Check the math.

Stop building plants ratepayers don't need: $350M/yr

AVOIDED SCENARIO Prevents the next increase phases in 2027-2035

Sizing bracket: $120M conservative / $350M base / $700M aggressive · confidence: med · this page carries $350M.

• LPSC Docket U-37882 (filed March 25, 2026, “pursuant to the Commission's Lightning Initiative”): seven new gas units at the Richland and Pointe Coupee sites; the public testimony states “approximately $13 billion for the Proposed Generators.” The precise cost figure is from Entergy's Q1 2026 Form 10-Q (SEC accession 0000065984-26-000222): source

  “a total cost of approximately $12.9 billion”

• Entergy Q1 2026 Form 10-Q (SEC accession 0000065984-26-000222): ELL planned generation capital 2026-2029 of $26.68B out of a $35.86B ELL total; the quarter-over-quarter $13.7B jump in the corporate plan is “primarily related to resources identified in Entergy Louisiana's application filed with the LPSC in March 2026.” source
• LPSC Docket R-35462, Customer Centered Options: 3.5 GW of industry-funded supply offered with a no-harm study; closed in 2025 (General Order dated June 18, 2025; 4-1, Commissioner Lewis dissenting) without the study being run. LPSC General Order R-34247 is the competitive-procurement order whose bidding process the Lightning Initiative fast-track bypasses.
• Proof companies pay when required: the Stack and Amazon arrangements, and U-37425's own structure. When Waterford 5's estimate rose from $1,079M to a $1,755M Class 3 estimate, the Quarterly Monitoring Report (May 2026) states:

  “The final costs of the Generation facilities will be reflected in the Customer's minimum bill payments per the terms of the ESA and Rider 1”

• What this number is: the ~$350M/yr is an avoided scenario: the annualized revenue requirement of over-build that disciplined procurement, binding cost allocation, and honest need review would keep off the rate base. It is never a cut to today's bill, and it is counted once (the flexibility and efficiency levers below are sized net of it).

Lower the guaranteed return on electric monopolies: $318.7M/yr

MODELED FROM FILED INPUTS Cuts today's bill phases in 2027-2032

Sizing bracket: $80M conservative / $190M base / $385M aggressive · confidence: high · this page carries $318.7M (the full-reform derivation shown below).

The arithmetic, shown in full. Method: conservative revenue-requirement delta, computed per utility from filed figures: savings = rate base × [(current equity share × current ROE − reform equity share × reform ROE) − (equity shifted to debt × new debt cost)]. No tax gross-up counted.

Input sources: ELL FY2025 10-K regulatory table (SEC 0000065984-26-000174, filed 2026-02-19); conservative: footnote (c) excludes ~$1.0B of rider-recovered T&D/resilience plant; U-37594 FRP TY2024 Miscellaneous Data (FileId MOcDznVJwJY=): COMMON EQUITY RATIO = 50.91% (3-yr avg 49.51/53.52/49.71); matches 10-K. Cleco rate-base schedule, §21 OCR pull (billion-dollar-savings-sources.md); U-37776 FRP Annual Monitoring TME 6/30/2025 (FileId uz0GaC6+KLM=): 'Common Equity Portion of Capitalization is Fixed at 52% with 9.7% ROE per Order in Docket No. U-36923'. SWEPCO LA rate-base schedule TY2022 (U-35441, §21 OCR pull); stale-conservative, has likely grown since; ESTIMATE: U-37502-A sets methodology (year-end capital balances), not a ratio; last FILED actual was 52.747% (TY2022, U-35441), which is higher, so 0.505 understates the savings. Reform debt cost: stated assumption: 5.5% new-issue utility debt cost for the incremental debt share (Cleco filed embedded 5.57% U-37776; Moody's Baa ~6.05% May 2026; Delta new-issue 6.39%; sensitivity ~-\$3.5M per +10bps shown on sources page).

• LPSC Docket U-36959, Entergy Louisiana Formula Rate Plan: authorized ROE midpoint 9.70% (bandwidth 9.30-10.10%). ELL's June 1, 2026 motion asks to extend the FRP with “the currently effective 9.7% EPCOE” unchanged.
• LPSC Docket U-37594, ELL FRP Test Year 2024 Miscellaneous Data (filed May 30, 2025): the ratemaking common-equity ratio.

