Madalena. e n e r g y inc. Advancing Four Unconventional Resource Plays and Implementing North American Horizontal Technology in Argentina

Transcription

1 Head Office: MADALENA ENERGY INC. Suite 3200, 500-4th Avenue SW Calgary, Alberta, Canada T2P 2V6 Argentina Office: MADALENA ENERGY S.A. 421 Lola Mora, 13th Floor Buenos Aires, ARG C1011ABE Madalena e n e r g y inc. MVN (TSX-V) MDLNF (OTC) Madalena s PMS-1135(h) Fracture Treatment: Rio Negro, Argentina Advancing Four Unconventional Resource Plays and Implementing North American Horizontal Technology in Argentina

2 READER ADVISORIES Forward-Looking Statements or Information Certain statements contained in this presentation of Madalena Energy Inc. ("Madalena" or the "Corporation") constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbour provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "illustrative", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target", "seek", "budget", "predict", "might" and similar words and derivatives thereof suggesting future events or future performance. All statements other than statements of historical fact may be forward-looking statements. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves or resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains, without limitation, forward-looking statements pertaining to the following: all details of, all projections of future activities related to, and all expectations of our performance and results as a result of executing Madalena's short and long term plans, strategies and goals, and the benefits anticipated to accrue to Madalena and its securityholders as a result thereof; expected production levels; expected additional oil and gas plays that could provide opportunities to the Corporation; expected product types in the Corporation's areas in which it holds assets; expected operations to be undertaken by the Corporation in the future and the timing thereof; type-curves for various kinds of wells that are expected by the Corporation and the assumptions related thereto; growth; the use of funds from production; Madalena's inventory of drilling locations; the expected quality of the Corporation's assets and the probability of successful operations on such assets; the thickness of zones in Madalena's assets; the quality of infrastructure in the areas in which the Corporation operates; matters pertaining to Madalena s reserves and resources; Madalena s corporate vision; matters pertaining to the 2015 capital budget including the source of funds for the budget; improving netbacks and operating costs; and matters pertaining to commodity prices and our operating environment. With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things: the expected nature of and timing of operational activity; Madalena's ability to execute on its short and long-term plans as described herein and the impact that the successful execution of such plan will have on Madalena and its shareholders; the laws and regulations that Madalena will be required to comply with, including laws and regulations relating to taxation, royalty regimes and environmental protection; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil prices; future crude oil, natural gas liquids and natural gas production levels; drilling results; future exchange rates and interest rates; future debt levels; the cost of expanding Madalena's property holdings and growing production; Madalena's ability to obtain equipment in a timely manner to carry out exploration and development activities and the costs thereof; Madalena's ability to market oil and natural gas successfully to current and new customers; the impact of increasing competition; Madalena's ability to obtain financing on acceptable terms; and our ability to add production and reserves through Madalena's development and exploitation activities. In addition, many of the forward-looking statements contained in this document are located proximate to assumptions that are specific to those forward-looking statements, and such assumptions should be taken into account when reading such forward-looking statements. Although Madalena believes that the expectations reflected in the forward-looking statements contained in this presentation, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the predictions, forecasts, projections and other forward-looking statements will not occur, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that Madalena will not be able to successfully execute its short or long-term plan in part or in full, and the possibility that some or all of the benefits that Madalena anticipates will accrue to it and its securityholders as a result of the successful execution of such plans do not materialize; the impact of weather conditions on seasonal demand and Madalena's ability to execute capital programs; risks inherent in oil and natural gas operations; uncertainties associated with estimating reserves and resources; competition for, among other things, capital, acquisitions of reserves, resources, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems; general economic and political conditions in Canada, the U.S., Argentina and globally, and in particular, the effect that those conditions have on commodity prices and Madalena's access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil produced in Canada and Argentina, respectively, as compared to other markets, and transportation restrictions; royalties payable in respect of oil and natural gas production and changes to government royalty frameworks; changes in government regulation of the oil and natural gas industry, including environmental regulation; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including wild fires and flooding); failure to obtain regulatory, industry partner and other third-party consents and approvals when required, including for acquisitions, dispositions and mergers; failure to realize the anticipated benefits of dispositions, acquisitions, joint ventures and partnerships; changes in taxation and other laws and regulations that affect us and our securityholders; the potential failure of counterparties to honour their contractual obligations; and the other factors described under"risk Factors" in our Annual Information Form, and described in our public filings available in Canada at Readers are cautioned that this list of risk factors should not be construed as exhaustive. The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this document are expressly qualified by this cautionary statement. 2

