The document is a corporate presentation for NZEC detailing their operations and future plans in oil and gas production on New Zealand's North Island. It includes forward-looking statements about resource potential, production capabilities, and potential risks involved in exploration and development, alongside an overview of reserves and resources. The presentation emphasizes their current production capacity and investment strategies for increasing output while addressing the need for additional capital for exploration activities.

1. TSX-V: NZ
OTCQX: NZERF
Waihapa Production Station
Corporate Presentation
September 3, 2014

2. Cautionary Notes
Forward-looking Statements
This document contains certain 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 “being”, “will”, “until”, “estimate”, “forecast”, “will be”, “is considering”, “will proceed”, “plans”, “reactivate”, “recommence”, “would be”, “could be”, “will bring”, “could bring”, “expected”, 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. Such forward-looking statements should not be unduly relied upon. The Company 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. This document contains forward-looking statements and assumptions pertaining to the following: business strategy, strength and focus; the granting of regulatory approvals; the timing for receipt of regulatory approvals; geological and engineering estimates relating to the resource potential of the Properties; the estimated quantity and quality of the Company’s oil and natural gas resources; supply and demand for oil and natural gas and the Company’s ability to market crude oil, natural gas and; expectations regarding the ability to raise capital and to continually add to reserves and resources through acquisitions and development; the Company’s ability to obtain qualified staff and equipment in a timely and cost-efficient manner; the ability of the Company’s subsidiaries to obtain mining permits and access rights in respect of land and resource and environmental consents; the recoverability of the Company’s crude oil, natural gas reserves and resources; and future capital expenditures to be made by the Company. 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 document, such as 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 costs 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 Company 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 “reserves and 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 document are expressly qualified by this cautionary statement. These statements speak only as of the date of this document and the Company does not undertake to update any forward-looking statements that are contained in this document, except in accordance with applicable securities laws. More information is available in the Company’s Annual Information Form for the year ended December 31, 2012, filed on June 17, 2013 on SEDAR at www.sedar.com.
Reserve & Resource Estimates
The oil and gas reserve and resource calculations and net present value projections 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. Revenue projections presented are based in part on forecasts of market prices, current exchange rates, inflation, market demand and government policy which are subject to uncertainties and may in future differ materially from the forecasts above. Present values of future net revenues do not necessarily represent the fair market value of the reserves evaluated. Information concerning reserves may also be deemed to be forward looking as estimates imply that the reserves described can be profitably produced in the future. These statements are based on current expectations that involve a number of risks and uncertainties, which could cause the actual results to differ from those anticipated. Contingent resources are those quantities of oil and gas estimated on a given date to be potentially recoverable from known accumulations using established technology or technology under development, but which are not currently considered to be commercially recoverable due to one or more contingencies. Contingencies may include factors such as economic, legal, environmental, political and regulatory matters, or a lack of markets. Prospective resources are those quantities of oil and gas estimated on a given date to be potentially recoverable from undiscovered accumulations. Undiscovered resources means those quantities of oil and gas estimated on a given date to be contained in accumulations yet to be discovered. The resources reported are estimates only and there is no certainty that any portion of the reported resources will be discovered and that, if discovered, it will be economically viable or technically feasible to produce. More information is available in the Company’s Form F1-101F1 Statement of Reserves Data and Other Oil and Gas Information dated April 2, 2014, which is filed on SEDAR at www.sedar.com. 2

3. Fully Integrated Upstream/Midstream Company
•
1.15 million total acres on New Zealand’s north island with both conventional and unconventional opportunities
•
97,637 acres and a full-cycle production facility in the main Taranaki Basin production fairway
•
Experienced New Zealand team with exploration and operations expertise
•
Focused on increasing production and cash flow (August 2014: 205 bbl/d) 1
-
Optimizing production from existing wells
-
Advancing previously drilled wells to production  low-cost workovers, rapid tie-in using existing infrastructure
-
New exploration opportunities across multiple prospective formations 2 3
1. Development and operating costs are to be funded initially by existing working capital and cash flows from production. To carry out all of the planned development activities, the Company is considering a number of options to increase its financial capacity, including additional joint arrangements, commercial arrangements, or other financing alternatives. 2. NZEC requires additional working capital or a funding partner to commence drilling new exploration opportunities.

