Definitions

1   (1) In this direction:

"Act" means the Utilities Commission Act;

"applicable customers" means customers of a utility other than customers receiving service

(a) under a fixed rate,

(b) in the Fort Nelson service area of the utility, unless the Fort Nelson service area no longer has a distinct rate base, or

(c) under the transportation rate schedule;

"CNG service" means a service that includes one or both of the following:

(a) compressing and dispensing of natural gas through specialized fuelling facilities or equipment;

(b) transporting compressed natural gas using specialized trailers or equipment;

"construction carrying costs" means a return on the feasibility, development and capital costs of a facility, equal to the utility's weighted average cost of capital, that will be incurred during the period ending when the facility enters a utility's natural gas class of service rate base;

"contract demand" has the same meaning as in the LNG rate schedule;

"CTS expansion project" means any of the following projects:

(a) the project to expand the transmission facilities of FortisBC Energy Inc. at and between the Cape Horn Valve Assembly and Coquitlam Gate Station;

(b) the project to expand the transmission facilities of FortisBC Energy Inc. at and between the Nichol Valve Assembly and Port Mann Crossover Station;

(c) the project to expand the transmission facilities of FortisBC Energy Inc. at and between the Nichol Valve Assembly and Roebuck Valve Assembly;

(d) the project to expand the transmission facilities of FortisBC Energy Inc. at and between the Tilbury Gate Station and Tilbury LNG Facility;

"EGP project" means the project to expand the transmission facilities of FortisBC Energy (Vancouver Island) Inc at and between the Eagle Mountain Compressor Station in Coquitlam and an LNG facility in Woodfibre, and at the Port Mellon Compressor Station;

"expansion facilities" means LNG facilities to be constructed, operated and owned or leased, after this direction comes into force, by a utility at Tilbury Island, Delta, British Columbia;

"extraordinary retirement costs" means asset retirement costs from causes not reasonably anticipated when calculating the depreciation of the asset;

"first nation" includes a person authorized to act on behalf of Indigenous peoples who hold rights recognized and affirmed by section 35 of the Constitution Act, 1982;

"fixed rate" means a charge for natural gas service not subject to adjustment based on changes in the revenue requirements of a utility;

"letter agreement" means the letter agreement as set out in Appendix 3 attached to this direction;

"liquefaction capacity" means the capacity of an LNG facility, measured in terajoules per day, to liquefy natural gas to produce LNG;

"LNG" means liquefied natural gas;

"LNG dispensing service" means the dispensing service referred to in sections 3 to 5 of the LNG rate schedule;

"LNG facility" means a facility that produces, stores and dispenses LNG and, in some cases, vaporizes LNG;

"LNG rate schedule" means the utility's Liquefied Natural Gas Sales, Dispensing and Transportation Service Rate Schedule 46 as set out in Appendix 1 attached to this direction;

"LNG revenue variance regulatory account" means an account to capture the first 3 annual revenue variances between

(a) the forecast revenues from the LNG rate schedule that are used by the commission in setting rates for applicable customers, and

(b) the actual annual revenues received under the LNG rate schedule;

"LNG service" means one or more of the following services:

(a) procurement of natural gas and electrical power for the purposes of LNG production;

(b) procurement of LNG;

(c) transmission and distribution of natural gas to an LNG facility;

(d) production of LNG from natural gas at an LNG facility;

(e) storage of LNG;

(f) provision or sale of LNG, including LNG dispensing service and marine LNG service;

(g) use of LNG fuelling stations and fuelling equipment;

(h) transportation of LNG, including LNG transportation service;

(i) use of cryogenic receptacles, including, but not limited to, tankers, containers and vessels;

"LNG transportation service" means the transportation service referred to in section 6 of the LNG rate schedule;

"marine LNG rate schedule" means the utility's Liquefied Natural Gas (LNG) and Renewable LNG (RLNG) Sales, Transport, Dispensing and Jetty Service Rate Schedule 48 set out in Appendix 6 attached to this direction;

"marine LNG revenue deficiency regulatory account" means an account to capture the first 10 annual variances between

(a) the forecast cost of service in relation to marine LNG service, and

(b) the forecast revenues in relation to that service under the marine LNG rate schedule that are used by the commission in setting rates for applicable customers;