3 MADALENA ENERGY INC.: Argentina Focused Presentation Outline Madalena Overview and Yearly Growth Comparison Argentina Commodity Prices Summary of Key Properties Surubi Conventional oil production Cash Cow Coiron Amargo Conventional base + growth production Unconventional Shale Oil upside in Vaca Muerta Curamhuele High impact exploration in scalable unconventional resource plays Lower Agrio Oil, Mulichinco Liquids Rich Gas and Vaca Muerta shale Puesto Morales Conventional base production Loma Montosa oil resource play scalable development Closing Summary 3

4 MADALENA ENERGY INC.: Overview UPSTREAM OIL AND GAS COMPANY FOCUSED ON THE DELINEATION OF SHALE AND UNCONVENTIONAL RESOURCES IN ARGENTINA Trading Symbol: TSXV MVN Total Issued and Outstanding Shares ~541 million Market Capitalization ($0.37/share) ~$200 million March 31, 2015 Positive Working Capital ~$ 3 million 2015 Budget Up to $44 million 100% of 2015 Budget directed towards Argentina Current Base Production ~4,000 Boe/d (~95% from Argentina) Additional ~400 Boe/d of Temporarily Shut-in Volumes in Canada Conventional Assets Provide Solid Platform 2014 YE Proved and Probable ( 2P ) Reserves ~11.5 MMBoe 2014 YE 2P NPV@10% Btax ~$200 MM Four Unconventional Resource Plays Provide Growth & Strategic Value 4

5 MADALENA ENERGY INC.: Conventional Growth Year to Year MBoe 12,000 10,000 8,000 6,000 Madalena Consolidated Reserves Proved + Probable MBoe Argentina Canada Proved + Probable Boe per thousand shares Boe/000 shares Boe/d 3,500 3,000 2,500 2,000 1,500 Madalena Consolidated Production boe/d Argentina Canada Boe per MM shares Boe/MM shares , , , YE 2012 YE 2013 YE Madalena Proved + Probable Reserves NPV@10% 2014 vs % increase in Proved + Probable Reserves 72% per share growth in Proved + Probable Reserves 297% increase in Proved + Probable NPV@10% 168% increase in Proved + Probable NPV@10% per share 165% increase in production 79% increase in production per share Conventional 2P reserves provides value backstop Unconventional Shale Assets and Resource Play Upside not included in charts 5

6 ARGENTINA OIL PRICING: Current Regulated Premium to Brent In Argentina, oil prices are set by the government monthly for product sold into the domestic oil market Regulators in Argentina set April & May 2015 oil pricing at approximately USD $76 per barrel for Medanito quality crude oil which continues to remain well above comparative Brent price and WTI benchmarks February 2, 2015 USD $3.00 / Bbl (royalty free) incentive program above USD $76/Bbl Medanito price Madalena Q operating netback 1 $37.16/Bbl (doesn t include incentive program at this time) Madalena recently entered into a new gas contract at USD $5.30/mmbtu for period May to September Historical Oil Price US$/Bbl -Argentina Medanito vs Brent and WTI Argentina US$/Bbl WTI US$/Bbl Brent US$/Bbl Jan-11 Mar-11 May-11 Jul-11 Sep-11 Nov-11 Jan-12 Mar-12 May-12 Jul-12 Sep-12 Nov-12 Jan-13 Mar-13 May-13 Jul-13 Sep-13 Nov-13 Jan-14 Mar-14 May-14 Jul-14 Sep-14 Nov-14 Jan-15 Mar-15 May-15 Jul-15 Note: 1 Operating netback is a non-gaap measure calculated as the average per boe of the Company s oil and gas sales, less royalties and operating costs 6

7 ARGENTINA PROPERTIES: Multiple Blocks in Two Basins Block Summary Block W.I. Operator Net Acres Province/Basin Valle Morado 1 97% Madalena 47,423 Salta/Noroeste Santa Victoria 1 100% Madalena 516,846 Salta/Noroeste El Vinalar 100% Madalena 61,035 Salta/Noroeste El Chivil 100% Madalena 30,394 Formosa/Noroeste Surubi 85% Madalena 77,200 Formosa/Noroeste Palmar Largo 14% High Luck 20,532 Formosa/Noroeste Curamhuele 1 90% Madalena 50,595 Neuquén/Neuquén Coiron Amargo 35% Roch 34,951 Neuquén/Neuquén Cortadera 1 38% Yac. del Sur 46,522 Neuquén/Neuquén Puesto Morales 100% Madalena 31,254 Rio Negro/Neuquén Puesto Morales Este 100% Madalena 1,483 Rio Negro/Neuquén Rinconada Sur 100% Madalena 28,417 Rio Negro/Neuquén Rinconada Norte 35% Petrogas 8,216 La Pampa/Neuquén Total Net Acres 954,868 Total Gross Acres 1,258,697 Notes: ¹ Currently non-producing properties with no reserves assigned NOROESTE BASIN NEUQUÉN BASIN 7