4. Asset Overview – New Zealand’s North Island 4
Permit
Working Interest
Net Acres
2P boe Reserves 1
Contingent Resource 1
Prospective Resource 1
Taranaki Basin – Conventional Targets
Copper Moki
100%
944
536,000
-
-
Eltham
100%
46,444
-
-
31.6 MM bbl
Alton
65%
38,717
-
-
45.0 MM bbl
TWN
50%
11,525
1,113,000
580 M boe
11.7 MM boe
East Coast Basin – Conventional and Unconventional Targets
East Cape
100%
1,048,406
-
-
355.4 MM bbl
Total
1,146,036
1,649,000 boe 2P Reserves net to NZEC (80% oil) $57.9 million NPV (after tax, 10% discount)
1. Reserves and resources estimated by Deloitte LLP. The term barrels of oil equivalent (“boe”) may be misleading. A boe conversion ratio of six Mcf: one bbl was used by NZEC. For effective dates and estimated recovery rates, see NZEC’s most recent annual and interim reserve and resource reports filed on SEDAR in April 2014, the Reserve and Resource tables in this presentation, and the Cautionary Notes. Reserves are updated annually.
Eltham
Alton
East Cape
TWN

5. Multiple Prospective Conventional Formations in Taranaki Basin 5
Moki
Tikorangi
Kapuni
Mt Messenger
Kapuni Group
2,500 metres
3,000 metres
3,500 metres
4,000 metres
Approximate Depth

6. NZEC Production & Development Wells Status at August 29, 2014 6

7. 7
Full-cycle Production Station

8. 8
Oil facility
•
25,000 bbl/d oil handling facility
•
7,800 bbl oil storage capacity
•
49-km 15,500 bbl/d oil sales pipeline from Waihapa to Shell’s Omata Tank Farm
Gas facility
•
45 mmcf/d separation and compression capacity
•
70 tonne/d LPG processing capacity
•
51-km 8-inch gas sales pipeline from Waihapa to New Plymouth
•
Storage bullets for LPG
Water disposal operations
•
3,600 bbl water storage capacity
•
18,000 bbl/d water injection capacity
Includes 100 acres of land providing a buffer zone surrounding the facility
Waihapa Production Station Assets Full-cycle facility with gathering and sales pipeline infrastructure
1. NZEC and L&M Energy have formed a 50/50 joint venture to explore, develop and operate the TWN Licenses and Waihapa Production Station.

9. NZEC’s TWN Management & Operational Experience 9
NZEC Position
Years Relevant O&G Experience
Years Experience with TWN Assets
Previous TWN Associated Roles
Mike Oakes, GM Operations
35+
8
NZ Asset Manager (Origin), Plant Super & Commissioning Supervisor (Fletcher Energy)
Derek Gardiner,
CFO
25
3
Commercial & Finance Manager (Origin)
Newton Cockerill,
Controller
5
5
Business Performance & Accounting Manager (Origin)
Stewart Angelo, Engineering & Maintenance Manager
25+
15
Maintenance & Engineering Consultant (Origin), Maintenance Superintendent (Fletcher Challenge)
Peter Kingsnorth, Plant Superintendent
25+
20
Shift Supervisor (Origin), Plant Operator (Fletcher Challenge and Petrocorp)
Pono Cooper, Field Superintendent
25+
5
Well Services Supervisor (Swift), Waihapa Operations Superintendent (Origin)

