Buru Energy Books 15.25 MMboe Rafael Reserves Unlocking Path to 2027 FID
Key Takeaways
- Buru Energy has booked maiden independently assessed 2P Reserves of 15.25 MMboe for the Rafael gas-condensate field, including 65.7 Bscf of sales gas, certified by Sproule ERCE under the SPE-PRMS global standard with an effective date of 31 August 2026.
- The reserves certification is the critical prerequisite for project financing discussions and a Final Investment Decision, which Buru has targeted for 2027 — meaning this milestone directly unlocks the next phase of capital engagement.
- Buru holds a 100% working interest in EP428, retaining the full economic upside from any development outcome without a joint venture partner diluting returns.
- Midstream partner Clean Energy Fuels Australia will build, own, and operate the LNG plant, separating upstream and midstream capital risk and limiting Buru's direct development outlay to wells and approvals.
- Beyond the foundation two-well development, Sproule ERCE has assessed 2C Contingent Resources of 21.24 MMboe, with a longer-term 3C figure of 49.58 MMboe representing extended upside as additional wells and compression are added.
Buru Energy books maiden Rafael reserves in major step toward 2029 first gas
Buru Energy (ASX: BRU) has announced the maiden independently assessed Proved and Probable Reserves for its Rafael gas-condensate field, booking 15.25 MMboe of 2P Reserves, including 65.7 Bscf of sales gas, 98.5kt of LPGs, and 2.9 MMstb of condensate. The assessment was completed by independent energy consultancy Sproule ERCE in accordance with the SPE Petroleum Resources Management System (SPE-PRMS), with an effective date of 31 August 2026.
Rafael is located in EP428 in the onshore Canning Basin, approximately 100km east of Broome, Western Australia, with Buru holding a 100% working interest. This maiden reserves booking is the foundational milestone required before project financing conversations and a Final Investment Decision (FID), which the company has targeted for 2027, can advance in earnest.
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Breaking down the Rafael reserves: what the numbers show
The full independently assessed reserves and contingent resources, net 100% to Buru as at the effective date, are presented below.
| Commodity | Units | 1P | 2P | 3P | 2C |
|---|---|---|---|---|---|
| Sales gas | Bscf | 22.74 | 65.74 | 83.23 | 105.7 |
| Condensate | MMstb | 1.00 | 2.89 | 3.89 | 2.7 |
| LPG | ktonnes | 34.07 | 98.50 | 124.70 | — |
| Total oil equivalent | MMboe | 5.28 | 15.25 | 19.54 | 21.24 |
The 1P figure (5.28 MMboe) represents Proved Reserves — the highest-confidence category. The 2P figure (15.25 MMboe) is the Proved plus Probable best estimate and is the headline number used in project financing. A 3P upside case of 19.54 MMboe also exists, while a longer-term 3C figure of 49.58 MMboe (including 245 Bscf of gas) represents extended upside beyond the initial development scope.
All reserves are classified as sales volumes and include Sproule ERCE’s allowances for fuel, flare, and gas shrinkage. Contingent Resources are reported unrisked, on a Development Pending basis.
What petroleum reserves certification means for investors
The SPE-PRMS framework is the global industry standard for classifying oil and gas volumes. In plain terms, it works like this: 1P (Proved) means there is a 90% or greater probability of recovery under current economic conditions. 2P (Proved plus Probable) is the best-estimate case, with at least a 50% probability. 3P (Proved plus Probable plus Possible) is the upside scenario.
The distinction between Resources and Reserves matters enormously when it comes to project financing. Resources represent volumes that are potentially recoverable but have not yet been independently certified as commercially viable. Reserves, by contrast, have been independently assessed, modelled against real economic assumptions, and confirmed as commercially producible. Lenders, project financiers, and strategic partners require independently certified Reserves before they will commit capital. A company-estimated resource, however credible internally, does not meet that threshold.
Buru’s move from contingent resources to a maiden reserves booking is precisely the step that opens the door to formal financing discussions. It converts Rafael from a promising geological discovery into a certified, commercially characterised asset that third parties can evaluate with confidence.
Development plan, timeline, and the path to first sales
The Rafael Gas Project is structured as a phased, modular development built around two horizontal production wells. The planned development sequence is:
- 2027: Drill and flow-test Rafael 1H and Rafael 2H
- 2027: Final Investment Decision anticipated
- 2028: Facility construction (modular LNG and liquids processing)
- Early 2029: First gas and first sales targeted
The proposed facility carries a nameplate capacity of 300 tonnes LNG per day, equivalent to approximately 18 MMscf/d of raw gas, and is designed to produce LNG, LPG, and condensate-derived products for regional Kimberley markets. Sproule ERCE’s best-case production forecast supports an 11 MMscf/d plateau for approximately 14.9 years, with production remaining at or above plant turndown for approximately 20 years.
The midstream partner is Clean Energy Fuels Australia (CEFA), which will build, own, and operate the LNG plant. Buru’s capital exposure is principally to the upstream wells, resource validation, and approvals. This structure separates upstream and midstream capital risk, limiting Buru’s direct development outlay.
Documentation is currently being finalised for the Rafael Gas Project Referral for submission to the Environmental Protection Authority Western Australia, which is the primary environmental approval document required.
Rafael Gas Project FID progress has been building steadily through 2026, with Buru advancing commercial documentation, partner negotiations, and environmental referral preparation in parallel with the reserves certification process.
David Maxwell, Executive Chair
“The Rafael Reserves result is a landmark for Buru and a major step for the Rafael Gas Project. The maiden booking of independently assessed Reserves confirms a substantial, commercially robust resource base for the foundation long-term Rafael two-well development. It provides great confidence to Buru and other stakeholders as the project moves rapidly to a final investment decision…”
Beyond the foundation: contingent resources and longer-term upside
The booked 2P Reserves reflect the initial two-well development only. Beyond that foundation, Sproule ERCE has assessed 2C Contingent Resources of 21.24 MMboe, including 105.7 Bscf of gas and 2.7 MMstb of condensate. These volumes reflect the potential recovery from additional wells, compression, and extension of facility life, and are classified as Development Pending.
In other words, the initial two-well programme is the starting point, not the ceiling. The data gathered from drilling and testing Rafael 1H and Rafael 2H is expected to inform optimisation of subsequent development stages.
Maxwell also noted additional prospective upside in immediate proximity to the Rafael field. These include the “T30” sand, which recorded gas shows in Rafael 1 above the main reservoir, and the Flying Fox prospect beneath the Rafael field. Both are prospective resources currently being updated by Buru. They have not been independently certified and should not be read as booked resources.
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Investment case: why this milestone matters
The maiden reserves booking represents a material shift in Rafael’s commercial status. Key points for investors to consider:
- The maiden independent reserves booking provides the formal technical and commercial credential required for project financing discussions and partner engagement
- Buru’s 100% working interest in EP428 means the company retains full value from any development outcome
- The modular, phased development structure is designed to limit upfront capital exposure
- CEFA’s role as midstream operator separates upstream and midstream capital risk, with Buru focused on wells and approvals
- The Kimberley market is identified as supply-constrained, with all hydrocarbon products currently transported in from the Pilbara or further
- FID is anticipated in 2027, with first sales targeted in early 2029
As Maxwell noted, the company’s focus is now on converting the independent technical validation into a funded development, progressing financing, commercial documentation, approvals, and preparations for the planned development wells.
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