8 CORE PROPERTIES: Q1 Production Oil Gas Boe/d % Total Puesto Morales/Rinconada 895 3,859 1,538 47% Surubi % Coiron Amargo % Sub Total 2,191 4,284 2,905 88% Minor Properties % Total 2,588 4,284 3, % 78 % light oil Top three properties account for 88% of total Production growth at Coiron Amargo and Puesto Morales has taken current net production to ~ 3,800 Boe/d in Argentina 8

9 P A N U S A D O M J A M Caracas ^ ^ C O L Bogota ^ Quito E C U c e a n i c O P E R ^ Lima ^ Santo Domingo V E N B O L G U Y S U R G U F B R A Brasilia ^ F PALMAR LARGO (BALBUENA ESTE) WI:14 % A r g e n t i n a Salta P rovinc e Legend CHIVIL WI: 100% Operated Property EL CHORRO Non-Operated Property PALMAR LARGO WI: 14% HONDO TEUCO Formosa Province P a r a g u a y PILCOMAYO SURUBI WI: 85% a c i f ( ( (( P R Y h P S o u t C H L Santiago ^ ((( A R G U R Y Montevideo ^ ^ Buenos Aires t i c O c e a n Palmar largo Field l a n A t t h Northern Properties: Surubi, Chivil and Palmar Largo Surubi Mature stable production platform High volume, lower op costs resulting in the highest netback (Q1 ~ US$ 53/bbl) No interference from PROA-3 to original PROA-2 Wells currently flowing, opportunity to go to high volume lift 10,000 SurubiField: PROA Structure Daily Oil (bbls/d) 1 A R G S o u 1, ) - Madalena has an 85% WI in Surubi Surubi Block

10 NOROESTE BASIN: Conventional Light Oil Production with Exploration Upside El Chivil Palmar Largo Palmar Largo (14% Non-Op) 17 wells have cum. production of > 40 MMBbls Surubi (85% Operated) Proa-2 well has produced > 1.1MM Bbls in 21 mo. Surubi Bolivia Palmar Largo (Balbuena Este) Valle Morado 125 km Santa Victoria El Vinalar Operated (Exploration) Operated (Exploitation) Non-operated (Exploitation) El Chivil Palmar Largo Palmar Largo Paraguay Surubi Argentina Additional Exploration & Appraisal Blocks EL Chivil -1 00% Operated (Producing) El Vinalar - 100% Operated (Producing) Santa Victoria - 100% Operated Valle Morado % Operated Multiple exploration leads on 2D and 3D seismic 10

11 PRIMARY STRATEGY: Delineating Unconventional Shales & Tight Sands Plays in Neuquen Basin 2015 Budget: Vertical & Horizontal Activities to Delineate Four Unconventional Resource Plays MULICHINCO RESOURCE PLAY (Liquids-rich Gas) -Curamhuele Drilling, Completion & Frac Activities LOWER AGRIO SHALES (Oil) -Curamhuele Drilling, Completion & Frac Activities NEUQUÉN BASIN LOMA MONTOSA RESOURCE PLAY (Oil) -Puesto Morales Horizontal Multi-stage Frac VACA MUERTA SHALES (Oil) -Coiron Amargo Vertical Appraisal Fracs -Coiron Amargo Horizontal Multi-stage Frac 11

12 COIRON AMARGO: Recent Offsetting Vaca Muerta Operations Aguada Federal-Wintershall; March 16, 2015 (Wintershall website) -2 vertical VM wells in Contingency of 6 horizontal VM wells La Amarga Chica-Petronas; May 2014 (YPF Website) vertical VM wells + 2 horizontal VM wells Loma Campana -Chevron / YPF; Jan. 9, 2015 (Petrolnews.net) -200 VM wells on production vertical VM wells + 40 horizontal VM wells Cruz de Lorena & Sierras Blancas Shell; Dec. 2, 2014 (O&G Journal) -Plan to invest $250 MM exploring 2 blocks Dec. 16, 2014 (Shell) Operations to include 7 wells in VM plus 1 vertical well for microseismic 12

