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Yoho Resources Inc. Announces Year End Financial Results, Corporate Reserves and Duvernay and Montney Contingent Resource Assessments

Thursday, November 22, 2012

Yoho Resources Inc. Announces Year End Financial Results, Corporate Reserves and Duvernay and Montney Contingent Resource Assessments09:00 EST Thursday, November 22, 2012CALGARY, ALBERTA--(Marketwire - Nov. 22, 2012) - Yoho Resources Inc. (TSX VENTURE:YO) ("Yoho" or the "Company") has filed today on SEDAR the financial statements for the year ended September 30, 2012 and the related managements' discussion and analysis ("MD&A"). Yoho today also filed its Annual Information Form for the year ended September 30, 2012 which includes the Company's reserves data and other oil and gas information for the year ended September 30, 2012 as mandated by National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities of the Canadian Securities Administrators ("NI 51-101"). Copies of these documents may be found on www.sedar.com.Yoho is also pleased to announce the results of a reserve and contingent resource assessment of the Company's Kaybob Duvernay assets and an updated reserve and contingent resource assessment of certain of the Company's Nig Montney assets as evaluated by GLJ Petroleum Consultants Ltd. ("GLJ").HighlightsYoho's proved plus probable reserves as evaluated by GLJ as at September 30, 2012 increased 96% to 27.4 MMboe from 14.0 MMboe at September 30, 2011. The Company's proved reserves as at September 30, 2012 increased 40% to 10.8 MMboe from 7.7 MMboe. The percentage of Yoho's proved plus probable reserves that are natural gas liquids has increased to 29% at September 30, 2012 from 17% at September 30, 2011. The net present value of Yoho's estimated future net revenue before income taxes from proved plus probable reserves as at September 30, 2012 and utilizing GLJ's October 1, 2012 price forecast and discounted at 10%, is $216.4 million and the net present value of total proved reserves as at September 30, 2012 is $87.7 million Yoho's production during fiscal 2011 averaged 2,207 boe per day, a 10% decrease from fiscal 2011 production of 2,475 boe per day. Fiscal 2012 production was impacted by disruptions in third party pipelines and a resulting delay in obtaining regulatory approvals for re-commissioning. These disruptions have been remedied and current production is estimated at 2,500 boe per day. Yoho has an additional 700 boe per day behind pipe to be tied-in following completion of pipeline construction. Notwithstanding a year of low natural gas prices, Yoho generated funds from operations for fiscal 2012 of $9.9 million ($0.22 per share basic and diluted). Net exploration and development expenditures for fiscal 2012 were $34.2 million. During the year ended September 30, 2012, Yoho drilled 8 (3.7 net) gas wells with an overall success rate of 100%. All of the wells drilled in fiscal 2012 were individual, unconventional delineation wells. Yoho maintained a flexible balance sheet with total net debt of $18.5 million at September 30, 2012 on a bank credit facility of $52 million. Reserve replacement was 484% on proved reserves and 1,760% on proved plus probable reserves. For fiscal 2012, Yoho achieved all-in finding, development and acquisition costs of $16.30 per boe (including all technical revisions and changes in future development capital). For the past three years, Yoho's rolling average finding, development and acquisition costs were $15.95 per boe (including all technical revisions and changes to future development capital). Total future development capital for Yoho's proved plus probable reserves at September 30, 2012 is $284.3 million scheduled over five years. Total future development capital for Yoho's total proved reserves at September 30, 3012 is $99.5 million scheduled over three years. Yoho's proved plus probable reserve life index (RLI), based on average fiscal 2012 production, increased by 112% to 34 years from 16 years at September 30, 2012. At September 30, 2012 Yoho had 135,200 net acres of undeveloped land with an internally estimated value of $75.4 million. Yoho's net asset value per share as at September 30, 2012 is calculated at $5.43 per share (basic) including an internal land value of $75.4 million and $3.93 per share (basic) excluding land value. The best estimate for the Company's Contingent Resources for the evaluated area at Kaybob in the Duvernay formation is 47.3 MMboe net as at September 30, 2012, consisting of 162.6 bcf of natural gas and 20.2 million barrels of natural gas liquids. This estimate excludes all proved plus probable reserves assigned to Yoho's interests at Kaybob by GLJ as at September 30, 2012. The best estimate of the Kaybob Duvernay Contingent Resources has a net present value to Yoho of $255.0 million (after the recovery of all anticipated capital) using a discount rate of 10% and utilizing the GLJ price forecast as at October 1, 2012. The net present value of the Kaybob Duvernay Contingent Resources is $5.07 per share basic. This value has not been included in the calculation of Yoho's net asset value. The best estimate for the Company's Contingent Resources for the evaluated area at Nig in the Upper Montney formation is 52.7 MMboe net as at September 30, 2012, consisting of 266.3 bcf of natural gas and 8.3 million barrels of natural gas liquids. This estimate excludes all proved plus probable reserves assigned to Yoho's interest at Nig by GLJ as at September 30, 2012. The best estimate of the Nig Montney Contingent Resources has a net present value to Yoho of $194.9 million (after the recovery of all anticipated capital) using a discount rate of 10% and utilizing the GLJ price forecast as at October 1, 2012. The net present value of the Nig Montney Contingent Resources is $3.87 per share basic. This value has not been included in the calculation of Yoho's net asset value.FINANCIALYear ended September 30, 2012Year ended September 30, 2011Financial ($)Petroleum and