10. Mt. Messenger Opportunities
Drill-proven formation
•
Significant discoveries to the west (TAG: Cheal), south (NZEC: Copper Moki, Waitapu) and east (Kea: Puka)
•
Contingent resources: 88,000 bbl oil (100% basis) 1
•
Prospective resources: 2,061,000 bbl oil (100% basis) 1 Low-cost production potential in existing wells 2
•
Well information shows uphole Mt. Messenger completion potential in multiple Tikorangi wells
•
First successful uphole completion in March 2014
•
Three additional uphole completion opportunities identified to date
•
Drill pads and gathering systems in place  reduced drilling expense, expedited tie-in, reduced opex New exploration opportunities 2
•
More than 18 new Mt. Messenger leads identified on 3D seismic on TWN Licenses
•
Additional drill targets on Eltham and Alton permits 10
1. Prospective resources for Mt. Messenger formation only, shown on a 100% basis. Additional ~880,000 bbl prospective resources estimated for Urenui and Moki formations. Resources attributable to NZEC at 50%. See TWN Resource Estimate and Cautionary Notes. 2. Development and operating costs are to be funded initially by existing working capital and cash flows from production. To carry out all of the planned development activities, the Company is considering a number of options to increase its financial capacity, including additional joint arrangements, commercial arrangements, or other financing alternatives. NZEC requires additional working capital or a funding partner to commence drilling new exploration opportunities.

11. Tikorangi Limestone
Drill proven formation
•
23.6 million bbl of historical production from Tikorangi on TWN Licenses
•
A number of TWN Tikorangi wells produced at IP rates in excess of 3,000 bbl/d
Drill new wells to access oil reserves 1
•
Remaining 2P reserves estimated at 1,852,700 bbl oil, 1.45 Bcf gas, 50,700 bbl NGL (100% basis) 2
•
410,300 bbl (100% basis) 2P Undeveloped Reserves attributed to crestal well 2
-
Potential crestal well location
•
Fractured limestone reservoir oil recoveries can be as high as 65% of OOIP (OIIP range estimated at 25 to 100 million bbl)
•
NZEC study indicates higher productivity within 250 metre fault buffer zone
•
Two potential locations for second well 11
1. Development and operating costs are to be funded initially by existing working capital and cash flows from production. NZEC requires additional working capital or a funding partner to commence drilling new exploration opportunities. 2. Reserve estimate completed by Deloitte LLP with an effective date of April 30, 2013. Reserves restricted to the Tikorangi Formation on the Waihapa and Ngaere Permits, attributable to NZEC at 50%. See Cautionary Note Regarding Reserve & Resource Estimates.

12. Kapuni Group
Drill-proven formation
•
Kapuni Gas Field onshore oil/gas discovery (Shell) producing since 1969
-
Estimated ultimate recovery of 1,365 billion cf (Bcf) natural gas and 66 million bbl oil
•
TWN Licences tested by four wells  all encountered gas in the Kapuni Group
•
Two potential Kapuni well locations identified 1 2013 Deloitte Resource Estimate 2
•
Contingent resource: 5.0 Bcf gas, 233,000 bbl NGL (100% basis)
•
Prospective resource: 95.8 Bcf gas, 4.5 million bbl NGL (100% basis)
•
Discovered PIIP: 13.8 Bcf gas (100% basis)
•
Undiscovered PIIP: 261.1 Bcf gas (100% basis) 12
1. Kapuni exploration contingent on finding a funding partner. 2. Shown on a 100% basis, attributable to NZEC at 50%. See TWN Resource Estimate and Cautionary Notes.

13. 13
Drilling Inventory

14. Proprietary Merged 3D Seismic Database 14
Reprocessed datasets
•
Combined five 3D surveys
•
Total area covered (full fold) 552 km2
•
Pre-stack merge and post-stack time migration complete, pre-stack time migration underway
•
Greater geological understanding of basin reduces drilling risk by providing consistent interpretation of seismic anomalies and the correlation with production success and pool size
Volume
Vintage
Area (km2)
Kapuni
1989
305
Waihapa
1989
43
Eltham
2002
20
Brecon
2006
74
Rotokare
2012
110
ELTHAM
ALTON
WAIHAPA
NGAERE
TARIKI

