Focus Capital Advisers' Mordechai Yavneh on the greatest acquisition of all time (Valeura Energy)
Summary
- Mordechai Yavneh’s core call is that Valeura Energy (VLE) can earn its enterprise value in roughly two to three years without requiring higher oil prices. Valeura is the Gulf of Thailand’s largest independent producer, with about 25,000 barrels per day, no debt, and—by Yavneh’s December 31 figure—$260 million of cash, versus a roughly $650 million market cap. At $75 oil, he estimates approximately $150 million of annual cash generation after treating all planned capital spending as expense: “If you like money, this is the stock for you.”
- Valeura’s first Thailand deal bought the suspended Wassana field for an effective $14.5 million, then added a tax asset potentially worth far more than the purchase price. Wassana could produce roughly 3,000-5,000 barrels per day and was estimated to generate $36 million annually at stronger oil prices, although Walker puts it around $12 million nearer $70 oil. The acquired entity also carried about $400 million of tax losses, which Yavneh values near $200 million after their application was broadened across the combined business.
- The Mubadala Energy transaction effectively paid Valeura to acquire a functioning 20,000-barrel-per-day enterprise. Valeura paid $10.5 million for Jasmine, Nong Yao, Manora, and the operating organization, while economics accrued from September 1 through the March closing; at roughly $15 million of monthly net cash generation, about $105 million remained inside the acquired company. Andrew Walker’s reaction captures the anomaly: “They gave you 8x your purchase price on day one.”
- The extraordinary price arose from a completed auction colliding with Mubadala’s mandated oil exit, rising crude prices, and unusual deal timing—not from a repeatable acquisition formula. Mubadala reportedly went silent as oil approached $100, then retained the earlier months’ cash flow by reducing the consideration and resetting the effective date without reopening the auction. Yavneh concedes the result required “a confluence of luck,” while Walker says the economics were so implausible that his first instinct was to check the auditor.
- The decisive variant perception is whether Valeura’s short booked reserve life represents depletion or merely the Gulf of Thailand’s conservative reserve-recognition pattern. Across the basin, Yavneh cites 122% average reserve replacement; Jasmine began with 7 million booked barrels, produced 95 million, and finished 2024 with 17 million, while Nong Yao began with 3 million, produced 29 million, and retained 16.9 million. His formulation: “You produce what you have and just replace it.”
- Reserve replacement changes both sides of the valuation by adding production years and postponing abandonment spending. Manora, once expected to close in 2025, is now projected into mid-2030; 2024 drilling pushed every field’s expected end date by roughly 2.5-5 years. Engineering work, reuse, and later timing have reduced the booked decommissioning liability from about $200 million to approximately $84-90 million.
- The company’s stated C$13.60-per-share NAV already uses booked reserves and a 10% discount rate, versus a quoted share price of C$8.35, but the long-tail thesis still has a hard concession boundary. Most fields’ concessions end in the early 2030s. Thailand has historically granted producing fields their first 10-year extension on the same terms, though guarantees or a modest signing payment may be required; Yavneh’s answer about what happens after that statutory extension is blunt: “I have no clue.” The investment does not need 2050 production, but claims extending that far remain a bet, not a reserve estimate.
- The next test is whether disciplined operations can convert Wassana and adjacent discoveries into profitable organic growth without compromising capital allocation. A larger, roughly $150 million Wassana platform could add 10-12 million barrels before potential North and South developments, with first oil targeted around Q2 2027 if the pending investment decision and costs cooperate. Valeura aspires to 100,000 barrels per day, but Yavneh assigns no value to another acquisition and stresses that management has gone roughly 2.5 years without buying because it has not found the right deal.
Deep dive
1. The pitch begins with cash yield, not an oil-price forecast
Yavneh describes Valeura as an extremely profitable Gulf of Thailand oil producer with about 25,000 barrels per day, substantial cash, and no debt. His headline is that the company should generate its enterprise value in “two to three years” through “gushing cash,” even at oil prices somewhat below those prevailing during the discussion.
The commodity sensitivity remains explicit: lower oil means less profit, higher oil means substantially more, and Yavneh claims no ability to predict direction. His downside framing is narrower—that the fields should remain profitable at sharply lower prices—not that Valeura is insulated from crude.