natural gas sales23,177,16029,523,389Funds from operations (1)9,917,53214,618,416per share - basic0.220.38per share - diluted0.220.38Net loss(8,899,211)(6,196,510)per share - basic(0.20)(0.16)per share - diluted(0.20)(0.16)Net exploration and development expenditures34,696,55535,029,751Net acquisitions and dispositions(488,352)(810,000)Total assets154,495,876138,595,121Total debt (including working capital deficiency)18,505,73022,622,390Shareholders' equity113,911,02393,684,548Weighted average common shares outstandingBasic44,922,72838,183,816Diluted44,922,72838,183,816Notes: (1) Funds from operations is calculated as cash provided by operating activities, adding the change in non-cash working capital, decommissioning obligation expenditures, the transportation liability charge and acquisition costs. Funds from operations is used to analyze the Company's operating performance and leverage. Funds from operations does not have a standardized measure prescribed by International Financial Reporting Standards ("IFRS") and therefore may not be comparable with the calculations of similar measures for other companies. Yoho's calculation of funds from operations is detailed in the MD&A for the years ended September 30, 2012 and 2011. Year ended September 30, 2012Year ended September 30, 2011OperationsProductionNatural gas (mcf/d)10,02211,435Oil and NGL (bbls/d)537569Combined (boe/d)2,2072,475Realized sales pricesNatural gas ($/mcf)2.393.62Oil and NGL ($/bbl)73.3269.46Funds from operations per boe ($/boe)Petroleum and natural gas sales28.6832.68Royalties(2.84)(3.89)Operating expenses(10.70)(10.39)Operating netback (2)15.1418.40General and administrative(3.29)(2.86)Interest(0.94)(0.71)Realized gain on financial derivative contracts1.371.35Funds from operations (1)12.2816.18Drilling activityTotal wells89Working interest wells3.74.7Success rate on working interest wells100%100%Undeveloped land (net acres)135,266151,812Notes: (1) Funds from operations is calculated as cash provided by operating activities, adding the change in non-cash working capital, decommissioning obligation expenditures, the transportation liability charge and acquisition costs. Funds from operations is used to analyze the Company's operating performance and leverage. Funds from operations does not have a standardized measure prescribed by IFRS and therefore may not be comparable with the calculations of similar measures for other companies. Yoho's calculation of funds from operations is detailed in the MD&A for the years ended September 30, 2012 and 2011. (2) Operating netback equals petroleum and natural gas sales including realized hedging gains and losses on commodity contracts less royalties, operating costs and transportation costs calculated on a boe basis. Operating netback and funds from operations netback do not have a standardized measure prescribed by IFRS and therefore may not be comparable with the calculations of similar measures for other companies.FINANCIALNotwithstanding a year of low natural gas prices, Yoho generated funds from operations for fiscal 2012 of $9.9 million ($0.22 per share basic and diluted). The fiscal 2012 capital program focused on drilling individual, unconventional delineation wells, primarily at Kaybob, Alberta and Nig, British Columbia. Yoho did not drill any wells on conventional style plays during fiscal 2012. As a result of decreasing natural gas prices during fiscal 2012, the Company recognized an $8.8 million impairment on its conventional cash generating units. Total net debt at September 30, 2012 was $18.5 million on a bank credit facility of $52 million. OPERATIONS UPDATEKaybob DuvernayYoho is currently drilling the first two horizontal Duvernay development wells from a pad site at 15P-16-62-21 W6 on the Yoho operated Tony Creek block. The wells are expected to be drilled and completed by the end of December 2012, with production testing of the well in early 2013. Construction of an 11.2 kilometer pipeline from the padsite to a SemCams pipeline has recommenced now that surface conditions have improved in the area with completion expected in early 2013. Upon completion of the pipeline construction, the 13-22-62-21 W5 horizontal well, along with the 15P-16 pad production, will be brought on-stream.Nig MontneyThe 7.2 kilometer Yoho operated pipeline at Nig (50% working interest) has been completed and previously shut-in production from the d-97-H/94-H-4 gas/liquids well located in the northern portion of the Company's land block was placed on production on November 20, 2012. This pipeline is part of Yoho's development plan in the Nig area and will facilitate timely tie-in of future development wells. LAND HOLDINGSThe Company internally estimated the fair market value of its net undeveloped land holdings as at September 30, 2012 to be $75.4 million. This evaluation was completed principally using industry activity levels, third party transactions and land acquisitions that occurred in proximity to Yoho's undeveloped lands during the previous 12 months. A summary of the Company's land holdings at September 30, 2012 is outlined below:Developed AcresUndeveloped AcresTotal AcresLocationGross (1)Net (2)Gross (1)Net (2)Gross (1)Net (2)Alberta74,80534,755115,24566,165190,049100,920British Columbia53,17931,04399,24169,101152,420100,114Other324117--324117Total128,30865,915214,486135,266342,793201,181Notes:(1) "Gross" means the total area of properties in which the Company has an interest. (2) "Net" means the total area in which the Company has an interest multiplied by the working interest owned by the Company.CORPORATE RESERVESThe reserves data set forth below is based upon an independent reserve assessment and evaluation prepared by GLJ dated November 15, 2012 with an effective date of September 30, 2012 (the "GLJ Report"). The following presentation summarizes the Company's crude oil, natural gas liquids and natural gas reserves and the net present values before income taxes of future net revenue for the Company's reserves using forecast prices and