Sonde Resources Corp.

Sonde Resources Corp.
July, 2011

Forward-looking information
• This presentation contains "forward-looking information" (within the meaning of applicable
Canadian securities laws) and "forward-looking statements" (within the meaning of the U.S. Private
Securities Litigation Reform Act of 1995). These include statements about our strategic and
operational plans and goals, proposed development and growth opportunities and capital
spending, production base and changes to production base, the expected closing date for the
proposed sale of the Trinidad assets, in conjunction with Joint Oil, the potential for a two year
extension to our exploration program and the expectation of successful future results.
• Such forward-looking information or statements are based on a number of risks, uncertainties and
assumptions which may cause actual results or other expectations to differ materially from those
anticipated and which may prove to be incorrect. Assumptions have been made regarding, among
other things, operating conditions, regulatory approvals, availability of capital, capital and other
expenditures. Actual results could differ materially due to a number of factors, including, without
limitation, risks affecting the Company's ability to execute projects and market oil and natural gas,
volatility of oil and gas prices, risks inherent in operating in foreign jurisdictions, the inability to raise
additional capital, changes in project schedules, commercial negotiations, and unforeseen
technical difficulties. Additional assumptions and risks are set out in detail in the Company's annual
reports on Form 40-F or Form 20-F on file with the U.S. Securities and Exchange Commission.
• Prospective investors should not place undue reliance on forward-looking statements because the
Company can provide no assurance that such expectations will prove to be correct. We base our
forward-looking statements on information currently available and do not assume any obligation to
update them except as required by law.
2

Forward-looking information
Additional advisories
• This presentation includes information pertaining to the reserves of the Company as at December
31, 2010 as evaluated by GLJ Petroleum Consultants Ltd., independent oil and natural gas
reservoir engineers in their report dated March 9, 2011 (the "GLJ Report"). There is no assurance
that the forecast price and cost assumptions contained in the GLJ Report will be attained and
variances could be material.
• Boes are presented on the basis of one Boe for six Mcf of natural gas. Disclosure provided herein
in respect of Boes 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.
• Cash flow is a non-GAAP measures and thus may not be comparable to similar measures used by
other companies. The most comparable GAAP measure is net earnings. Cash flow is calculated
before changes to non-cash working capital and asset retirement expenditures.
• Cash flow is used by management as a performance measure and provides shareholders and
investors with a measurement of the company’s ability to fund future growth. Management feels
this is a useful metric as it is a common metric used by other companies operating in the oil and
gas industry in order to provide a comparison of relative overall performance between companies.
Management uses the metric to assess the Company's overall performance relative to that of its
competitors and internal planning purposes.
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Sonde Key Metrics
• Market cap: USD $182 mm (July 19, 2011)
• Common Shares outstanding: 62.3 million
• Production: 2,740 BOEPD (75% gas) + 400 BOEPD waiting on tie-in
or plant capacity
• $60 MM cash / no debt / $60 MM facility

Sonde Key Metrics (cont)
• Reserves:
‣ W. Canada 2P (GLJ): 10.2 MMBOE, added 1.6 MMBOE over 2009.
‣ Tunisia Petroleum Initially In-Place (PIIP) Report (Ryder Scott): 362 MMbbl
Oil / Condensate + 980 BCF Gas (50% CO2)
‣ Management estimate: W. Canada assets contain ~24 MMBOE 3P
reserves, 157 oil-oriented HZ drilling locations
‣ 2 Drumheller Mannville “I” Pool HZ wells in drilled and cased, 3 rd near
completion. First 2 wells frac’ing now
• Land (gross / net acres):
‣ W. Canada (Developed + Exploratory): 446,222 gross / 316,760 net
‣ Tunisia (Exploratory): 780,000 / 780,000

The Team
“For Purpose” team, focus on:
‐Talent (top quartile performers)
‐Experience (20+ years in most leadership positions)
‐Fit with Corporate Strategy & Leadership style
Tunisia Country
Manager
Magnus Clouston
Manager, Exploration
Ed Chau
Production
Supervisor South
Byron Muddle
President/CEO
Jack Schanck
COO
Bill Dirks
Manager Land/Bus
Development
David Cassidy
Manager Engineering
and Operations
Laurie Henderson
Drilling / Compl
Mgr
Randy Pryor
Manager of
Facilities/Production
John Krug
CFO
Kurt Nelson
HSE Manager
Garry Mann
Production
Supervisor North
Neil Dimond
Asset Manager South
Gordon McIntosh
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Strategy
•Oil oriented growth: focus in Western Canada, related Rockies basins
‐HZ infill drilling in existing pools
‐exposure to high‐leverage resource plays (Duvernay)
‐a substantial asset for future monetization in N. Africa.
•Sonde established a strong path forward in 2010:
‐Vertical proof‐of‐concept wells in W. Canada eliminated base decline
‐Divested Trinidad and LNG assets
‐Built team capable of executing plan
•2011‐2012 CAPEX program aimed at bringing significant new Production and Reserves online
‐W. Canada: ~160 HZ development locations identified, “proof of economics” program in 2011
($34 MM), aggressively attack in 2012+ given success
‐Additional capital for M&A, core asset consolidation (Drumheller)
•Results indicate that the company has a large, under‐booked, oily Reserves / Resources base:
‐W. Canada: mitigated base decline and increased reserves 20% with minimal capital and no
new drilling
‐Results from first HZ wells imminent