13 CURAMHUELE: Recent Offsetting Activities Lower Agrio Shale & Vaca Muerta Shale Offsetting activity by international operators including ExxonMobil, YPF, Chevron and Total August 14, 2014 YPF announces very important oil discovery in the Agrio EL TRAPIAL (CHEVRON) -ET.x-2006 (Vaca Muerta) -Indicated to be capable of significant liquids and gas production - Four Vaca Muerta delineation wells drilled in 2014 Lower Agrio shale to be evaluated in the Madalena Ch.x-1 vertical well - Originally flowed ~75 Bopd without frac/stimulation Mulichinco to be evaluated in the Madalena Yp.x-1001 vertical well YPF YPF - Offsetting Yp.x-1st tested at 10 MMcf/d of gas and 500 Bbls/d of 51º condensate after acidizing Los Toldos II (ExxonMobil / Americas Petrogas) LTE.x-1 (Vaca Muerta) -Tested 694 Bbls/d 40⁰ API oil Mcf/d gas - IP 30 : 254 Bbls/d 40⁰ API oil Mcf/d gas Total Madalena e n e r g y inc. Chevron ExxonMobil ADA.x-1 (Vaca Muerta) -Tested 260 Bbls/d La Invernada (ExxonMobil) LAL.x-3 (Hz) (Vaca Muerta) -On completion Loma Del Molle (YPF) YPF YPF ExxonMobil LDMo.x-1 (Vaca Muerta) Total Loma Del Molle (YPF) CLMi.x-1 (Vaca Muerta) Fraced in 6 stages YPF Los Toldos I (ExxonMobil / Americas Petrogas) ALL.x-1 (Vaca Muerta) -Tested 3.2 MMcf/d + 18 Bbls/d of 54-58⁰ condensate ExxonMobil Source: Based on mapping by the Gobierno de la Provincia del Neuquén, modified by Madalena Energy Inc. *** See Analogous Information on Slide 30 of this presentation. Development Potential in the Vaca Muerta, Lower Agrio & Mulichinco 13

14 VACA MUERTA SHALE PLAY: Overview Prospective at Coiron Amargo, Curamhuele and Cortadera Thickness¹ >500m Progressively deeper & thicker from east to west in the basin Thickness¹ >1000m with the inclusion of the overlying Quintuco formation Madalena expects that the Vaca Muerta is Oil prone at Coiron Amargo, Gas prone around the Cortadera block and Gas & Liquids prone at Curamhuele Sources: (Isopach Map) Madalena Energy Inc. mapping; (Thermal Maturity Map) Based on mapping by the Gobierno de la Provincia del Neuquén, modified by Madalena Energy Inc. Note: ¹ Ryder Scott Company, Petroleum Consultants, May 2013 and Madalena Energy Inc. internal data; Madalena owns a 35% working interest in the Vaca Muerta rights on the Coiron Amargo block, a 90% working interest in the Vaca Muerta rights on the Curamhuele block and a 38% working interest in the Vaca Muerta rights on the Cortadera block in the Neuquen basin of Argentina. Madalena expects the Vaca Muerta to be oil prone at Coiron Amargo, gas prone at Cortadera and gas & liquids prone at Curamhuele. Please see the disclosure at the beginning of this presentation and Madalena s AIF dated April 16, 2015 for details with respect to the risks and uncertainty associated with Madalena and its business. *** See Analogous Information on Slide 30 of this presentation. 14

15 LOWER AGRIO SHALE PLAY: Overview Prospective at Curamhuele and Cortadera The Lower Agrio cycle began with a marine flooding event that created good oil source rock in the centre of the basin Remainder of the cycle predominately filled the basin with sandstone Lower Agrio flowed ~75 bbl/d oil without stimulation at Ch.x-1(¹) Lower Agrio shale is up to 225 m thick¹ across the Curamhuele block Horizontal multi-stage frac potential The layered and brittle nature of the shale is ideal for fracture propagation / stimulation Lower Agrio defines top of basin overpressuring (1) Average rate over the initial day of a multi-day production test (2) Tested through perforations after acid stimulation at YP.x-1 and unstimulated at YP.x-1001 The Lower Agrio shale is prospective for oil within the Curamhuele block Note: ¹ Ryder Scott Company, Petroleum Consultants, May 2013 and Madalena Energy Inc. internal data; Madalena owns a 90% working interest in the Lower Agrio rights on the Curamhuele block and a 38% working interest in the Lower Agrio rights on the Cortadera block in the Neuquen basin of Argentina. Madalena expects the Lower Agrio to be oil prone at Curamhuele and gas & liquids prone at Cortadera. Please see the disclosure at the beginning of this presentation and Madalena s AIF dated April 16, 2015 for details with respect to the risks and uncertainty associated with Madalena and its business. *** See Analogous Information on Slide 30 of this presentation. 15

