2012

ANNUAL

REPORT

Kinabalu, Malaysia

We are quickly moving to strengthen and 

focus our company by imposing strict 

capital discipline, increasing the cash 

margins on the barrels we produce, and 

unlocking value through asset sales or 

strategic joint ventures.”

Hal Kvisle, President and CEO
DEAR Shareholders

The obligation of the Board of Directors is to ensure 

the best interests of shareholders are being served 

at all times, which requires strong governance and 

oversight of ethical and transparent behaviour, 

operational excellence, and a sound strategy.”

In 2008, the company set out a strategy of 

long-term profitable growth. We invested 

in North American shale, high netback 

production in Southeast Asia and pursued 

high impact exploration for future growth. 

A significant percentage of this was funded 

by selling non-core conventional natural 

gas assets. Prior to this, Talisman’s strategy 

had been largely centred on acquiring 

international assets. This had worked well 

in an environment of rising oil prices and 

relatively low competition for assets. 

For several years, our new strategy was 

very successful. We entered into the North 

American shale business via strategic land 

acquisitions in the Marcellus, Eagle Ford, 

Montney and Duvernay plays. We quickly 

built a world-class, low-cost natural gas 

play in the Marcellus. As North American 

natural gas prices fell, we shifted to liquids 

growth in the Eagle Ford. We sold a 50% 

working interest in a portion of our Montney 

play for over $2 billion, and acquired 

350,000 net acres in the very prospective 

Duvernay shale, which we are now piloting.

We have increased the size of our business 

in Southeast Asia by 40%, continuing 

to build on the long-life base of Corridor 

in Indonesia, as well as PM-3, which 

straddles Malaysia and Vietnam. Talisman’s 

track record and relationships make us a 

partner of choice for national oil companies 

in the region, which continues to serve us 

well as we look for new opportunities.

We have added significant amounts 

of contingent resource, both in North 

American shale plays and through our 

exploration activities in Kurdistan and 

Papua New Guinea. Our investment in 

Colombia will add shareholder value, both 

from our interest in the Ocensa pipeline 

and exploration and development upside.

Parts of the strategy did not work out as 

planned, which happens with any dynamic 

business plan. We invested considerable 

amounts of capital in dry gas, believing 

that our low-cost position in the Marcellus 

would be robust despite a drop in prices. 

The company reduced funding of assets 

in the North Sea and Western Canada, 

believing the size of the opportunities 

was too small. We invested a substantial 

amount of capital in long-dated exploration 

programs, believing that cash flow from 

North American natural gas investments 

would sustain us.

In early 2012, the Board asked for a review 

of the strategy. We were concerned with the 

sudden drop in North American natural gas 

prices and declining North Sea production. 

The strategy at the time was shifting 

funds to liquids-rich opportunities, but still 

envisioned spending well in excess of cash 

flow, including continued spending on 

long-dated exploration plays, necessitating 

asset sales to bridge the free cash flow gap.

It became clear that a significant change 

was needed, both in terms of our strategic 

direction, as well as how we ran the 

company. Simply put, we had made several 

large bets on a growth trajectory that did 

not materialize as planned. 

Normally this wouldn’t be part of the 

discussion in an annual report, but in 

this case I felt it was important to set 

some context around the appointment of 

Hal Kvisle as president and chief executive 

officer in September 2012. It is a difficult 

decision to replace a sitting CEO, but the 

Board felt an alternative strategy – 

in capable, experienced hands – was 

needed quickly. 

Hal, who was already on the Board, with 

over 35 years of industry experience 

and an exemplary track record of 

running companies in a disciplined 

manner, graciously agreed to take on the 

responsibility. He implemented a very 

successful new strategy at a major pipeline 

company, creating significant value for 

shareholders during his tenure, and has 

oil and gas credentials, both domestically 

and growing an international upstream 

company. Hal will tell you that his first love 

is the E&P business.

CHAIRMAN’S MESSAGE
“We see the next 12 months as a period of stabilization, 

unlocking value, maintaining optionality and rebuilding 

credibility to prepare for future growth in cash flow per 

share through a range of possible options.”

The Board has approved four strategic 

priorities centred on lower capital spending 

and manageable debt levels, increased 

capital focus, improved operational 

performance and unlocking 

the net asset value of the portfolio. 

The decisions to date have put the 

company on the right track, with a 

focused, high-value capital plan for 

2013. We see the next 12 months as a 

period of stabilization, unlocking value, 

maintaining optionality, and rebuilding 

credibility to prepare for future growth in 

cash flow per share through a range of 

possible options. The Board is actively 

overseeing the implementation of these 

new strategic priorities.

Board renewal continues to be a top 

priority for the Governance and Nominating 

Committee to ensure that the Board of 

Directors continues to maintain the right 

mix of skills and experience. We have a 

number of directors slated to retire over 

the next two years, upon reaching the 

age of 70, or after 10 years of service. We 

have an active process underway to review 

potential Board candidates with oil and gas 

experience, which includes shareholder 

feedback. I am confident that the election 

or appointment of at least three new 

directors by 2014 will bring dynamic new 

perspectives to the Board. 

I am pleased to announce that Brian Levitt 

has agreed to serve as a director of the 

company and will be nominated for election 

at the upcoming shareholders’ meeting. 

Brian, who is currently serving as Chair 

of the TD Bank Group and non-executive 

co-Chair of Osler, Hoskin & Harcourt LLP, 

has a wealth of experience in leading 

Canadian companies and in creating value 

for shareholders.

Talisman, along with all major North 

American natural gas producers, has 

challenges. However, we also have 

high-value liquids opportunities, a large 

contingent resource position, a growing 

business in Asia, and most importantly, 

very talented, dedicated people across 

all of our regions. With our new strategic 

direction, I am confident in our ability to 

meet our promise of a significant increase 

in total shareholder returns.

Charles (Chuck) Williamson

Chairman of the Board

OUR VALUES

•	 SAFETY: Our goal is to create working 

conditions where we cause no harm to people

•	 PASSION: We inspire others by the passion we 

demonstrate for our work

•	 RESULTS: We have a bias for results and 

take initiative to get things done efficiently, 

creating value for our shareholders

•	 RESPECT: We take time to consider and 

appreciate other people’s points of view, and 

treat the environment with respect

•	 EXCELLENCE: We strive for excellence in what 

we do and how we do it

•	 TEAMWORK: By working effectively together, 

we can deliver results far beyond our 

individual capabilities

•	 HONEST COMMUNICATION: We show courage 

to speak honestly and support others to do 

the same
MANAGEMENT’S DISCUSSION AND ANALYSIS 15

CONSOLIDATED FINANCIAL STATEMENTS AND NOTES 51

SUPPLEMENTARY OIL AND GAS INFORMATION 104

ADDITIONAL INFORMATION 113

DETAILED PROPERTY REVIEWS 121

CORPORATE GOVERNANCE 129

INVESTOR INFORMATION 130

CORPORATE INFORMATION 131

MARKET INFORMATION 134

CHAIRMAN’S MESSAGE

Letter from Hal Kvisle

President and Chief Executive Officer 2

ADDRESSING THE ISSUES 4

LIVE WITHIN OUR MEANS 5

FOCUS OUR CAPITAL PROGRAM 5

IMPROVE OPERATIONAL PERFORMANCE 6

UNLOCK NET ASSET VALUE OF THE PORTFOLIO 7

FOCUS AREAS 8

THE AMERICAS 9

ASIA-PACIFIC 10

CORPORATE RESPONSIBILITY 12

CONTENTS

Marcellus Shale Play North America
TALISMAN ENERGY ANNUAL REPORT 2012 1

ABOUT OUR COMPANY

Talisman Energy Inc. is a global upstream oil and gas company, headquartered in Canada. Talisman has two core operating areas: 

the Americas (North America and Colombia) and Asia-Pacific. Talisman is committed to conducting business safely, in a socially 

and environmentally responsible manner, and is included in the Dow Jones Sustainability (North America) Index. Talisman is listed 

on the Toronto and New York stock exchanges under the symbol TLM.

Please visit our website at www.talisman-energy.com.

THE OBJECTIVE OF OUR 2013 CAPITAL AND OPERATING PLAN IS TO INCREASE TOTAL SHAREHOLDER RETURNS BY 

UNLOCKING NET ASSET VALUE AND GROWING CASH FLOW PER SHARE. OPERATIONALLY, THE PLAN FOCUSES ON 

TALISMAN’S TWO CORE AREAS (THE AMERICAS AND ASIA-PACIFIC), INCREASING THE CONTRIBUTION FROM LIQUIDS 

VOLUMES, MAINTAINING A STRONG BALANCE SHEET AND DRIVING OPERATIONAL EXCELLENCE. 

2012 highlights

•	 Capital expenditure: $4 billion.

•	 Production exceeded expectations at 426,000 boe/d. 

•	 Grew Southeast Asia production by 8%.

•	 Grew North American liquids by 17%. 

•	 Cash flow: $3 billion. Down from 2011, due to lower 

North Sea volumes, lower North American natural gas 

prices, and higher costs. 

•	 Completed $2.5 billion in asset sales. 

•	 Sold a 49% equity interest in our UK North Sea business 

to Sinopec for $1.5 billion. 

•	 Reduced net debt by approximately $750 million, ending 

the year at $3.7 billion. 

•	 Made significant oil discovery in Kurdistan. 

2013 Guidance Summary

Executing a focused and disciplined capital 

spending program:

•	 $3 billion capital budget, a 25% reduction from 2012.

•	 90% of capital directed at liquids and international gas.

•	 The majority of capital will be spent in our two core regions.

Replacing low-margin North American natural gas with higher 

margin barrels:

•	 375,000-395,000 boe/d production target for 2013.

•	 Liquids weighting expected to increase from 35% to 40%.

Liquids momentum carries into 2014.

•	 High netback international gas expected to account for 

25% of production.

•	 Cash flow expected to be approximately $2.5 billion.*

2012 asset sales account for the majority of the reduction 

from last year. 

•	 Six core properties account for 60% of cash flow.

Taking steps to unlock net asset value:

•	 $2-3 billion of dispositions or joint ventures planned for the 

next 12-18 months.

$1-1.5 billion in North America. Actively marketing North 

Duvernay shale and parts of the Montney.

$1-1.5 billion of international assets.

•	 Options for proceeds include debt reduction and increasing 

cash flow per share through short-term development spending 

or share repurchases.

* assumes $90/bbl WTI oil, $105/bbl Brent oil, $3.60/mmbtu 

NYMEX natural gas.
2 TALISMAN ENERGY ANNUAL REPORT 2012

As our Chairman Chuck Williamson said in his letter, 

Talisman is a company with tremendous potential in 

two core regions, Asia-Pacific and the Americas.”

Over the past five years, Talisman has 

established significant positions in North 

American shale gas, developed long-life 

assets in Asia-Pacific and discovered large 

accumulations of oil and gas in Kurdistan 

and Papua New Guinea. Unfortunately, 

capital expenditures significantly outpaced 

cash flow, production growth did not 

materialize, costs increased more than 

expected and North American natural gas 

prices fell precipitously. 

The Board felt that a quick and decisive 

change was needed and I was appointed 

CEO in September 2012, after serving 

two years as an independent member 

of the Board. Since September, I have 

developed a detailed understanding of 

the company, our assets, our people, 

our strengths and weaknesses and the 

challenges we face. I have also met with 

many Talisman shareholders and I am 

grateful for their insights.

In the last six months, working with my 

Talisman colleagues, we have refined our 

strategies and developed a business plan 

that will improve performance, unlock value 

from undeveloped assets and improve 

shareholder returns. We will improve 

performance through an unwavering focus 

on operational excellence – doing things 

better, faster, safer and at lower cost. We will 

focus scarce capital resources on 

opportunities that deliver shareholder value 

more quickly and predictably. We will unlock 

value by shedding undeveloped assets that 

are not recognized in our current share 

price. We are committed to improving 

shareholder returns, and we are committed 

to doing so quickly.

In October of 2012, I set out four strategic 

priorities to significantly increase total shareholder returns. Here are the priorities and 

some specific steps we are taking in 2013:

First, we will live within our means. 

We are reducing our capital program 

by 25% in 2013 and layering on more 

commodity price hedges to reduce cash flow 

volatility. A reduction in our capital program 

was essential, and we moved quickly to 

define a $3 billion investment program that 

would sustain flat production in our core 

regions and fund highly selective growth 

programs. We will maintain a strong balance 

sheet, with financial flexibility to increase 

development activity in the event of higher 

natural gas prices or exploratory success.

Second, we will focus our capital 

program to turn opportunities into cash 

flow more quickly. 

We will invest in projects with higher 

netbacks and shorter cycle times, capable 

of delivering sustainable cash flow. 

A smaller capital program will cause us to 

focus our scarce dollars on the very best 

opportunities – in 2013, we will direct 90% 

of our investment program to liquids and 

immediate cash flow opportunities. We 

will sustain and grow our production base 

through production optimization, reservoir 

exploitation, bolt-on acquisitions and highly 

selective exploration.

Going forward, we will focus our efforts 

and expertise on our best assets in two 

core areas, the Americas and Asia-Pacific. 

In North America, we believe we can 

double our liquids volumes over the 

next few years – adding significant 

value – starting from a base of 30,000 

barrels per day. In Colombia, we have 

opportunities to double production 

to 40,000 barrels per day through 

development of deep foothills gascondensate reservoirs and Llanos Basin 

heavy oil pools. I am pleased to see a 

number of our long-delayed regulatory 

approvals coming through in Colombia, 

and we look forward to significant 

production growth over the next two years. 

North American natural gas volumes 

(38% of our total 2012 production) 

will decline by approximately 20% this 

year, with spending directed to holding 

strategic acreage. We have built a 

large asset base with significant gas 

development upside, but we will not 

invest to grow production until we can 

lock in forward prices to deliver positive 

full-cycle margins.

Letter from Hal Kvisle

President and Chief Executive Officer
TALISMAN ENERGY ANNUAL REPORT 2012 3

“We will exit 2013 a stronger, more focused company.”

With long-life properties at PM-3 and 

Corridor and near-term development 

projects underway, we expect to grow 

production and value in Asia-Pacific while 

generating more than $400 million of free 

cash flow per year.

Our third priority is to achieve operational 

excellence in all parts of our business. 

Winning strategies in the upstream 

sector are always driven by topquartile cost performance. Superior 

development, onstream and production 

costs are driven by tight cost control, 

strong reserve additions and strong, 

sustainable production rates. Talisman has 

demonstrated operational excellence in the 

Marcellus shale, with highly competitive 

costs and excellent reserves and 

production per well. We have sharpened 

our drilling performance in the Montney 

gas play, and we are now focused on Eagle 

Ford drilling and completions costs. In 

all parts of our business, we will strive to 

demonstrate operational excellence and 

strong, full-cycle returns.

We are looking closely at overhead costs 

in Calgary and in our operating regions. 

Over the past several years, we have seen 

G&A costs increase significantly as we 

staffed-up in anticipation of a much larger 

production base. We will lower our annual 

G&A run rate by approximately 20% by the 

end of this year through office closures, 

staff reductions, fewer consultants and 

cost reductions across the board. 

And our fourth priority is to unlock net asset 

value in all regions. 

There is a lot of value hidden in properties 

that currently deliver little or no cash. 

Talisman has amassed a much larger 

development portfolio than we can 

currently fund, and we are examining 

opportunities to sell $2-3 billion of noncore assets over the next 12-18 months.

For example, we have large contingent 

resource positions in our Montney 

and Duvernay shale plays in Western 

Canada, together with large undeveloped 

oil in Kurdistan and large undeveloped 

natural gas in Papua New Guinea. In 

addition, we have many smaller assets, 

both undeveloped and producing, in 

various parts of the world. We will work to 

monetize the value of these assets over the 

next 12-18 months.

There is also value in more consistent 

performance and delivering on promises. 

Talisman trades at a discount to net 

asset value, in part because our 

performance has been difficult to 

predict. We have struggled with erratic 

production in the North Sea; however 

as a result of the divestment to Sinopec, 

the North Sea now accounts for less than 

12% of our production. Going forward, 

we are determined to deliver more 

consistent results.

If North American natural gas prices 

strengthen, we are well positioned to 

capture value. Talisman holds large, 

high-quality land positions in some of 

the best natural gas plays in Canada and 

the United States. Wellhead netbacks 

are currently insufficient to fund drilling 

and development in most parts of North 

America, and we do expect gas prices 

to rise as drilling slows and demand 

continues to grow. With a strong focus on 

both costs and production, Talisman is well 

positioned to capture value as and when 

natural gas prices recover.

We will exit 2013 a stronger, more focused 

company. We have the assets, the people, 

and the competitive strengths to create 

significant value for shareholders. As we 

grow cash flow, our options to deliver 

value to shareholders will increase through 

asset growth, increased dividends, share 

buybacks or debt reduction. 

I’d like to thank our shareholders for their 

patience and confidence in our company, 

our Board for its decisive actions and 

support, and most of all our employees for 

their unwavering commitment, loyalty and 

hard work through a very difficult year.

Hal Kvisle

President & Chief Executive Officer
4 TALISMAN ENERGY ANNUAL REPORT 2012

Addressing the Issues

We have Stabilized 

the Company

We’ve reduced debt by about $750 million 

over the course of 2012. We will maintain a 

strong balance sheet going forward, with a 

target debt-to-cash flow ratio of 1.5 times. 

We are increasingly protecting our capital 

program through hedging.

We are A More

Focused Company

Talisman has two core areas: Asia-Pacific 

and the Americas (North America and 

Colombia), which account for 

approximately 90% of our production and 

85% of our 2P reserves. We will continue 

to strengthen and high-grade our assets 

within this core. For other areas, we are 

examining all options, including harvesting 

cash flow, ongoing development, joint 

venture opportunities or sale.

We are Unlocking the Net

Asset Value (NAV) in our

Portfolio

We expect to sell (or joint venture) 

$2-3 billion of non-core assets over the 

next 12-18 months to unlock NAV not 

currently reflected in our share price. 

We are actively marketing our stake in 

both the North Duvernay shale play and 

parts of our Montney position.

WE ARE BUILDING OIL 

AND LIQUIDS MOMENTUM IN 

2013, WHICH WILL CONTINUE 

INTO 2014

Talisman has a large inventory of liquids 

and high netback international gas 

opportunities within the existing portfolio. 

In 2013, approximately 90% of our capital 

program is directed at these cash flow 

generating opportunities. We plan to 

grow five key liquids projects, currently 

producing 10,000 bbls/d, to approximately 

65,000 bbls/d in 2014.

Operational Excellence

and Capital Efficiency

ARE Top PrioritIES

We will improve all aspects of our cost 

structure, with the objective of increasing 

cash margins on every barrel we produce. 

A major focus will be to continue to 

improve drilling performance in the Eagle 

Ford. Significant progress has been 

made over the past two years, and we will 

continue to lower costs and reduce drilling 

times. Talisman is also taking steps to 

reduce our run rate for net general 

and administrative (G&A) costs by 

$100-150 million by the end of 2013.

We are quickly moving to strengthen and focus 

our company by imposing strict capital discipline, 

increasing the cash margins on the barrels we produce, 

and unlocking value through asset sales or strategic 

joint ventures. Our focused capital program targets 

high-margin, near-term opportunities in our two 

core areas. We will be less reliant on asset sales 

to fund core capital programs in 2013. As a result, 

once we execute planned sales or joint ventures, 

we will have the option of using proceeds to pay 

down debt, or increase cash flow per share 

through incremental short-term development 

spending, or share repurchases.””Hal Kvisle, President and CEO
TALISMAN ENERGY ANNUAL REPORT 2012 5

IN OCTOBER 2012, TALISMAN SET FOUR STRATEGIC PRIORITIES, ALONG WITH ACTIONS AND OUTCOMES. 

PRIORITY 1 – LIVE WITHIN 

OUR MEANS. 

We will set capital spending 

budgets that can be largely funded 

by operating cash flows. We will 

maintain balance sheet strength 

so that we are able to respond to 

quality investment opportunities 

within our core regions.

We have set a capital budget of 

$3 billion in 2013, a reduction of 25%. 

•	 We have set our 2013 capital budget 

at approximately $3 billion, down 

from $4 billion in 2012 and against a 

current investment opportunity set of 

$4.5 billion.

•	 Going forward we will be less 

reliant on asset sales to fund our 

capital programs. 

Priority 2 – focus our

capital program. 

We will invest in projects 

(focused in our two core regions) 

that come onstream more quickly, 

and deliver sustainable cash flow 

over the longer term. We will 

reduce upfront capital invested in 

high-risk exploration.

The 2013 capital program will focus on 

near-term, higher netback opportunities. 

Exploration spending has been cut in 

half, and is directed primarily at proving 

up substantial oil potential in Colombia, 

Kurdistan and Asia-Pacific. Long-dated 

exploration spending in 2013 is expected 

to account for only about 5% of Talisman’s 

total capital spend. 

•	 We are directing the majority of 

2013 capital towards our two core 

areas: the Americas (North America 

and Colombia) and Asia-Pacific. 

Approximately 90% of capital will 

be aimed at near-term liquids and 

international natural gas production. 

•	 In North America and Colombia, 

Talisman will invest to double liquids 

production over the next few years.

•	 The Asia-Pacific region is expected 

to grow at around 8% per annum over 

the medium-term, generating over 

$400 million per year in free cash flow.

•	 Our liquids weighting is expected 

to increase from 35% in 2012 to 

approximately 40% in 2013.

* includes Algeria

TWO CORE REGIONS: AMERICAS AND ASIA-PACIFIC*

~90%

of production

2013 production 

375-395 mboe/d

2012 2P reserves 

1.7 billion boe

RLI ~ 12 years

~85%

of 2P reserves 

2012 COGEH 2P value 

~ $14 billion

~90%

of COGEH 

2P value

2012 contingent 

resource 

6.7 billion boe

~95%

of contingent 

resource

2012 unrisked 

prospective

resource 

3.1 billion boe

~85%

of unrisked 

prospective 

resource

Our top six assets will produce ~60% of 2013 

cash flow: Corridor, PM-3, Marcellus, Colombia, 

Eagle Ford and Vietnam.
6 TALISMAN ENERGY ANNUAL REPORT 2012

Priority 3 – improve operational performance and reduce

cost structure. 

We will do things better, faster, safer and at lower cost. Our aim 

is to enhance project execution and to improve margins on every barrel 

we produce. 

Talisman is reviewing all aspects of 

our cost structure. In 2013, we are 

taking actions to reduce general and 

administrative (G&A) costs, and will 

continue to improve drilling performance 

in the Eagle Ford. 

•	 We expect to reduce our run rate for 

G&A costs by $100-150 million by the 

end of 2013. This will be achieved 

through office closures, country exits, 

decreased consulting and IT expenses, 

lower travel and general costs, and staff 

reductions (based on a more focused 

activity set).

