Madale na Argentina Office: MADALENA ENERGY S.A. 421 Lola Mora, - - PowerPoint PPT Presentation

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Madale na Argentina Office: MADALENA ENERGY S.A. 421 Lola Mora, - - PowerPoint PPT Presentation

Head Office: MADALENA ENERGY INC. Suite 3200, 500 - 4th Avenue SW Calgary, Alberta, Canada T2P 2V6 Madale na Argentina Office: MADALENA ENERGY S.A. 421 Lola Mora, 13th Floor inc . e n e r g y Buenos Aires, ARG C1011ABE


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SLIDE 1

Madalena’s PMS-1135(h) Fracture Treatment: Rio Negro, Argentina

Advancing Four Unconventional Resource Plays:

VACA MUERTA SHALE, AGRIO SHALE, LOMA MONTOSA, MULICHINCO and Implementing North American Horizontal Technology in Argentina

SEPTEMBER 2015

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 www.madalenaenergy.com MVN (TSX-V) MDLNF (OTC)

Madale na

e n e r g y

inc .

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SLIDE 2

READER ADVISORIES

SEPTEMBER 2015 2

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

  • f 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

  • bligations; and the other factors described under "Risk Factors" in our Annual Information Form, and described in our public filings available in Canada at www.sedar.com. 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.

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SLIDE 3

3

  • Trading Symbol: TSXV – MVN
  • Total Issued and Outstanding Shares ~541 million
  • Market Capitalization ($0.29/share) ~$157 million
  • June 30, 2015 Positive Working Capital ~$ 14.2 million
  • Long Term Debt June 30, 2015 ~$ 7.1 million
  • Q2 – 2015 Production 3,996 Boe/d

(81% Oil + NGL)

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

MADALENA ENERGY INC.: Overview FOCUSED ON WORLD CLASS SHALE AND CONVENTIONAL RESOURCES IN ARGENTINA

SEPTEMBER 2015

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SLIDE 4

4

SUCCESSFUL GROWTH: Conventional Drilling and Acquisitions

5.00 8.00 11.00 14.00 17.00 20.00 23.00

  • 2,000

4,000 6,000 8,000 10,000 12,000 YE 2012 YE 2013 YE 2014 Madalena Consolidated Reserves Proved + Probable MBoe Argentina Canada Proved + Probable Boe per thousand shares

MBoe Boe/000 shares

2014 vs. 2013

  • 155% 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

Madalena Proved + Probable Reserves NPV@10%

Conventional 2P reserves provides value backstop Unconventional Shale Assets and Select Resource Play Upside Not Included in Charts

SEPTEMBER 2015 0.00 1.00 2.00 3.00 4.00 5.00 6.00 7.00 8.00

  • 500

1,000 1,500 2,000 2,500 3,000 3,500 4,000 2012 2013 2014 2015 June YTD Madalena Consolidated Production boe/d Argentina Canada Boe/d

Boe/MM shares

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SLIDE 5

5

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
  • Q3 – 2015 average Argentina oil price set at USD $76 per barrel for Medanito posted pricing
  • Incremental USD $3.00/Bbl (royalty free) incentive program for 2015 (option to extend for 2016)
  • Madalena Q2 – 2015 Argentina oil and NGL prices in Argentina averaged CDN $96.33/Bbl
  • Madalena Q2 2015 operating netback1 in Argentina CDN $37.39/Boe
  • Gas contracted at USD $5.30/mmbtu (CDN $6.28/mcf) for period May to September 2015

Note: 1Operating 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

40 50 60 70 80 90 100 110 120 130 140 Jan-11 Jan-12 Jan-13 Jan-14 Jan-15

Argentina US$/Bbl WTI US$/Bbl Brent US$/Bbl

SEPTEMBER 2015

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SLIDE 6

6

Fiscal Differences

  • New Hydrocarbon Law (Dec 2014) has improved regulatory and fiscal understanding between

