Midstream Pipeline Acquisition Data Room: ROW + FERC (2026)

Last updated: May 2026

Quick answer: A midstream pipeline acquisition data room runs 200-400 GB at Phase II for $1-3B G&P bolt-ons (400-plus GB at the Sunoco-Parkland 14,000-mile scale), gates documents through the 4-Tier Midstream M&A Access Model (operator equity, non-operator equity, FERC-regulatory counsel, project-finance lender), and surfaces the regulatory archive through the FERC Tier A-E document escalation framework (certificates, tariffs, Form 6 financials, operational filings, decommissioning). The proprietary diagnostic frames are the ROW Assignment Integrity Test (4-axis: recording / assignability / regulator dependency / decommissioning-bond gating), the Throughput-Decay Diagnostic (5-factor: MVC roll-off / counterparty credit / TOP shortfall / recontracting / acreage dedication), and Decommissioning-Bond Gating under 49 CFR Section 192.727 plus state PUC. HSR threshold is $133.9M effective February 17, 2026; FERC Order 871 (a natural gas pipeline construction-authorization rule under NGA Section 7) was rescinded October 7, 2025 (193 FERC ¶ 61,014, docket RM25-15-000) — it does not affect tariff diligence.

I run Peony, a data room platform. The diagnostic frames in this post are calibrated against a year of fielding diligence questions from midstream MLP corp-dev running G&P bolt-ons across the Permian and Williston, infrastructure-fund principals auctioning processing platforms, FERC counsel running regulatory-tier diligence on interstate gas transmission, term-loan-A lenders underwriting $3B-plus acquisitions, throughput counterparties stress-testing recontracting exposure at producer-acreage tie-back, and PHMSA-experienced compliance leads reviewing seller integrity-management plans against the Mega Rule Phase 2 plus the January 2025 corrections. The question that recurs across every seat: what's the full doc inventory, and how does mass actually scale from a 100-mile bolt-on to a 14,000-mile interstate platform?

The platform comparison anchor names the ten platforms and frames the FID cliff; the 42-document checklist catalogs what goes in each folder; the farm-out workflow playbook sequences the 7-step workflow plus 4-tier farm-out access model; the LNG project finance deep dive maps the FEED-to-FID escalation curve; the upstream divestiture deep dive anchors the 12-month timeline plus 4-tier reserves disclosure progressive-tiering matrix. This post is the midstream pipeline acquisition deep dive anchored on the ROW Assignment Integrity Test plus FERC Tier A-E document escalation framework plus 4-Tier Midstream M&A Access Model.

TL;DR — a midstream pipeline acquisition data room runs 8,000-50,000+ ROW easement instruments + the full FERC Tier A-E regulatory stack + throughput contracts + PHMSA integrity records, scaling 5 GB to 400+ GB by mileage:

• ROW Assignment Integrity Test (4-axis): recording completeness (% recorded in correct county jurisdiction with valid grantor / grantee chain), assignability (% requiring third-party consent), regulator dependency (% requiring FERC certificate amendment / BIA tribal renewal / state PUC), and decommissioning-bond gating (49 CFR Section 192.727 plus state PUC). Below 85 percent on axis one or two typically gates the financing close.
• FERC Tier A-E document escalation framework: Tier A certificates under NGA Section 7(c) (CPCN plus amendments plus NEPA EA/EIS plus abandonment authorizations); Tier B tariffs under 18 CFR Part 154 for natural gas pipelines (currently effective tariff plus Section 4 rate cases) plus FERC Oil Pipeline Index filings under the 5-year index review (RM26-6-000) for ICA-regulated oil pipelines; the now-rescinded Order 871 was a separate gas-pipeline construction-authorization rule rescinded October 7, 2025 (193 FERC ¶ 61,014, docket RM25-15-000) and does not affect tariff diligence; Tier C Form 6 plus Form 6-Q financials (5 years annual plus 8 quarters); Tier D operational filings (open-season, IOC reports, Section 284 transportation, discount and negotiated-rate authority); Tier E decommissioning (49 CFR Section 192.727 / Section 195.402, 60-day operator-change notification, state PUC abandonment).
• 4-Tier Midstream M&A Access Model: Tier 1 operator equity / strategic acquirer (full data room); Tier 2 non-operator equity / co-investor (counterparty-name-redacted contracts plus ROW summary scorecard); Tier 3 FERC-regulatory counsel (full Tier A-E plus state PUC plus BIA plus eminent-domain dockets); Tier 4 project-finance lender plus term-loan-A lender (financial model plus throughput-contract counterparty-credit summary plus IMP plus integrity records plus ROW assignability summary plus decommissioning bond/accrual reserves).
• Throughput-Decay Diagnostic (5-factor): MVC roll-off schedule (year-by-year, counterparty-by-counterparty); counterparty credit concentration (top-1, top-5, top-10 percent of revenue plus rating distribution); take-or-pay (TOP) shortfall payment history (last 5 years); recontracting risk (24-month-pre-expiration basis differential vs contract rate); producer-acreage tie-back (long-term acreage dedication exposure).
• Seller's Midstream Data Room Platform Diagnostic Test (8-question): extends Post 5's 5-question diagnostic with three midstream-specific questions covering segregated regulatory tier permissioning, per-counterparty contract folder permissioning, and 30,000-plus-document ZIP-stream uploads.
• Decommissioning-Bond Gating (4 evidence categories): historical 49 CFR Section 192.727 / Section 195.402 abandonment authorizations plus state PUC filings plus FERC abandonment certificates; GAAP-basis accrual ledger plus actuarial calculations; bond and letter-of-credit posting; segment-by-segment retirement-cost estimate plus third-party engineering review.
• Real-deal anchors (≤12-month recency, May 2026): Sunoco-Parkland $9.1B (closed October 31, 2025, 14,000 miles plus 160 fuel terminals); Brookfield-Colonial Enterprises ~$9B EV (closed August 2025, 5,500-mile refined-products); Plains All American-EPIC Crude Holdings $2.9B aggregate plus $193M earnout (closed October 31 plus November 1, 2025, 800-mile Permian-to-Corpus Christi crude); Kinder Morgan-Outrigger Energy II $640M (closed February 18, 2025, Williston Basin 270 MMcf/d processing); DT Midstream-ONEOK 3 Pipelines $1.2B (closed December 31, 2024, three FERC-regulated interstate gas pipelines); ONEOK-EnLink final close $4.3B (closed January 31, 2025); Energy Transfer-WTG Midstream $3.25B (closed July 15, 2024, ~6,000 miles Midland Basin G&P plus 1.3 Bcf/d processing).
• 2026 regulatory updates: HSR threshold $133.9M effective February 17, 2026 (FTC announced January 14, 2026, up from $126.4M in 2025); FERC Order 871 rescinded October 7, 2025 (193 FERC ¶ 61,014, docket RM25-15-000); PHMSA Mega Rule Phase 2 corrections published January 15, 2025 following August 16, 2024 D.C. Circuit partial vacatur; EPA OOOOb/OOOOc state-plan deadline extended ~10.5 months (March 9, 2026 → January 22, 2027) per EPA November 26, 2025 final rule (effective December 3, 2025); GHGRP Subpart W RY 2025 first reports due March 31, 2026.
• Peony Data Room at $52/admin/month ships NDA gates, dynamic watermarks, screenshot protection, visitor groups, page-level analytics, and unlimited storage with no per-file cap — the structurally cheaper alternative to Datasite per-page billing ($0.40-$1.00 per page on 200-300 GB Phase II archives per Capterra/G2/Vendr/Papermark, 2026) and to Intralinks at custom-quoted enterprise pricing.

The FID cliff — defined in the cluster anchor post as the document-mass plus counterparty-count surge between FEED and Final Investment Decision — has a midstream M&A analogue: the Round 1-to-Round 2 transition where 8 to 15 indicative bidders narrow to 3 to 6 short-list and the file mass jumps from 20 to 50 GB (statistical ROW summary plus aggregate FERC tariff plus throughput-contract counterparty list) to 200 to 300+ GB (full ROW archive across 30,000+ easements plus full FERC Tier A-E with 5-year Form 6 plus 8-quarter Form 6-Q plus full throughput-contract base plus PHMSA integrity records plus EPA OOOOb/OOOOc plus GHGRP Subpart W plus state PUC). Below the Round 1 file mass, most VDRs handle the workflow. Past the Round 2 jump, generic VDRs collapse on file-size caps, flat permission models, or per-page billing that turns a 30,000-easement ROW archive into a six-figure invoice.

This guide breaks down what makes a midstream pipeline acquisition data room structurally distinct from generic M&A and from the upstream divestiture playbook, the ROW Assignment Integrity Test as the proprietary diagnostic frame for the easement archive, the FERC Tier A-E document escalation framework for the regulatory archive, the 4-Tier Midstream M&A Access Model for permission tiering, the Throughput-Decay Diagnostic for revenue diligence, Decommissioning-Bond Gating under 49 CFR Section 192.727 plus state PUC, the 2024-2026 deal anchors that calibrate scale, and how Peony Data Room at $52/admin/month handles the 200 to 400 GB Phase II archive at flat per-admin cost.

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What is a midstream pipeline acquisition data room?

A midstream pipeline acquisition data room is the structured document repository that supports the sale of working interest in midstream assets — interstate transmission pipelines, gathering-and-processing systems, NGL pipelines, refined-products pipelines, crude pipelines, storage, and fractionation — from one operator (MLP, integrated, infrastructure fund, or PE sponsor) to a counterparty including a strategic midstream MLP, infrastructure fund, NOC subsidiary, or term-loan-A-backed financial buyer. The defining feature that separates a midstream pipeline acquisition data room from a generic M&A data room and even from the 4-tier reserves disclosure progressive-tiering matrix in upstream divestitures is the ROW Assignment Integrity Test — a midstream-specific diagnostic that scores the easement and right-of-way archive across four axes (recording / assignability / regulator dependency / decommissioning-bond gating) — operating jointly with the FERC Tier A-E document escalation framework and the 4-Tier Midstream M&A Access Model.

Five document categories make midstream pipeline acquisition data rooms structurally distinct from generic M&A rooms and from upstream divestiture rooms.

