Sterling Resources holds material oil and gas assets in the UK North Sea including the Breagh gas field with over 20 years of remaining production and the upcoming Cladhan oil field. Sterling plans to maximize production at Breagh through additional drilling and well stimulations over the next two years. The company also holds exploration licenses with significant prospective resources. Sterling is focused on stabilizing its operations and finances through portfolio rationalization, cost reductions, and refinancing its debt.

1. May 28, 2015
Annual General Meeting
Corporate Presentation

2. Page 1May 28, 2015 AGM
Forward-Looking Statements
The information in this presentation contains certain forward-looking statements, including expectations of future production and capital expenditures. These statements
relate to future events or our future performance. All statements other than statements of historical fact may be forward-looking statements. Information concerning
reserves or resources are deemed to be forward-looking statements, as such estimates involve the implied assessment that the reserves or resources described can be
profitably produced in the future. These statements are only predictions. These statements reflect current expectations that involve numerous assumptions and which are
subject to a number of risks and uncertainties that contribute to the possibility that the predictions, forecasts, projections and other forward-looking statements will prove
inaccurate and which could cause actual results to differ from those anticipated by the Company. Although management believes that the expectations reflected in the
forward-looking statements are reasonable, there can be no assurance that such expectations will prove to be correct. The Company cannot guarantee future results, levels
of activity, performance or achievements. Actual results and future plans could differ materially from those anticipated in forward-looking statements contained in this
presentation as a result of the risks described below.
Certain of the risks and other factors, some of which are beyond the Company’s control, which could cause results to differ materially from those expressed in the forward-
looking statements contained in this presentation include, but are not limited to those as described in the Company’s annual information form for the year ended December
31, 2014 (the “AIF”) which is available at www.sedar.com. Those factors should not be considered as exhaustive.
In addition, this presentation may contain forward-looking statements attributed to third-party industry sources. These sources are not endorsed or adopted by the
Company explicitly or implicitly. Undue reliance should not be placed on these forward-looking statements, as there can be no assurance that the plans, intentions or
expectations upon which they are based will occur.
The forward-looking statements contained in this presentation are expressly qualified by the foregoing cautionary statement and, subject to applicable securities laws, the
Company is under no duty to update any of the forward-looking statements after the date hereof or to compare such statements to actual results or changes in the
Company’s expectations. Financial outlook information contained in this presentation about prospective results of operations, financial position or cash flows is based on
assumptions about future events, including economic conditions and proposed courses of action, based on management’s assessment of the relevant information currently
available. Readers are cautioned that any such financial outlook information contained in this presentation should not be used for purposes other than for which it is
disclosed herein.
No Solicitation or Offer
Nothing contained herein is intended to constitute an offer to sell or a solicitation of an offer to purchase securities. Any such offer or solicitation may only be made by
prospectus or otherwise pursuant to an exemption from prospectus and registration requirements applicable to the Company.
Non-IFRS Measures
This presentation may contain non-IFRS measures, including the term “net debt”. This and any other non-IFRS measures used in this presentation are intended to provide
investors with additional information regarding the Company’s business.
Disclaimer

3. Strategy
Operations update
Financial

4. Page 3May 28, 2015 AGM
Overview of Sterling Resources
• E&P independent listed on TSX-V (Toronto, ticker SLG)
− Market cap of US$55m (26 May 2015, at C$0.18/share)
− Net debt of $185m(1) at 31 March 2015
• North Sea business with operations in UK and the Netherlands
− Recent streamlining of operations makes the company a more attractive
corporate acquisition and merger candidate
• Material asset base: 23 MMboe of 2P reserves(2) and current net
production of ~5,800 boe/day
− Main asset is Breagh gas field in UK; current field production ~114
MMscf/d (34 MMscf/d net) sales gas from 8 wells
− Cladhan field under development with expected first oil end Q3 2015
(capex mostly carried by Cladhan field operator TAQA)
• Large UK tax loss of ~£451m ($667m)(3): no taxes forecasted to be
paid until ~2025(4)
• Focus on streamlining the portfolio and cutting expenditure
− Announced sale of Romanian business for net $32.5m cash and issue of
$7.5m of shares; removes licence well commitments
− Reducing expected annual net G&A cost by 40% from 2014 to 2016
− Pursuing farm-outs across UK licence portfolio
(1) Non-IFRS estimate: outstanding Bond amount of $202.5m less total cash/cash
equivalents/restricted cash of $18m at 31 March 2015
(2) Sterling end-2014 NI 51-101 F1. See page 23
(3) Management estimate as at 31 Mar 2015 for RFCT loss (SCT loss is approx. £402m ($595m)).
(4) Assuming RPS pricing and new Investment Allowance (an additional tax relief introduced in
2015), after impact of future estimated E&A, G&A and Bond interest (see page 6)