Federal and Provincial Governments

  • Regulated oil and gas pricing (September USD $75/Bbl, USD $5.30/mmbtu)
  • Incentive programs for oil and gas pricing set by regulators and usually awarded based on production/reserves criteria
  • Restrictions on free movement of funds and currency control measures
  • Foreign exchange risk with US$ 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
  • Flat Provincial Government Royalties 12-15%

Operational Differences

  • Access to services requires more planning and longer lead times
  • Unionized workforce provides additional complexities
  • Import restrictions and complex regulatory approval system can impact the ability to execute in a timely fashion

Note: For additional information on risks see the Company’s YE 2014 MD&A dated April 16, 2015 or the Company’s Annual Information Form (”AIF”) dated April 16, 2015

Potential to unlock much bigger value in Argentina makes the challenges of

  • perating there worthwhile, but effort and patience are required to achieve success

ARGENTINA: Macro Economic and Fiscal Highlights

SEPTEMBER 2015

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SLIDE 7

ARGENTINA PROPERTIES: Multiple Blocks in Two Basins

7

Block Summary

Notes: ¹ Currently non-producing properties with no reserves assigned

Block W.I. Operator Net Acres Province/Basin

Valle Morado1 97% Madalena 47,423 Salta/Noroeste Santa Victoria1 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 Curamhuele1 90% Madalena 50,595 Neuquén/Neuquén Coiron Amargo 35% Roch 34,951 Neuquén/Neuquén Cortadera1 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

Total Net Acres 946,652 Total Gross Acres 1,235,223

NOROESTE BASIN NEUQUÉN BASIN SEPTEMBER 2015

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SLIDE 8

CORE PROPERTIES: Q2 Sales Volumes

8

Oil + NGL Gas Boe/d % Total Bbls/d Mcf/d 6:1 Puesto Morales/Rinconada 1,113 3,789 1,745 44% Surubi 1,124 1,124 28% Coiron Amargo 437 666 548 14% Sub Total 2,674 4,455 3,417 86% Minor Arg Properties 418 418 10% Canada 132 181 162 4% Total 3,224 4,636 3,996 100%

  • 81 % light oil and NGL
  • Top three properties account for 86% of total
  • Block contracts for 90% of the production have been continued for at least ten years

with options to extend further

SEPTEMBER 2015

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SLIDE 9

9

  • 2015 Budget: Vertical & Horizontal Activities to Delineate Four Unconventional Resource Plays

GROWTH STRATEGY: Delineating Unconventional Shales & Tight Sand Plays in Neuquen Basin

LOMA MONTOSA RESOURCE PLAY (Oil)

  • Puesto Morales Horizontal Multi-stage Frac

MULICHINCO RESOURCE PLAY (Liquids-rich Gas)

  • Curamhuele Drilling, Completion & Frac Activities

LOWER AGRIO SHALES (Oil)

  • Curamhuele Drilling, Completion & Frac Activities

VACA MUERTA SHALES (Oil)

  • Coiron Amargo Vertical Appraisal Fracs
  • Coiron Amargo Horizontal Multi-stage Frac

NEUQUÉN BASIN SEPTEMBER 2015

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SLIDE 10

10 SEPTEMBER 2015

  • Thickness of 100 metres to 500+ metres
  • Progressively deeper & thicker from east to west in the basin
  • The Vaca Muerta is Oil prone at Coiron Amargo
  • Madalena expects the Vaca Muerta is Gas prone around the Cortadera block

and Gas, Liquids & Oil prone at Curamhuele

VACA MUERTA: One of Largest Shale Plays Outside of N. America1

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 – EIA June 26, 2015 – World Shale Gas and Shale Oil Resource Assessment 2 - 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. 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.