16 MULICHINCO LIQUIDS-RICH GAS RESOURCE PLAY: Overview Prospective at Curamhuele and Cortadera Liquids-rich gas bearing tight sand play Rapid thickening (> 200 m )¹ of the Mulichinco on the Curamhuele and Cortadera blocks Significant horizontal development potential in the lowermost and coarser clastic portion of the Mulichinco Deposited during an initial low-stand period Total S.A. reportedly drilling successful Mulichinco horizontals at Aguada Pichana Significant Mulichinco production test on Madalena land at Curamhuele The Mulichinco tight sandstones are prospective for gas within the Curamhuele and Cortadera blocks Note: ¹ Ryder Scott Company, Petroleum Consultants, May 2013 and Madalena Energy Inc. internal data; Madalena owns a 35% working interest in the Mulichinco rights on the Coiron Amargo block, a 90% working interest in the Mulichinco rights on the Curamhuele block and a 38% working interest in the Mulichinco rights on the Cortadera block in the Neuquen basin of Argentina. Madalena expects the Mulichinco to be gas prone at Cortadera and gas & liquids prone at Curamhuele. Please see the disclosure at the beginning of this presentation and Madalena s AIF dated April 16, 2015 for details with respect to the risks and uncertainty associated with Madalena and its business. *** See Analogous Information on Slide 30 of this presentation. 16

17 PUESTO MORALES : Loma Montosa Oil Play Overview Prospective at Puesto Morales Light Oil Resource Play at Puesto Morales field MVN is operator with 100% W.I. Tight Dolostones with good well control in Loma Montosa zone Shallow drill depths with TVD ~1350 m Initial Hz Multifrac Proof of Concept horizontal (PMN-1117(h)) drilled and placed on production in 2012 Q Madalena drilled, fraced and tested the PMS-1135(h) appraisal horizontal Scalable development potential PMN-1117(h) PMS-1135(h) PMS-1135(h) Total depth of 2,600m with a horizontal length of approximately 1,095m Argentina's first 12-stage ball-drop frac Hybrid slickwater/gel frac with ~ 30 tonnes of proppant per stage Placed on-stream April 9, 2015 IP(30-Day): ~571 Boe/d flowing up 5.5 casing including 300 Bopd plus 1,626 Mcf/d of gas at a flowing pressure of 450 psi and a 40% water cut ~1 SECTION (640 Acres) 17

18 LOMA MONTOSA OIL PLAY: Applying N.A Horizontal Technology in Argentina PMS-1135(h): Longer Hz, More Stages & Bigger Fracs Providing Solid Results To Date 1,000 Boe/d PMS day IP 570 Boe/d TARGET 300 MBoe Type Curve PMN-1117 (Hz) 500m Hz with 5 fracs Proved-up concept 100 PMN-1094 Offsetting Vertical

19 LOMA MONTOSA OIL PLAY: Applying N.A Horizontal Technology in Argentina PMS-1135 (h) LM-93/96 LM-100 Best Reservoir a Horiz.Well PHIE Net thickness Res3-4-5 thickness 19

20 Puesto Morales Facilities: Madalena Operated & Controlled Originally cost approximately USD $40 MM to build Plant & Infrastructure Room to Grow via Horizontal Development in Loma Montosa Oil Resource Play Q4 Oil 968 bbl/d Capacity ~ 12,000 bbls/d Q4 Gas 4.1 mmcf/d Capacity ~ 7.8 mmcf/d Expandable to ~ 15.5 mmcf/d Oil Sales Line ~ 12,000 bbls/d Gas Sales Line ~ 30 mmcf/d PMN Main Battery 20

21 COIRON AMARGO NORTH: Sierras Blancas Horizontals Applying N.A. Horizontal Technology to Conventional Light Oil Development Coiron Amargo Norte (108 km 2 ) converted to 25-year exploitation license (MVN 35% W.I. -Non-Op) Recently placed CAN-16(h) well on-production Additional horizontals planned for 2015 Inventory of low-risk horizontal development wells GLJ 2P approximately 10% Recovery Factor opportunity for growth CAN-18(h) CAN-15(h) CAN.xr-2(h) Source: Madalena Energy Inc. mapping CAN-16(h) Avg. production over the first 60 days was 450 bopd, 670 mcf/d ~564 Boe/d (197 Boe/d WI) As of May 16, 2015 the well was flowing 480 bopd, 1000 mcf/d ~ 650 Boe/d (227 Boe/d wellhead pressure of 1225 psi and a 19% water cut 21

22 COIRON AMARGO NORTH: Sierras Blancas Horizontal Prod Average Daily Oil Prod Coiron Hz Well v Offset Sierras Blancas Hz CAN-15(h) -now pumping CAN.xr-2(h) -Cum 254 Mbbls in 17 months CAN-16(h) -recently increased to Boe/d CAN-18(h) now pumping Average of seven LJE wells CAN.xr-2(h) CAN-15(h) CAN-18(h) CAN-16(h)

