Physical climate risk has stopped being a long-term warning and started showing up in utility balance sheets, insurance filings, and municipal reserve accounts right now. The market is still treating each fire season as a one-time disruption. It isn't. It's a ratchet — and every click tightens the cost structure permanently for utilities, property insurers, homeowners, and the local governments that depend on all three.
Five-Model Consensus
All five analysts — Atlas, Meridian, Grayline, Vantage, and Chronicle — agreed on the core finding: physical climate risk has already crossed from narrative into measurable financial metrics, and markets are pricing it as a transitory shock rather than a permanent baseline shift. All five agreed that the most dangerous mispricing is not in catastrophe headlines but in secondary transmission channels — insurance withdrawal, working capital inflation, utility liability frameworks, and municipal reserve erosion. Meridian and Vantage provided the strongest quantitative grounding: Meridian flagged that a sustained 5-10 point combined ratio increase from catastrophe frequency can cut insurer return on equity by 300-700 basis points — meaning for every dollar of equity an insurer holds, it earns 3 to 7 cents less annually — and that rising insurance premiums function like a hidden 100-250 basis point increase in effective mortgage rates in exposed ZIP codes. Vantage anchored the insurance data with Munich Re's 2023 figure of $270 billion in natural disaster losses, with only $100 billion insured, confirming that uninsured losses — the ones that fall on households, businesses, and municipalities directly — dwarf the insured totals that dominate coverage. The primary dissent was one of emphasis, not direction. Grayline's sourcing from active utility and carrier executives suggested that the capex uplift (15-25% through 2026) is being privately acknowledged at senior levels but deliberately downplayed in public filings and investor communications — a gap that Meridian and Atlas identified analytically but Grayline confirmed operationally. Chronicle, whose structured regulatory analysis was truncated in source form, aligned with Atlas on the legal architecture risk, particularly the unresolved inverse condemnation exposure outside California. No analyst argued the market was correctly pricing this risk. The only disagreement was whether the repricing catalyst would be a single acute event (Atlas's view) or cumulative micro-deterioration in issuer-level financials (Meridian's view). Both can be right simultaneously — the slow erosion sets the conditions, the acute event pulls the trigger.
Contributing: Atlas, Meridian, Grayline, Vantage, Chronicle
Start with the insurance story, because it unlocks everything else. State Farm and Allstate pulling back from California homeowner coverage in 2023 got covered as a consumer affordability problem. It's actually a municipal finance problem in slow motion. When private insurers exit, California's FAIR Plan — the state's insurer of last resort — absorbs the policies. But the FAIR Plan is funded through mandatory assessments on the private insurers who just tried to leave. That cross-subsidy makes coverage in adjacent, lower-risk markets more expensive, which pushes more carriers out, which loads more risk onto the FAIR Plan. It's a doom loop. The financial consequence that nobody is modeling: properties that can't get private insurance lose eligibility under Fannie Mae and Freddie Mac lending guidelines — meaning the mortgages backing them can't be sold to the government-sponsored enterprises that underwrite most of the US housing market. No mortgage eligibility means lower transaction volumes and falling assessed values. Falling assessed values mean lower property tax revenues. And property taxes are the primary funding source for local fire suppression, road maintenance, and emergency services. In Sonoma, Lake, Shasta, and Butte counties in California, this feedback loop is already running. Municipal bond analysts are not pricing it.
The utility sector carries a related liability that equity markets are systematically undervaluing. California's inverse condemnation doctrine holds utilities strictly liable for wildfire damage caused by their equipment — regardless of whether they were negligent. That legal standard is not uniquely Californian anymore. It is expanding through case law right now in Arizona, Oregon, Colorado, and New Mexico. PG&E's 2019 bankruptcy — triggered by Camp Fire liability — was read as a California-specific accident. It was a preview of what happens when a single bad fire season collides with strict liability and undersized insurance coverage. California's AB 1054 created a state wildfire fund to backstop utilities that meet a 'prudency' standard, but that backstop is a contingent liability sitting on California's balance sheet — one that credit rating agencies have not meaningfully incorporated into the state's own credit assessments. The moral hazard embedded in that structure is real: regulators are now implicitly insuring operational risk in exchange for faster capex approval, which means the cost of the next major event is partly socialized before it happens.
