Announcement PDF Buru Energy Limited Level 2, 16 Ord Street, West Perth WA 6005 Telephone: 1800 337 330 Email: info@buruenergy.com ABN: 71 130 651 437 Quarterly Activities Report 30 September 2026 29 October 2026 Highlights • Rafael maiden reserves - 2P (Proved plus Probable) Reserves: 15.25 MMboe including 65.7 Bscf (69.4 PJ) sales gas, 98.5kt of LPGs and 2.9 MMstb of condensate - 1P (Proved) Reserves: 5.28 MMboe including 22.7 Bscf (24 PJ) sales gas, 34kt of LPGs and 1.0 MMstb of condensate • Rafael environmental - Buru refers Rafael Project to the EPA WA • Rafael Production Licence - Application submitted • Ungani 200% resource increase - 2C Contingent Resources attributable to the Ungani oil field increased from 220,000 bbls to 660,000 bbls. Comments from the Executive Chair, David Maxwell “Buru is maturing and rapidly advancing the Rafael Conventional Gas Project. The 15.25 million boe Proved and Probable Reserves underpin the attractive economics of the proposed Rafael development. The delivery of the independently certified Reserves is an important milestone and the basis for the Board decision to approve the drilling of the planned Rafael production wells, subject to funding. Our disciplined focus is on project simplicity, capital efficiency and early cashflow as we progress towards next year’s drilling program and the delivery of a new source of reliable energy for northern Western Australia with first gas by early 2029. The best result for Buru shareholders is to maintain as much equity in the Rafael Project as possible. It is pleasing the funding discussions are advancing on this basis.” Authorisation This ASX announcement has been authorised for release by the Buru Board of Directors. For further information, visit www.buruenergy.com or contact: David Maxwell Executive Chair Telephone: +61 8 9215 1800 Freecall: 1800 337 330 Email: info@buruenergy.com 2 Activities during the September 2026 Quarter Rafael Gas Project (EP 428 – Buru 100% and Operator) The Rafael Gas Project (“Rafael” or “Project”) is based on a small footprint, modular development concept utilising proven small scale LNG technology. Rafael is being developed to generate long-term cashflow, reduce the greater Kimberley region’s reliance on imported energy such as LNG and LPG and provide a long-term foundation for Buru’s future growth. Reserves Certification On 11 September 2026, Buru announced the maiden independent certification of Proved and Probable Reserves for the Rafael gas-condensate field in its 100% owned EP428, onshore Canning Basin, Western Australia. Based on the planned two wells, the assessment is a major advance in the commercialisation of Rafael and an important foundation for project funding. The evaluation 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. It incorporates the Rafael 1 discovery, petrophysics and flow test from 2021/22, the Rafael 2023 3D seismic survey, updated geological and geophysical interpretation, dynamic reservoir modelling and a modular LNG and liquids processing facility. The booked Reserves relate to the foundation development only. This comprises two horizontal production wells and a modular LNG and liquids processing facility. Additional recoverable volumes associated with further wells, compression and extension of facility life have been classified as Contingent Resources, Development Pending. The independently assessed Reserves and Contingent Resources1 are summarised below: Commodity Units 1P 2P 3P 1C 2C 3C Sales gas Bscf 22.74 65.74 83.23 50.4 105.7 245.0 Condensate MMstb 1.00 2.89 3.89 1.4 2.7 6.6 LPG ktonnes 34.07 98.50 124.70 — — — Total oil equivalent MMboe 5.28 15.25 19.54 10.24 21.24 49.58 1Reserves are sales volumes calculated at the effective date of 31 August and are presented on a field gross and 100% net-interest basis representing Buru’s assessed entitlement. The Reserves include a deduction for fuel and flare (12%) plus gas shrinkage. Conversion factors used by Sproule ERCE are 1 Bscf = 1.055 PJ and 5.7 Mcf:1 boe for gas and [boe/t] for LPG and are rounded. Contingent Resources are unrisked, classified as Development Pending, exclude fuel and flare, and are reported as gas and condensate only. Sproule ERCE did not separately report LPG or total oil- equivalent Contingent Resources and Buru has used the same gas conversion factors as Sproule ERCE in calculating the BOE equivalent shown in the Table. Refer to the ASX release of 11 September 2026 for full definitions and disclosures. Buru is not aware of any new information or data that materially affects this assessment and confirms that all material assumptions and technical parameters underpinning the estimates continue to apply and have not materially changed. Environmental Approvals Subsequent to the report period, on 5 October 2026 Buru formally referred the Rafael Conventional Gas Project (“the Project”) to the Environmental Protection Authority of Western Australia (EPA WA) under Part IV of the Environmental Protection Act 1986. Following the completion of the public comment period, the EPA WA is deciding whether or not to assess the Project. Proposals that do not have a significant environmental impact do not meet the criteria for assessment by the EPA WA. The EPA WA’s decision on the Project is anticipated by late 2026. Buru conducted extensive studies, modelling and surveys as part of its Environmental Impact Assessment and did not identify any significant environmental impacts during the analysis. 