costs based on the GLJ Report. The GLJ Report has been prepared in accordance with the standards contained in the Canadian Oil and Gas Evaluation Handbook (the "COGE Handbook") and the reserve definitions contained in NI 51-101.All evaluations and reviews of future net cash flows are stated prior to any provisions for interest costs or general and administrative costs and after the deduction of estimated future capital expenditures for wells to which reserves have been assigned. It should not be assumed that the estimates of future net revenues presented in the tables below and in the "Highlights" section above represent the fair market value of the reserves. There is no assurance that the forecast prices and cost assumptions will be attained and variances could be material. The recovery and reserve estimates of our crude oil, natural gas liquids and natural gas reserves provided herein are estimates only and there is no guarantee that the estimated reserves will be recovered. Actual crude oil, natural gas and natural gas liquids reserves may be greater than or less than the estimates provided herein. Reserves SummaryThe Company's total proved plus probable reserves increased by 96% in fiscal 2012 to 27,449 Mboe. Proved reserves increased by 40% to 10,821 Mboe and comprised 39% of the Company's total proved plus probable reserves. Proved undeveloped reserves are 54% of the total proved reserves. The future capital in the GLJ Report (undiscounted) is $284.3 million for the proved and probable reserves and is $99.5 million for total proved reserves.The following table provides summary reserve information based upon the GLJ Report and using the published GLJ (October 1, 2012) price forecast.Light and Medium OilHeavy OilNatural Gas LiquidsCompany Interest (1)Net (2)Company Interest (1)Net(2)Company Interest (1)Net (2)(Mbbl)(Mbbl)(Mbbl)(Mbbl)(Mbbl)(Mbbl)Proved producing2812189681577422Non-producing11--180137Undeveloped11489--1,6251,238Total proved39630796812,3821,797Probable52742628245,4414,057Total proved & probable9227331241057,8235,855Natural GasTotal Barrels of Oil Equivalent (3)Company Interest (1)Net (2)Company Interest (1)Net (2)(Mmcf)(Mmcf)(Mboe)(Mboe)Proved producing19,97818,0304,2843,726Non-producing2,8652,514658557Undeveloped24,84122,0755,8795,006Total proved47,68442,61810,8219,289Probable63,79357,29716,62814,056Total proved & probable111,47799,91627,44923,345Notes:(1) "Company Interest" reserves means Yoho's working interest (operating and non-operating) share before deduction of royalties and including any royalty interest of the Company. (2) "Net" reserves means Yoho's working interest (operated and non-operated) share after deduction of royalty obligations, plus Yoho's royalty interest in reserves. (3) Oil equivalent amounts have been calculated using a conversion rate of six thousand cubic feet of natural gas to one barrel of oil. BOEs may be misleading, particularly if used in isolation. A BOE conversion ratio of six thousand cubic feet of natural gas to one barrel of oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6 mcf: 1 bbl, utilizing a conversion ratio of 6 mcf: 1 bbl may be a misleading indication of value. (4) May not add due to rounding.Reserves ValuesThe estimated before tax net present value of future net revenues associated with Yoho's reserves effective September 30, 2012 and based on the published GLJ (October 1, 2012) future price forecast are summarized in the following table:Discounted atUndiscounted5%10%15%20%(M$)Proved producing92,19669,05155,30846,32240,024Non-producing15,33311,2768,8507,2616,143Undeveloped97,10948,82623,5589,042112Total proved204,638129,15387,71662,62646,280Probable464,657227,455128,70879,12150,802Total proved plus probable669,294356,608216,424141,74797,082Notes:(1) The estimated future net revenues are stated before deducting future estimated site restoration costs and are reduced for estimated future abandonment costs and estimated capital for future development associated with the reserves. (2) The net present value of future revenues does not represent fair market value. (3) May not add due to rounding.The following table sets forth development costs deducted in the estimation of the future net revenue attributable to the reserve categories noted below.Forecast Prices and CostsProved ReservesProved Plus Probable ReservesYear(M$)(M$)20122,4672,467201331,55861,026201453,61790,880201511,86747,8122016-51,6322017-30,1972018--2019-1262020-2021--Remainder-196Total Undiscounted (all years)99,509284,335Total discounted 10%86,330228,382Price ForecastThe GLJ October 1, 2012 price forecast is summarized as follows:$US/$CdnWTI @EdmontonHardisty HeavyNatural gasWestcoastYearExchangeCushinglight crude oil12 APIat AECO-CStation 2Ratespot(US$/bbl)(C$/bbl)($Cdn/bbl)(C$/MMbtu)(C$/MMbtu)2012 Q41.0092.5090.5066.782.922.7220130.9892.5092.3569.003.443.2420140.9895.0095.9272.573.903.7020150.9897.5098.4774.534.364.1620160.98100.00101.0276.484.824.6220170.98100.00101.0276.485.054.8520180.98101.35102.4077.545.435.2320190.98103.38104.4779.135.545.3420200.98105.45106.5880.755.655.4520210.98107.56108.7382.405.765.56Thereafter-+2.0%/yr+2.0%/yr+2.0%/yr+2.0%/yr+2.0%/yrNotes:(1) Inflation is accounted for at 2.0% per yearThe following table compares the GLJ October 1, 2012 price forecast with the GLJ October 1, 2011 price forecast. AECO Spot Gas $/MmbtuEdmonton Light Sweet Crude $/BblYearOctober 1, 2012October 1, 2011Variance %October 1, 2012October 1, 2011Variance %2012 Q42.923.90(25.1)90.5091.84(1.5)20133.444.36(21.1)92.3594.39(2.2)20143.904.59(15.0)95.9296.94(1.1)20154.365.05(13.7)98.47102.02(2.5)20164.825.51(12.5)101.02101.02(-)20175.055.97(15.4)101.02102.41(1.4)20185.436.43(15.6)102.40104.47(2.0)Capital Program Efficiency The efficiency of the Company's capital program for the fiscal year ended September 30, 2012 is summarized below.20122011 (5)Three Year Average 2010 - 2012ProvedProvedProvedplusplusplusProvedProbableProvedProbableProvedProbableExploration and development expenditures($ thousands)33,61533,61535,03035,03091,44091,440Net