The Clearwater King — and the Spinout That Comes With It

Headwater Exploration (HWX-TSX) merges with Tamarack Valley (TVE-TSX), and a new company called Tributary falls out the bottom

Me and my new best friend Claude give you the facts and the story.

A retail investor report — September 12, 2026

 

WHAT’S INSIDE

Part 1 — The new Tamarack Valley, in bullets

Part 2 — Tributary Exploration, in bullets

Part 3 — The story: how a play nobody wanted built a $10 billion company

Part 4 — Tributary Exploration: the fourth act

Part 5 — When does this happen?

 

PART 1 — THE NEW TAMARACK VALLEY, IN BULLETS
All figures in Canadian dollars unless noted.

 

Who runs it 

•   Steve Buytels becomes President and CEO effective January 1, 2027. He joined Tamarack in March 2020 as CFO and was promoted to President in July 2025.

•   Brian Schmidt, Tamarack’s founding CEO since August 2009, moves up to Executive Chairman on the same date.

•   Jason Jaskela — Headwater’s CEO — joins the Tamarack board at closing, along with one more Headwater nominee agreed to by Tamarack.

•   Everything else is Tamarack. Tamarack’s name, Tamarack’s ticker (TVE), Tamarack’s head office in Calgary. Headwater’s management team does not run this company. They leave, and they take the spinout with them.

•   Directors and officers of Headwater who roll into TVE will hold about 2% of the combined shares, and they are locked up: one third free at three months after close, one third at six, one third at nine.

 

Share structure 

•   Headwater shareholders receive 1.0 Tamarack share for each Headwater share. No cash, no premium, no collar.

•   Tamarack issues 237.8 million new shares to buy all of Headwater.

•   Roughly 711 million shares outstanding after close — up from about 474 million today.

•   Ownership splits 66.5% Tamarack / 33.5% Headwater.

•   Deal value: $10 billion, as the companies describe the combined entity. On my math, 711 million shares at $13.54 is a market cap of about $9.6 billion.

 

Production 

•   Run-rate pro forma Clearwater production of more than 80,000 boe/d. That is 94% crude oil and 6% gas and NGLs.

•   2026 full-year pro forma guidance: 65,500–67,500 boe/d, a 7% bump over Tamarack’s prior guidance, assuming a mid-Q4 close.

•   Q4 2026 guidance alone: 70,000–72,000 boe/d.

•   Growth target of 10–12% per year through the five-year plan — raised from Tamarack’s standalone 8–10%, and above Headwater’s standalone ~10%.

•   2027 corporate decline rate drops to 15%, helped by waterflood outperformance at both companies.

•   One Canadian broker models 88,836 boe/d in 2027 and 98,049 boe/d in 2028 — they expect the company to cross 100,000 boe/d during 2028.

•   Land and inventory: more than 1,500 sections across the greater Clearwater fairway, more than 300 million boe of proved-plus-probable reserves, and more than 3,000 identified drilling locations. At 80,000 boe/d, 300 million boe of 2P is about 10 years of reserve life (my math).

 

Cash flow — gross and per share 

•   2026 estimate: $911 million of funds flow, or $1.79 per fully diluted share

•   2027 estimate: $1,210 million of funds flow, or $1.74 per fully diluted share

•   2028 estimate: $1,175 million, or $1.74 per share

•   Capital spending of $600–650 million per year under the five-year plan.

•   That leaves roughly $591 million of free funds flow in 2027 — about $0.85 per share on 693.7 million diluted 2027 share count, or $0.83 on the full 711 million (my math: 2027 funds flow less 2027 capex).

•   The deal is expected to be more than 10% accretive to Tamarack’s free funds flow per share in year one.

•   Free funds flow breakeven of US$37/bbl WTI, unhedged, after paying the higher dividend and sustaining capital.

•   Synergies of more than $50 million a year, and more than $350 million over the development plan. In the first $50 million, there’s $20 million of corporate cost cuts, $15 million of capital efficiency gains, and $15 million of better netbacks from opex, transport and marketing.

 

Debt 

•   Gross debt of roughly $300 million at close.

•   Net cash of more than $50 million — cash and receivables exceed the debt.