3 Subject to regulatory approvals, the submission of the referral to the EPA WA is another significant step which de-risks the Project and maintains the timeline towards a Final Investment Decision in 2H CY 2027 and first gas production in early CY 2029. 1 Rafael Production Licence Application Subsequent to the report period, on 19 October 2026, Buru announced it had submitted an application for a Petroleum Production Licence (PL) over the Rafael gas and condensate field in Exploration Permit EP 428 in Western Australia’s onshore Canning Basin. The application for a PL is an important step in establishing the regulatory tenure required to produce from the Rafael field. Traditional Owner Negotiations During the quarter Buru continued to advance the negotiations with the Traditional Owners for agreements on the Rafael Gas Project. This included a Community Meeting on 9 and 10 September in Derby which provided opportunity for the Traditional Owners to be briefed on the progress of the Project and answer any questions. 2027 Rafael Drilling Program and Funding Buru has all environmental approvals required for the proposed drilling and flow testing of the two Rafael wells in 2027. The Company is advancing negotiations with potential investors to raise funds which will allow for the execution of the 2027 Rafael Drilling Program. The objective of the funding structures under discussion is to provide a fully funded solution for the Rafael Gas Project through to first gas, including the drilling program being planned for 2027. The Board has approved the drilling, completion and testing of the two Rafael production wells subject to funding being in place. Rafael Project Timeline The Rafael Project Development timeline is illustrated in figure 1 below. Figure 1 – Rafael Project Development Timeline 4 Flying Fox Prospect (EP 428 – Buru 100% and Operator) The Flying Fox prospect was identified following work on the interpretation of the Rafael 3D Seismic acquired in 2023. The Flying Fox prospect lies immediately beneath the main Rafael gas and condensate field at a depth of approximately 4,015m TVDSS2. The Flying Fox prospect has been assessed to contain Prospective Resources3 between 60 Bscf and 614 Bscf of gas, with a best estimate (P50) volume of 247 Bscf, and between 1.2 MMstb and 12.6 MMstb of condensate with a best estimate (P50) of 5.0 MMstb. The Flying Fox prospect could be tested by drilling an incremental ~500 meters below the Rafael gas accumulation. Chance of Success Condensate (MMstb) Gas (Bscf) (COS) 1U 2U 3U 1U 2U 3U Gross Prospective Resources 45 1.2 5.0 12.6 60 247 614 Net Prospective Resources 45 1.1 4.6 11.3 57 226 551 Figure 2 – Flying Fox Prospective Resources3 Cautionary Statement: Prospective Resources are estimated quantities of petroleum that may be potentially recovered by the application of a future development project and relate to undiscovered accumulations. These estimates have both an associated risk of discovery and a risk of development. Further exploration, appraisal and evaluation are required to determine the existence of a significant quantity of potentially recoverable hydrocarbons. Figure 3 – Flying Fox Prospective location below main Rafael structure 2 True Vertical Depth Subsea. 3 Refer to the ASX release of 14 August 2025 for full definitions and disclosures. Buru is not aware of any new information or data that materially affects this assessment and that all material assumptions and technical parameters underpinning the estimates continue to apply and have not materially changed. 5 Ungani Oilfield (L 20/L 21 – Buru 100%) The Ungani Oilfield remained in care and maintenance during the quarter. Buru is currently reviewing options which may enable the restart of operations at the Ungani Oilfield. During the quarter a reservoir assessment was completed on the remaining recoverable oil volumes residing in the Ungani Oilfield. Following this reservoir and operating review, Buru estimates that the 2C Contingent Resources attributable to the Ungani oil field have increased by approximately 200%, from 220,000 bbls to 660,000 bbls4. Recovery of these resources is subject to the maturation of commercial restart and offtake options noting that trucking and export costs under the previous operating model contributed more than 50% of the operating costs. Buru is continuing to assess the market opportunities, including establishing a micro-refinery to process Ungani crude oil to diesel and other products to supply the greater Kimberley region. 