23 MADALENA ENERGY: Argentina Focused Plan Entering 2015 with No Debt & Focused Plan Active Argentina Focused Drill Program in / 2016 Plan: Advance Four Key Resource Plays Loma Montosa Oil resource play at Puesto Morales - Initial Success at Puesto Morales on Scalable Asset Lower Agrio Shale oil at Curamhuele Mulichinco Liquids-Rich Gas resource play at Curamhuele Vaca Muerta Shale at Coiron Amargo Continue to Implement North American Horizontal (Hz) Technology in Argentina Continued horizontal development of multiple Sierras Blancas light oil pools Follow-up on Loma Montosa horizontal success with multi-well horizontal program Work with partners on design and planning for first Hz multi-frac into the Vaca Muerta shale Continue to assess Non-core Asset Sales and Joint Venture Partnerships 23

24 APPENDICES 24

25 APPENDIX #1: Experienced Full-Cycle Operating Team MANAGEMENT TEAM Kevin Shaw, P. Eng., MBA President & CEO Previously Managing Director & Head of Energy Research at a boutique investment bank; Prior to a Senior E&P Research Analyst and Partner, Wellington West Capital Markets (now National Bank) Prior thereto, held various technical, senior management and/or officer roles with ExxonMobil (via Imperial Oil), Trimox Energy Inc. (VP Operations & Engineering), WorleyParsons (BP Alliance Manager). Thomas Love, CA VP, Finance & CFO Previously CFO, Online Energy Inc., CFO, Trimox Energy and Moxie Exploration and President & CEO, Moxie Petroleum Prior thereto with Westward Energy Ltd. and Charterhall Oil Canada, Articled at Clarkson Gordon & Co. (now Ernst & Young LLP) Steve Dabner, P. Geol. VP, Exploration Previously President and CEO, Online Energy Inc., President & CEO, Trimox Energy and Moxie Exploration and VP Exploration, Moxie Petroleum Prior thereto with Cimarron Petroleum Ltd. and Home Oil Company Ltd. Stephen Kapusta, P. Eng. Head of Engineering Over 30 years of diverse Operations, Reservoir Engineering and Management experience. Actively involved in the planning and execution of complex operations in unconventional reservoirs over the past 15 years; Previously with Texaco, Unocal, Star Oil & Gas, Canex Energy and Zargon in senior officer, director, consultant or manager roles. Ruy Riavitz Argentina Country Manager Previously E&P Manager, Hidenesa Gas SA (now GyP of Neuquen) & Independent Engineering Consultant Prior thereto Senior Consultant, PA Consulting, Reservoir Engineer, YPF Robert Stanton, P. Eng. - VP, Operations Previously VP, Operations, Online Energy Inc., VP, Engineering and Operations, Result Energy Inc. Prior thereto with Oiltec Resources Ltd., Pinnacle Resources Ltd., Jordan Petroleum Ltd., Transwest Energy Inc., Triton Canada Resources Ltd., Canadian Worldwide Energy Ltd. and Petro-Canada Inc. BOARD OF DIRECTORS Barry Larson VP Operations & COO, Parex Resources Inc.(South American producer) Gus Halas Director of Triangle Petroleum Corp. & executive roles at Central Garden a & Pet, T-3 Energy Services, Dresser s Pump Services & Aquilex Corp Jay Reid Partner, Burnet, Duckworth & Palmer LLP Keith MacDonald President, Bamako Investment Management Ltd; Director of Surge Energy and Bellatrix Kevin Shaw, P. Eng., MBA President & CEO, Madalena Energy Inc Raymond Smith, P. Eng. President, CEO & Director, Bellatrix Exploration Ltd. Steven Sharpe (Chairman) Former Chairman of Longview Oil Corp (acquired by Surge Energy) & Advantage Oil & Gas; Former Director of Renegade (acquired by Spartan) Ving Woo, P. Eng. Former VP, Engineering & COO, Bellatrix Exploration Ltd. 25

26 APPENDIX #2: Argentina s World-Class Shale Potential June 2013 EIA Released Updated World Shale Oil & Gas Assessment Argentina has 4th largest technically recoverable shale oil resource in the world Behind only Russia, USA & China 3X greater than Canada Argentina has 2nd largest technically recoverable shale gas resource in the world Behind only China 1.2X greater than USA 1.4X greater than Canada Three Shale Plays in Argentina: Vaca Muerta, Agrio,Los Molles Neuquén Basin is a the focus of Shale Resource development by Major E&Ps and NOCs *** See Analogous Information on Slide 30 of this presentation. 26

