December 2014

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The Disclaimer & Forward-Looking Statements

This presentation, and any supplemental information (written or oral) or other documents provided in connection therewith (collectively, the “materials”), are provided solely for the information of those being presented to and may not be distributed, published, reproduced or otherwise disseminated without the express written consent of the Company. This presentation is incomplete without reference to, and should be considered in conjunction with, any supplemental information provided by and discussions with the Company in connection therewith. Any defined terms used herein shall have the meanings set forth herein, even if such defined terms have been given different meanings elsewhere.

These materials are for discussion purposes only and may not be relied upon by any person or entity for any purpose except as expressly permitted by the Company. The materials were prepared specifically for this presentation and were not prepared with a view to public disclosure or to conform with any disclosure standards under any state, federal or international securities laws or other laws, rules or regulations and the Company takes no responsibility for any further use of these materials.

The materials are based on the financial, economic and market conditions as in effect when the materials were prepared. Although subsequent developments may affect the contents of the materials, the Company has not undertaken, and is under no obligation, to update, revise or reaffirm the materials. The materials do not constitute an opinion of the Company or any representative of the Company on whether to buy or sell securities or assets of any company. The materials do not constitute an offer to sell or a solicitation of any offer to buy any securities. Offers are made only by prospectus or other offering materials.

2

UK Head Office: 3000 Cathedral Hill | Guildford | Surrey GU2 7YB | Main number: +44 (0) 20 3582 1350 Richard Swindells, Chief Financial Officer & Company Secretary US Office: 1805 Shea Center Drive, Suite 290 | Highlands Ranch, CO 80129 | Main number: +1 303 407 9600 Richard McCullough, Chairman and Chief Executive Officer Website: www.nighthawkenergy.com

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Appendix Slides

Needs Work The Company

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The Overview

Public company, U.S. operator in Colorado’s prolific Denver-Julesburg Basin

100% WI in more than 200,000 net acres, or about 10% of play

Multi-zone opportunities; inventory of more than 81 drill ready locations and 16 uphole recompletions

Substantial leverage to success of South Eastern DJ Basin

Cash Flow Upside: First-mover advantage in focused area of operations

Proven geologic exploration concept

Company now moving into production phase focusing on increasing EBITDA

NPV Growth: Proved Reserves of 3.0-3.5 MMBOE*

Company trades as HAWK on UK AIM and NHEGF on US OTCQX

Enterprise value: US$161.2 million** on 5 Dec ‘14

Shares Issued: 961.4 million; average daily volume: 3.0 million shares

H1 2014 interim results: Record production, profitability and cash flow

4

* Company risked estimate prepared to SPE standard **Using 1.57:1 US$/GBP conversion

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Appendix Slides

Needs Work The People

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6

Rick McCullough, Chairman Rick was appointed Chairman of Nighthawk on October 1, 2014 and has over 30 years’ experience in the US energy and oil and gas industries. He served with NASDAQ-listed PDC Energy Inc. as Chief Financial Officer from 2006 to 2008 and as Chief Executive and then Chairman from 2008 until 2011, where he led a strategic turnaround resulting in an almost four-fold increase in share price. In 2011, he was named as CEO of the year for US mid-cap companies by Investor Relations Magazine. Prior to joining PDC Energy, Rick served as President and CEO at Gasource, LLC and as an investment banker at JP Morgan.

Chuck Wilson, Chief Operating Officer, US Operations Chuck joined Nighthawk in August 2011 from Gasco Energy Inc. where he was VP of Engineering and Operations. Previously he was the U.S. Onshore Drilling Manager for Denver-based Forest Oil Company, a NYSE-listed exploration and production company. Chuck has more than 33 years of experience in the oil and gas industry ranging from drilling, completion and production operations to surface equipment installations, including horizontal drilling in the Bakken. He holds a BS degree in Petroleum Engineering from the University of Wyoming and in addition has held several positions within the Society of Petroleum Engineers and the American Association of Drilling Engineers.