"marine LNG service" means any service referred to in section 3, 4, 5, 6 or 9 of the marine LNG rate schedule;

"marine LNG variance regulatory account" means an account to capture the following variances:

(a) the first 10 annual variances between the forecast cost of service in relation to marine LNG service and the actual cost of service in relation to that service;

(b) the first 10 annual variances between the forecast revenues from marine LNG service under the marine LNG rate schedule and the actual revenues from that service under the marine LNG rate schedule;

"operating costs", in relation to a facility, means

(a) operating and maintenance expenses,

(b) electricity expenses,

(c) interest expenses,

(d) taxes, including property taxes,

(e) return on equity,

(f) extraordinary retirement costs, and

(g) amounts with respect to the depreciation of the

(i) capital costs,

(ii) construction carrying costs,

(iii) feasibility and development costs,

(iv) sustaining capital costs, and

(v) decommissioning and salvaging costs

determined with reference to the remaining service life of the facility, as estimated by the commission in setting rates for applicable customers;

"phase 1A facilities" means expansion facilities to provide

(a) liquefaction capacity of up to 40 terajoules per day of LNG, and

(b) storage capacity of between 1.0 petajoules and 1.1 petajoules of LNG;

"phase 1B facilities" means all of the following:

(a) expansion facilities other than phase 1A facilities or LNG storage facilities;

(b) the Tilbury Island electrical facilities;

(c) the Tilbury Island jetty;

(d) a new cryogenic pipeline and related facilities for the purpose of providing marine LNG service at the Tilbury Island jetty;

"sustaining capital costs" means capital costs expended for the purpose of maintaining or extending the life of an asset;

"Tilbury Island electrical facilities" means a new 230 kilovolt electric transmission line, and related facilities, from the Arnott substation of the authority to the expansion facilities, to be constructed, operated and owned or leased by a utility;

"Tilbury Island jetty" means a jetty at Tilbury Island to be constructed, operated and owned or leased by a utility for the purpose of providing marine LNG service;

"transportation agreements" means the transportation agreements as set out in Appendix 4.1 attached to this direction;

"transportation rate schedule" means the Large Volume Industrial Transportation Rate Schedule 50 of FortisBC Energy Inc. as set out in Appendix 4 attached to this direction;

"utility" means

(a) FortisBC Energy Inc.,

(b) FortisBC Energy (Vancouver Island) Inc., or

(c) FortisBC Energy (Whistler) Inc.,

or any of those entities' successor entities on amalgamation, merger or consolidation.

(2) In this direction, a reference to a utility referred to in the definition of "utility" in subsection (1) includes any successor entities of that utility on amalgamation, merger or consolidation.

[am. B.C. Regs. 265/2014, s. 1; 74/2023, s. 1; 147/2026, s. 1.]

Application

2   This direction is issued to the commission under section 3 of the Act.

CNG services and LNG services

3   In setting rates under the Act for a utility, the commission must do all of the following:

(a) treat CNG service and LNG service, and all costs and revenues related to those services, as part of the utility's natural gas class of service;

(b) allocate all costs and revenues related to CNG service and LNG service to all applicable customers;

(c) allow recovery of costs of purchasing LNG under the agreement referred to in section 5 (1) (b) of this direction.

Expansion facilities

4   (1) The commission must not exercise its power under section 45 (5) of the Act in respect of

(a) phase 1A facilities, and

(b) phase 1B facilities.

(2) In setting rates under the Act for FortisBC Energy Inc., the commission must do all of the following:

(a) include in the utility's natural gas class of service rate base the sum of the following:

(i) the lesser of

(A) the capital costs of the phase 1A facilities, and

(B) $425 million;

(ii) the construction carrying costs for the phase 1A facilities;

(iii) the feasibility and development costs incurred on or after January 1, 2013;

(b) include in the utility's natural gas class of service rate base the sum of the following:

(i) the lesser of

(A) the capital costs of phase 1B facilities, and

(B) $2.2 billion;

(ii) the construction carrying costs for phase 1B facilities;

(iii) the feasibility and development costs incurred on or after January 1, 2013;

(c) include in the calculation of rates for applicable customers

(i) the annual revenues from the sale of LNG from phase 1A facilities and phase 1B facilities,