acquisitions ($ thousands) (2)593593(810)(810)20,94020,940Change in future development capital - exploration and development ($thousands)57,431197,60631,66761,73097,007276,897Total91,639231,81465,88795,950209,387389,277Reserves additions after revisions (Mboe) (4)- Exploration and development3,78014,0252,9166,1068,58123,121- Revisions110116(16)(277)334(36)- Net acquisitions2582(18)(23)8021,324- Total reserve additions after revisions3,91514,2232,8825,8069,71724,409Finding & Development Costs ($/boe)(1)23.4016.3523.0016.6021.1415.96Finding, Development & Acquisition Costs ($/boe) (3)23.4116.3022.8616.5221.5515.95Reserves Replacement Ratio484%1,760%319%643%383%961%Notes:(1) The aggregate of the exploration and development costs incurred in the most recent financial year and the change during that year in estimated future development costs generally will not reflect total finding and development costs related to reserve additions for that year. (2) Acquisition costs related to corporate acquisitions reflects the consideration paid for the shares acquired plus the net debt assumed, both valued at closing and does not reflect the fair market value allocated to the acquired oil and gas assets under IFRS. (3) Calculation includes reserve revisions and changes in future development costs. Yoho also calculates finding, development and acquisition ("FD&A") costs which incorporate both the costs and associated reserve additions related to acquisitions net of any dispositions during the year. Since acquisitions can have a significant impact on Yoho's annual reserve replacement costs, the Company believes that FD&A costs provide a more meaningful representation of Yoho's cost structure than finding and development costs alone. (4) Oil equivalent amounts have been calculated using a conversion rate of six thousand cubic feet of natural gas to one barrel of oil. BOEs may be misleading, particularly if used in isolation. A BOE conversion ratio of six thousand cubic feet of natural gas to one barrel of oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6 mcf: 1 bbl, utilizing a conversion ratio of 6 mcf: 1 bbl may be a misleading indication of value. (5) Exploration and development expenditures for 2011 have been adjusted from previous year's disclosure to comply with IFRS.Net Asset ValueThe following table provides a calculation of Yoho's estimated net asset value and net asset value per share as at September 30, 3012 based on the estimated future net revenues associated with Yoho's proved plus probable reserves discounted at 10% as presented in the GLJ Report. The values in this table do not include the net present value assigned to either of the Company's Contingent Resource Reports. Forecast Prices and Costs before tax($ thousands)Proved plus probable reserves - discounted at 10%216,424Undeveloped land (1)75,400Bank debt and working capital deficiency as at September 30, 2012 (2)(18,506)Net asset value273,318Common shares outstanding at September 30, 2012 (thousands) - Basic50,332Net asset value per share - basic$ 5.43Net asset value per share - basic (excluding land value)$ 3.93Notes:(1) Internally estimated value (see "Land Holdings"). (2) Working capital deficiency includes an estimate of the Company's accounts receivable and future tax less accounts payable and accrued liabilities and derivatives as at September 30, 2012.RESOURCE AND RESERVES EVALUATION FOR KAYBOB DUVERNAYGLJ was engaged to prepare an independent evaluation report of Yoho's reserves and contingent resources at Kaybob, Alberta effective as at September 30, 2012 (the "GLJ Kaybob Report"). The GLJ Kaybob Report is dated November 15, 2012 and was prepared in accordance with NI 51-101 and the COGE Handbook. The GLJ Kaybob Report is the first independent assessment prepared for Yoho for the Duvernay at Kaybob and evaluated 100% of Yoho's acreage at Kaybob. Resource EvaluationSummary of Company Duvernay Contingent Resources (1)(2)(3)(4)(5)Forecast Prices and CostsAs at September 30, 2012Natural GasNatural Gas LiquidsBOE(MMcf)(Mbbl)(MBoe)Low Estimate (5)133,61614,09036,360Best Estimate (5)162,57620,22647,322High Estimate (5)244,03536,40677,079Notes:(1) Yoho's total working interest contingent resources are before deducting royalties owned by others. (2) Oil equivalent amounts have been calculated using a conversion rate of six thousand cubic feet of natural gas to one barrel of oil. BOEs may be misleading, particularly if used in isolation. A BOE conversion ratio of six thousand cubic feet of natural gas to one barrel of oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6 mcf: 1 bbl, utilizing a conversion ratio of 6 mcf: 1 bbl may be a misleading indication of value.(3) The estimates of contingent resources for individual properties may not reflect the same confidence level as estimates of net present values for all properties, due to the effects of aggregation.(4) May not add due to rounding.(5) See note on probabilities under "Special Note Regarding Disclosure of Reserves or Resources" below.Summary of Company Duvernay Contingent Resources Net Present Values of Future Revenue (1)(2)(3)(4)(5)(6)Forecast Prices and CostsBefore Income Taxes ($ thousands) as at September 30, 2012Discounted atUndiscounted5%10%15%20%Low Estimate (6)731,676263,85283,4967,620(25,697)Best Estimate (6)1,485,280572,114255,051121,52257,984High Estimate (6)3,273,6721,328,367680,485395,949248,553Notes:(1) The estimated future net revenues are stated before deducting income taxes and future estimated site restoration costs, and are reduced for estimated future abandonment costs and estimated capital for future development associated with the contingent resource.(2) It should not be assumed that the undiscounted and discounted net present values represent the fair market value of the contingent resource.(3) The estimates of net present values for individual properties may not reflect the same confidence level as estimates of net present values for all properties, due to the effects of aggregation.