4Refer to the ASX release of 19 August 2026 for full definitions and disclosures. Buru is not aware of any new information or data that materially affects this assessment and confirms that all material assumptions and technical parameters underpinning the estimates continue to apply and have not materially changed. Mars Exploration Prospect (L 20/L 21 – Buru 100%) Mars is a high-potential, exploration target located approximately 9 kms north of the Ungani facility and in the same licence area. Buru is considering a farmout for the Mars oil prospect. Mars exploration success would provide a material growth and long-term backfill to the Ungani production profile and significantly increase the value of an integrated operation. Utilising the existing processing and storage capacity at Ungani, a discovery at Mars represents a low-risk, high-reward pathway to generating cash flow which is further enhanced if a micro-refinery is established. Mars is a large fault-bounded anticlinal closure up-dip from the interpreted oil pay in the Ungani North 1 well that is confidently defined on high-quality modern 3D seismic data. The prospect was initially identified on the Ungani 3D seismic, with the structure confirmed on the reprocessed Ungani 3D pre-stack depth migration volume in 2019. Ungani North 1 confirmed excellent reservoir quality within the Reeves Formation sandstones with 17% porosity measured from sidewall cores at 1,765m. Strong oil shows in several sidewall cores recovered from sands of the Reeves Formation at Ungani North 1 provides confidence of oil charge into the Mars structure. Buru’s internal assessment indicates a chance of success of 40% for a Mars 1 well5. Figure 4 – Section A-A’ from Ungani Far West 1 (UFW1) to Mars Prospect 5 Further details on the Mars prospect can be found in the ASX announcement released on 17 June 2024, and can be accessed here: https://buruenergy.com/announcements/6385907 6 Yulleroo Gas Field (EP 391 & EP 436 - Buru 100%) Yulleroo is a large unconventional discovered gas resource. It is a world-class accumulation of gas and high-value liquids within the Carboniferous-aged Laurel Formation. The landscape for onshore gas in the Canning Basin has reached a significant stage following the Environmental Protection Authority’s (EPA) January 2026 recommendation for approval of the Valhalla Gas Exploration and Appraisal Program. The EPA’s conclusion was that the environmental risks associated with hydraulic fracture stimulation can be strictly managed through rigorous, science-based conditions. The Yulleroo accumulation is defined by four wells - all intersecting thick gas saturated sections with gas below closure mapped on 3D seismic and Yulleroo 4 deliberately drilled outside closure. There is also a potential conventional pay in Yulleroo 3. The Yulleroo 2 well was tested in 2010 (3 zones) and produced gas rates up to 1.8 mmcfd and high condensate content. Yulleroo is relatively close to the Dampier to Bunbury pipeline and therefore capable of: • supplying main Western Australia demand centres; and/or • being backfill for major offshore LNG assets. The development of the Yulleroo gas resources could help secure Western Australian’s energy future by meeting near- term domestic gas requirements whilst also providing the firming fuel required to support renewable energy delivery. Contingent Resources5 1C 2C 3C Unlimited Recoverable Sales Gas (PJ) 321.4 714.0 1,627.0 Unlimited Recoverable Associated Liquids (MMbbls) 9.5 24.9 47.6 Prospective Resources5 Low Best High Sales Gas (PJ) 124.6 302.8 611.0 Associated Liquids (MMbbls) 4.3 11.9 24.8 Figure 5 – Yulleroo Contingent and Prospective Resources6 6 Contingent Resource and Prospective Resource assessment (completed by RISC Advisory Pty Ltd) was prepared using the probabilistic method and an evaluation date of 1 December 2017. Contingent Resources are quantities of petroleum estimates as of a given date to be potentially recoverable from known accumulations by application of development project(s) but which are not currently considered to be commercially recoverable due to one or more contingencies. Contingent Resources are a class of discovered recoverable resources. Prospective Resources are estimated quantities of petroleum that may potentially be recovered by the application of a future development project(s) that relate to undiscovered accumulations. These estimates have both an associated risk of discovery and a risk of development. Further exploration, appraisal and evaluation is required to determine the existence of a significant quantity of potentially moveable hydrocarbons. The full resource statement is set out in accordance with ASX Listing Rules in Buru’s ASX release of 18 January 2018. Buru Energy is not aware of any new information or data that materially affects the information included in the 18 January 2018 release and all material assumptions and technical parameters underpinning the estimates in that release continue to apply and have not materially changed. 