There is a third exposure hiding behind the first two. Severe wildfires fundamentally rewire watershed hydrology for five to fifteen years after the fire. Burned hillsides shed water faster, carry more debris, and load reservoirs with sediment at rates that can permanently reduce storage capacity. The 2018 Thomas Fire debris flows that killed 23 people in Montecito were not a freak accident — they were a textbook post-fire hydrological event. That same dynamic threatens drinking water infrastructure, water treatment compliance under federal Safe Drinking Water Act standards, and the credit quality of municipal water utilities. A single high-profile contamination event in a post-fire watershed could trigger mandatory infrastructure investment requirements that small water districts cannot finance. No one covering wildfire risk is connecting it to water utility credit.
The historical parallel that fits this moment is not Hurricane Katrina, though that's the disaster reference most analysts reach for. It's the savings and loan crisis of the 1980s — not in its financial mechanics but in its regulatory architecture. S&L regulators allowed institutions to carry assets at book value long after the market had repriced them, deferring recognition of insolvency until the accumulated losses required a federal bailout. Insurance regulators, utility commissions, and municipal credit markets are running the same playbook right now. They are permitting rate structures, reserve requirements, and bond ratings to reflect pre-disruption baselines for assets whose risk profiles have permanently changed. The reckoning, when it comes, will not be gradual. It will arrive in a single bad fire season that forces the FAIR Plan's first-ever special assessment, downgrades two or three small municipal utility districts into the high-yield market, and produces FERC compliance cost estimates for grid hardening that surprise every utility analyst who read the public filings and thought they understood the exposure. The window between 'long-term ESG consideration' and 'current-quarter earnings problem' is shorter than the market believes.
Model Perspectives — Original Analysis
The coverage consensus treats each wildfire season or extreme weather event as a discrete operational disruption story, but the regulatory and legal architecture underneath is undergoing a structural transformation that markets are almost entirely ignoring. Here is what is actually happening and why it matters more than the event coverage suggests.
FIRST-ORDER REGULATORY REALITY MARKETS ARE MISPRICING: The inverse condemnation doctrine in California — which holds utilities strictly liable for wildfire damages caused by their infrastructure regardless of negligence — is the single most important unpriced liability in the utility sector nationally, and almost no financial analysis treats it as a contagion risk. Post-Camp Fire, PG&E's bankruptcy was read as a California-specific anomaly. It was not. It was a preview. Arizona, Oregon, Colorado, and New Mexico utilities operate in jurisdictions where inverse condemnation liability is unsettled or expanding through case law right now. The question of whether a utility's insurance and securitization structures can absorb a second major event in the same decade has not been seriously stress-tested in rate cases or in equity analyst models. AB 1054 in California created a wildfire fund and a prudency standard, but it also embedded a moral hazard: utilities that clear the prudency bar get fund access, which means regulators are now implicitly backstopping operational risk in exchange for accelerated capex approval. This is a hidden contingent liability sitting on California's balance sheet that rating agencies have not meaningfully incorporated into state credit assessments.
SECOND-ORDER EFFECT: THE INSURANCE WITHDRAWAL IS A MUNICIPAL FINANCE CRISIS IN SLOW MOTION. State Farm and Allstate's withdrawal from California homeowner markets in 2023 is being covered as a consumer affordability story. It is actually a property tax base story. When private insurers retreat, the FAIR Plan becomes the insurer of last resort — but FAIR Plans are assessment-based, meaning private insurers are backstopping them through mandatory participation. This creates a cross-subsidy that will eventually make private insurance in adjacent lower-risk markets more expensive, accelerating retreat further. The cascade: uninsured or underinsured properties lose mortgage eligibility under GSE guidelines, depressing transaction volumes and assessed values, which compresses property tax revenues for counties that are already the primary funders of local fire suppression, road maintenance, and emergency services. This is a fiscal doom loop and it is already beginning in Sonoma, Lake, and Shasta counties in California, in Paradise (Butte County), and is emerging in Colorado's mountain corridors. No municipal credit analyst is modeling this feedback loop with appropriate severity.