15. Individual 3D Surveys = Mismatched Data 15
Kapuni 3D
Rotokare 3D
1989
2012

16. Proprietary Merged 3D Datasets Increase Chance of Success 16
Kapuni 3D
Rotokare 3D
Reprocessed and merged 2013

17. Inventory of Taranaki Drilling Leads NZEC’s Copper Moki area converted to long-term mining license 17
Waitapu
Copper Moki
Arakamu
Wairere
Horoi site

18. 18
East Coast Basin Oil Shales
Advancing unconventional oil shales
•
Over 300 oil and gas seeps sourced back to two oil shale formations
•
NZEC has drilled three wells to take core samples from the Waipawa Black Shale 1
-
Late Paleocene
-
10-50 metres thick
-
TOC typically 2-6%, up to 12%
-
S2 typically 5-20 kg HC/t rock
-
Kerogen Type II + III
-
Shale porosity 5-10%
-
Quartz 46-56%
-
Clay 28-38%
-
Carbonate 0-4% NZEC’s East Cape Permit
•
1,048,406 acres
•
Exploration period granted to Dec 2018
•
Estimated prospective resources 2
-
Conventional: 53.3 million bbl oil
-
Unconventional: 302.1 million bbl oil
1. Technical data for Waipawa Black Shale gleaned from both NZEC’s work and other technical work in the region. 2. Resource estimate completed by Deloitte LLP with an effective date of February 1, 2011. Best estimate assuming 9% recovery for conventional resources and 2% recovery for unconventional resources. See Taranaki and East Coast Resource Estimates and Cautionary Note Regarding Reserve & Resource Estimates.

19. Common shares outstanding at August 2014
Options outstanding at August 2014 (Exercisable at average $0.55)
Warrants issued in Oct 2013 Private Placement (Exercisable at $0.45 until Oct 2014)
Finder’s warrants issued in Private Placement (Exercisable at $0.33 until Oct 2014)
Fully diluted shares outstanding
170,873,459
11,938,200
24,452,173
3,045,849
210,309,681
Insider ownership (fully diluted)
52 Week High / Low
Average Volume (Q2-2014)
~25%
$0.46 / $0.09
~400,000 shares/day
Current market cap (August 29, 2014)
2P Reserves 1,649,000 boe
~$17 million
NPV $57.9 million 1
Financial Highlights 2
Oil produced during six-month period ended June 30, 2014
Pre-tax revenue during six-month period ended June 30, 2014
Cumulative third-party revenue earned from Waihapa Production Station (Aug 29, 2014)
Anticipate revenue commencing September 2014 from gas transportation agreement
Average realized oil price for six-month period ended June 30, 2014
Field netback for six-month period ended June 30, 2014 3
Estimated working capital (August 29, 2014) (excluding materials and supplies of ~NZ$1.9 M)
38,748 bbl
$9.4 million
$1,383,528
TBD
$118.65 / bbl
$63.92 / bbl
$2.3 million
Corporate Profile 19
1. After tax, 10% discount. 2. As per NZEC’s Q2-2014 interim financial statements, filed on August 29, 2014. NZEC’s Q3-2014 financial statements will be released in the last week of November 2014. 3. NZEC’s wells are producing light (~40 API), high-quality oil that sells at Brent pricing. NZEC calculates its netback as the oil sale price less fixed and variable operating costs and a royalty.