5. Page 4May 28, 2015 AGM
2014 Strategy look-back
2014 Stated Strategy
• Stabilize and improve Breagh production
− Resolve plant start-up issues
− Increase Breagh production
• Rationalize portfolio / capital exposure
─ Reduce exploration commitments
─ Reduce high equity interest in Romania
• Improve debt structure
─ Refinance bond with RBL
2014 Strategy Scorecard
• Stabilize and improve Breagh production
− Recent uptime >95%
− A07 & A08 fracture stimulations improving rates & recovery
− Further development drilling planned – end 2015 to early 2017
− Fracture stimulations planned for new & some existing wells
• Rationalize portfolio / capital exposure
─ No further exploration applications
─ Seismic acquired to facilitate farm-outs
─ Exit from Romania with Carlyle sale
─ Potential Breagh part sale
• Improve debt structure
─ Operational stabilization required first
─ Romania sale raises cash & removes commitments
─ Pursuing several options to refinance by end October 2015
• Unforeseen circumstances
─ Commodity price
─ RWE / L1 sale and DECC response

6. Page 5May 28, 2015 AGM
2015 Strategy
• Sterling Resources - North Sea focused E&P company
− Maximize Breagh cash flow through increased investment in drilling and compression
− Enhance value of UK tax losses through asset acquisition and/or consolidation
− Complete exit from France and Romania
− Monetize 2C resources in Netherlands
• Achieve long-term financial stability
− Refinance debt / strengthen balance sheet
− Minimize E&A expenditure
− Significant actions taken to reduce costs and commitments
• Achieve sustainable scale or sell company

7. Strategy
Operations update
Financial

8. Page 7May 28, 2015 AGM
Significant production and long term reserves
Reserves and resource base Stable long-term production
• Material reserves from Breagh (and Cladhan) (1)
− Breagh 2P reserves: 23.1 MMboe
− Forecast 20+ years remaining production life
• Further 2C Contingent Resources in UK and Netherlands(1)
− UK: 24.1(2) MMboe
− NL: 12.0 MMboe (1) Sterling AIF
(2) UK Contingent Resources subject to revision post Crosgan well results

9. Page 8May 28, 2015 AGM
Participants Sterling (30%), Dea (70%, op.)
Field 2P Reserves(1) 444 Bcf sales gas, 1.6 MMb condensate
Net 2P Reserves(1) 133 Bcf, 0.5 MMb cond. (22.7 MMboe)
First Production October 2013
Expected 2015 prod.(2) 104 MMscf/d field, 31 MMscf/d net
Breagh: Long-term UK gas production
(1) RPS End-2014 Breagh Report
(2) Sterling adjustment of RPS production to reflect latest expected well timings
Material North Sea gas producer
• 8 production wells drilled from the Breagh Alpha platform
• Substantial reserve base
• New 3D acquired in 2014, key to defining additional well targets and
unlocking Phase 2 decision
• 48 bcf produced to date
Strong operational performance
• Early phase production issues now resolved
• 2015 Plant uptime >95%
• Improved production rates following hydraulic fraccing (A07 & A08)
• Current production c. 114 MMscf/day sales gas
• Low opex - $7.9/boe over 2015-19
Production growth through 2015-17 development
• Drill up to four new wells and stimulate two existing wells by 2017 (A09
and A10 + 1 re-entry budget committed)
• Onshore gas compression from mid 2017 to enhance recovery
• Make use of recent 3D seismic targeting 2C resources in SE area of field
• Re-commence Phase 2 development planning Q4 2015