1. ROW easement archive — 8,000 to 15,000 individual easement instruments per 1,000 miles of interstate pipeline, 30,000 to 50,000-plus on 6,000-mile gathering systems. Surfaces across five state-stack layers: state-by-state county recording (Texas county-clerk recording in the Real Property Records, New Mexico county-clerk plus State Land Office plus BLM, Pennsylvania prothonotary plus PADEP, North Dakota register of deeds plus BIA, California county recorder plus CPUC); tribal-land consultation under National Historic Preservation Act Section 106 (BIA right-of-way grants under 25 CFR Section 169, ACHP consultation, treaty-tribe consultation); regulator-dependency dependencies (FERC Section 7(c) certificate amendments, federal land BLM ROW renewal under 43 CFR Part 2880, USFS special-use permits, USACE Clean Water Act Section 404 permits, DOI mineral-rights leases); eminent-domain history (state-by-state takings dockets, compensation awards, Texas common-carrier challenge case law including Denbury Green Pipeline and Texas Rice Land Partners); and assignability plus consent-required clauses (form-of-easement assignability boilerplate, mortgagee subordination, title curative work product, ALTA pipeline endorsements).

2. FERC Tier A-E document escalation framework — Tier A certificates under NGA Section 7(c) (CPCN plus subsequent amendments plus NEPA EA/EIS plus Section 7(c) abandonment authorization for retired segments); Tier B tariffs under 18 CFR Part 154 for natural gas pipelines (currently effective tariff in the FERC eTariff system, statement of rates plus general terms and conditions, all Section 4 rate cases since the last general rate case, plus — for ICA-regulated oil pipelines — FERC Oil Pipeline Index filings under the 5-year index review (RM26-6-000, NPRM November 20, 2025; Final Rule April 24, 2026); note the now-rescinded Order 871 was a separate gas-pipeline construction-authorization rule under NGA Section 7 rescinded October 7, 2025 (193 FERC ¶ 61,014, docket RM25-15-000) and does not affect tariff diligence); Tier C Form 6 plus Form 6-Q financial filings (5 years annual plus 8 quarters); Tier D operational filings (open-season, Index of Customers reports, Section 284 transportation reports, discount plus negotiated-rate authority); Tier E decommissioning (49 CFR Section 192.727 for gas pipelines, 49 CFR Section 195.402 for hazardous liquid pipelines, 60-day operator-change notification to PHMSA for transfers 50 miles or longer, state PUC abandonment filings).

3. Throughput contract typology — four contract families: Family A minimum volume commitments (MVC) where producer commits to delivering X volumes per period (common in Permian / Bakken / Eagle Ford gathering, roll-off schedules typically 7 to 15 years from gathering tie-in); Family B take-or-pay demand-charge contracts where customer commits to fixed demand charge regardless of throughput (common in interstate transmission plus LNG offtake-tied transmission, long-dated 15 to 25 years); Family C fee-based cost-of-service tolling structure (used for cryogenic processing capacity plus fractionators); Family D: FERC Oil Pipeline Index rate transmission (interstate liquids pipelines under the Interstate Commerce Act). Rates indexed every 5 years per RM26-6-000 (NPRM November 20, 2025; Final Rule April 24, 2026).

4. PHMSA integrity records under 49 CFR Parts 191 / 192 / 195 — annual reports (Form PHMSA F 7100.1-1 for gas distribution, 7100.2-1 for gas transmission, 7000-1.1 for hazardous liquid); incident reports (Form PHMSA F 7000-1) with 1-hour NRC call audit trail (1-800-424-8802) plus 30-day written report for ALL incidents in the prior 7 years; Mega Rule Phase 2 ('Gas Transmission RIN2') compliance with both the May 24, 2023 effective rule AND the January 15, 2025 corrections following the August 16, 2024 D.C. Circuit partial vacatur in Interstate Natural Gas Association of America v. PHMSA (D.C. Cir., No. 22-1148); 49 CFR Section 192.727 abandonment records; the 60-day operator-change notification; the Integrity Management Plan under 49 CFR Section 192 Subpart O for gas transmission and 49 CFR Section 195 Subpart F for hazardous liquid; High Consequence Area assessments plus In-Line Inspection tool runs (typically MFL, UT, IMU, geometry); hydrostatic test records plus spike hydrostatic test records.

5. EPA methane plus GHGRP Subpart W reporting — EPA OOOOb new-source performance standards for sources constructed or modified after December 6, 2022; OOOOc existing-source state-plan emission guidelines (final rule effective May 7, 2024; EPA's November 26, 2025 final rule (effective December 3, 2025) extended the state-plan submission deadline by approximately 10.5 months from March 9, 2026 to January 22, 2027); GHGRP Subpart W (final May 6, 2024, effective for reporting year 2025, first reports due March 31, 2026) covering transmission compression, transmission pipelines, storage, and blowdown vents.

Standard M&A checklists were built for corporate M&A. They do not cover the midstream-specific ROW archive, the FERC stack, the throughput-contract typology, the PHMSA integrity discipline, or the EPA methane plus Subpart W reporting reality. The next section breaks down the ROW Assignment Integrity Test.

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What is the ROW Assignment Integrity Test?

The ROW Assignment Integrity Test is the proprietary frame I use to diagnose midstream pipeline acquisition data room composition: a 4-axis scorecard that evaluates the easement and right-of-way archive across recording completeness, assignability, regulator dependency, and decommissioning-bond gating. The ROW Assignment Integrity Test has no upstream or LNG analog because no upstream or LNG asset class has a multi-thousand-easement archive — upstream is reserves-driven (logs, seismic, SEC PUD reserves), LNG is plant-permit plus EPC-pack driven, and only midstream has the 8,000 to 15,000-instrument-per-1,000-mile easement-archive density that demands the 4-axis discipline.

ROW Assignment Integrity Test summary table

Axis one — Recording completeness. What percentage of total easements are recorded in the correct county jurisdiction with valid grantor and grantee chain? The state-stack layer matters: Texas requires county-clerk recording in the Real Property Records of each county, where T-4 permit (Texas Railroad Commission) gives operating-authority only and statutory eminent-domain runs through Natural Resources Code Chapter 111 (common-carrier status declaration). New Mexico requires county-clerk recording plus State Land Office for state-trust-land easements plus BLM right-of-way grants for federal land. Pennsylvania requires prothonotary's office recording plus PADEP state pipeline jurisdiction. North Dakota requires register of deeds plus BIA on tribal lands (Fort Berthold, Standing Rock). California requires county recorder plus CPUC plus state lands commission.

Axis two — Assignability. What percentage of easements require third-party consent (landowner, mortgagee, subordinate-lien holder) before assignment to acquirer? Most modern grants are freely assignable; older grants from the 1950s-60s often require landowner consent. Mortgagee subordination agreements may require subordinate-lien-holder consent. Title curative work product (curatives, supplements, partial releases) populates the assignability axis.

Axis three — Regulator dependency. What fraction of segments require FERC Section 7(c) certificate amendment, BIA tribal-renewal under 25 CFR Section 169, state PUC abandonment authorization, BLM ROW renewal under 43 CFR Part 2880 (typically 30-year term on federal land), USFS special-use permits for forest-land crossings, or USACE Clean Water Act Section 404 nationwide or individual permits for stream crossings to transfer? Each regulator-dependency line item carries an independent timeline tail that compresses or stretches the overall close.

Axis four — Decommissioning-bond gating. For any retired or partially retired segment, what bonds and accruals exist under 49 CFR Section 192.727 (gas pipelines) and 49 CFR Section 195.402 (hazardous liquid pipelines), and how does state PUC interplay with FERC? The decommissioning-bond gating axis is where the lender's term-loan-A credit committee prefers to see the seller's GAAP-basis accrual ledger, supporting actuarial calculations, and posted bonds before approving disbursement.

A score below 85 percent on axis one or axis two typically gates the financing close — buyers cannot syndicate term loan A without closure on these layers. The Williams-MountainWest Pipeline transaction ($1.5B EV including $1.07B cash plus $0.43B debt assumption, closed February 14, 2023, 2,000 miles interstate gas plus 56 Bcf storage Utah / Wyoming / Colorado, sold by Southwest Gas Holdings) is a recent FERC Section 7(c) certificate-assignment precedent at 2,000-mile scale that anchored the ROW Assignment Integrity Test methodology — notwithstanding that the deal is now ~3 years old and works only as historical-precedent context, not recency anchor. The DT Midstream-ONEOK 3 Pipelines transaction ($1.2B closed December 31, 2024, three FERC-regulated interstate gas pipelines) is the recent-recency anchor for cross-multi-state ROW assignment with parallel FERC plus state PUC review.

The ROW Assignment Integrity Test is the load-bearing fitness check before committing a $2-5B midstream acquisition to a closing schedule — get the answers wrong on axis one or axis two and the room either fails on financing close or pushes the FERC Section 7(c) timeline 6 to 18 months past the buyer's expected close. See the farm-out workflow playbook for the parallel 4-tier farm-out access model where the upstream-LNG archive ROW analog is the seismic-data NDA pattern, and the oil and gas data room cluster anchor for the head-on platform comparison.

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What is the FERC Tier A-E document escalation framework?

The FERC Tier A-E document escalation framework is the proprietary frame I use to diagnose the regulatory archive in midstream pipeline acquisition data rooms — a 5-tier escalation running Tier A certificates, Tier B tariffs, Tier C Form 6 financials, Tier D operational filings, and Tier E decommissioning. The framework parallels but is distinct from the LNG project finance FEED-to-FID document escalation curve I covered in the LNG project finance deep dive — both are escalation frameworks, but the FERC version is regulatory-archive-driven (NGA Section 7(c) plus 18 CFR Part 154), while the LNG version is project-development-driven (FEED through EPC LSTK through ECA disbursement). For interstate natural gas pipelines (regulated under the Natural Gas Act and 18 CFR), the FERC Tier A-E document escalation framework is the canonical structure.

