September 2012

Forward-looking Statements

2

This presentation contains forward-looking information and forward-looking statements within the meaning of applicable securities legislation (collectively “forward-looking statements”). The use of any of the words “upside”, “repeat”, “recruit”, “prove”, “accelerate”, “identify”, “target”, “facilitate”, “prioritize”, “advance”, “expand”, “incorporate”, “refine”, “increase”, “continue”, “evaluate”, “considering”, “advancing”, “analyzing”, “completing”, “commencing” and similar expressions are intended to identify forward-looking statements. These statements involve known and unknown risks, uncertainties and other factors that may cause actual results or events to differ materially from those anticipated in such forward-looking statements. The Corporation believes the expectations reflected in those forward-looking statements are reasonable, but no assurance can be given that these expectations will prove to be correct. Such forward-looking statements included in the presentation should not be unduly relied upon. These statements speak only as of the date of the presentation. The presentation contains forward-looking statements pertaining to the following: business strategy, strength and focus; the granting of regulatory approvals; the timing for receipt of regulatory approvals; the resource potential of the Properties; the estimated quantity and quality of the Corporation’s oil and natural gas resources; projections of market prices and costs and the related sensitivity of distributions; supply and demand for oil and natural gas; expectations regarding the ability to raise capital and to continually add to resources through acquisitions and development; treatment under governmental regulatory regimes and tax laws, and capital expenditure programs; expectations with respect to the Corporation’s future working capital position; capital expenditure programs; and abandonment and reclamation costs. With respect to forward-looking statements contained in the presentation, assumptions have been made regarding, among other things: future commodity prices; the Corporation’s ability to obtain qualified staff and equipment in a timely and cost-efficient manner; the ability of the Corporation to progress through the conditions precedent to conclude the Origin Agreement on schedule, or at all; the impact of any changes in New Zealand law; the regulatory framework governing royalties, taxes and environmental matters in New Zealand and any other jurisdictions in which the Corporation may conduct its business in the future; the ability of the Corporation's subsidiaries to obtain subsequent mining permits, access rights in respect of land and resource and environmental consents; the recoverability of the Corporation’s crude oil, natural gas and natural gas liquids resources; the applicability of technologies for recovery and production of the Corporation’s oil, natural gas and natural gas liquids resources; the Corporation’s future production levels; the Corporation’s ability to market crude oil, natural gas and natural gas liquids production; future development plans for the Corporation’s assets unfolding as currently envisioned; future capital expenditures to be made by the Corporation; future cash flows from production meeting the expectations stated herein; future sources of funding for the Corporation’s capital program; the Corporation’s future debt levels; geological and engineering estimates in respect of the Corporation’s resources; the geography of the areas in which the Corporation is exploring; the impact of increasing competition on the Corporation; and the Corporation’s ability to obtain financing on acceptable terms, or at all. Actual results could differ materially from those anticipated in these forward-looking statements as a result of the risk factors set forth below and elsewhere in the presentation: the speculative nature of exploration, appraisal and development of oil and natural gas properties; uncertainties associated with estimating oil and natural gas resources; changes in the cost of operations, including cots of extracting and delivering oil and natural gas to market, that affect potential profitability of oil and natural gas exploration; operating hazards and risks inherent in oil and natural gas operations; volatility in market prices for oil and natural gas; market conditions that prevent the Corporation from raising the funds necessary for exploration and development on acceptable terms or at all; global financial market events that cause significant volatility in commodity prices; unexpected costs or liabilities for environmental matters; competition for, among other things, capital, acquisitions of resources, skilled personnel, and access to equipment and services required for exploration, development and production; changes in exchange rates, laws of New Zealand or laws of Canada affecting foreign trade, taxation and investment; failure to realize the anticipated benefits of acquisitions; and other factors. Readers are cautioned that the foregoing list of factors is not exhaustive. Statements relating to “resources” are deemed to be forward-looking statements, as they involve the implied assessment, based on certain estimates and assumptions, that the resources described can be profitably produced in the future. The forward-looking statements contained in the presentation are expressly qualified by this cautionary statement. Except as required under applicable securities laws, the Corporation does not undertake or assume any obligation to publicly update or revise any forward-looking statements.