27 APPENDIX #3: Vaca Muerta vs US Shales 0 m Shale Thickness 750 1,000 Oil Shales Gas Shales Vaca Muerta Shale Madalena s Coiron Amargo Area ¹ Eagle Ford ² Bakken ³ Vaca Muerta Shale Madalena s Cortadera Area ¹ Barnett ⁴ Haynesville ⁴ Marcellus ⁴ Shale Comparisons Thickness (m) Depth (m) Porosity (%) Permeability (nd) K 500K TOC (%) Reservoir Pressure (psi) >11, Pressure Gradient (psi/ft) > The Vaca Muerta shale compares favourably to leading US shale resource plays Notes: ¹ Ryder Scott Company, Petroleum Consultants, May 2013 and Madalena Energy Inc. internal data; Madalena owns a 35% working interest in the Vaca Muerta rights on the Coiron Amargo block, a 90% working interest in the Vaca Muerta rights on the Curamhuele block and a 38% working interest in the Vaca Muerta rights on the Cortadera block in the Neuquen basin of Argentina. Madalena expects the Vaca Muerta to be oil prone at Coiron Amargo, gas prone at Cortadera and gas & liquids prone at Curamhuele. Please see the disclosure at the beginning of this presentation and Madalena s AIF dated April 16, 2015 for details with respect to the risks and uncertainty associated with Madalena and its business. ² EOG Analyst Conference, April 2010 ³ Tudor, Pickering, Holt, The Bakken Momentum Continues November 2011, Hart Energy Playbooks 2008 & 2010, Jarvie AAPG Section Meeting 2008 ⁴ Schlumberger, World Shale Summit September Gas y Petroleo del Neuquén and YPF *** See Analogous Information on Slide 30 of this presentation. 27

28 APPENDIX #4: ARGENTINA VS. CANADA Higher Risk = Larger Rewards Potential to unlock much bigger value in Argentina makes the challenges of operating there worthwhile, but effort and patience are required to achieve success Fiscal Differences Regulated oil and gas pricing (May US $ 76/Bbl), future prices set on monthly basis Incentive programs for oil and gas pricing set by regulators and usually awarded based on production/reserves criteria Restrictions on free movement of funds and currency control measures Foreign exchange risk with US$ sales, Argentina PESO expenses and reporting in CDN$ Block contracts require continual management and negotiations for amendments and/or extensions Higher inflation rates in Argentina affects cost structures and local business New Hydrocarbon Law has improved regulatory and fiscal understanding between Federal and Provincial Governments Operational Differences Access to services requires more planning and longer lead times Unionized workforce provides additional complexities Import restrictions & complex regulatory approval system can impact the ability to execute in a timely fashion Note: For additional information on risks see Company s YE 2014 MD&A dated April 16, 2015 or the Company s Annual Information Form ( AIF ) dated April 16,

29 APPENDIX #5: CANADIAN ASSETS - West-Central Alberta ALBERTA EDMONTON CALGARY Greater Paddle River Core Area (>150 Net Sections of Land) High Working Interest & Primarily Operated Multiple Plays for horizontal multi-stage frac operations: Nordegg -Emerging ~139 net sections -Oil & Liquids-rich gas Ostracod -Development ~57 net sections -Oil Notikewin/Wilrich -Development -Liquids-rich gas ~137 net sections Additional opportunities exist in: Viking oil, Rock Creek oil Large Inventory of unbooked horizontal drilling locations Drill-Ready Program of horizontal development wells 29