FERC Tier A-E document escalation framework summary table

Tier A — Certificate documents (NGA Section 7(c)). Original certificate of public convenience and necessity (CPCN) plus every subsequent amendment for capacity, route, or abandonment. Environmental assessment (EA) or environmental impact statement (EIS) under NEPA for each amendment cycle. Section 7(c) abandonment authorization for any segment that has been retired. Buyer's FERC counsel runs reverse-chronological audit Tier A first because certificate validity gates everything downstream.

Tier B — Tariff documents under 18 CFR Part 154 (NGA-regulated gas) and ICA / FERC Oil Pipeline Index (oil pipelines). Currently effective tariff (electronic filing in the FERC eTariff system). Statement of rates plus general terms and conditions. All Section 4 rate cases since the last general rate case. For ICA-regulated oil pipelines, FERC Oil Pipeline Index filings under the 5-year index review (RM26-6-000, NPRM November 20, 2025; Final Rule April 24, 2026) — pre-2026 index filings remain operative as historical priors. Important regulatory-frame note: FERC Order 871 was rescinded October 7, 2025 (193 FERC ¶ 61,014, docket RM25-15-000). Order 871 prohibited issuance of NGA Section 7 construction authorization during the 30-day rehearing period; its rescission removes a permitting bottleneck for new natural gas pipeline projects but does not affect tariff diligence. NGA-regulated transmission uses cost-of-service or negotiated-rate mechanisms; oil-pipeline (ICA-regulated) tariffs use the FERC Oil Pipeline Index reset every 5 years. All pending or settled Section 5 (FERC-initiated) rate filings.

Tier C — Form 6 / Form 6-Q financial filings under 18 CFR Part 260. Annual Form 6 for the prior 5 years (regulated annual financials). Quarterly Form 6-Q for the prior 8 quarters. Any Form 6 corrections or re-filings. Underlying workpapers if the buyer requests via clean-room or signed addendum. Tier C is the credit-committee tier — the buyer's RBL syndicate, term-loan-A lenders, and external counsel cross-check Form 6 against the seller's financial model.

Tier D — Operational filings. Open-season filings for capacity allocation. Index of Customers (IOC) reports plus posted shipper lists. Section 284 transportation reports. Discount plus negotiated-rate authority filings. Tier D feeds directly into the Throughput-Decay Diagnostic (covered in the next section): the IOC reports plus posted shipper lists let the buyer identify counterparty concentration, and the negotiated-rate authority filings reveal whether the seller has been carrying rates below the cost-of-service rate base.

Tier E — Decommissioning / abandonment. 49 CFR Section 192.727 abandonment compliance documentation for gas pipelines. 49 CFR Section 195.402 abandonment compliance for hazardous liquid pipelines. 60-day operator-change notification to PHMSA for any transfer 50 miles or longer. State PUC abandonment filings where state retains concurrent authority on intrastate segments. Tier E feeds directly into Decommissioning-Bond Gating (covered later in this post): the 49 CFR Section 192.727 abandonment record plus the state PUC concurrent jurisdiction is what the lender's term-loan-A credit committee uses to evaluate whether the seller has properly funded end-of-life liability.

Why this matters for the data room. Buyer's FERC counsel runs reverse-chronological audit Tier A first, then Tier B, then Tier C and Tier D in parallel. Sellers who pre-curate the FERC Tier A-E stack chronologically (rather than functionally) save 4 to 6 weeks of regulatory diligence latency. The DT Midstream-ONEOK 3 Pipelines transaction (Guardian Pipeline plus Midwestern Gas Transmission plus Viking Gas Transmission, $1.2B cash, closed effective 11:59pm CT December 31, 2024, buy-side financial advisor Barclays with legal counsel Weil, Gotshal & Manges (sell-side advisor not publicly disclosed), requiring FERC Section 7(c) certificate amendment plus HSR clearance per DT Midstream IR plus 8-K) is the recent precedent that exercised the full Tier A-E framework on three FERC-regulated interstate natural gas pipelines. See the oil and gas data room checklist for the underlying 12-folder mapping where the FERC Tier A-E stack lives in the regulatory folder.

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What is the 4-Tier Midstream M&A Access Model?

The 4-Tier Midstream M&A Access Model is the proprietary frame I use to gate access in midstream pipeline acquisition data rooms — Tier 1 operator equity / strategic acquirer, Tier 2 non-operator equity / co-investor, Tier 3 FERC-regulatory counsel, and Tier 4 project-finance lender plus term-loan-A lender. The model is the direct midstream analog to the 4-tier farm-out access model covered in the farm-out workflow playbook (operator / non-operator / state partner / lender), with FERC counsel substituting for the state-partner role because midstream regulatory dependency is federal-agency-led not host-government-led.

4-Tier Midstream M&A Access Model summary table

Tier 1 — Operator equity / strategic acquirer. Receives full data room. Includes financial model, full throughput-contract counterparty list, full FERC Tier A-E stack, all integrity records under 49 CFR Section 192 Subpart O (gas transmission) and Section 195 Subpart F (hazardous liquid), and all five ROW archive layers (state-by-state county recording, tribal-land consultation under National Historic Preservation Act Section 106, regulator-dependency dependencies, eminent-domain history, assignability plus consent-required clauses). Expected I-count 5/5 across all queries. The 4-Tier Midstream M&A Access Model assumes the strategic acquirer is the Energy Transfer / Enterprise Products / Williams / Kinder Morgan / ONEOK / Targa / Plains / Sunoco / Enbridge / MPLX / DT Midstream / Phillips 66 Midstream tier of midstream MLP or C-corp.

Tier 2 — Non-operator equity / co-investor. Receives all operational plus financial documents but counterparty-name-redacted contracts. ROW archive may be summary-only (statistical recording-completeness scorecard, not full document set). Counterparty names walled because Tier 2 co-investors include other infrastructure funds (Brookfield Infrastructure, Stonepeak, Energy Spectrum Capital, Quantum Capital, I Squared Capital, Global Infrastructure Partners now BlackRock GIP, Ares Infrastructure, Pearl Energy Investments) that may bid on the same counterparties' future contracts.

Tier 3 — FERC-regulatory counsel. Receives the full FERC Tier A-E stack (Tier A certificates plus Tier B tariffs plus Tier C Form 6/6-Q financials plus Tier D operational filings plus Tier E decommissioning), state PUC filings, BIA tribal documents under 25 CFR Section 169, eminent-domain dockets per state, and Texas common-carrier challenge case law where applicable. Operational financial details and throughput-contract terms are NOT exposed at this tier — outside FERC counsel reviews regulatory exposure, not commercial economics.

Tier 4 — Project-finance lender plus term-loan-A lender. Receives financial model, throughput-contract counterparty-credit summary (counterparty-name-redacted may apply during initial round; full disclosure post-mandate-letter), FERC Form 6 plus 6-Q financial vintages, Integrity Management Plan plus integrity records, ROW assignability summary scorecard (axis-one through axis-four output of the ROW Assignment Integrity Test), and decommissioning bond plus accrual reserves (the Decommissioning-Bond Gating evidence stack). Tier 4 includes the buyer's RBL syndicate, term-loan-A lender, and lender's external counsel.

Crucially: any single data room platform must support all four access tiers from a single project upload. Per-page-billing platforms become economically prohibitive when Tier 3 plus Tier 4 counterparties browse 10,000-plus pages each during diligence; flat-fee per-admin pricing (Peony Data Room at $52/admin/month) preserves margin. Peony Data Room expresses the 4-Tier Midstream M&A Access Model through programmatic visitor groups so each tier sees their permission-isolated subfolder without manual permission resets, with dynamic watermarks tagging every page with viewer name plus timestamp plus page position, NDA gates with integrated e-signatures so each tier signs the seller's NDA template before any tier-gated documents are visible, and screenshot protection on desktop and mobile for the throughput-contract counterparty-credit-summary folder where counterparty-name redaction depends on no-screenshot enforcement.

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How does the Throughput-Decay Diagnostic score MVC + take-or-pay + counterparty credit?

The Throughput-Decay Diagnostic is the proprietary frame I use to score the throughput contract base in midstream pipeline acquisition data rooms — a 5-factor scorecard evaluating MVC roll-off schedule, counterparty credit concentration, take-or-pay (TOP) shortfall payment history, recontracting risk, and producer-acreage-dedication tie-back. The Throughput-Decay Diagnostic is genuinely unique to midstream; upstream is reserves-driven (PDP / PUD decline curves, SEC reserve tiering covered in the upstream divestiture deep dive), LNG is 20-year SPA take-or-pay-driven covered in the LNG project finance deep dive, and only midstream has the 5-factor MVC roll-off plus counterparty-credit plus TOP shortfall plus recontracting plus acreage-dedication risk stack.

Throughput-Decay Diagnostic summary table

Factor 1 — MVC roll-off schedule. When does each MVC contract expire or step down? Sellers stack-and-rank by year and by counterparty so the buyer's credit team can model the cliff. MVC roll-off schedules typically run 7 to 15 years from gathering tie-in for Permian, Bakken, and Eagle Ford gathering. The MVC roll-off cliff matters because a single counterparty's MVC stepping down by 30 percent in year 3 of a 10-year financing can blow the lender's debt-service-coverage-ratio modeling.

Factor 2 — Counterparty credit concentration. What percentage of total revenue comes from top-1, top-5, and top-10 counterparties? What's the credit rating distribution? Top-1 concentration above 25 percent with sub-investment-grade rating is a yellow flag; top-1 above 40 percent is a red flag. The counterparty-credit matrix exhibit must surface the rating-distribution histogram alongside the revenue-concentration table.

Factor 3 — Take-or-pay (TOP) shortfall payment history. Has any counterparty paid take-or-pay shortfall in the last 5 years? A TOP shortfall payment is a leading indicator of producer-side tightening — if a producer is paying shortfall, they're delivering below MVC, which signals well-economics decay or pad-completion delay. The TOP shortfall history exhibit must surface payment events with reason codes (decline-curve underperformance, drilling-program slip, basis-differential blow-out).