Michael Thomsen, President, US Operations Mike has more than 30 years’ experience in the natural resources industry and has worked in more than 40 countries on acquisitions, project development and exploration. He has directed and managed a number of energy and minerals companies and was the former Chairman of Oil Quest Resources plc. Mike was previously Chief Geologist with Freeport-McMoRan Inc, a major US energy and minerals producer, where he directed programs in the Permian Basin of west Texas, the Gulf of Mexico region, the Sergipe Basin of Brazil and the Suez-Sinai region of Egypt. He was also Director of International Exploration with Newmont Mining Corporation.

Richard Swindells, Chief Financial Officer and Company Secretary Richard joined Nighthawk in June 2011 having previously spent 15 years as an investment banker, the past five of which he has spent advising and raising equity for resources companies. Richard joined from Ambrian Partners where he was Head of Oil & Gas Corporate Finance having previously been CEO of Nabarro Wells & Co and director of Corporate Finance at Panmure Gordon. Richard has an economics degree from University of Birmingham and holds the Chartered Institute for Securities and Investment diploma.

Nighthawk’s Management Team

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Nighthawk’s Management Team

7

Harold Mayland, Operations Manager Harold started his career in 1960 as a tool pusher working on production rigs. He spent 4 years with Shell Oil as Production Field Foreman. This was followed by one year with Flying Diamond as Production Superintendent. He spent three years with Baker Oil tools providing services to oil and gas companies. He later started Mountain States Oil Tools, at that time he designed and patented test and production equipment for subsurface use, which he sold out 6 years later. It is now known as Weatherford Completions service. Mr. Mayland started Osprey Oil & Gas Company, where he bought several old fields and entered into joint ventures with other companies to drill and complete producing wells. Since 1982, he has been involved in providing consulting services for well site drilling, completions, workover operations, production, and oilfield construction.

Anders Elgerd, Exploration Manager Anders has more than 32 years of experience in petroleum exploration and development in the disciplines of Geology and Geophysics. He has worked most of the major producing basins in the US as well as internationally. Since February 2012 he has headed up the exploration efforts at Nighthawk in Eastern Colorado. He graduated with high honors from the University of Florida in 1980 with a Bachelor of Science Degree in Geology. He is a member of the American Association of Petroleum Geologists, the Denver Geophysical Society, the Rocky Mountain Association of Geologists and the Denver International Petroleum Society.

David Faulder, Reservoir Engineering Manager David joined Nighthawk in August 2014 and has over 33 years’ experience as a reservoir engineer in a wide variety of geologic environments. He started his career with Chevron and was reservoir engineer for Rangely, Colorado for three years, the largest oil field in the Rocky mountains. He later worked with the Idaho National Laboratory (a USDOE facility) as Advisory Scientist, for the National Petroleum Technology Office as an analyst and for SAIC evaluating Alaska’s oil and gas production potential as project reservoir engineer and economist. Later assignments include Bill Barrett Corporation as exploration engineering advisor, and Terra-Gen Power as reservoir engineering manager. David has petroleum engineering degrees from the University of Wyoming (BS), and MS and PhD degrees from Colorado School of Mines were he is also an Adjunct Professor teaching classes in well testing, reservoir simulation, economics, and geothermal reservoir engineering. He has been a consultant since 1992 and has Professional Engineering licenses from California and Colorado.

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Appendix Slides

Needs Work The Strength of the Story

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The Business Strategy of Nighthawk Energy

Large operated land position with attractive geologic and hydrocarbon production characteristics

Use best in class drilling and completion technologies to produce wells at optimum rates

Use geologic 3D model to increase drill bit success rate and shorten “proof of concept” time period

Invest wisely to grow production and reserve base

Optimize shareholder returns by increasing EBITDA , maintaining low-cost structure, utilizing hedging programs, and actively managing the balance sheet

9

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Appendix Slides

Needs Work The Assets

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World-Class Operators: Eastern Colorado’s D-J Basin

Core Stacked Formation Play Approx. 3 million gross acres Major players by Acreage* Pioneer 20% Cascade 15% Nighthawk 10% Anadarko 10% Devon 10% Southwestern 10% Pine Ridge 5% NexGen 5% Wiepking 5%