10. Page 9May 28, 2015 AGM
0
10
20
30
40
50
60
70
80
90
100
110
120
130
140
150
160
1 Jan 14 1 Feb 14 1 Mar 14 1 Apr 14 1 May 14 1 Jun 14 1 Jul 14 1 Aug 14 1 Sep 14 1 Oct 14 1 Nov 14 1 Dec 14 1 Jan 15 1 Feb 15 1 Mar 15 1 Apr 15 1 May 15
Dailyproducon(MMscf/d)&Cumulaveproducon(bcf)
Daily Raw Gas Produc on
Cumula ve Raw gas produc on
Breagh: Production Operations
Early life operational issues
• Instrument contamination – resolved
• MEG contamination – resolved
• Operational disturbance due to rig operations –
drilling program completed
Steady state operations
• Facilities debugged during 2014 – reliability from
November
• Fracced wells continue to perform strongly
• Intelligent pig run completed
Well productivity
• A01, A02, A05, A06 producing at consistent rates
• A03 continues to produce strongly
• A07 & A08 were fracced to enhance well
productivity and continue to deliver above
expectations
Breagh wet gas production to date
ENSCO70rigmove
ENSCO70rigmove&platformhydraulictrip
Operationalproductioncurtailment
Resolutionofsolidsmanagementissues
Operationaldisturbancedueto
solidscontamination
TGPPvesselinspections
A07
on line
A08 on line

11. Page 10May 28, 2015 AGM
Breagh: Strong results from fraccing to reshaped the future development plan
Field experience shows benefit from fraccing wells
• A07 well – producing August 2014
− Drilled in in SE of Field as Z1A producer
− Two zones fracced with 180,000 lbs of proppant pumped
− Stabilised Initial production rate of 32 MMscf/d sales gas (rate restricted)
− Estimated 2–3 times increase over expected un-fracced rate
• A08 well – producing November 2014
─ Drilled to NE of Field as Z1B producer
─ Two zones fracced with 150,00 lbs of proppant pumped
─ Stabilised Initial production rate of 47 MMscf/d sales gas (rate restricted)
• Fracs conducted over Breagh Alpha platform while producing
─ Operations conducted effectively
─ Downhole screens installed and working well
All further wells to be fracced to access full Breagh potential
─ Second drilling campaign on Breagh Alpha platform
• Wells A09, A10 and 1 well intervention
• Wells A11, A12 and 1 sidetrack
─ Phase 2 development
• Platform wells to be fracced
Schlumberger ‘Big Orange XVIII’ stimulation vessel

12. Page 11May 28, 2015 AGM
Breagh: future plans
Remaining Phase 1 development
• Drilling program expected to recommence in Q4 2015
─ A09, A10 and hydraulic stimulation of one existing well are firm,
─ On stream mid 2016
─ A11, A12 and hydraulic stimulation of another existing well are contingent,
─ On stream mid 2017
─ All new wells to be hydraulically stimulated in batches
• Install onshore compression over 2015-2017 to boost production rates and
increase reserves
Potential Phase 2 development
• Recommence development planning Q4 2015
• Results of stimulated wells and of 2014 3D seismic important for
optimizing Phase 2 scope
Additional upside
• Possible tie-back to platform with exploration success on Ossian or Darach
• Third party opportunities – significant prospectivity in area
A04
A06
A07
A02
A01
A05
A08
A03
A12
A4 s/t
A09
A10
A11
Phase 2
A04
A06
A07
A02
A01
A05
A08
A03
A12
A4 s/t
A09
A10
A11