20. Investment Highlights
•
Highly prospective property portfolio
-
1.15 million total acres on New Zealand’s north island with both conventional and unconventional opportunities
-
97,630 acres and a full-cycle production facility in the main Taranaki Basin production fairway
-
1,649,000 boe of 2P reserves with an NPV (10% discount) of $57.9 million 1
•
Focused in New Zealand, a politically and fiscally stable jurisdiction with a supportive government, excellent tax and royalty regime, and Brent oil pricing
•
Experienced New Zealand team with exploration and operations expertise
•
Focused on increasing production and cash flow 2
-
Optimizing production from existing wells
-
Opportunities to advance additional existing wells to production  low-cost workovers, rapid tie-in using existing infrastructure
•
Actively engaging in opportunities to increase financial capacity
•
Actively seeking farm-in and joint venture partners to fund new drilling
-
Significant exploration opportunities across multiple prospective formations
-
580,000 boe of contingent resources 3
-
195,906,000 boe of prospective conventional resources 3
-
456,200,000 boe of prospective unconventional resources 3 20
1. NZEC’s share of reserves. See detailed Reserve tables and Cautionary Notes. 2. Development and operating costs are to be funded initially by existing working capital and cash flows from production. To carry out all of the planned development activities, the Company is considering a number of options to increase its financial capacity, including additional joint arrangements, commercial arrangements, or other financing alternatives. 3. Resources estimated by Deloitte LLP. Best estimate. The term barrels of oil equivalent (“boe”) may be misleading. A boe conversion ratio of six Mcf: one bbl was used by NZEC. See Resource tables and Cautionary Notes.

21. Appendix
21

22. NZEC Reserve Estimate (net to NZEC) 1 22
1. Reserves on NZEC’s Copper Moki Permit are restricted to the Mt. Messenger Formation. NZEC’s on the TWN Licenses are restricted to the Tikorangi Formation in the Waihapa and Ngaere permits. See NZEC’s Form 51-101 Statement of Reserves Data dated April 2, 2014, filed on SEDAR at www.sedar.com.
Proved Developed Producing 517,000 935,000 40,000 713,000 $18,452,900 Proved Developed Non-producing 181,000 554,000 27,000 301,000 $19,574,600 Proved Undeveloped 111,000 88,000 3,000 129,000 $3,806,300 Total Proved 809,000 1,576,000 71,000 1,143,000 $41,833,800 Probable 359,000 683,000 34,000 506,000 $16,072,000 Proved + Probable 1,168,000 2,260,000 104,000 1,649,000 $57,905,800 Notes: 1. Reserve estimates calculated by Deloitte LLP with an effective date of December 31, 2013. 2. bbl – barrels. Mcf – thousand cubic feet of natural gas. boe – barrels of oil equivalent3. Reserves net to NZEC after deduction of royalty obligations to the New Zealand government and Origin Energy Resources NZ (TAWN) Limited. 4. See Cautionary Note Regarding Reserve and Resource Estimates. 3. Barrels of oil equivalent (boe) may be misleading, particularly if used in isolation. The boe conversion ratio of 6 Mcf : 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Marketable Oil and Gas ReservesAs at December 31, 2013Forecast Prices and CostsReserves CategoryLight & Medium Oil (bbl) Natural Gas (Mcf) Natural Gas Liquids (bbl) Barrels Oil Equivalent (boe) NPV, After Tax (10% Discount)

23. TWN Resource Estimate (NZEC’s 50% Interest) 1
Formation
Product Type
Low
Best
High
Contingent Resources
Miocene Sands (Mt. Messenger)
Oil (Mbbl)
17
44
101
Eocene Sands (Kapuni Group)
Gas (MMcf – sales)
1,257
2,518
5,168
NGL (Mbbl)
51
117
263
Total
BOE (Mboe)
277
580
1,225
Prospective Resources
Miocene Sands (Urenui, Mt. Messenger, Moki)
Oil (Mbbl)
803
1,471
2,866
Eocene Sands (Kapuni Group)
Gas (MMcf – sales)
21,417
47,919
113,212
NGL (Mbbl)
955
2,249
5,688
Total
BOE (Mboe)
5,327
11,706
27,422
Discovered PIIP
Miocene Sands (Mt. Messenger)
Oil (Mbbl)
164
341
700
Eocene Sands (Kapuni Group)
Gas (MMcf – raw)
3,606
6,885
13,468
Total
BOE (Mboe)
764
1,488
2,945
Undiscovered PIIP
Miocene Sands (Urenui, Mt. Messenger, Moki)
Oil (Mbbl)
5,658
10,221
18,902
Eocene Sands (Kapuni Group)
Gas (MMcf – raw)
59,491
130,540
302,930
Total
BOE (Mboe)
15,573
31,978
69,390
1. NZEC’s 50% share of TWN Resources as estimated by Deloitte with an effective date of April 30, 2013 assuming 9 to 14% recovery for oil resources and 50% for gas resources. See Cautionary Note Regarding Reserve and Resource Estimates. 23

