88R21988 JXC-F

By: Metcalf H.B. No. 2555

Substitute the following for H.B. No. 2555:

By: Smithee C.S.H.B. No. 2555

A BILL TO BE ENTITLED

AN ACT

relating to transmission and distribution system resiliency planning by and cost recovery for electric utilities.

BE IT ENACTED BY THE LEGISLATURE OF THE STATE OF TEXAS:

SECTION 1. The legislature finds that:

(1) extreme weather conditions, including high winds, lightning, flooding, and freezes, can cause extraordinary damage to electrical transmission and distribution facilities, resulting in power outages;

(2) it is in the state's interest to promote the use of resiliency measures to enable electrical transmission and distribution infrastructure to withstand extreme weather conditions, including hardening electrical transmission and distribution facilities, undergrounding certain electrical distribution lines, lightning mitigation measures, flood mitigation measures, information technology and cyber security measures, vegetation management, and wildfire mitigation and response;

(3) protecting electrical transmission and distribution infrastructure from extreme weather conditions can effectively reduce system restoration costs to and outage times for customers and improve system resiliency and overall service reliability for customers;

(4) it is in the state's interest for each electric utility to seek to mitigate system restoration costs to and outage times for customers when developing plans to enhance electrical transmission and distribution infrastructure storm resiliency; and

(5) all customers benefit from reduced system restoration costs.

SECTION 2. Subchapter D, Chapter 38, Utilities Code, is amended by adding Section 38.078 to read as follows:

Sec. 38.078. TRANSMISSION AND DISTRIBUTION SYSTEM RESILIENCY PLAN AND COST RECOVERY. (a) In this section, "plan" means a transmission and distribution system resiliency plan described by Subsection (b).

(b) An electric utility may file, in a manner authorized by commission rule, a plan to enhance the resiliency of the utility's transmission and distribution system through at least one of the following methods:

(1) hardening electrical transmission and distribution facilities;

(2) modernizing electrical transmission and distribution facilities;

(3) undergrounding certain electrical distribution lines;

(4) lightning mitigation measures;

(5) flood mitigation measures;

(6) information technology;

(7) cyber security measures;

(8) physical security measures;

(9) vegetation management; or

(10) wildfire mitigation and response.

(c) A plan must explain the systematic approach the electric utility will use to carry out the plan during at least a three-year period.

(d) In determining whether to approve a plan filed under this section, the commission shall consider:

(1) the extent to which the plan is expected to enhance system resiliency, including whether the plan prioritizes areas of lower performance; and

(2) the estimated costs of implementing the measures proposed in the plan.

(e) Not later than the 180th day after an electric utility files a plan under Subsection (b) that complies with any applicable commission rules, the commission shall by order approve, approve with modification, or deny the plan. The commission may not approve a plan if the commission determines that approving the plan is not in the public interest. If the commission does not issue an order by the 180th day, the plan and any associated rider described by Subsection (i) are considered to have been approved.

(f) If the commission approves the plan, the approval is not considered to be a requirement for the purposes of Chapter 36 or this chapter that an electric utility implement all the measures or incur all the estimated costs in the plan if business needs, financial conditions, or supply chain or labor conditions dictate otherwise. If the commission denies the plan, the denial is not considered to be a finding of the prudence or imprudence of a measure or cost in the plan for the purposes of Chapter 36 or this chapter.

(g) An electric utility for which the commission has approved a plan under this section may request that the commission review an updated plan submitted by the electric utility. The updated plan must comply with any applicable commission rules and take effect on a date that is not earlier than the third anniversary of the approval of the utility's most recently approved plan. The commission shall review and approve, modify, or deny the updated plan in the manner provided by Subsections (d), (e), and (f).

(h) An electric utility's implementation of a plan approved under this section may not be considered imprudent for the purposes of Chapter 36 or this chapter. If the commission determines that the costs to implement an approved plan were prudently incurred, those costs are not subject to disallowance for exceeding the estimates in the plan.

(i) Notwithstanding any other law, an electric utility may file with a plan an application for a rider to recover all or a portion of the estimated costs relating to the electric utility's implementation of the plan. If the commission approves the plan and the electric utility filed an application for a rider, the commission shall determine the appropriate terms of the rider in the approval order. A rider approved under this subsection must allow the electric utility to begin recovering the levelized cost of implementing the approved plan at the time the plan is first implemented.

(j) As part of a review described by Subsection (g), the commission shall reconcile any rider approved in connection with the previously approved plan to determine the electric utility's reasonably and prudently incurred plan costs.

(k) If an electric utility that files a plan with the commission does not apply for a rider under Subsection (i), the utility may defer all or a portion of the costs relating to the implementation of the plan for future recovery as a regulatory asset, including carrying costs at the utility's weighted average cost of capital established in the commission's final order in the utility's most recent base rate proceeding, and use commission authorized cost recovery alternatives under Sections 35.004, 36.209, and 36.210 or another general rate proceeding.

(l) Plan costs considered by the commission to be reasonable and prudent may not include the same costs otherwise recovered through the electric utility's base rates and must be allocated to customer classes pursuant to the rate design most recently approved by the commission. If a capital investment is recoverable as a plan cost, the electric utility may recover all reasonable and prudent costs associated with the investment, including the annual depreciation expense related to the investment calculated at the utility's currently approved depreciation rates, the after-tax return on the undepreciated balance of the investment calculated using the rate of return approved by the commission in the utility's last comprehensive base rate proceeding, and federal income tax and other taxes related to the investment.

(m) An electric utility for which the commission has approved a plan under this section is not required to submit to the commission during the period in which the plan is in effect any annual report required by Section 38.005 or 38.101 or by commission rule adopted under those sections. This subsection does not apply to an annual service quality report required by commission rule.

SECTION 3. The Public Utility Commission of Texas shall adopt rules to implement Section 38.078, Utilities Code, as added by this Act, not later than the 180th day after the effective date of this Act.

SECTION 4. This Act takes effect immediately if it receives a vote of two-thirds of all the members elected to each house, as provided by Section 39, Article III, Texas Constitution. If this Act does not receive the vote necessary for immediate effect, this Act takes effect September 1, 2023.