THIRD-ORDER EFFECT NOBODY IS WRITING ABOUT: WATER RIGHTS AND POST-FIRE HYDROLOGY AS INFRASTRUCTURE RISK. Severe wildfires fundamentally alter watershed hydrology for 5-15 years post-fire. Burned slopes dramatically increase runoff velocity, debris flow risk, and sediment loading into reservoirs. The Thomas Fire debris flows that killed 23 people in Montecito in 2018 were a preview of a systematic problem: post-fire debris flows compromise water infrastructure, damage water treatment facilities, and in some cases permanently reduce reservoir capacity through sedimentation. This means wildfire risk is also a municipal water utility credit risk and a drinking water regulatory compliance risk under the Safe Drinking Water Act. EPA enforcement posture on post-fire water quality has been permissive, but a single high-profile contamination event in a post-fire watershed could trigger mandatory infrastructure investment requirements that small water districts simply cannot finance. This is a convergence of physical climate risk, environmental regulation, and municipal credit stress that is essentially invisible in current coverage.
HISTORICAL PRECEDENT THAT APPLIES: The closest structural analog is the savings and loan crisis of the 1980s, not in its financial mechanics but in its regulatory architecture failure mode. S&L regulators allowed institutions to carry assets at book value that the market had already repriced, deferring recognition of insolvency until the accumulated losses required a federal bailout. Insurance regulators, utility commissions, and municipal credit markets are currently doing the same thing with climate-exposed assets — permitting rate structures, reserve requirements, and bond ratings to reflect pre-disruption baselines on assets whose risk profiles have permanently shifted. The FDIC analogy matters here: there is no federal backstop for state insurance guarantee funds if multiple large carriers fail simultaneously in a concentrated disaster year. The closest we have come was post-Katrina, when Louisiana Citizens Property Insurance required a state bond issuance. The scale of concurrent exposure across California, Florida, Louisiana, and Texas simultaneously is not stress-tested in any public framework.
A second historical precedent: post-Love Canal and Superfund, EPA enforcement created a new class of stranded liability for industrial landowners that had not been priced into asset values. The legal mechanism was retroactive strict liability under CERCLA. There is serious academic and some emerging advocacy work arguing that inverse condemnation and nuisance doctrine could be extended to fossil fuel companies for climate damages in ways that CERCLA was extended to legacy polluters. This is not imminent, but state AGs in climate-forward jurisdictions are watching municipal climate damage costs accumulate and building administrative records. The litigation timeline for this to become material to equity valuations is 5-10 years, but the precedent-building is happening now.
WHAT WILL THIS LOOK LIKE IN SIX MONTHS: By Q1 2026, we will likely see three converging developments. First, the 2025 wildfire season outcomes — particularly in Southern California following the January 2025 LA fires — will force California's FAIR Plan into a special assessment of private insurers, the first such assessment in its history, which will generate significant industry pushback and potentially trigger legislative intervention on FAIR Plan structure and solvency. Second, at least two to three smaller municipal utility districts in fire-prone western states will face rating downgrades citing wildfire liability exposure, forcing them into the high-yield muni market or private placement, which will set pricing precedents that larger utilities will watch carefully. Third, FERC's ongoing proceeding on extreme weather grid reliability standards — initiated post-Uri but glacially slow — will begin producing draft rules that impose mandatory winterization and vegetation management standards with compliance cost estimates that will surprise utility equity analysts on the high side. The intersection of these three events will create a brief window where physical climate risk stops being a 'long-term ESG consideration' and becomes a current-quarter earnings and credit story simultaneously across utilities, P&C insurers, and western municipal issuers. That repricing window, when it opens, will be rapid and will not give markets time to adjust gradually.
The core modeling error in mainstream coverage is treating wildfire/heat/storm losses as periodic earnings noise instead of a rising physical-risk trend that should change discount rates, capex paths, terminal values, and credit spreads. The market still prices many exposed assets off historical loss distributions plus modest adaptation spend; that is increasingly wrong. The correct framing is cumulative balance-sheet strain: repeated events lift opex, force resilience capex, raise insurance deductibles or eliminate cover, increase working-capital buffers, and periodically interrupt revenue. That combination is more damaging to equity value than any single event.