•   Available funding of more than $1.2 billion, including a fully undrawn $875 million credit facility that does not mature until May 2030.

•   Context on how fast Tamarack fixed its balance sheet: ATB shows year-end 2025 net debt of $686 million turning into net cash of $133 million by September 2026, funded largely by the $804 million Charlie Lake sale, announced in May 2026 and closed that June.

 

Valuation — EV/EBITDA 

•   Enterprise value of roughly $9.6 billion (my math: ~711 million shares at $13.54, less $50 million of net cash — at this size the net cash barely moves the number).

•   EV to debt-adjusted cash flow of 8.0x for 2026, 7.7x for 2027, and 7.6x for 2028 (ATB). ATB publishes DACF rather than EBITDA for Tamarack; the two are close here because the company carries almost no interest expense. On my own math at $13.54, 2027 works out near 7.9x.

•   What Tamarack is paying for Headwater: about $121,000 per flowing boe/d, about 7.8x 2027 cash flow, about 2.9x the value of proved developed producing reserves, and 149% of proved-plus-probable NPV10 (ATB).

•   Price targets: $16.50 on TVE, raised from $15.00 on the news, and $17.00 on HWX. Net asset value math gives $16.28 per share on a risked basis and $20.17 unrisked.

•   Most large firms have not published fresh targets. National Bank, RBC and CIBC are advising Tamarack, BMO is advising Headwater’s independent committee, and Peters & Co. is Headwater’s exclusive advisor — so several of the shops you would most want to hear from are restricted while the deal is live.

 

Dividend per share 

•   $0.06 per share per quarter, or $0.24 per year, starting December 2026 — a 20% raise, contingent on the deal closing.

•   That is a yield of about 1.8% at $13.54 (my math).

•   This is Tamarack’s second raise of 2026. It went from $0.04 to $0.05 in June after the Charlie Lake sale.

•   The annual dividend bill is about $171 million against roughly $591 million of 2027 free funds flow — a payout near 29% (my math). That’s a lot of room.

•   Read this part carefully if you own HWX. Headwater pays $0.12 a quarter today — $0.48 a year, a 3.5% yield. You are trading into a stock that pays $0.24. Your dividend income gets cut in half.

 

PART 2 — TRIBUTARY EXPLORATION, IN BULLETS
Tributary Exploration Inc. is the new company that gets spun out at closing. Every figure below is before the planned 5-for-1 share consolidation unless I say otherwise.

 

Who runs it 

•   Neil Roszell, P.Eng. — Executive Chairman. He founded Headwater, Raging River and Wild Stream.

•   Jason Jaskela, P.Eng. — President, CEO and Director. He founded Headwater and was COO and a founder of Raging River.

•   Ali Horvath — CFO. Terry Danku — VP Corporate Planning. Brad Christman — VP Operations. Georgia Little — VP Finance. Scott Rideout — VP Land. Dieter Deines — VP Exploration. Jeff Magee — VP Engineering. Wade Hein — VP Production.

•   Board: Kevin Olson, Chandra Henry, Stephen Larke, Kam Sandhar and Cheree Stephenson — all current Headwater directors.

•   In plain English: the entire Headwater team walks across the street into a company with a $150 million market value at the deemed price. That is the whole idea.

 

How many shares you get 

•   If you own TVE: 0.33 Tributary shares for every Tamarack share you hold.

•   If you own HWX: 0.33 Tributary shares for every Headwater share you hold, PLUS 0.20 of an arrangement warrant per Headwater share.

•   Each whole arrangement warrant buys one Tributary share at $0.42 — the deemed net asset value — and it expires 60 days after closing. Use it or lose it.

•   237.8 million shares are issued at close: 158.1 million to Tamarack holders (66.5%) and 79.7 million to Headwater holders (33.5%).

•   If every arrangement warrant gets exercised, the split shifts to 55.4% Tamarack / 44.6% Headwater. That warrant is the only real premium Headwater shareholders receive in this deal.

•   After the planned 5-for-1 consolidation, 0.33 of a share becomes about 0.066 — roughly one Tributary share for every 15 shares you hold, at a net asset value of about $2.10 (my math).