Factor 4 — Recontracting risk. For any contract within 24 months of expiration, what's the current basis differential at the relevant pricing hub (Waha, Henry Hub, Dominion South, MichCon, Chicago Citygate, Permian hub differentials, Mont Belvieu LST for NGL)? How does it compare to the contract rate? Negative basis plus low residual term equals high recontracting downside. The recontracting-risk exhibit must surface the basis-differential time series alongside the contract-rate map.

Factor 5 — Producer-acreage tie-back. Is the customer producer hedged against the gathering system via long-term acreage dedication? Loss of dedication is the single most common throughput-decay surprise. Acreage-dedication maps with expiration calendar plus the producer's drilling-activity overlay are both required. If the producer's acreage dedication expires and the producer pivots to a competing midstream system, the throughput decline is structural not cyclical.

Why this matters for lenders. Project-finance lenders plus term-loan-A lenders require Throughput-Decay Diagnostic-style modeling before credit-committee approval. Sellers who pre-curate the data room with diagnostic-test-ready exhibits cut financing-close latency by 4 to 8 weeks. The Energy Transfer-WTG Midstream transaction ($3.25B announced May 28, 2024 and closed July 15, 2024 per Energy Transfer IR plus BusinessWire, $2.275B cash plus 50.8 million ET LP units, ~6,000 miles of Midland Basin gas-gathering plus eight cryogenic gas-processing plants at 1.3 Bcf/d aggregate, sellers Stonepeak plus DiamondBack-related entities, BofA on Energy Transfer side and Jefferies on WTG side as lead financial advisors with Sidley Austin as WTG legal counsel, HSR cleared) is the recent precedent at $3B-plus Permian G&P scale where the Throughput-Decay Diagnostic anchored lender credit-committee review. The Plains All American-EPIC Crude Holdings transaction ($2.9B aggregate; 55 percent from Diamondback / Kinetik for $1.57B closed October 31, 2025; 45 percent from Ares Infrastructure for $1.33B closed November 1, 2025; 800-mile long-haul Permian-to-Eagle Ford-to-Corpus Christi crude pipeline at 600-plus kbpd nameplate; $193M earnout tied to ~900 kbpd capacity-expansion sanction by year-end 2027 per Plains IR; rebranded Cactus III on close) illustrates the sophisticated structure where the earnout itself anchors the recontracting-risk axis of the Throughput-Decay Diagnostic.

Peony Business at $30/admin/month ships page-level analytics tracking per-page dwell time and screenshot block attempts on the throughput contract counterparty-credit-summary folder, with dynamic watermarking and its version log on the Data Room plan ($52/admin/month) — exactly the audit trail term-loan-A syndicate counsel and credit-committee modelers expect. See the oil and gas data room checklist for the underlying 12-folder mapping where the throughput-contract folder lives in the commercial agreements tier.

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How does Decommissioning-Bond Gating work under 49 CFR §192.727 + state PUC?

Decommissioning-Bond Gating is the proprietary frame I use to evaluate end-of-life liability funding in midstream pipeline acquisition data rooms — the disciplined evaluation of bonds, accruals, and abandonment-cost reserves under 49 CFR Section 192.727 (gas pipelines) plus 49 CFR Section 195.402 (hazardous liquid pipelines) plus state PUC concurrent jurisdiction plus FERC abandonment under NGA Section 7(c). Decommissioning-Bond Gating conceptually parallels the upstream UKCS NSTA decommissioning-security framework covered in Post 5 (NSTA decommissioning notices plus Petroleum Act 1998 Section 29 plus DSAs), but the regulatory stack is distinct. Both invoke "bond gating" but on different statutes — branding the midstream version separately is justified.

Decommissioning-Bond Gating evidence categories summary table

Category 1 — Historical abandonment authorizations. Every 49 CFR Section 192.727 authorization granted to the seller for retired or partially retired segments. Every state PUC abandonment filing where state retains concurrent authority on intrastate segments. Every FERC Section 7(c) abandonment certificate where applicable to interstate segments. The corresponding 60-day operator-change notification to PHMSA for transfers 50 miles or longer. This category validates the seller's compliance posture — has the seller properly retired segments at end-of-life through the federal-state regulatory stack?

Category 2 — Accrual ledgers. The seller's GAAP-basis abandonment accrual schedule, the supporting actuarial calculations (typical assumptions: discount rate, inflation, segment-by-segment retirement timing), and the cumulative balance against expected end-of-life cost. The accrual-ledger category answers the funding-adequacy question: has the seller actually funded the future liability against booked depreciation, or is the accrual nominal-only?

Category 3 — Bond and letter-of-credit posting. State PUC bond requirements where applicable — Texas Railroad Commission requires segment-specific bonding that runs separately from the T-4 permit; California CPUC concurrent jurisdiction can require additional bonding above and beyond federal 49 CFR Section 192.727 minimums; Pennsylvania DEP plus PUC; North Dakota PSC. The seller's posted financial assurance instruments — surety bonds, letters of credit, parental guarantees — must be evidenced in the data room with current market-value-equivalent.

Category 4 — Abandonment-cost-reserve calculation methodology. Segment-by-segment retirement-cost estimates. The seller's third-party engineering review (typically by a PHMSA-experienced engineering firm). The reconciliation against booked accrual. Category four matters because the engineering-firm review is what the buyer's term-loan-A lender uses to validate that the booked accrual reflects actual end-of-life cost — not a nominal placeholder.

The Decommissioning-Bond Gating mechanic for the lender. Term-loan-A lenders require Decommissioning-Bond Gating evidence at Tier 4 access before credit-committee approval — without adequate bond posting plus accrual coverage, the asset-level financing is non-recourse-impaired. The state PUC interplay matters because state PUC concurrent jurisdiction can require additional bonding above and beyond federal 49 CFR Section 192.727 minimums — particularly in California where CPUC review of intrastate segments runs parallel to FERC review of interstate. The 60 to 180 day Decommissioning-Bond Gating review period is the typical Tier 4 lender-side timeline; for first-time entrants to a particular state PUC's bonding regime, the timeline can stretch to 9 to 12 months.

The DT Midstream-ONEOK 3 Pipelines transaction (Guardian Pipeline plus Midwestern Gas Transmission plus Viking Gas Transmission, $1.2B cash, closed effective 11:59pm CT December 31, 2024 per DT Midstream IR plus 8-K filing) is the recent precedent that exercised Decommissioning-Bond Gating across three FERC-regulated interstate gas pipelines spanning multiple states with parallel state PUC review. The Williams-MountainWest transaction at 2,000-mile interstate gas plus 56 Bcf storage is the conceptual precedent at similar mileage, but at ~3 years old it's historical-context only; the DT Midstream close is the recency anchor.

Peony Data Room at $52/admin/month ships NDA gates plus page-level analytics preserving the audit trail across the 60 to 180 day Decommissioning-Bond Gating review — the per-page audit trail is exactly what the buyer's term-loan-A lender plus external counsel cross-check during credit-committee approval. See the LNG project finance deep dive for the parallel Equator Principles 4 IESC review in LNG project finance, which is the conceptually-adjacent lender-tier review for upstream-LNG transactions.

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How big is a typical midstream pipeline acquisition data room at Phase II, and how do per-page billing platforms break?

A typical midstream pipeline acquisition data room at Phase II runs 200 to 300 GB for a $1-3B G&P bolt-on; multi-state interstate transmission systems plus 14,000-mile retail-platform-rollups (the Sunoco-Parkland scale) routinely hit 400-plus GB. The structural composition: ROW easement archive 50 to 150 GB (8,000 to 15,000 instruments per 1,000 miles for interstate transmission, 30,000 to 50,000-plus on 6,000-mile gathering systems); FERC Tier A-E stack 20 to 50 GB; throughput contract base 10 to 30 GB; PHMSA integrity records (annual reports, incident reports, IMP, ILI, hydrostatic) 20 to 60 GB; EPA OOOOb/OOOOc plus GHGRP Subpart W reporting 5 to 15 GB; financial-model plus counterparty-credit summary 5 to 10 GB; state PUC plus BIA tribal documents plus eminent-domain dockets 10 to 30 GB.

Platforms that handle 200 to 400 GB Phase II archives without splitting and at sustainable cost across the 14-month FERC Section 7(c) certificate-amendment plus HSR-clearance lifecycle are narrow.

• Peony Data Room at $52/admin/month. No per-file cap (chunked parallel transfers with global CDN). Unlimited storage. Ships NDA gates, dynamic watermarks, screenshot protection, visitor groups, page-level analytics on the same room. For 6 admins on a 14-month midstream-acquisition cycle, that is $4,368 total flat.
• Datasite Diligence. 10 GB single-file cap with zip files supported up to 50 GB per Datasite FAQ — requires splitting on full ROW-archive ZIP-streams of 30,000-plus title documents. Bills $0.40 to $1.00 per page (Capterra-aggregated buyer data, 2026; G2; Vendr; Papermark). On a 200 to 300 GB Phase II archive rendering at 200,000-plus pages, $25,000 to $80,000-plus per deal at enterprise tier per the same buyer data; six-figure invoices on 14-month FERC-certificate-amendment lifecycle.
• Intralinks VDRPro at enterprise tier. 25 GB single-file cap raised from 15 GB across US, Germany, and Australia per Intralinks release notes — workable for individual reports but breaks on the larger SEG-Y-style compressed ROW archives. Custom-quoted pricing typically $25,000 to $80,000 per deal at enterprise tier.
• Box Enterprise Advanced. Supports 500 GB single-file uploads (largest in market) but ships zero NDA gates, dynamic watermarks, or screenshot protection — fails the 4-Tier Midstream M&A Access Model test outright.
• Firmex. 10 GB drag-and-drop cap (Firmex documentation) — fine for paper-heavy CIMs but corrupts archive continuity when split.

Cost wedge math at Phase II scale. For 6 admins on a 14-month midstream-acquisition cycle handling a 200 to 300 GB Phase II archive: Peony Data Room runs $4,368 total flat (6 admins x $52 x 14 months). Datasite enterprise typically lands $25,000 to $80,000-plus per deal at $0.40 to $1.00 per page rendered across the archive (Capterra/G2/Vendr/Papermark, 2026). The 6x to 18x cost gap on data-heavy Phase II workflows is structural, not promotional — Datasite per-page billing punishes the 30,000-easement ROW archive disproportionately because each title document renders as multiple pages on the per-page invoice. For smaller admin teams running a single sell-side mandate that does not need unlimited rooms, Peony Business at $30/admin/month ships the screenshot stack with a simple NDA gate, reduced storage, and lower room caps, with dynamic watermarks on the Data Room plan ($52/admin/month) — a fit for sell-side advisor teams of 2 to 3 admins.