  “COMMON EQUITY RATIO = 50.91% … Test Year 2022 49.51% / Test Year 2023 53.52% / Test Year 2024 49.71% / Three Year Average = 50.91%”

• Entergy FY2025 Form 10-K (SEC accession 0000065984-26-000174, filed 2026-02-19), state-regulatory table: rate base and equity ratio. The $16.7B rate base is conservative: footnote (c) excludes roughly $1.0B of rider-recovered transmission, distribution, and resilience plant. source

  “Entergy Louisiana $16.7 (c) 9.3% - 10.1% 6.95% 50.91%”

• LPSC Docket U-37776, Cleco FRP Annual Monitoring Report (TME 6/30/2025): capital structure fixed by order.

  “Debt Portion of Capitalization is Fixed at 48% per Order in Docket No. U-36923 … Common Equity Portion of Capitalization is Fixed at 52% with 9.7% ROE”

• LPSC Order U-37502-A (decided March 18, 2026), SWEPCO FRP extension.

  “The approved return on equity (ROE) for the 2025 test year and through the three-year period of the extension shall be 9.70%”

• Comparators: Ofgem (UK) RIIO-3 final determinations, December 2025: 5.70% allowed equity return. BNetzA (Germany), 2024: 5.07% allowed return on new network assets. US true-cost-of-equity estimates: RMI ~7.9%; American Economic Liberties Project ~6.1-6.2%. The reform target of ~7.5% sits within that range of independent estimates.
• Sensitivity: with every assumption set against the claim, the number holds. At RMI's higher 7.9% cost-of-equity target instead of 7.5%: ~$288M. At a 6.39% new-debt cost (the highest recent Louisiana utility new-issue rate, vs Cleco's own filed embedded 5.57% and Moody's Baa ~6.05%): ~$287M. Both at once: ~$256M. Hold Cleco at its 48% minimum-equity covenant instead of 35%: about $9M less. Every adversarial combination stays far above the ~$190M a first-cycle ROE order alone would deliver, and none of these counts the ~$169M tax gross-up on equity returns that ratepayers also fund, which this page deliberately excludes. SWEPCO's equity ratio is an estimate (its order sets a methodology, not a ratio; the last filed actual, 52.747% in 2022, is higher, meaning the estimate understates the savings).

Lower the gas companies' guaranteed return: $25.7M/yr

MODELED FROM FILED INPUTS Cuts today's bill phases in 2027-2031

Sizing bracket: $5M conservative / $15M base / $45M aggressive · confidence: med · this page carries $25.7M (the full-reform derivation shown below).

The arithmetic, shown in full. Method: conservative revenue-requirement delta, computed per utility from filed figures: savings = rate base × [(current equity share × current ROE − reform equity share × reform ROE) − (equity shifted to debt × new debt cost)]. No tax gross-up counted.

Input sources: Atmos LA rate base $1.353B (U-37554); Atmos RSC common-equity cap 58%. Delta North $260.5M + South $239.1M ≈ $499.6M (U-37741/U-37742 RSP earnings reports + 6/5/2026 Staff Reports); hypothetical 48/52 debt/equity structure (U-37741/42). Reform debt cost: Delta actual new debt cost 6.39% (U-37741/42 RSP, conservative-high).

• Atmos Energy Louisiana, Rate Stabilization Clause: midpoint ROE 9.80% (band 9.60-10.00%), common-equity-ratio cap 58%; rate base $1.353B (LPSC Docket U-37554). Atmos's 2024 earned ROE was 7.30% (below the band), so rates were trued UP toward the guaranteed 9.80%.
• Delta Utilities (North/South, formerly CenterPoint and Entergy gas LDCs): LPSC Dockets U-37741 / U-37742, Rate Stabilization Plan earnings reports + June 5, 2026 Staff Reports: authorized ROE 9.95% ±50 bps on a hypothetical 48/52 debt/equity structure; rate base $260.5M (North) + $239.1M (South). Both companies are currently UNDER-earning (Staff-adjusted 6.66% and 5.51%) and rates are being trued up toward the 9.95% target, which is why this page frames the reform as lowering the guaranteed true-up target, not clawing back profits.