 

Share structure and insider skin in the game 

•   47.6 million arrangement warrants at $0.42, 60-day life, worth $20 million if fully exercised.

•   A non-brokered private placement of up to 71.4 million units at $0.42 for up to $30 million — offered only to officers, directors and staff of Tributary. Each unit is one share plus one four-year warrant at $0.42, with performance vesting tied to the trading price.

•   Basic shares: 356.8 million. Fully diluted: up to 428.2 million.

•   Insider ownership: 22.1% basic (79.0 million shares), and up to 35.1% fully diluted (150.4 million shares).

•   A 5-for-1 consolidation follows all the issuances, taking the basic count to roughly 71.4 million shares.

•   Officers, directors and staff are writing a cheque of up to $30 million at the same price you receive your shares at. I always look for that.

 

Production 

•   One producing asset: the McCully gas field near Sussex, New Brunswick. About 6.5 mmcf/d during the season — roughly 1,083 boe/d (my math).

•   It runs winter only, December 1 to April 30, to capture Algonquin city-gate pricing into New England.

•   12.5-year proved developed producing reserve life, with no development drilling required to hold it.

•   Reserves: 2.1 million boe PDP, 2.8 million boe proved, 3.9 million boe proved-plus-probable.

•   266 net sections of undeveloped land — about 168,000 acres. That is 120 sections of W4 Mannville Stack, 68 at Duncan, 55 at Handel, and 23 elsewhere.

•   Oil in place under that land: 463 million barrels at Duncan, more than 570 million at the W4 Mannville Stack, and 172 million at Handel. More than 1.2 billion barrels in total, on management’s internal estimates.

 

Cash flow — gross and per share 

•   About $17 million a year, the average of the last three winter seasons: $15.2 million in 2023/24, $16.2 million in 2024/25, and $18.9 million in 2025/26.

•   Note the trend. It is going up, not down, which is unusual for a field that has been on production since 2008.

•   Per share: about $0.048 on 356.8 million basic shares, or roughly $0.24 per share after the 5-for-1 consolidation (my math).

•   Maintenance capital is under $0.5 million a year. Almost all of that cash flow is free.

•   Important caveat, straight from the presentation: this is an asset-level number, before any corporate costs. A public company with ten officers will not keep all $17 million.

•   The team has also banked $14 million of realized hedging gains on this asset since 2020.

 

Debt 

•   Zero debt. None.

•   About $50 million of cash — $20 million from the arrangement warrants plus $30 million from the private placement, before issue costs.

•   Up to another $30 million arrives if the private placement warrants get exercised over the next four years.

•   Asset retirement obligation of $11.1 million, undiscounted.

 

Valuation — EV/EBITDA 

•   Net asset value of $100.7 million: $88.3 million of after-tax 2P NPV10 plus $12.4 million of undeveloped land. On 237.8 million shares that is the $0.42 deemed value.

•   Market cap at the deemed price is about $150 million on 356.8 million shares, less $50 million of cash — an enterprise value near $100 million (my math).

•   That works out to roughly 5.3x cash flow using last winter’s $18.9 million, or about 5.9x using the $17 million three-year average (my math; ATB publishes both).

•   $0.42 is arguably too low. The reserve value is struck after tax; before tax the same 2P reserves are worth $100.6 million, or $0.42 a share on their own — meaning the land is effectively thrown in for free.

•   The 266 sections are carried at $47,000 per section. ATB calls that low for Mannville stack acreage.

•   For what it is worth, ATB points to two recent spinouts: Logan Energy came out at a deemed $0.35 and closed its first day at $0.80. Coelacanth came out at $0.27 and closed at $0.60.

 

Dividend per share 

•   Nothing. Zero. This is a growth and exploration vehicle, and it should be judged that way.

 

PART 3 — THE STORY:
HOW A PLAY NOBODY WANTED
BUILT A $10 BILLION COMPANY
 

Here is the short version. Two companies that got rich off the same oil play just agreed to become one company. The bigger one, Tamarack Valley, is buying the smaller one, Headwater Exploration, with paper. And the management team that built Headwater is not sticking around to collect a paycheque. They are taking the odds and ends nobody wanted, putting $30 million of their own money in, and starting over.