Vaca Muerta is Prospective at Coiron, Cortadera and Curamhuele

Comparison of Vaca Muerta and US Shale Plays

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SLIDE 11

VACA MUERTA: Coiron Amargo in the Activity Sweet Spot

11 11

Wintershall - Aguada Federal; March 16, 2015 (Wintershall website)

  • 2 vertical VM wells in 2015
  • Contingency of 6 horizontal VM wells

Petronas La Amarga Chica; Dec 2014 (YPF Website) $ 550 Million Drilling Venture Loma Campana -Chevron / YPF;

  • Jan. 9, 2015 (Petrolnews.net)
  • 200 VM wells on production
  • 2015 -120 vertical VM wells

+ 40 horizontal VM wells SHELL - Cruz de Lorena & Sierras Blancas ; Aug 26, 2015 – Buenos Aires Herald

  • 35 yr Exploitation Contract Awarded
  • Plan to invest $250 MM exploring 2 blocks

SEPTEMBER 2015

CAS.X-16 CAS.X-15

*** See “Analogous Information” on Slide 30 of this presentation.

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SLIDE 12

COIRON AMARGO: Offsetting Significant Production Increases

12 12

Source: July 2015 Unconventional Resources Technology Conference: 2153944 Paper – Sweet Spots in Vaca Muerta: Integration of Subsurface and Production Data in Loma Campana Shale Development, Argentina *** See “Analogous Information” on Slide 30 of this presentation.

SEPTEMBER 2015

Vaca Muerta Development Positive Results

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SLIDE 13

Vaca Muerta Sweet Spot: Horizontal Development Accelerating

13 13

Notes: All Production data up to July 2015 – Source: Secretaria De Energia (www.energia.gov.ar) See page 30 for a discussion on Analogous Information

SEPTEMBER 2015

Hz Well’s 17 Miles 2015 Shell Two Vaca Muerta Hz Wells SB.x-1005(h) + SB.x-1006(h) IP(30) July 2015 average per well 654 Bopd, 320 Mcf/d, 7% wcut, 706 Boe/d Vaca Muerta Vertical Light Oil producers and show wells 2014 Shell First Hz at Cruz De Lorena CdL.x-1(h) Onstream Mar 2014, IP(30) April 2014 417 Bopd, 220 Mcf/d, 13% wcut, 514 Boe/d July ‘15 (17 mon later) – 226 Bbls/d, 116 Mcf/d, 1% Wcut, 245 Boe/d Cum Oil 124 MBbls, 61 MMcf, 134 MBoe YPF Loma Campana East Side Ten New Vaca Muerta Hz Wells Daily Production (Boe/d) Madalena Sierras Blancas Light Oil Conventional Hz Development All wells have shallower Vaca Muerta oil pay

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SLIDE 14

14

Source: Madalena Energy Inc. mapping

CAN-15(h) CAN-16(h) CAN.xr-2(h) CAN-18(h)

COIRON AMARGO NORTH: Sierras Blancas Horizontal Wells

CURRENTLY DRILLING

SEPTEMBER 2015

Applying N.A. Horizontal Technology to Conventional Light Oil Development

  • Coiron Amargo Norte (108 km2) converted to 25-year exploitation license (MVN 35% W.I. -Non-Op)
  • Four horizontals on production three more planned for 2015 (CAN-19(h), CAN-20(h) & CAN-6(h))
  • Q2 – 2015 Operating Netback US $ 45.57/Boe (CDN $56.05/Boe)
  • GLJ 2P approximately 10% Recovery Factor – opportunity for growth
  • Complementary to Vaca Muerta Unconventional resource play
slide-15
SLIDE 15

15

COIRON AMARGO NORTH: Strong Conventional Production Results

Madalena has a 35% WI

SEPTEMBER 2015

Note: Production results up to July 2015. Avg LJE Hz is the average production from seven Sierras Blancas Hz wells in the Loma Jarillosa Este block directly offsetting Coiron Amargo *** See “Analogous Information” on Slide 30 of this presentation.