30 READER ADVISORIES Barrels of Oil Equivalent All calculations converting natural gas to barrels of oil equivalent ("boe") have been made using a conversion ratio of six thousand cubic feet (six "Mcf") of natural gas to one barrel of oil, unless otherwise stated. The use of boe may be misleading, particularly if usedin isolation,as the conversionratioofsix Mcfofnatural gas toone barrelof oilis basedonan energyequivalencyconversionmethod primarilyapplicable at the burner tipanddoes not represent a value equivalencyat the wellhead. Giventhatthevalueratiobasedonthecurrentpriceofcrudeoilascomparedtonaturalgasissignificantly different from theenergyequivalency of6:1,utilizing aconversionona6:1basismay bemisleading asanindication ofvalue. Analogous Information Certain information in this document may constitute"analogous information" as defined in National Instrument Standards of Disclosure for Oil and Gas Activities("NI "), including, but not limited to, information relating to areas, wells and /or operations that are in geographical proximity to or on-trend with prospective lands held by Madalena and production information related to wells that are believed to be on trend with Madalena's properties. Such information has been obtained from government sources, regulatory agencies or other industry participants. Management of Madalena believes the information may be relevant to help define the reservoir characteristics in which Madalena may hold an interest and such information has been presented to help demonstrate the basis for Madalena's business plans and strategies. However, to Madalena s knowledge, such analogous information has not been prepared in accordance with NI and the Canadian Oil and Gas Evaluation Handbook and Madalena is unable to confirm that the analogous information was prepared by a qualified reserves evaluator or auditor. Madalena has no way of verifying the accuracy of such information. There is no certainty that the results of the analogous information or inferred thereby will be achieved by Madalena and such information shouldnotbeconstruedasanestimateoffutureproductionlevels.suchinformationisalsonotanestimateofthereservesorresourcesattributabletolandsheldortobeheldbymadalenaandthereisnocertaintythatthereservoirdataandeconomics information for the lands held or to be held by Madalena will be similar to the information presented herein. The reader is cautioned that the data relied upon by Madalena may be in error and/or may not be analogous to such lands to be held by Madalena. Initial Production Rates Any references in this document to test rates, flow rates, initial and/or final raw test or production rates, early production, test volumes and/or"flush" production rates are useful in confirming the presence of hydrocarbons, however, such rates are not necessarily indicative of long-term performance or of ultimate recovery. Such rates may also include recovered "load" fluids used in well completion stimulation. Readers are cautioned not to place reliance on such rates in calculating the aggregate production for Madalena. In addition, the Vaca Muerta shale is an unconventional resource play which may be subject to high initial decline rates. Such rates may be estimated based on other third party estimates or limited data available at this time and are not determinative of the rates at which such wells will continue production and decline thereafter. Financial Outlook Any financial outlook or future oriented financial information in this presentation, as defined by applicable securities legislation, was approved by management of Madalena on January 7, Such financial outlook or future oriented financial information is provided for the purpose of providing information about management's current expectations and plans relating to the future. Readers are cautioned that reliance on such information may not be appropriate for other purposes. Non-GAAP Measures In this presentation, management uses certain key performance indicators and industry benchmarks such as cash flow and operating netbacks to analyze financial and operating performance. Management feels that these key performance indicators and benchmarks are key measures of profitability for Madalena and provide investors with information that is commonly used by other oil and gas companies. These key performance indicators and benchmarks as presented do not have any standardized meaning prescribed by Canadian generally accepted accounting principles and therefore may not be comparable with the calculation of similar measures for other entities. For additional information on the use of these measures please see Madalena's Management s Discussion and Analysis at Finding and Development Costs NI specifies how finding and development costs ("F&D costs") should be calculated if they are reported. Essentially NI requires that the exploration and development costs incurred in the year along with the change in estimated Future Development Costs ( FDC ) be aggregated and then divided by the applicable reserve additions. The calculation specifically excludes the effects of acquisitions and dispositions on both reserves and costs. Since acquisitions can have a significant impact on annual reserve replacement costs, excluding these amounts could result in an inaccurate portrayal of Madalena's cost structure. F&D costs disclosed herein are based on working interest gross reserves. The aggregate of the exploration and development costs incurred in the most recent financial year and the change during that year in estimated FDC generally will not reflect total F&D costs related to reserve additions for that year. Information Regarding Disclosure on Reserves and Resources The reserve and resource estimates contained herein are estimates only and there is no guarantee that the estimated reserves or resources will be recovered. In relation to the disclosure of estimates for individual properties, companies or business units, as adjusted, such estimates may not reflect the same confidence level as estimates of reserves or resources and future net revenue for all properties, due to the effects of aggregation. The estimates of reserves and future net revenue from individual properties or wells may not reflect the same confidence level as estimates of reserves and future net revenue for all properties and wells, due to the effects of aggregation. Where discussed herein"npv 10%" represents the net present value(net of capex) of net income discounted at 10%, with net income reflecting the indicated oil, liquids and natural gas prices and IP rate, less internal estimates of operating costs and royalties. It should not be assumed that the future net revenues estimated by Madalena's independent resource evaluators represent the fair market value of the reserves, nor should it be assumed that Madalena's internally estimated value of its undeveloped land holdings or any estimates referred to herein from third parties represent the fair market value of the lands. Drilling Locations This press release refers to unbooked drilling locations. Unbooked locations are internal estimates based on Madalena's prospective acreage and an assumption as to the number of wells that can be drilled per section based on industry practice and internal review. Unbooked locations do not have attributed reserves. Unbooked locations have been identified by management as an estimation of our future drilling activities based on evaluation of applicable geologic, seismic, engineering, production and reserves information. There is no certainty that Madalena will drill all unbooked drilling locations and if drilled there is no certainty that such locations will result in additional oil and gas reserves or production. The drilling locations on which we actually drill wells will ultimately depend upon the availability of capital, regulatory approvals, access restrictions, oil and natural gas prices, costs, actual drilling results, additional reservoir information that is obtained and other factors. While certain of the unbooked drilling locations have been derisked by drilling existing wells in relative close proximity to such unbooked drilling locations, some of other unbooked drilling locations are farther away from existing wells where management has less information about the characteristics of the reservoir and therefore there is more uncertainty whether wells will be drilled in such locations and if drilled there is more uncertainty that such wells will result in additional oil and gas reserves or production. 30