13. Page 12May 28, 2015 AGM
Breagh: Life of Field production profile – management view
0
150
300
450
600
750
0
50
100
150
200
250
2013 2015 2017 2019 2021 2023 2025 2027 2029 2031 2033 2035 2037 2039
CumulativeGasProduction,Bscf
AverageWetGasProductionRate,MMscf/d
Breagh (17wells) Life of Field Profile
Breagh Alpha (12 wells) Breagh Bravo (Nominal 5 wells) Alpha Cum Bravo Cum

14. Page 13May 28, 2015 AGM
Cladhan: ongoing North Sea development
• Subsea development via Tern platform (operated by TAQA, 17km to NE)
• Initial development with two producers (P1, P2) and one water injector
(W1) – all wells drilled and completed
─ P2 well encountered less reservoir section than expected, contributing to
reserves reduction
• Project activity will complete during 2015
─ Riser pull ins
─ Subsea equipment hook up
─ Residual topsides modifications
─ Commissioning
• First oil forecast at end Q3 2015
• Average Opex $20.9/bbl over 2015-2019
Participants Sterling 2-13.8%, TAQA (52.7%, op.), MOL (33.5%)
2P Reserves(1) 10.4 MMbbls field, 1.44 MMbbls net (post carry)
First Production Q3 2015
(1) RPS End-2014 Cladhan Report

15. Page 14May 28, 2015 AGM
UKCS: additional Southern North Sea assets
(1) RPS 2014 YE evaluation
(2) Sterling AIF
• Ossian & Darach – Blocks 36/30, 42/2a, 42/3a,
42/4, 42/5
− Dual target: Permian reef and Carboniferous
− Potentially large structure with 1,076 bcf P10 GIP(1)
− Net Best Estimate Prospective Resources of 168 Bcf(2)
− Opportunity to tie-back to Breagh in event of success
• Nia & Niadar – Blocks 49/18a & 49/19a
− Permian Rotliegendes target
− Good quality reservoir tested near prospect
− Transpressional pop-up structure
− Potential of with 156 bcf P10 GIP(1)
− Net Best Estimate Prospective Resources of 59 Bcf(2)
• Crosgan discovery – Blocks 42/10a & 42/15a
− Well results announced on 5 February 2015
Nia & Niadar LocationOssian & Darach Location
Ossian Reef play Nia & Niadar seismic line

16. Page 15May 28, 2015 AGM
UKCS: Central North Sea assets
• Discovered oil in Evelyn and Belinda – Block 21/30f
− P50 Contingent Resources 4.1 MMboe net(1) (Sterling 20% WI)
• Well planned on Evelyn/Belinda (appraisal - 2016)
− High proportion of dry hole costs carried by Shell
− Considering Belinda following G&G review
• On success, Belinda considered as a sub-sea tie-back to nearby
infrastructure
(1) Sterling AIF

17. Page 16May 28, 2015 AGM
• Sterling is Operator of Jurassic and Early Cretaceous horizons in licences
F17a, F18 (Sterling 35%)
• Net 2C Resources in F17a/18 of 12 MMbbls(1), in four oil discoveries
• Appraisal activity by Wintershall pushing forward possible oil development
hub
− Drilled successful appraisal wells, F17-11 and F17-12, in H2 2014 and F17-13/13z in Q2 2015
in Late Cretaceous chalk
− Announced application for development licence of Rembrandt field - ~30 million barrels of
oil equivalent (2)
• Sterling acquired 3D seismic in Q2 2014 to improve reservoir understanding
and support evaluation of development options
Netherlands: F Quad probable oil development
(1) Sterling AIF
(2) Wintershall news release 15 April 2015

18. Page 17May 28, 2015 AGM
Work program
commitment or firm contingent
United Kingdom
Drill, stimulate A9,10 & re-entry Drill, stimulate A11,12 & sidetr.
O n s h o r e c o m p r e s s i o n
Breagh Phase 2 development FDP approval  Detailed design, fabrication, installation First gas  Ongoing drilling
Breagh 3D seismic Processing and interpretation
Cladhan development First oil 
E&A drilling Crosgan Belinda/Evelyn Niadar Ossian/Darach
Romania
Sale process VDR, bids Closing
Netherlands
3D seismic Processing and interpretation
2018
Q1 Q2 Q3 Q4
Breagh Phase 1 development
Q3 Q4
2015 2016 2017
Q1 Q2 Q1 Q2 Q3 Q4Q1 Q2 Q3 Q4