That last part is the part I find most interesting. But let me start with the rock.

 

The play everyone walked past 

The Clearwater sits in north-central Alberta, around places called Marten Hills, Nipisi, Peavine and Jarvie. Geologists had logged through it for decades and kept going. The rock is full of a clay called kaolinite, and kaolinite makes an oil-soaked sand look wet and worthless on a wireline log. So the industry drilled past a billion barrels of oil for forty years because the paperwork said there was nothing there.

 

Then around 2016 and 2017, a couple of small private operators — Spur Petroleum and Deltastream — looked again. They found sand with permeability running as high as 900 millidarcies, porosity around 22%, and about 12 metres of net pay. That is fantastic rock. The oil is heavy-ish, 14 to 24 degrees API, but it flows.

 

The real breakthrough was how they drilled it. They do not frac these wells. They drill one hole, then kick four to eight lateral legs off it — about six on average — and leave them open. No casing in the lateral. No frac crew. No sand. The legs are spaced tightly enough that the reservoir drains without stimulation.

 

The economics that fall out of that are the reason this play exists. Early wells in the play cost $1.2 to $1.7 million. Now Tamarack puts wells at $1.5 million in the Marten C and Nipisi area and $1.8 million in West Marten, with 30-day rates of 115 to 200 boe/d, capital efficiencies of $12,300 to $17,800 per flowing barrel, and payouts of eight to eleven months.

 

Headwater has publicly reported Clearwater wells paying out in four to nine months at US$80 oil. I have been writing about energy for a long time. Payouts under a year do not happen very often.

 

The play went from almost nothing in late 2016 to about 27,000 barrels a day by the end of 2019, 60,000 by the end of 2021, and somewhere between 175,000 and 230,000 barrels a day today depending on whose count you use. In the first half of 2026, Alberta issued 1,764 drilling licences — the most since 2014 — and nearly one in five of them targeted the Clearwater. That is a record share for a single play.

 

And here is the kicker—after five years of the combined company’s drilling plan, less than 2% of the oil in place will have been recovered. Tamarack has publicly claimed roughly 12 billion barrels of oil in place under its own acreage. Take company OOIP estimates with salt — oil in place is not oil you can produce — but the point stands: they have barely scratched it.

 

How Headwater got its land 

Headwater’s story starts with a shell. In early 2020, a company called Corridor Resources was sitting on a winter gas field in New Brunswick and not much else. Neil Roszell and Jason Jaskela — who had already built and sold Wild Stream Exploration and Raging River Exploration — took it over and raised $50 million at 92 cents a share. The financing closed in two tranches, February and March of 2020.

 

Then COVID hit and oil went negative. Terrible luck, or spectacular timing, depending on how you look at it.

 

In November 2020, with the world still frozen, Cenovus agreed to sell them the Marten Hills Clearwater assets. Headwater paid $35 million in cash, 50 million shares and 15 million warrants struck at $2.00. For that they got about 2,800 barrels a day and 270 net sections of Clearwater rights.

Cenovus ended up owning a quarter of Headwater and put two directors on the board.

 

Everything after that was organic. They added 75 net sections in late 2021 and drilled the first Marten Hills West wells. They added 157 net sections in 2024 alone, taking the position past 611 net Clearwater sections. They found a Grand Rapids pool at Marten Hills West and grew it more than 80% in a single year to over 4,000 barrels a day. They built a Wabiskaw polymer flood at Greater Pelican.

 

Production went from roughly 2,800 barrels a day at the end of 2020 to a record 24,567 boe/d in the second quarter of 2026. They started paying a dividend in January 2023 and have declared $401 million of dividends since inception. They never carried bank debt.

 

Six years. Zero to 24,500 barrels a day, no debt, $401 million of dividends declared. That is about as good as it gets in this business.

 

How Tamarack got its land 

Tamarack took the other route. It bought.

 

Brian Schmidt had been running Tamarack since 2009 as a light-oil producer. In December 2021 he bought Crestwynd Exploration for $184.7 million, picking up about 4,500 boe/d and taking Tamarack to 445 net sections across Nipisi, West Marten Hills and Southern Clearwater.