slide-16
SLIDE 16

Curamhuele is a High W. I. Block with Unconventional Resource Potential

  • Exploration Concession
  • Operated 90% W.I. in 56,216 gross

(50,595 net) acres

  • High-impact Plays :

Lower Agrio shale – Light oil Mulichinco tight sandstone – Natural gas Vaca Muerta shale – Gas and Liquids

  • Well logs and tests on two key wells
  • CH.x-1 – Lower Agrio Oil test

3,000 – 3,200 m

  • YP.x-1 – Mulchinco gas and liquids test

3,700 m

CURAMHUELE: Lower Agrio Shale + Mulichinco Tight Gas + Vaca Muerta Shale

16 SEPTEMBER 2015

Filo Morado El Trapial Los Toldos Loma Del Molle La Invernada *** See “Analogous Information” on Slide 30 of this presentation.

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SLIDE 17

No reserves are currently assigned to Curamhuele. Planning a multi-frac operation on the Lower Agrio and Mulichinco prior to year end

2015 PLAN: Combined Test of Lower Agrio + Mulichinco

Note: ¹ Madalena owns a 90% working interest in the Lower Agrio and Mulichinco rights on the Curamhuele block. 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.

17

SJ.Nq.Yp.x-1 TD=3880.0 7.4 km SJ.Nq.Ch.x-1 TD=3457.0

Correlation 200 API
  • 100
50 MV 6 16 IN 0.2 2000 0.2 2000 0.2 2000 350 50 US/MT 450 90 US/MT 0.45
  • 0.15
1908 2898 KG/MT 20 B/E

3150 3200 3250 3300 3350 3400 3450 3500 3550 3600 3650 3700

Correlation 200 API
  • 100
50 6 16 in 0.2 2000 OHMM 0.2 2000 OHMM 0.2 2000 350 50 US/MT 450 90 US/MT 0.45
  • 0.15
V/V 1908 2898 KG/MT 20

2800 2850 2900 2950 3000 3050 3100 3150 3200 3250

Mulichinco

400 m gross pay in YP.X-1

SEPTEMBER 2015

Lower Agrio

  • Plan is to deepen an offset well

(YP.x-1001) by 600 m

  • Multi Frac and commingle the

Lower Agrio and Mulichinco

  • CH.x-1 (Lower Agrio)

Perforated a 10 m interval and flowed without stimulation Aug 1999 – 24hr test 147 bopd, 1% wcut Tested 43 days in Oct-Nov 2008 Flowed at 1,100 psi thru 9 mm choke Averaged 25 Bbls/d oil @ 38 API, no water, gas not measured. Reservoir Pressure ~ 7,400 psi (0.75/ft)

  • YP.x-1 – (Mulichinco)

Perforated a 15 m interval and acidized with 40 m3 (250 bbls) of 15% HCl Initial Test 1990 – 10 mmcf/d, 515 bbls/d

  • f 51 API condensate

Long term test Oct – Nov 2008 (25 days) Average 4.6 mmcf/d, 113 bbls/d condensate 880 Boe/d

slide-18
SLIDE 18

Four Stage Hydraulic Fracture Designed to Maximize Frac Surface Area

CURAMHUELE: Unconventional Frac Design

18 SEPTEMBER 2015

Mulichinco Tight Sand Modelled Frac Wings 400 m (1300 ft) Lower Agrio Section 250 m (800 ft) Sweet Spot High TOC, Brittle,

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SLIDE 19

19

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

  • Q1-2015 – Madalena drilled, fraced and tested the

PMS-1135(h) appraisal horizontal

  • Scalable development potential

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

  • IP(90-Day): ~ 412 Boe/d (200 Bopd plus 1,280 Mcf/d)

PMN-1117(h) PMS-1135(h)

~1 SECTION (640 Acres)

SEPTEMBER 2015

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SLIDE 20

LOMA MONTOSA OIL PLAY: Production Results

20

Note: ¹ Management estimated or reference type curve is based on an internal evaluation by a qualified reservoir engineer. The estimated recovery and production forecast is presented to show the potential of future

  • locations. Despite the early well results on the PMS-1135, there is no certainty that these results can be achieved. Actual or future well results may be materially less than anticipated.