Share over-earnings with customers: $12M/yr

FILED Cuts today's bill phases in 2027-2029

Sizing bracket: $5M conservative / $12M base / $25M aggressive · confidence: low · this page carries $12M.

• ELL Rider FRP Schedule, Section 2.C.2 (Docket U-36959): the ±0.40% dead-band means earnings up to 10.10% are retained in full before any sharing.
• LPSC Docket U-37776, Cleco FRP Annual Monitoring Report (twelve months ending 6/30/2025): Cleco's achieved ROE was 10.26% against its 9.70% target, and the refund calculation produced $0 because earnings sat below the 10.30% sharing threshold (jurisdictional earnings $182.268M vs. the no-sharing cap of $182.964M). Facts verified directly from the report's refund calculation; no refund was owed.
• Precedent: Hawaii PUC Docket 2018-0088, performance-based regulation with a true earnings-sharing mechanism and customer dividend.

Audit storm-hardening plans before they hit your bill: $337.4M/yr

AVOIDED SCENARIO, MODELED FROM FILED INPUTS Prevents the next increase phases in 2027-2035

Sizing bracket: $25M conservative / $120M base / $380M aggressive · confidence: low · this page carries $337.4M (the full-reform derivation shown below).

The arithmetic, shown in full. Method, per utility at full program build: program dollars × the routine-capital share the Commission’s own consultant found (91.7%: only $732M of the $8.85B reviewed list passed the but-for-resilience screen) × an avoided fraction of 50% × after-tax return (~7%). The 50% is the judgment input, bracketed by the evidence: the floor is ~22% (Cleco’s own uncontested settlement trimmed its filed ask that much under light scrutiny), the ceiling is ~77% (the consultant’s alternative benefit-cost screen passed only ~$2.0B of $8.85B), and the Dolet Hills precedent ($125M disallowed, U-35753) shows deferred-maintenance capital can be put on shareholders outright. Return-avoidance only: the routine work largely still happens through normal reviewed rate cases; what reform avoids is the accelerated-rider return on it. Outright capex denial would be roughly twice as large per dollar and is deliberately not claimed. The CSRS share is template-transferred to Cleco and SWEPCO, which have no equivalent screen yet (SWEPCO’s RFP-26-01 consultant review is the in-flight equivalent).

• LPSC Docket U-36625, Entergy's Future Ready Resilience Plan: $9.6B over 10 years as proposed; the Commission approved a $1.9B first tranche in April 2024 on a 3-2 vote. Recovery runs through a single-issue Resilience Program Rider (capital recovery earning the authorized return, outside a full rate case).
• CSRS, the Commission's own independent engineering consultant (report filed August 2023 in U-36625), reviewed the full 9,611-project, ~$8.85B proposal and found roughly $732M of projects that would not already belong in a normal capital plan:

  “the total proposed resilience investment eligible for accelerated recovery would be approximately $732,363,092”

• The same report on the rest of the program:

  “many of the other project types proposed in the Future Ready Plan blend upgrades designed to increase grid resilience with routine capital replacement and upgrades that are needed due to deferred capital replacement”

• The consultant also outlined a broader screen (projects with a benefit-cost ratio of 4.0 or better, roughly $2.0B). The page quotes the strict but-for screen; either screen leaves the large majority of the $8.85B proposal in the category of work that belongs in normal, fully-reviewed capital planning rather than an accelerated rider.
• Commission Staff's consultant proposed a baseline safeguard so O&M already funded in base rates (such as vegetation management) could not shift into the rider; the approved order did not visibly adopt it. The approved framework also authorizes a regulatory asset recovering the remaining book value of replaced assets. These are the double-recovery doors this lever closes.
• The scrutiny is a three-utility posture, and as of this revision the dollars are too. Cleco (Docket U-37479): a 10-year, ~$510M / 1,400-project grid resiliency plan; Phase 1 filed December 2024 at $257.6M (781 projects), settled and approved November 2025 at approximately $200M, with a Grid Resiliency Rate Rider effective January 1, 2026 (semi-annual true-up and prudency review). Verbatim, from Cleco's FY2025 Form 10-K (SEC accession 0001089819-26-000002): source

  “On November 3, 2025, Cleco Power filed an uncontested stipulated settlement with the LPSC, reducing the proposed investment to approximately $200.0 million.”