Cautionary Note Regarding Reserve & Resource Estimates

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A prospective resource is defined as those quantities of petroleum estimated, as of a given date, to be potentially recoverable from undiscovered accumulations by application of future development projects. Prospective resources have both an associated chance of discovery and a chance of development. Prospective resources are further subdivided in accordance with the level of certainty associated with recoverable estimates assuming their discovery and development and may be sub‐classified based on project maturity. There is no certainty that any portion of the resources will be discovered. If discovered, there is no certainty that it will be commercially viable to produce any portion of the resources. In April 2012, NZEC released its 2011 year-end reserve and resource estimation and economic evaluation (the “Report”), prepared by Deloitte & Touche LLP (“AJM Deloitte”). The reserve estimate and economic evaluation was confined to NZEC’s 100% working interest Eltham Permit (PEP 51150) and was based on the reservoir and production data from the Copper Moki-1 well with a December 31, 2011 cut-off. The oil and gas reserves calculations and income projections, upon which the Report was based, were estimated in accordance with the Canadian Oil and Gas Evaluation Handbook (“COGEH”) and National Instrument 51-101 (“NI 51-101”). The term barrels of oil equivalent (“boe”) may be misleading, particularly if used in isolation. A boe conversion ratio of six Mcf: one bbl was used by NZEC. This conversion ratio is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Reserves are estimated remaining quantities of oil and natural gas and related substances anticipated to be recoverable from known accumulations, as of a given date, based on: the analysis of drilling, geological, geophysical, and engineering data; the use of established technology; and specified economic conditions, which are generally accepted as being reasonable. Reserves are classified according to the degree of certainty associated with the estimates. Proved Reserves are those reserves that can be estimated with a high degree of certainty to be recoverable. It is likely that the actual remaining quantities recovered will exceed the estimated proved reserves. Probable Reserves are those additional reserves that are less certain to be recovered than proved reserves. It is equally likely that the actual remaining quantities recovered will be greater or less than the sum of the estimated proved plus probable reserves. Possible Reserves are those additional reserves that are less certain to be recovered than probable reserves. There is a 10% probability that the actual remaining quantities recovered will exceed the sum of the estimated proved plus probable plus possible reserves.

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NZEC Opportunity: Producing and exploring for oil and natural gas in New Zealand

Production • Three wells in production $5.4 M positive cash flow in Q2-2012 • Top-tier operating netback in Brent pricing environment $78/bbl in Q2-20121

Exploration • Eight-well exploration campaign underway • Multi-zone potential in each well • More than 30 3D-defined drilling leads, up to four wells per lead

Growth • 2 million acre land package with both conventional and unconventional targets2

• Large prospective reserve/resource base: 203 MM bbl conventional 478 MM bbl unconventional3,4

• Expanding portfolio with acquisitions and partnerships

1. NZEC calculates the netback as the oil sale price less fixed and variable operating costs and a 5% royalty. Q2-2012 netback of US$78.12/bbl based on average realized oil price of US$105. Netback will fluctuate based on prevailing oil price. 2. Approximately 1 million net acres granted across four permits. East Cape permit is pending Crown approval. 3. Reserves published April 30 based on Copper Moki-1 reservoir and production data with Dec 31, 2011 cut-off. Resources based on AJM Petroleum Consultants Net Prospective Resource (best estimate). See Cautionary Note Regarding Reserve & Resource Estimates. 4. Assumes NZEC completes requirements to earn full 65% interest in Alton Permit.

5

New Zealand Advantage

• Proactive Government approach to exploration and development

• Favorable royalty and tax structure • Brent pricing environment with top-tier

netbacks • Proven hydrocarbon systems with

multi-zone potential • Established infrastructure with capacity • New Zealand Government goal of

energy self sufficiency by 2030 • Current oil production of ~55,000 bbl/d,

demand of ~150,000 bbl/d • Current natural gas production of

~460 MMcf/d with significant additional in-country capacity

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Permit Working Interest

Net Acres Prospective Resource 1

Eltham 100% 93,167 32.1 MM bbl

Alton 65%2 77,482 45.0 MM bbl

New Petroleum Licenses

100% 26,907 Acquisition pending 3

Ranui 100% 223,087 40.5 MM bbl

Castlepoint 100% 551,045 208.6 MM bbl

East Cape 4 100% 1,067,495 355.4 MM bbl

Total Acreage 2,012,276

1. Net Prospective Resource as identified by AJM Petroleum Consultants (best estimate) assuming 9% recovery for conventional resources and 2% recovery for unconventional resources.

