Multi Utility Services Inc.Talasa Central Energy Plant/ Sun Rivers Resort Community Order G-102-15

Belmonte Central Energy Plant/Sun Rivers Resort Community Order G-103-15

SOLO District Development – Phase 1 G-129-15A (rescinds G-54-14)

Waterstone Pier G-191-14 Alysen Place G-191-14 Flatiron G-191-14 Pomaria G-191-14 The Hudson G-191-14

ENVIRONMENTAL CALCULATORThe BC Utilities Commission saved the following resources by using: 21.2900 lb(s) of Rolland Enviro100 Satin and 4.2700 lb(s) of Rolland Enviro100 Digital, made with 100% recycled fibre and 100% post-consumer waste, processed chlorine-free.

RESULTS: Based on the Cascades products selected compared to products in the industry made with 100% virgin fiber, the ecological footprint of this publication has been reduced by:

0 tree

10 kg of waste

795 L of water2 days of waterconsumption

32 kg CO2

213 KM driven

0 kg NOx

0 GJ1,010 60W light bulbsfor one hour

SOURCES: Environmental impact estimates for the North American marketplace are made using the Environmental Paper Network Paper Calculator Version 3.2. For more information visit www.papercalculator.org. The fine papers' environmental savings related to greenhouse gaz impacts are based on the Life Cycle Assessment methodology. The LCA was made by Rolland and validated by a third-party www.rollandinc.com.

TO BE UPDATED

AT PRINT

British Columbia Utilities CommissionSixth Floor, 900 Howe Street, Box 250Vancouver, British Columbia, Canada V6Z 2N3

Telephone (604) 660-4700Facsimile (604) 660-1102BC Toll Free 1-800-663-1385

General Inquiries & Filings: [email protected]

Utility Customer Complaints: [email protected]

Natural Gas Marketing, Customer Choice Inquiries: [email protected]

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