SEPTEMBER 2015

1

slide-21
SLIDE 21

LOMA MONTOSA OIL PLAY: Scalable Resource Play

21

Implementing North American Horizontal (Hz) Multi Frac Technology in Argentina

Note: 1 See “Drilling Locations” on slide 30 2 Management estimated or reference type curve is based on an internal evaluation by a qualified reservoir engineer. The estimated recovery and production forecast is presented to show the potential of future

  • locations. Despite the early well results on the PMS-1135, there is no certainty that these results can be achieved. Actual or future well results may be materially less than anticipated.
  • Dec 31, 2014 Reserve Report has Eight Loma Montosa Hz Undeveloped wells

Proved + Probable Reserves @ 170 Mbbl and 180 mmcf (200 Mboe/well)

  • Management estimated type curve2 of 300 Mboe reflects a target for new multi-frac Hz’s
  • Four Month performance on PMS-1135 is exceeding management’s estimates
  • 40 Unbooked locations1 in mapped area

assuming four wells per square mile

SEPTEMBER 2015

Number of Wells

slide-22
SLIDE 22

Puesto Morales Facilities: 100% Operated & Controlled

22

PMN Main Battery

  • Q2 - 2015 Oil

1,113 bbl/d

  • Capacity

~ 12,000 bbls/d

  • Q2 - 2015 Gas

3.8 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

  • Originally cost approximately USD $40 MM to build

Plant & Infrastructure

  • Room to Grow via Horizontal Development

in Loma Montosa Oil Resource Play

SEPTEMBER 2015

slide-23
SLIDE 23

NOROESTE BASIN: Conventional Light Oil Production with Exploration Upside

SEPTEMBER 2015 23

Additional Exploration & Appraisal Blocks

  • EL Chivil -100% Operated (Producing); Geological features

similar to Surubi area / field

  • El Vinalar -100% Operated (Producing)
  • Santa Victoria - 100% Operated
  • Valle Morado - 96.6% Operated; Significant structure with

confirmed gas (unbooked upside)

  • Multiple exploration leads on 2D and 3D seismic

Palmar Largo (14% Non-Op) 17 wells have cumulative production of > 40 MMBbls Surubi (85% Operated) Proa-2 well has produced > 1.1MM Bbls in 21 months

Palmar Largo (Balbuena Este) Surubi Palmar Largo El Chivil Palmar Largo El Vinalar Valle Morado Santa Victoria

Bolivia Paraguay Argentina

125 km

Operated (Exploration) Non-operated (Exploitation) Operated (Exploitation)

El Chivil Palmar Largo Surubi

*** See “Analogous Information” on Slide 30 of this presentation.

slide-24
SLIDE 24

SUMMARY: Argentina Focused Plan

24

  • Positive Working Capital Position & Focused Plan
  • Active Argentina Drill Program in 2015

2015 / 2016 Plan: Advance Four Key Resource Plays

Loma Montosa Oil play at Puesto Morales - Initial Success at Puesto Morales

  • Lower Agrio Shale oil at Curamhuele
  • Mulichinco Liquids-Rich Gas 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 Strategic Partnerships

SEPTEMBER 2015

slide-25
SLIDE 25

25

APPENDICES

SEPTEMBER 2015

slide-26
SLIDE 26

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. – VP, Engineering

  • Over 30 years of diverse Operations, Reservoir Engineering and

Management experience. Actively involved in the planning and execution

  • f 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. Gus Halas

  • Director of Triangle Petroleum Corp. & executive roles at Central Garden a

& Pet, T-3 Energy Services, Dresser’s Pump Services & Aquilex Corp Barry Larson

  • VP Operations & COO, Parex Resources Inc.(South American producer)