•	 We will continue to target significant 

drilling improvements in the Eagle Ford 

shale play in 2013. We have made 

significant improvements in drilling 

cycle times and D&C costs per well. 

•	 We are spending joint venture dollars 

to improve operating efficiency and 

reliability in the North Sea.

In the Eagle Ford, we have made significant 

improvements in drilling cycle times and D&C 

costs per well. In 2013, we expect to make 

further progress as we move to a more efficient 

‘factory’ mode, by increasing our pad drilling 

capability and zipper fracking completions.

We have demonstrated 

operational excellence in 

the Marcellus, sharpened 

drilling performance in the 

Montney and we are now 

focused on the Eagle Ford.
TALISMAN ENERGY ANNUAL REPORT 2012 7

Priority 4 – unlock net asset value of the portfolio. 

Talisman’s asset base includes large positions in several long-dated 

plays that generate little to no cash flow. We will surface value for 

shareholders. We will continue to high-grade our portfolio and consider 

divestments and joint ventures where underlying asset values are not 

reflected in our share price. 

For example, we formed joint ventures 

in PNG and parts of our Montney play 

and reduced our exposure to the UK 

North Sea. These actions helped us to 

realize value and allowed us to focus on 

opportunities in our core regions. We have 

a portfolio of valuable, tradeable assets 

that we will monetize or continue to hold 

in an opportunistic fashion. 

•	 Our target is to unlock $2-3 billion 

in value through asset sales or 

joint-ventures – both internationally 

and in North America – over the next 

12-18 months. 

•	 We are marketing our positions in 

the North Duvernay and parts of the 

Montney in North America and will 

examine international options including 

the North Sea.

•	 In PNG and Kurdistan, we will 

continue exploration and appraisal 

drilling to establish the extent of the 

resource base before looking at ways 

to unlock value. 

Talisman has a large resource position in North 

America, including the Montney where we 

have 28 tcf of net contingent resource with 

over 5,000 net well locations. We are currently 

marketing our North Duvernay play and 

portions of our Montney acreage, and expect 

to raise $1-1.5 billion through a sale or joint 

venture in the next 12-18 months.

We have a portfolio of 

valuable, tradeable assets 

that we will monetize or 

continue to hold in an 

opportunistic fashion.
8 TALISMAN ENERGY ANNUAL REPORT 2012

ASIA-PACIFIC

AMERICAS

FOCUS AREAS

South Duvernay 

North America Operations

We are committed to long-term growth and value 

creation within two core regions: the Americas (North 

America and Colombia) and Asia-Pacific. In North 

America, we have the flexibility to adjust our 

spending profile to take advantage of liquids and 

natural gas opportunities. In Colombia, we are growing 

in an oil-prone basin and have secured access to key 

infrastructure. In the Asia-Pacific region, we have a 

large and growing portfolio, established relationships 

with host governments, all in a part of the world 

characterized by strong market demand and relatively 

high commodity prices.
TALISMAN ENERGY ANNUAL REPORT 2012 9

THE AMERICAS – 

LARGE RESOURCE BASE 

AND LIQUIDS-RICH 

OPPORTUNITIES

North America

Talisman is well positioned in five leading 

plays in North America, with over 35 tcfe 

(approximately 6 billion boe) of contingent 

resource in an area of 1.3 million net 

acres. We have material positions in 

three liquids-rich plays and upside 

exposure in two of the best dry gas plays 

in North America. 

A significant portion of this resource base 

is located in our Canadian heritage region, 

which stretches from Fort St. John in 

northeastern British Columbia to Edson in 

west-central Alberta. Here, we have a large, 

contiguous land base, providing extensive 

running room. This land is supported by 

company-operated midstream infrastructure.

Talisman has established itself as a top-tier 

operator in the Marcellus shale play with 

5 tcf of contingent resource and an estimated 

1,600 prospective drilling locations. The play 

is currently self-funded and provides material 

upside with an increase in North American 

natural gas prices.

In the current low natural gas price 

environment, we have sharpened our 

focus in North America in 2013, reducing 

spending on dry gas plays. Our short-term 

priority is to continue to develop the 

liquids-rich Eagle Ford shale play, where 

production growth combined with capital 

and operating efficiency improvements 

will deliver considerable cash flow from 

this high-cash margin play.

In addition, our 2013 priorities for North 

America include drilling to hold strategic 

land positions in some of our dry gas plays. 

We will also seek to monetize assets with 

minimal cash flow and high net asset 

values, specifically the Montney and North 

Duvernay plays. 

Key drivers in 2013

We plan to spend approximately 

$1.1 billion in our core North American 

business in 2013 – a decrease of roughly 

30% from the previous year. Approximately 

80% of capital is being allocated to three 

liquids-rich plays, with a significant 

reduction in spending on dry gas plays. 

This activity set positions Talisman to 

double its North American liquids 

production over the next few years. 

In the Eagle Ford, we will continue to focus 

on liquids-rich parts of the acreage and 

we are increasing pad drilling in 2013. 

We have built a secure egress position and 

we entered the year with 50 uncompleted 

wells, which we plan to complete and tie-in. 

In the liquids-rich Duvernay shale, we 

hold approximately 350,000 net acres. 

We recently completed a well reporting 

one of the highest liquids ratios in the play 

and we plan to continue appraisal drilling 

in 2013.

At Wild River, we are growing NGL volumes 

through development of this multi-zone play, 

with a new Deep Cut liquids extraction 

facility that should be operational by the 

end of this year. 

In the Montney, the majority of the capital 

program is funded by our joint venture 

partner. Here, we will continue to assess 

and appraise the property and continue to 

develop the liquids-rich eastern part of the 

play. We will also invest capital at Edson to 

maintain mineral rights and assess 

liquids-rich opportunities. 

In the Marcellus shale, we will selectively 

spend capital to hold strategic core 

acreage positions.

Colombia

In the three years since the Equion joint 

venture, we have drilled some exciting 

exploration wells, completed a successful 

stratigraphic program – which indicates 

large heavy oil potential – and secured 

interest in a key pipeline to access markets. 

With these activities, we have moved into 

the development phase. 

We have three key areas in Colombia: 

the Equion joint venture (with the 

Piedemonte complex), the heavy oil region 

(Block CPO-9 and CPE-6), and the Ocensa 

pipeline. Part of Talisman’s Niscota license 

(adjacent to Piedemonte), and operatorship 

is being transferred to Equion. We plan 

to spend approximately $250 million on 

exploration and development activities in 

Colombia in 2013. 

The majority of production comes from 

Piedemonte within our Equion joint 

venture. In 2012, daily production from 

Colombia averaged 17,000 boe/d of 

high netback liquids and natural gas. In 

2013, we will continue to progress toward 

Piedemonte Phase II facilities expansion. 

Exploration activities in the Niscota Block 

continue with imminent flow testing of the 

Huron-2 well and ongoing drilling of the 

Huron-3 well. 

In the heavy oil region, we have secured 

the Exploration Environmental License 

for CPO-9, allowing us to move forward 

with a seven-well Akacias appraisal 

program with the intention of flowing 

wells on extended well tests in 2013. An 

exploration well in the Lorito prospect 

is also planned. In CPE-6, 3D seismic 

is ongoing. Upon license approval, we 

will drill and flow test three wells prior to 

proceeding toward development activity. 

While we have made progress on securing 

permits, permitting delays continue to 

affect the pace of development. 

Talisman now has a 12.15% ownership 

position in the Ocensa pipeline and 

approximately 55,000 bbls/d of capacity, 

plus an additional 13,900 bbls/d through 

Equion. Ocensa is now a profit centre for 

the company, generating dividends from 

our ownership position and marketing/

capacity fees from oil transport capacity 

that is in short supply in the Llanos Basin. 

As Talisman’s production from Blocks 

CPO-9, CPE-6 and the Niscota Block 

ramp up, we will have access to the 

export facilities on the Caribbean coast. 

Monetization of all or part of our Ocensa 

pipeline equity is also an option.
10 TALISMAN ENERGY ANNUAL REPORT 2012

ASIA-PACIFIC – 

HIGH NETBACK 

SELF-FUNDED GROWTH

Asia-Pacific is characterized by rapid 

economic growth supporting strong 

energy demand. Talisman’s portfolio in the 

region is anchored by projects at Corridor 

(South Sumatra, Indonesia) and PM-3 

CAA (Malay Basin, offshore Malaysia/

Vietnam), which are connected to high 

netback natural gas markets through 

existing pipeline infrastructure. We have 

been operating in the region for 20 years 

and have demonstrated our operating 

capability with a strong track record 

of consistent, safe delivery. We have 

established close working relationships 

with host governments and national oil 

companies to take full advantage of the 

region’s investment opportunities. The 

company is on track to deliver average 

production growth of approximately 

8% per annum over the medium term, 

and the region is expected to contribute 

over $400 million annually in free cash 

flow to Talisman.

Key drivers in 2013

Total capital spending in the region 

is expected to be approximately 

$650 million, with five projects 

accounting for 85% of the total. 

The focus of the Malay Basin is long-life 

production and cash flow. The PM-3 

CAA fields are characterized by multiple 

stacked reservoirs, which offer significant 

opportunities for increased recoveries. In 

the near term, we will maintain production 

through infill drilling, well interventions, 

and continuous operations improvements. 

We are currently in discussion with key 

stakeholders with respect to an extension 

of the current PM-3 CAA license, with 

the blocks expiring in 2017 and 2018. 

In addition, we are looking for near-field 

exploration opportunities. 

Talisman’s acreage in the Sabah Basin 

provides access to low-cost discovered 

oil and gas reserves, with extensive 

infrastructure in place. In late 2012, we 

took over operatorship of the Kinabalu 

field and will seek to enhance production 

through workovers, development drilling, 

and enhanced oil recovery techniques. 

We hold two large exploration licenses next 

to Kinabalu where new 3D seismic has 

identified potential hydrocarbons, and two 

exploration wells will be drilled in 2013. 

In Indonesia, the South Sumatra area 

includes key assets such as Corridor 

and Jambi Merang. At Corridor, the 

company has a very large natural gas 

reserve base. Here, we continue to 

invest in development opportunities, 

including proving up additional reserves 

to potentially allow sanction of another 

production train at the Suban field. 

At Jambi Merang, we will invest to 

maintain a high level of operating 

efficiency and consider expanding into 

the next development phase.

In Vietnam, Talisman is completing the 

HST/HSD field development, which is 

expected to come onstream in the second 

half of 2013 with net production expected 

at approximately 10,000 boe/d. 

In PNG, we are continuing our gas 

aggregation strategy across our large land 

position, with potential of up to 20 tcf of 

undiscovered petroleum initially in place 

(unrisked). Our principal partner, Mitsubishi, 

brings funding and LNG expertise. In the 

near term, we will high-grade our land 

position to maintain quality and focus, while 

we execute the Stanley condensate recovery 

scheme with the goal of bringing on first 

production in late 2014 at the earliest. 

~8% growth per annum

over the medium term. 

Expected to contribute 

over $400 million annually

in free cash flow to Talisman.

Talisman has been operating in the Asia-Pacific 

region for 20 years, and has demonstrated its 

operating capability with a strong track record 

of consistent, safe delivery.
TALISMAN ENERGY ANNUAL REPORT 2012 11

OTHER OPERATING 

AREAS

The North Sea 

The North Sea is an oil-based portfolio in 

a strong Brent oil price environment. With 

20 years of operating experience in the 

basin, Talisman has focused on operating 

late-life, mature fields. In recent years, 

we have not invested adequate capital in 

the UK, which has contributed to asset 

reliability challenges as well as reduced 

production capability. 

Recognizing the need for additional 

capital and looking to reduce our 

exposure to inherent production volatility, 

Talisman sold a 49% working interest in 

our UK assets to Sinopec for $1.5 billion 

in late 2012.

Key drivers in 2013 

This transaction enables increased 

investment by the joint venture in the 

UK North Sea, while allowing Talisman 

to reduce net spending. In 2013, 

investments will be made to improve 

operational efficiency in the UK and to 

execute economic redevelopment and life 

extension projects. 

Redevelopment of the Montrose area – 

including facilities upgrades, development 

drilling, and the tie-back of undeveloped 

fields – accounts for approximately 

one-half of our UK North Sea spending 

this year. Investment will also be directed 

to infill drilling, water injection, platform, 

and subsea upgrades. We will also 

re-examine the possibility of developing 

the Auk South field. 

In Norway, spending will be focused at 

Brage and Varg, including development 

drilling, field extensions, near-field 

exploration and the Varg gas export project. 

In 2012, the Yme project experienced 

significant delays, quality issues and cost 

overruns. Given the uncertainty of the 

timing of first oil, Talisman removed Yme 

from its forward production projections and 

recorded impairment losses.

Talisman’s overall capital spending in the 

region is expected to be about one-third 

less in 2013, after accounting for the joint 

venture. Our strategy across the North 

Sea is to optimize value through near-term 

opportunities, while driving safe, efficient, 

and reliable operations.

Kurdistan Region of Iraq

Talisman operates two blocks in the 

Kurdistan Region of Iraq: Kurdamir and 

Topkhana. Kurdistan is a world-class 

exploration opportunity in an underexplored basin. In 2012, we made a 

significant oil discovery in Kurdamir. 

Talisman’s net 2C contingent resources in 

Kurdamir/Topkhana today are 

114 mmbbls of liquids and 1.5 tcf of 

natural gas. Further appraisal drilling 

is targeted at proving the significant oil 

upside that exists. We currently estimate 

329 mmbbls and 1.2 tcf of net unrisked 

prospective resource.

One of our key priorities this year is to 

recognize value in our portfolio. To do 

so, we will continue exploration and 

appraisal drilling to establish the extent 

of the resource base in Kurdistan. 

In 2013, we will drill two wells: 

Kurdamir-3 to evaluate the extent of 

the oil column, and a second well at 

Topkhana. Once these drilling programs 

are completed, we will consider all options 

to unlock value in this asset.

In 2012, Talisman made a significant 

oil discovery in Kurdistan. In 2013, 

the company will continue exploration 

drilling to establish the extent of the resource 

before looking at ways to unlock value.
12 TALISMAN ENERGY ANNUAL REPORT 2012

CORPORATE RESPONSIBILITY

We have a track record of high standards in terms 

of how we do business around the world – a testament 

to the efforts of our leaders and employees who take 

steps to ensure we are a partner of choice in many 

areas. We strive to be welcomed by governments, 

communities and peers around the globe.”

SAFETY

Safe operations are a top priority. We 

continuously set improvement targets, 

assess performance and enhance policies 

and processes to develop and evolve best 

practices. Our goal is to create a work 

environment where we cause no harm to 

people, and we engineer, construct and 

operate our businesses to prevent major 

accidents. The visible commitment of our 

leadership and people at all levels of our 

organization helps embed a safety-focused 

culture. Each year, through our annual 

CEO Safety Awards, individuals and teams 

from around our global operations are 

recognized for their significant health, 

safety and environmental achievements.

PEOPLE

The talent, commitment, and technical 

and commercial expertise of our nearly 

3,700 employees are integral to our 

success. We develop our people through 

challenging work in a fast-paced, engaging 

environment, and provide opportunities for 

personal and career development through 

a combination of structured technical 

and leadership development programs. 

We work to ensure the right people are 

located in the part of the business where 

they can add the most value, and where 

possible, employees have the opportunity 

to transition their skills into new roles and 

international locations.

COMMUNITIES

With safe operations as a foundation, 

our community and stakeholder 

relations activities are integral to our 

being accepted and welcomed into the 

communities where we operate. We 

work alongside these communities, 

outlining our plans, and listening to and 

addressing any concerns. We employ 

highly experienced people who work with 

communities to minimize the impact 

of our operations and maximize the 

benefits of our presence. Globally, we 

focus our investments in the areas of 

education, environment and empowering 

communities. 

To learn more about our corporate 

responsibility activities, please visit 

www.talisman-energy.com.

IMPROVING NORTH AMERICAN

HSE FOUNDATIONS

(Per million exposure hours)

2010 2011 2012

Total Recordable Spills

Injury Frequency

0

2

4

6

8

0

1

2

3

4
TALISMAN ENERGY ANNUAL REPORT 2012 13

628

Asia-Pacific

2,171

The Americas

889

Rest of World

TALISMAN PERMANENT EMPLOYEES:

3,688*

*Total permanent employees as at December 31, 2012. Includes our joint 

venture partnership in the UK North Sea – Talisman Sinopec Energy UK Limited.

In our 2012 employee survey, 75% of employees said they 

believe they have the opportunity for personal development 

and growth at Talisman. This is an increase of 2% from our 

2010 survey, and 9% higher than our peers.
14 TALISMAN ENERGY ANNUAL REPORT 2012

Management’s Discussion and Analysis 15

Company Overview 15

2012 Performance Highlights 16

Financial and Operating Highlights 16

2012 Net Income Variances 17

Operations Review 18

Asset Disposals 27

Farm Outs 28

Acquisitions 28

Reserves at December 31 28

Liquidity and Capital Resources 29

Sensitivities 31

Commitments and Off Balance Sheet Arrangements 31

Transactions with Related Parties 32

Risk Management 32

Summary of Quarterly Results 34

Strategy and Outlook 35

Internal Control over Financial Reporting and Disclosure Controls 

and Procedures 36

Legal Proceedings 36

Application of Critical Accounting Policies and Use of Estimates 37

Accounting Changes 40

Regulatory Developments 42

Risk Factors 42

Report of Management 51

Management Report on Internal Control over Financial Reporting 51

Independent Auditors’ Report on Internal Controls Under 

Standards of the Public Company Accounting Oversight 

Board (United States) 52

Independent Auditors’ Report of Registered Public 

Accounting Firm 53

Consolidated Balance Sheets 54

Consolidated Statements of Income 55

Consolidated Statements of Comprehensive Income 56

Consolidated Statements of Changes in Shareholders’ Equity 57

Consolidated Statements of Cash Flows 58

Notes to the Consolidated Financial Statements 59

Supplementary Oil and Gas Information 104

Results of Operations from Oil and Gas Producing Activities 104

Capitalized Costs Relating to Oil and Gas Activities 105

Costs Incurred in Oil and Gas Activities 106

Discounted Future Net Cash Flows 107

Standardized Measure of Discounted Future Net Cash Flows 

from Proved Reserves 109

Principal Sources of Changes in Standardized Measure of 

Discounted Future Net Cash Flows 110

Continuity of Net Proved Reserves 111

Additional Information 113

Consolidated Financial Ratios 113

Ratios and Key Indicators 113

 Historical Operations Summary 114

Net Production – After Royalties 115

Product Netbacks – After Royalties 116

 Historical Gross Proved Reserves 118

Continuity of Gross Proved Reserves 119

Detailed Property Reviews 121

2012 Acreage 121

2012 Drilling Activity 122

Five Year Drilling Results 123

Advisories 124

Abbreviations and Definitions 128

Governance 129

Investor Information 130

Corporate Information 131

Market Information 134

FINANCIAL PERFORMANCE
(March 6, 2013)

This Management’s Discussion and Analysis (MD&A) should be read in conjunction with the Consolidated Financial Statements of

Talisman Energy Inc. (Talisman or the Company) for the year ended December 31, 2012. The Company’s Consolidated Financial

Statements and the financial data included in this MD&A have been prepared in accordance with International Financial Reporting

Standards (IFRS), unless otherwise noted.

Unless otherwise stated, references to production and reserves represent Talisman’s working interest share (including Talisman’s

share of volumes of royalty interest) before deduction of royalties. Throughout this MD&A, the calculation of barrels of oil equivalent

(boe) is calculated at a conversion rate of six thousand cubic feet (mcf) of natural gas to one barrel (bbl) of oil. The boe measure may

be misleading, particularly if used in isolation. A boe conversion ratio of 6 mcf:1 bbl is based on an energy equivalence conversion

method primarily applicable at the burner tip and does not necessarily represent a value equivalence at the wellhead.

All comparisons are between the years ended December 31, 2012 and 2011, unless stated otherwise. All amounts presented are in

US$, except where otherwise indicated. Abbreviations used in this MD&A are listed in the section ‘Abbreviations and Definitions’.

Additional information relating to the Company, including the Company’s Annual Information Form (AIF), can be found on the

Canadian System for Electronic Document Analysis and Retrieval (SEDAR) at www.sedar.com. The Company’s Annual Report on

Form 40-F may be found in the Electronic Data Gathering, Analysis, and Retrieval (EDGAR) database at www.sec.gov.

Effective January 1, 2011, the Company changed its reporting currency from C$ to US$. This change to US$ reporting recognizes the

fact that a significant portion of the Company’s activities and transactions are conducted in US$. Accordingly, all financial amounts in

this MD&A are presented in US$ unless otherwise indicated.

Effective January 1, 2011, the composition of the Company’s segments changed such that activities in the UK and Norway are now

reported as a single ‘North Sea’ segment. This change reflects the fact that, since 2011, the UK and Norway businesses each operate

a mature set of cash-generating assets sharing similar economic characteristics. Comparative period balances have been restated

accordingly.

Talisman Energy Inc. is a global upstream oil and gas company, headquartered in Canada. Talisman has three main operating areas:

the Americas (North America and Latin America), Southeast Asia and the North Sea, with an active exploration program across all

three. Talisman is committed to conducting business safely, in a socially and environmentally responsible manner, and is included in

the Dow Jones Sustainability (North America) Index. Talisman is listed on the Toronto Stock Exchange and New York Stock Exchange

under the symbol TLM.

Unless the context indicates otherwise, references in this MD&A to ‘Talisman’ or ‘the Company’ include, for reporting purposes only,

the direct or indirect subsidiaries of Talisman Energy Inc. and partnership interests held by Talisman Energy Inc. and its subsidiaries.

Such use of ‘Talisman’ or ‘the Company’ to refer to these other legal entities and partnership interests does not constitute a waiver by

Talisman Energy Inc. or such entities or partnerships of their separate legal status, for any purpose.

Talisman’s financial statements are prepared on a consolidated basis and include the accounts of Talisman and its subsidiaries.

Substantially all of Talisman’s activities are conducted jointly with others, and the Consolidated Financial Statements reflect only the

Company’s proportionate interest in such activities.

Note 31 to the Consolidated Financial Statements provides segmented financial information that forms the basis for much of the

following discussion and analysis. In 2012, Talisman’s activities were conducted in four geographic segments for the purposes of

financial reporting: North America, Southeast Asia, North Sea and Other. The North America segment includes operations in Canada

and the US. The Southeast Asia segment includes operations and exploration activities in Indonesia, Malaysia, Vietnam and Papua

New Guinea and non-operated production in Australia/Timor-Leste. The North Sea segment includes operations and exploration

activities in the UK and Norway. The Company also has non-operated production in Algeria, operations and exploration activities in

Colombia, and exploration activities in Sierra Leone and the Kurdistan Region of Iraq. In 2012, the Company decided to exit Peru and

expects to complete the process in 2013. For ease of reference, the activities in Algeria, Colombia, Peru, Poland, Sierra Leone and the

Kurdistan Region of Iraq are referred to collectively as the Other geographic segment or rest of the world.