2011 Goals – W. Canada*
• Production and Revenue: 20% growth (excl. M&A) – Target 3300
BOE/d
• Reserves: 20% growth (excl. M&A) – Target 12 MM BOE
• Lease Operating Expense: 15% reduction
• F&D cost: Target below $11.00 / BOE
• Double oil production
• HSE: Double Y/Y capital spending while maintaining top 25% rating
for reportable accidents and lost time injuries
* based on $34 MM capital spending in Canada

Portfolio - Western Canada
• 2,740 BOE/d net WI production (75%
gas)
• 446,222 gross / 316,760 net ac.
2P: 471 Mboe
Un-booked upsides: 1,500 Mboe
2P: 1,356 Mboe
Un-booked upsides: 7,700 Mboe
2P: 6,783 Mboe
Un-booked upsides: 7,500 Mboe
• Proof of underdeveloped assets: Q3 /
Q4 2010 re-entry and workover
program, stems base decline of 600
Boe / d
• 2011 drilling program: Eleven 100%
WI, low-risk, HZ infill wells for oil and
liquids-rich gas
• Actively working acquisitions for
consolidation at Drumheller, Kaybob
• New resource plays being identified,
captured 60,000 net acres in Kaybob
Duvernay play to date

Portfolio - Drumheller Core Area
Highlights
Mannville PP oil pool
Chain Banff A oil pool
Michichi Banff / Detrital oil pool
Mannville FF & K oil pool
Mannville I oil pool Wildunn Banff F oil pool
HZ Development Program – 117 Oil
Locations
(2011 program: 6 HZ infills)
• 2 wells drilled / cased, 1 near
completion
• Frac’ing first 2 wells now, 3 rd by early
August
Vertical Re‐Development Program
(2011 program: 40 re‐entries / WO’s)
• 60+ vertical behind‐pipe and 100+
vertical work‐over locations for oil
and gas
A concentrated land position with significant light‐oil development
potential
10
Land Base
• 159,147 gross acres (36% of Sonde
Western Canada)
• 90,899 net acres (32% of Sonde)

Ellerslie HZ Re-development program,
Drumheller Mannville I pool
*Volumetrics:
110 MMbbl OOIP, 3.1% recovered
10% primary recovery = 7.6 MMbbl to be recv.
+
10% waterflood recovery = 11 MMbbl to be recv.
=
18.6 MMbbl remaining recoverable reserves
*Internal estimates
Drumheller Ellerslie Re-dev
49 HZ locations
HZ economics model
Well cost = $3.0 MM, $85 flat
Best case IP=270 BOEPD (3x vert)
EUR = 363k, PV10 DCF = $7.1 MM
P50 case IP=180 BOEPD (2x)
EUR = 242k, PV10 DCF = $3.8 MM
3/1 Sonde Av. WI = 67%
Worst case IP=100 BOEPD (vert well P50 case)
EUR = 134k, PV10 DCF = $0.8 MM
HZ drilling credit not factored in
Waterflood not factored in

Michichi and Wildunn HZ Oil Re-development
4-9-31-17W4 500m HZ
Michichi Detrital Pool
20+ locations
Stabilized rate = 65 BOPD
Decline =

Portfolio – Kaybob Core Area
Highlights
Duvernay Oil Resource Play
150 Prospective HZ Locations
Gething HZ Development Program
–35 Gas / Liquids Locations
(2011 program: 2 HZ infills)
• 2 proof of concept vertical wells
online
• High‐rate HZ analog immediately
west of Sonde holdings
• First HZ well August 2011
Duvernay Program
(2011 program: 1 HZ well
• 60+ vertical behind‐pipe and 100+
vertical work‐over locations for oil
and gas
Windfall Gething Pool
35 HZ Locations
Land Base
• 91,000 gross acres
• 62,000 net acres