• SWEPCO (Docket U-37794, System Improvement Plan, filed November 24, 2025, pending): approximately $401.8M over roughly four years, with a rider proposal that places O&M in a regulatory asset recovered alongside capital costs (the same double-recovery door the consultant's baseline-safeguard flagged at Entergy). The Commission's RFP-26-01 retains an outside consultant to review it. Verbatim, from RFP-26-01: source

  “SWEPCO's SIP seeks approval of approximately $401.8 million of achievable, resiliency projects, which would fully trim approximately 6,095 line-miles of right-of-way and harden over 629 line-miles over roughly four years.”

• Two notes on scope: the 91.7% routine share is the consultant's finding for Entergy's program and is template-transferred to Cleco and SWEPCO, which have no equivalent screen yet (the SWEPCO RFP-26-01 consultant review is the in-flight equivalent and the firm-up trigger). The 50% avoided fraction is the explicit judgment input, bracketed 22%-77% by the evidence in the arithmetic note above. Cleco and SWEPCO programs combined (~$0.9B announced) are roughly a tenth of Entergy's $9.6B, so the dollars remain overwhelmingly an Entergy story, proportional to program size.

Don't bill customers for half-built plants: $40M/yr

MODELED FROM FILED INPUTS Cuts today's bill phases in 2027-2029

Sizing bracket: $10M conservative / $40M base / $90M aggressive · confidence: low · this page carries $40M.

• Entergy FY2025 10-K: ELL construction work in progress $2,032M at YE2025 vs $762M at YE2024. The savings basis uses only the pre-surge general-system level (~$761M), a floor.
• LPSC Docket U-37425, Laidley (Meta) Quarterly Monitoring Report, filed May 15, 2026 (public redacted): total Meta-project spend from inception through March 31, 2026 was $966.5M (Franklin Farms 1&2 $837.1M + Waterford 5 $113.7M + transmission $15.7M). So the Meta share of YE2025 CWIP was under ~$966M and the general-system share at least ~$1.07B; the $761M basis understates it. source

Enforce the maintenance you already pay for: $30M/yr

MODELED FROM FILED INPUTS Cuts today's bill phases in 2027-2029

Sizing bracket: $8M conservative / $30M base / $70M aggressive · confidence: med · this page carries $30M.

• Entergy FY2025 10-K: ELL Other O&M $1,136.6M. LPSC Docket R-36226 (grid-status reporting). Magnitude modeled: enforceable maintenance standards audited against base-rate funding already collected.

Refinance uneconomic plants at bond rates: $20M/yr

EXTERNAL PRECEDENT Cuts today's bill phases in 2027-2029

Sizing bracket: $5M conservative / $20M base / $45M aggressive · confidence: med · this page carries $20M.

• Out-of-state precedent: securitized refinancing of uneconomic plant balances in Michigan (~$124M consumer benefit) and New Mexico (~$80M). Louisiana's own storm securitizations financed roughly 50% below traditional utility capital costs (see the receipts section). EXTERNAL PRECEDENT label: Louisiana has not yet applied securitization to non-storm legacy assets.

End the single-issue rider games: $50M/yr

MODELED FROM FILED INPUTS Cuts today's bill phases in 2027-2029

Sizing bracket: $15M conservative / $50M base / $120M aggressive · confidence: med · this page carries $50M.

• LPSC Docket U-36959: the FRP and its transmission/distribution recovery caps ($350/375/400M). Magnitude modeled: single-issue riders recover costs outside a full rate case where nothing nets against anything; the discipline is denying stand-alone treatment and forcing offsets in comprehensive review.

Return the excess tax money: $40M/yr

MODELED FROM FILED INPUTS Cuts today's bill phases in 2027-2029

Sizing bracket: $10M conservative / $40M base / $90M aggressive · confidence: low · this page carries $40M.

• Entergy FY2025 10-K: ELL net accumulated deferred income taxes ~$3,093M; net income-tax regulatory liability ~$313M. Magnitude modeled: depreciation-life review plus faster flow-back of excess deferred taxes within IRS normalization rules.