2. Assumes NZEC completes the requirements to increase its interest in the Alton permit from 50% to 65%, as per an agreement with L&M Energy Limited.

3. Acquisition of four Petroleum Licenses and Waihapa Production Station from Origin Energy. Transaction expected to close in Q4-2012. See Strategic Taranaki Acquisition.

4. East Cape permit pending Crown approval.

Eltham Alton

Ranui

Castlepoint

East Cape

Conventional Focus

Conventional and Unconventional Targets

Asset Overview

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• Proven hydrocarbon basin producing ~130,000 boe/day from 18 fields

• 2 permits with more than 33 prospects

• Four consecutive oil discoveries

• 2D seismic database: 60,666 km • 3D seismic database: 5,802 km2

170,649 Net acres 1

843 MM Barrels OOIP 1,4

77.1 MM Barrels conventional prospective resource 1,3

1. Assumes NZEC completes the requirements to increase its interest in the Alton permit from 50% to 65%, as per an agreement with L&M Energy Limited. 2. Reserves estimate based on reservoir and production data from Copper Moki-1 with a Dec 31, 2011 cut-off. 3. Net Prospective Resource as identified by AJM Petroleum Consultants (best estimate) assuming 9% recovery. 4. Net Undiscovered Petroleum Initially in Place (OOIP) as identified by AJM Petroleum Consultants. See Cautionary Note Regarding Reserve & Resource Estimates.

412,200 Barrels oil equivalent 3P reserves 2

Taranaki Basin

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~20,000 boe/d production surrounding NZEC permits

Copper Moki wells x

1. Natural gas and liquids currently being flared pending completion of a natural gas pipeline, on schedule for tie-in to Waihapa Production Station by end of June 2012.

Taranaki Basin

• Permits on trend with existing oil and gas fields

• Exploration strategy • Mt. Messenger is primary target • Use 3D seismic to identify leads • Prioritize leads with multi-zone

potential high impact exploration with low incremental capital cost

• Significant drilling inventory of 3D defined leads • Up to four wells per lead • Up to 1 MM bbl recoverable per

well • Waitapu-1 spud August 19 fully

funded for eight well drilling program

Waitapu-1 well

x

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Copper Moki Site

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Seismic Cross Section Cheal - Copper Moki - Taranaki Thrust Fault Zone

Multi-zone Production Potential

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Taranaki Basin – Exploration Strategy

Copper Moki wells x • Target Mt.

Messenger formation

• Explore multi-zone potential at minimal incremental cost

x

Waitapu-1 well

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Production Report Card

CM-1 CM-2 CM-3 CM-4

Producing formation

Oil quality

Initiated continuous production

Cumulative production to August 28

Cumulative revenue to August 28

Average oil production1

Reserves

Mt. Messenger

41.8o API

December 2011

88,809 bbl

$9,741,000

~125 bbl/d

412,000 boe 3P

Mt. Messenger

41.8o API

April 2012

57,215 bbl

$6,275,000

~121 bbl/d

n/a

Mt. Messenger

40.0o API

July 2012

21,819 bbl

$2,393,000

~219 bbl/d

n/a

Urenui

29o API

Awaiting installation of

artificial lift

Gas and liquids opportunity

Gas to be sold1

Condensate to be recovered1

LPG to be recovered1

Estimated daily revenue3

480 mcf/d

6 bbl/d

23 bbl/d

$3,274

515 mcf/d

6 bbl/d

25 bbl/d

$3,512

252 mcf/d

3 bbl/d

12 bbl/d

$1,719

1. Average daily production for month of August 2012. NZEC has completed a natural gas pipeline and tie-in to the Waihapa Production Station. The operator is finalizing arrangements to receive the gas, and NZEC expects to begin generating cash flow from its natural gas production shortly. 2. Gross revenue based on August production numbers assuming 60 bbl of liquids for every MMcf natural gas produced, with each bbl of liquids composed of 80% LPG and 20% condensate and a sale price of $4/mcf of natural gas , $85/bbl of condensate and $37.50/bbl of LPG.

