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Performance was driven by the execution of a multi-jurisdictional regulatory strategy and significantly lower interest expense following the full repayment of HoldCo debt.

The company achieved a key milestone in Nevada with the Triennial Resource Plan approval, providing prudency predeterminations for $186 million in infrastructure investment.

Utility returns improved to an adjusted 8.0% ROE, though management noted a remaining gap to the authorized 9.89% that they expect to close through pending rate cases.

Operational efficiency remained a focus, with O&M expenses declining by nearly 3% due to lower outside services and bad debt expense despite continued customer growth.

The Great Basin 2028 Expansion Project was upsized to a 48-inch pipeline design to accommodate strong market demand, which has reached 1 Bcf per day in binding agreements.

Management emphasized that their regulatory strategy is diversified across three states, reducing dependency on any single case outcome or political environment.

The 2028 Expansion Project capital estimate increased to $2.3 billion, which is expected to generate $270 million to $300 million in incremental annual margin upon completion.

Management anticipates no equity issuances for the remainder of 2026, with the remaining financing plan consisting of utility-level debt while leveraging holding company capacity for longer-term needs.

Long-term rate base CAGR is projected at 9.5% to 11.5% through 2030, effectively doubling the system-wide rate base from 2025 levels.

The company plans to file for a FERC Certificate of Public Convenience and Necessity (CPCN) by year-end 2026, targeting a late 2027 approval and Q4 2028 in-service date.

Future capacity needs beyond 2028, estimated at 1.8 Bcf of interest through 2035, are expected to be managed via incremental compression additions rather than further pipe diameter increases.

A $9.7 million incremental net income gain was recognized in Q2 following a California decision that allowed for retroactive recovery of deferred margins.

HoldCo interest expense decreased by $8.6 million year-over-year, reflecting a structurally leaner balance sheet following debt retirement.

Other income declined by $9.4 million, attributed to lower utility cash balances, weaker COLI performance, and the timing of charitable contributions.

The company plans a routine renewal of its at-the-market (ATM) equity program; however, management explicitly stated this is not a signal of near-term issuance.

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Management confirmed the 48-inch pipe design provides a foundation to accommodate the 1.8 Bcf of additional interest through 2035 via compression.

Capital intensity for future phases remains 'to-be-determined' as it depends on converting current expressions of interest into binding precedent agreements.

The company intends to use holding company leverage capacity to absorb equity needs at the utility level, citing significant cushion above downgrade thresholds.

Management expects the high margin profile of the completed project to eventually deleverage the balance sheet, minimizing the need for external equity through 2030.

Incremental demand is primarily coming from data center development and power generation, alongside mining and manufacturing sectors.

Management noted that every open season has resulted in demand exceeding expectations, reinforcing confidence in regional economic development.