*Company’s internal estimates 11

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Why Nighthawk is Focused on D-J Basin

Attractive entry point for assimilating large acreage position

Average cost of less than US$60/acre; High NRI of 80-85%

All rights to all depths provides large resource potential

High-quality assets

Multiple stacked pay targets with vertical and horizontal potential

Low decline rates and low water production

Low development cost behind pipe recompletion opportunities

Excellent production infrastructure and permitting processes

Attractive cost structure: vertical wells cost US$2MM D&C

Rapid per-well payback: typically 6-12 months

Most projects have IRR >100%

25% breakeven IRR at less than US$40/barrel (WTI Index)

High margin: normalized EBITDA of US$51/BOE gross H1’14

100% crude oil stream; Crude oil sells at (9%) differential to WTI 12

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The Company’s Competitive Comparisons

13

Nighthawk Energy Per-Well EUR D&C (US$ million) IRR Payback Period

DJ Basin 250 MBOE $2.0 55% - 200+% 6-12 Months

Company A Per-Well EUR D&C (US$ million) IRR Payback Period

Niobrara 384 MBOE $4.2 70% @ $90 WTI & $4.00 Nat Gas 1.42 Years

Codell 370 MBOE $4.2 70% @ $90 WTI & $4.00 Nat Gas 1.42 Years

Company B Per-Well EUR D&C (US$ million) IRR Payback Period

Niobrara Formation 203 MBOE $3.6 31% @ $85 WTI 2.7 years

Company C Per-Well EUR D&C (US$ million) IRR Payback Period

Wattenberg Field 313 MBOE $4.2 65% 1.5 Years

Company D 30-day IP (BOEPD per well) D&C (US$ million) IRR Payback Period

Codell and Niobrara 450-566 $4.0 Not disclosed by Company 68% after 5 months

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Impact of Low Oil Prices

Source: Credit Suisse. Note: Assumed natural gas price of $3.60/Mcf.

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28

33

36

39

43

50

52

54

54

54

56

58

58

62

63

65

66

68

69

71

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72

76

76

77

77

79

83

83

85

0

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30

40

50

60

70

80

90

$100

Nighthawk Well

Breakeven Analysis

14

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Nighthawk Energy’s Capital Program Strategy

15

- Low-Cost, High-Margin Projects - Low-risk, rapid completions

- Low-Cost, High-Margin Projects - Low-risk, rapid completions

- Mississippian Wells - Pennsylvanian Wells - Low declines - Triple digit returns

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Geologic Concepts

16 MULTIPLE STACKED PAY

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Arikaree Creek Field Development

Steamboat 8-10First prod 11-28-2013IP30 227 stb/dCum 188.7 MstbEUR 294.7 Mstb

Big Sky 4-11First prod 5-24-2013IP30 374 stb/dCum 144.1 MstbEUR 213.1 MstbTaos 1-10

First prod 6-16-2013IP30 527 stb/dCum 229.5 MstbEUR 846.5 Mstb

Silverton 16-10First prod 7-9-2013IP30 144 stb/dCum 41.2 MstbEUR 73.2 Mstb

Snowbird 9-15First prod 7-17-2013IP30 132 stb/dCum 49.7 MstbEUR 133.7 Mstb

Big Sky 12-11First prod 11-15-2013IP30 249 stb/dCum 46.8 MstbEUR 134.8 Mstb

Big Sky 5-11First prod 3-2-2014IP30 277 stb/dCum 36.7 MstbEUR 115.7 Mstb

Big Sky 13-11First prod 2-13-2014IP30 116 stb/dCum 25.0 MstbEUR 173.0 Mstb

Big Sky 14-11First prod 5-19-2014IP30 56 stb/dCum 6.0 MstbEUR 32.0 Mstb

Blackcomb 5-14First prod 10-5-2014IP30 371 stb/dCum 0 MstbEUR 85.0 Mstb

Blackcomb 12-14First prod 9-1-2014IP30 148 stb/dCum 4.4 MstbEUR 15.4 Mstb

Snowbird 16-15First prod 11-8-2014IP6 468 stb/dCum 0 MstbEUR 170.0 Mstb Blackcomb 3-14

IP30 250 stb/d Cum 0 Mstb EUR 200.0 Mstb 17 * Pennsylvanian recompletions in progress.