(4) Based on GLJ's price deck dated October 1, 2012.(5) Numbers in this table are subject to rounding error.(6) See note on probabilities under "Special Note Regarding Disclosure of Reserves or Resources" below.Contingent resources are those quantities of petroleum estimated, as of a given date, to be potentially recoverable from known accumulations using established technology or technology under development, but which are not currently considered to be commercially recoverable due to one or more contingencies. Contingencies which must be overcome to enable the reclassification of contingent resources as reserves can be categorized as economic, non-technical and technical. The COGE Handbook identifies non-technical contingencies as legal, environmental, political and regulatory matters or a lack of markets. There are several non-technical contingencies that prevent the classification of the contingent resources estimated above as being classified as reserves. The primary contingency which prevents the classification of Yoho's contingent resources as reserves is the current early stage of development. Additional drilling, completion, and testing data is generally required before Yoho can commit to their development. It is also appropriate to classify as contingent resources the estimated discovered recoverable quantities associated with a project in the early evaluation stage. As additional drilling takes place, it is expected that the contingent resources will be booked into the reserves category. Estimates of contingent resources described herein are estimates only; the actual resources may be higher or lower than those calculated in the GLJ Kaybob Report. There is no certainty that it will be commercially viable to produce any portion of the resources described in the evaluation.The most significant positive and negative factors with respect to the contingent resource estimates relate to the fact that the field is currently at an evaluation/delineation stage. Resource-in-place, productivity and capital costs may be higher or lower than current estimates. Additional drilling and testing are required to confirm volumetric estimates and reservoir productivity for the contingent resources to be reclassified as reserves. Reserves EvaluationAfter the recent drilling success at Kaybob, the Company's working interest of total proved plus probable reserves for the Duvernay at Kaybob as at September 30, 2012 is estimated by GLJ to be 15.0 MMboe. As at September 30, 2011, a total of 2.6 MMboe of proved plus probable reserves were assigned to the Duvernay at Kaybob. The reserves evaluation incorporates approximately 23% of Yoho's land base at Kaybob, Alberta. Summary of Kaybob Duvernay Company Working Interest Reserves(1) (2) (3) (4) (5) Forecast Prices and CostsAs at September 30, 2012Natural GasNatural Gas LiquidsBOE Total Barrels of Oil Equivalent(MMcf)(Mbbl)(MBoe)Proved producing1,377155385Total proved13,9021,6063,923Total probable37,5544,85611,115Total proved plus probable51,4566,46215,038Notes:(1) Yoho's total working interest means Yoho's working interest (operated and non-operated) share before deducting royalties and including any royalty interests of the Company.(2) Oil equivalent amounts have been calculated using a conversion rate of six thousand cubic feet of natural gas to one barrel of oil. BOEs may be misleading, particularly if used in isolation. A BOE conversion ratio of six thousand cubic feet of natural gas to one barrel of oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6 mcf: 1 bbl, utilizing a conversion ratio of 6 mcf: 1 bbl may be a misleading indication of value.(3) The estimates of reserves for individual properties may not reflect the same confidence level as estimates of reserves for all properties, due to the effects of aggregation.(4) Includes non-associated gas, associated gas and solution gas.(5) Numbers in this table are subject to rounding error.Summary of Kaybob Duvernay Company Net Present Value of Future Revenue from Reserves(1) (2) (3) (4) (5)Forecast Prices and CostsBefore Income Taxes ($ thousands)As at September 30, 2012Discounted atUndiscounted5%10%Total proved87,03949,88730,298Total probable341,811165,51693,740Total proved plus probable428,820215,403124,038Notes:(1) The estimated future net revenues are stated before deducting income taxes and future estimated site restoration costs, and are reduced for estimated future abandonment costs and estimated capital for future development associated with the reserves.(2) It should not be assumed that the undiscounted and discounted net present values represent the fair market value of the reserves.(3) The estimates of net present values for individual properties may not reflect the same confidence level as estimates of net present values for all properties, due to the effects of aggregation.(4) Based on GLJ's price deck dated October 1, 2012.(5) Numbers in this table are subject to rounding error.RESOURCE AND RESERVES EVALUATION FOR NIG MONTNEYGLJ was engaged to prepare an independent evaluation report of Yoho's reserves and contingent resources at Nig, British Columbia effective as at September 30, 2012 (the "GLJ Nig Report"). The GLJ Nig Report is dated November 15, 2012 and was prepared in accordance with NI 51-101 and the COGE Handbook. The GLJ Nig Report is an update to the report previously prepared by GLJ which evaluated approximately 55% of Yoho's acreage at Nig. As a result of recent drilling activity during fiscal 2012, GLJ has now been able to evaluate a total of 82% of the Company's acreage at Nig.Nig MontneyResource EvaluationSummary of Company Montney Contingent Resources (1)(2)(3)(4)(5)Forecast Prices and CostsAs at September 30, 2012Natural GasNatural Gas LiquidsBOE(MMcf)(Mbbl)(MBoe)Low Estimate (5)206,2126,41540,784Best Estimate (5)266,3648,28752,681High Estimate (5)324,94810,10964,267Notes:(1) Yoho's total working interest contingent resources are before deducting royalties owned by others. (2) Oil equivalent amounts have been calculated using a conversion rate of six thousand cubic feet of natural gas to one barrel of oil. BOEs may be misleading, particularly if used in isolation. A BOE conversion ratio of six thousand cubic feet of natural gas to one barrel of oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6 mcf: 1 bbl, utilizing a conversion ratio of 6 mcf: 1 bbl may be a misleading indication of value. (3) The estimates of contingent resources for individual properties may not reflect the same confidence level as estimates of net present values for all properties, due to the effects of aggregation.