Valeura emerged from a radically different starting point. After selling its Turkish gas interests in 2020, it was essentially an undeveloped asset plus roughly $40 million of cash; management waited several years before two 2022 transactions transformed it into the Gulf’s largest independent and second-largest overall producer.
2. Wassana established the beachhead—and carried a hidden tax prize
Valeura acquired the suspended Wassana field from bankrupt KrisEnergy for $3 million, paid another $9 million for equipment, and accepted contingent consideration whose relevant portion Yavneh estimates near $2 million. After simplifying the related Rossukon interest, his effective purchase-price figure is $14.5 million.
Wassana had produced before being halted around the period of $30 oil. Valeura expected to restart near 3,000 barrels per day, potentially rising toward 4,500-5,000, with opex around $36 per barrel; Yavneh estimates approximately $36 million of annual after-tax cash flow at stronger pricing, versus roughly $12 million nearer $70 oil according to Walker.
Walker’s challenge—why would anyone sell near one times cash flow?—has a concrete answer: this was not a turnkey stream. Valeura spent roughly a year rehabilitating it, then endured shutdowns after a service vessel struck a platform leg and a separate crack appeared; the aging mobile platform still requires replacement.
The purchase also brought approximately $400 million of tax losses. After lengthy legal and technical work allowed much of those losses to shelter profits from the later Mubadala assets, Yavneh estimates their value near $200 million: the small field purchase delivered “tax losses that are worth” many times its cost.
3. Thailand is politically messy, but its petroleum contracts have held
Walker flags the obvious jurisdictional risk: Thailand is less democratic and more coup-prone than the United States, while government involvement always creates political exposure. Yavneh’s pushback is specific rather than dismissive—Thailand has supported a sizable oil industry for decades and has never retroactively altered an existing concession’s fiscal terms.
Thailand has introduced successive “Thai 1,” “Thai 2,” and later fiscal regimes, but Yavneh says each applied prospectively. His claim is not that the country is uncorrupt or politically placid; it is that petroleum arrangements have remained insulated from the broader upheaval.
Operationally, these are relatively shallow offshore fields, generally no deeper than about 1,500 feet, rather than complex deepwater developments. Their distinctive challenge and opportunity is geological: hydrocarbons sit in numerous stacked compartments, so only zones directly demonstrated by drilling enter booked reserves.
4. Mubadala sold a whole business for less than one month’s earnings
Valeura’s second transaction acquired roughly 20,000 barrels per day across Jasmine, Nong Yao, and Manora from Mubadala Energy, an arm of an Abu Dhabi sovereign wealth fund. The transfer included employees, technical teams, engineers, and management—“lock, stock and barrel”—apart from Mubadala’s country head.
These operations were generating approximately $15 million net per month, yet the stated price was $10.5 million. Because the economic effective date was September 1 and closing occurred the following March, roughly seven months—or about $105 million—of accumulated economics remained in the acquired company.
Walker compares the pitch to being offered a fund promising 4% annualized returns per day: the numbers sound fraudulent on first hearing. The critical distinction is that this is a completed 2022 transaction, with field-level production observable through Thai government reporting, public oil prices, audited accounts, and two subsequent years of operating results.
Even the host struggles to rationalize the bargain: “It is the biggest gift I’ve ever heard.” His disbelief is part of the thesis, not edited away—the price would almost be easier to trust if the terms were merely very good rather than economically surreal.
5. The deal’s explanation is plausible, but not fully satisfying
Mubadala wanted to exit oil and emphasize cleaner energy, including natural gas and solar. Yavneh finds an Abu Dhabi-linked seller abandoning profitable oil for ESG reasons “mindboggling,” but that higher-level mandate explains why the assets eventually returned to the negotiating table.
Valeura had reportedly won the auction during 2021 at a materially higher, undisclosed price. As oil moved toward $100, Mubadala developed cold feet and went silent; when it resurfaced, the parent still required an exit, but the seller wanted to retain the cash generated during the delay.
Yavneh uses $150 million only as an illustrative, explicitly invented original price: if the seller had earned roughly that difference during the delay, it could lower consideration to $10.5 million while shifting the effective date to September. What remains inexplicable is why Mubadala did not reopen the auction once economics changed so dramatically.