13 13

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Strategic Taranaki Acquisition

Upstream Assets • Four Petroleum Licenses covering

26,907 acres, contiguous with Eltham and Alton permits

Midstream Assets • Waihapa Production Station – includes

facilities for gas processing, C3 plus liquids recovery, oil processing and water disposal with associated gathering and sales pipelines

Deal Terms • Purchasing Assets from Origin Energy • C$42 million plus 5% gross overriding

royalty to Origin • Expected to close in Q4-2012 subject to

a number of conditions precedent1

1. Closing of the acquisition is targeted for Q4-2012 and contingent on receiving government approvals, Origin completing the current recommissioning of the TAWN LPG extraction facility, Origin and/or NZEC entering into an agreement with Contact Energy regarding ongoing operation of Contact’s Ahuroa gas storage facility, and standard TSX Venture Exchange approvals.

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Transaction Rationale

Prime acreage in heart of Taranaki fairway • 26,907 acres offering 3D-defined drilling leads, well control from 27 logs and near term tie-in

potential • 16 drill pads with infrastructure provide opportunity for near-term drilling and immediate tie-in of

discoveries • Significant increase to drilling inventory

• 200% increase in Mt. Messenger leads defined by 3D seismic

Accelerated tie-in timelines and cost savings for gas and liquids production • Having oil and gas gathering lines in place reduces tie-in timeline by 6 to 9 months

• $2.5 M to $3.6 M1 savings / well • Controlling midstream infrastructure could reduce processing costs by ~$0.7 M to $1.4 M1 per well

Preparing for growth • Waihapa Production Station and pipeline infrastructure will facilitate growth beyond 25,000 boe/d • Control of Taranaki oil and gas processing hub and infrastructure strategically positions NZEC to

quickly get its own production to market, with new business opportunities to process third-party production

1. Present value of estimated cost savings discounted at 10%. Assumes acceleration of the tie-in of new wells resulting in earlier cash flow from natural gas and oil production, reduced costs associated with delivering oil and natural gas to market, savings resulting from ability to tie-in to pipeline infrastructure, and midstream cost savings.

Strategic Acquisition – Existing Wells

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Uphole completion potential • Previous wells penetrated NZEC’s

target formations • Well log data from 27 wells • Well control expedites exploration

cycle time, reduces drilling risk • Data demonstrate production

potential from Mt. Messenger and Kapuni formations, with good hydrocarbon shows in Moki and Urenui formations

• Uphole completion potential in existing wells across target formations

• Evaluating well log data and well condition to prioritize exploration opportunities once acquisition closes Closing of the acquisition is targeted for Q4-2012 and contingent on receiving government approvals, Origin

completing the current recommissioning of the TAWN LPG extraction facility, Origin and/or NZEC entering into an agreement with Contact Energy regarding ongoing operation of Contact’s Ahuroa gas storage facility, and standard TSX Venture Exchange approvals.

Strategic Acquisition – New Leads & Prospects

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Four Petroleum Licenses • Renewable without relinquishment • Resource consents in place • 16 established drill pads, most with oil

and gas gathering lines in place

Expanded inventory of 3D seismic leads • 93 km2 3D seismic data, 585 km 2D

seismic data • 14 Mt. Messenger leads, 8 Urenui

leads, 8 Moki leads • 6 leads on 2D seismic, assessment of

Kapuni potential underway • Continuing to evaluate seismic and

well log data, drill pads and surface facilities to prioritize exploration opportunities once acquisition closes

Closing of the acquisition is targeted for Q4-2012 and contingent on receiving government approvals, Origin completing the current recommissioning of the TAWN LPG extraction facility, Origin and/or NZEC entering into an agreement with Contact Energy regarding ongoing operation of Contact’s Ahuroa gas storage facility, and standard TSX Venture Exchange approvals.

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Taranaki Basin – Drilling Inventory

Mt. Messenger formation Leads & Prospects Potential Inventory (Wells)

Eltham and Alton permits – 3D 6 24

Eltham and Alton permits – 2D 12 48

New Petroleum Licenses – 3D 1 14 56

32 128

Additional leads and prospects identified in Urenui and Moki formations

• Up to four wells per prospect • Up to 1 MM bbl recoverable per well • In addition to its Mt. Messenger focus, NZEC has identified numerous Urenui and

Moki leads and is considering opportunities in the deeper Kapuni formation • New Petroleum Licenses offer uphole completion opportunities in NZEC’s target

formations • Interpretation of recently completed 100 km2 3D seismic survey and well log

data from new Petroleum Licenses will further delineate exploration prospects

1. Acquisition of four Petroleum Licenses and Waihapa Production Station from Origin Energy. Transaction expected to close in Q4-2012. See Strategic Taranaki Acquisition.