19. Strategy
Operations update
Financial

20. Page 19May 28, 2015 AGM
Asset value backing
• Before-tax RPS reserves valuations as at end 2014(1):
(1) Based on discount rate of 10%, RPS End-2014 Asset Reports. Note these valuations
do not reflect benefit of lower SCT rate or Investment Allowance (see page 16)
(2) Differences between RPS opening tax loss and estimated total UK tax losses at end
2014: RFCT £433m ($673m); SCT £397m ($616m).
Before Tax 1P $m 2P $m 3P $m
Breagh Phase 1 377 496 675
Cladhan 4 13 30
Total 381 509 705
• After-tax RPS reserves valuations as at end 2014(1):
− Reflect Capital Allowances plus accumulated RFES of £285m and £38m for Breagh and Cladhan respectively
− Does not reflect additional UK tax losses of £110m (RFCT, end-2014) and £74m (SCT, end-2014) which would be available
to shelter remaining tax paid in after tax valuations(2)
After Tax 1P $m 2P $m 3P $m
Breagh Phase 1 346 403 481
Cladhan 4 13 30
Total 350 416 511

21. Page 20May 28, 2015 AGM
Significant value in tax losses
• Issuer has very significant UK tax losses:
− As of March 31, 2015: £441m ($667m) (RFCT) loss(1) and £402m ($595m)
(SCT) loss(1)
− Ring Fence Exploration Supplement increases tax loss base by 10% p.a.,
still available to claim for 2015.
− No UK tax expected to be paid until around 2025 based on RPS price
assumptions and management expenditure estimates(2)
− Net Present Value of full existing tax losses, including future RFES benefit,
estimated by Sterling as $172m(2)
− Net Present Value of tax losses not already included in RPS asset
valuations = $33m(3)
− Subject to anti-avoidance legislation, a purchaser of the UK company
could theoretically realise close to full nominal value for Sterling’s UK tax
loss and sooner than is currently the case
• UK 2015 Budget introduced further tax incentives:
− SCT rate reduced to 20% (from 32%) from January 1, 2015
− Extended RFES for losses incurred from December 5, 2013 for a further 4
years
− Investment Allowance of 62.5% uplift on eligible capital expenditures for
SCT purposes from January 1, 2015
(1) Sterling estimates; RFCT = Ring Fence Corporation Tax , SCT = Supplementary
Corporation Tax
(2) Includes G&A, E&A & financing costs; reflects recent tax changes.
(3) Value of £110m ($158m) of RFCT loss and £74m ($117m) SCT loss not reflected in RPS
valuations as at end Dec 2014
Sterling Resources UK tax position

22. Page 21May 28, 2015 AGM
Bond amendments – May 2015
• A second set of bond amendments was approved by bondholders on 8 May 2015
• Benefits to Sterling:
− A deferral of the amortization instalment (including amortization premium) due on April 30, 2015, until the earlier of (i) the closing date of the Romanian Sale
and (ii) October 30, 2015.
− A further suspension of transfers of funds into the DSRA from April 30, 2015 until, but excluding, October 30, 2015 (this represents a continuation of the
current suspension which has been in place since October 30, 2014).
− A reduction in the minimum UK liquidity requirement from $10 million to $5 million from April 30, 2015 to October 30, 2015.
− A permanent one month deferral in monthly transfers to DSRA, from when these would otherwise resume on October 30, 2015.
• Compensation to bondholders
− Organizational review has resulted in reduction of UK employee headcount by 25%
− A deferral of the amortization instalment (including amortization premium) due on April 30, 2015, until the earlier of (i) the closing date of the Romanian Sale
and (ii) October 30, 2015.
− A further suspension of transfers of funds into the DSRA from April 30, 2015 until, but excluding, October 30, 2015 (this represents a continuation of the
current suspension which has been in place since October 30, 2014).
− A reduction in the minimum UK liquidity requirement from $10 million to $5 million from April 30, 2015 to October 30, 2015.
− A permanent one month deferral in monthly transfers to DSRA, from when these would otherwise resume on October 30, 2015.
Together, the Bond Amendments are anticipated to provide necessary incremental liquidity
which the Company believes will be sufficient to ensure it is properly funded through to
late October 2015.