For the Phase II lender-plus-counsel syndicate at 6 to 8 admins on a 14-month lifecycle, Peony Data Room at $52/admin/month is the right tier. See the horizontal sibling large-file data room with NDA gates for the file-mass mechanics across mining, biotech, AEC, and oil-gas.

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What is the Seller's Midstream Data Room Platform Diagnostic Test?

The Seller's Midstream Data Room Platform Diagnostic Test is the proprietary 8-question scorecard I use to benchmark platform fit before committing a midstream pipeline acquisition data room to a vendor. The test extends the 5-question diagnostic from the upstream divestiture deep dive with three midstream-specific questions covering segregated regulatory tier permissioning, per-counterparty contract folder permissioning, and 30,000-plus-document ZIP-stream uploads. Run the Seller's Midstream Data Room Platform Diagnostic Test against any vendor before signing the procurement contract — get the answers wrong on questions 1, 6, or 8 and the room either fails on file-size caps or buries a six-figure invoice in the per-page meter at the 30,000-easement ROW archive.

Seller's Midstream Data Room Platform Diagnostic Test summary table

Standard 5 (carry-over from Post 5).

1. Can the platform handle 200-300+ GB total upload (with single-file limits above 10GB for raw seismic or pipeline-survey datasets)? Peony unlimited. Datasite caps single files at 10 GB with zip files supported up to 50 GB. Intralinks caps single files at 25 GB across US, Germany, and Australia. Firmex caps drag-and-drop at 10 GB. Box Enterprise Advanced supports 500 GB single-file uploads (largest in market) but ships zero NDA gates, dynamic watermarks, or screenshot protection — fails the basic 4-Tier Midstream M&A Access Model test.

2. Can NDA gate logic enforce per-tier access (4-Tier Midstream M&A Access Model: operator equity, non-operator equity, FERC counsel, lender)? Peony NDA gates yes via programmatic permission groups. Datasite enterprise yes. Intralinks enterprise yes. Box no.

3. Can watermarks dynamically embed bidder-name plus timestamp plus page-position? Peony dynamic watermarks yes — every page tagged with viewer name, email, IP, and timestamp. Datasite enterprise yes. Intralinks enterprise yes. Box no.

4. Does pricing scale flat (Peony Data Room at $52/admin/month) or per-page (Datasite at $0.40-$1.00/page)? Peony Data Room flat $52/admin/month. Datasite $0.40-$1.00 per page rendered. Intralinks custom-quoted $25,000 to $80,000 per deal at enterprise tier. The pricing-scale question is decisive at the 30,000-easement ROW archive — per-page billing renders each title document as multiple pages.

5. Can analytics surface 5-second-page-view filtering to detect tire-kicker counterparties? Peony page-level analytics yes — per-page dwell time, filtering by threshold, watermark version log, screenshot block attempts. Datasite yes at enterprise tier. Intralinks yes at enterprise tier.

Midstream-specific 3 (the extension).

6. Can the platform support segregated regulatory tier (FERC plus state PUC plus tribal plus BIA plus USACE) with each sub-folder permission-isolated for outside regulatory counsel only? Peony visitor groups yes through programmatic permission. Datasite yes via permission groups at enterprise tier. The midstream-specific extension matters because Tier 3 (FERC-regulatory counsel) needs full access to the FERC Tier A-E stack but zero access to operational financial details or throughput-contract terms — a permission discipline that flat hierarchies break.

7. Does the throughput-contract folder support per-counterparty subfolder permissioning so that customer A cannot see customer B's contract terms during due-diligence cross-check? Peony yes through visitor groups. Datasite yes via permission groups. Intralinks yes. The per-counterparty subfolder permissioning matters because the throughput-contract folder is where Tier 4 (project-finance lender) does Throughput-Decay Diagnostic modeling — which requires access to counterparty-credit summary across counterparties without exposing competitor counterparties' contract terms.

8. For ROW archive specifically: can the platform handle ZIP-stream uploads of 30,000-plus individual title documents without chunking, with inline preview of recorded instruments? Peony yes (no per-file cap, chunked parallel transfers with global CDN). Datasite force splits at 50 GB zip cap. Intralinks force splits at 25 GB single-file cap on the larger compressed archives. Box no preview support.

A platform that scores below 6/8 on this test is unsuitable for a midstream M&A data room above $1B. Below $500M, scoring 5/8 is acceptable; below $100M, 4/8. Peony Data Room scores 8/8 on this test. The Seller's Midstream Data Room Platform Diagnostic Test is the load-bearing fitness check before committing the 200 to 400 GB Phase II archive to a platform — get the answers wrong and the room either fails on file-size caps (question 1, question 8) or buries a six-figure invoice in the per-page meter (question 4). The DT Midstream-ONEOK 3 Pipelines transaction at $1.2B and the Energy Transfer-WTG Midstream transaction at $3.25B are both the precedents where the diagnostic test would gate platform selection at enterprise scale.

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What does Peony do that legacy midstream M&A VDRs don't on the 4-Tier Midstream M&A Access Model?

Peony Data Room at $52/admin/month handles midstream pipeline acquisition data rooms — 200 to 300 GB at Phase II, 400-plus GB at the 14,000-mile retail-platform-rollup scale, across a 14-month FERC Section 7(c) certificate-amendment plus HSR-clearance lifecycle from teaser through closing through 12 to 24 month post-closing dispute resolution — at a cost structure that decouples from data volume and counterparty count, while preserving the security primitives that gate Tier 3 (FERC-regulatory counsel) and Tier 4 (lender) tiers on the 4-Tier Midstream M&A Access Model. Run the Seller's Midstream Data Room Platform Diagnostic Test against Peony and the eight answers all pass. The structural cost wedge against Datasite per-page billing is 6x to 18x on data-heavy Phase II workflows.

Five capabilities that matter for midstream pipeline acquisition work.

1. No per-file cap. A 30,000-easement ROW archive uploads as ZIP-streams without splitting, with the audit trail preserved. Datasite caps single files at 10 GB with zip files supported up to 50 GB; Intralinks caps single files at 25 GB across US, Germany, and Australia; Firmex caps drag-and-drop at 10 GB. Box Enterprise Advanced supports 500 GB single-file uploads but ships zero NDA gates, dynamic watermarks, or screenshot protection — fails the basic 4-Tier Midstream M&A Access Model test.

2. NDA gates with integrated e-signatures. Each Tier 1 (operator equity), Tier 2 (non-operator equity), Tier 3 (FERC-regulatory counsel), and Tier 4 (project-finance lender plus term-loan-A lender) recipient signs the seller's NDA template inline before any tier-gated documents are visible. Signature record exportable as PDF audit trail satisfying SEC plus FERC plus PSA disclosure-liability documentation.

3. Dynamic watermarks tagging every page with viewer name, email, IP, and timestamp — across the ROW archive, FERC Tier A-E stack, throughput contract counterparty-credit summary, PHMSA Mega Rule Phase 2 plus January 2025 corrections record, EPA OOOOb/OOOOc plus GHGRP Subpart W reporting, and decommissioning-bond gating evidence.

4. Screenshot protection on desktop and mobile — non-negotiable for FERC counsel reviewing Tier B tariff filings, term-loan-A syndicate counsel evaluating throughput-contract counterparty-credit concentration, and PHMSA-experienced engineering firms reviewing the seller's incident-report folder.

5. Programmatic visitor groups expressing the 4-Tier Midstream M&A Access Model without manual permission resets across the 14-month midstream-acquisition lifecycle plus 12 to 24 month post-closing dispute resolution period. Page-level analytics preserve per-page dwell time, per-document NDA signature record, watermark version log, and screenshot block attempts — the audit trail term-loan-A syndicate counsel and credit-committee modelers expect.

Trade-offs to be honest about. Peony does not ship a dedicated FERC docket cross-reference workflow (FERC docket lookup runs through standard search rather than a dedicated integration); Datasite remains the de-facto procurement standard at certain mega-cap midstream M&A groups where buyer-side procurement expects a Datasite-branded room (the Sunoco-Parkland scale-of-deal reference); Intralinks ships pre-built workflow templates at enterprise tier with SS&C Technologies' pedigree on $35T+ in transactions processed. Where those defaults are hard requirements, the legacy choice still applies. Where the data room is selected by the seller's corp-dev or sell-side advisor rather than dictated by buyer-side procurement, Peony becomes structurally compelling across the 14-month lifecycle — for a 6-admin sell-side team that is $4,368 total flat versus $25,000 to $80,000-plus per deal on enterprise per-project pricing.

Cluster anchors for further reading: the 10 best data rooms for oil and gas companies (2026); the 42-document oil and gas data room checklist; the 7-step farm-out workflow plus 4-tier farm-out access model; the LNG project finance data room FEED-to-FID escalation curve; the upstream divestiture data room 12-month timeline plus 4-tier reserves disclosure; the large-file data room with NDA gates; and /solutions/energy.

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Frequently asked questions

I run corp-dev at a midstream MLP about to acquire a 6,000-mile gathering system in the Permian — what's the full document inventory I need to surface in the data room across ROW archive, FERC stack, throughput contracts, and PHMSA integrity records, and how does total doc mass scale from a 100-mile bolt-on to a 14,000-mile platform deal?