TALISMAN ENERGY ANNUAL REPORT 2012

MANAGEMENT’S DISCUSSION AND ANALYSIS (MD&A)

General

Change in Reporting Conventions

Company Overview

15
Hal Kvisle was appointed President and Chief Executive Officer on September 10, 2012, and has set four strategic priorities for

the Company;

Production was 426,000 boe/d, exceeding guidance. Liquids growth in Southeast Asia, Colombia and the Eagle Ford, and higher

gas volumes in North America offset North Sea declines.

Fourth quarter net income was $376 million, compared to a loss of $117 million the previous year. Net income for the year was

$132 million, compared to $776 million in 2011.

The Company completed approximately $2.5 billion in asset sales, including the sale of a 49% equity interest in Talisman’s UK

North Sea business to China Petrochemical Corporation (Sinopec) for $1.5 billion.

In Southeast Asia, Talisman assumed operatorship of the Kinabalu PSC in Malaysia in December.

The Company announced a significant oil discovery in Kurdistan.

(millions of $, unless otherwise stated) 2011 2010

Cash provided by operating activities 2,812 3,144

776 945

277 249

– –

0.76 0.93

0.38 0.93

US$ 0.27 C$ 0.25

– –

426 417

383 343

65.35 53.80

8,272 6,982

14.17 12.44

2,617 2,275

4,142 3,473

24,226 22,094

4,895 4,204

414 1,653

10,745 9,186

1) In 2012, net income per share includes an adjustment to the numerator for after-tax cumulative preferred share dividends.

2) Diluted net income per share computed under IFRS includes an adjustment to the numerator for the change in the fair value of stock options and after-tax cumulative

preferred share dividends.

TALISMAN ENERGY ANNUAL REPORT 2012

2012 Performance Highlights

Financial and Operating Highlights

2012

2,716

Net income 132

Common share dividends 277

Preferred share dividends 9

Per share ($)

Net income(1) 0.12

Diluted net income(2) 0.01

Common share dividends US$ 0.27

Preferred share dividends C$ 1.10

Production (mboe/d) 426

Production from ongoing operations (mboe/d) 397

Average sales price ($/boe) 58.56

Total revenue and other income 7,312

Operating costs ($/boe) 15.83

Depreciation, depletion and amortization (DD&A) expense, exploration and dry hole expense 3,116

Total exploration and development expenditures 3,511

Total assets 21,858

Total long-term debt (including current portion) 4,442

Cash and cash equivalents, net of bank indebtedness 721

Total long-term liabilities 9,472

16

•

•

•

•

•

•
(millions of $)

2011 net income

Favourable (unfavourable) variances(1):

Total variances

2012 net income

1) Variances are before tax except for current and deferred taxes.

2) In the commentary that follows, the term ‘sales’ refers to the net impact of commodity prices, production volumes and royalties.

The significant variances from 2011, as summarized in the net income variances table, are:

Lower oil and gas revenues reflecting lower commodity prices;

Reduced production in the North Sea driven by planned and unplanned maintenance activities and natural declines, partially offset

by higher volumes from successful developments in North America and the ramp up of new fields in Southeast Asia;

Higher operating expenses due to increased production and the introduction of the Pennsylvania Impact Fee in North America,

higher production in Southeast Asia, combined with increased maintenance costs in the North Sea;

Higher DD&A expense due to increased rates and production from high rate assets and downward reserves revisions in the

fourth quarter;

Higher asset impairments due principally to uncertainty surrounding the Yme project in Norway, a significant drop in reservoir

pressure and reserves at the Rev field in Norway, reserves revision and increased future cost estimates in the UK, the Company’s

decision to exit Peru, lower long-term gas price assumptions and reserves reduction in North America and its decision to not

commit capital in the foreseeable future to certain exploration and evaluation assets, including Quebec and Norway;

A smaller share-based payments recovery relative to the 2011 recovery as a result of movements in Talisman’s share price;

An increase in gain on disposals in 2012, reflecting the sale of non-core oil and gas properties in North America along with the

Company’s divestiture of a 49% equity interest in Talisman Energy (UK) Limited (TEUK) on December 17, 2012;

Gain on revaluation of investment represents the fair value adjustment recorded upon restructuring of the Company’s Colombian

investment in Oleoducto Central S.A. (Ocensa);

A decrease in loss on held-for-trading financial instruments as a result of lower realized losses on Brent collar commodity price

derivatives relative to 2011;

Decreased current taxes due principally to lower production in the North Sea, partially offset by increased revenues in Southeast

Asia; and

A significant deferred income tax recovery in 2012 compared to a tax expense in 2011, as a result of North Sea impairments taken

during 2012, partially offset by the derecognition of deferred tax assets in the US.

TALISMAN ENERGY ANNUAL REPORT 2012

2012 Net Income Variances

776

Commodity prices(2) (527)

Production volumes(2) (510)

Royalties(2) 49

Operating expenses (262)

General and administrative (G&A) expense (79)

DD&A expense (552)

Impairment (2,518)

Dry hole expense (28)

Exploration expense 81

Finance costs 2

Share-based payments recovery (248)

Gain on disposals 1,432

Gain on revaluation of investment 365

Loss on held-for-trading financial instruments 117

Current taxes (including Petroleum Revenue Tax (PRT)) 567

Deferred taxes (including PRT) 1,408

Other 59

(644)

132

17

•

•

•

•

•

•

•

•

•

•

•
Sales of oil, liquids and natural gas in 2012 were $7.2 billion, down 12% from 2011. Oil and liquids revenue decreased by

$648 million due to lower production in the North Sea and lower realized prices in North America and Southeast Asia, partially offset

by higher production in North America and Southeast Asia. Natural gas revenue decreased by $338 million primarily due to lower

realized prices in North America.

In North America, production growth of 11% was offset by lower gas prices resulting in a decrease in sales. DD&A and operating

expenses increased year-over-year.

In Southeast Asia, sales of $2.2 billion were 16% higher than 2011 due principally to a full year of production at the Jambi Merang

and Kitan fields. Operating expenses and DD&A increased year-over-year.

In the North Sea, sales decreased by 27% as a result of lower production. Operational issues associated with the Galley pipeline and

extended turnarounds in the UK along with natural declines at Varg, pressure decline at Rev and base decline on Brage contributed

to this reduction.

In the rest of the world, sales of $623 million were 15% higher than 2011 due to new wells coming online in the Piedemonte region

and increased production from the Cusiana liquefied petroleum gas plant in Colombia, which went into operation in December 2011.

Gross before royalties Net of royalties

2011 2010 2011 2010

Oil and liquids (mbbls/d)

23 23 19 18

34 39 17 22

98 113 97 113

23 14 13 7

178 189 146 160

Natural gas (mmcf/d)

899 778 803 718

506 485 351 339

52 104 52 104

34 – 27 –

1,491 1,367 1,233 1,161

Total Daily Production (mboe/d)

173 153 153 137

119 119 75 78

106 131 106 131

28 14 17 7

Total (mboe/d) 426 417 351 353

Assets sold

8 36 6 31

35 38 34 37

From ongoing operations (mboe/d) 383 343 311 285

Production represents gross production before royalties, unless noted otherwise. Production identified as net is production after

deducting royalties.

TALISMAN ENERGY ANNUAL REPORT 2012

Operations Review

Results Summary

Daily Average Production

2012 2012

North America 27 23

Southeast Asia 42 24

North Sea 71 70

Other 22 14

162 131

North America 985 871

Southeast Asia 524 357

North Sea 31 31

Other 42 33

1,582 1,292

North America 192 168

Southeast Asia 129 84

North Sea 76 75

Other 29 20

426 347

North America 4 3

North Sea 25 25

397 319

18
Production from ongoing operations increased by 4% over 2011 due principally to higher oil and gas volumes in North America and

Southeast Asia, partially offset by lower North Sea production and the sale of non-core assets in North America. Total production

remained flat compared to 2011, despite an underlying shift in the segments from which volumes were produced.

In North America, production from ongoing operations increased by 14%. Oil and liquids production increased 17% mainly due to

successful development in the liquids-rich Eagle Ford shale play, where liquids production averaged nine mboe/d in the current year

and two mboe/d in 2011. Natural gas production increased by 10% due principally to successful development in the Marcellus, Eagle

Ford and Montney shale plays, partially offset by asset dispositions and natural declines in conventional assets.

In Southeast Asia, natural gas production increased by 4% due principally to improved production efficiency at PM-3 CAA, located

between Malaysia and Vietnam, and a full year of production from Jambi Merang. Oil and liquids production increased due principally

to a full year of production from Kitan, partially offset by natural declines and the unitization of the Suban field in late 2011.

In the North Sea, total production decreased 28% compared to 2011. In the UK, production was down due to extended turnaround

activity on Tartan to repair the Galley pipeline and on Auk North to address production efficiency issues, along with natural decline

and reduced well performance on Tweedsmuir. Norway also contributed to the decrease with natural declines at Varg and Brage and

pressure decline at Rev.

In the rest of the world, production from new wells drilled in Colombia accounted for most of the increase over 2011.

2011 2010

Southeast Asia – bbls/d 960 108

(687) (174)

400 237

Total produced into inventory – bbls/d 673 171

Total produced into inventory – mmbbls 0.2 0.1

Inventory at December 31 – mmbbls 1.9 1.6

1) Gross before royalties.

In the Company’s international operations, produced oil is frequently stored in tanks until there is sufficient volume to be lifted. The

Company recognizes revenue and the related expenses on crude oil production when liftings have occurred. Volumes presented in

the ‘Daily Average Production’ table represent production volumes in the period, which include oil volumes produced into inventory

and exclude volumes sold out of inventory.

During the year ended December 31, 2012, volumes in inventory increased from 1.9 mmbbls to 2.2 mmbbls due principally to

increased inventories in Malaysia, Indonesia and Algeria, partially offset by reduced inventories in Norway and Australia.

TALISMAN ENERGY ANNUAL REPORT 2012

Volumes Produced Into (Sold Out of) Inventory(1)

2012

920

North Sea – bbls/d (482)

Other – bbls/d 450

888

0.3

2.2

19
Gross before royalties Net of royalties

2011 2010 2011 2010

Oil and liquids ($/bbl)

107.04 78.19 107.04 78.19

19.69 12.00 – –

1.29 1.15 1.58 1.35

25.72 20.10 31.49 23.74

60.34 44.94 73.97 53.10

Natural gas ($/mcf)

5.92 5.59 5.92 5.59

1.24 0.93 – –

0.24 0.28 0.31 0.34

0.98 1.02 1.24 1.22

3.46 3.36 4.37 4.03

Total $/boe (6mcf=1boe)

65.35 53.80 65.35 53.80

12.54 8.49 – –

1.39 1.45 1.72 1.73

14.17 12.44 17.68 14.81

37.25 31.42 45.95 37.26

1) Netbacks do not include pipeline operations.

During 2012, the Company’s average gross netback was $29.13/boe, 22% lower than in 2011. Talisman’s realized net price of

$58.56/boe was 10% lower than 2011, due principally to lower commodity prices in North America.

The Company’s realized net sale price includes the impact of physical commodity contracts, but does not include the impact of

financial commodity price derivatives discussed in the ‘Risk Management’ section of this MD&A.

TALISMAN ENERGY ANNUAL REPORT 2012

Company Netbacks(1)

2012 2012

Sales price 104.82 104.82

Royalties 20.33 –

Transportation 1.28 1.59

Operating costs 31.25 38.78

51.96 64.45

Sales price 5.01 5.01

Royalties 1.19 –

Transportation 0.25 0.33

Operating costs 1.05 1.38

2.52 3.30

Sales price 58.56 58.56

Royalties 12.18 –

Transportation 1.42 1.79

Operating costs 15.83 20.31

29.13 36.46

20
2011 2010

Oil and liquids ($/bbl)

75.19 62.59

115.82 80.54

110.75 80.13

110.32 82.69

107.04 78.19

Natural gas ($/mcf)

3.93 4.79

9.30 6.72

8.62 6.35

4.22 –

5.92 5.59

Company $/boe (6mcf=1boe) 65.35 53.80

Benchmark prices and foreign exchange rates

95.13 79.53

111.27 79.47

117.11 80.81

4.07 4.39

3.48 3.82

C$/US$ exchange rate 0.99 1.03

UK£/US$ exchange rate 0.62 0.65

Talisman’s realized oil and liquids prices decreased by 2%, consistent with movement in the benchmark price in the Company’s

primary oil and gas producing regions. North America natural gas prices decreased by 33%, which is consistent with decreases in

NYMEX and AECO prices whereas Southeast Asia natural gas prices remained relatively flat since a significant portion of the

Southeast Asia gas production is linked to oil-based indices. Corridor gas prices averaged $10.12/mcf, where 55% of sales are

referenced to Duri crude oil and High Sulphur Fuel Oil on an energy equivalent basis.

Rate (%) $ million Rate (%) $ million

North America 13 255 11 217

40 1,236 36 834

1 25 – 7

43 402 53 215

19 1,918 16 1,273

1) Includes impact of royalties related to sales volumes.

The corporate royalty rate was 21%, up slightly from 19% in 2011. In the rest of the world, increased production from Equion Energ  ́ ıa ́

Limited (Equion) further reduced the royalty rate to 37% in 2012 while increased production in the US contributed to a higher overall  ́

royalty rate in North America. In Southeast Asia, production from newly producing properties reduced the overall royalty rate due to

the cost recovery of exploration and development costs.

TALISMAN ENERGY ANNUAL REPORT 2012

Commodity Prices and Exchange

2012

North America 69.39

Southeast Asia 111.69

North Sea 111.83

Other 113.52

104.82

North America 2.63

Southeast Asia 9.28

North Sea 9.77

Other 4.30

5.01

58.56

WTI ($/bbl) 94.22

Dated Brent ($/bbl) 111.61

Tapis ($/bbl) 117.03

NYMEX ($/mmbtu) 2.80

AECO (C$/gj) 2.28

1.00

0.63

Royalties(1)

2012 2011 2010

Rate (%) $ million

14 239

Southeast Asia 36 1,243

North Sea 1 18

Other 37 369

21 1,869

21
Gross before royalties Net of royalties

($/boe) 2011 2010 2011 2010

North America 7.11 8.65 8.04 9.59

8.78 6.67 13.82 10.14

33.60 22.91 33.79 22.95

7.07 5.37 11.65 11.39

14.17 12.44 17.68 14.81

1) Includes impact of production volumes.

(millions of $) 2011 2010

North America 454 487

372 280

1,292 1,096

72 27

2,190 1,890

Total operating expenses increased by $262 million, due primarily to higher maintenance costs, increased production in North

America and a full year of operations from new fields in Southeast Asia.

In North America, operating expenses increased with higher production in the Eagle Ford, and a $45 million expense relating to the

Pennsylvania Impact Fee, of which $25 million relates to the retrospective charge for wells drilled prior to 2012, partially offset by

non-core asset dispositions in the first half of the year.

In Southeast Asia, operating expenses increased due to a full year of production at the Kitan and Jambi Merang fields along with

higher planned maintenance costs on certain assets.

In the North Sea, operating expenses were higher due to increased maintenance and logistics costs combined with emergency

response costs incurred to repair the Galley pipeline. These increases were slightly offset by a reduction of $31 million in operating

expenses as a result of the 49% divestiture in TEUK on December 17, 2012.

The increase in the rest of the world was largely due to the startup of the Cusiana liquefied petroleum gas plant in Colombia and

higher production during 2012 at Equion.  ́

Unit operating expenses for the Company increased to $15.83/boe due to the reasons noted above.

Gross before royalties Net of royalties

($/boe) 2011 2010 2011 2010

North America 13.50 12.85 15.26 14.24

7.10 6.37 11.22 9.69

17.21 16.08 17.31 16.11

11.82 5.53 20.92 11.97

12.55 11.76 15.28 13.88

TALISMAN ENERGY ANNUAL REPORT 2012

Unit Operating Expenses(1)

2012 2012

7.91 9.05

Southeast Asia 9.03 13.88

North Sea 50.29 50.59

Other 8.18 12.42

15.83 20.31

Total Operating Expenses

2012

564

Southeast Asia 418

North Sea 1,383

Other 87

2,452

Unit Depreciation, Depletion and Amortization (DD&A) Expense

2012 2012

16.25 18.58

Southeast Asia 9.13 14.10

North Sea 28.56 28.73

Other 12.89 20.75

16.09 19.85

22
(millions of $) 2011 2010

North America 852 717

305 277

671 766

121 28

1,949 1,788

Total DD&A expense was $2.5 billion, up 28% from 2011 as a result of higher production volumes and rates in North America, fourth

quarter reserves revisions and the ramp up of a number of fields, partially offset by lower North Sea production. During the fourth

quarter of 2012, the Company recorded $187 million of DD&A associated with the write-off of proved reserves in two fields. This

incremental DD&A resulted in a full write-off of the book values of the associated fields.

DD&A expense in North America increased largely due to higher production in Marcellus and Eagle Ford and an increase in unit rates

for the Company’s shale properties. In Southeast Asia, the increase was due principally to a full year of production at Kitan and Jambi

Merang and an increase in production from higher unit rate fields. DD&A expense in the North Sea increased due principally to

changes in production mix and higher rates at various fields as a result of reserves revisions, including a $165 million DD&A charge

associated with the write-off of proved reserves for the Auk field. This increase was partially offset by lower production volumes and a

$21 million reduction in the annual DD&A charge as a result of the sale of a 49% equity interest in TEUK on December 17, 2012.

DD&A expense in the rest of the world increased due to changes in production mix in 2012.

Unit DD&A expense was impacted by the same factors as noted above with overall unit DD&A increasing to $16.09/boe.

For additional information relating to DD&A, refer to the ‘Application of Critical Accounting Policies and Use of Estimates’ section of

this MD&A.

(millions of $) 2011 2010

Impairment losses

129 116

– 21

231 164

– –

360 301

Impairment reversals

– –

16 –

118 –

– –

134 –

Net impairment 226 301

During 2012, the Company recorded impairment expense of $363 million in North America of which $194 million pre-tax

($138 million after-tax) relates to lower long-term gas price assumptions and reserves reduction in conventional areas, and

impairment expense of $60 million pre-tax ($45 million after-tax) was recorded in respect of conventional assets disposed of in the

third quarter. In addition, the Company concluded during the third quarter that it would not commit capital in the foreseeable future to

exploration and evaluation activities in Quebec, where the prohibition regarding hydraulic fracturing for shale gas developments has

been reaffirmed. Accordingly, the Company fully impaired its Quebec exploration and evaluation assets and recorded an impairment

expense of $109 million pre-tax ($82 million after-tax).

Impairments of $2.1 billion were recorded for the North Sea, primarily related to the Yme project in Norway. In 2012, the Yme project

experienced significant delays, quality issues and cost overruns and is subject to arbitration with the platform contractor. In the third

quarter, Talisman made a decision to de-man the platform for safety related reasons and it has not been re-manned since. Given the

uncertainty of the timing for first oil, Talisman removed Yme from its forward projections and recorded impairment losses of

$1,475 million pre-tax ($373 million after-tax). At the end of the third quarter, this represented an impairment of the remaining book

TALISMAN ENERGY ANNUAL REPORT 2012

Total DD&A Expense

2012

1,140

Southeast Asia 427

North Sea 796

Other 138

2,501

Impairment

2012

North America 363

Southeast Asia –

North Sea 2,097

Other 284

2,744

North America –

Southeast Asia –

North Sea –

Other –

–

2,744

23
value of the PP&E of Yme, leaving a deferred tax asset of $521 million relating to the investment in the project. Capital expenditures

incurred during the fourth quarter, capitalized interest and revised decommissioning liabilities totalling $99 million pre-tax

($28 million after-tax) were also impaired in full. Management continues to work with all stakeholders to evaluate project options.

During the year, the Rev field in Norway experienced a significant drop in reservoir pressure, resulting in a decline in production. As a

result, the Company made a downward revision of its estimates of recoverable reserves and recorded an impairment expense of

$250 million pre-tax ($55 million after-tax). In the fourth quarter, the Company recorded impairment expense of $74 million pre-tax

($17 million after-tax) in respect of other Norwegian exploration assets upon completion of commercial feasibility studies on these

assets. In addition, a revision to decommissioning cost estimates at Gyda resulted in the Company recording an impairment expense

of $41 million pre-tax ($9 million after-tax).

In the UK, impairment expense of $158 million pre-tax ($66 million after-tax) was recorded in respect of certain development areas

largely due to fourth quarter reserves revisions and increased future cost estimates.

In the third quarter, the Company decided to cease exploration activities in the Maranon Basin in northern Peru and exit the country.  ̃

As a result, $171 million of impairment expense was recorded. The Company will fulfil its outstanding legal obligations as it exits Peru.

In addition, impairment expense of $41 million was recorded during 2012 in respect of exploration and evaluation assets in Poland.

In addition to the impairments discussed above, $72 million of impairment expense was recorded in respect of exploration acreage

relinquished in the Kurdistan Region of Iraq, where Talisman will focus on the discoveries in its remaining Topkhana and Kurdamir

Blocks.

(millions of $) 2011 2010

North America 6 (11)

127 31

106 70

2 23

241 113

In 2012, dry hole expense principally relates to the write-off of unsuccessful exploration wells in Canada, Vietnam, Norway, Sierra

Leone, Peru and Colombia.

(millions of $) 2011 2010

North America 70 52

208 116

40 47

109 159

427 374

Exploration expense consists of geological and geophysical costs, seismic, non-producing land lease rentals and indirect exploration

expense. These costs are expensed as incurred.

In North America, exploration expense decreased by $41 million relative to 2011 due principally to reduced seismic activity in the

Eagle Ford and Marcellus.

In Southeast Asia, exploration expense decreased by $116 million relative to 2011 due principally to the Mitsubishi carry discussed in

the ‘Farm-Outs’ section of this MD&A and a reduction in seismic activity across the region.

In the North Sea, the acquisition of seismic data for three blocks in Norway contributed to the increase of $7 million of exploration

expense year-over-year.

Exploration expense in the rest of the world increased $69 million year-over-year as a result of increased seismic activity in Colombia

and increased activity in certain blocks in Peru prior to the Company’s third quarter decision to exit the country.

