Sensitivity analysis for the main parameters of the discounted cash flow (gas price and quantity of gas sold) at December 31, <strong>2011</strong>Sensitivity/categoryFuture income, Thousand USDTotalPresentvaluediscountedat 10%Presentvaluediscountedat 15%Present valuediscounted at20% Sensitivity/category TotalFuture income, Thousand USD10% increase in the price/quantity of gas sales 10% decrease in the price/quantity of gas salesPresentvaluediscountedat 10%Presentvaluediscountedat 15%Present valuediscounted at20%P1 – Proved reserves 20,001 60,323 02,210 03,312 P1 – Proved reserves 06,061 31,6,3 36,1,0 06,061Probable reserves 0,,00 0,11, 0,202 0,011 Probable reserves 0,312 0,303 0,616 0,312Total P2 – Proved +probable reserves2,,326 63,010 01,331 00,113Total P2 – Proved +probable reserves03,103 3,,,12 32,,,3 03,103Possible reserves 6,061 6,101 6,002 0,130 Possible reserves 6,300 0,103 0,021 6,300Total P3 – Proved +probable + possible reserves10,606 66,,00 61,012 02,600Total P3 – Proved +probable + possible reserves15% increase in the price/quantity of gas sales 15% decrease in the price/quantity of gas sales02,060 00,10, 31,060 02,060P1 – Proved reserves 21,0,2 63,660 01,232 06,002 P1 – Proved reserves 01,606 32,662 33,,16 01,606Probable reserves 6,031 0,,60 0,130 0,60, Probable reserves 0,61, 0,661 0,030 0,61,Total P2 – Proved +probable reserves16,233 66,006 61,310 02,226Total P2 – Proved +probable reserves00,0,0 31,113 36,133 00,0,0Possible reserves 6,310 6,101 6,66, 0,1,1 Possible reserves 6,616 0,161 0,3,1 6,616Total P3 – Proved +probable + possible reserves11,101 61,6,0 66,6,, 01,023Total P3 – Proved +probable + possible reserves20% increase in the price/quantity of gas sales 20% decrease in the price/quantity of gas sales03,2,3 3,,600 32,063 03,2,3P1 – Proved reserves 11,661 66,216 61,6,0 02,,36 P1 – Proved reserves 31,,60 30,612 36,116 31,,60Probable reserves 6,321 6,161 0,101 0,202 Probable reserves 0,010 0,001 0,16, 0,010Total P2 – Proved +probable reserves16,,01 61,103 66,000 01,601Total P2 reserves – Proved+ probable reserves3,,066 36,202 33,120 3,,066Possible reserves 6,201 6,,26 6,301 0,12, Possible reserves 6,1,3 0,200 0,301 6,1,3Total P3 – Proved +probable + possible reserves 10,66, 21,216 60,161 61,001Total P3 reserves – Proved+ probable + possiblereserves00,606 31,611 30,31, 00,606Note: It is clarified that the discounted cash flow figures, whether they have been calculated at a specific discount rate or without a discount rate, represent thepresent value but not necessarily the fair value.Forward-looking information: The discounted cash flows set out above are forward-looking information as defined in the Securities Law. The information above isbased on various assumptions, including the rate and duration of natural gas sales from the reservoir, which may not materialize, and the quantity of natural gasactually produced could be different from these estimates and assumptions, inter alia, due to operational and technical conditions and/or changes in regulationand/or the supply and demand in the natural gas market and/or actual performance of the reservoir.A-31
(4) Production dataThe following table presents production data for the Mary-B field:Total output (attributable to the Partnership's share) inthe period (MMcf)Average price per production unit (attributable to thePartnership) (USD thousands per MMcf)Average royalties (each paymentderived from the output of the producingasset, including from the gross incomefrom the oil asset) paid per productionunit (attributable to the Partnership'sshare) (USD thousands per MMcf)The StateThird partiesAverage production costs per production unit(attributable to the Partnership's share) (USD thousandsper MMcf)Average production costs per production unit(attributable to the Partnership's share) (USD thousandsper MMcf)<strong>2011</strong> 2010 200935,2674.711.53 1.3,1.03 1.0115,,05 19,03,,.19 9.,70.39Stakeholders 1.00 1.1, 0.400.223.71.16 1.1909.00 1.58<strong>Oil</strong> and gas profits levy: 0.27 - -Average net intake per production unit after oil and gasprofits tax (attributable to the Partnership's share) (inUSD thousands for MMcf)3.43Depletion rate in the reporting period in relation to the42.8overall quantity of gas in the reservoir (%) 349.00 1.5819 05.8(5) Opinion of the appraiserThe reserves report prepared by NSAI at December 31, <strong>2011</strong> is attached to this reportas Appendix A and includes the consent of NSAI to attach them to this report.(6) Management declaration(7) Declaration date: March 28, 2012(8) Name of reporting corporation: <strong>Avner</strong> <strong>Oil</strong> Exploration(9) Name of officer for assessment of the resources: Gideon Tadmor(10) We hereby confirm that the assessor received all the relevant information required toperform the work.(11) We hereby confirm that nothing came to our attention that indicates any dependencebetween the assessor and the Partnership.(12) We hereby confirm that the preparation of the resource assessment and thedisclosure therein are our responsibility.(13) We hereby confirm that to the best of our knowledge, the resources assessed by theassessor are the most relevant, accurate and updated estimates available to us.(14) We hereby confirm that no change has been made to the identity of the assessorpreparing the reserves report or the most recent contingent resources report issued bythe Partnership.(15) We agree to include this statement in this report.Gideon Tadmor34The depletion rate is the annual percentage of gas produced out of the proved and probable reserves at thebeginning of that year.A-32