For your corp-dev role at a midstream MLP acquiring a 6,000-mile Permian gathering system, the full document inventory spans five archives — ROW easement archive, FERC Tier A-E stack, throughput contract typology, PHMSA integrity records, and EPA methane plus Subpart W reporting — and total doc mass scales roughly linearly with mileage. A 100-mile bolt-on typically runs 5 to 15 GB across 50,000 to 100,000 files; a 1,000-mile system runs 50 to 80 GB across 400,000 to 500,000 files; a 6,000-mile Permian gathering platform runs 200 to 300 GB across 2 million-plus files; a combined-platform deal at the Sunoco-Parkland scale runs 400-plus GB. The ROW archive alone carries 8,000 to 15,000 individual easement instruments per 1,000 miles of interstate pipeline, and 30,000 to 50,000-plus on 6,000-mile gathering systems. The FERC Tier A-E document escalation framework structures the regulatory archive into Tier A certificates under NGA Section 7(c), Tier B tariff documents under 18 CFR Part 154, Tier C Form 6 plus Form 6-Q financials, Tier D operational filings, and Tier E decommissioning under 49 CFR Section 192.727 plus Section 195.402. Throughput contracts decompose into four families — minimum volume commitments (MVC), take-or-pay demand-charge contracts, fee-based cost-of-service tolling, and FERC Oil Pipeline Index rate transmission for ICA-regulated liquids pipelines under the 5-year index review (RM26-6-000); the now-rescinded Order 871 was a separate gas-pipeline construction-authorization rule rescinded October 7, 2025 (193 FERC ¶ 61,014, docket RM25-15-000) and does not affect tariff diligence. PHMSA integrity records require both the May 24, 2023 Mega Rule Phase 2 effective rule AND the January 15, 2025 corrections following the August 16, 2024 D.C. Circuit partial vacatur in Interstate Natural Gas Association of America v. PHMSA (D.C. Cir., No. 22-1148). Peony Data Room at $52/admin/month handles the 200 to 400 GB Phase II archive without per-file caps and ships unlimited storage plus programmatic visitor groups expressing the 4-Tier Midstream M&A Access Model — see the oil and gas data room cluster anchor for the platform comparison and the upstream divestiture timeline for the parallel 4-tier reserves disclosure progressive-tiering matrix.

I'm IR at an integrated divesting a 2,000-mile interstate gas pipeline plus storage — what does the ROW Assignment Integrity Test score, and how do I pre-curate state-by-state recording, tribal-land renewal, and consent-required clauses before the buyer's regulatory counsel runs the test against me?

For your IR role divesting a 2,000-mile interstate gas pipeline plus storage, the ROW Assignment Integrity Test scores the easement archive across four axes — recording completeness, assignability, regulator dependency, and decommissioning-bond gating — and you pre-curate by mapping each axis at the document layer before the buyer's FERC counsel runs the test. Axis one, recording completeness, asks what percentage of total easements are recorded in the correct county jurisdiction with valid grantor and grantee chain. Axis two, assignability, asks what percentage require third-party consent (landowner, mortgagee, subordinate-lien holder) before assignment. Axis three, regulator dependency, asks what fraction of segments require FERC Section 7(c) certificate amendment, BIA tribal renewal under 25 CFR Section 169, or state PUC abandonment authorization to transfer. Axis four, decommissioning-bond gating, asks what bonds and accruals exist under 49 CFR Section 192.727 and how state PUC interplay with FERC. Pre-curation on axis one means walking each county recorder, each prothonotary office, and each register of deeds across the state-by-state recording footprint — Texas county-clerk recording in the Real Property Records, New Mexico county-clerk plus State Land Office plus BLM, Pennsylvania prothonotary plus PADEP, North Dakota register of deeds plus BIA on tribal lands, California county recorder plus CPUC. Pre-curation on axis two stratifies the easement form into freely assignable (most modern grants), landowner-consent-required (older 1950s-60s grants), and mortgagee-subordination-required. Pre-curation on axis three runs the FERC docket lookup for each segment under NGA Section 7(c), the BIA right-of-way grant renewal calendar under 25 CFR Section 169.3(a) for tribal-land segments, and the BLM 30-year ROW renewal under 43 CFR Part 2880. The Williams-MountainWest precedent — $1.5B EV closed February 14, 2023, 2,000 miles interstate gas plus 56 Bcf storage Utah, Wyoming, Colorado per Williams Companies and Southwest Gas Holdings press releases — is the same-mileage precedent for FERC Section 7(c) certificate-assignment. A score below 85 percent on axis one or axis two typically gates the financing close. Peony Data Room at $52/admin/month ships unlimited storage for the 30,000 to 50,000-easement archive — see the oil and gas data room checklist for the underlying 12-folder mapping.

I'm outside counsel running the regulatory tier of a midstream M&A data room — what FERC documents must surface for a Section 7(c) certificated interstate gas pipeline, how do the FERC Oil Pipeline Index 5-year review (RM26-6-000) and the October 7 2025 rescission of Order 871 (193 FERC ¶ 61,014, docket RM25-15-000 — a separate gas-pipeline construction-authorization rule) factor into tariff and certificate diligence today, and which Form 6 / Form 6-Q vintages does the buyer's credit committee want?

For your outside counsel role on the regulatory tier of a midstream M&A data room, the FERC stack surfaces through the FERC Tier A-E document escalation framework. Important framing note: Order 871 was a natural gas pipeline construction-authorization rule under NGA Section 7 (it precluded issuance of certificates during the 30-day rehearing period) — it was rescinded October 7, 2025 (193 FERC ¶ 61,014, docket RM25-15-000) and does NOT affect tariff diligence. NGA-regulated gas tariffs continue under cost-of-service or negotiated-rate mechanisms; ICA-regulated oil pipeline tariffs follow the FERC Oil Pipeline Index 5-year review (RM26-6-000, NPRM November 20, 2025; Final Rule April 24, 2026). The buyer's credit committee typically wants five years of Form 6 plus eight quarters of Form 6-Q. Tier A surfaces the original certificate of public convenience and necessity (CPCN) under NGA Section 7(c) plus every subsequent amendment for capacity, route, and abandonment, plus the environmental assessment or environmental impact statement under NEPA, plus Section 7(c) abandonment authorization for any retired segment. Tier B surfaces the currently effective tariff (electronic filing in the FERC eTariff system), statement of rates plus general terms and conditions, all Section 4 rate cases since the last general rate case, plus — for any ICA-regulated oil pipeline component — all FERC Oil Pipeline Index filings under the 5-year index review (RM26-6-000), and all pending or settled Section 5 FERC-initiated rate filings. Tier C surfaces the prior five years of annual Form 6, the prior eight quarters of Form 6-Q, any Form 6 corrections or re-filings, and the underlying workpapers via clean-room or signed addendum at the buyer's request. Tier D surfaces open-season filings for capacity allocation, the Index of Customers (IOC) reports plus posted shipper lists, Section 284 transportation reports, and discount plus negotiated-rate authority filings. Tier E surfaces 49 CFR Section 192.727 abandonment compliance for gas pipelines, 49 CFR Section 195.402 for hazardous liquid pipelines, the 60-day operator-change notification to PHMSA for any transfer 50 miles or longer, and state PUC abandonment filings where state retains concurrent authority on intrastate segments. Buyer's FERC counsel typically runs reverse-chronological audit Tier A first, then Tier B, then Tier C and Tier D in parallel. The DT Midstream-ONEOK 3 Pipelines transaction — $1.2B cash announced November 19, 2024 and closed effective 11:59pm CT December 31, 2024 per DT Midstream IR plus 8-K filing, requiring FERC Section 7(c) certificate amendment plus HSR clearance — is the recent precedent for assignment of three FERC-regulated interstate natural gas pipelines (Guardian, Midwestern Gas Transmission, Viking Gas Transmission). Peony Data Room at $52/admin/month ships NDA gates plus dynamic watermarks so each Tier 3 FERC-counsel reviewer signs the seller's NDA template before any tariff backup is visible.

I'm a midstream credit MD at MUFG underwriting term loan A on a $3B-plus G&P acquisition — how does the Throughput-Decay Diagnostic score MVC roll-off plus take-or-pay shortfall payments plus counterparty credit concentration, and what historical throughput data must be in the data room for me to pass credit committee?

For your midstream credit MD role at MUFG underwriting term loan A on a $3B-plus G&P acquisition, the Throughput-Decay Diagnostic scores the throughput contract base across five factors — MVC roll-off schedule, counterparty credit concentration, take-or-pay (TOP) shortfall payment history, recontracting risk, and producer-acreage-dedication tie-back — and the data room must surface stacked historical throughput data at quarterly granularity for the prior 60 months. Factor one, MVC roll-off, asks when each minimum-volume-commitment contract expires or steps down — sellers stack-and-rank by year and by counterparty so the buyer's credit team can model the cliff. MVC roll-off schedules typically run 7 to 15 years from gathering tie-in for Permian, Bakken, and Eagle Ford gathering. Factor two, counterparty credit concentration, asks what percentage of total revenue comes from top-1, top-5, and top-10 counterparties plus the credit rating distribution. Factor three, TOP shortfall, asks whether any counterparty has paid take-or-pay shortfall in the last five years — a TOP shortfall payment is a leading indicator of producer-side tightening and forecast recontracting downside. Factor four, recontracting risk, asks for any contract within 24 months of expiration what the current basis differential is and how it compares to the contract rate; negative basis plus low residual term equals high recontracting downside. Factor five, producer-acreage tie-back, asks whether the customer producer is hedged against the gathering system via long-term acreage dedication; loss of dedication is the single most common throughput-decay surprise. The historical data the credit committee requires: monthly throughput by contract, counterparty, and basin for the prior 60 months; MVC deficiency-payment history per counterparty; TOP shortfall payment history with reason codes; basis-differential time series at relevant pricing hubs (Waha, Henry Hub, Dominion South, MichCon, Chicago Citygate, plus Permian hub differentials); acreage-dedication maps with expiration calendar; and producer drilling-activity overlay. The Energy Transfer-WTG Midstream precedent — $3.25B closed July 15, 2024 per Energy Transfer IR plus BusinessWire, with $2.275B cash plus 50.8 million ET LP units consideration to Stonepeak and DiamondBack-related entities for approximately 6,000 miles of Midland Basin gas-gathering plus eight cryogenic gas-processing plants at 1.3 Bcf/d aggregate — illustrates the Permian G&P scale where the Throughput-Decay Diagnostic anchors lender credit-committee review. Peony Business at $30/admin/month ships page-level analytics tracking per-page dwell time and screenshot block attempts on the throughput contract folder, with dynamic watermarking and its version log on the Data Room plan ($52/admin/month) — exactly the audit trail term-loan-A syndicate counsel and credit-committee modelers expect.