(ii) the annual operating costs of phase 1A facilities and phase 1B facilities, and

(iii) the capital costs, construction carrying costs, sustaining capital costs, decommissioning and salvaging costs and feasibility and development costs respecting phase 1A facilities and phase 1B facilities;

(iv) amounts paid, under the Electric Tariff of the authority, by the utility in relation to upgrades necessary to connect the Tilbury Island electrical facilities to the Arnott substation of the authority;

(d) allow a utility to establish an LNG revenue variance regulatory account for the following 2 purposes, if applicable:

(i) for the operation of the phase 1A facilities;

(ii) for the operation of the phase 1B facilities;

(e) set rates for applicable customers in such a way as to allow the LNG revenue variance regulatory account to be cleared from time to time, and within a reasonable period by allowing the balance to be returned to or recovered from applicable customers;

(f) allow the utility to establish a marine LNG revenue deficiency regulatory account for the purposes of the operation of the phase 1B facilities;

(g) set rates for applicable customers in such a way as to allow

(i) the utility to recover a return on the balance in the marine LNG revenue deficiency regulatory account equal to the utility's weighted average cost of capital, and

(ii) the marine LNG revenue deficiency regulatory account to be cleared from time to time and within a reasonable period by allowing the balance to be returned to or recovered from applicable customers;

(h) allow the utility to establish a marine LNG variance regulatory account for the purposes of the operation of the phase 1B facilities;

(i) set rates for applicable customers in such a way as to allow the marine LNG variance regulatory account to be cleared from time to time and within a reasonable period by allowing the balance to be returned to or recovered from applicable customers.

[en. B.C. Reg. 265/2014, s. 2; am. B.C. Regs. 115/2017, ss. 1 to 4; 147/2026, s. 2.]

LNG rate schedule and LNG purchase agreement

5   (1) Within 20 days of the date this direction comes into force, the commission must do all of the following:

(a) issue an order setting the LNG rate schedule as a rate for FortisBC Energy Inc., effective on the date the order is issued;

(b) accept for filing under section 71 of the Act the Gas Liquefaction, Storage and Dispensing Service Agreement between FortisBC Energy (Vancouver Island) Inc. and FortisBC Energy Inc. as set out in Appendix 2 attached to this direction;

(c) issue an order setting the agreement referred to in paragraph (b) as a rate for FortisBC Energy (Vancouver Island) Inc.

(1.1) Before January 1, 2015, the commission must issue an order amending the LNG rate schedule as set out in Appendix 5 attached to this direction, effective on January 1, 2015.

(1.2) Within 60 days of the date this subsection comes into force, the commission must issue an order amending the LNG rate schedule by deleting section 3 (1) (b) and (c) on the version of page R-46.22 accepted for filing on January 25, 2016.

(2) The commission must not do anything to amend, cancel or suspend the LNG rate schedule, except on application by the utility.

(3) If FortisBC Energy Inc. applies to the commission to amend a charge in the LNG rate schedule, the commission must not set the charge by reference to charges imposed by other providers providing similar services.

(4) The commission must not exercise a power under the Act in a way that would directly or indirectly prevent FortisBC Energy Inc. from providing LNG dispensing service under the LNG rate schedule.

[am. B.C. Regs. 265/2014, s. 3; 115/2017, s. 5.]

Transportation rate schedule

6   (1) Repealed. [B.C. Reg. 74/2023, s. 2 (a).]

(1.1) Within 60 days after the date this subsection comes into force, the commission must issue an order setting the transportation rate schedule as a rate for FortisBC Energy Inc., effective on the date the order is issued.

(2) In calculating rates for applicable customers, the commission must include the annual revenues and operating costs arising from services provided under the transportation rate schedule.

(3) Section 5 (2) applies to the transportation rate schedule.

(4) The commission must not exercise a power under the Act in a way that would directly or indirectly prevent FortisBC Energy Inc. from providing service under the transportation rate schedule.

(5) If the shipper is not creditworthy and has not provided the guarantee referred to in section 13.2 (b) of the transportation rate schedule, the commission must set the required security amount on the basis of the following:

(a) the shipper's creditworthiness;

(b) the contract demand and the contract term of the transportation agreement;

(c) the book value of the incremental system upgrades constructed, acquired, contracted for or secured by a utility to serve the shipper;

(d) any other matter the commission considers relevant.