Asked how Valeura repeatedly secured transactions that survived the hostile 2022 energy-cycle hindsight, Yavneh’s answer is simply “no comment.” He credits patience and judgment but resists mythology: “I don’t want to overstate the dealmakers”—this outcome needed “a confluence of luck.”
6. The market prices finite reserves; the thesis prices recurring replacement
Valeura’s shares rose dramatically—its presentation showed roughly 1,400% since the strategy began versus about 135% for the next-best peer—but Yavneh argues awareness remains thin. It is a small Canadian-listed oil company with unfamiliar Thai assets; one recent YouTube earnings call reportedly had only 29 views.
His behavioral explanation is that extraordinary good news can outrun the buying capacity of investors who understand it. Interested holders reach their 5%, 10%, or 15% concentration limits, while many institutions cannot own a roughly $650 million company, leaving the story only partially transmitted.
The financial statements also screen poorly. At acquisition, booked reserve life was roughly 2.5 years against about $200 million of decommissioning obligations; even later estimates near five years can make four times free cash flow look fair if production disappears and abandonment follows immediately.
Walker isolates the variant cleanly: the market may be paying for five years, while Yavneh believes another 20 years of production and the related delay in decommissioning are effectively free. Yavneh agrees—“That is the alpha opportunity”—but says the evidence becomes clear when investors examine the basin and company history.
7. Field history supports the thesis, while concessions cap certainty
Gulf-wide reserve replacement averages 122%, according to Yavneh. Jasmine began production in 2005 with 7 million booked barrels, subsequently produced 95 million, and ended 2024 with 17 million; Nong Yao began with 3 million, produced 29 million, and still held 16.9 million.
Across the acquired fields, booked reserves were about 20 million barrels at the end of 2019 and approximately 21 million at the end of 2022 despite intervening production. Under Valeura, reserve additions in 2023 and 2024 exceeded twice the volumes produced.
Walker’s “only so many dinosaurs” objection remains unresolved in principle. Yavneh cannot prove production lasts until 2050, nor will management book unproved barrels, but Manora’s expected shutdown has already moved from 2025 to mid-2030; during 2024, drilling extended each field’s projected life by approximately 2.5-5 years.
Most fields’ concessions end in the early 2030s. The first 10-year extension has historically been granted when a field had oil to produce, on the same terms, though guarantees or a modest signing payment may be required. Beyond that extension, no established mechanism exists. Yavneh’s deliberately “non-insightful answer” is: “I have no clue.”
8. Existing NAV and organic projects provide separate ways to win
Valeura’s presentation calculated C$13.60 per share of NAV from booked reserves, cash, operating costs, capital requirements, and decommissioning, versus C$8.35 in the discussion. Because that NAV is discounted at 10%, Yavneh emphasizes that buying at C$13.60 would itself imply a 10% return; replacement extending toward 2040 could make C$8.35 closer to one-third of expected NAV.
Decommissioning is becoming less threatening even before further reserve additions. Later field closures increase the discount period, while engineering studies, component reuse, and newer well-by-well methods reduce ultimate cost; together they lowered the booked obligation from roughly $200 million to approximately $84-90 million.
Operational gains reinforce the asset argument: Valeura reschedules one rented rig across fields, converts appraisal wells into development wells, shares vessels, idles engines more efficiently, and is installing generation at Jasmine to turn waste gas into fuel. A Nong Yao floating-storage purchase cost $19 million with an estimated two-year payback.
The organic pipeline includes the Ratree exploration well at Jasmine and the already-producing Nong Yao C area, where positive appraisal wells could establish a new reserve base. Yavneh treats 2025’s roughly $135 million of broader capital spending plus $11 million of exploration as expense rather than separating growth from maintenance—and still estimates about $150 million of cash generation at $75 oil.
Wassana is the pivotal catalyst. Instead of replacing its roughly 4,000-barrel-per-day mobile platform like-for-like, Valeura was considering a larger, centrally positioned platform costing around $150 million and adding 10-12 million barrels, with later links to Wassana North and South; conditional first oil was targeted for Q2 2027.
That project captures management’s acquisition philosophy: buy fields where additional capital can earn attractive returns, turning “a small field” into “a large field” and potentially “a mega field.” The current NAV does not include the larger platform, the final investment decision and development cost remain pending, and Yavneh includes no value for another acquisition in his analysis.