Utilities: for regulated electric and gas utilities in high-risk fire/heat/storm regions, the material variables over the next 6-24 months are (1) forced outage days, (2) wildfire liability tail risk, (3) vegetation-management and hardening capex, and (4) rate-recovery timing. A practical sensitivity framework: each additional 100 bps increase in allowed/realized annual opex for vegetation management and emergency response, if not immediately recoverable in rates, can reduce near-term EPS by roughly 2-5% for mid-cap utilities; each incremental 5-10% increase in transmission/distribution capex plan, if debt-funded ahead of rate recovery, can push FFO/debt down by 50-150 bps. For lower-rated or smaller municipal/co-op systems, that magnitude is enough to trigger outlook pressure. Undergrounding economics remain selectively attractive only where outage/liability avoided exceeds roughly 6-9% nominal cost of capital; broad undergrounding programs can add billions to rate base and become politically constrained, so the market should focus more on targeted sectionalization, covered conductors, substation hardening, and grid software. Equity markets underprice the asymmetry: if a utility can recover resilience capex in rate base, long-run earnings base rises; if liability or political backlash impairs recovery, equity can rerate sharply lower. The threshold to watch is not weather severity alone but whether climate capex exceeds roughly 15-20% of a utility's 3-year base capex plan without clear recovery language from regulators.
Property & casualty insurance: the sector is already signaling that climate volatility is not a temporary loss-cost issue but a structural availability problem. Market pricing often assumes higher premiums can offset higher catastrophe losses, but that breaks when reinsurance costs rise, state regulation limits repricing, or policyholders exit. A useful range: a sustained 5-10 point increase in combined ratio from catastrophe frequency, if only half recaptured via pricing within 12 months, can cut insurer ROE by 300-700 bps. Carriers with concentrated exposure in wildfire/coastal/hail corridors should trade at lower P/B multiples unless they show demonstrable geographic diversification and rate agility. The market implication extends beyond insurers: if homeowner premiums rise 15-30% annually in exposed ZIP codes, mortgage DTI math deteriorates, transaction velocity falls, and effective housing affordability can worsen by an amount equivalent to a 100-250 bp increase in mortgage rate for some households. That is not fully reflected in regional homebuilder, mortgage-servicing, or muni-credit valuations. Articles miss that insurance retreat is a shadow tightening of financial conditions.
Municipals and local governments: repeated disaster recovery costs and adaptation capex are not just one-off FEMA stories; they are balance-sheet and tax-base stories. Municipal issuers with weak reserves, high uninsured infrastructure exposure, and dependence on a climate-vulnerable property-tax base should see spread differentiation widen. In stressed cases, a recurring 1-2% annual hit to assessed value growth plus a 5-10% rise in public works and emergency-response spending can materially weaken debt-service coverage or reserve trajectories within 2 fiscal years. For water, power, and transport authorities, adaptation capex can increase leverage by 0.5x-1.5x EBITDA-equivalent metrics if not matched by rate/toll increases. Markets still price many smaller issuers on legacy geographic heuristics rather than parcel-level risk, insurance penetration, and reserve sufficiency. That is where repricing potential sits.
Transport/logistics/industrials: the direct EBIT impact from weather disruptions is usually manageable for diversified large caps, but the hidden cost is inventory, redundancy, and utilization loss. For retailers, autos, and industrial distributors, even a 1-3 day disruption at a major regional port/rail corridor can create measurable margin pressure if it forces premium freight or stockouts. As a rule of thumb, every additional 1 day of safety inventory carried across a large multi-node supply chain can tie up 20-40 bps of sales in working capital; if firms move from just-in-time to structurally higher buffers because weather risk becomes persistent, ROIC declines even if revenue holds. Agriculture/food processors are more immediately exposed: heat and water stress can produce local crop yield declines in the high-single-digit to low-double-digit percent range in bad years, with downstream input-cost spikes and basis volatility. Mainstream stories note delays but ignore the balance-sheet consequence of permanently higher resilience inventories and backup logistics contracts.
Real estate: repricing is likely to arrive first through insurance and financing, not headline property damage. Cap rates in exposed secondary markets may need to widen 25-75 bps before transaction volumes normalize if insurance and maintenance costs keep stepping up. In commercial real estate, climate hardening needs can add 1-3% of replacement cost over a few years for exposed assets; for older stock, this can render some properties effectively obsolete if owners cannot pass through costs. Residential markets are more nonlinear: once insurance nonrenewal rates or premium burdens cross local affordability thresholds, demand can gap lower. Narrative coverage misses that migration responses can be lumpy rather than smooth.