(4) May not add due to rounding.(5) See note on probabilities under "Special Note Regarding Disclosure of Reserves or Resources" below.Summary of Company Montney Contingent Resources Net Present Values of Future Revenue (1)(2)(3)(4)(5)(6)Forecast Prices and CostsBefore Income Taxes ($ thousands) as at September 30, 2012Discounted atUndiscounted5%10%15%20%Low Estimate (6)836,704320,526133,85857,91124,112Best Estimate (6)1,317,426470,152194,96188,47441,674High Estimate (6)1,806,191615,225256,833121,63361,994Notes:(1) The estimated future net revenues are stated before deducting income taxes and future estimated site restoration costs, and are reduced for estimated future abandonment costs and estimated capital for future development associated with the contingent resource.(2) It should not be assumed that the undiscounted and discounted net present values represent the fair market value of the contingent resource.(3) The estimates of net present values for individual properties may not reflect the same confidence level as estimates of net present values for all properties, due to the effects of aggregation.(4) Based on GLJ's price deck dated October 1, 2012.(5) Numbers in this table are subject to rounding error.(6) See note on probabilities under "Special Note Regarding Disclosure of Reserves or Resources" below.Contingent resources are those quantities of petroleum estimated, as of a given date, to be potentially recoverable from known accumulations using established technology or technology under development, but which are not currently considered to be commercially recoverable due to one or more contingencies. Contingencies which must be overcome to enable the reclassification of contingent resources as reserves can be categorized as economic, non-technical and technical. The COGE Handbook identifies non-technical contingencies as legal, environmental, political and regulatory matters or a lack of markets. There are several non-technical contingencies that prevent the classification of the contingent resources estimated above as being classified as reserves. The primary contingency which prevents the classification of Yoho's contingent resources as reserves at Nig is the current early stage of development. Additional drilling, completion, and testing data is generally required before Yoho can commit to their development. As additional drilling and/or development takes place, it is expected that some or all of the contingent resources will be booked as reserves. Additional drilling and testing are required to confirm volumetric estimates and reservoir productivity for the contingent resources to be reclassified as reserves. It is also appropriate to classify as contingent resources the estimated discovered recoverable quantities associated with a project in the early evaluation stage. As additional drilling takes place, it is expected that the contingent resources will be booked into the reserves category. The most significant positive and negative factors with respect to the contingent resource estimates at Nig relate to the fact that the field is currently at an evaluation/delineation stage. At Nig, the Montney formation is areally extensive in this region; however, well control in certain areas of Yoho's lands is limited. As well, the resource evaluation includes the Upper Montney only and does not include an assessment of the Lower Montney which the Company considers prospective over its land base. Resource-in-place, productivity and capital costs may be higher or lower than current estimates. There is no certainty that it will be commercially viable to produce any portion of the resources described in the evaluation. Reserves EvaluationAfter the recent drilling success at Nig, the Company's interest of total proved plus probable reserves for the Montney at Nig as at September 30, 2012 is estimated by GLJ to be 4.9 MMboe. As at September 30, 2011, a total of 3.4 MMboe of proved plus probable reserves were assigned to the Montney at Nig. The reserves evaluation incorporates approximately 6% of Yoho's land base at Nig, British Columbia.Summary of Nig Montney Company Working Interest Reserves(1) (2) (3) (4) (5) Forecast Prices and CostsAs at September 30, 2012Natural GasNatural Gas LiquidsBOE Total Barrels of Oil Equivalent(MMcf)(Mbbl)(MBoe)Proved producing2,64596536Total proved11,5223722,292Total probable13,2864182,632Total proved plus probable24,8087904,924Notes:(1) Yoho's total working interest means Yoho's working interest (operated and non-operated) share before deducting royalties and including any royalty interests of the Company.(2) Oil equivalent amounts have been calculated using a conversion rate of six thousand cubic feet of natural gas to one barrel of oil. BOEs may be misleading, particularly if used in isolation. A BOE conversion ratio of six thousand cubic feet of natural gas to one barrel of oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6 mcf: 1 bbl, utilizing a conversion ratio of 6 mcf: 1 bbl may be a misleading indication of value.(3) The estimates of reserves for individual properties may not reflect the same confidence level as estimates of reserves for all properties, due to the effects of aggregation.(4) Includes non-associated gas, associated gas and solution gas.