Audit what the parent company charges itself: $30M/yr

MODELED FROM FILED INPUTS Cuts today's bill phases in 2027-2029

Sizing bracket: $15M conservative / $30M base / $60M aggressive · confidence: low · this page carries $30M.

• First, what is actually allowed, because it matters here: a utility's service-company affiliate (Entergy Services) is required to bill the utility 'at cost,' with no profit markup, under a FERC-approved cost-allocation agreement. So this lever is not about banning an illegal markup; that is already banned. It is about whether 'at cost' is ever audited. The abuse that survives the no-markup rule is unaudited cost allocation (overhead, executive time, IT, and legal assigned to the regulated side) and above-market affiliate purchases.
• The LPSC was investigating exactly that. Docket X-35071 examined Entergy Services costs billed to Entergy Louisiana and settled into the U-36959 global regulatory liability of $184.0M. That figure is blended (affiliate billing plus an IRS audit plus six FRP test years), so the affiliate-only share is not broken out: it is a credibility anchor that the Commission itself thought this was worth pursuing, not the size of the claim. For scale, ELL's total intercompany operating expense was $639.6M in 2025 (FY2025 10-K, Note 18), an upper bound that also bundles affiliate power purchases. source

  “regulatory liability in the amount of $184.0 million”

• Why this number is $30M and not larger: much of the electric-affiliate allocation flows through a FERC-approved system agreement that the U.S. Supreme Court held the LPSC cannot second-guess as imprudent (Entergy Louisiana, Inc. v. LPSC, 539 U.S. 39 (2003)). The cleanly reachable money is the water side, where CSWR / Magnolia loads general-and-administrative cost at roughly 48.7% of revenue against an industry norm closer to 25%, squarely within LPSC authority, plus tighter audit of the non-preempted electric allocations. This lever was trimmed from $50M to $30M to reflect that preemption cap. source

Stop billing ratepayers for bonuses and politics: $22M/yr

MODELED FROM FILED INPUTS Cuts today's bill phases in 2027-2029

Sizing bracket: $5M conservative / $22M base / $45M aggressive · confidence: med · this page carries $22M.

• LPSC Docket U-36959, Section 8: ELL is already prohibited from recovering financial-metric incentive compensation in rates. The savings here is enforcement plus extending the same prohibition to Cleco, SWEPCO, and the gas companies, whose orders lack the parallel ban. Magnitude modeled from disclosed compensation structures (~87% of incentive comp is tied to financial metrics).

Kill the charge for energy nobody used: $13M/yr

FILED Cuts today's bill phases in 2027-2029

Sizing bracket: $13M conservative / $13M base / $15M aggressive · confidence: high · this page carries $13M.

• LPSC Docket R-31106 (energy efficiency): the Lost Contribution to Fixed Costs. ELL's filed Program Year 10 / 2024 LCFC: $4,931,127.85; ELL + Cleco filed ~$11.96M; the ~$12.8M/yr figure is the computed all-utility aggregate from the 2024 program-year filings.

Hire staff instead of renting consultants by the hour: $5M/yr

MODELED FROM FILED INPUTS Cuts today's bill phases in 2027-2029

Sizing bracket: $2M conservative / $5M base / $12M aggressive · confidence: med · this page carries $5M.

• LPSC RFP-25-04 response (June 2025), outside special counsel rate schedule: discounted attorney rates $225-$395/hour against standard rates up to $800/hour. source

  “Stone Pigman will charge discounted attorney rates in the range of $225 to $395 per hour”

• LPSC RFP-26-03 response (May 2026), outside technical consultant: $183,000 not-to-exceed for one audit engagement; hourly rates $70-$309. January 14, 2026 B&E minutes: additional retentions at $80-$295/hour. These fees are assessed to the utilities and recovered in rates. source
• Louisiana Senate Fiscal Services, FY26 PSC budget presentation: the agency's entire professional-services budget line is $5,000; a single docket's outside-counsel budget can exceed the agency's own professional-services line roughly 40-fold, because consultant costs are routed to utilities and recovered from ratepayers instead. source

Diversify before the LNG export squeeze: $45M/yr

AVOIDED SCENARIO Prevents the next increase phases in 2027-2035

Sizing bracket: $12M conservative / $45M base / $240M aggressive · confidence: low · this page carries $45M.