*

*

*

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1.8 1.4 1.6 1.4 1.6

1.9 2.0

2.6

1.5

1.9 2.1

2.4

1.5

2.6

1.7

2.6

1.9

3.3

2.7

2.1 1.9

1.2

2.6

1.7

0.9

1.6 1.5 1.5 1.5 1.5 1.5 1.6 1.5 1.4 1.7 1.5 1.7 1.5 1.5

1.0

1.4 1.7

2.6

1.8 1.8 1.8 2.0

1.8 2.0

1.0

0.0

1.0

2.0

3.0

$4.0

$ MM Actual Budget Actual Average Budget Average

Successful 87%

Successful 50%

Unsuccessful 50%

ARIKAREE CREEK DEVELOPMENT (1) EXPLORATION

Successful/Total Wells 5/10 13/15

$1.6

$2.0

Past Drilling Success ($ in millions unless otherwise noted)

18 (1) Whistler 6-22 and Telluride 13-2 wells are waiting on an uphole recompletion.

AFE vs. Actual Cost

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Arikaree Creek field discovered in November 2012 with Steamboat Hansen 8-10 discovery well

13 producers, 2 shut-in wells

Current production of ~1,800 BOEPD gross (as of October 2014)

Net operating cash flow to date of ~$50 million

Capex spent to date of ~$26 million

Estimated PV-10 of future cash flows is ~$84 million

Analysis based on PDP only with no further drilling assumed

Implies potential return of ~5x on invested capital

19 Note: Estimates based on Nighthawk analysis assuming flat oil price of $70/bbl.

Arikaree Creek Historical Field Analysis ($ in millions unless otherwise noted)

Overview Production

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2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025

Net Operating Cash Flow Free Cash Flow

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1,500

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2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025

BOEPD Actual Illustrative profile

Actual Illustrative profile

Free Cash Flow

13 producers; no additional wells or recompletions

13 producers; no additional wells or recompletions

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20

Current Thinking Arikaree Creek

Penn Prospective Outline (54 potential locations)

Area of Pennsylvanian drape

Existing Wells 12 Miss, 2 Penn Awaiting recompletion Loc (Miss and Penn) Loc (Penn only) Salt water disposal

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21

Is Snow King another Arikaree Creek?

Existing Well (Snowking 13-33) Dry hole with oil shows Currently drilling (Keystone 3-7)

Penn Prospective Outline (68 potential locations)

Area of Pennsylvanian drape

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Ryder Scott Case

Ryder Scott Management Case

Category MBOE

PDP 1,197

Proved Shut-In 85

TOTAL PROVED 1,282

Probable Producing 553

Probable Undeveloped 578

TOTAL PROBABLE 1,131

Possible Producing 172

Possible Undeveloped 1,088

TOTAL POSSIBLE 1,260

TOTAL RESERVES 3,673

Ryder Scott Reserves vs. Potential

Oil 100%

Proved 30%

Probable 13%

Possible 57%

Ryder Scott Reserves (net) (1) Potential

Nighthawk estimates 11 MMBOE of net 3P Reserves(2) on the currently de-risked acreage (~8,000 acres)

Recent recompletion success in the Pennsylvanian age formation in the Arikaree Creek field should over time add significantly to the 3P reserve categories

2 more successful Mississippian wells in the Arikaree field further de-risked the structure

More credit for proved producing based on stable production rates in the existing producers

22

Product Breakdown

(1) Ryder Scott report on Nighthawk reserves as of Oct 1, ‘14. Assumed oil price of $82.42/bbl held constant for the life of each property (2) Company estimate prepared to SPE standards and further risked for conservatism. 11 MMBOE 3P Reserves includes 3.0-3.5 MMBOE Proved Reserves estimated by Company

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Appendix Slides

Needs Work The Next Steps

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Meeting and Exceeding Strategic Targets

Proof of Concept

Established

• Establish sustainable and material levels of production

• Build out geologic base model to support sustainable, repeatable & high IRR drilling programs

• Initial exploration drill success ~50%

• Initial 2013 target of 1,000 BOEPD exceeded June 2013

Development Mode to

Increase EBITDA and Value

• Timeline: 2014

• YE’14 exit rate target > 2,600+ BOEPD gross ; Continued development of conventional Miss- and Penn- aged targets.