TALISMAN ENERGY ANNUAL REPORT 2012

Dry Hole Expense

2012

22

Southeast Asia 77

North Sea 45

Other 125

269

Exploration Expense

2012

29

Southeast Asia 92

North Sea 47

Other 178

346

24
(millions of $) 2011 2010

G&A expense 431 371

278 276

(310) 212

210 (87)

(192) (520)

– –

78 107

161 72

G&A expense was higher due in part to new offices opened during 2011, increased external consulting costs, severance costs, IT

costs and normal workforce cost inflation.

Finance costs include interest on long-term debt (including current portion), other finance charges and accretion expense relating to

decommissioning liabilities, less interest capitalized. Finance costs were relatively flat year-over-year as higher interest expense, due

primarily to the completion in May 2012 of a $600 million offering of 5.5% 30-year notes, was offset by an increase in capitalized

interest costs in 2012.

The share-based payments recovery for the year ended December 31, 2012 was $62 million, compared to a recovery of $310 million

in 2011 due principally to changes in Talisman’s share price.

Talisman recorded a loss on held-for-trading financial instruments of $93 million principally related to an increase in the Dated Brent

price. See the ‘Risk Management’ section of this MD&A for further details concerning the Company’s financial instruments.

The 2012 gain on disposals arose largely from the sale of non-core coal and oil and gas assets in North America and the Company’s

divestiture of a 49% equity interest in TEUK. Refer to the ‘Asset Disposals’ section of this MD&A. The gain in 2011 arose principally

from the sale of a 50% working interest in the Farrell Creek and Cypress A assets to Sasol Limited (Sasol).

The $365 million gain on revaluation of investment in 2012 represents the fair value adjustment recorded upon restructuring of the

Company’s investment in Ocensa. Prior to the reorganization, the Company’s interest in Ocensa was held through a joint venture and

now Talisman has direct ownership of its shares and transportation rights in Ocensa.

Other income includes $46 million of pipeline and processing revenue in 2012 (2011 – $53 million; 2010 – $75 million).

In 2012, other expenses, net includes foreign exchange losses of $32 million, PP&E derecognition expense of $20 million, costs

associated with the gas to liquids feasibility study and other miscellaneous expenses. Other expenses, net in 2011 included a

$65 million allowance for a doubtful account.

TALISMAN ENERGY ANNUAL REPORT 2012

Corporate and Other

2012

510

Finance costs 276

Share-based payments expense (recovery) (62)

(Gain) loss on held-for-trading financial instruments 93

Gain on disposals (1,624)

Gain on revaluation of investment (365)

Other income 83

Other expenses, net 125

25
(millions of $) 2011 2010

Income (loss) before taxes 2,445 1,971

Less: PRT

121 124

52 (20)

Total PRT 173 104

2,272 1,867

Income tax expense (recovery)

1,320 1,012

176 (90)

Income tax expense (recovery) (excluding PRT) 1,496 922

Effective income tax rate (%) 66% 49%

The effective tax rate is expressed as a percentage of income before taxes adjusted for PRT, which is deductible in determining

taxable income. The effective tax rate was impacted by pre-tax losses of approximately $1.5 billion in the North Sea segment where

tax rates are between 62% and 78% and pre-tax losses of approximately $0.8 billion in the North America segment where the rates

are between 25% and 39%, partially offset by income of approximately $1.1 billion in the Southeast Asia segment where the rates

range from 30% to 55%.

In addition to the jurisdictional mix of income, the effective tax rate was also impacted by:

The $860 million gain on the sale of a 49% equity interest in TEUK which was non-taxable.

The Company derecognized $429 million of deferred tax assets related to the Company’s US operations because of a recent history

of cumulative book losses.

The Company recorded deferred taxes of $137 million as a result of a legislative change in the UK in 2012 which restricted tax

relief for decommissioning expenditures to a 50% tax rate from the UK tax rate of 62%.

The Company did not recognize tax benefits associated with impairments in Peru, the Kurdistan Region of Iraq, and Poland.

The Company’s 2011 expected effective tax rate based on the mix of income and losses in various jurisdictions was 57%. The 2011

income tax expense of $1,496 million was different from the expected amount primarily as a result of a $225 million impact due to the

UK rate change that was enacted in 2011. In March 2011, the UK government announced that, from March 24, 2011, the rate of

supplementary charge levied on ring fence profits increased from 20% to 32%. A supplementary charge is levied on ring fence profits

in addition to the ring fence corporation tax rate of 30%. Consequently, there is now a combined corporation tax and supplementary

charge rate of 62% for oil and gas fields not subject to PRT and 81% with fields subject to PRT.

The reduction of $548 million in current taxes from $1,320 million in 2011 to $772 million in 2012 was primarily driven by lower

revenues and higher operating costs in the North Sea segment.

The deferred tax recovery of $1,146 million in 2012 compared to the deferred tax expense of $176 million in 2011 was due

principally to higher impairments in the North Sea segment and higher DD&A in 2012 versus 2011. The deferred tax recovery

associated with the higher impairments and DD&A was offset by deferred tax expense on the gains associated with non-core asset

disposals in Canada, the revaluation gain on the Company’s investment in Ocensa and the derecognition of deferred tax assets in

the US.

(millions of $) 2011 2010

North America 2,155 1,700

487 442

1,205 1,117

295 214

Exploration and development 4,142 3,473

159 78

1,319 1,530

(569) (2,273)

5,051 2,808

TALISMAN ENERGY ANNUAL REPORT 2012

Income Taxes

2012

(174)

Current 102

Deferred (34)

68

(242)

Current income tax 772

Deferred income tax (1,146)

(374)

155%

Capital Expenditures

2012

1,562

Southeast Asia 421

North Sea 1,173

Other 355

3,511

Corporate, IS and Administrative 138

Acquisitions 160

Proceeds of dispositions (964)

2,845

26

•

•

•

•
North America capital expenditures for the year were $1.6 billion, of which $1.4 billion related to development drilling, with the

majority spent in the Eagle Ford, Marcellus, and Canadian conventional programs. The remaining capital was mainly invested in

exploration drilling activities, largely in Canada.

In Southeast Asia, capital expenditures of $421 million included $362 million on development, with the majority spent on

development in Vietnam and development drilling in Indonesia and Malaysia. The majority of the $59 million for exploration was spent

on the drilling of exploration wells in Vietnam. In 2012, Talisman participated in 35 development wells, seven exploration wells and

three appraisal wells.

In the North Sea, capital expenditures of $1.2 billion related primarily to development projects including Auk South, Auk North and

Tweedsmuir in the UK, Yme in Norway and the Montrose area redevelopment in the UK. Included in the total $1.2 billion of capital

expenditures was $86 million for exploration activity, the majority of which occurred in Norway. A total of seven development wells and

three exploration wells were drilled during 2012.

Capital expenditures in other areas were $355 million, including $249 million on exploration activity in Colombia, Peru, Poland, Sierra

Leone and the Kurdistan Region of Iraq. Talisman also spent $106 million on development in Colombia and Algeria. During the year,

the Company participated in four exploration wells, two appraisal wells and five stratigraphic wells in Colombia, one exploration well in

Peru, one exploration well in the Kurdistan Region of Iraq, two exploration wells in Poland, one exploration well in Sierra Leone and

seven development wells in Algeria.

Information related to details and funding of the planned 2013 capital expenditures program is included in the ‘Strategy and Outlook’

section of this MD&A.

On December 17, 2012, Talisman completed the sale of a 49% equity interest in TEUK, which owns substantially all of Talisman’s UK

assets, to Addax Petroleum UK Limited (APUK), an indirect wholly owned subsidiary of Sinopec, for cash consideration of $1.5 billion,

based on an effective date of January 1, 2012. The $1.5 billion cash consideration is comprised of $1,349 million in cash

($1,467 million cash received net of $118 million cash disposed) and $33 million of working capital and other adjustments.

The transaction resulted in a non-taxable gain of $860 million, which is included in ‘Gain on disposals’ on the Consolidated

Statements of Income. Talisman will continue to hold 51% of the joint venture company, with APUK holding the remaining 49%.

TEUK has been renamed Talisman Sinopec Energy UK Limited (TSEUK). Since TSEUK is a jointly controlled entity, the Company is

proportionately consolidating its interest within the North Sea segment for the period December 17, 2012 through

December 31, 2012.

In 2012, Talisman completed sales of oil and gas producing assets in Western Canada for proceeds of $437 million, resulting in gains

of $189 million, net of tax of $67 million.

In 2012, Talisman sold non-core coal assets in northeast British Columbia for cash consideration of $496 million after transaction

costs. The carrying value of these assets was $nil and a gain of $372 million was recorded, net of tax of $124 million.

During 2011, Talisman completed a transaction creating a strategic partnership with Sasol to develop the Farrell Creek assets in

Talisman’s Montney shale play in British Columbia. Talisman sold 50% of its working interests in the Farrell Creek assets for

approximately $1 billion, comprising $238 million in cash and approximately $800 million of certain future development costs. The

transaction resulted in a pre-tax gain of $89 million, which is included in ‘Gain on disposals’ on the Consolidated Statements

of Income.

Also in 2011, Talisman completed an additional transaction with Sasol to develop the Cypress A assets in Talisman’s Montney shale

play in British Columbia. Talisman sold 50% of its working interests in the Cypress A assets for approximately $1.1 billion, comprising

$257 million in cash and approximately $800 million of certain future development costs. The transaction resulted in a pre-tax gain of

$113 million, which is included in ‘Gain on disposals’ on the Consolidated Statements of Income.

TALISMAN ENERGY ANNUAL REPORT 2012

Asset Disposals

Sale of 49% Equity Interest in TEUK to Sinopec

North America Dispositions

Asset Sales Completed in 2011

27
In October 2012, the Company reached agreements to farm down its working interest in the Block SL04B-10 in Sierra Leone from

80% to 30%, including a reimbursement of past costs.

In February 2012, Talisman reached an agreement with Mitsubishi to farm-out interests in nine of the Company’s licences in Papua

New Guinea’s onshore Western Province. The agreement has been approved by all partners and government approval was obtained

in July 2012. This agreement is valued at approximately $280 million and is being paid in the form of a capital carry. Following the

farm-out, the Company’s equity position averages 40% in these nine licences.

During the year ended December 31, 2012, Talisman completed an agreement with the Kurdistan Regional Government for a further

investment of $50 million in the Kurdamir Block arising from the Company’s decision to enter the next exploration sub-period of

the licence.

The Company entered into a new PSC with PETRONAS, the national oil company of Malaysia, acquiring ownership of a 60% working

interest in the Kinabalu PSC as well as assuming operatorship on December 26, 2012. As consideration for receipt of the PSC

interest, the Company paid to PETRONAS a financial commitment in the amount of $50 million in January 2013.

During 2011, Talisman completed the acquisition of a 49% interest in Equion for cash consideration of $785 million, of which  ́

$613 million was paid as a deposit in 2010. Since Equion is a jointly controlled entity, the Company is proportionately consolidating its  ́

interest, which is reported in the Other segment.

Also in 2011, the Company acquired undeveloped land in the Alberta Duvernay shale play for approximately $510 million and

acquired undeveloped land in the Eagle Ford shale play for approximately $145 million. This is in addition to the Eagle Ford acreage

acquired in 2010 for cash consideration of $910 million.

As a Canadian public company, Talisman is subject to the oil and gas disclosure requirements of National Instrument 51-101

(NI 51-101) of the Canadian Securities Administrators. Information regarding the pricing assumptions used in the preparation of the

estimates of NI 51-101 reserves is set forth in Schedule A of Talisman’s AIF dated March 6, 2013.

Talisman’s gross proved and probable reserves at December 31, 2012, compiled in accordance with NI 51-101 disclosure

requirements using forecast prices, are estimated as follows:

Non-Shale

Summary of working interest Light Oil Heavy Oil Shale Oil Shale Gas Natural NGL Total

reserves on gross basis (mmbbls) (mmbbls) (mmbbls) (bcf) Gas (bcf) (mmbbls) (mmboe)

Proved Developed Producing 125.6 35.0 1.9 1,026.1 1,689.6 49.4 664.6

Proved 182.1 35.1 7.7 1,983.4 2,695.5 86.0 1,091.0

Total Proved Plus Probable 360.4 39.6 12.2 3,201.3 3,867.8 119.3 1,710.0

TALISMAN ENERGY ANNUAL REPORT 2012

Farm-Outs

Acquisitions

Reserves at December 31

Disclosure Requirements

Proved Developed Non-Producing 8.6 – 1.1 111.7 183.4 2.4 61.4

Proved Undeveloped 47.9 0.1 4.7 845.6 822.5 34.2 365.0

Probable 178.3 4.5 4.5 1,217.9 1,172.3 33.3 619.0

28
Reconciliation of proved and probable reserves:

Non-Shale

Continuity of working interest Light Oil Heavy Oil Shale Oil Shale Gas Natural NGL Total

reserves on gross basis (mmbbls) (mmbbls) (mmbbls) (bcf) Gas (bcf) (mmbbls) (mmboe)

At December 31, 2011 701.1 53.1 7.4 3,551.7 4,636.6 95.9 2,222.3

At December 31, 2012 360.4 39.6 12.2 3,201.3 3,867.8 119.3 1,710.0

At the end of 2012, Talisman’s proved plus probable reserves totalled 1.7 billion boe. The Company added (discoveries, extensions,

and additions plus other revisions) approximately 31 mmboe of proved plus probable reserves (18 mmboe proved) in the liquids-rich

Eagle Ford shale play, 26 mmboe proved plus probable reserves (19 mmboe proved) in the Montney shale, 11 mmboe proved plus

probable reserves (five mmboe proved) in Wild River, Canada, and seven mmboe proved plus probable (nil proved) reserves in

Corridor, Indonesia.

In the Marcellus dry gas shale play, capital spending has been reduced significantly, which led to negative reserve additions

(discoveries, extensions, and additions plus other revisions) of approximately 38 mmboe of proved plus probable reserves (91 mmboe

proved). These negative additions reflect uncertainty in the timing of development, not technical certainty.

In the North Sea, development of the Auk South and Yme projects have been deferred, resulting in negative additions (discoveries,

extensions, and additions plus other revisions) of approximately 56 mmboe of proved plus probable reserves (44 mmboe proved).

The negative additions in the North Sea also primarily reflect uncertainty in the timing of development, not technical certainty.

As part of the decision to focus the portfolio, Talisman announced it will exit Peru, with a reduction of approximately 21 mmboe of

proved plus probable (nil proved) reserves.

Talisman’s debt at December 31, 2012 was $4.4 billion ($3.7 billion, net of cash and cash equivalents and bank indebtedness), down

from $4.9 billion ($4.5 billion, net of cash and cash equivalents and bank indebtedness) at December 31, 2011.

During 2012, the Company generated $2.7 billion of cash provided by operating activities, incurred capital expenditures of

$3.7 billion and acquisition expenditures of $109 million, and received proceeds of $964 million from the disposition of assets and

proceeds of $1.3 billion from the reduction in its UK investment, net of cash disposed.

On an ongoing basis, Talisman plans to fund its capital program and acquisitions through a combination of cash on hand, cash

provided by operating activities and cash proceeds from the disposition of non-core assets, by drawing on the Company’s credit

facilities, issuing commercial paper, or issuing equity, long-term notes or debentures under the Company’s shelf prospectuses.

In April 2012, the Company renewed the universal shelf prospectus under the Multi-Jurisdictional Disclosure System pursuant to

which it may issue up to C$3.5 billion of debt securities, common shares, preferred shares, subscription receipts, warrants and units.

The Company also renewed its medium term note shelf prospectus in Canada pursuant to which it may issue up to C$1 billion of

medium term notes in Canada. Both shelf prospectuses remain valid over a 25 month period.

In May 2012, Talisman completed a $600 million offering of 5.5% unsecured notes due May 2042. Interest on the notes is payable

semi-annually. The proceeds of $583 million, net of the discount and issuance costs, were used to repay commercial paper and

bankers’ acceptances.

At December 31, 2012, there were 8,000,000 Series 1 preferred shares outstanding. Holders of Series 1 preferred shares are entitled

to receive cumulative quarterly fixed dividends of 4.2% per annum for the initial period ending December 31, 2016, as and when

declared by the Board of Directors. Thereafter, the dividend rate will be reset every five years at a rate equal to the five-year

Government of Canada bond yield plus 2.77%. During 2012, Talisman declared preferred share dividends of C$1.1011 per share

(2011 – C$nil; 2010 – C$nil), including dividends for the full year of 2012 and a pro-rata amount from the date of issuance of the

TALISMAN ENERGY ANNUAL REPORT 2012

Discoveries –––––––

Additions and extensions (68.6) 1.0 8.1 (340.1) (116.2) 31.5 (104.3)

Acquisitions 10.1 – – – 11.9 – 12.0

Divestment (206.6) (11.0) – – (194.9) (4.0) (254.4)

Technical revisions (21.7) 1.3 (3.1) 107.3 (131.9) 3.4 (23.3)

Economic revisions (7.1) (0.2) 0.2 109.8 14.6 0.4 13.9

Production (46.8) (4.6) (0.4) (227.4) (352.3) (7.9) (156.2)

Liquidity and Capital Resources

29
Series 1 preferred shares on December 13, 2011 until December 31, 2011, for an aggregate dividend of $9 million (2011 – $nil;

2010 – $nil).

The Company has an active hedging program that will partially protect 2013 cash flow from the effect of declining oil and gas prices.

See the ‘Risk Management’ section of this MD&A for further information.

With the exception of the $8 million of debt presented as a current liability relating to the Company’s participation in a series of

Tangguh project financing facilities, Talisman has no significant debt maturities until 2014.

Talisman manages its balance sheet with reference to its liquidity and a debt-to-cash flow ratio. The main factors in assessing the

Company’s liquidity are cash flow (defined in accordance with the Company’s debt covenant as cash provided by operating activities

before adjusting for changes in non-cash working capital, exploration expenditure and amounts attributable to assets subject to

non-recourse debt), cash provided by and used in investing activities and available bank credit facilities. The debt-to-cash flow ratio is

calculated using debt (calculated by adding the gross debt and bank indebtedness, production payments and finance lease less

non-recourse debt) divided by cash flow for the year.

The Company is in compliance with all of its debt covenants. The Company’s principal financial covenant under its primary bank

credit facility is a debt-to-cash flow ratio of less than 3.5:1, calculated quarterly on a trailing 12-month basis as of the last day of each

fiscal quarter. Talisman’s debt-to-cash flow was 1.41:1 at December 31, 2012 compared to 1.39:1 at December 31, 2011.

At December 31, 2012, Talisman has unsecured bank credit facilities of $4.1 billion, consisting of facilities of $3.9 billion (Facility

No. 1) and $200 million (Facility No. 2), which are fully committed through November 2014. The maturity date of these facilities may

be extended from time to time upon agreement between the Company and the respective lenders.

The Company established a US commercial paper program in November 2011. The authorized amount under this program is

$1 billion. The amount available under the commercial paper program is limited to the availability of backup funds under the

Company’s bank credit facilities. The outstanding commercial paper was repaid in full during 2012.

Available borrowing capacity was $4.0 billion at December 31, 2012.

The Company utilizes letters of credit pursuant to letter of credit facilities, most of which are uncommitted. Letters of credit are issued

by banks under these uncommitted facilities and most are renewed annually. At January 1, 2013, letters of credit totalling $2.1 billion

had been issued under these facilities, of which $1.6 billion were provided as security for the costs of decommissioning obligations in

the UK. Under the contractual arrangements pursuant to which APUK acquired 49% of the share capital of TEUK, APUK’s parent

company, China Petrochemical Corporation, has provided an unconditional and irrevocable guarantee for 49% of the UK

decommissioning obligations. The remaining outstanding letters of credit relate primarily to a retirement compensation arrangement,

guarantees of minimum work commitments and decommissioning obligations in other areas.

The Company routinely assesses the financial strength of its joint venture participants and customers, in accordance with the

Company’s credit risk guidelines. At this time, Talisman expects that such counterparties will be able to meet their obligations when

they become due.

A significant proportion of Talisman’s accounts receivable balance is with customers in the oil and gas industry and is subject to

normal industry credit risks. At December 31, 2012, approximately 91% of the Company’s trade accounts receivable were current

and the largest single counterparty exposure, accounting for 21% of the total, was with a very highly rated counterparty. Concentration

of credit risk is mitigated by having a broad domestic and international customer base. The maximum credit exposure associated with

accounts receivable is the carrying value. At December 31, 2012, an allowance of $33 million, representing the Company’s 51%

share of the $65 million allowance recorded in TEUK in 2011, consisted of a balance due from a counterparty that had filed

for bankruptcy.

Talisman’s normal course issuer bid program expired on December 14, 2011. Talisman did not renew this program in 2012 and did

not repurchase any common shares under its normal course issuer bid during the year ended December 31, 2011.

During 2012, Talisman declared common share dividends of $0.27 per share (2011 – $0.27 per share; 2010 – C$0.25 per share) for

an aggregate dividend of $277 million (2011 – $277 million; 2010 – $249 million).

At December 31, 2012, there were 1,032,463,974 common shares outstanding, of which 7,014,244 were held in trust by the

Company (see below) resulting in 1,025,449,730 common shares outstanding for accounting purposes. Subsequent to

December 31, 2012, 1,313,810 shares were issued pursuant to the exercise of stock options, with 1,033,777,784 common shares

outstanding at February 28, 2013, of which 7,014,244 were held in trust by the Company resulting in 1,026,763,540 common shares

outstanding for accounting purposes.

30 TALISMAN ENERGY ANNUAL REPORT 2012
At December 31, 2012, there were 59,836,097 stock options, 6,795,106 cash units and 16,536,700 long-term performance share

units (PSUs) outstanding. Subsequent to December 31, 2012, 117,270 stock options were granted, 1,313,810 were exercised for

shares, 259,500 were surrendered for cash and 1,922,532 were forfeited or expired, with 56,457,525 outstanding at February 28,

2013. Subsequent to December 31, 2012, 57,007 cash units were granted, 143,306 were exercised and 191,104 were forfeited or

expired, with 6,517,703 outstanding at February 28, 2013. Subsequent to December 31, 2012, 622,578 long-term PSUs were

granted and 1,186,873 were forfeited or expired, with 15,972,405 outstanding at February 28, 2013.

The Company may purchase shares on the open market to satisfy its obligation to deliver common shares to settle long-term PSUs,

which are held in trust. During the year ended December 31, 2012, 2,022,000 common shares were purchased on the open market

for $25 million and placed in a trust having an arm’s-length third party trustee. Between January 1 and February 28, 2013, no further

common shares were purchased on the open market.

Talisman continually monitors its portfolio of assets and investigates business opportunities in the oil and gas sector. The Company

may make acquisitions, investments or dispositions, some of which may be material. In connection with any acquisition or

investment, Talisman may incur debt or issue equity.