 

Then in September 2022 he swung hard. Tamarack bought Deltastream — one of the two companies that opened the play — for $1.425 billion. That was $825 million cash, a $300 million deferred payment and $300 million of stock. It brought about 23,000 boe/d and 184 net sections at Nipisi, Canal, Marten Hills, Greater Peavine, Perryvale and Jarvie.

 

It also brought a pile of debt, and the market punished the stock for two years. Fair enough. But Schmidt spent 2024 and 2025 paying it down and buying back 81 million shares — about 15% of the company.

 

Then in May 2026 he did the cleanest thing he has ever done. He sold the Charlie Lake assets — 18,000 boe/d, a quarter of corporate production — for $804 million cash. That wiped out the debt, funded a 25% dividend increase, and turned Tamarack into a pure-play Clearwater producer with 900+ sections and 54,000 boe/d of Clearwater.

 

One company drilled its way in. The other wrote cheques. They ended up beside each other on the map.

 

So why merge? 

Look at the map and the answer is obvious. The core land at Marten Hills, Marten Hills West and Nipisi becomes one contiguous block under one operator. When two companies own alternating sections, both of them leave buffer zones along the boundaries and both of them build their own batteries and pipelines. Put them together and those problems disappear.

 

The $50 million of annual synergies comes from: $20 million out of the corporate line, $15 million from capital efficiency, and $15 million from better netbacks. The capital efficiency piece is real engineering, not accounting — longer laterals where the combined acreage allows it, fewer buffer sections, one set of infrastructure instead of two. The netback piece is fewer field operators, shared trucking, and Tamarack’s slightly better marketing applied to Headwater’s barrels.

 

There is a second reason, and it is about the shareholder register more than the rocks. A 40,000 barrel-a-day Canadian heavy oil producer does not get a phone call from a large American fund. An 80,000 barrel-a-day producer with net cash, a 15% decline rate and a US$37 breakeven might. The whole argument is that scale earns a better multiple and a cheaper cost of capital, and that the re-rating is worth more than any premium Tamarack could have paid in cash.

 

They also fixed something that was quietly holding both companies back: they can now put more money into waterflood. Waterflood allocation goes from 30% to 40% of the capital budget, while exploration spending comes down. Both companies have said publicly that water injection roughly doubles the oil recovered for less than double the cost, and Headwater has put the return on a doubled recovery factor at roughly four times the invested capital at US$70 oil over the life of the asset.

 

Those are company statements, not audited results — but the waterfloods have been outperforming at both companies, and that is why the decline rate is falling to 15% next year.

 

And be honest about what Headwater holders are getting. Using 30-day average prices before the announcement, one Tamarack share at $13.29 plus 0.33 of a Tributary share at $0.42 comes to $13.43. Headwater’s own 30-day average was $13.71. There is no premium here. The bet is that the combined company trades better than the two pieces did apart, and that the warrant and the spinout are worth more than the deemed values suggest.

 

The risks I would actually worry about 

1.  Egress. The company has secured 35,000 barrels a day of capacity out of the basin, but 25,000 of that on Trans Mountain depends on a drag-reducing-agent expansion finishing in the first quarter of 2027, and the other 10,000 rides on the South Bow Prairie Connector, which has not been approved or built and might start at the end of 2028. If you are growing 10–12% a year in one basin, local pipe capacity is the thing that bites you.

2.  Heavy oil differentials. The breakeven math assumes a WCS discount of US$12.00 a barrel. That number has been far worse in living memory.

3.  Integration. Two cultures, two field organizations, one set of synergy promises. The $50 million is a target, not a receipt.

4.  The lock-up expiries. A third of the Headwater insider stock comes free at three months, six months and nine months after closing.

5.  Concentration. Run-rate Clearwater production is 94% oil, and after the Charlie Lake sale this is a one-play, one-basin company. (Tamarack’s full-year 2026 corporate production is about 88% oil, because the year includes the assets it sold.) The pure-play story cuts both ways.