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Strategic Acquisition – Waihapa Production Station

Closing of the acquisition is targeted for Q4-2012 and contingent on receiving government approvals, Origin completing the current recommissioning of the TAWN LPG extraction facility, Origin and/or NZEC entering into an agreement with Contact Energy regarding ongoing operation of Contact’s Ahuroa gas storage facility, and standard TSX Venture Exchange approvals.

Oil handling

Water handling Gas compression TAWN LPG facilities

Condensate tank

Propane, butane and LPG tanks

Water reservoir

• Only open-access midstream facility in Taranaki Basin business opportunities for processing third-party gas, liquids, oil and water

• Full-cycle gathering and sales infrastructure

• Central to NZEC’s inventory of exploration prospects

• Reduces NZEC’s processing and transportation costs

• Gathering capacity in place to service NZEC’s oil and gas production

• Sales pipelines in place to deliver NZEC production to market

• Facilitates NZEC’s longer-term growth plans

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Midstream Assets – Waihapa Production Station

• Waihapa oil facility • 25,000 bbl/d oil processing facility • 7,800 bbl oil storage capacity • 49-km 15,500 bbl/d oil sales pipeline from Waihapa to Omata Tank Farm

• TAWN gas facility • 45 mmcf/d LPG separation capacity • 44 mmcf/d compression capacity • 51-km 8-inch gas sales pipeline from TAWN to New Plymouth • Storage tanks for LNG, butane and propane

• Water disposal operations • 3,600 bbl water storage capacity • 18,000 bbl/d water injection capacity

• Various contracts relating to Waihapa Production Station • 100 acres of buffer fields surrounding Waihapa Production Station

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• World-class resource potential in two oil shale packages

• 1.4 B bbl conventional OOIP 3

• 20.9 B bbl unconventional OOIP 3

• 2 permits issued, 1 permit pending 1

• 2D seismic database: 14,535 km • 3D seismic database: 1,390 km2

1.8 M Net acres 1

126 MM Barrels conventional prospective resource 2

478 MM Barrels unconventional prospective resource 2

1. East Cape Permit pending Crown approval. 2. Net Prospective Resource as identified by AJM Petroleum Consultants (best estimate) assuming 9% recovery for conventional resources and 2% recovery for unconventional resources. 3. Net Undiscovered Petroleum Initially in Place (OOIP) as identified by AJM Petroleum Consultants. See Cautionary Note Regarding Reserve & Resource Estimates.

East Coast Basin

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• Over 300 oil and gas seeps sourced back to two oil shale formations

• Advancing technical understanding of shale targets • NZEC analyzing results from

three stratigraphic wells • Recently completed 70 km of 2D

seismic on Ranui and Castlepoint permits

• Apache Corp. and TAG Oil exploring offsetting permits

East Coast Basin Exploration

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East Coast Basin Oil Shale Potential Waipawa Whangai Bakken

Basin/Jurisdiction East Coast New Zealand

East Coast New Zealand

Willesden North Dakota & Saskatchewan

Quartz Content (%) 40 – 80 40 – 80 40 – 60 Carbonate Content (%) 5 – 40 5 – 40 10 – 20 Clay Content (%) Unknown Unknown 5 – 20 Depth (meters) 0 – 5,000 0 – 5,000 2,700 – 3,500 Thickness (meters) 10 – 70 300 – 600 10 – 50 Porosity (%) 3 – 8 3 – 8 4 – 12 Permeability (microdarcies) 10 – 200 10 – 110 5 – 1,000 Kerogen Type Type II Type II Type II TOC (%) 3.0 – 12.0 0.2 – 1.7 1.0 – 21.0 Vit Reflectance (R) 0.3 – 0.4 0.4 – 1.4 0.7 – 1.1 Tmax (Celsius) 430 – 445 420 – 445 420 – 450

Geologic Age Late Paleocene Late Cretaceous / Paleocene Upper Devonian

Source: AJM Petroleum Consultants

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Corporate Profile

Common Shares Outstanding Options (Exercisable at average $1.22) Advisor Warrants (Exercisable at $1.00) Fully Diluted Shares Outstanding