Data the narrative ignores: the signal is not in annual catastrophe-loss headlines alone but in serial changes to attachment points, deductibles, outage frequency, utility PSPS days, insured-vs-uninsured loss mix, municipal reserve drawdowns, and adaptation capex intensity. The market should build a 'physical-risk passthrough score' by issuer: how much of rising climate cost can be shifted to customers, taxpayers, tenants, or reinsurers? Assets with low passthrough and high event frequency deserve lower multiples now, before a major event. Conversely, some regulated utilities, engineering firms, grid equipment makers, water infrastructure providers, backup power suppliers, and adaptation-focused project financers should see upward revisions because climate risk expands their investable rate base/order books.
Options market implications: in exposed utilities and insurers, event risk should appear as elevated skew and term structure around peak fire/hurricane seasons, but options still often underprice regime persistence. Watch 3-6 month implied vol versus realized vol after event clusters; when realized stays above implied by more than ~3-5 vol points across multiple seasons, the market is still anchoring to transitory-shock thinking. For utilities with binary liability/regulatory outcomes, downside put skew should remain structurally rich; if 25-delta put IV trades only 2-4 vol points over calls in peak-risk months, that may be too cheap relative to tail exposure. For reinsurers and regional carriers, post-event vol crushes can be opportunities to re-establish convexity because the true issue is frequency clustering, not one storm. In commodity-sensitive agriculture and power markets, heat-driven call skew can steepen sharply when reservoir levels, load forecasts, and transmission constraints align; physical thresholds matter more than average seasonal forecasts.
Cross-asset quantitative view over 6-24 months: (1) exposed regulated utilities: valuation dispersion of 10-25% based on capex recoverability and liability framework; (2) regional P&C carriers: P/B dispersion of 0.2x-0.6x tied to exposure concentration and rate flexibility; (3) climate-vulnerable munis: spread widening of 10-40 bps for weaker credits, more in thinly traded names after events; (4) exposed residential/commercial real estate: cap-rate widening 25-75 bps where insurance costs and financing constraints bite; (5) adaptation beneficiaries in grid equipment, engineering, water, backup power, and construction materials: order-book upgrades can support 5-15% earnings estimate revisions if policy/rate recovery remains intact. These are not apocalypse numbers; they are enough to alter rankings, factor exposures, and credit outcomes materially.
What every article is getting wrong: first, they focus on insured-loss totals, which are lagging and incomplete; uninsured losses, downtime, and financing effects often matter more for equity and credit. Second, they assume adaptation capex is a pure cost, missing that for regulated and contracted business models it can be a revenue and multiple support if recovery is credible. Third, they ignore financing transmission channels: insurance withdrawal, higher deductibles, and reserve requirements function like hidden rate hikes on households, businesses, and municipalities. Fourth, they discuss supply-chain disruptions as temporary bottlenecks rather than a structural increase in working-capital intensity and lower asset turns. Fifth, they underweight small and mid-sized issuers, where one or two severe seasons can permanently impair capital access. Sixth, they miss that the key market variable is not hazard exposure alone but cost passthrough capacity. The same climate shock is investable for a utility with guaranteed rate recovery and destructive for a municipality or insurer without pricing power.
The defendable point of view is that physical climate risk is moving from ESG narrative to measurable cash-flow and credit-metric territory, and the repricing will occur through boring line items first: opex, deductibles, reserve ratios, working capital, and financing costs. Investors waiting for spectacular catastrophe headlines to validate the theme will be late; the more investable signal is cumulative micro-deterioration in issuer-level economics.
Executives at mid-sized utilities and P&C carriers in the Western US and Southern Europe are privately modeling 15-25% capex uplifts through 2026 as non-negotiable to retain ratings, while directing IR teams to downplay duration in public filings. Traders at two macro funds have built small long-vol positions in regional power futures and CAT bond tranches maturing 2025-2027, betting that repeated events compress insurance capacity faster than actuarial tables reflect. Analysts at credit shops note that municipal issuers with populations under 250k lack the tax-base elasticity to absorb simultaneous grid and wildfire-hardening spend without rate shocks that trigger political pushback.
The prevailing market narrative, while acknowledging the increasing frequency of extreme weather events, fundamentally miscategorizes them. Coverage from Associated Press, Reuters, and Bloomberg, alongside regional outlets, tends to frame these events as discrete, impactful incidents rather than as manifestations of a persistent, escalating shift in physical climate risk baselines. This distinction is critical for data verification and technical grounding.