I'm in-house compliance at a midstream acquirer reviewing the seller's PHMSA Mega Rule Phase 2 compliance, EPA Subpart OOOOb/OOOOc methane records, and GHGRP Subpart W reports — what data room exhibits are mandatory, and how do the November 26 2025 OOOOb/c deadline extensions change my buyer's pre-close remediation budget?

For your in-house compliance role at a midstream acquirer, the mandatory exhibits cover five regulatory streams (PHMSA, EPA OOOOb/OOOOc, GHGRP Subpart W, CERCLA/RCRA legacy, and state PUC plus state environmental), and the November 26, 2025 OOOOb/OOOOc deadline extension (effective December 3, 2025) moves state-plan submissions originally due March 9, 2026 to January 22, 2027 — meaning your pre-close remediation runway extends approximately 10.5 months but you can no longer use 'extension uncertainty' as a price-pad excuse. PHMSA requires the seller's annual reports (Form PHMSA F 7100.1-1 for gas distribution; 7100.2-1 for gas transmission; 7000-1.1 for hazardous liquid), incident reports (Form PHMSA F 7000-1) with the 1-hour NRC call audit trail (1-800-424-8802) plus 30-day written report for ALL incidents in the prior seven years, the May 24, 2023 Mega Rule Phase 2 ('Gas Transmission RIN2') compliance record AND the January 15, 2025 corrections following the August 16, 2024 D.C. Circuit partial vacatur in Interstate Natural Gas Association of America v. PHMSA (D.C. Cir., No. 22-1148), 49 CFR Section 192.727 abandonment records, the 60-day operator-change notification for any transfer 50 miles or longer, the Integrity Management Plan (IMP) under 49 CFR Section 192 Subpart O for gas transmission and Section 195 Subpart F for hazardous liquid, High Consequence Area (HCA) assessments plus In-Line Inspection (ILI) tool runs (typically MFL, UT, IMU, geometry), and hydrostatic test records plus spike hydrostatic test records. EPA OOOOb covers new-source performance standards for sources constructed or modified after December 6, 2022; OOOOc covers existing-source state-plan emission guidelines. The final rule was effective May 7, 2024; the November 26, 2025 announcement extended the state-plan submission deadline by approximately 10.5 months (March 9, 2026 → January 22, 2027) per EPA's November 26, 2025 final rule (effective December 3, 2025). GHGRP Subpart W (final May 6, 2024; effective for reporting year 2025; first reports due March 31, 2026) covers transmission compression, transmission pipelines, storage, and blowdown vents — your buyer's data room exhibit should include the seller's just-filed RY 2025 Subpart W submission as a standard exhibit. CERCLA and RCRA legacy covers Phase I plus Phase II ESAs for compressor stations and terminal sites, UST registrations plus leak history, and NPDES discharge permits for hydrostatic test water. The November 2025 deadline extension implication for your remediation budget: extend the assumed compliance-capex runway from the original March 9, 2026 deadline to January 22, 2027, but tighten the seller-side contingent-liability cap because the seller cannot use uncertainty as a price-pad excuse. Peony Business at $30/admin/month ships screenshot protection on desktop and mobile, with dynamic watermarks on the seller's incident-report folder available on the Data Room plan ($52/admin/month) — see the oil and gas farm-out workflow playbook for the parallel state-partner regulatory tier mechanics.

I'm corp-dev sequencing an $8B midstream merger in 2026 — how does the February 17 2026 HSR threshold of $133.9M change pre-merger filing strategy, when does the FTC Second Request risk peak for midstream deals, and what does the data room reveal about market-share overlap?

For your corp-dev role sequencing an $8B midstream merger in 2026, the HSR threshold of $133.9M effective February 17, 2026 (per FTC announcement January 14, 2026, up from $126.4M for 2025 and the original 2024 figure of $119.5M) is essentially formality at the $8B deal size — your filing is automatic — but FTC Second Request risk peaks for midstream deals where the combined post-acquisition footprint creates basin-share concentration above approximately 30 percent in Permian, Williston, or DJ. The data room must surface market-share overlap through three exhibits: a basin-by-basin pipeline-mile and processing-capacity inventory benchmarked against EIA plus FERC Form 6 aggregate data, a counterparty-overlap matrix showing the combined-firm percentage of producer customers per basin, and a tariff-history map for any FERC-regulated interstate segments where rate-base concentration could trigger Section 5 review. HSR filing thresholds adjust annually based on GNP — 2024 was $119.5M, 2025 was $126.4M, 2026 is $133.9M effective February 17, 2026. Many midstream G&P bolt-ons sit between $400M and $3B and trigger Part 803 filing automatically; FTC Second Request risk concentrates in geographically overlapping basin-share deals. The Sunoco-Parkland transaction — $9.1B (or $9.6B with debt) announced May 5, 2025 and closed October 31, 2025, where Sunoco's combined network post-acquisition includes approximately 14,000 miles of pipeline plus over 160 terminals; Parkland contributes more than 3,600 retail and convenience locations including 699 U.S. sites with Barclays and RBC Capital Markets as Sunoco's financial advisors; Goldman Sachs Canada and BofA Securities as Parkland's financial advisors; Vinson & Elkins, Weil Gotshal & Manges, Stikeman Elliott, and McCarthy Tetrault as legal advisors — is the recent $9B-plus HSR precedent that cleared without Second Request because the LP-rollup-plus-Canadian-asset structure avoided basin-share overlap concentration. The Brookfield Infrastructure-Colonial Enterprises transaction (~$9B EV / 9x EBITDA, closed August 2025, 5,500-mile refined-products pipeline Texas to NY, the largest refined-products pipeline in the U.S., consortium divestiture from Shell, Koch Capital Investments, KKR-Keats Pipeline Investors, CDPQ (La Caisse), and IFM Investors with Jefferies, Greenhill (a Mizuho affiliate), and Morgan Stanley as Brookfield financial advisors and Morgan Stanley Senior Funding plus Mizuho Bank leading debt financing) is the parallel August 2025 close that also cleared without Second Request. The Plains All American-EPIC Crude Holdings transaction ($2.9B aggregate; 55 percent from Diamondback / Kinetik for $1.57B closed October 31, 2025; 45 percent from Ares Infrastructure for $1.33B closed November 1, 2025; $193M earnout tied to ~900 kbpd capacity-expansion sanction by year-end 2027 per Plains IR; rebranded Cactus III on close) illustrates the sophisticated two-tranche structure that synthesizes around HSR sequencing across multiple sellers. Peony Data Room at $52/admin/month ships unlimited storage for the basin-share map exhibit at full resolution.

I'm a partner at an infrastructure fund running an auction divestiture of a Permian processing platform — what auction-stage data room access tiers do I open for strategic vs financial bidders, and how do the 4-Tier Midstream M&A Access Model and FERC Section 7(c) certificate-assignment timeline shape my bid milestones?

For your partner role at an infrastructure fund auctioning a Permian processing platform, the 4-Tier Midstream M&A Access Model gates documents through operator equity (Tier 1), non-operator equity (Tier 2), FERC-regulatory counsel (Tier 3), and project-finance lender plus term-loan-A lender (Tier 4) — and FERC Section 7(c) certificate-assignment timeline of 12 to 18 months for interstate transmission shapes your bid milestones such that strategic bidders typically clear Round 1 plus Round 2 in 8 to 12 weeks while lender-syndicated financial bidders need parallel Tier 4 disclosure starting at Round 1. Tier 1 (operator equity / strategic acquirer) receives the full data room — financial model, throughput-contract counterparty list, FERC tariff history, all integrity records, all ROW archive layers — with expected I-count 5/5 across all queries. Tier 2 (non-operator equity / co-investor) receives all operational and financial documents but counterparty-name-redacted contracts, with the ROW archive permitted as summary-only (statistical recording-completeness scorecard, not full document set). Tier 3 (FERC-regulatory counsel) receives the FERC Tier A-E stack (full certificate plus tariff plus Form 6 plus operational filings plus decommissioning), state PUC filings, BIA tribal documents, and eminent-domain dockets — but operational financial details and throughput-contract terms are NOT exposed at this tier. Tier 4 (project-finance lender plus term-loan-A lender) receives the financial model, throughput-contract counterparty-credit summary (counterparty-name-redacted may apply during initial round; full disclosure post-mandate-letter), FERC Form 6 plus 6-Q financial vintages, IMP plus integrity records, ROW assignability summary scorecard, and decommissioning bond plus accrual reserves. Auction-stage milestones for a Permian G&P platform — the asset class is gathering plus processing, not interstate transmission, so FERC Section 7(c) does not bite directly but HSR clearance and term-loan-A syndication still drive timeline. Round 1 (indicative bid, 4 to 6 weeks) opens Tier 1 and Tier 2 to 8 to 15 self-selected NDA-signed parties; Tier 3 opens for any bidder with FERC-regulated nominally-affected segments; Tier 4 opens at indicative-bid stage for syndication bidders. Round 2 (binding bid, 6 to 10 weeks) narrows to 3 to 6 short-list with full Tier 4 lender access. The Kinder Morgan-Outrigger Energy II transaction — $640M cash closed February 18, 2025 per Kinder Morgan / Hiland Partners and Outrigger coverage, 270 MMcf/d processing plus 104-mile rich-gas gathering in the Williston Basin, sell-side advisors Evercore (lead) and Citi with Vinson & Elkins as legal counsel, with Outrigger having been a portfolio company of NGP Energy Capital — is the recent ~$640M Williston Basin G&P precedent. Peony Data Room at $52/admin/month expresses the 4-Tier Midstream M&A Access Model through programmatic visitor groups so each tier sees their permission-isolated subfolder without manual permission resets — see the oil and gas farm-out data room for the parallel 4-tier farm-out access model.

I'm regulatory counsel reviewing a bid for a 60-year-old gas-transmission system — how does Decommissioning-Bond Gating work under 49 CFR Section 192.727 plus state PUC requirements, and what evidence of accruals plus bonds plus abandonment-cost reserves must the seller produce in the data room?