For additional information regarding the Company’s liquidity and capital resources, refer to notes 17 and 20 to the 2012 audited

Consolidated Financial Statements.

Talisman’s financial performance is affected by factors such as changes in production volumes, commodity prices and exchange

rates. The estimated annualized impact of these factors for 2013 (excluding the effect of derivative contracts) is summarized in the

following table, based on a Dated Brent oil price of approximately $100/bbl, a NYMEX natural gas price of approximately

$3.60/mmbtu and exchange rates of US$1=C$1 and UK£1=US$1.60.

Cash Provided

by Operating

(millions of $) Net Income Activities

Volume changes

Price changes(1)

Exchange rate changes

1) The impact of price changes excludes the effect of commodity derivatives. See specific commodity derivative terms in the ‘Risk Management’ section of this MD&A, and

note 22 to the Consolidated Financial Statements.

2) Price sensitivity on natural gas relates to North American natural gas only. The Company’s exposure to changes in the natural gas prices in the UK, Norway, Vietnam and

Colombia is not material. The majority of the natural gas price in Indonesia and Malaysia is based on the price of oil and, accordingly, has been included in the price

sensitivity for oil except for that part which is sold at a fixed price.

As part of its normal business, the Company has entered into arrangements and incurred obligations that will impact the Company’s

future operations and liquidity, some of which are reflected as liabilities in the Consolidated Financial Statements at year-end. The

principal commitments of the Company are in the form of debt repayments, decommissioning obligations, lease commitments

relating to corporate offices and ocean-going vessels, firm commitments for gathering, processing and transmission services,

minimum work commitments under various international agreements, other service contracts and fixed price commodity sales

contracts.

Additional disclosure of the Company’s decommissioning liabilities, debt repayment obligations and significant commitments can be

found in notes 15, 17, 18 and 23 to the 2012 audited Consolidated Financial Statements. A discussion of the Company’s derivative

financial instruments and commodity sales contracts can be found in the ‘Risk Management’ section of this MD&A.

TALISMAN ENERGY ANNUAL REPORT 2012

Sensitivities

Oil – 10,000 bbls/d 75 190

Natural gas – 60 mmcf/d 10 50

Oil – $1.00/bbl 20 35

Natural gas (North America)(2) – $0.10/mcf 15 25

US$/C$ decreased by US$0.01 (5) (5)

US$/UK£ increased by US$0.02 – 5

Commitments and Off-Balance Sheet Arrangements

31
The following table includes the Company’s gross long-term debt, decommissioning obligations, share-based payments, operating

and finance leases, PP&E and E&E assets, commitments and other expected future payment commitments as at December 31, 2012

and estimated timing of such payments:

Payments due by period (1),(2) (millions of $)

Recognized Less than After

Commitments in balance sheet Total 1 year 1-3 years 4-5 years 5 years

Gross long-term debt Yes – Liability 4,442 8 443 576 3,415

Total 13,364 1,381 1,974 1,778 8,231

1) Payments exclude ongoing operating costs related to certain leases, interest on long-term debt and payments made to settle derivative contracts.

2) Payments denominated in foreign currencies have been translated at the December 31, 2012 exchange rate.

3) The decommissioning liabilities represent management’s probability weighted, undiscounted best estimate of the cost and timing of decommissioning obligations based

on engineering estimates and in accordance with existing legislation and industry practice.

4) Certain of the Company’s transportation commitments are tied to firm gas sales contracts.

5) PP&E and E&E assets include drilling rig commitments to meet a portion of the Company’s future drilling requirements, as well as minimum work commitments.

6) The liability for share-based payments recognized on the balance sheet is based on the Company’s year-end stock price or valued at the time of issuance based on the

number of stock options, performance share units and cash units outstanding, adjusted for vesting terms. The amount included in this table includes the full value of

unvested stock options and cash units. Timing of payments is based on vesting and expiry. Actual payments are dependent on the Company’s stock price at the time

of exercise.

There have been no significant changes in the Company’s expected future payment commitments, and the timing of those payments,

since December 31, 2012.

The compensation of key management personnel, consisting of the Company’s directors and executive officers, is as follows:

(millions of $) 2011 2010

Short-term benefits 15 14

5 4

4 –

11 15

35 33

1) The amount reported represents the cost to the Company of key management’s participation in share-based payment plans, as measured by the fair value that the

individual received based on the value of the shares exercised in the current period.

There were no other significant transactions with related parties.

Talisman monitors its exposure to variations in commodity prices, interest rates and foreign exchange rates. In response, Talisman

periodically enters into physical delivery transactions for commodities of fixed or collared prices and into derivative financial

instruments to reduce exposure to unfavourable movements in commodity prices, interest rates and foreign exchange rates. The

terms of these contracts or instruments may limit the benefit of favourable changes in commodity prices, interest rates and currency

values and may result in financial or opportunity loss due to delivery commitments, royalty rates and counterparty risks associated

with contracts.

The Company has established a system of internal controls to minimize risks associated with its derivatives program and credit risk

associated with derivatives counterparties.

TALISMAN ENERGY ANNUAL REPORT 2012

Decommissioning liabilities(3) Yes – Partially accrued 4,074 49 160 220 3,645

Office leases No 191 49 63 25 54

Vessel leases No 571 125 109 183 154

Finance lease obligations Yes – Partially accrued 97 18 36 28 15

Transportation and processing

commitments(4) No 2,348 329 536 544 939

PP&E and E&E assets(5) No 850 413 360 77 –

Other service contracts No 628 248 246 125 9

Share-based payments(6) Yes – Liability 163 142 21 – –

Transactions with Related Parties

2012

15

Pension and other post-employment benefits 6

Termination benefits 15

Share-based payments(1) 13

49

Risk Management

32
The accounting policy with respect to derivative financial instruments and commodity sales contracts is set out in note 3(p) to the

Consolidated Financial Statements. Derivative financial instruments and commodity sales contracts outstanding at December 31,

2012, including their respective fair values, are detailed in note 22 to the Consolidated Financial Statements.

The Company has elected not to designate as hedges for accounting purposes any commodity price derivative contracts entered into.

These derivatives are classified as held-for-trading financial instruments and are measured at fair value with changes in fair value

recognized in net income quarterly. This can potentially increase the volatility of net income.

The Company had the following commodity price derivative contracts outstanding at December 31, 2012, none of which are

designated as hedges:

Two-way collars (Oil) Term bbls/d Floor/ceiling $/bbl

Dated Brent oil index Jan – Dec 2013 6,000 90.00/121.63

Fixed price swaps (Oil) Term bbls/d $/bbl

Dated Brent oil index Jan – Dec 2013 7,500 110.01

Two-way collars (Gas) Term mcf/d Floor/ceiling $/mcf

NYMEX Jan – Dec 2013 47,468 3.16/4.67

Subsequent to December 31, 2012, the Company entered into a Dated Brent swap for the first quarter of 2014 of 1,000 bbls/d for

$104.15/bbl, a Dated Brent swap for the first half of 2014 of 10,000 bbls/d for $103.06/bbl, a Dated Brent swap for the second half of

2014 of 9,000 bbls/d for $103.67/bbl, a WTI swap for 2014 of 2,500 bbls/d for $91.91/bbl and a NYMEX swap for 2014 of

85,443 mcf/d for $4.25/mcf.

Further details of contracts outstanding are presented in note 22 to the Consolidated Financial Statements.

In order to support the Company’s investments in natural gas projects outside of North America and the North Sea, Talisman has

entered into a number of long-term sales contracts.

The majority of Talisman’s Corridor natural gas production in Indonesia is currently sold under long-term sales agreements with PT

Chevron Pacific Indonesia (Chevron), Gas Supply Pte. Ltd. (Gas Supply) and PT Perusahaan Gas Negara (Persero), Tbk (PGN).

Under two sales agreements with Chevron, the majority of sales are priced at approximately 76% of the equivalent value of the

Indonesia Crude Price for Duri crude oil. One of the agreements with Chevron is currently scheduled to expire in 2013 while the

second agreement is due to expire in 2021. The minimum volume commitment under the second agreement is approximately

294 bcf over its remaining nine-year life.

Under the sales agreement with Gas Supply, sales to Singapore from Corridor are referenced to the spot price of high sulphur fuel oil

in Singapore. The minimum volume commitment is approximately 197 bcf over the remaining 11-year life of the contract. Sales from

Corridor to PGN for their markets in West Java are sold under a long-term contract with no associated transportation costs. The

minimum volume commitment is approximately 523 bcf over the remaining 11-year life of the contract. Subsequent to December 31,

2012, an agreement has been reached with PGN to increase the contract price for the sale of Corridor gas under the PGN West Java

Gas Sales Agreement. Under the new agreement, the gas price will increase in stages effective September 2012.

The balance of the gas production from Corridor is sold under medium to long-term agreements which vary in length from two to

seven years and are generally at fixed prices with fixed annual escalation.

At Jambi Merang, the majority of gas production is sold under long-term agreements which contain fixed prices with fixed annual

escalation and are in place until the current termination date of the PSC, which is February 2019.

TALISMAN ENERGY ANNUAL REPORT 2012

Commodity Price Derivative Financial Instruments

Dated Brent oil index Jan – Dec 2013 10,000 90.00/101.91

Dated Brent oil index Jan – Dec 2013 10,000 90.00/105.33

WTI Jan – Dec 2013 10,000 85.00/104.05

Dated Brent oil index Jan – Dec 2013 26,500 105.22

Dated Brent oil index Jan – Mar 2014 9,000 103.12

NYMEX Jan – Dec 2013 94,936 3.16/4.74

NYMEX Jan – Dec 2013 94,936 3.69/4.86

NYMEX Jan – Dec 2013 94,936 3.79/4.69

NYMEX Jan – Dec 2014 94,936 4.21/4.71

Long-Term Sales Contracts

33
The Company is subject to volume delivery requirements for approximately 90 mmcf/d, at prices referenced to the Singapore high

sulphur fuel oil spot market in relation to a long-term sales contract in Malaysia, currently scheduled to end in 2018. In the event

these delivery requirements are not met in a contract year, volumes delivered in the subsequent contract year are subject to a 25%

price discount for the equivalent volume of unexcused shortage that was not delivered in the prior year.

Currently, the Company anticipates having sufficient production to meet future delivery requirements.

In order to swap a portion of the $375 million 5.125% notes due 2015 to floating interest rates, the Company entered into fixed to

floating interest rate swap contracts with a total notional amount of $300 million that expire on May 15, 2015. These swap contracts

require Talisman to pay interest at a rate of three-month US$ LIBOR plus 0.433% while receiving payments of 5.125% semi-annually.

The following is a summary of quarterly results of the Company for the eight most recently completed quarters.

Three months ended

(millions of $, unless otherwise stated) Annual Dec. 31 Sep. 30 Jun. 30 Mar. 31

2012

Net income (loss)

Per common share ($)

Daily average production

Total (mboe/d)

2011

Net income (loss) 776 (117) 521 698 (326)

Per common share ($)

Daily average production

Total (mboe/d) 426 442 400 420 444

1) In 2012, net income (loss) per share includes an adjustment to the numerator for after-tax cumulative preferred share dividends.

2) Diluted net income (loss) per share computed under IFRS includes an adjustment to the numerator for the change in the fair value of stock options and after-tax

cumulative preferred share dividends.

3) Includes oil volumes produced into inventory, and excludes oil volumes sold out of inventory, for the years ended December 31, 2012 and 2011 of 888 bbls/d and

673 bbls/d, respectively.

During the three-month period ended December 31, 2012, total revenue and other income decreased by $476 million over the same

period in 2011 due principally to lower production volumes in the North Sea. Net loss of $117 million in the three-month period

ended December 31, 2011 increased to net income of $376 million in the three-month period ended December 31, 2012 due

principally to the gain on sale of a 49% equity interest in TEUK to Sinopec, the revaluation gain recorded upon restructuring the

Company’s investment in Ocensa, as well as a decrease in taxes and a decrease in loss on held-for-trading financial instruments,

partially offset by the revenue variance and an increase in impairment expense and DD&A.

TALISMAN ENERGY ANNUAL REPORT 2012

Interest Rate Swap

Summary of Quarterly Results

Total revenue and other income 7,312 1,606 1,722 1,869 2,115

132 376 (731) 196 291

Net income (loss)(1) 0.12 0.37 (0.71) 0.19 0.28

Diluted net income (loss)(2) 0.01 0.31 (0.71) 0.14 0.24

Oil and liquids from ongoing operations (mbbls/d)(3) 162 143 159 161 187

Natural gas from ongoing operations (mmcf/d) 1,582 1,498 1,533 1,642 1,652

From ongoing operations (mboe/d) 397 373 388 404 424

Assets sold (mboe/d) 29 19 27 31 38

426 392 415 435 462

Total revenue and other income 8,272 2,082 1,956 2,234 2,000

Net income (loss) 0.76 (0.11) 0.51 0.68 (0.32)

Diluted net income (loss)(2) 0.38 (0.11) 0.24 0.50 (0.32)

Oil and liquids from ongoing operations (mbbls/d)(3) 178 180 161 175 197

Natural gas from ongoing operations (mmcf/d) 1,491 1,572 1,435 1,470 1,484

From ongoing operations (mboe/d) 383 403 364 376 391

Assets sold (mboe/d) 43 39 36 44 53

34
Also, during the three-month period ended December 31, 2012, the Company:

Recorded total production of 392,000 boe/d, down 11% from 2011. Production from ongoing operations was down 7%;

Assumed operatorship of the Kinabalu PSC on December 26, 2012;

Closed a $1.5 billion sale of a 49% equity interest in TEUK to Sinopec;

Confirmed the presence of light oil in the Kurdamir-2 well in the Kurdistan Region of Iraq;

Recorded a $365 million revaluation gain upon restructuring of the Company’s investment in Ocensa;

Recorded one-time DD&A charges of $165 million in the North Sea associated with the write-off of Auk reserves and $22 million

related to the write-off of reserves in the Lynx Palliser area in Canada;

Recorded a $429 million charge to derecognize the US deferred tax assets; and

Recognized $581 million in asset impairment charges due principally to lower long-term gas price assumptions and reserves

reduction in North America, reduced capital commitments for certain exploration and evaluation assets in Norway, and reduced

reserves and higher future operating costs estimates for certain properties in the UK.

Talisman plans to improve total shareholder returns through more selective and disciplined allocation of capital, and better execution

of day-to-day operations within a more focused portfolio. Achieving this goal, combined with a focus on short-term, high cash margin

opportunities, is expected to increase cash flow per share. To achieve this, Talisman has set four key priorities:

Live within its means;

Focus its capital program;

Improve operational performance and reduce cost structure; and

Unlock net asset value of portfolio.

The 2013 capital focus has shifted to near-term, higher netback opportunities. Exploration activities are expected to be reduced

significantly and will be directed primarily at proving up oil potential in Colombia, the Kurdistan Region of Iraq and Southeast Asia.

In 2013, Talisman plans to spend approximately $3.0 billion on exploration and development activities. The Company has some

flexibility to adjust its capital spending to pursue opportunities and respond to a changing economic outlook. Indicative capital

estimates across the Company’s subsidiaries and jointly controlled entities, which are subject to change, are as follows:

(millions of $) 2013

North America 1,100

The Company intends to sell approximately $2 – 3 billion in non-core assets in the next 12 to 18 months.

Production for 2013 is expected to be between 375,000 – 395,000 boe/d, down from 426,000 boe/d in 2012, primarily as a result of

disposals of approximately 25,000 boe/d through the UK joint venture and 4,000 boe/d of non-core assets in North America.

Liquids and international gas is expected to account for approximately 65% of 2013 volumes, an increase of 8% compared to

2012. Volumes are projected to increase in Southeast Asia, the Eagle Ford and Colombia.

North American natural gas production is expected to decline 20% in 2013, with very limited investment, focused on maintaining

strategic land holdings.

TALISMAN ENERGY ANNUAL REPORT 2012

Strategy and Outlook

Colombia 250

Southeast Asia 650

North Sea 800

Rest of the World and Corporate 200

3,000

35

•

•

•

•

•

•

•

•

•

•

•

•

•

•
Management is responsible for establishing and maintaining adequate internal control over financial reporting, as defined in

rules 13a-15(f) and 15d-15(f) under the United States Securities Exchange Act of 1934, as amended (the Exchange Act).

Management, including the Company’s Chief Executive Officer and Chief Financial Officer, has conducted an evaluation of the

Company’s internal control over financial reporting based on criteria established in Internal Control – Integrated Framework issued by

the Committee of Sponsoring Organizations of the Treadway Commission.

Based on management’s assessment as at December 31, 2012, management has concluded that the Company’s internal control

over financial reporting is effective.

The results of management’s assessment were reviewed with the Audit Committee of the Company’s Board of Directors. Ernst &

Young LLP, the independent registered public accounting firm that audited the Company’s Consolidated Financial Statements,

independently assessed the effectiveness of the Company’s internal control over financial reporting. Ernst & Young LLP’s attestation is

located in the Independent Auditors’ Report on Internal Controls Under Standards of the Public Company Accounting Oversight

Board (United States), which is an exhibit to the Company’s Annual Report on Form 40-F.

Because of its inherent limitations, internal control over financial reporting is not intended to provide absolute assurance that a

misstatement of the Company’s financial statements would be prevented or detected. Further, the evaluation of the effectiveness of

internal control over financial reporting was made as of a specific date, and continued effectiveness in future periods is subject to the

risks that controls may become inadequate.

Effective January 1, 2012, Talisman implemented a new integrated finance and supply chain application in its North American

business and corporate function. The implementation of this new application was not in response to any deficiency in the Company’s

internal controls. The Company has assessed the impact of the application implementation and has made modifications to the control

environment accordingly.

Except as disclosed above, there have been no other changes in Talisman’s internal control over financial reporting during the year

ended December 31, 2012 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control

over financial reporting.

At the end of the period covered by this MD&A, an evaluation was carried out under the supervision of, and with the participation of,

the Company’s management, including the Chief Executive Officer and the Chief Financial Officer, of the effectiveness of the design

and operation of the Company’s disclosure controls and procedures (as defined in rule 13a-15(e) and 15d-15(e) under the Exchange

Act). Based on that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that the design and operation of

these disclosure controls and procedures were effective.

Talisman’s disclosure controls and procedures are designed to ensure that information required to be disclosed by an issuer in the

reports that it files or submits under the Exchange Act is (a) accumulated and communicated to the issuer’s management, including

its principal executive and principal financial officers, or persons performing similar functions, as appropriate, to allow timely

decisions regarding required disclosure; and (b) reported within the time periods specified in the rules and forms of the SEC and the

Canadian Securities Administrators.

From time to time, Talisman is the subject of litigation arising out of the Company’s operations. Damages claimed under such litigation

may be material or may be indeterminate and the outcome of such litigation may materially impact the Company’s financial condition

or results of operations. While Talisman assesses the merits of each lawsuit and defends itself accordingly, the Company may be

required to incur significant expenses or devote significant resources to defend itself against such litigation. These claims are not

expected to have a material impact on the Company’s financial position.

The New York Attorney General has commenced an investigation, pursuant to the Martin Act, into the disclosure practices of

companies engaged in hydraulic fracturing in the New York state area. The Martin Act provides broad authority to commence and

conduct investigations, whether upon receipt of a complaint, or on the Attorney General’s own initiative. Subpoenas have been issued

to a number of companies, including Talisman. The Company has been cooperating with the New York Attorney General in the

investigation. No enforcement action has been taken against Talisman, nor has the Company been advised that any enforcement

action is imminent.

TALISMAN ENERGY ANNUAL REPORT 2012

Internal Control over Financial Reporting and Disclosure Controls and Procedures

Internal Control over Financial Reporting

Disclosure Controls and Procedures

Legal Proceedings

36
The preparation of financial statements requires management to make estimates and assumptions that affect reported assets and

liabilities, disclosures of contingencies and revenues and expenses. Management is also required to adopt accounting policies that

require the use of significant estimates and judgment. Actual results could differ materially from those estimates. A summary of

significant accounting policies adopted by Talisman can be found in note 3 to the Consolidated Financial Statements. In assisting the

Company’s Audit Committee to fulfil its financial statement oversight role, management regularly meets with the Committee to review

the Company’s significant accounting policies, estimates and any significant changes thereto, including those discussed below.

Management believes the most critical accounting policies, including judgments in their application, which may have an impact on

the Company’s financial results, relate to the accounting for PP&E, E&E assets, decommissioning liabilities, the recognition of assets

acquired and liabilities assumed upon a business combination and goodwill. The rate at which the Company’s assets are depleted,

depreciated or otherwise written off and the decommissioning liabilities provided for, with the associated accretion expensed to the

income statement, are subject to a number of estimates about future events, many of which are beyond management’s control.

Reserves recognition is central to much of an oil and gas company’s accounting, as described below.

Underpinning Talisman’s estimates and judgments regarding oil and gas assets and goodwill are its oil and gas reserves. Detailed

rules and industry practice, to which Talisman adheres, have been developed to provide uniform reserves recognition criteria.

However, the process of estimating oil and gas reserves is inherently judgmental. There are two principal sources of uncertainty:

technical and commercial. Technical reserves estimates are made using available geological and reservoir data as well as production

performance data. As new data becomes available, including actual reservoir performance, reserves estimates may change. Reserves

can also be classified as proved or probable with decreasing levels of certainty as to the likelihood that the reserves will be ultimately

produced.

Reserves recognition is also impacted by economic considerations. In order for reserves to be recognized, they must be reasonably

certain of being produced under existing economic and operating conditions, which is viewed as being annual average commodity

prices determined by the prices in effect on the first day of each month with a cost profile based on current operations

(SEC requirements) or forecast prices and cost assumptions (NI 51-101 requirements). Any anticipated changes in conditions must

have reasonable certainty of occurrence. In particular, in international operations, consideration includes the status of field

development planning and gas sales contracts. As economic conditions change, primarily as a result of changes in commodity prices

and, to a lesser extent, operating and capital costs, marginally profitable production, typically experienced in the later years of a field’s

life cycle, may be added to reserves or, conversely, may no longer qualify for reserves recognition.

The Company’s reserves and revisions to those reserves, although not separately reported on the Company’s balance sheet or income

statement, impact the Company’s reported assets, liabilities and net income through the DD&A of the Company’s PP&E, impairments

and the provision for decommissioning liabilities.

The Reserves Committee of Talisman’s Board of Directors reviews the Company’s reserves booking process and related public

disclosures and the report of the internal qualified reserves evaluator (IQRE). The primary responsibilities of the Reserves Committee

include, among other things, reviewing the Company’s reserves booking process and recommending to the Board of Directors the

Company’s annual disclosure of reserves data and other oil and gas information contained in the Company’s AIF. The IQRE reports

the Company’s annual reserves data to the Reserves Committee and delivers a regulatory certificate regarding proved and probable

reserves and their related future net revenue, disclosed pursuant to NI 51-101 requirements.

