01The deal in one paragraph

On February 27, 2026, Equinix and Canada Pension Plan Investment Board announced a joint agreement to acquire Nordic data centre operator atNorth from Partners Group for an EV of US$4 billion. CPP Investments holds a 60 percent controlling stake; Equinix takes 40 percent as the strategic operating partner. Per Equinix’s disclosure, atNorth brings eight operational sites, an active development pipeline of approximately 800 MW expected over the next five years, and an additional 1 GW of secured power beyond that pipeline. The transaction is funded via a US$4.2 billion financing package and is expected to be immediately accretive to Equinix’s AFFO per share on close. Subject to regulatory approvals; expected close in second half 2026.

02Why this deal matters

This deal matters for three overlapping reasons. It is first a template for how PE-owned digital infrastructure gets transitioned during sponsor exit windows: Partners Group needed an exit, Equinix wanted the operating footprint without shareholder-dilutive capital, CPP could supply the capital duration Equinix could not, and pairing the two produced a bid Partners Group could accept. Expect the shape to recur through 2026-2027 as DigitalBridge, IPI, Blackstone, and KKR-owned platforms reach exit maturity. Beyond the structure, roughly 800 MW of active development pipeline plus an additional 1 GW of secured Nordic power across eight sites is a scarce asset in an interconnection-constrained market, and grid interconnection status per site (the workstream most acquirers under-weight) is where a lot of the strategic value in this transaction actually sits. The third reason is narrower and mostly technical: the immediate-accretion claim on Equinix’s AFFO is a specific representation that DD needs to check against a DD-normalised EBITDA walk rather than take from the CIM.

What Equinix specifically brings to the joint venture, beyond capital, is Platform Equinix and xScale: a global interconnection ecosystem with cloud on-ramps, network cross-connects, dense fabric routing, and existing hyperscaler qualification status across every named tier-one customer, plus the xScale product line built for hyperscale-scale colocation contracts (originally structured as a JV with GIC). Neither is available to a standalone Nordic operator. Plugging atNorth capacity into Platform Equinix commands premium pricing versus generic Nordic wholesale colocation, reduces the change-of-control re-qualification friction that a financial-buyer-only take-out would face, and accelerates hyperscaler pre-leasing on the 800 MW pipeline. That strategic uplift is the case for Equinix’s 40 percent stake, and it is what CPP as a pure financial owner cannot supply.

03What I would test first

If a sponsor asked me to scope commercial DD on this platform. Or if I were on the Equinix side testing the acquirer’s own thesis before signing. Here is my first-90-minute test list, ranked by risk-weighted urgency.