24. Taranaki and East Coast Resource Estimates 24
Low Best High Low Best High TARANAKI BASINEltham (PEP 51150) and188.0 46,444.2 Copper Moki (PMP 55491)3.8 943.7 100% NZECConventional 1231.4 346.8 578.8 19.7 31.6 56.9 Alton (PEP 51151)156.7 38,717.4 65% NZEC / 35% L&MConventional 1224.8 493.7 1,229.7 18.9 45.0 116.9 EAST COAST BASINEast Cape (PEP 52976)4,320.0 1,048,406.3 100% NZEC Conventional 1189.8 615.7 1,997.4 14.6 53.3 195.4 Unconventional 25,747.2 13,148.1 31,838.3 110.3 302.1 906.3 Total4,668.5 1,134,511.6 6,393.2 14,604.3 35,644.2 163.5 432.0 1,275.5 Conventional 1646.0 1,456.2 3,805.9 53.2 129.9 369.2 Unconventional 25,747.2 13,148.1 31,838.3 110.3 302.1 906.3 Resources estimated by Deloitte LLP. Eltham and Copper Moki resources effective date December 31, 2011. Other resources effective date February 1, 2011.1 Assumes 9% recovery. 2 Assumes 2% recovery. Net Permit Area Net Permit Acreage Net Unrisked Undiscovered Petroleum Net Unrisked Prospective Recoverable (MM barrels of oil) (MM barrels of oil)

25. Historical Production – Tikorangi Formation
1. Select production data using publicly available information regarding wells that produced oil on the TWN Licences.
Well name 1
Max bbl/d
Total bbl produced
Ngaere-1
7,537
4,337,084
Ngaere-2
3,658
1,002,565
Ngaere-3
8,652
1,089,505
Toko-2B
298
126,286
Waihapa H-1
1,953
45,349
Waihapa-1B
4,804
4,909,317
Waihapa-2
3,182
4,798,752
Waihapa-4
2,674
2,990,189
Waihapa-5
979
91,055
Waihapa-6A
4,674
4,262,707
23.6 million bbl of historical production 1 25

26. Board of Directors 26
Name
Expertise
Experience
John 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 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, Director & CEO, Southern Arc Minerals Inc.
•
Chairman, Director & Interim CEO, Eagle Hill Exploration Corp.
•
Chairman, Canada Energy Partners Inc.
Hamish 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
David Robinson, B.A, G.C.M
Director
•
Significant business and management experience in New Zealand’s oil and gas industry
•
CEO, Petroleum Exploration & Production Assoc. of New Zealand
•
Commercial General Manager, Z Energy
•
Director, other downstream commercial positions, Shell