Kaybob / Windfall HZ Gething Development
Sonde Wind 14-21-59-19W5
Sonde Wind 16-28-59-15W5 HZ
IP 1.2 MM + 15 BO (Vert)
Relatively water-free low res pay
Celtic 1-5-59-18 HZ
IP 12 MM + 2 BO (HZ)
10-month cum 1.6 BCF, EUR 13.5 BCF
Amoco etal Kaybob S 6-8-59-18W5
59-18
Offset to Celtic 1-5-59-18 HZ
$3 MM well, $3.70 flat
PV10 DNCF $7.1 MM+
(HZ drilling credit not factored in)

Portfolio - Kaybob / Puskwaskau Duvernay
Play
Commentary
• Thick, organic-rich formation over
85 township (2 MM acre) fairway in
W. Central Alberta
• Has characteristics similar to
Bakken Oil Resource play (1,000-
3,000 BOPD IP, 250k-750k bbl /
well EUR)
• Still early days with the majority of
data analysis/findings confidential;
Trilogy 3-13-60-20W5 HZ results
encouraging
• Sonde used Williston & US
Rockies experience to identify /
acquire 62,000 ac, av price $28 /
ac
• First Sonde well Q3/Q4
Grand Prairie
Fox Creek
Duvernay
150+ ft
Beaverhill Lake
Duvernay Isopach
(thick = warm colors)
Celtic et al
15-33-60-20W6

Kaybob / Puskwa Duvernay

Portfolio - W. Canada Oil Resource Plays
Muskwa
Exshaw
Duvernay
Sonde “Investment-quality” characteristics:
-Large (>1 MM ac) play area
-Petrophysically-definable sweet spots
-Reservoir within / between source packages
(Bakken middle-member model)
-Overpressure
-Recent sale prices

Other Sonde Assets
Cabin-Petitot
Umbach
Boundary Lake
Morinville
Rimbey
Moosejaw

Portfolio - Tunisia / Libya Offshore
• 780,000 ac 7 th of November block
(Sonde: 100% Operated WI) splits the
Libya/Tunisia border; national oil
company partner is Joint Oil (coalition
between Tunisia and Libya)
• Sonde Zarat North‐1 appraisal well: 240’
net pay, confirms substantial oil /
condensate / gas accumulation to be
appraised & developed 2011‐2013
• Large exploration upsides on block, but
working to re‐structure 3 well exploration
commitment re‐focused on Zarat
appraisal
• Block subject to Force Majeure
Large Light oil Development
Ryder Scott Petroleum Initially In‐Place (“PIIP”) report dated May 27, 2011

Zarat Field
Greater Zarat Anticline
-Regional structural high >25,000
acres
GOC ~-2,660m
(dark red + green)
OWC ~-2,700m
(yellow / orange boundary)
Sonde
-Reservoir: Eocene El Gueria limestone,
gas / condensate / oil proven in 3 wells
-Marathon Zarat 1: 279 ft net pay
-Sonde Zarat N-1: 240 ft net pay
-Marathon Zarat 1: Test rates as high as
15 MMCF + 1,192 BO / day
-Sonde Zarat N-1: Stabilized test rate
8 MMCF + 750 BO / day, peak rates
1,100 BO / day
Sonde Zarat North-1
Sonde
ENI
1 sq km
PA
Marathon Zarat 1

7 th Of November Block – Petroleum In-Place
Report Ryder Scott PIIP analysis 5/2011
Sonde Original
Area OGIP OCIP OOIP
Block (ac) (BCF) (MMbbl) (MMbbl)
1A (PA) 5,271 578 49.1 139.5
3
1B (SOQ) 2,477 274 23.3 59.6
2 (SOQ) 4,147 321 27.3 97.8
3 (SOQ) 2,934 99 8.4 37.5
2
Total 14,829 1,272 108.1 334.4
SOQ 9,558 694 59.0 194.8
(55%) (55%) (58%)
1B
1A
Ryder Scott

Summary
Oil‐oriented growth
Low‐risk W. Canada Development Program
Exponential Reserves, Value Growth Through Tunisia Development
Oil Resource Plays for W. Canada Upsides
• W. Canada:
‣ Light oil development programs at Drumheller, Kaybob
‣ Horizontal wells / multi-stage fracs to increase rate & EUR
‣ Use low risk, low-cost behind-pipe conventional gas inventory to flatten base decline
‣ Double capital spending, # of new wells in each of 2011 and 2012
‣ Add one new oil resource play annually, 50,000 to 100,000 low cost acres
• Tunisia:
‣ Currently under Force Majeure