• Arikaree Creek success rate >80%

• First Horizontal Well Permit filed: Additional behind pipe reserves at Arikaree Creek to be developed through horizontal drilling

Transition to Balanced

Development Potential/

NAV Expansion

• Timeline: 2015+

• Plans to increase production materially by end of 2015

• Expand resource potential through organic drilling program with material production from multiple horizons and widely dispersed wells

• Provide shareholders with considerable potential valuation expansion; current operating strategy supports both

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(25) (22) (27) (30) (30) (24) (16)

37 37 43

47 51

56 58 46

36 30

12 15 17 18 22

32 42

46

36 30

(30)

(10)

10

30

50

$70

2015 2016 2017 2018 2019 2020 2021 2022 2023 2024

Capital Net Operating Cash Flow Free Cash Flow

Illustration of $25MM Incremental Investment ($ in millions unless otherwise noted)

25

Key Drill-out model assumptions:

Effective date of January 1, 2015

Assumes $70/Bbl & $3.50/Mcf flat

Assumed $25 million capital budget for 2015

Future years drilling within the cash flow

Assumes risk factor of 0.7

Risked PV-10 of $202 MM

Implied potential return of ~8.1x on invested capital

Illustrative Incremental Free Cash Flow

Illustrative Average Incremental Production by Year Overview

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Net Boe/d

(1) Illustrations based on Company’s risked estimates of drilling and recompletion inventory

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The Reasons to Invest in HAWK’s Growth

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Developmental drilling with continuing exploration at high IRRs First-mover advantage: high-quality assets supports top-tier project metrics Experienced management team with large-scale development c.v.’s Increasing forward inventory of drilling opportunities

Mix of developmental and exploration Behind pipe Marmaton and Cherokee (Arikaree Creek and Salen) Vertical Spergen wells on structure (Arikaree Creek and Snow King) Vertical Marmaton and Cherokee (Arikaree Creek, Salen, Snow King) HZ on structure (Arikaree Creek, Snow King) Vertical or HZ off structure

Strong financial position supports building EBITDA, production & reserves

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Jan

-12

Mar

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May

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Jul-

12

Sep

-12

No

v-1

2

Jan

-13

Mar

-13

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-13

Jul-

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-13

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3

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-14

Mar

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-14

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-14

No

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Jan

-15

Mar

-15

May

-15

Jul-

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-15

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Proved Developed Producing Growth Potential

Growth Potential

Pp Net BOEPD

(1) Illustrations based on Company’s risked estimates of PDP and drilling and recompletion inventory

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Appendix Slides

Needs Work Appendix

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Interim Results 30 June 2014

28

Unaudited6months

Unaudited6months

Unaudited6months

AuditedYear

ended30 ended31 ended30

ended31

June2014 December2013 June2013

December2013

Revenue 25,417,770 20,432,696 5,721,514

26,154,210

Costofsales (8,109,558) (5,681,610) (2,055,867)

(7,737,477)

Grossprofit 17,308,212 14,751,086 3,665,647

18,416,733

Administrativeexpenses (3,202,170) (3,221,689) (2,338,101)

(5,559,790)

Normalisedoperatingprofitbeforeexceptionaladministrativeitems 14,106,042 11,529,397 1,327,546

12,856,943

Depreciation&amortisation 3,311,123 2,854,408 919,404

3,773,812

NormalisedEBITDAbeforeexceptionaladministrativeitems 17,417,165 14,383,805 2,246,950

16,630,755

Grossbarrelssold 342,384 274,866 83,428

358,294

Netbarrelssold 279,964 223,240 67,423

290,664

Dailyaveragebarrelssold(gross) 1,892 1,494 461

982

Averagesalespriceperbarrel $91.73 $92.70 $85.60

$91.05

NormalisedEBITDApergrossbarrelsold $50.87 $52.33 $26.93

$46.42

1. Normalisedoperatingprofitisoperatingprofitadjustedforexceptionaladministrativeitemsand,in

respectoftheperiodended31December2013,againonsteppedacquisition.2. Normalised EBITDA is operating profit adjusted for depreciation, amortisation, exceptional

administrativeitemsand,inrespectoftheperiodended31December2013,againonsteppedacquisition.

