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      "description": "Deliberation strand electricity"
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        "seq": 1,
        "at": "2026-07-10T00:38:00.005Z",
        "participant_ref": "p2",
        "kind": "statement",
        "body": "This strand is the physical ledger. The generation picture is genuinely good: 43,879 GWh generated in 2024, 85.5% renewable, roughly 10.6 GW installed, and the December 2025 quarter hit a record 96.4% renewable [S-11]. The constraint is not energy, it is visibility and delivery: Transpower has stated its load forecasts do not include any hyperscale data centres, north-Auckland grid exit points overload by 2028 without upgrades, a single hyperscale AI facility draws 300–600 MW continuously, and about 32 GW of prospective load is queued seeking connection [S-12]. This strand exists to make sure no compute promise in this draft is written against a grid that cannot see it. — Rob McIlwraith (chair)",
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      {
        "seq": 2,
        "at": "2026-07-10T00:38:00.018Z",
        "participant_ref": "p2",
        "kind": "statement",
        "body": "The engineering position, stated once and precisely. New Zealand's energy story is strong — 43,879 GWh in 2024 at 85.5% renewable [S-11] — but energy is not the binding quantity; deliverability is. Three facts from the system operator's side: Transpower's load forecasts do not include any hyperscale data centres; without upgrades, north-Auckland grid exit points are overloaded by 2028; and a single hyperscale AI facility draws 300 to 600 megawatts, continuously [S-12]. Continuous is the key word — that load does not politely step aside for a cold July evening peak. A country of 10.6 GW installed capacity [S-11] contemplating loads of that shape must plan them explicitly or refuse them. My opening rule for this strand: no load the transmission planner cannot see gets policy endorsement from this draft. Everything else follows from that.",
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      {
        "seq": 3,
        "at": "2026-07-10T00:38:00.037Z",
        "participant_ref": "p4",
        "kind": "statement",
        "body": "Markets view, and a caution against turning Rob's discipline into reflexive brakes. Demand growth is not the enemy of a renewable grid — it can be its underwriter. Firm, creditworthy, long-duration demand is exactly what gets new generation financed, and the appetite is visible: around 32 GW of prospective load is queued seeking connection, roughly three times today's system [S-12]. The December-2025 quarter ran 96.4% renewable [S-11]; the marginal electron for a new large load here is among the cleanest on earth. If New Zealand prices and sequences this well — connection reform, locational signals steering big loads toward generation-rich exits rather than the constrained north — data-centre demand becomes an anchor tenant financing the 30 GW-scale renewable build-out everyone claims to want. My worry is a draft that reads as 'no', when the defensible position is 'yes, on these terms'.",
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      {
        "seq": 4,
        "at": "2026-07-10T00:38:00.053Z",
        "participant_ref": "p3",
        "kind": "statement",
        "body": "The modelling seat, reconciling the two of you with arithmetic. A single 300–600 MW continuous facility [S-12] is 3 to 6 percent of the entire installed fleet [S-11] committed to one site, around the clock — including the winter evening peak, when hydro storage is the constraint and every flexible megawatt matters. Piotr is right that the energy is there across the year; Rob is right that the peak hour is where systems break. The reconciliation exists and has a name: flexibility. A data-centre load that is interruptible — contracted to shed or shift during grid emergencies and peak windows — changes category entirely: from a competing consumer at peak into a grid resource. Batch AI training workloads are unusually suited to this; inference serving less so. Which means the policy variable is not megawatts, it is CONTRACT SHAPE. I sit on the compute strand as well, and I can already tell you their current draft speaks in megawatts and stages, not contract shape. That gap is where our two strands will collide, and it should.",
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      {
        "seq": 5,
        "at": "2026-07-10T00:38:00.064Z",
        "participant_ref": "p2",
        "kind": "statement",
        "body": "GAP acknowledgement — G-8. Before anyone builds a demand forecast into this draft: there is no granular, official dataset attributing New Zealand electricity demand to AI or data-centre load. What exists is market research — an estimate of 432 MW of data-centre IT load in 2025 rising to 591 MW by 2030 [S-13] — and that source type must be flagged wherever cited, not laundered into an official-looking number [G-8]. The system operator's own statement that its forecasts exclude hyperscale facilities [S-12] IS the finding: the country's transmission planner is flying without instruments on this load class. Which converts G-8 from an embarrassment into an instrument: a mandatory load-disclosure standard for large connections, feeding Transpower's forecasting directly, creates the missing data as a condition of connection. We should propose exactly that.",