 

PART 4 — TRIBUTARY EXPLORATION: THE FOURTH ACT
 

Now the part I actually want to talk about.

 

Neil Roszell and Jason Jaskela have done this three times. Not twice. Three times.

1.   Wild Stream Exploration issued $381 million of equity and sold to Crescent Point in January 2012 for $770 million.

2.   Raging River Exploration issued $588 million and sold to Baytex in 2018 for $1.6 billion.

3.   Headwater issued $143 million, declared $401 million of dividends along the way, and is now exiting at $3.2 billion. One note on those equity numbers: they include stock issued to pay for acquisitions, not just cash raised. Headwater’s actual cash raise was the $50 million at 92 cents.

The presentation puts a number on it that stopped me. One dollar put into Wild Stream’s first public financing at $4.50 a share in late 2009, rolled into each next company at its founding price, would be worth about $152 today. The company is careful to say past results are not indicative of future ones, and they are right to say it. But that is a 152-bagger across seventeen years and three companies, and the same people are doing it a fourth time.

What they are taking with them 

Tributary gets three things.

First, a cheque book. About $50 million of cash, no debt. Twenty million of that assumes Headwater shareholders exercise every arrangement warrant, and up to thirty million comes from a private placement that only officers, directors and staff can buy. If the warrants go unexercised, the cash is smaller. Insiders will own 22% of the basic shares and up to 35% fully diluted. Nobody is getting a free ride here.

 

Second, a paycheque. The McCully gas field in New Brunswick — which, in a nice piece of symmetry, is the original asset from the Corridor Resources shell they took over in 2020. It produces about 6.5 mmcf/d, but only from December 1 to April 30. They shut it in the rest of the year on purpose.

 

That sounds odd until you look at where the gas goes. Headwater owns the plant and a transmission line running into the Maritimes and Northeast Pipeline, which feeds Boston at the Algonquin city-gate. New England has no meaningful gas storage and not enough pipe. Every winter, Algonquin prices spike. So they produce only in the months when the price is best, and leave the gas in the ground the rest of the year.

 

The result is a field producing since 2008 whose cash flow is going up: $15.2 million in the 2023/24 winter, $16.2 million in 2024/25, $18.9 million last winter. Maintenance capital is under $500,000 a year. There is no development drilling required — the proved developed producing reserve life is 12.5 years. They have also banked $14 million of hedging gains on it since 2020.

 

Third, and this is the real reason the company exists, the land.

 

The land nobody could justify drilling 

Headwater had 266 net sections of undeveloped Alberta and Saskatchewan acreage — mostly its own, plus some minor lands coming over from Tamarack — that never got a dollar of capital. Not because it was bad. Because the Clearwater was so good that nothing else could compete for the budget. When a four-month payback is sitting on your desk, you do not go drill a science project.

 

So it sat there. Now it becomes the whole company.

 

The W4 Mannville Stack is the biggest piece — 120 sections, more than 570 million barrels of oil in place, with established production nearby and drilling inventory in several stacked Mannville horizons. Stacked pay matters: you drill one surface location and produce more than one zone.

Duncan is 68 sections with 463 million barrels of oil in place, which they think can be unlocked with thermal or circulation-string techniques.

 

Handel, in Saskatchewan, is 55 sections with 172 million barrels in place. It has conventional Mannville targets today and what management calls significant upside in a small SAGD or thermal project later.

 

Add it up and Tributary owns rights over more than 1.2 billion barrels of oil in place — on management’s own internal estimates, which is an important qualifier — with up to $50 million of cash, no debt, and roughly $17 million a year coming in the door.

 

The Mannville stack multilaterals cost about $2 million a well. At $50 million of cash they can drill a real program without selling a share. The small SAGD project at Handel is a different animal — capex is $175–200 million, which Tributary cannot fund today. That is a later-decade story, or a story that gets funded by somebody else.

 

What it is worth 

The deemed value is $0.42 a share. That is $88.3 million of after-tax proved-plus-probable reserve value plus $12.4 million of land, spread over the 237.8 million shares issued at close.

 

Three observations.