(5) Numbers in this table are subject to rounding error.Summary of Nig Montney Company Net Present Value of Future Revenue from Reserves(1) (2) (3) (4) (5)Forecast Prices and CostsBefore Income Taxes ($ thousands)As at September 30, 2012Discounted atUndiscounted5%10%Total proved33,45018,71110,851Total probable53,60024,37212,159Total proved plus probable87,05043,08323,010Notes:(1) The estimated future net revenues are stated before deducting income taxes and future estimated site restoration costs, and are reduced for estimated future abandonment costs and estimated capital for future development associated with the reserves.(2) It should not be assumed that the undiscounted and discounted net present values represent the fair market value of the reserves.(3) The estimates of net present values for individual properties may not reflect the same confidence level as estimates of net present values for all properties, due to the effects of aggregation.(4) Based on GLJ's price deck dated October 1, 2012.(5) Numbers in this table are subject to rounding error.OUTLOOKFor fiscal 2013, Yoho is currently planning a total capital program of between $35.0 and $38.0 million. The exploration program and related capital budget is weighted to drilling the two unconventional plays at Kaybob and Nig, with the majority of the capital allocated to the Duvernay at Kaybob. Yoho's fiscal 2013 budget assumes an oil price of $90.00 per barrel at Edmonton and a posted gas price of $2.82 per GJ at AECO. It is estimated that overall production for fiscal 2013 will average approximately 3,100 to 3,200 boe per day with exit production estimated at 3,400 to 3,500 boe per day. Activity levels for fiscal 2013 will continue to be monitored to align capital expenditures with expected cash flow and available credit lines.About YohoYoho Resources Inc. is a Calgary based junior oil and natural gas company with operations focusing in West Central Alberta and northeast British Columbia. The common shares of Yoho are listed on the TSX Venture Exchange under the symbol "YO". This press release shall not constitute an offer to sell or a solicitation of an offer to buy the securities in any jurisdiction. The common shares of Yoho will not be and have not been registered under the United States Securities Act of 1933, as amended, and may not be offered or sold in the United States, or to a U.S. person, absent registration or applicable exemption therefrom. Cautionary Statements Special Note Regarding Forward-Looking InformationThis news release contains certain forward-looking statements, which are based on numerous assumptions including but not limited to (i) drilling success; (ii) production; (iii) future capital expenditures; (iv) net present values of future net revenues; and (v) cash flow from operating activities. The reader is cautioned that assumptions used in the preparation of such information may prove to be incorrect.With respect to forward-looking statements contained in this document, Yoho has made a number of assumptions. The key assumptions underlying the aforementioned forward-looking statements include assumptions that: (i) commodity prices will be volatile throughout calendar 2012 and 2013; (ii) capital, undeveloped lands and skilled personnel will continue to be available at the level Yoho has enjoyed to date; (iii) Yoho will be able to obtain equipment in a timely manner to carry out exploration, development and exploitation activities; (iv) production rates for fiscal 2013 are expected to show growth from fiscal 2012; (v) Yoho will have sufficient financial resources with which to conduct the capital program; and (vi) the current tax and regulatory regime will remain substantially unchanged. Certain or all of the forgoing assumptions may prove to be untrue.Certain information regarding Yoho set forth in this document, including estimates of the quantities of the Company's proved reserves, probable reserves, contingent resources, estimates of the net present value of future net revenue of the estimates of the Company's proved reserves, and probable reserves and contingent resources and expected operating activities in the Kaybob - Duvernay and Nig Montney areas, may constitute forward-looking statements under applicable securities laws and necessarily involve substantial known and unknown risks and uncertainties. These forward-looking statements are subject to numerous risks and uncertainties, certain of which are beyond Yoho's control, including without limitation, risks associated with oil and gas exploration, development, exploitation, production, marketing and transportation, loss of markets, volatility of commodity prices, environmental risks, inability to obtain drilling rigs or other services, capital expenditure costs, including drilling, completion and facility costs, unexpected decline rates in wells, wells not performing as expected, delays resulting from or inability to obtain required regulatory approvals and ability to access sufficient capital from internal and external sources, the impact of general economic conditions in Canada, the United States and overseas, industry conditions, changes in laws and regulations (including the adoption of new environmental laws and regulations) and changes in how they are interpreted and enforced, increased competition, the lack of availability of qualified personnel or management, fluctuations in foreign exchange or interest rates, and stock market volatility and market valuations of companies with respect to announced transactions and the final valuations thereof. Readers are cautioned that the foregoing list of factors is not exhaustive.Yoho's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits, including the amount of proceeds, that the Company will derive therefrom. All subsequent forward-looking statements, whether written or oral, attributable to the Company or persons acting on its behalf are expressly qualified in their entirety by these cautionary statements. Additional information on these and other factors that could affect Yoho's operations and financial results are included in reports on file with Canadian securities regulatory authorities and may be accessed through the SEDAR