• U.S. Department of Energy, 2024 LNG Export Study, summary report (Dec 2024), p. S-27 + Table 10: the federal government's own modeling of how additional LNG exports raise the domestic price of the natural gas Louisiana's power plants burn. In the full-buildout 2050 case the study source

  “leads to a $1.09/MMBtu (31%) increase in Henry Hub prices in 2050, from $3.53/MMBtu to”

• Resources for the Future, “Unpacking the DOE Report” (Mar 2025): independent critique finding the price response per Bcf/d of exports is more than twice DOE's marginal coefficient. This page's $45M base uses a $1.00/MMBtu exposure (between DOE's marginal figure and RFF's), applied to a 15% shift of the IOUs' roughly 300 million MMBtu/yr gas burn to zero-fuel resources (industry self-supply, solar paired with storage serving existing load). Conservative floor $12M uses DOE's own marginal coefficient ($0.03/MMBtu per Bcf/d, ~13 Bcf/d of export capacity built or firmly under construction per EIA's Oct 2025 outlook) rounded down.
• SUBSTITUTION CHANNEL ONLY (double-count guard): the avoided-generation cluster above prices capital only; efficiency and demand-flexibility fuel value stays with those levers; the hedging lever covers volatility on the remaining burn. Fuel is a 100% pass-through to bills, so every megawatt served without burning gas carries zero exposure to the export squeeze. Full arithmetic and the three archived source texts: the campaign's LNG bill-impact scenario file (available on request).

Audit the gas purchasing: $25M/yr

MODELED FROM FILED INPUTS Cuts today's bill phases in 2027-2029

Sizing bracket: $5M conservative / $25M base / $60M aggressive · confidence: low · this page carries $25M.

• Atmos Louisiana tariff: the Purchased Gas Adjustment is a pure pass-through (demand + commodity + adjustments). LPSC RFP-26-03 (May 2026): the Commission's outside consultant audits the fuel clauses of all three electric IOUs for 2023-2025 on a $183,000 not-to-exceed budget; this lever scales up that audit function. source

Give the utility skin in the game on fuel: $18M/yr

MODELED FROM FILED INPUTS Cuts today's bill phases in 2027-2029

Sizing bracket: $7M conservative / $18M base / $41M aggressive · confidence: med · this page carries $18M.

• Entergy FY2025 10-K: ELL fuel ($1.3B) plus purchased power ($0.9B): roughly $2.2B/yr flowing through the Fuel Adjustment Clause at 100% pass-through with no shareholder exposure. Magnitude modeled: a modest sharing band on controllable procurement costs (the value of incentive alignment, NOT a percentage of the whole fuel bill).

Manage the gas-price risk: $5M/yr

AVOIDED SCENARIO Prevents the next increase phases in 2027-2035

Sizing bracket: $0M conservative / $5M base / $15M aggressive · confidence: low · this page carries $5M.

• LPSC General Order R-32975 / Order X-34341: Louisiana already operates a long-term gas hedging program, which is why this lever is small: hedging manages volatility, it does not reliably lower expected cost, and this page does not claim otherwise.

Open the grid: transmission competition + congestion relief: $120M/yr

AVOIDED SCENARIO Prevents the next increase phases in 2027-2035

Sizing bracket: $30M conservative / $120M base / $300M aggressive · confidence: med · this page carries $120M.

• FERC Order 1000 (competitive transmission); MISO day-ahead congestion costs run on the order of $1.3B/yr market-wide, and Louisiana's share of relief is counted conservatively. Cost estimates move when someone runs the detailed engineering: the as-filed $439.9M Sarepta-to-Mount-Olive estimate fell to $363.5M once a firm Class 3 estimate was completed (U-37425 Quarterly Monitoring Report, May 2026).

Use the grid we already have: $60M/yr

AVOIDED SCENARIO Prevents the next increase phases in 2027-2035

Sizing bracket: $20M conservative / $60M base / $150M aggressive · confidence: low · this page carries $60M.

• Duke University headroom study (Norris and colleagues): roughly 15 GW of new load could be served within MISO's existing system at ~0.5% annual curtailment. Brattle, “The Untapped Grid”: grid-utilization measures nationally. Sized net of the avoided-generation cluster to prevent double-counting.