7 Canning Basin Exploration Remaining Acreage Position (L 6, L 8, L 17, EP 129 and EP 431 with Buru 100% and Operator, and EP 457 with Buru 60% and Operator, Rey Resources 40%) Following portfolio rationalisation in 2025, activities within these licenses have focused on maintaining the assets in good standing with minimal expenditure being incurred. Corporate On 28 September 2026, Buru announced it had executed Interim Executive Director Agreements with Mr David Maxwell and Ms Joanne Williams for fulfilling the roles of Executive Chair and Executive Director (Technical) respectively. These arrangements will stay in place until a new CEO is appointed at an appropriate time for the Company. Being conscious of the Company’s limited cash resources both Mr Maxwell and Ms Williams offered to take on the executive roles for no increase in director cash fees or salary as a short to medium term arrangement, whilst linking appropriate remuneration to an equity-based performance scheme aligned with Buru Shareholder’s interests. During the quarter the following changes to securities issued under the Companies Employee Incentive Performance Rights Plan were made: • On 1 July 2025 1,885,000 Performance Rights lapsed in accordance with their terms; • On 15 July 2025 1,355,000 Performance Rights were exercised resulting in the issuance of 1,355,000 new fully paid ordinary shares in the Company. Financial As at 30 September 2026, the Company had $2.5 million in cash and cash equivalents, with no debt. The ASX Appendix 5B attached to this report contains the Company’s cash flow statement for the quarter which is summarised as follows: Cashflows September 2026 Quarter Year to Date 2026 Opening cash $4.5m $4.1m Exploration & Appraisal ($1.5m) ($5.0m) Care and maintenance ($0.3m) ($0.5m) Corporate & admin (net of interest income) ($0.4m) ($1.3m) Research & Development tax credit 0.2m 0.2m Proceeds from issues of equity (net of costs) - $5.0m Total cash inflow / (outflow) ($2.0m) ($1.6m) Closing cash $2.5m $2.5m Exploration & Appraisal Exploration cash outflows mainly consisted of appraisal expenditure for the Rafael Gas Project and geological and geophysical work across the Canning Basin portfolio. Care and Maintenance Cash outflows for the quarter primarily consisted of fixed and monthly operating costs for the Ungani Production Facility whilst under care and maintenance. Corporate and Admin Corporate and admin cash outflows were in line with the prior quarter. As outlined in the attached Appendix 5B (section 6.1), $84,000 in payments were made to related parties for Directors’ fees. 8 Appendix 1 – Buru’s Capital Structure Shares on issue1 : 1,358,660,440 Market capitalisation1 : $20 million Cash2 : $2.5 million Debt: Nil 12-month high: 2.7c 12-month low: 1.1c Appendix 2 – Buru’s Operational Areas Figure 6 Buru’s Operational Areas in the Canning Basin of Western Australia 1 - As at 26 October 2026 2 - As at 30 September 2026 9 Appendix 3 – Schedule of interests in permits as at 30 Sep 2026 Permit Type Ownership Operator Location L 61 Production licence 100.00% Buru Energy Ltd Canning Basin, WA L 8 Production licence 100.00% Buru Energy Ltd Canning Basin, WA L 17 Production licence 100.00% Buru Energy Ltd Canning Basin, WA L 20 Production licence 100.00% Buru Energy Ltd Canning Basin, WA L 21 Production licence 100.00% Buru Energy Ltd Canning Basin, WA EP 1291 Exploration permit 100.00% Buru Energy Ltd Canning Basin, WA EP 391 Exploration permit 100.00% Buru Energy Ltd Canning Basin, WA EP 428 Exploration permit 100.00% Buru Energy Ltd Canning Basin, WA EP 431 Exploration permit 100.00% Buru Energy Ltd Canning Basin, WA EP 436 Exploration permit 100.00% Buru Energy Ltd Canning Basin, WA EP 457 Exploration permit 60.00% Buru Fitzroy Pty Ltd Canning Basin, WA 1 Buru’s interest in L6 and EP 129 exclude the Backreef Area. 10 About Buru Energy Buru Energy is a Western Australian energy company headquartered in Perth with an operational office in Broome. The Company’s goal is to deliver material benefits to its shareholders, the State of Western Australia, the Traditional Owners and communities of the areas in which it operates. The Company plans to achieve this goal by building a compelling foundation Kimberley-based energy supply business based on its wholly owned Rafael conventional gas and condensate discovery. The Company’s petroleum assets and tenements are located onshore in the Canning Basin in the southwest Kimberley region of Western Australia. In the Kimberley it operates and owns 100% of the conventional gas condensate discovery at Rafael 1 and owns and operates 100% of the conventional Ungani Oilfield project. It also operates a Canning Basin wide portfolio of exploration permits and licences prospective for conventional and unconventional resources with