A significant portion of the Company’s PP&E is amortized based on the unit of production method with other assets being depreciated

on a straight-line basis over their expected useful lives. The unit of production method attempts to amortize the asset’s cost over its

proved oil and gas reserves base. Accordingly, revisions to reserves or changes to management’s view as to the operational lifespan of

an asset will impact the Company’s future DD&A expense. Depletion and depreciation rates are updated in each reporting period that

a significant change in circumstances, including reserves revisions, occurs.

Exploration well costs are initially capitalized and, if subsequently determined to have not found sufficient reserves to justify

commercial production, are charged to dry hole expense. Exploration well costs that have found sufficient reserves to justify

commercial production, but those reserves cannot be classified as proved, continue to be capitalized as long as sufficient progress is

being made to assess the reserves and economic viability of the well and/or related project. All such carried costs are subject to

technical, commercial and management review at each reporting date to confirm the continued intent to develop or otherwise extract

value from the discovery. When this is no longer the case, the costs are written off. When proved reserves of oil and natural gas are

TALISMAN ENERGY ANNUAL REPORT 2012

Application of Critical Accounting Policies and Use of Estimates

Reserves Recognition

Depreciation, Depletion and Amortization Expense (DD&A)

Exploration and Evaluation (E&E) Assets

37
determined and development is sanctioned, the relevant expenditure is tested for potential impairment and then transferred to PP&E.

If a project no longer meets these criteria, it is tested for impairment and transferred back from PP&E to E&E assets.

Undeveloped land costs are classified initially as E&E assets and transferred to PP&E as proved reserves are assigned.

E&E assets are not subject to DD&A.

The Company tests PP&E and E&E assets for possible impairment whenever events or changes in circumstances indicate that the

carrying value of an asset may not be recoverable; for example, changes in assumptions relating to future prices, future costs,

reserves and contingent resources. Individual assets are grouped for impairment assessment purposes at the lowest level at which

there are identifiable cash inflows that are largely independent of the cash inflows of other groups of assets, known as a

cash-generating unit (CGU). If any such indication of impairment exists, an estimate of the CGU’s recoverable amount is made. A

CGU’s recoverable amount is the higher of its fair value less costs to sell and its value in use. These assessments require the use of

estimates and assumptions regarding long-term commodity prices, discount rates, future capital expenditures requirements, reserves

determination and life-of-field. Consideration is also given to recent market transactions for similar assets in assessing fair value. E&E

assets are also tested for impairment when transferred to PP&E.

A previously recognized impairment loss is reversed only if there has been a change in the estimates or assumptions used to

determine the CGU’s recoverable amount since the impairment loss was recognized. If that is the case, the carrying amount of the

CGU is increased to its recoverable amount. That increased amount cannot exceed the carrying amount that would have been

determined, net of depreciation, had no impairment loss been recognized for the CGU in prior periods. Such a reversal is recognized

in net income, following which the depreciation charge is adjusted in future periods to allocate the CGU’s revised carrying amount,

less any residual value, on a systematic basis over its remaining useful life.

In estimating the possible impairment to PP&E, management estimates fair value based on market information, which consists of

offers to purchase the asset or comparable assets, independent market surveys and values derived from exchange-quoted prices.

Where reliable market information is not available, the recoverable amount was determined using cash flow projections that were

based on a long-term view of commodity prices and a post-tax discount rate of 10%.

During the year, the Company recorded a net impairment of oil and gas assets of $2.7 billion (2011 – $226 million; 2010 –

$301 million).

Goodwill represents the excess of the consideration transferred over the fair value of the identifiable assets acquired and liabilities

assumed in a business combination. Goodwill is tested for impairment annually and when circumstances indicate that the carrying

value may be impaired. The impairment test requires that goodwill be allocated to CGUs, which Talisman has determined by

aggregating locations having similar economic characteristics and/or which are in similar geographic locations, and which correspond

with the operating segments, except for locations within the Other segment, which are allocated to the relevant countries. Impairment

is determined for goodwill by assessing the recoverable amount (based on fair value less costs to sell) of each segment to which the

goodwill relates. Where the recoverable amount of the segment is less than the carrying amount, an impairment loss is recognized.

Goodwill impairment losses cannot be reversed. No impairment of goodwill was recorded during the year.

Business combinations are accounted for using the acquisition method. The cost of an acquisition is measured as the aggregate of

the consideration transferred at acquisition date fair value. When the Company acquires a business, it assesses the assets and

liabilities assumed for appropriate classification and designation in accordance with the contractual terms, economic circumstances

and pertinent conditions as at the acquisition date. The Company allocates the purchase price to identifiable assets and liabilities

based on their fair value. In many cases, the determination of fair value requires management to make certain assumptions and

estimates regarding future events. Typically in determining fair value, management develops a number of possible future cash flow

scenarios to which probabilities are judgmentally assigned. The acquired assets and liabilities may span multiple geographical

segments and may be amortized at different rates, or not at all as in the case of goodwill or, initially, for acquired probable reserves.

Transaction costs include stamp duty, consulting fees (e.g. legal, accounting and valuation fees) and other integration costs and are

expensed as incurred.

TALISMAN ENERGY ANNUAL REPORT 2012

Impairment of Assets

Goodwill Impairments

Business Combinations

38
Decommissioning liabilities are measured based on the estimated cost of abandonment discounted to its net present value using a

weighted average credit-adjusted risk free rate. At December 31, 2012, the net present value of the Company’s decommissioning

liability was $2.8 billion (2011 – $3.0 billion) and is recorded as a liability on the Company’s balance sheet. In determining the net

present value of the Company’s decommissioning liability, management developed a number of possible remediation scenarios to

which probabilities were assigned based on management’s reasonable judgment. The undiscounted decommissioning obligations

were estimated at $4.1 billion at December 31, 2012 (2011 – $5.0 billion), which is based on management’s probability weighted

estimate of costs and is in accordance with existing legislation and industry practice. The majority of the payments to settle this

provision will occur over a period of 35 years and will be funded from the general resources of the Company as they arise. The

provision for the costs of decommissioning production facilities and pipelines at the end of their economic lives has been estimated

using existing technology, at current prices or long-term assumptions and based upon the expected timing of the activity. The

provision has been discounted using a weighted average credit-adjusted risk free rate of 2.3% (2011 – 3.1%), which excludes the

impact of inflation.

In 2012, the sale of a 49% equity interest in TEUK resulted in a reduction of decommissioning liabilities having a net present value of

$996 million.

While the provision is based on the best estimate of future costs and the economic lives of the facilities and pipelines, there is

uncertainty regarding both the amount and timing of incurring these costs. As an indication of possible future changes in estimated

decommissioning liabilities, if all of the Company’s decommissioning obligations could be deferred by one year, the net present value

of the liabilities would decrease by approximately $55 million.

Current tax is based on estimated taxable income and tax rates, which are determined pursuant to the tax laws that are enacted or

substantively enacted at the balance sheet date.

Deferred tax is determined using the liability method. Under the liability method, deferred tax is calculated based on the differences

between assets and liabilities reported for financial accounting purposes and those reported for income tax purposes. Deferred tax

assets and liabilities are measured using substantively enacted tax rates. The impact of a change in tax rate is recognized in net

income in the period in which the tax rate is substantively enacted. The Company recognizes in its financial statements the best

estimate of the impact of a tax position by determining if the available evidence indicates whether it is more likely than not, based

solely on technical merits, that the position will be sustained on audit. The Company estimates the amount to be recorded by

weighting all possible outcomes by their associated probabilities.

Deferred tax assets and liabilities are offset only when a legally enforceable right of offset exists and the deferred tax assets and

liabilities arose in the same tax jurisdiction and relate to the same taxable entity. The Company assesses the available positive and

negative evidence of both an objective and subjective nature to estimate if sufficient future taxable income will be generated to realize

the existing deferred tax assets.

The determination of the income tax provision is an inherently complex process, requiring management to interpret continually

changing regulations and to make certain judgments. Issues in dispute for audited years and audits for subsequent years are ongoing

and in various stages of completion in the jurisdictions in which the Company operates around the world. As a consequence, the

balance in unrecognized tax benefits can be expected to fluctuate from period to period. It is reasonably possible that such changes

could be significant when compared with the Company’s total unrecognized tax benefits. However, the amount of change cannot

be quantified.

Talisman’s worldwide operations expose the Company to transactions denominated in a number of different currencies, which are

required to be translated into one currency for financial statement reporting purposes. Talisman’s foreign currency translation policy,

as detailed in note 3(n) to the Consolidated Financial Statements, is designed to reflect the economic exposure of the Company’s

operations to the various currencies. The Company’s functional currency is US$, a reflection of Talisman’s overall exposure to US$

denominated transactions, assets and liabilities; oil prices are largely denominated in US$ as is much of the Company’s corporate

debt and international capital spending and operating costs.

Prior to January 1, 2011 in the UK and prior to January 1, 2010 in Canada and Norway, the Company’s operations were translated

from UK£, C$ and NOK, respectively, into US$ using the current rate method whereby assets and liabilities were translated at

year-end exchange rates, while revenues and expenses were converted using average rates for the period. Gains and losses arising on

translation from UK£, C$ and NOK to US$ were deferred and included in a separate component of shareholders’ equity described as

accumulated other comprehensive income.

TALISMAN ENERGY ANNUAL REPORT 2012

Decommissioning Liabilities

Income Taxes

Foreign Exchange Accounting

39
As a result of changes in the composition of revenue and costs and changes in intercompany loan arrangements, management has

determined that the functional currency of the Company’s UK operation is more closely linked to the US$. Accordingly, effective

January 1, 2011, this operation has been accounted for as a US$ functional currency entity. Following the change in the functional

currency of the UK operation on January 1, 2011, the debt denominated in UK£ was no longer designated as a hedge of Talisman’s

net investment in the UK and, accordingly, foreign exchange gains and losses are recorded on the Consolidated Statements of

Income. In conjunction with the Company’s reduction of its net investment in its UK subsidiary in 2012, foreign currency translation

adjustments of $23 million were reclassified out of accumulated comprehensive income into income.

The Company’s operations in Canada and Norway are accounted for as US$ functional currency entities. As a result, foreign currency

translation adjustments remain in accumulated other comprehensive income until Talisman reduces its net investment in its

Canadian or Norwegian subsidiaries.

The remaining foreign operations are translated as follows: monetary assets and liabilities at exchange rates in effect at the balance

sheet date, non-monetary assets and liabilities at rates in effect on the dates the assets were acquired or liabilities were assumed, and

revenues and expenses at rates of exchange prevailing on the transaction dates. Gains and losses on translation are reflected in

income when incurred.

A significant portion of the Company’s operations outside North America and the North Sea are governed by PSCs. Under PSCs,

Talisman, along with other working interest holders, typically bears all risk and costs for exploration, development and production. In

return, if exploration is successful, Talisman recovers the sum of its investment and operating costs (cost oil) from a percentage of the

production and sale of the associated hydrocarbons. Talisman is also entitled to receive a share of the production in excess of cost oil

(profit oil). The sharing of profit oil varies between the working interest holders and the government from contract to contract. The cost

oil, together with the Company’s share of profit oil, represents Talisman’s hydrocarbon entitlement (working interest less royalties).

Talisman records gross production, sales and reserves based on its working interest ownership with sales disclosed net of royalties. In

addition, certain of the Company’s contractual arrangements in foreign jurisdictions stipulate that income tax payments are to be

withheld from the Company and paid to the government out of the respective national oil company’s entitlement share of production.

The Company includes such amounts in income tax expense at the statutory tax rate in effect at the time of production.

The amount of cost oil required to recover Talisman’s investment and costs in a PSC is dependent on commodity prices and,

consequently, Talisman’s share of profit oil is also impacted. Accordingly, the amount of royalty paid by Talisman over the term of a

PSC and the corresponding net after royalty reserves booked by the Company are dependent on the amount of initial investment and

past costs yet to be recovered and anticipated future costs, commodity prices and production. As a result, when year-end prices

increase, the amount of net reserves after royalty the Company books may decrease and vice versa.

The Company enters into derivative financial instruments in order to manage risks associated with fluctuations in commodity prices,

interest rates and foreign currency exchange rates. As detailed in Talisman’s financial instruments accounting policy described in

note 3(p) to the Consolidated Financial Statements, derivative instruments are recorded at fair value on the Consolidated Balance

Sheets. Gains or losses on financial instruments are recognized as hedging gains or losses or held-for-trading gains or losses in net

income. Fair values are determined based on third party market information and are subject to a degree of uncertainty. Estimates of

fair value are subject to change with fluctuations in commodity prices, interest rates, foreign currency exchange rates and estimates

of non-performance risk. Cash settlement of derivative financial instruments may vary from fair value estimates, depending on the

underlying market prices at the date of settlement.

The following pronouncements from the International Accounting Standards Board (IASB) are applicable to Talisman and will become

effective for future reporting periods, but have not yet been adopted.

IAS 1 Presentation of Items of Other Comprehensive Income – Amendments to IAS 1. The amendments to IAS 1 improve the

quality of the presentation of other comprehensive income (OCI). The amendments require companies preparing financial

statements in accordance with IFRS to group together items within OCI that may be reclassified to the profit or loss section of the

income statement. The amendments also reaffirm existing requirements that items in OCI and profit or loss should be presented as

either a single statement or two consecutive statements. The amendments to IAS 1 are effective for annual periods beginning on or

after July 1, 2012. The amendment affects presentation only and has no impact on the Company’s financial position

or performance;

TALISMAN ENERGY ANNUAL REPORT 2012

Production Sharing Contract (PSC) Arrangements

Risk Management

Accounting Changes

Accounting Standards and Interpretations Issued but Not Yet Effective

Effective January 1, 2013

40

•
IFRS 7 Disclosures – Offsetting Financial Assets and Financial Liabilities – Amendments to IFRS 7. These amendments to IFRS 7

introduce new disclosure requirements about the effects of offsetting financial assets and financial liabilities and related

arrangements on an entity’s financial position. The disclosures will provide users with information that may be useful in evaluating

the effect of any netting arrangements in an entity’s financial position. The amendments to IFRS 7 are effective for annual periods

beginning on or after January 1, 2013. The amendments affect disclosure only and will not impact the Company’s financial position

or performance;

IFRS 10 Consolidated Financial Statements – establishes the accounting principles for consolidated financial statements when one

entity controls other entities and replaces IAS 27 Consolidated and Separate Financial Statements and the related provisions of

SIC-12 Consolidation – Special Purpose Entities. This standard establishes a new control model that applies to all entities. This

standard will have no significant impact on Talisman’s financial results as all subsidiaries are 100% owned, the trust holding

common shares has been consolidated since it is a special purpose entity controlled by the Company and all other results are from

joint operations and ventures;

IFRS 11 Joint Arrangements – establishes the accounting principles for parties to a joint arrangement and replaces IAS 31 Interest

in Joint Ventures and SIC-13 Jointly Controlled Entities: Non-Monetary Contributions by Venturers. This standard requires a party to

assess its rights and obligations from the arrangement in order to determine whether a joint arrangement represents a joint venture

or a joint operation. As at December 31, 2012, the Company proportionately consolidated all its interest in joint arrangements.

Upon adoption of this standard on January 1, 2013, the Company will be required to account for its investments in TSEUK and

Equion using the equity method of accounting and requires retrospective application;  ́

IFRS 12 Disclosure of Interests in Other Entities – establishes comprehensive disclosure requirements for subsidiaries, joint

arrangements, associates, and unconsolidated structured entities and replaces existing disclosures in related standards. The

impact on Talisman will be increased disclosure regarding its equity interest in TSEUK and Equion;  ́

IFRS 13 Fair Value Measurement – establishes a single framework for fair value measurement and disclosures when fair value is

required or permitted under IFRS. Talisman is currently assessing the impact that this standard will have on the financial position

and performance. Based on the Company’s analysis, this standard is expected to increase the financial statement disclosures, but

is not expected to have a material impact on Talisman’s financial position;

IAS 19 Employee Benefits (revised) – IAS 19 provides the accounting and disclosure requirements by employers for employee

benefits. The amendments to IAS 19 will provide investors and other users of financial statements with a better understanding of an

entity’s obligations resulting from the provision of defined benefit plans and how those obligations will affect its financial position,

financial performance and cash flow. Among other things, the amendment eliminates the option to defer the recognition of gains

and losses, known as the ‘corridor method’, and will impact the net benefit expense as the expected return on plan assets will be

calculated using the same interest rate as applied for the purpose of discounting the benefit obligation. The amendments to IAS 19

are effective for annual periods beginning on or after January 1, 2013. As stated in the Company’s accounting policies, actuarial

gains and losses for defined benefit plans are recognized in full in the period in which they occur in OCI and such actuarial gains

and losses are also immediately recognized in retained earnings and are not reclassified to profit and loss in subsequent periods.

Therefore, the amendment which eliminates the ‘corridor method’ will have no impact on the Company’s financial position or

performance. The Company does not expect the net benefit expense to change significantly as a result of applying the rate used to

discount the benefit obligation as the rate used for calculating the Company’s expected return on plan assets. Any adjustment

required to reflect the actual return on plan assets as compared to the expected return on assets will be recorded in OCI. The

amended standard requires retrospective application;

IAS 27 Separate Financial Statements – establishes the accounting and disclosure requirements for investments in subsidiaries,

joint ventures, and associates when an entity prepares separate financial statements and replaces the current IAS 27 Consolidated

and Separate Financial Statements as the consolidation guidance is included in IFRS 10 Consolidated Financial Statements. This

standard is not expected to have an impact on Talisman’s Consolidated Financial Statements; and

IAS 28 Investments in Associates and Joint Ventures – establishes the accounting for investments in associates and defines how

the equity method is applied when accounting for associates and joint ventures. This standard is not expected to have an impact on

Talisman’s Consolidated Financial Statements.

IAS 32 Offsetting Financial Assets and Financial Liabilities – Amendments to IAS 32, Financial Instruments Presentation. The

amended standard requires entities to disclose both gross information and net information about both instruments and transactions

eligible for offset in the statement of financial position and instruments and transactions subject to an agreement similar to a master

netting arrangement. The scope includes derivatives, sale and repurchase agreements and reverse sale and repurchase

agreements and securities borrowing and securities lending agreements. The amendments to IAS 32 are effective for annual

TALISMAN ENERGY ANNUAL REPORT 2012

Effective Subsequent to 2013

41

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•

•

•

•

•

•

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periods beginning on or after January 1, 2014 and require retrospective application. The Company is currently evaluating the

impact of adopting this amended standard;

IFRS 9 Financial Instruments – as issued, reflects the first phase of the IASB’s work on the replacement of IAS 39 and applies to

classification and measurement of financial assets and financial liabilities as defined in IAS 39. The standard was initially effective

for annual periods beginning on or after January 1, 2013, but an amendment issued in December 2011 moved the mandatory

effective date to January 1, 2015. In subsequent phases, the IASB will address hedge accounting and impairment of financial

assets. The adoption of the first phase of this standard may have an effect on the classification and measurement of the Company’s

financial assets, but will not have an impact on classification and measurement of financial liabilities. The Company is currently

evaluating the potential impacts and will quantify the effect in conjunction with the other phases, when issued, to present a

comprehensive picture.

In 2010, the US Dodd-Frank Wall Street Reform and Consumer Protection Act (Dodd-Frank Act or the Act) was signed into law. The

Dodd-Frank Act provides for numerous new substantive requirements in areas such as the disclosure of payments made to foreign

governments, rules regarding the use of credit ratings, and corporate governance and executive compensation reforms, among

others, some of which apply to Talisman as a foreign private issuer. Talisman will continue to assess the effect on the Company of the

Dodd-Frank Act and related rules. The SEC has yet to issue the rules relating to pay-for-performance, pay parity, hedging and

executive compensation clawbacks.

In August 2012, the SEC adopted rules to implement Section 1504 of the Dodd-Frank Act. The rules require resource extraction

issuers to disclose payments made to the US federal government or a foreign government (including a department, agent or

instrumentality of a foreign government or a company owned by a foreign government) in their annual reports. A payment would be

an amount that is not de minimus and that is paid to further the commercial development of oil, natural gas or minerals, including

taxes, royalties, fees (including licence fees), bonuses, production entitlements or any other material benefits the SEC determines is

part of commonly recognized revenue streams for resource extraction. These rules come into effect for year-end 2013, but only with

respect to the period from October 1 to December 31, 2013. Thereafter, Talisman will be required to report annually.

Talisman is exposed to a number of risks inherent in exploring for, developing and producing crude oil and natural gas. This section

describes the important risks and other matters that could cause actual results of Talisman to differ materially from those presented

and that could affect the trading price of the Company’s outstanding securities. The risks described below may not be the only risks

Talisman faces, as Talisman’s business and operations may also be subject to risks that Talisman does not yet know of, or that

Talisman currently believes are immaterial. If any of the events or circumstances described below actually occurs, Talisman’s

business, financial condition, results of operations or cash flow could be materially and adversely affected and the trading price of

Talisman’s securities could decline. The risks described below are interconnected, and more than one of these risks could materialize

simultaneously or in short sequence if certain events or circumstances described below actually occur. The following risk factors

should be read in conjunction with the other information contained herein and in the Consolidated Financial Statements and the

related notes.

Talisman’s financial performance is highly sensitive to the prevailing prices of crude oil and natural gas. Fluctuations in crude oil or

natural gas prices could have a material adverse effect on the Company’s operations and financial condition, the value of its oil and

natural gas reserves and its level of expenditure for oil and gas exploration and development. Prices for crude oil and natural gas

fluctuate in response to changes in the supply of and demand for crude oil and natural gas, market uncertainty and a variety of

additional factors that are largely beyond the Company’s control. Oil prices are determined by international supply and demand.

Factors which affect crude oil prices include the actions of the Organization of Petroleum Exporting Countries, world economic

conditions, government regulation, political stability throughout the world, the availability of alternative fuel sources, technological

advances affecting energy production and consumption, and weather conditions. About 60% of the natural gas prices realized by

Talisman are affected primarily by North American supply and demand, weather conditions and prices of alternative sources of

energy. The remaining 40% of natural gas prices realized by Talisman are from markets outside of North America, primarily in

Southeast Asia. These other prices are typically determined by long-term contracts that are linked to international oil and/or oil

prevalent prices. The development of oil and natural gas discoveries in offshore areas and the development of shale gas plays are

particularly dependent on the outlook for oil and natural gas prices because of the large amount of capital expenditure required for

development prior to commencing production.