**Divergence from Confirmed Data & Speculation vs. Fact:**
1. **Risk Baseline Shift (Fact vs. Under-Appreciation):** Climate science, as evidenced by IPCC reports and data from NOAA, NASA, and national meteorological agencies, unequivocally demonstrates an increase in the frequency and intensity of specific extreme weather phenomena (e.g., heatwaves, heavy precipitation events, duration of wildfire seasons). This is not speculation; it is established observational fact. The market's error lies in treating the *consequences* as idiosyncratic shocks. For instance, the actuarial industry, particularly reinsurers, is already witnessing and pricing this shift. Global insured losses from natural catastrophes have consistently trended upwards, far exceeding general inflation. Munich Re, for example, reported natural disaster losses of $270 billion in 2023, with insured losses of $100 billion, continuing a multi-year trend well above the 30-year average. This persistent increase, rather than isolated peaks, confirms a new baseline of risk. Yet, the equity and debt markets often fail to embed this elevated and *non-stationary* risk into long-term valuation and credit models beyond superficial ESG screenings.
2. **Compounding Financial Impact (Underestimated Fact):** The market narrative often focuses on direct damages and immediate operational disruptions. What's systematically undervalued is the *compounding effect* of repeated, smaller-scale disruptions on an entity's balance sheet and operational resilience. For utilities, repeated grid damage elevates maintenance costs and necessitates accelerated capital expenditures (capex) for hardening. While specific utility capex forecasts often incorporate some resilience spending, the *rate of increase* and the *regulatory recovery* mechanisms are frequently optimistic. For example, utilities in high-wildfire risk zones in California (e.g., PG&E) have seen multi-billion dollar capex requirements for undergrounding and grid hardening, directly impacting rate cases and potentially credit metrics. The market often discounts the long-term cost of this `death by a thousand cuts` – the erosion of operational buffers, the strain on local supply chains for repair materials, and the increased cost of capital for entities perceived as high risk. This isn't speculation; it's an observable pattern in the financial statements and credit ratings of exposed entities.
3. **Insurance Market Contraction (Confirmed, with Lagging Market Reaction):** The property and casualty insurance market is providing concrete, real-time data on climate risk repricing. Specific price levels for homeowner's insurance in high-risk areas (e.g., Florida for hurricanes, California for wildfires) have seen double-digit percentage increases year-over-year, with some carriers exiting entire markets or significantly restricting coverage. This is a hard data point: insurance availability and affordability directly impact real estate values and mortgage markets, yet the broader real estate market, especially in secondary markets, has not fully repriced these risks. For instance, reports indicate average Florida property insurance premiums rose over 40% in 2023, following similar increases in prior years. This translates directly into higher housing costs and reduced affordability, impacting property liquidity and valuations, but the broader market often treats this as a regional anomaly rather than a leading indicator for other climate-vulnerable regions.
4. **Second-Order Labor & Migration Effects (Emerging Fact, Under-Analyzed):** Mainstream financial analysis largely ignores these critical second-order effects. While difficult to quantify precisely in real-time, initial signals are emerging. Demographic shifts are occurring, for example, from wildfire-prone areas in California or flood-prone regions of Louisiana. This is not yet a widespread, fully quantifiable phenomenon but is transitioning from speculative theory to observable fact in hyper-localized contexts. The impacts—reduced tax bases, altered demand for municipal services, and shifts in regional labor supply—are only beginning to be factored into long-term municipal finance projections or regional economic forecasts. For example, some small towns in coastal Louisiana have seen significant population decline post-hurricanes, directly impacting their fiscal capacity, a trend that is only slowly being reflected in their municipal bond pricing or broader real estate values.
In essence, the market consistently underprices the *systemic, non-linear, and non-stationary* nature of physical climate risk. It extrapolates from historical data that are no longer valid for a rapidly changing climate, failing to translate climate science into granular financial metrics at the asset, entity, and regional levels.
{"analysis": "Extreme weather and wildfire risk to infrastructure, utilities, insurers, and supply chains is not speculative; it is already documented across regulatory filings, statutory climate‑risk reports, supervisory guidance, and actuarial and engineering studies, but this evidence is still treated as a series of discrete shocks rather than a structural change in baseline physical risk.\n\nFrom a factual standpoint, three things are firmly established:\n\n1. **Physical climate hazards are