121.8 million 7.4 million 0.7 million

129.8 million

Insider Ownership (FD) 52 Week High / Low Average Volume (Q2-2012)

~35% $3.79 / $0.90

~460,000 shares/day

IPO – August 2011 $63M Financing – March 2012

$1.00/share $3.00/share

Q2-2012 Highlights Oil sold Positive cash flow Average realized oil price Netback 1

Cash and cash equivalents (at August 28)

58,952 barrels

$5.4 million US$105/bbl

US$78.12/bbl $43.8 million

1. NZEC calculates the netback as the oil sale price less fixed and variable operating costs and a 5% royalty. Q2-2012 netback of US$78.12/bbl based on average realized oil price of US$105. Netback will fluctuate based on prevailing oil price.

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Significant Catalysts in H2-2012

Production • Achieve 3,000 boe/d by year-end 20121

• Generate cash flow from natural gas, liquids and condensate production

Exploration • Eight well drilling program underway • Update reserve estimate

Growth • Complete acquisition of Petroleum

Licenses and Waihapa Production Station • Incorporate exploration leads and uphole

completion opportunities into Taranaki Basin exploration strategy

• Refine exploration strategy for East Coast oil shales

1. Management prepared production forecast based on operational success in the Taranaki Basin, planned drilling of eight exploration wells in H2-2012, completion of natural gas pipeline allowing for marketing of natural gas production, and continued performance in line with existing oil and natural gas production from Copper Moki-1 and Copper Moki-2.

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Focused on Growth in 2013

Production • Increase reserves, production and cash

flow through exploration success

Exploration • Drill one well per month into

conventional Taranaki targets • Drill at least one exploration well to

evaluate East Coast oil shale formations

Growth • Continue to evaluate acquisition and

farm-in opportunities • Continue to expand team to support

growth plans

27

Appendix

Collaborative Partnerships

• Forged Cooperation Agreement with New Zealand iwi partners

• Employ more than 70 people from local communities

• Committed to bringing long-term benefits to community partners

Cooperation Agreement Meeting February 22, 2012

28

29

Board of Directors

Name Expertise Experience

John A. Greig, M.Sc, P.Geo

Chairman

• Founder and financier of numerous mining and oil and gas companies. Specializing in recognizing undervalued geological assets

• Founder, Director & Officer Sutton Resources, Cumberland Resources Ltd., Eurozinc Mining Corp., Crown Resources Corp.

John G. Proust, C.Dir CEO

Director

•Proven track record of building companies from grass roots to advanced development. Specializes in identifying undervalued assets on a global basis

•Chairman, CEO & Director, Southern Arc Minerals Inc. •Chairman, Canada Energy Partners Inc.

Bruce G. McIntyre, P.Geol

Executive Director

•Professional petroleum geologist with over 30 years of proven exploration and development oriented value creation

•President, CEO Sebring Energy Inc. •President, CEO TriQuest Energy Corp. •President, CEO BXL Energy Ltd., • Exploration Manager Gascan Resources Ltd.

D. Kenneth Truscott Director

• Senior executive with over 30 years of corporate development and negotiation experience in the Canadian oil and gas industry

• Senior Vice President, Land & Business Development Crew Energy Inc.

• Founder, CEO Morpheus Energy Corp.

Hamish J. Campbell B.Sc (Geology),

FAusIMM Director

•Professional geologist with 30 years of experience managing exploration programs, evaluation and assessment of joint ventures and acquisitions

•Director of a number of New Zealand limited liability mineral and petroleum companies

•Principal Indonesian mining service company • Executive Vice President, Southern Arc Minerals Inc.

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Corporate Office – Canada

Name Expertise Experience

John G. Proust, C.Dir Chief Executive Officer

• Proven track record of building companies from grass roots to advanced development. Specializes in identifying undervalued assets on a global basis

• Chairman, CEO & Director, Southern Arc Minerals Inc. • Chairman, Canada Energy Partners Inc.

Bruce G. McIntyre, P.Geol Executive Director

• Professional petroleum geologist with over 30 years of proven exploration and development oriented value creation

• President, CEO Sebring Energy Inc. • President, CEO TriQuest Energy Corp. • President, CEO BXL Energy Ltd., • Exploration Manager Gascan Resources Ltd.