1. Grid interconnection status per site (Regulatory + Manufacturing, DD Part XI + Part VI). Equinix’s disclosure separates ~800 MW of active development pipeline from an additional 1 GW of secured power beyond the pipeline. The DD test on each: for the pipeline, how much has a signed ISA versus land-only positions; for the secured 1 GW, how much is energised and drawing versus contracted-not-yet-energised versus optioned. Nordic queues (particularly in Sweden, Denmark, Norway) have tightened over the past three years, though 2026 has shown early signs of improvement in Sweden following Svenska kraftnät process reforms. An 800 MW pipeline that is 70 percent permit-ready with signed ISAs is a different asset from one that is 30 percent shovel-ready.
2. Customer concentration and CoC exposure (Customer DD, DD Part IV). Nordic data centre customers skew hyperscaler and crypto-mining. Both segments carry specific risks. Hyperscaler contracts often carry change-of-control termination rights that can accelerate if the acquirer is unable to inherit the qualification status. Crypto customers carry price sensitivity to power cost movements and payment-cycle risk in downturns. Test: what percentage of trailing revenue and contracted future revenue is (a) hyperscaler subject to CoC review, (b) crypto or high-density compute, (c) enterprise colocation. The mix determines the risk-adjusted revenue base.
3. PPA and power-cost structure by bidding zone (Legal + Capex, DD Part X + Part VIII). Nordic power markets are not monolithic. Northern hydro-surplus zones (SE1, SE2, NO3, NO4) and Iceland’s isolated geothermal grid clear at roughly €15-40/MWh through most of the recent cycle. Southern demand zones (SE3, SE4, NO1, DK1, DK2) saw wholesale prices spike into €80-150/MWh territory in 2022-2024. atNorth’s siting concentrates in the cheap-power zones (Iceland, northern Sweden), which is the platform’s underlying cost-of-electricity advantage. Legacy 2018-2022 PPAs at those zone prices sit at very different rates from PPAs available now. Test: PPA book by counterparty, bidding zone, tenor, and price; mark-to-market against the specific zone benchmarks; roll-off schedule; and merchant-market exposure in the specific zones each site draws from.
4. QoE walk on Partners Group-managed EBITDA (QoE, DD Part VII). Sellers preparing for exit optimise EBITDA presentation. PE-owned targets in a competitive process routinely present CIM EBITDA that requires 8-15 percent normalisation to reach DD-defensible figures across the category. Add-back categories typical for data centre platforms: fit-out costs miscategorised as expense, capitalised interest treatment, stock-based compensation, and one-time facility commissioning costs. Test: full add-back walk. The atNorth-specific number depends on the QoE outputs; the category benchmark says a 5-10 percent adjustment range is where the walk typically lands, and the DD budget should be sized against that expectation rather than against the CIM headline.
5. Development pipeline realism (Capex + Product, DD Part VIII + Part V). The “several developments” language covers a range from “shovel-ready with signed customer LOIs” to “land option with concept design.” The valuation likely embeds pipeline value. Test: for each development site, what is the permit status, customer commitment, capex schedule, and power interconnection status? Discount aggressively where any of the four is missing.
6. Joint acquisition governance mechanics (Structure, DD Part XII). CPP 60 percent + Equinix 40 percent is a controlling+strategic structure that only works if the shareholder agreement is precisely drafted. Test: exit rights (tag/drag), buyout mechanics on Equinix if operating performance disappoints, capital call obligations, board composition, tie-breaker on capex authorisation. Bad drafting here creates the year-3 dispute that consumes management attention.
7. EU regulatory approvals for a Canadian majority buyer (Regulatory, DD Part XI). CPP Investments is a Canadian pension fund taking control of a critical-infrastructure asset in multiple EU jurisdictions. EU FDI screening applies in Denmark, Sweden, Iceland, and potentially Norway depending on site locations. Timeline exposure: 3-9 months per jurisdiction, potentially requiring undertakings. Test: which jurisdictions have signed off, which are pending, and what is the fallback if any block?
8. Financing structure and refinance exposure (Financing, DD Part XIII). The $4.2B financing package is larger than the $4B EV, implying some transaction costs and possibly a revolver capacity buffer. Test: term loan sizing vs DD-normalised EBITDA, coupon, tenor, covenant package, and refinance date. A 2029 refinance in a compressed European private credit market with tightening covenant regimes is a different exposure than a 2030 refinance at a rate that has come down.
9. Platform Equinix strategic-commitment durability (Structure + Product, DD Part XII + Part V). If atNorth’s post-close value uplift depends on plugging into Platform Equinix and xScale. And per Section 02 it does, that is the strategic rationale for the 40 percent stake. The DD needs to understand how durable that integration commitment is under future Equinix leadership, strategy shifts, or portfolio rationalisation. Test: what is the contractual guarantee on the integration commitment (network peering, cross-connect enablement, cloud on-ramp access, xScale product roadmap alignment), what is the buyout mechanism if Equinix later exits the strategic partner role, and how does CPP protect against becoming the majority financial owner of a de-networked Nordic colocation platform if Equinix’s priorities move? This is a novel workstream this structure creates.

04Questions I would want answered

• What is the decomposition of “1 GW+ secured power” between energised, contracted-not-energised, and queue-application-stage?
• What is the customer mix by segment (hyperscaler, crypto, enterprise colocation, other) as percent of TTM revenue and percent of contracted future revenue?
• Which top-10 customer contracts contain change-of-control termination rights?
• What is the PPA book by counterparty, tenor, price, and roll-off schedule?
• What was the CIM-adjusted EBITDA and what is the DD-normalised figure after add-back scrutiny?
• For each development site: permit status, customer LOI or contract, capex committed vs authorised, power interconnection status?
• What are the governance mechanics between CPP and Equinix. Specifically buyout triggers, capex authorisation thresholds, and exit provisions?
• Which EU FDI screening regimes have been notified, and what is the timeline?
• What is the financing package structure and 2029 refinance covenant risk?
• What is Partners Group’s post-close involvement (rollover, transition services, non-competes)?