23. Page 22May 28, 2015 AGM
Financial situation and outlook
• Group cash balances end-April 2015: $10 million
• Free cash deficit at October 31, 2015 expected to be approx. $17m
− This is the deficit after a) completion of Romanian sale in early July, b) paying outstanding amortization instalment (with 7.5% premium) from April 30, 2015,
c) making an amortization instalment (with 7.5% premium) and interest payment of $33.3m on October 30, 2015, and d) providing for $10m of minimum UK
unrestricted cash from October 31, 2015
− Reflects latest forward curve gas prices
• Sterling’s principal financing problem is that the current bond will be amortizing steadily over the next two years when
material capital expenditures are being incurred on Breagh – the amortization profile does not match the field’s cash flow
profile
• Sterling is actively seeking to refinance the current bond during the next 5 months: the principal options include a reserves
based loan or a new bond issue
• Separately, Sterling has aggressively cut costs in 2015 to adapt to its financial situation and the lower commodity price
environment
− Organizational review has resulted in reduction of UK employee headcount by 25%
− No annual salary increases or cash bonuses for 2014 to be paid to staff in 2015
− UK offices in Aberdeen and London being relocated with aggregate saving of $0.5m pa
o Aberdeen – smaller office in Westhill, moved April 2015
o London – smaller office in Stockley Park (business park close to Heathrow), moved mid March 2015
− Expected $8.5m gross/$6.5m net annual G&A from 2016 (also reflects sale of Romania); down from $19m gross/$11m net in 2014 (lower recoveries and
allocations because of loss of operated assets in Romania and lower levels of licence activity)

24. Page 23May 28, 2015 AGM
• Current production rates disclosed herein may not be indicative of long term performance or ultimate recovery. Such rates are not determinative of the future production
rates of the relevant fields and do not reflect how the production from such fields will decline thereafter.
• Estimates of Reserves and Future Net Revenue have been made assuming the development of each property in respect of which the estimate is made will occur, without
regard to the likely availability to the Company of funding required for that development.
• Possible Reserves are those additional reserves that are less certain to be recovered than Probable Reserves.
• Company Reserves totals are arithmetic aggregations of multiple estimates, which statistical principles indicate may be misleading as to volumes that may actually be
recovered.
• Readers should give particular attention to the estimates of individual classes of Reserves and appreciate the differing probabilities of recovery associated with each class
under a specific set of economic conditions:
- A 90 percent probability that the quantities actually recovered will equal or exceed the estimated Proved Reserves (1P);
- A 50 percent probability that the quantities actually recovered will equal or exceed the sum of the estimated Proved plus Probable Reserves (2P); and
- A 10 percent probability that the quantities actually recovered will equal or exceed the sum of the estimated Proved plus Probable plus Possible Reserves (3P).
• The estimates of Reserves and Future Net Revenue for individual properties may not reflect the same confidence level as estimates of Reserves and Future Net Revenue for
all properties, due to the effects of aggregation.
• Contingent Resources are those quantities of petroleum estimated, as of 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. It is also appropriate to classify as contingent resources the estimated
discovered recoverable quantities associated with a project in the early evaluation stage. There is no certainty that it will be commercially viable to produce any portion of
the resources.
• The P(50) or 2C Contingent Resources quantity is considered to be the best estimate of the quantity that will actually be recovered. If probabilistic methods are used there
should be at least a 50 percent probability P(50) that the quantities actually recovered will equal or exceed the estimate.
• Prospective resources are 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. 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 relation to the relative uncertainty of recoverability of resources, a Best Estimate resources quantity is considered to be the best estimate of the quantity that will actually
be recovered. It is equally likely that the actual remaining quantities recovered will be greater or less than the best estimate. There should be at least a 50 percent
probability that the quantities actually recovered will equal or exceed the best estimate.
• MMboe numbers may be misleading, particularly if used in isolation. A 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. Given that the volume ratio based on the current price of crude oil as compared to
natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
Important notes