working interests ranging from 60% to 100%. Forward Looking Statements This document has been prepared by Buru Energy Limited ABN 71 130 651 437 (“Buru Energy"). This report contains certain statements which may constitute "forward-looking statements". It is believed that the expectations reflected in these statements are reasonable but they may be affected by a variety of variables and changes in underlying assumptions which could cause actual results or trends to differ materially, including, but not limited to: price fluctuations, actual demand, currency fluctuations, drilling and production results, reserve and resource estimates, loss of market, industry competition, environmental risks, physical risks, legislative, fiscal and regulatory developments, economic and financial market conditions in various countries and regions, political risks, project delays or advancements, approvals and cost estimates. All of Buru’s operations and activities are subject to joint venture, regulatory and other approvals and their timing and order may also be affected by weather, availability of equipment and materials and land access arrangements, including native title arrangements. Although Buru believes that the expectations raised in this report are reasonable there can be no certainty that the events or operations described in this report will occur in the timeframe or order presented or at all. There are numerous uncertainties inherent in estimating reserves and resources, and in projecting future production, development expenditures, operating expenses and cash flows. Oil and gas reserve engineering and resource assessment must be recognised as a subjective process of estimating subsurface accumulations of oil and gas that cannot be measured in an exact way. Any reserves, contingent resources and prospective resources presented in this report are pursuant to the Company’s ASX releases of 11 September 2026, 19 August 2026, 14 August 2025, 17 June 2024 and 18 January 2018. The estimates of reserves, contingent and prospective resources included in this Presentation have been prepared in accordance with the definitions and guidelines set forth in the SPE PRMS. Buru Energy is not aware of any new information or data that materially affects the information included in this presentation and all material assumptions and technical parameters underpinning the estimates in this presentation continue to apply and have not materially changed. The probabilistic method was used to prepare the estimates of the contingent and prospective resources. No representation or warranty, expressed or implied, is made by Buru or any other person that the material contained in this report will be achieved or prove to be correct. Except for statutory liability which cannot be excluded, each of Buru, its officers, employees and advisers expressly disclaim any responsibility for the accuracy or completeness of the material contained in this report and excludes all liability whatsoever (including in negligence) for any loss or damage which may be suffered by any person as a consequence if any information in this report or any error or omission there from. Neither Buru nor any other person accepts any responsibility to update any person regarding any inaccuracy, omission or change in information in this report or any other information made available to a person nor any obligation to furnish the person with any further information. All references to $ are in Australian currency, unless stated otherwise. Rule 5.5 ASX Listing Rules Appendix 5B (17/07/20) Page 1 + See chapter 19 of the ASX Listing Rules for defined terms. Appendix 5B Mining exploration entity or oil and gas exploration entity quarterly cash flow report Name of entity BURU ENERGY LIMITED ABN Quarter ended (“current quarter”) 71 130 651 437 30 September 2026 Consolidated statement of cash flows Current quarter $A’000 Year to date (9 months) $A’000 1. Cash flows from operating activities - - 1.1 Receipts from customers 1.2 Payments for (486) (1,881) (a) exploration & evaluation (b) development - - (c) production (care and maintenance) (378) (568) (d) admin and corporate costs (staff) (215) (680) (e) admin and corporate costs (other) (208) (675) 1.3 Dividends received (see note 3) - - 1.4 Interest received 35 93 1.5 Interest and other costs of finance paid - - 1.6 Income taxes paid - - 1.7 Government grants and tax incentives 182 182 1.8 Net cash from / (used in) operating activities (1,070) (3,529) 2. Cash flows from investing activities - - 2.1 Payments to acquire or for: (a) entities (b) tenements - - (c) property, plant and equipment - - (d) exploration & evaluation (987) (3,215) (e) investments - - (f) other non-current assets - - Appendix 5B Mining exploration entity or oil and gas exploration entity quarterly cash flow report ASX Listing Rules Appendix 5B (17/07/20) Page 2 + See chapter 19 of the ASX Listing Rules for defined terms. Consolidated statement of cash