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(B)(C)The report was based on the r
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At the signing date of the letter o
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(G)addition, Yam Tethys partners ha
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(4) The gas price stipulated in the
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energy market is characterized by h
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The dollar-denominated loan bears a
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tests 157 ; compliance with the res
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(E)financing agreement; purchase of
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(C)Tamar financing agreementFinanci
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As set out above, under licenses an
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The gas facilities that the license
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subsection (4) below exist (conditi
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(N)(O)(9) If a revised assessment i
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# Assumption Details and explanatio
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7.24 AntitrustOn October 12, 2000,
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(C)For expenses associated with dev
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(F)(G)(H)committee of the joint ven
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(L)(M)(N)(O)accumulated according t
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(D)(E)Subject to the terms of the o
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(I)(J)committee meetings, and will
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obtaining Cypriot government approv
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(5) It is noted that under Regulati
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Contingent agreements for the sale
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had not yet been received, although
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Liquefaction (LNG) The Partnership
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7.30 Risk factorsOil and gas explor
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in deviations in the budget (expect
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process for transferring the rights
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GlossaryAppraisal well: a drilling
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Avner Oil Exploration Limited Partn
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The effects of the increase in sale
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USD 6.5 million, as noted above. In
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investment in development of the Ta
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marine areas on the Cyprus continen
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Part II: Market Risks - Exposure an
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As collateral for the Partnership's
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3. Independent directorsThe Compani
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4) Accepting a financial liability
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Project cash flow (in USD millions)
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AVNER OIL EXPLORATION (LIMITED PART
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Auditors' Report to the Partners of
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Untimely Meditationshad only you, t
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Regulation 10A: Summary of the Part
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Regulation 12:Regulation 13:Regulat
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C. Interested parties in the Partne
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Regulation 24:will not be able to d
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Regulation 24B: Holders of the Part
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10. Occupation in the past five yea
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9. Education: LLB, Tel Aviv Univers
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Ronen Edward (ID 024652745)1. Date
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executive liability insurance, base
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Avner Oil Exploration - Limited Par
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Declaration of the CFO based on Reg