25. Page 24May 28, 2015 AGM
Important Notes (continued)
• Certain information in this presentation may constitute "analogous information" as defined in National Instrument 51-101 – Standards of Disclosure for Oil and Gas
Activities (“NI 51-101”), including, but not limited to, discoveries in the same block in which the Company has an interest in the Netherlands. Such information has been
obtained from government sources, regulatory agencies or other industry participants. The Company’s management believes the information is relevant as it helps to define
the reservoir characteristics and the reserves and production potential in which the Company holds an interest. Such information has not been prepared in accordance with
NI 51-101. The Company is also unable to confirm that the analogous information was prepared by a qualified reserves evaluator or auditor. Such information is not an
estimate of the resources attributable to the acreage held or to be held by the Company and there is no certainty that the reservoir data, resource estimates, production
and decline rates and economics information for the acreage held by the Company will be similar to the information presented herein. The reader is cautioned that the data
relied upon by the Company may be in error and/or may prove not be analogous to the acreage be held by the Company.
Information Sources
Information on reserves and resources in this presentation are drawn from (i) the Company’s most recent Statement of Reserves Data and Other Oil and Gas Information on
Form 51-101 F1 for the year ended December 31, 2014 (“End-2014 NI 51-101 F1”), (ii) the Company’s AIF; (iii) the RPS Energy report “Executive Summary Reserves and
Resources Evaluation for the Breagh Gas Field Quad 42 UK North Sea as at December 31, 2014”; and (iv) the RPS Energy report “Executive Summary Reserves and Resources
Evaluation for the Cladhan Oil Field Quad 210 License Blocks UK North Sea as at December 31, 2014”; to be filed shortly on SEDAR at www.sedar.com. Items (iii) and (iv) are
referred to as “RPS End-2014 Breagh Report” and “RPS End-2014 Cladhan Report” respectively and together the “RPS End-2014 Asset Reports” in this presentation. Numbers
may not correspond precisely with those set forth in the Company's annual disclosure in Form 51-101F1 due to the effects of rounding.
Economic Assumptions
(1) RPS end-2014 NBP sales gas price. $8.52/Mcf for 2015, $8.81/Mcf for 2016, $9.42/Mcf for 2017, $9.77 for 2018 escalated 2% thereafter.
(2) RPS end-2014 Brent crude oil price. $70.03/bbl for 2015, $74.64/bbl for 2016, $79.50/bbl for 2017, $84.50 for 2018, $89.50 for 2019, $93.85 for 2020 escalated 2%
thereafter. Cladhan crude is assumed to realise a premium to Brent of $1.13/bbl for 2015, $0.88/bbl in 2016, $0.88/bbl in 2017, $0.92/bbl in 2018, $0.97/bbl in 2019,
$1.02/bbl in 2020 and $1.07 /bbl in 2021.
(3) RPS flat exchange rate GBP/USD 1.60 throughout field life.
Abbreviations
All dollars in this presentation are US dollars unless otherwise stated. $m = million dollars.
boe = barrel of oil equivalent. Capex = capital expenditures. E&A = exploration & appraisal costs. G&A = general & administrative costs. Mcf = thousand cubic feet. MMscf/d =
million cubic feet of gas per day. MMb =millions of barrels NBP = National Balancing Point (for UK gas prices). Opex = operating expenditures. RFCT = Ring Fence Corporation
Tax. RFES = Ring Fence Expenditure Supplement. SCT = Supplementary Charge Corporation Tax.
Important Notes, Info Sources, Economic Assumptions and Abbreviations