(6) Terms used in subsection (5) and not defined in this direction have the same meaning as in the transportation rate schedule.

[en. B.C. Reg. 265/2014, s. 4; am. B.C. Regs. 115/2017, s. 6; 74/2023, s. 2.]

Transportation rate schedule — transportation agreements

6.1   (1) Within 60 days after the date this subsection comes into force, the commission must issue an order setting the transportation agreements as rates for FortisBC Energy Inc., effective on the date the order is issued.

(2) Section 5 (2) applies to the transportation agreements.

[en. B.C. Reg. 74/2023, s. 3.]

EGP project

7   (1) Within 60 days of the date this section comes into force, the commission must, by regulation under section 45 (4) of the Act, exclude the EGP project from the operation of section 45 (1) of the Act.

(2) In setting rates under the Act for FortisBC Energy (Vancouver Island) Inc., the commission must

(a) include in the utility's natural gas class of service rate base the capital costs, construction carrying costs and feasibility and development costs for the EGP project,

(b) allow the utility to earn a return on the costs referred to in paragraph (a), and

(c) include in the calculation of rates for applicable customers

(i) the annual operating costs of the EGP project, and

(ii) the capital costs, construction carrying costs, sustaining capital costs, decommissioning and salvaging costs and feasibility and development costs respecting the EGP project.

[en. B.C. Reg. 265/2014, s. 4; am. B.C. Reg. 115/2017, s. 7.]

CTS expansion projects

8   (1) The commission must refrain from exercising its power under section 45 (5) of the Act with respect to a CTS expansion project.

(2) In setting rates under the Act for FortisBC Energy Inc., the commission must

(a) include in the utility's natural gas class of service rate base the capital costs, construction carrying costs and feasibility and development costs for the CTS expansion project,

(b) allow the utility to earn a return on the costs referred to in paragraph (a), and

(c) include in the calculation of rates for applicable customers

(i) the annual operating costs of the CTS expansion project, and

(ii) the capital costs, construction carrying costs, sustaining capital costs, decommissioning and salvaging costs and feasibility and development costs respecting the CTS expansion project.

[en. B.C. Reg. 265/2014, s. 4; am. B.C. Reg. 115/2017, s. 8.]

Letter agreement

9   (1) Within 60 days of the date this section comes into force, the commission must issue an order setting the letter agreement as a rate for FortisBC Energy Inc. and FortisBC Energy (Vancouver Island) Inc., effective, subject to section 2.1 of the letter agreement, on the date the order is issued.

(2) Section 5 (2) applies to the letter agreement.

[en. B.C. Reg. 265/2014, s. 4.]

Marine LNG rate schedule

10   (1) Within 30 days of the date this section comes into force, the commission must issue an order setting the marine LNG rate schedule as a rate for FortisBC Energy Inc.

(2) The commission must not do anything to amend, cancel or suspend the marine LNG rate schedule, except on application by the utility.

(3) If FortisBC Energy Inc. applies to the commission to amend a charge in the marine LNG rate schedule, the commission must not set the charge by reference to charges imposed by other providers providing similar services.

(4) The commission must not exercise a power under the Act in a way that would directly or indirectly prevent FortisBC Energy Inc. from providing marine LNG service under the marine LNG rate schedule.

[en. B.C. Reg. 147/2026, s. 3.]

Co-ownership of phase 1B facilities

11   (1) This section applies if FortisBC Energy Inc. makes an application to the commission in relation to

(a) the disposition of one or more of the phase 1B facilities to a limited partnership through which FortisBC Energy Inc. and a first nation would hold ownership interests in those phase 1B facilities, and

(b) the lease of one or more of the phase 1B facilities by the limited partnership to FortisBC Energy Inc.

(2) The commission must not exercise a power or perform a duty under the Act in a way that would directly or indirectly prevent FortisBC Energy Inc. from disposing of and leasing back one or more of the phase 1B facilities as contemplated in an application described in subsection (1), unless the commission determines the disposition and lease would materially increase the amounts paid by applicable customers through rates set under the Act for FortisBC Energy Inc.

[en. B.C. Reg. 147/2026, s. 3.]