27. NZEC – Corporate Team
27
Name
Expertise
Experience
John 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, Director & CEO, Southern Arc Minerals Inc.
•
Chairman, Director & Interim CEO, Eagle Hill Exploration Corp.
•
Chairman, Canada Energy Partners Inc.
David Robinson, B.A, G.C.M
CEO New Zealand Business
•
Significant business and management experience in New Zealand’s oil and gas industry
•
CEO, Petroleum Exploration & Production Assoc. of New Zealand
•
Commercial General Manager, Z Energy
•
Director, other downstream commercial positions, Shell
Derek Gardiner, CA
Chief Financial Officer
•
Chartered Accountant and Chartered Corporate Secretary with more than 25 years of experience in the New Zealand oil gas industry
•
Commercial and Finance Manager, Origin Energy
•
Chief Financial Officer, Austral Pacific Energy
•
Numerous senior positions, Shell
Gerrie van der Westhuizen, CA
Vice President Finance
•
Chartered Accountant with expertise in financial reporting and controls, equity offerings, treasury management and debt structures, tax compliance
•
Progressively senior positions with publicly-traded natural resource companies
•
Audit Manager, Mining Group, PricewaterhouseCoopers
Newton Cockerill, B.Com
Controller
•
Accountant with 18 years of finance experience, including 6 years in the oil and gas industry
•
Expertise in budgeting, forecasting, strategic planning, financial reporting, consolidation and control
•
Progressively senior positions within private sector
•
Recent roles include 5 years with Origin Energy as Business Performance and Accounting Manager, and 5 years with Orange Plc in the UK as Senior Consolidation Analyst
Rhylin Bailie, B.ES
VP Communications & Investor Relations
•
More than 18 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.
Jonathan Bahnuik, LL.B, MBA
General Counsel
•
More than 10 years of experience providing legal advice to junior oil and gas companies, including upstream, midstream and transactional matters
•
General Counsel to several TSX-V listed companies
•
Partner at a Calgary based boutique corporate commercial law firm
Eileen Au, B.Sc
Corporate Secretary
•
More than 16 years of experience overseeing corporate governance and corporate affairs for publicly-listed resource companies
•
Corporate Secretary for various public and private resource companies

28. NZEC – Operations & Technical Team 28
Name
Expertise
Experience
Mike Oakes
General Manager
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
Stewart Angelo
Engineering & Maintenance Manager
•
25 years in oil and gas midstream assets focused around development and implementation of procedures and processes for asset management systems
•
Engineering Officer with New Zealand Merchant Navy
•
Maintenance Engineer, Fletcher Challenge
•
Director of Productive Maintenance
Dan MacDonald, B.Sc
Drilling Manager
•
Mechanical engineer with 30 years of experience
•
Drilling and completion work, design, approval and implementation of drilling programs
Toka Walden
Land Manager
•
Senior Manager, New Zealand Dept. of Conservation
•
Negotiating access provisions and facilitating resource consent process, assisting with community relationship building
Peter Kingsnorth
Plant Superintendent
•
Mechanic with over 25 years of experience in oil and gas plant commissioning and start up, staffing and operation of oil and gas fields and production facilities
•
Mechanical Supervisor, Fitzroy Engineering
•
Project Operations Lead , Ahuroa Gas Storage Facility
•
Operations Team Leader, Origin Energy
Pono Cooper
Field Superintendent
•
Extensive experience with wireline and well head surface facilities. Supervising installation of well testing facilities. Over 24 years of oil and gas experience. Experienced in waxy oil fields and pumping wells.
•
Field and Plant Operations, Shell Todd Oil Services
•
Field Supervisor, Swift Energy
•
Field and Operations Superintendent, Origin Energy
Dr. Richard Kellett, B.Sc (Hons), PhD, PGeoph
•
Geoscientist with worldwide exploration and business development experience
•
Seismic interpretation, geophysical survey design and prospect evaluation
Dr. Simon Ward, B.Sc (Hons), PhD
•
Petroleum geology related to the Taranaki and other New Zealand basins
•
Drilling risk assessment and well design
•
Production analysis and reporting, and regulatory compliance

29. Analyst Coverage 29
Company
Analyst
Contact
Credit Suisse
David Phung
403-476-6023
Dundee Capital Markets
David Dudlyke
44-203-440-6870
Mackie Research
Bill Newman
403-750-1297
M Partners
David Buma
416-603-7381
Prosdocimi
Brian O’Connell
44-207-199-3000

30. Contact NZEC 30
Corporate Head Office
John Proust, Chief Executive Officer
Rhylin Bailie, VP Investor Relations
North America Toll-free: 1-855-630-8997
Phone: + 1-604-630-8997
New Zealand Operations Office
David Robinson, CEO New Zealand Business
Phone: + 646-757-4470
info@NewZealandEnergy.com
www.NewZealandEnergy.com