flows Current quarter $A’000 Year to date (9 months) $A’000 2.2 Proceeds from the disposal of: - - (a) entities (b) tenements - - (c) property, plant and equipment 70 70 (d) investments - - (e) other non-current assets - - 2.3 Cash flows from loans to other entities - - 2.4 Dividends received (see note 3) - - 2.5 Others - - 2.6 Net cash from / (used in) investing activities (917) (3,145) 3. Cash flows from financing activities - 5,224 3.1 Proceeds from issues of equity securities (excluding convertible debt securities) 3.2 Proceeds from issue of convertible debt securities - - 3.3 Proceeds from exercise of options - 2 3.4 Transaction costs related to issues of equity securities or convertible debt securities (33) (236) 3.5 Proceeds from borrowings - - 3.6 Repayment of borrowings - - 3.7 Transaction costs related to loans and borrowings - - 3.8 Dividends paid - - 3.9 Other (provide details if material) - - 3.10 Net cash from / (used in) financing activities (33) 4,990 4. Net increase / (decrease) in cash and cash equivalents for the period 4.1 Cash and cash equivalents at beginning of period 4,482 4,149 4.2 Net cash from / (used in) operating activities (item 1.8 above) (1,070) (3,529) 4.3 Net cash from / (used in) investing activities (item 2.6 above) (917) (3,145) 4.4 Net cash from / (used in) financing activities (item 3.10 above) (33) 4,990 Appendix 5B Mining exploration entity or oil and gas exploration entity quarterly cash flow report ASX Listing Rules Appendix 5B (17/07/20) Page 3 + See chapter 19 of the ASX Listing Rules for defined terms. Consolidated statement of cash flows Current quarter $A’000 Year to date (9 months) $A’000 4.5 Effect of movement in exchange rates on cash held 2 (1) 4.6 Cash and cash equivalents at end of period 2,464 2,464 5. Reconciliation of cash and cash equivalents at the end of the quarter (as shown in the consolidated statement of cash flows) to the related items in the accounts Current quarter $A’000 Previous quarter $A’000 5.1 Bank balances 179 799 5.2 Term deposits 2,285 3,683 5.3 Bank overdrafts - - 5.4 Other (provide details) - - 5.5 Cash and cash equivalents at end of quarter (should equal item 4.6 above) 2,464 4,482 6. Payments to related parties of the entity and their associates Current quarter $A'000 6.1 Aggregate amount of payments to related parties and their associates included in item 1 84 6.2 Aggregate amount of payments to related parties and their associates included in item 2 - Note: if any amounts are shown in items 6.1 or 6.2, your quarterly activity report must include a description of, and an explanation for, such payments. Amounts included in 6.1 are remuneration payments made to Directors. Appendix 5B Mining exploration entity or oil and gas exploration entity quarterly cash flow report ASX Listing Rules Appendix 5B (17/07/20) Page 4 + See chapter 19 of the ASX Listing Rules for defined terms. 7. Financing facilities Note: the term “facility’ includes all forms of financing arrangements available to the entity. Add notes as necessary for an understanding of the sources of finance available to the entity. Total facility amount at quarter end $A’000 Amount drawn at quarter end $A’000 7.1 Loan facilities - - 7.2 Credit standby arrangements - - 7.3 Other (please specify) - - 7.4 Total financing facilities - - 7.5 Unused financing facilities available at quarter end - 7.6 Include in the box below a description of each facility above, including the lender, interest rate, maturity date and whether it is secured or unsecured. If any additional financing facilities have been entered into or are proposed to be entered into after quarter end, include a note providing details of those facilities as well. 8. Estimated cash available for future operating activities $A’000 8.1 Net cash from / (used in) operating activities (item 1.8) (1,070) 8.2 Payments for exploration & evaluation classified as investing activities (item 2.1(d)) (917) 8.3 Total relevant outgoings (item 8.1 + item 8.2) (1,987) 8.4 Cash and cash equivalents at quarter end (item 4.6) 2,464 8.5 Unused finance facilities available at quarter end (item 7.5) - 8.6 Total available funding (item 8.4 + item 8.5) 2,464 8.7 Estimated quarters of funding available (item 8.6 divided by item 8.3) 1.24 Note: if the entity has reported positive relevant outgoings (i.e. a net cash inflow) in item 8.3, answer item 8.7 as “N/A”. Otherwise a figure for the estimated quarters of funding available must be included in item 8.7. 8.8 If item 8.7 is less than 2 quarters, please provide answers to the following questions: 8.8.1 Does the entity expect that it will continue to have the current level of net operating cash flows for the time being and, if not, why not? Answer: Yes 8.8.2 Has the entity taken any steps, or does it propose to take any steps, to raise further cash to fund its operations and, if so, what are those steps and how likely does it believe that they will be successful? Answer: Yes