 

One: the reserve number is struck after tax. Before tax, the same reserves are worth $100.6 million — which on its own is $0.42 a share. So on a pre-tax basis, the entire 266-section land package is being handed to you for nothing.

 

Two: the land is carried at about $47,000 a section—arguably that’s low.

 

Three: deemed values on spinouts are almost always set conservatively, because nobody wants to be accused of pushing paper out at an inflated price. Logan Energy, which came out at a deemed $0.35 and closed its first day at $0.80, and Coelacanth, deemed at $0.27 and closing at $0.60. That is not a guarantee. It is a pattern.

 

One thing to keep straight: if you own Tamarack, you get the Tributary shares but not the warrant. The warrant is Headwater’s alone.

 

PART 5 — WHEN DOES THIS HAPPEN?
 

Here is the calendar as it stands today.

September 8, 2026

Deal announced. Both boards approved unanimously. Directors and officers holding about 6% of Headwater and 2% of Tamarack have signed support agreements.

October 2026

Joint information circular mailed to both sets of shareholders. This is the document that will contain the full fairness opinions, the Tributary reserve report detail, and the arrangement agreement. Read it.

November 2026

Special meetings of both Tamarack and Headwater shareholders. The deal needs two-thirds of votes cast at each company, plus a simple majority of Headwater’s minority shareholders under MI 61-101. The Tributary private placement needs its own separate majority vote at both companies.

Mid-to-late Q4 2026

Closing, subject to the Court of King’s Bench of Alberta, the Competition Act and TSX approval. ATB’s working assumption is late November. The Tributary spinout happens at closing — the shares and warrants are distributed the same day.

December 2026

The dividend goes to $0.06 a quarter. Formal 2027 guidance for both Tamarack and Tributary is expected.

Late 2026 to Q1 2027

Tributary lists. The sequence is: shares and warrants issue at closing, then the 60-day warrant exercise window runs, then the private placement, then the 5-for-1 consolidation, then listing. The company says only that a listing is ‘subject to Tributary fulfilling all the listing requirements of such stock exchange’ — there is no committed date and no exchange named yet. If you want a working assumption, plan on trading beginning somewhere between December 2026 and the end of the first quarter of 2027, and do not be shocked if it slips.

January 1, 2027

Steve Buytels becomes CEO of Tamarack. Brian Schmidt becomes Executive Chairman.

Q1 2027

The 25,000 bbl/d of Trans Mountain capacity is targeted to start, subject to the drag-reducing-agent expansion finishing.

End of 2028

The 10,000 bbl/d on the South Bow Prairie Connector could start — if the project gets approved and built.

 

One practical note on the warrants, and it matters. If you own Headwater, your arrangement warrants live for 60 days after closing and strike at $0.42. If closing lands in late November, that window likely closes in late January. Warrants that expire that fast get forgotten by retail investors all the time. Put it in your calendar the day the deal closes.

 

THE BOTTOM LINE 

What I take away from all of this: you are being handed two very different investments in one envelope. The big one is a low-decline, net-cash, 80,000 barrel-a-day heavy oil machine with a US$37 breakeven, growing 10–12% a year and paying you 1.8% while it does. That is an income-and-durability story, and the whole thesis rests on the multiple expanding as it gets bigger.

The small one is a $150 million shell with up to $50 million of cash, a winter gas field that pays the bills, a billion-plus barrels of oil in place nobody has drilled, and the same team that has turned a dollar into $152 over three companies since 2009.

They are not the same bet.

 

DISCLAIMER

This report is for information only and is not investment advice. I am not a registered investment advisor. Figures come from the joint press release dated September 8, 2026, the Tributary Exploration investor presentation dated September 2026, Various sell side research comments post announcement. Background on the Clearwater play’s history and geology, both companies’ past acquisitions and operating results, and the McCully asset’s origins come from public company news releases, regulatory filings and trade press, and are not drawn from those four documents. Forward-looking figures, including production guidance, synergies, growth rates, net asset values and analyst estimates, are projections and may not be achieved. The deal has not closed and requires shareholder, court and regulatory approval. Tributary Exploration is not yet listed on any stock exchange and there is no assurance it will be. Do your own work and speak to your own advisor before buying or selling anything.