Jeff Redmond, CA Chief Financial Officer

• Finance, mergers & acquisitions, and taxation • Public company reporting and assurance

• Former Director of Finance, acting CFO for Western Coal Corp • Controller for hi-tech publicly listed company • Auditor with KPMG LLP

Celeste M. Curran, B.A. (Hon), L.L.B.

VP Corporate & Legal Affairs

• Over 20 years of legal and negotiating experience specializing in major projects

• VP, Corporate & Legal Affairs, J. Proust & Associates • Lead counsel for City of Vancouver and City of Richmond for

the 2010 Olympic and Paralympic Winter Games • Senior Solicitor, City of Vancouver

Rhylin Bailie, B.ES VP Communications &

Investor Relations

• More than 16 years of experience in the resource industry, in both finance and investor relations

• Professional writer and editor

• Director Communications & Investor Relations, NovaGold Resources Inc.

• Supervisor Treasury Administration, Placer Dome Inc.

Eileen Au, B.Sc Corporate Secretary

• More than 15 years of experience overseeing corporate governance and corporate affairs for publicly-listed resource companies

• Corporate Secretary for various public and private resource companies

• Director of Bryant Resources and Charlotte Resources

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Operations Team – New Plymouth, NZ

Name Expertise Experience

Chris Bush, B.Sc (Hon), CFA New Zealand

Country Manager (starting end of Sept)

• Chemical engineer with more than 30 years in both upstream and downstream oil and gas experience internationally

• New Zealand Country Manager/Director, Origin Energy • Chairman of Petroleum Exploration and Producers Association

of New Zealand

Cliff Butchko P.Eng, MBA (Hon) General Manager

Upstream Operations

• Professional engineer with over 30 years experience evaluating and managing oil and gas resources

• President Omni Oil and Gas Inc. • Vice President Lexoil Inc. • Partner and Co-founder TIFF advisory group • Senior technical positions in several resource companies

Mike Oakes General Manager

Midstream Operations

• More than 30 years of international oil and gas experience overseeing design, commissioning and start up, staffing and operation of oil and gas fields and production facilities

• Operations Manager, Asset Manager and Operational Excellence Advisor, Origin Energy

• Technical Advisor, Total E&P Borneo

James Watchorn, B.Sc Operations Manager

• Mechanical engineer with more than 15 years of experience in all aspects of drilling, completions and production, and facility and wellsite construction

• Production and Facilities Manager, TAG Oil • Senior Petroleum Engineer, Origin Energy • Operations Engineer, Iteration Energy/Chinook Energy

John Hudson, B.BS, CA Group Financial Controller

• More than 18 years of accounting experience, including six years in the oil and gas sector, with expertise in systems implementation and process controls

• Financial Controller for Weatherford International, Parker Drilling (NZ) and Taranaki District Health Board

• Ernst & Young Chartered Accountant

Toka Walden Land Manager • Senior Manager, New Zealand Dept. of Conservation

• Negotiating access provisions and facilitating resource consent process, assisting with community relationship building

32

Technical Team – Wellington, NZ

Name Qualifications Expertise

Dr. Ian Brown D.Eng Chief Operating Officer; professional geological engineer

June Cahill B.Sc,

B. Applied Econ. Acquisition, management, and analysis of complex geoscience data

Bill Leask B.Sc (Hons) M.Sc (Hons)

Petroleum geology related to the East Coast and other New Zealand basins

Dr. Simon Ward B.Sc (Hons)

Ph.D Petroleum geology related to the Taranaki and other New Zealand basins

Ian Calman B.Sc (Hons) Seismic data acquisition, processing, and interpretation

Gareth Reynolds B.Sc (Hons) Geology Geoscientist with experience in New Zealand Basin analysis

Dr. Richard Kellett B.Sc (Hons), Ph.D, P.Geoph Geoscientist with worldwide exploration and business development experience

Peter Wood B.E (Hons), B.Sc ,

M.Comp.Sci Management and development of computing resources for geoscience applications

Sam Pryde B.Sc

Post.Grad.Dip. Geological investigations in the East Coast basin area

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Contact NZEC

Corporate Head Office John Proust, Chief Executive Officer Bruce McIntyre, Executive Director Rhylin Bailie, VP Investor Relations NA Toll-free: 1-855-601-2010 info@newzealandenergy.com

New Zealand Office Ian Brown, Chief Operating Officer Tel: + 64-4-471-1464 NZ Toll-free: 0800-469-363 www.NewZealandEnergy.com