A substantial and extended decline in the prices of crude oil or natural gas could result in delay or cancellation of drilling,

development or construction programs, curtailment in production or unutilized long-term transportation commitments, all of which

TALISMAN ENERGY ANNUAL REPORT 2012

Regulatory Developments

Dodd-Frank Act

Risk Factors

Volatility of Oil and Natural Gas Prices

42

•
could have a material adverse impact on the Company. The amount of cost oil required to recover Talisman’s investment and costs in

various PSCs is dependent on commodity prices, with higher commodity prices resulting in the booking of lower oil and gas reserves

net of royalties.

Moreover, changes in commodity prices may result in the Company making downward adjustments to the Company’s estimated

reserves. If this occurs, or if the Company’s estimates of production or economic factors change, accounting rules may require the

Company to impair, as a non-cash charge to earnings, the carrying value of the Company’s oil and gas properties. The Company is

required to perform impairment tests on oil and gas properties whenever events or changes in circumstances indicate that the

carrying value of properties may not be recoverable. To the extent such tests indicate a reduction of the estimated useful life or

estimated future cash flows of the Company’s oil and gas properties, the carrying value may not be recoverable and, therefore, an

impairment charge will be required to reduce the carrying value of the properties to their estimated fair value. The Company may

incur impairment charges in the future, which could materially affect the Company’s results of operations in the period incurred.

Results of operations are affected primarily by the exchange rates between the US$, the C$, UK£ and NOK. These exchange rates

may vary substantially. Most of the Company’s revenue is received in or is referenced to US$ denominated prices (including the

Company’s Consolidated Financial Statements, which are presented in US$), while the majority of Talisman’s expenditures are

denominated in US$, C$, UK£ and NOK. A change in the relative value of the US$ against the C$ or the UK£ would also result in an

increase or decrease in Talisman’s C$ or UK£ denominated debt, as expressed in US$, and the related interest expense. Talisman is

also exposed to fluctuations in other foreign currencies.

The process of estimating oil and gas reserves is complex and involves a significant number of assumptions in evaluating available

geological, geophysical, engineering and economic data. In addition, the process requires future projections of reservoir performance

and economic conditions; therefore, reserves estimates are inherently uncertain. Since all reserves estimates are, to some degree,

uncertain, reserves classification attempts to qualify the degree of uncertainty involved.

Since the evaluation of reserves involves the evaluator’s interpretation of available data and projections of price and other economic

factors, estimates of the economically recoverable oil and natural gas reserves attributable to any particular group of properties, the

classification of such reserves based on estimated uncertainty, and the estimates of future net revenue or future net cash flows

prepared by different evaluators or by the same evaluators at different times may vary substantially.

Each year, Talisman prepares evaluations of all of its reserves internally. Initial estimates of reserves are often based upon volumetric

calculations and analogy to similar types of reservoirs, rather than actual well data and performance history. Estimates based on these

methods generally are less certain than those based on actual performance. The Company may adjust its estimates and classification

of reserves and future net revenues or cash flows based on results of exploration and development drilling and testing, additional

performance history, prevailing oil and gas prices, and other factors, many of which are beyond the Company’s control. As new

information becomes available, subsequent evaluations of the same reserves may continue to have variations in the estimated

reserves, some of which may be material. In addition, Talisman’s actual production, taxes, and development and operating

expenditures with respect to its reserves will likely vary from such estimates and such variances could be material.

The Company’s future success depends largely on its ability to find and develop, or acquire, additional oil and gas reserves that are

economically recoverable. Hydrocarbons are a limited resource, and Talisman is subject to increasing competition from other

companies, including national oil companies. Exploration and development drilling may not result in commercially productive

reserves and, if production begins, reservoir performance may be less than projected. Successful acquisitions require an assessment

of a number of factors, many of which are uncertain. These factors include recoverable reserves, exploration potential, future oil and

gas prices, operating costs and potential environmental and other liabilities. Such assessments are inexact and their accuracy is

inherently uncertain. If a high impact prospect identified by the Company fails to materialize in a given year, the Company’s multi-year

exploration and/or development portfolio may be compromised. See also ‘Risk Factors – Volatility of Oil and Natural Gas Prices.’

Continued failure to achieve anticipated reserve and resource addition targets may result in the Company’s withdrawal from an area,

which in turn may result in a writedown of any associated reserves and/or resources for that area.

Talisman manages a variety of projects, including exploration and development projects and the construction or expansion of facilities

and pipelines. Project delays may impact expected revenues and project cost overruns could make projects uneconomic. Talisman’s

ability to complete projects depends upon numerous factors, many of which are beyond the Company’s control. These factors include

the level of direct control by Talisman since many of the projects in which Talisman is involved are not operated by Talisman, and

timing and project management control are the responsibility of the operator. See also ‘Risk Factors – Non-Operatorship and Partner

TALISMAN ENERGY ANNUAL REPORT 2012

Exchange Rate Fluctuations

Uncertainty of Reserves Estimates

Ability to Find, Develop or Acquire Additional Reserves

Project Delivery

43
Relations.’ In particular, the majority of the Company’s operations in Colombia are non-operated. In addition, for Talisman-operated

projects, the global demand for project resources can impact the access to appropriately competent contractors and construction

yards as well as to raw products, such as steel. Typical execution risks include the availability of processing capacity, the availability

and proximity of pipeline capacity, the availability of drilling and other equipment, the ability to access lands, weather, unexpected

cost increases, accidents, the availability of skilled labour, including engineering and project planning personnel, the need for

government approvals and permits, and regulatory matters. Subsurface challenges can also result in additional risk of cost and

schedule overrun if conditions are not typical of historical experiences, such as in up-scaling shale operations from pilot to full field

developments. Talisman utilizes materials and services which are subject to general industry-wide conditions. Cost escalation for

materials and services may be unrelated to commodity price changes and may continue to have a significant impact on project

planning and economics. Talisman operates in challenging, environmentally hostile climates, such as Papua New Guinea, where

logistical costs can be materially impacted by seasonal and occasionally unanticipated weather patterns. Contracts where work has

been placed under a lump sum arrangement, for example with the Company’s Yme project, are subject to additional challenges

related to scheduling, reputation and relationship management with the Company’s coventurers, as the contractor is wholly

responsible for delivery of the facility.

Talisman’s long-term financial performance is sensitive to the capital allocation decisions taken and the underlying performance of the

projects undertaken. In 2013, Talisman plans to spend approximately $3 billion in cash capital expenditures, the majority of which is

to be allocated among Talisman’s North America, Southeast Asia, North Sea and exploration portfolios. Capital allocation and project

decisions are undertaken after assessing reserve and production projections, capital and operating cost estimates and applicable

fiscal regimes that govern the respective government take from any project. All of these factors are evaluated against common

commodity pricing assumptions and the relative risks of projects. These factors are used to establish a relative ranking of projects and

capital allocation, which is then calibrated to ensure the debt and liquidity of the Company is not compromised. However, material

changes to project outcomes, and deviation from forecasted assumptions such as production volumes and rates, realized commodity

price, cost or tax and/or royalties, could have a material impact on the Company’s cash flow and financial performance, as well as

assessed impacts of impairments on Talisman’s assets. Adverse economic and/or fiscal conditions could impact the prioritization of

projects and capital allocation to these projects, which in turn could lead to adverse effects such as asset underinvestment, asset

performance, impairments or land access expiries.

Uncertainties around some of Talisman’s projects, including the Yme project, could result in changes to the Company’s capital

allocation or the $3 billion spend target being exceeded. The Company cannot be certain that funding, if needed, will be available to

the extent required or on acceptable terms. To the extent that asset sales are necessary to fund capital requirements, Talisman’s

ability to sell assets is subject to market interest. If Talisman is unable to access funding when needed on acceptable terms, the

Company may not be able to fully implement its business plans, take advantage of business opportunities or respond to competitive

pressures, any of which could have a material adverse effect on Talisman’s business, financial condition, cash flows, and results of

operations. See also ‘Risk Factors – Credit and Liquidity’ and ‘Risk Factors – Interest Rates.’

Major Incident, Major Spill / Loss of Well Control

Oil and gas drilling and producing operations are subject to many risks, including the risk of fire, explosions, mechanical failure, pipe

or well cement failure, well casing collapse, pressure or irregularities in formations, chemical and other spills, unauthorized access to

hydrocarbons, accidental flows of oil, natural gas or well fluids, sour gas releases, contamination of oil and gas, vessel collision,

structural failure, loss of buoyancy, storms or other adverse weather conditions and other occurrences. If any of these should occur,

Talisman could incur legal defence costs and remedial costs and could suffer substantial losses due to injury or loss of life, human

health risks, severe damage to or destruction of property, natural resources and equipment, pollution or other environmental damage,

unplanned production outage, cleanup responsibilities, regulatory investigation and penalties, increased public interest in Talisman’s

operational performance and suspension of operations. The Company’s horizontal and deep drilling activities involve greater risk of

mechanical problems than vertical and shallow drilling operations.

Talisman maintains insurance that contemplates both first and third party exposures for Talisman’s onshore and offshore operations

globally. There is no assurance that this insurance will be adequate to cover all losses or exposures to liability. The Company believes

that its coverage is aligned with customary industry practices and in amounts and at costs that Talisman believes to be prudent and

commercially practicable. While Talisman believes these policies are customary in the industry, they do not provide complete

coverage against all operating risks. In addition, the Company’s insurance does not cover penalties or fines that may be assessed by a

governmental authority. A loss not fully covered by insurance could have a material adverse effect on the Company’s financial

position, results of operations and cash flows. The insurance coverage that the Company maintains may not be sufficient to cover

every claim made against Talisman in the future. In addition, a major incident could impact Talisman’s reputation in such a way that it

could have a material adverse effect on the Company’s business.

TALISMAN ENERGY ANNUAL REPORT 2012

Capital Allocation and Project Decisions

Operational Risks

44
Talisman operates and drills wells in both mature producing areas such as the UK, Norway and North America and in several remote

areas in multiple countries. In 2012, Talisman carried out drilling operations in the Kurdistan Region of Iraq, Papua New Guinea,

Poland, Colombia, Peru and offshore Sierra Leone. The Company may seek new leases and/or drill in similar environments.

Health Hazards and Personal Safety Incidents

The employee and contractor personnel involved in exploration and production activities and operations of the Company, including,

but not limited to, well fracturing are subject to many inherent health and safety risks and hazards, which could result in occupational

illness or health issues, personal injury and loss of life, facility quarantine and/or facility and personnel evacuation. In particular,

employees and contractors working in well fracturing operations are subject to the possibility of loss of containment. This could lead to

exposure to the release of high pressure materials as well as collateral shrapnel from piping or vessels which could result in personal

injury and loss of life.

Security Incident

Talisman’s operations may be adversely affected by security-related incidents which are not within the control of the Company, such

as war (external and internal conflicts) and remnants of war, sectarian violence, civil unrest or criminal acts in locations where

Talisman operates. Security-related incidents may include allegations of human rights abuse associated with the provision of security

to Talisman operations. In particular, the Company faces increased security risks in the Kurdistan Region of Iraq and Colombia within

Talisman’s current portfolio. A significant security incident could result in the deferral of or termination of Company activity within the

impacted areas of operations, thus adversely impacting execution of the Company’s business strategy (e.g., delaying exploration,

causing a halt to production or forcing exit strategy processes), which could adversely affect Talisman’s financial condition.

Talisman’s exploration and production operations are subject to extensive regulation at many levels of government, including

municipal, state, provincial and federal governments, in the countries where Talisman operates and are subject to interruption or

termination by governmental and regulatory authorities based on environmental or other considerations. Moreover, Talisman has

incurred and will continue to incur costs in the Company’s efforts to comply with the requirements of environmental, safety and other

regulations. Further, the regulatory environment in the oil and gas industry could change in ways that Talisman cannot predict and

that might substantially increase the Company’s costs of compliance and, in turn, materially and adversely affect the Company’s

business, results of operations and financial condition.

Failure to comply with the applicable laws or regulations may result in significant increases in costs, fines or penalties and even

shutdowns or losses of operating licences or criminal sanctions. If regulatory approvals or permits required for operations are delayed

or not obtained, Talisman could experience delays or abandonment of projects, decreases in production and increases in costs. This

could result in an inability of the Company to fully execute its strategy and adverse impacts on its financial condition. See also ‘Risk

Factors – Fiscal Stability’ and ‘Risk Factors – Socio-Political Risks.’

Changes to existing laws and regulations or new laws could have an adverse effect on Talisman’s business by increasing costs,

impacting development schedules, reducing revenue and cash flow from natural gas and oil sales, reducing liquidity or otherwise

altering the way Talisman conducts business. There have been various proposals to enact new, or amend existing, laws and

regulations relating to greenhouse gas (GHG) emissions, hydraulic fracturing (including associated additives, water use, induced

seismicity, and disposal) and shale gas development generally. For example, in Colombia, the high level of oil and gas activity in the

country has resulted in significant delays in the granting of the required environmental licences. These delays may result in reduced

near-term production. In Quebec, delays in shale gas development are expected to continue as the Province completes a strategic

environmental assessment on shale gas development. Indonesia dissolved its upstream oil and gas regulatory body, BP Migas,

creating uncertainty for oil and gas producers. See also ‘Risk Factors – Environmental Risks.’

Talisman continues to monitor and assess any new policies, legislation, regulations and treaties in the areas where the Company

operates to determine the impact on Talisman’s operations. Governmental organizations unilaterally control the timing, scope and

effect of any currently proposed or future laws, regulations or treaties, and such enactments are subject to a myriad of factors,

including political, monetary and social pressures. Talisman acknowledges that the direct and indirect costs of such laws, regulations

and treaties (if enacted) could materially and adversely affect the Company’s business, results of operations and financial condition.

Governments may amend or create new legislation that could impact the Company’s operations and that could result in increased

capital, operating and compliance costs. The UK could increase the ring fence taxes due to the change in the UK supplementary tax.

Moreover, Talisman’s operations are subject to various levels of taxation in the countries where the Company operates. Federal,

provincial, and state income tax rates or incentive programs relating to the oil and gas industry in the jurisdictions where the Company

operates may in the future be changed or interpreted in a manner that could materially affect the economic value of the respective

assets. For example, the US Congress has been considering a revision of the immediate deduction currently available for

drilling costs.

TALISMAN ENERGY ANNUAL REPORT 2012

Regulatory Approvals and Changes to Laws and Regulations

Fiscal Stability

45
From time to time, Talisman is the subject of litigation arising out of the Company’s operations. Specific disclosure of current legal

proceedings, and the risks associated with current proceedings and litigation generally, are disclosed under the heading ‘Legal

Proceedings’ in this MD&A.

General

All phases of Talisman’s oil and natural gas business are subject to environmental regulation pursuant to a variety of laws and

regulations in the countries where Talisman does business. These laws and regulations may require the acquisition of a permit before

drilling commences, restrict the types, quantities and concentration of substances that can be released into the environment in

connection with the Company’s drilling and production activities, limit or prohibit drilling activities on certain lands lying within

wilderness, wetlands and other protected areas, and impose substantial liabilities for pollution that may result from the Company’s

operations. Talisman’s business is subject to the trend toward increased rigour in regulatory compliance and civil or criminal liability

for environmental matters in certain regions (e.g., Canada, the United States and the European Union). Compliance with

environmental legislation can require significant expenditures, and failure to comply with environmental legislation may result in the

assessment of administrative, civil and criminal penalties, the cancellation or suspension of regulatory permits, the imposition of

investigatory or remedial obligations or the issuance of injunctions restricting or prohibiting certain activities. Under existing

environmental laws and regulations, Talisman could be held strictly liable for the remediation of previously released materials or

property contamination resulting from its operations, regardless of whether those operations were in compliance with all applicable

laws at the time they were performed. Regulatory delays, legal proceedings and reputational impacts from an environmental incident

could result in a material adverse effect on the Company’s business. Increased stakeholder concerns and regulatory actions regarding

shale gas development could lead to third party or governmental claims, and could adversely affect the Company’s business and

financial condition. Although Talisman currently believes that the costs of complying with environmental legislation and dealing with

environmental civil liabilities will not have a material adverse effect on the Company’s financial condition or results of operations, there

can be no assurance that such costs will not have such an effect in the future.

Hydraulic Fracturing

Concern has been expressed over the potential environmental impact of hydraulic fracturing operations, including water aquifer

contamination and other qualitative and quantitative effects on water resources as large quantities of water are used and injected

fluids either remain underground or flow back to the surface to be collected, treated and disposed. Regulatory authorities in certain

jurisdictions have announced initiatives in response to such concerns. Federal, provincial, state, and local legislative and regulatory

initiatives relating to hydraulic fracturing, as well as governmental reviews of such activities, could result in increased costs, additional

operating restrictions or delays, and adversely affect Talisman’s production. Public perception of environmental risks associated with

hydraulic fracturing can further increase pressure to adopt new laws, regulation or permitting requirements or lead to regulatory

delays, legal proceedings and/or reputational impacts. Any new laws, regulations or permitting requirements regarding hydraulic

fracturing could lead to operational delay, increased operating costs, and third party or governmental claims. They could also increase

the Company’s costs of compliance and doing business as well as delay the development of hydrocarbon (natural gas and oil)

resources from shale formations, which may not be commercial without the use of hydraulic fracturing. Restrictions on hydraulic

fracturing could also reduce the amount of oil and natural gas that the Company is ultimately able to produce from its reserves.

If legal restrictions are adopted in areas where Talisman is currently conducting or in the future plans to conduct operations, Talisman

may incur additional costs to comply with such requirements that may be significant in nature, experience delays or curtailment in the

pursuit of exploration, development, or production activities, and perhaps even be precluded from the drilling of wells. In addition, if

hydraulic fracturing becomes more regulated, the Company’s fracturing activities could become subject to additional permitting

requirements and result in permitting delays as well as potential increases in costs. Restrictions on hydraulic fracturing could also

reduce the amount of oil and natural gas that the Company is ultimately able to produce from its reserves.

Greenhouse Gas Emissions (GHG)

Talisman is subject to various GHG emissions-related legislation. Current GHG emissions legislation does not result in material

compliance costs, but compliance costs may increase in the future and may impact the Company’s operations and financial results.

Talisman operates in jurisdictions with existing GHG legislation (e.g., UK, Norway, United States and Canada, notably Alberta and

British Columbia) as well as in regions which currently do not have GHG emissions legislation and jurisdictions where GHG emissions

legislation is emerging or is subject to change. Talisman monitors GHG legislative developments in all areas that the Company

operates. Potential new or additional GHG legislation, and associated compliance costs, may have a material impact on the Company.

TALISMAN ENERGY ANNUAL REPORT 2012

Litigation

Environmental Risks

46
Talisman is involved in the operation and maintenance of facilities and infrastructure in difficult and challenging areas, including

offshore, deepwater, jungle and desert environments. Despite Talisman’s implementation of health, safety and environmental

standards, there is a risk that accidents or regulatory noncompliance can occur, the outcomes of which, including remedial work or

regulatory intervention, cannot be foreseen or planned for. Talisman expects to incur site restoration costs over a prolonged period as

existing fields are depleted. The Company provides for decommissioning liabilities in its annual Consolidated Financial Statements in

accordance with IFRS. Additional information regarding decommissioning liabilities is set forth in the notes to the annual Consolidated

Financial Statements. The process of estimating decommissioning liabilities is complex and involves significant uncertainties

concerning the timing of the decommissioning activity; legislative changes; technological advancement; regulatory, environmental

and political changes; and the appropriate discount rate used in estimating the liability. Any change to these assumptions could result

in a change to the decommissioning liabilities to which Talisman is subject. In Talisman’s North Sea operations, changes in these

assumptions would potentially have a significant impact on the Company’s decommissioning liabilities because of the assessed size of

these future costs. There can be no assurances that the cost estimates and decommissioning liabilities are materially correct and that

the liabilities will occur when predicted. In addition, Talisman is often jointly and severally liable for the decommissioning costs

associated with Talisman’s various operations and could, therefore, be required to pay more than its net share.

The Company’s operations may be adversely affected by political or economic developments or social instability in the jurisdictions in

which it operates, which are not within the control of Talisman, including, among other things, a change in crude oil or natural gas

pricing policy and/or related regulatory delays, the risks of war, terrorism, abduction, expropriation, nationalization, renegotiation or

nullification of existing concessions and contracts, a change in taxation policies, economic sanctions, the imposition of specific drilling

obligations, the imposition of rules relating to development and abandonment of fields, jurisdictional boundary disputes, and currency

controls. As a result of continuing evolution of an international framework for corporate responsibility and accountability for

international crimes, the Company could also be exposed to potential claims for alleged breaches of international law, health, safety

and environmental regulations, and other human rights-based litigation risk. Numerous countries in which the Company is active,

including, but not limited to, the Kurdistan Region of Iraq, Colombia, Vietnam, Algeria, Sierra Leone and Papua New Guinea, have

been subject to recent economic or political instability, disputes and social unrest, and military or rebel hostilities. The potential

deterioration of socio-political security situations (i.e. political instability and/or disputes) poses increased risk, which may result in the

cessation of operations as well as the delay in payment or exports; for example, in the Kurdistan Region of Iraq with respect to the

negotiation of Iraq Federal Oil and Gas Law, and in Vietnam and Malaysia with respect to China’s claim over disputed waters in the

South China Sea. In addition, Talisman regularly evaluates opportunities worldwide, and may in the future engage in projects or

acquire properties in other nations that are experiencing economic or political instability, social unrest, military hostilities or United

Nations, US or other international sanctions. Some of the foregoing government actions may lead to political or reputational pressures

on the Company from non-governmental organizations, home governments and investors.

Talisman’s planned activities may be adversely affected if there is strong community opposition to its operations. For example, local

community concerns in parts of Colombia, the Kurdistan Region of Iraq and Papua New Guinea could potentially result in

development and production delays in those operations. There is also heightened public concern regarding hydraulic fracturing in

parts of North America which could materially affect the Company’s shale operations. In some circumstances, this risk of community

opposition may be higher in areas where Talisman operates alongside indigenous communities who may have additional concerns

regarding land ownership, usage or claim compensation.

Some of Talisman’s projects are conducted in joint venture environments where Talisman has a limited ability to influence or control

operations or future development, safety and environmental standards, and amount of capital expenditures. Companies which

operate these properties may not necessarily share Talisman’s health, safety and environmental standards or strategic or operational

goals or approach to partner relationships, which may result in accidents, regulatory noncompliance, project delays or unexpected

future costs, all of which may affect the viability of these projects and Talisman’s standing in the external market.

Talisman is also dependent on other working interest co-participants of these projects to fund their contractual share of the capital

expenditures. If these co-participants are unable to fund their contractual share of, or do not approve, the capital expenditures, the

co-participants may seek to defer programs, resulting in strategic misalignments and a delay of a portion of development of Talisman’s

programs, or the co-participants may default such that projects may be delayed and/or Talisman may be partially or totally liable for

their share.