website (www.sedar.com) or Yoho's website (www.yohoresources.ca).The forward-looking statements contained in this document are made as at the date of this news release and Yoho does not undertake any obligation to update publicly or to revise any of the included forward-looking statements, whether as a result of new information, future events or otherwise, except as may be required by applicable securities laws.Special Note Regarding Disclosure of Reserves and ResourcesContingent resources is defined in the COGE Handbook as those quantities of petroleum estimated, as of a given date, to be potentially recoverable from known accumulations using established technology or technology under development, but which are not currently considered to be commercially recoverable due to one or more contingencies. Contingencies may include factors such as economic, legal, environmental, political, and regulatory matters, or a lack of markets. It is also appropriate to classify as contingent resources the estimated discovered recoverable quantities associated with a project in the early evaluation stage. Contingent resources are further classified in accordance with the level of certainty associated with the estimates and may be subclassified based on project maturity and/or characterized by their economic status.The contingent resources estimates herein, including the corresponding estimates of before tax present value estimates, are estimates only and the actual results may be greater than or less than the estimates provided herein. There is no certainty that it will be commercially viable or technically feasible to produce any portion of the resources.Probability"Low Estimate" is a classification of estimated resources described in the COGE Handbook as being considered to be a conservative estimate of the quantity that will actually be recovered. It is likely that the actual remaining quantities recovered will exceed the Low Estimate. If probabilistic methods are used, there should be a 90% probability (P90) that the quantities actually recovered will equal or exceed the Low Estimate. "Best Estimate" is a classification of estimated resources described in the COGE Handbook as being considered to be the best estimate of the quantity that will actually be recovered. It is equally likely that the actual remaining quantities recovered will be greater or less than the Best Estimate. If probabilistic methods are used, there should be a 50% probability (P50) that the quantities actually recovered will equal or exceed the Best Estimate. "High Estimate" is a classification of estimated resources described in the COGE Handbook as being considered to be an optimistic estimate of the quantity that will actually be recovered. It is unlikely that the actual remaining quantities recovered will exceed the High Estimate. If probabilistic methods are used, there should be a 10% probability (P10) that the quantities actually recovered will equal or exceed the High Estimate.BOE Equivalency Barrel of oil equivalents or BOEs may be misleading, particularly if used in isolation. A BOE conversion ratio of 6 Mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6 mcf: 1 bbl, utilizing a conversion ratio of 6 mcf: 1 bbl may be a misleading indication of value.Internal estimatesAdditionally, certain information contained herein, such as the estimated fair value of the Company's land holdings, are based on estimated values the Company believes to be reasonable and are subject to the same limitations as discussed under "Special Note Regarding Forward-looking Information" above.Oil and Gas AdvisoryThe reserves information contained in this press release has been prepared in accordance with NI 51-101. Complete NI 51- 101 reserves disclosure will be included in our Annual Information Form for the year ended September 30, 2012. Listed below are cautionary statements applicable to our reserves information that are specifically required by NI 51-101: Individual properties may not reflect the same confidence level as estimates of reserves for all properties due to the effects of aggregation.With respect to finding and development costs, the aggregate of the exploration and development costs incurred in the most recent financial year and the change during that year in estimated future development costs generally will not reflect total finding and development costs related to reserve additions for that year.This press release contains estimates of the net present value of our future net revenue from our reserves. Such amounts do not represent the fair market value of our reserves.Reserves included herein are stated on a company interest basis (before royalty burdens and including royalty interests) unless noted otherwise as well as on a gross and net basis as defined in NI 51-101. "Company interest" is not a term defined by NI 51-101 and as such the estimates of Company interest reserves herein may not be comparable to estimates of "gross" reserves prepared in accordance with NI 51-101 or to other issuers' estimates of company interest reserves.Selected DefinitionsThe following terms used in this press release have the meanings set forth below:"AECO" refers to a natural gas storage facility located at Suffield, Alberta"API" means American Petroleum Institute"Bbl" means barrel"boe" means barrel of oil equivalent of natural gas and crude oil on the basis of 1 boe for six thousand cubic feet of natural gas (this conversion factor is and industry accepted norm and is not based on either energy content or current prices)"Mboe" means 1,000 barrels of oil equivalent"MMbtu" means million British Thermal Units"$M" means thousands of dollars"WTI" means West Texas Intermediate, the reference price paid in U.S. dollars at Cushing, Oklahoma for the crude oil standard grade.FOR FURTHER INFORMATION PLEASE CONTACT: Neither TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this release. Contact Information: Yoho Resources Inc.Wendy S. Woolsey, CAVice President, Finance and CFO(403) 537-1771www.yohoresources.ca