Keith MacDonald

  • President, Bamako Investment Management Ltd; Director of Surge Energy

and Bellatrix Jay Reid

  • Partner, Burnet, Duckworth & Palmer LLP

Kevin Shaw, P. Eng., MBA

  • President & CEO, Madalena Energy Inc

Steven Sharpe (Chairman)

  • Former Chairman of Longview Oil Corp (acquired by Surge Energy) &

Advantage Oil & Gas; Former Director of Renegade (acquired by Spartan) Raymond Smith, P. Eng. President, CEO & Director, Bellatrix Exploration Ltd. Ving Woo, P. Eng.

  • Former VP, Engineering & COO, Bellatrix Exploration Ltd.

MANAGEMENT TEAM BOARD OF DIRECTORS

APPENDIX #1: Experienced Full-Cycle Operating Team

26 SEPTEMBER 2015

slide-27
SLIDE 27

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

APPENDIX #2: Argentina’s World-Class Shale Potential

27

*** See “Analogous Information” on Slide 30 of this presentation.

SEPTEMBER 2015

slide-28
SLIDE 28

28

APPENDIX #3: Vaca Muerta vs US Shales The Vaca Muerta shale compares favourably to leading US shale resource plays

250 500 750 1,000 m

Shale Thickness

Oil Shales Gas Shales Shale Comparisons 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 Thickness (m) 70 - 140 15 - 100 10 - 40 950 - 1350 45 - 75 70 - 90 20 - 45 Depth (m) 2800 - 3200 2200 - 3400 2700 - 3400 3200 - 4500 2300 3700 2100 Porosity (%) 4 - 8 4 - 11 5 - 8 6 - 10 4 - 8 7 - 9 7 - 9 Permeability (nD) 50 - 250 40 - 1300 50K – 500K 30 - 1000 50 - 200 100 - 500 100 - 200 TOC (%) 7 1 - 7 2 - 18 4 4 - 5 3 - 4 4 - 7 Reservoir Pressure (psi) 6300 - 8000 4700 - 7800 3800 – 8400 >11,000 3000 - 3800 7200 - 9100 3500 - 4200 Pressure Gradient (psi/ft) 0.65 – 0.75 0.65 – 0.70 0.43 – 0.75 >0.75 0.4 – 0.5 0.6 – 0.75 0.5 – 0.6

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 2013 -Gas y Petroleo del Neuquén and YPF *** See “Analogous Information” on Slide 30 of this presentation.

SEPTEMBER 2015

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SLIDE 29

Greater Paddle River Area (>130 Net Sections of Land)

  • High Working Interest & Primarily Operated
  • Multiple Plays for horizontal multi-stage frac operations:
  • Nordegg
  • Development

~115 net sections

  • Oil & Liquids-rich gas
  • Ostracod
  • Development

~ 55 net sections

  • Oil
  • Notikewin/Wilrich -Development

~113 net sections

  • Liquids-rich gas
  • Additional opportunities exist in: Viking oil, Rock Creek oil

29

APPENDIX #5: CANADIAN ASSETS - West-Central Alberta

ALBERTA

CALGARY EDMONTON

SEPTEMBER 2015

GREENCOURT PADDLE RIVER NITON LEAMAN BIGORAY WILDWOOD WEST COVE 6 miles

slide-30
SLIDE 30

READER ADVISORIES

30

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 used in isolation, as the conversion ratio of six Mcf 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 that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value. Analogous Information Certain information in this document may constitute "analogous information" as defined in National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities ("NI 51-101"), 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 51-101 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 should not be construed as an estimate of future production levels. Such information is also not an estimate of the reserves or resources attributable to lands held or to be held by Madalena and there is no certainty that the reservoir data and economics 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, 2015. 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 www.sedar.com. 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.

SEPTEMBER 2015