05What I would flag

Most of the $4B EV is being paid for what atNorth has already secured on the utility side. In Nordic markets where interconnection currently runs three years or more in the most-constrained southern zones (though Svenska kraftnät recently reported roughly a 30 percent reduction in preliminary-assessment lead times), a portfolio of ~800 MW of active pipeline plus an additional 1 GW of secured power is a scarcity position that is genuinely difficult to replicate. The DD needs to decompose both figures separately. For the 800 MW pipeline: what percent has a signed interconnection service agreement, what percent is permit-in-progress, what percent is land option only. For the additional 1 GW: what percent is energised and drawing today, what percent is contracted-not-yet-energised, what percent is queue-application-stage. The state distribution at Nordic zone-specific power and colocation pricing swings the DD-defensible value of the platform by several hundred million dollars.

The immediate-AFFO accretion Equinix has guided to is worth stress-testing as a second flag. Equinix takes a 40 percent equity-method stake, and the accretion depends on how the joint venture is consolidated, what intercompany pricing applies on the colocation-services relationship between Equinix and atNorth, and how much operating uplift Equinix embeds from Platform Equinix integration. A DD-normalised version of the accretion calculation may sit below the guidance number, may match it, or may exceed it depending on how those three inputs land; the point is that the DD should build the walk from first principles rather than accept the accretion representation on face.

The third flag is governance. Joint sponsor-plus-strategic acquisitions like this one tend to strain three or four years in, and the strain is almost always capital allocation. A majority financial owner like CPP is running the platform for stable cash yield to service its beneficiaries. A strategic operator like Equinix wants growth capex to fund customer acquisition and route optionality. Both are defensible positions and both can be accommodated at signing when interests happen to align around growth. They diverge under pressure. A bad year on hyperscaler bookings, a Nordic power-price shock, a permitting delay on a major site. And the party holding the tie-breaker vote on capex authorisation determines what the platform actually does. That clause is the piece of the joint venture agreement that most matters for how the platform performs from year three onwards, and it is nearly impossible to renegotiate once the platform is under stress.

06What the market is getting right, and what it is getting wrong

The market has read this deal correctly as a scarcity-asset acquisition rather than a growth-story acquisition, which explains why trading multiples on it are broadly in line with recent comparable Nordic transactions on a per-MW basis. That much is well-priced. Two parts of the coverage are missing what actually matters, though. The renewable-power branding, where most of the reporting sits, is real but secondary; the deal is more usefully read as the template for how PE-owned digital infrastructure gets transitioned through sponsor exit windows into joint sponsor-plus-strategic hands, and it will be studied inside every DigitalBridge, IPI, Stonepeak, and Blackstone platform reaching year-five maturity over the next eighteen months. Separately, change-of-control exposure on the hyperscaler contract book is being under-covered in the analyst notes I have read, though the coverage that does exist tends to over-weight the risk. Hyperscaler procurement teams do re-qualify colocation providers on change of control, but the standard DD stress case (which for a comparable financial-buyer-only take-out I would size at five to fifteen percent of revenue over the two years post-close) narrows here because Equinix already sits on the approved-vendor lists at every named tier-one hyperscaler. The Platform Equinix qualification status is one of the reasons Equinix rather than a generic operator is the strategic partner on this deal.

07Structural insight

Joint sponsor-plus-strategic acquisitions like this one are going to be a common shape for large digital infrastructure deals over the next two to three years, for the simple reason that neither side can do the deal alone. Strategic operators like Equinix, Digital Realty, GDS, and NTT cannot fund 1-to-5 GW-scale platform take-outs from their own balance sheets without shareholder dilution that public equity holders will not accept. Pure financial sponsors like Blackstone, KKR, CPP, and Brookfield have the capital duration but need operating expertise to run these assets after close. Pairing the two solves both problems, so this shape recurs. For anyone running commercial DD on a digital infrastructure transaction over the next year, the practical implication for the workplan is that joint-acquisition governance mechanics, which have historically been treated as a legal-team item late in Stage 4, should move into the commercial DD scope in Stage 2. The operating alignment between the two owners is what determines whether the platform performs after close. The fourteen-workstream DD framework I used on Eaton/Boyd applies here almost unchanged; the weightings shift toward regulatory (EU FDI screening), structure (joint-acquisition governance mechanics), and grid interconnection (asset scarcity as the primary value driver).