NZEC is an oil and natural gas company engaged in the production, development and exploration of petroleum and natural gas assets in New Zealand. NZEC’s property portfolio collectively covers approximately 1.15 million acres of conventional and unconventional prospects in the Taranaki Basin and East Coast Basin of New Zealand’s North Island. NZEC plans to execute a technically disciplined exploration and development program focused on the onshore oil and natural gas resources in the politically and fiscally stable country of New Zealand. The Company’s management team has extensive oil and gas exploration and operations experience in New Zealand. NZEC is listed on the TSX Venture Exchange under the symbol NZ and on the OTCQX International under the symbol NZERF. More information is available at www.newzealandenergy.com or by emailing info@newzealandenergy.com.

1. TSX-V: NZ
OTCQX: NZERF
Waihapa Production Station
Corporate Presentation
November 5, 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 (Oct 2014: 214 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 September 30, 2014
6
Average Daily Oil Production During 2014 net to NZEC (bbl/d)
Jan Feb Mar Apr May Jun Jul Aug Sep
202 228 233 228 201 231 202 205 205
NZEC’s Production & Development Wells – Status at September 30, 2014

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
WaitapuCopper 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 2015)
Finder’s warrants issued in Private Placement (Exercisable at $0.33 until Oct 2015)
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 (Q3-2014)
~25%
$0.46 / $0.09
~210,000 shares/day
Current market cap (November 5, 2014)
2P Reserves 1,649,000 boe
~$11 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)
Working Capital Facility with New Dawn Energy for up to NZ$5 million 4
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. 4. NZEC has executed a working capital facility agreement with New
Dawn Energy Limited for up to NZ$5 million, to be used for NZEC’s share of expenditures and equipment required to advance the TWN Assets, and for
other working capital purposes as agreed to by New Dawn Energy. See September 24, 2014 press release.

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  NZ$5 million
working capital facility with New Dawn Energy executed in Sept 2014
• 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 equivalent
3. 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 Reserves
As at December 31, 2013
Forecast Prices and Costs
Reserves Category
Light & 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 BASIN
Eltham (PEP 51150) and 188.0 46,444.2
Copper Moki (PMP 55491) 3.8 943.7
100% NZEC
Conventional 1
231.4 346.8 578.8 19.7 31.6 56.9
Alton (PEP 51151) 156.7 38,717.4
65% NZEC / 35% L&M
Conventional 1
224.8 493.7 1,229.7 18.9 45.0 116.9
EAST COAST BASIN
East Cape (PEP 52976) 4,320.0 1,048,406.3
100% NZEC
Conventional 1
189.8 615.7 1,997.4 14.6 53.3 195.4
Unconventional 2
5,747.2 13,148.1 31,838.3 110.3 302.1 906.3
Total 4,668.5 1,134,511.6 6,393.2 14,604.3 35,644.2 163.5 432.0 1,275.5
Conventional 1
646.0 1,456.2 3,805.9 53.2 129.9 369.2
Unconventional 2
5,747.2 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 Jessica Lindskog 44-203-440-6872
Mackie Research Bill Newman 403-750-1297
M Partners David Buma 416-603-7381
Prosdocimi Dorian Prosdocimi 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