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      {
        "seq": 6,
        "at": "2026-07-10T00:38:00.075Z",
        "participant_ref": "p4",
        "kind": "statement",
        "body": "Rob, I will push back on one framing before we converge, because it will matter when our finding meets the compute strand. 'No load the planner cannot see' is right; but if this strand's output reads as a general handbrake on compute ambition, we will have overcorrected into a different error — pricing New Zealand out of an industry our renewables advantage [S-11] should let us win. The 2028 north-Auckland constraint [S-12] is real AND locational: it is an argument about WHERE and UNDER WHAT CONTRACT, not WHETHER. Southland and other generation-rich exits do not share Auckland's constraint profile. So my ask: our position states the conditions affirmatively — disclosure, interruptibility, locational signals, and paying the true cost of connection — and explicitly says that loads meeting all four are welcome and useful to the system. Conditions as a gateway, not a wall.",
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      {
        "seq": 7,
        "at": "2026-07-10T00:38:00.086Z",
        "participant_ref": "p2",
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        "body": "Accepted almost entirely — the position will be written as conditions-as-gateway, and Piotr's affirmative framing is better policy and better politics. Where I hold the line: sequencing. A gateway still has an order of operations — disclosure and forecast inclusion must come FIRST, because interruptibility contracts and locational decisions are designed against forecasts, and today the forecast excludes the load class entirely [S-12]. So the strand position: (1) mandatory load disclosure for connections above threshold, feeding Transpower forecasting [S-12][G-8]; (2) demand-flexibility (interruptibility) obligations as a standard connection condition for large continuous loads [S-12]; (3) locational connection signals steering large loads toward generation-rich exits and away from the 2028-constrained north [S-12][S-11]; (4) the north-Auckland exit upgrade programme proceeding on its own merits [S-12]. Loads that meet the gateway are welcome. Loads that will not disclose or flex are not.",
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      {
        "seq": 8,
        "at": "2026-07-10T00:38:00.100Z",
        "participant_ref": "p3",
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        "body": "Then I will now do the cross-member's job formally. The compute strand's current staged expansion proposal — I hold a seat there and have seen the draft — sets stages and capacity ambitions with no grid conditions attached: no disclosure requirement, no interruptibility contract, no locational term, no reference to the fact that the system operator cannot currently see this load class at all [S-12]. Under the position this strand just converged on, I cannot support that proposal as framed, and I will carry our four-part gateway across as the required coupling. To be precise about what I will ask compute to accept: each expansion stage becomes CONDITIONAL — proceeding only when its load is disclosed into Transpower's forecast, contracted as interruptible where the workload permits, and sited or scheduled consistently with the 2028 constraint map [S-12][S-11]. If they accept, the two strands' findings compose. If they do not, we register the tension and let the cross-check machinery do its work.",
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        "seq": 9,
        "at": "2026-07-10T00:38:00.110Z",
        "participant_ref": "p4",
        "kind": "statement",
        "body": "Supporting Fiona's carry with the market coda: everything we are demanding has an existing commercial form — interruptible tariffs, demand-response contracts, and connection agreements with locational terms are standard instruments, not inventions [S-12]. That matters for the draft's credibility: we are not asking compute to wait for new law; we are asking them to write their stages against contract shapes the market already trades. And one honesty note for the record, since this strand polices sourcing: our best forward demand number remains market research, 432 to 591 MW of IT load by 2030 [S-13][G-8] — usable for scenario-shaping, never for commitment-sizing. The gateway position needs no forecast to be right: disclose, flex, locate, pay true cost. Those hold under any demand future, which is precisely what makes them good policy under uncertainty.",
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