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The Company’s Advisors

Nominated Advisor & Joint Broker: Westhouse Securities

Joint Broker: Canaccord Genuity

Auditors: BDO LLP (UK)

Solicitors: Simmons & Simmons LLP (UK), Greenberg Traurig, LLP (USA), Beatty & Wozniak (USA)

Reserves Analysis: Ryder Scott & Company

Bankers: Commonwealth Bank of Australia, Vectra Bank Colorado, Royal Bank of Scotland and JP Morgan Chase

UK Public Relations Consultants: FTI Consulting

US Investor Relations Consultants: EnerCom, Inc. 29

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Terminology

“AFE” – Authority for expenditure is a budgetary document, usually prepared by the operator, to list estimated expenses of drilling a well to a specified depth, casing point or geological objective, and then either completing or abandoning the well.

“Bbls” – barrels

“Behind pipe” - behind pipe opportunities, production or reserves refers to potentially producible zones that have been penetrated by a well bore but are separated from the well bore by casing (pipe) and cement and hence cannot be produced without recompleting the well in such behind pipe zones. Once completed and proved to be productive, behind pipe opportunities can increase production, cash flow and reserves.

“BOE” – Barrel of oil equivalent. A term used to summarize the amount of energy that is equivalent to the amount of energy found in a barrel of crude oil.

“BOEPD” – Barrels of oil equivalent per day

“Company” or “Nighthawk” Nighthawk Energy plc, a company incorporated and registered in England and Wales under the Companies Act 1985 with registered number 4000483

“D&C” – Drilling and Completion

“EBITDA” - Earnings before interest, tax, depreciation and amortization ,which generally equates to the revenues less operating costs of an entity.

“EUR” – Estimated ultimate recovery is the amount of oil and gas expected to be economically recovered from a reservoir or field by the end of its producing life.

“Group” the Company, its subsidiaries and its subsidiary undertakings

“IRR” – Internal rate of return

“MBOEPD” – Thousand barrels of oil equivalent per day

“MMBOE” - million barrels of oil equivalent

Continued…

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Terminology

“Mcf” – Thousand cubic feet

“NAV” – Net asset value

“Net revenue interest (NRI)” - Nighthawk's share of oil, gas, and associated hydrocarbons produced, saved, and marketed, after satisfaction of all royalties, overriding royalties, or other similar burdens on or measured by production of oil, gas, and associated hydrocarbons

“Net Present Value (NPV)” - The value today of a series of future cash flows adjusting those cash flows for the time value of money.

“Net Revenue Interest (NRI)” - A share of production after all burdens, such as royalty and overriding royalty, have been deducted from the working interest.

“PV” – Present value

“Possible reserves” are reserves that have a 10% chance of being greater than estimated and a 90% chance of being smaller

“Probable reserves” are reserves that have a 50% chance of being higher than estimated and a 50% chance of being lower

“Proved Developed Non-producing (PDNP) reserves” include shut-in and behind-pipe reserves

“Proved Developed Producing (PDP) reserves” are expected to be recovered from completion intervals (oil- and gas-producing sands or zones) that are open and producing at the time of the estimate

“Proved Undeveloped (PUD) reserves” are expected to be recovered from (1) new wells on undrilled acreage or (2) existing wells requiring major expenditure

“WI”- Working Interest is the percentage of ownership in an oil and gas lease granting its owner the right to explore, drill and produce oil and gas from a tract of property.

“West Texas Intermediate (WTI)” is a blend of crudes widely used as a price marker or benchmark for the international oil industry.

“3P Reserves” is the total of Proved Reserves, Probable Reserves and Possible Reserves

31