Scale efficiency to what pays for itself: $40M/yr

AVOIDED SCENARIO Prevents the next increase phases in 2027-2035

Sizing bracket: $10M conservative / $40M base / $100M aggressive · confidence: low · this page carries $40M.

• ACEEE, Louisiana 2030 Energy Efficiency Roadmap: cost-effective programs can meet roughly 5% of statewide electricity needs cumulatively; residential potential of 8,253 GWh by 2030. Louisiana has the country's highest per-capita electricity use. AVOIDED SCENARIO: every verified kilowatt-hour saved is generation nobody finances at a guaranteed return. source

One accountable administrator, measured results: $9M/yr

MODELED FROM FILED INPUTS Cuts today's bill phases in 2027-2029

Sizing bracket: $5M conservative / $9M base / $18M aggressive · confidence: med · this page carries $9M.

• LPSC Docket R-31106 family. The ~$9M/yr statewide-administrator consolidation estimate comes from the candidate's own professional work administering Louisiana efficiency programs (labeled as professional-experience basis, not a filed figure), paired with the move from deemed (estimated) savings to measured, pay-for-performance results.

Stop funding projects that fail the cost test: $7.5M/yr

FILED Cuts today's bill phases in 2027-2029

Sizing bracket: $5M conservative / $7.5M base / $10M aggressive · confidence: med · this page carries $7.5M.

• LPSC Docket R-31106 (Public Entities / commercial programs): roughly $80M awarded since 2017, with individual projects approved at paybacks of 128 and 249 years (public reporting, Louisiana Illuminator/WWNO; the program's selection process was questioned on the record by Commissioner Lewis).

Investors who buy failing water systems underwrite the fix: $15M/yr

FILED Cuts today's bill phases in 2027-2029

Sizing bracket: $5M conservative / $15M base / $35M aggressive · confidence: low · this page carries $15M.

• LPSC Dockets U-37584 (Magnolia Water FRP extension, approved June 17, 2026) and U-37570 (2025 annual adjustment + $8M regulatory asset, approved 3-2). Magnolia net plant $274.9M (2024); Commission Staff has already disallowed $2,440,690 over three FRP years. The Commission granted the 3-year extension with a condition: Magnolia must file a full rate review in conjunction with its 2027 test year, the books-open proceeding this lever's savings run through. (Had the extension been denied, the rider would have required a full rate case immediately.)
• The bill progression is sworn testimony in the official record: U-37584 evidentiary hearing, February 9, 2026 (transcript pp. 171-173), a Belair subdivision (Slidell) household, bill about $26 at move-in in 2020: source

  “Right now, my bill is somewhere around 136.”

• The over-$140 figure is tariff arithmetic under the currently approved rates (U-37570 Staff Report rate design, approved 3-2 on August 20, 2025: water base charges +10.35%, sewer flat rates +5%): a Tier II metered household using 8,000 gallons a month pays $43.88 base + 6 × $4.00 usage + $72.54 sewer = $140.42; the non-metered Tier II flat minimum is $138.12 before a single gallon. The rate table cross-checks to the penny against a documented zero-usage bill of $116.42 ($43.88 + $72.54). source
• The Tier 2 vs Tier 1 comparison is the same Staff Report's approved rate tables (Attachment A, Staff Recommended Rates). Tier II customers are 85% of Magnolia's customer base per the report. Approved residential rates: water Tier I $21.93 first 2,000 gallons + $2.50 per additional 1,000 vs Tier II $43.88 + $4.00; sewer flat Tier I $36.27 vs Tier II $72.54. At 8,000 gallons a month the Tier II household pays $140.42 vs $73.20 on Tier I rates, a $67.22 difference ($30.95 water + $36.27 sewer); the before-a-gallon minimums are $116.42 vs $58.20. The tier assignment rests on the per-system facilities and investment Magnolia claims, which is exactly what the full rate review ordered for the 2027 test year re-examines. source
• Precedent: Public Utility Commission of Texas, February 2025: unanimously denied Aqua Texas's $8.8M increase for failure of proof and ordered refunds for ~170,000 customers.