For your regulatory counsel role on a 60-year-old gas-transmission bid, Decommissioning-Bond Gating works through 49 CFR Section 192.727 federal abandonment authorization plus state PUC concurrent jurisdiction plus FERC abandonment under NGA Section 7(c), and the seller's data room must produce four evidence categories — historical abandonment authorizations, accrual ledgers, bond and letter-of-credit posting evidence, and abandonment-cost-reserve calculation methodology. Decommissioning-Bond Gating is the diagnostic frame for whether the seller has properly funded end-of-life liability across the federal-state regulatory stack — a different statutory regime from upstream UKCS NSTA decommissioning under the Petroleum Act 1998 Section 29 / Section 32 covered in the upstream divestiture deep-dive, but applying the same conceptual bond-gating discipline. Category one, historical abandonment authorizations: every 49 CFR Section 192.727 authorization granted to the seller for retired or partially retired segments, every state PUC abandonment filing where state retains concurrent authority on intrastate segments, every FERC Section 7(c) abandonment certificate where applicable to interstate segments, and the corresponding 60-day operator-change notification to PHMSA for transfers 50 miles or longer. Category two, accrual ledgers: the seller's GAAP-basis abandonment accrual schedule, the supporting actuarial calculations (typical assumptions: discount rate, inflation, segment-by-segment retirement timing), and the cumulative balance against expected end-of-life cost. Category three, bond and letter-of-credit posting: state PUC bond requirements where applicable (Texas, California, Pennsylvania, North Dakota) and the seller's posted financial assurance instruments. Category four, abandonment-cost-reserve calculation methodology: segment-by-segment retirement-cost estimates, the seller's third-party engineering review (typically by a PHMSA-experienced engineering firm), and the reconciliation against booked accrual. The decommissioning-bond-gating mechanic for the lender: term-loan-A lenders require Decommissioning-Bond Gating evidence at Tier 4 access before credit-committee approval — without adequate bond posting plus accrual coverage, the asset-level financing is non-recourse-impaired. State PUC interplay matters because state PUC concurrent jurisdiction can require additional bonding above and beyond federal 49 CFR Section 192.727 minimums — particularly in California where CPUC review of intrastate segments runs parallel to FERC review of interstate. The DT Midstream-ONEOK 3 Pipelines transaction (Guardian Pipeline plus Midwestern Gas Transmission plus Viking Gas Transmission, $1.2B cash, closed December 31, 2024 per DT Midstream IR plus 8-K filing) is the recent precedent for FERC Section 7(c) certificate-amendment plus parallel state PUC review on multi-state interstate transmission assignment. Peony Data Room at $52/admin/month ships NDA gates plus page-level analytics preserving the audit trail across the 60 to 180 day Decommissioning-Bond Gating review.

I'm watching the Energy Transfer-WTG Midstream $3.25B close in July 2024, the ONEOK-EnLink final close in January 2025, the Sunoco-NuStar $7.3B close in May 2024, and Sunoco-Parkland $9.1B close in October 2025 — what does the comparative documentation timing reveal about HSR / FERC sequencing, and which deal archetype best matches a $1-3B G&P bolt-on?

For your role watching the four deals, the comparative documentation timing reveals that HSR-only deals (gathering plus processing, no interstate transmission) close 4 to 8 weeks faster than FERC plus HSR deals (interstate transmission), MLP-rollup precedents compress the documentation timeline meaningfully, and the closest archetype for a $1-3B G&P bolt-on is Energy Transfer-WTG Midstream. Energy Transfer-WTG Midstream — $3.25B announced May 28, 2024 and closed July 15, 2024 per Energy Transfer IR plus BusinessWire, $2.275B cash plus 50.8M ET LP units to Stonepeak and DiamondBack-related entities, ~6,000 miles of Midland Basin gas-gathering plus eight cryogenic gas-processing plants at 1.3 Bcf/d aggregate, BofA on Energy Transfer side and Jefferies on WTG side as lead financial advisors with Sidley Austin as WTG legal counsel, HSR cleared — is the cleanest G&P-only HSR precedent at $3B-plus scale. ONEOK-EnLink Midstream — $4.3B all-stock final close completed January 31, 2025, where ONEOK acquired controlling-interest stake from Global Infrastructure Partners on October 15, 2024 ($3.3B for ~43% LP interest plus 100% GP), then closed remaining publicly-held units via merger January 31, 2025, with Goldman Sachs (ONEOK), Citi (EnLink), and Evercore (special committee) as lead advisors, HSR cleared with no FERC issues since EnLink is gathering plus processing not interstate transmission — is the multi-tranche staged-close archetype. Sunoco-NuStar — $7.3B all-equity announced January 22, 2024, HSR cleared April 9, 2024, closed May 3, 2024 — is the boundary recency-anchor (~24 months as of May 8, 2026) and the precedent for the 2024-25 MLP-rollup wave that culminated in Sunoco-Parkland. Sunoco-Parkland — $9.1B (or $9.6B with debt) announced May 5, 2025 and closed October 31, 2025, with Sunoco IPO'ing SUNC on November 6, 2025 to capture strategic-tax-restructuring upside, Barclays and RBC Capital Markets as Sunoco's financial advisors; Goldman Sachs Canada and BofA Securities as Parkland's financial advisors; Vinson & Elkins, Weil Gotshal & Manges, Stikeman Elliott, and McCarthy Tetrault as legal advisors, HSR cleared, CFIUS not implicated — is the largest recent MLP-rollup precedent. For a $1-3B G&P bolt-on the closest archetype is Energy Transfer-WTG Midstream because it's pure G&P at Permian scale with HSR-only timeline; if the $1-3B target carries any FERC-regulated interstate transmission, DT Midstream-ONEOK 3 Pipelines ($1.2B closed December 31, 2024) is the cleaner archetype because it tests the full FERC Section 7(c) certificate-amendment plus HSR sequence. Peony Data Room at $52/admin/month handles the 200 to 400 GB Phase II archive for either archetype with unlimited storage — see the oil and gas data room cluster anchor for the platform comparison.

I'm running the midstream data room procurement decision for a $2-5B acquisition with 200-300 GB of ROW plus integrity plus throughput data — how does Peony Data Room at $52/admin/month flat compare to Datasite per-page pricing on a 14-month FERC-certificate-amendment plus HSR-second-request timeline, and what features (visitor groups, watermarks, NDA gates, screenshot protection) actually map to the 4-Tier Midstream M&A Access Model?

For your procurement decision on a $2-5B midstream acquisition with 200-300 GB of ROW plus integrity plus throughput data across a 14-month timeline, Peony Data Room at $52/admin/month flat runs $4,368 total for 6 admins across 14 months versus Datasite per-page billing at $0.40-$1.00 per page (Capterra-aggregated buyer data, 2026; G2; Vendr; Papermark) which on a 200-300 GB Phase II archive rendering at 200,000-plus pages generates six-figure invoices on the bid-evaluation cycle alone — and the four features map directly to the 4-Tier Midstream M&A Access Model as follows: visitor groups equal four-tier permission isolation, dynamic watermarks equal bidder-name-plus-timestamp-plus-page-position embedding, NDA gates equal the seismic-equivalent gating for the 30,000-plus easement archive, and screenshot protection equals counterparty-credit redaction enforcement. The Seller's Midstream Data Room Platform Diagnostic Test scores eight questions: question one, can the platform handle 200-300-plus GB total upload with single-file limits above 10GB for raw seismic and pipeline-survey datasets — Peony unlimited, Datasite 10GB single-file plus zip up to 50GB per Datasite FAQ, Intralinks 25GB single-file across US/Germany/Australia per Intralinks release notes, Firmex 10GB drag-and-drop, Box Enterprise Advanced 500GB single-file (largest in market) but ships zero NDA gates plus dynamic watermarks plus screenshot protection so fails outright. Question two, can NDA gate logic enforce per-tier access (4-Tier Midstream M&A Access Model: operator equity, non-operator equity, FERC counsel, lender) — Peony NDA gates yes, Datasite enterprise yes, Intralinks enterprise yes, Box no. Question three, can watermarks dynamically embed bidder-name plus timestamp plus page-position — Peony dynamic watermarks yes, Datasite enterprise yes, Intralinks enterprise yes, Box no. Question four, does pricing scale flat or per-page — Peony Data Room $52/admin/month flat, Datasite $0.40-$1.00 per page rendered, Intralinks custom-quoted $25,000-$80,000 per deal at enterprise tier. Question five, can analytics surface 5-second-page-view filtering to detect tire-kicker counterparties — Peony page-level analytics yes per-page dwell time, Datasite yes, Intralinks yes. Question six (midstream-specific), can the platform support segregated regulatory tier (FERC plus state PUC plus tribal plus BIA plus USACE) with each sub-folder permission-isolated for outside regulatory counsel only — Peony visitor groups yes through programmatic permission, Datasite yes via permission groups at enterprise tier. Question seven (midstream-specific), does the throughput-contract folder support per-counterparty subfolder permissioning so customer A cannot see customer B's contract terms during cross-check — Peony yes through visitor groups, Datasite yes via permission groups, Intralinks yes. Question eight (midstream-specific), can the platform handle ZIP-stream uploads of 30,000-plus individual title documents without chunking, with inline preview of recorded instruments — Peony yes (no per-file cap, chunked parallel transfers with global CDN), Datasite force splits, Intralinks force splits at the larger end. A platform scoring below 6/8 on this test is unsuitable for a midstream M&A data room above $1B; below $500M, scoring 5/8 is acceptable; below $100M, 4/8. Peony Data Room scores 8/8 on this test. Cost wedge math at 6 admins for 14 months: Peony $4,368 flat versus Datasite $25,000-$80,000-plus per deal at enterprise tier per Capterra/G2/Vendr/Papermark 2026 buyer data — a 6x to 18x cost gap on data-heavy Phase II workflows that gets worse as ROW-archive document mass scales.

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Related resources

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• LNG Project Finance Data Room: FEED→FID Escalation + ECA Debt Pack (2026) — the LNG project-finance deep dive
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