TALISMAN ENERGY ANNUAL REPORT 2012

Environmental and Decommissioning Liabilities

Socio-Political Risks

Stakeholder Opposition

Non-Operatorship and Partner Relations

47
Some of Talisman’s projects involve transition of operatorship as part of a joint venture arrangement, which requires a significant

amount of effort and coordination. Successful handover of the operations to the partners is dependent on Talisman’s ability to

maintain equal governance and active involvement in the operations.

Successful execution of the Company’s plans is dependent on Talisman’s ability to attract and retain talented personnel who have the

skills necessary to deliver on the Company’s strategy and maintain safe operations. This includes not only key talent at a senior level,

but also individuals with the professional and technical skill sets critical for Talisman’s business, particularly geologists, geophysicists,

engineers and other specialists. As labour demand remains high and a greater percentage of the population reaches retirement age,

retention concerns are also heightened. In North America, Talisman competes for talent in two very competitive markets – Calgary

and Houston. If the Company is unable to attract and retain highly qualified petrotechnical people in these markets, its ability to

deliver may be significantly compromised. In addition, in the North Sea, high project activity has compounded competition for labour,

posing an increased retention risk. In Asia, energy demand driven by economic growth has resulted in higher levels of activity in the

sector and created strong competition for skilled technical staff. National oil companies and joint venture activities may also impose

requirements to develop their national talent, increase secondee assignments, and employ local nationals.

As increasing volumes of natural gas and liquids are brought onstream by Talisman and others, transportation infrastructure capacity

may at times be exceeded before capacity additions become available. In such an event, there is a risk that the transportation of some

of the Company’s production may be restricted or delayed until pipeline connection or infrastructure additions are complete. In

particular, Colombia’s oil export infrastructure generally continues to operate close to or at capacity, pending capacity additions which

are at various stages of approval and construction, including Phase 1 of the Bicentenario pipeline, which is due to come onstream

later in 2013. While Talisman and Equion currently have access to sufficient capacity in the key Ocensa and Oleoducto de Colombia  ́

(ODC) pipelines allowing access to the Covenas terminal and international markets, as Talisman’s production grows, the Company

may not be able to secure sufficient upstream pipeline access into Ocensa. If Talisman is unable to negotiate access to additional

pipeline capacity or to employ trucking as an alternative, Talisman’s production may be restricted or delayed and/or netbacks may be

reduced on a portion of Talisman’s production. In the Eagle Ford play, Talisman has acquired sufficient access to infrastructure for

both liquids and gas for the near and medium term (through January 2017); however, in the longer term, additional capacity and

infrastructure will be required. However, in the event there are delays in the ongoing construction of new pipelines and processing

projects in the Eagle Ford Play, Talisman’s access to additional pipeline capacity could be delayed. Another associated risk will be the

availability and diversity of contract and credit-enabled buyers depending upon the pipeline and infrastructure project with which

Talisman obtains capacity to take the product to market. Should Talisman be unable to secure access to infrastructure and qualified

buyers for its production, the Company could face reduced production and/or materially lower prices on some portion of production,

which in turn could adversely affect the Company’s operating results.

The global oil and gas industry is highly competitive. Talisman faces significant competition and many of the Company’s competitors

have resources in excess of Talisman’s available resources. The Company actively competes for the acquisition of properties, the

exploration for and development of new sources of supply, the contractual services for oil and gas drilling and production equipment

and services, the transportation and marketing of current production, and industry personnel, including, but not limited to, geologists,

geophysicists, engineers and other specialists that enable the business. Many of Talisman’s competitors have the ability to pay more

for seismic and lease rights in crude oil and natural gas properties and exploratory prospects. They can define, evaluate, bid for and

purchase a greater number of properties and prospects than Talisman’s financial or human resources permit. If the Company is not

successful in the competition for oil and gas reserves or in the marketing of production, Talisman’s financial condition and results of

operations may be adversely affected. Many of the Company’s competitors have resources substantially greater than Talisman’s and

have established positions in countries in which Talisman may seek new entry and, as a consequence, the Company may be at a

competitive disadvantage. Typically during times of high commodity prices or increased industry activity, drilling and operating costs

will also increase. These competitive forces may also lead to an overall increase in costs, which could have a negative impact on the

Company’s financial results.

From time to time, the Company may finance capital expenditures in whole or in part with debt. The volatility of credit markets can

result in market conditions that may restrict timely access and limit the Company’s ability to secure and maintain cost-effective

financing on acceptable terms and conditions. In addition, if any lender under Talisman’s syndicated bank credit facility is unable to

fund its commitment, the Company’s liquidity will be reduced by an amount up to the aggregate amount of such lender’s

commitment. See also ‘Risk Factors – Counterparty Credit Risk.’ Talisman’s financial performance and cash flow is highly sensitive to

the prevailing prices of crude oil and natural gas, which fluctuate in response to a variety of factors beyond the Company’s control. A

TALISMAN ENERGY ANNUAL REPORT 2012

Attraction, Retention and Development of Personnel

Egress and Gas & Liquids Buyers

Competitive Risk

Credit and Liquidity

48
substantial and extended decline in the prices of crude oil or natural gas could negatively impact the Company’s liquidity and/or credit

ratings, adversely affect the Company’s ability to comply with covenants under denominated long-term notes and credit facilities,

and/or affect the Company’s ability to pay dividends. See also ‘Risk Factors – Volatility of Oil and Natural Gas Prices.’

The credit rating agencies regularly evaluate the Company, and their ratings of the Company’s securities are based on a number of

factors not entirely within the Company’s control, including conditions affecting the oil and gas industry generally, and the wider state

of the economy. There can be no assurance that one or more of the Company’s credit ratings will not be downgraded. A reduction in

any of the Company’s current investment-grade credit ratings to below investment-grade could adversely affect the cost of borrowing

and/or access to sources of liquidity and capital, reduce the financing options available to the Company and increase the interest paid

on its bank credit facilities. In addition, the Company relies on access to letters of credit in the normal course of business in order to

support some of its operations. There can be no assurance that the Company will be able to obtain the necessary letters of credit. See

also ‘Risk Factors – Capital Allocation and Project Decisions.’

The Company is exposed to interest rate risk principally by virtue of its borrowings. Borrowing in floating rates exposes Talisman to

short-term movements in interest rates. Borrowing in fixed rates exposes Talisman to reset risk associated with debt maturity. Most of

the Company’s debt is issued at fixed interest rates; therefore, the Company’s main exposure to changes in interest rates would occur

in respect of short-term investments or borrowings in the event that substantial cash balances are invested in or owed to

the Company.

In the normal course of business, Talisman enters into contractual relationships with counterparties in the energy industry and other

industries, including suppliers and coventurers, counterparties to interest rate hedging, foreign exchange hedging and commodity

derivative arrangements. If such counterparties do not fulfil their contractual obligations or settle their liabilities to the Company, the

Company may suffer losses, may have to proceed on a sole risk basis, may have to forgo opportunities or may have to relinquish

leases or blocks. The Company also has credit risk arising from cash and cash equivalents held with banks and financial institutions.

While the Company maintains a risk management system that limits exposures to any one counterparty, losses due to the failure by

counterparties to fulfil their contractual obligations may adversely affect Talisman’s financial condition.

Talisman uses derivative instruments to hedge a portion of the Company’s expected production so as to manage the impact of

fluctuations in crude oil and natural gas prices on the Company’s results of operations and cash flow. Fluctuations in crude oil and gas

prices could have a material effect on the volatility of the Company’s earnings. To the extent that Talisman engages in hedging

activities to protect itself against commodity price declines, Talisman may be prevented from fully realizing the benefits of increases in

crude oil and natural gas prices above the prices established by the Company’s hedging contracts. See also ‘Risk Factors – Volatility of

Oil and Natural Gas Prices.’ When considered appropriate, the Company may also use currency swaps to manage fluctuations in

exchange rates and interest rate swaps to manage Talisman’s exposure to interest rate changes through the Company’s borrowings.

See also ‘Risk Factors – Exchange Rate Fluctuations’ and ‘Risk Factors – Interest Rates.’

Additionally, Talisman’s hedging portfolio may expose it to financial losses in certain circumstances, such as the recognition of certain

mark-to-market gains and losses on derivative instruments. The fair value of the Company’s natural gas and oil, exchange rate or

interest rate derivative instruments can fluctuate significantly between periods.

Talisman’s operations are governed by the laws of many jurisdictions, which generally prohibit bribery and other forms of corruption.

Talisman requires all employees to participate in ethics awareness training, which includes Talisman’s policies against giving or

accepting money or gifts in certain circumstances. Despite the training and policies, it is possible that Talisman, or some of its

employees or contractors, could be charged with bribery or corruption. If Talisman is found guilty of such a violation, which could

include a failure to take effective steps to prevent or address corruption by its employees or contractors, Talisman could be subject to

onerous penalties. A mere investigation itself could lead to significant corporate disruption, high legal costs and forced settlements

(such as the imposition of an internal monitor). In addition, bribery allegations or bribery or corruption convictions could impair

Talisman’s ability to work with governments or non-governmental organizations. Such convictions or allegations could result in the

formal exclusion of Talisman from a country or area, national or international lawsuits, government sanctions or fines, project

suspension or delays, reduced market capitalization and increased investor concern.

TALISMAN ENERGY ANNUAL REPORT 2012

Interest Rates

Counterparty Credit Risk

Hedging Activities

Corruption

49
Many of Talisman’s business processes depend on the availability, capacity, reliability and security of the Company’s information

technology infrastructure (IT) and Talisman’s ability to expand and continually update this infrastructure in response to the Company’s

changing needs. The Company’s IT systems are increasingly concentrated and integrated in terms of geography, number of systems,

and key contractors supporting the delivery of IT systems. The performance of Talisman’s key suppliers is critical to ensure

appropriate delivery of key services. Any failure to manage, expand and update the Company’s information technology infrastructure,

any failure in the extension or operation of this infrastructure, or any failure by the Company’s key contractors in the performance of

their services could materially and adversely harm Talisman’s business.

The ability of the IT function to support Talisman’s business in the event of a disaster such as fire, flood or loss/denial of any of the

Company’s DataCentres or major office locations and Talisman’s ability to recover key systems from unexpected interruptions cannot

be fully tested and there is a risk that if such an event actually occurs, the business continuity plan may not be adequate to

immediately address all repercussions of the disaster. In the event of a disaster affecting a DataCentre or key office location, key

systems may be unavailable for a number of days, leading to inability to perform some business processes in a timely manner.

In addition, the increasing risk of information security breaches, including more sophisticated attempts often referred to as advanced

persistent threats, requires Talisman to continually improve its ability to detect and prevent such occurrences. Disruption of critical IT

services, or breaches of information security, could have a negative effect on Talisman’s operational performance and earnings, as

well as on the Company’s reputation.

TALISMAN ENERGY ANNUAL REPORT 2012

Information Systems

50
16FEB201213133914 4MAR200902313968

Management is responsible for the Consolidated Financial Statements.

Management has prepared the Consolidated Financial Statements in accordance with International Financial Reporting Standards. If

alternative accounting methods exist, management has chosen those it deems most appropriate in the circumstances. Financial

statements are not precise since they include certain amounts based on estimates and judgments. Management has ensured that the

Consolidated Financial Statements are presented fairly in all material respects.

The Board of Directors is responsible for reviewing and approving the Consolidated Financial Statements and Management’s

Discussion and Analysis and, primarily through its Audit Committee, ensures that management fulfils its responsibilities for financial

reporting.

The Audit Committee is appointed by the Board of Directors and is composed entirely of unrelated, independent directors. The Audit

Committee meets regularly with management, and with the internal and external auditors, to discuss internal controls and reporting

issues and to satisfy itself that each party is properly discharging its responsibilities. It reviews the Consolidated Financial Statements

and the external auditors’ report. The Audit Committee also considers, for review by the Board of Directors and approval by the

shareholders, the engagement or reappointment of the external auditors.

Ernst & Young LLP, the external auditors, have audited the Consolidated Financial Statements in accordance with auditing standards

generally accepted in Canada and the standards of the Public Company Accounting Oversight Board (United States) on behalf of the

shareholders. Ernst & Young LLP have full and free access to the Audit Committee.

Management is responsible for establishing and maintaining adequate internal control over financial reporting, as defined in

rules 13a-15(f) and 15d-15(f) under the United States Securities Exchange Act of 1934, as amended.

Management has conducted an evaluation of the Company’s internal control over financial reporting based on criteria established in

Internal Control – Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).

Based on management’s assessment as at December 31, 2012, the end of the Company’s fiscal year, management has concluded

that the Company’s internal control over financial reporting is effective.

The results of management’s assessment were reviewed with the Audit Committee of the Company’s Board of Directors. Ernst &

Young LLP, the independent registered public accounting firm that audited the Company’s Consolidated Financial Statements

included herewith, independently assessed the effectiveness of the Company’s internal control over financial reporting. Ernst &

Young LLP’s attestation is located in the Independent Auditors’ Report on Internal Controls under Standards of the Public Company

Accounting Oversight Board (United States), which is an exhibit to the Company’s Annual Report on Form 40-F.

Harold N. Kvisle L. Scott Thomson

President and Chief Executive Officer Executive Vice-President, Finance and Chief Financial Officer

February 28, 2013

TALISMAN ENERGY ANNUAL REPORT 2012

REPORT OF MANAGEMENT

MANAGEMENT REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

51
4MAR201320500390

To the Shareholders of Talisman Energy Inc.

We have audited Talisman Energy Inc.’s internal control over financial reporting as at December 31, 2012, based on criteria

established in Internal Control – Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway

Commission (the COSO criteria). Talisman Energy Inc.’s management is responsible for maintaining effective internal control over

financial reporting, and for its assessment of the effectiveness of internal control over financial reporting included in the

accompanying Management Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the

Company’s internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those

standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over

financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over

financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of

internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances.

We believe that our audit provides a reasonable basis for our opinion.

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of

financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted

accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to

the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of

the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial

statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are

being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable

assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could

have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections

of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in

conditions, or that the degree of compliance with the policies or procedures may deteriorate.

In our opinion, Talisman Energy Inc. maintained, in all material respects, effective internal control over financial reporting as at

December 31, 2012, based on the COSO criteria.

We also have audited, in accordance with Canadian generally accepted auditing standards and the standards of the Public Company

Accounting Oversight Board (United States), the Consolidated Balance Sheets of Talisman Energy Inc. as at December 31, 2012 and

2011 and the Consolidated Statements of Income, Comprehensive Income, Changes in Shareholders’ Equity and Cash Flows for the

three-year period ended December 31, 2012 and our report dated February 28, 2013 expressed an unqualified opinion thereon.

Chartered Accountants

Calgary, Canada

February 28, 2013

TALISMAN ENERGY ANNUAL REPORT 2012

INDEPENDENT AUDITORS’ REPORT ON INTERNAL CONTROLS UNDER

STANDARDS OF THE PUBLIC COMPANY ACCOUNTING OVERSIGHT BOARD

(UNITED STATES)

52
4MAR201320500390

To the Shareholders of Talisman Energy Inc.

We have audited the accompanying Consolidated Financial Statements of Talisman Energy Inc., which comprise the Consolidated

Balance Sheets as at December 31, 2012 and 2011 and the Consolidated Statements of Income, Comprehensive Income, Changes

in Shareholders’ Equity and Cash Flows for the three-year period ended December 31, 2012 and a summary of significant accounting

policies and other explanatory information.

Management is responsible for the preparation and fair presentation of these consolidated financial statements in accordance with

International Financial Reporting Standards as issued by the International Accounting Standards Board, and for such internal control

as management determines is necessary to enable the preparation of consolidated financial statements that are free from material

misstatement, whether due to fraud or error.

Our responsibility is to express an opinion on these consolidated financial statements based on our audits. We conducted our audits

in accordance with Canadian generally accepted auditing standards and the standards of the Public Company Accounting Oversight

Board (United States). Those standards require that we comply with ethical requirements and plan and perform the audit to obtain

reasonable assurance about whether the consolidated financial statements are free from material misstatement.

An audit involves performing procedures to obtain audit evidence about the amounts and disclosures in the consolidated financial

statements. The procedures selected depend on the auditors’ judgment, including the assessment of the risks of material

misstatement of the consolidated financial statements, whether due to fraud or error. In making those risk assessments, the auditors

consider internal control relevant to the entity’s preparation and fair presentation of the consolidated financial statements in order to

design audit procedures that are appropriate in the circumstances. An audit also includes examining, on a test basis, evidence

supporting the amounts and disclosures in the consolidated financial statements, evaluating the appropriateness of accounting

policies used and the reasonableness of accounting estimates made by management, as well as evaluating the overall presentation of

the consolidated financial statements.

We believe that the audit evidence we have obtained in our audits is sufficient and appropriate to provide a basis for our audit opinion.

In our opinion, the Consolidated Financial Statements present fairly, in all material respects, the financial position of Talisman

Energy Inc. as at December 31, 2012 and 2011 and its financial performance and cash flows for the three-year period ended

December 31, 2012 in accordance with International Financial Reporting Standards as issued by the International Accounting

Standards Board.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States),

Talisman Energy Inc.’s internal control over financial reporting as at December 31, 2012, based on criteria established in Internal

Control – Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission, and our report

dated February 28, 2013 expressed an unqualified opinion on Talisman Energy Inc.’s internal control over financial reporting.

Chartered Accountants

Calgary, Canada

February 28, 2013

TALISMAN ENERGY ANNUAL REPORT 2012

INDEPENDENT AUDITORS’ REPORT OF

REGISTERED PUBLIC ACCOUNTING FIRM

Management’s Responsibility for the Consolidated Financial Statements

Auditors’ Responsibility

Opinion

Other Matter

53
8MAR201218294108 16FEB201213135401

December 31 (millions of US$) 2011

ASSETS

CURRENT

474

1,550

42

–

164

24

2,254

Other assets (note 11) 101

395

24

1,317

15,909

3,954

272

21,972

TOTAL ASSETS 24,226

LIABILITIES

CURRENT

60

2,622

–

371

410

3,463

Decommissioning liabilities (note 15) 2,982

346

–

4,485

2,932

10,745

Contingencies and commitments (note 23)

SHAREHOLDERS’ EQUITY

1,561

191

186

7,292

788

10,018

TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY 24,226

See accompanying notes.

On behalf of the Board:

Charles R. Williamson William R. P. Dalton

Chairman of the Board Director

TALISMAN ENERGY ANNUAL REPORT 2012

CONSOLIDATED BALANCE SHEETS

2012

Cash and cash equivalents (note 28) 721

Accounts receivable (note 9) 1,210

Risk management (note 22) 48

Income and other taxes receivable 10

Inventories (note 10) 150

Prepaid expenses 23

2,162

115

Investments (note 12) 747

Risk management (note 22) 26

Goodwill (note 8) 1,014

Property, plant and equipment (note 13) 13,005

Exploration and evaluation assets (note 13) 3,516

Deferred tax assets (note 26) 1,273

19,696

21,858

Bank indebtedness –

Accounts payable and accrued liabilities 2,250

Risk management (note 22) 81

Income and other taxes payable 137

Current portion of long-term debt (note 17) 8

2,476

2,743

Other long-term obligations (note 18) 313

Risk management (note 22) 1

Long-term debt (note 17) 4,434

Deferred tax liabilities (note 26) 1,981

9,472

Common shares (note 20) 1,639

Preferred shares (note 20) 191

Contributed surplus 121

Retained earnings 7,148

Accumulated other comprehensive income (note 21) 811

9,910

21,858

54
Years ended December 31 (millions of US$) 2011 2010

REVENUE

8,194 6,875

78 107

Total revenue and other income 8,272 6,982

EXPENSES

2,190 1,890

216 221

431 371

1,949 1,788

226 301

241 113

427 374

278 276

(310) 212

210 (87)

(192) (520)

– –

161 72

Total expenses 5,827 5,011

Income (loss) before taxes 2,445 1,971

Income taxes (note 26)

1,441 1,136

228 (110)

1,669 1,026

Net income 776 945

Per common share (US$):

0.76 0.93

0.38 0.93

Weighted average number of common shares outstanding (millions)

1,023 1,018

1,038 1,018

See accompanying notes.

TALISMAN ENERGY ANNUAL REPORT 2012

CONSOLIDATED STATEMENTS OF INCOME

2012

Sales 7,229

Other income (note 24) 83

7,312

Operating 2,452

Transportation 221

General and administrative 510

Depreciation, depletion and amortization (note 13) 2,501

Impairment (note 14) 2,744

Dry hole 269

Exploration 346

Finance costs (note 16) 276

Share-based payments expense (recovery) (note 20) (62)

(Gain) loss on held-for-trading financial instruments (note 22) 93

Gain on disposals (note 4) (1,624)

Gain on revaluation of investment (note 12) (365)

Other, net (note 25) 125

7,486

(174)

Current income tax 874

Deferred income tax (recovery) (1,180)

(306)

132

Net income 0.12

Diluted net income 0.01

Basic (note 29) 1,025

Diluted (note 29) 1,033

55
Years ended December 31 (millions of US$) 2011 2010

Net income 776 945

– (408)

(26) (12)

– 13

– (11)

– 2

Other comprehensive income (loss) (26) (418)

Comprehensive income 750 527

1) Includes net investment hedging gain of $nil (2011 – $nil; 2010 – $22 million)

2) Net of tax of $26 million (2011 – $29 million; 2010 – $1 million)

3) Net of tax of $nil (2011 – $nil; 2010 – $5 million)

4) Net of tax of $nil (2011 – $nil; 2010 – $4 million)

See accompanying notes.

TALISMAN ENERGY ANNUAL REPORT 2012

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

2012

132

Foreign currency translation (1) –

Actuarial gains (losses) relating to pension and other post-employment benefits(2) 10

Gains on derivatives designated as cash flow hedges

Gains arising during the year(3) –

Gains recognized in net income(4) –

–

10

142

56
Years ended December 31 (millions of US$) 2011 2010

COMMON SHARES

1,480 1,401

175 95

(94) (81)

– 65

– –

Balance at end of year 1,561 1,480

PREFERRED SHARES

– –

191 –

Balance at end of year 191 –

CONTRIBUTED SURPLUS

108 117

– (9)

– –

78 –

Balance at end of year 186 108

RETAINED EARNINGS

6,819 6,135

776 945

(26) (12)

(277) (249)

– –

Balance at end of year 7,292 6,819

ACCUMULATED OTHER COMPREHENSIVE INCOME

788 1,194

(26) (418)

– –

26 12

Balance at end of year 788 788

See accompanying notes.

TALISMAN ENERGY ANNUAL REPORT 2012

CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY

2012

Balance at beginning of year 1,561

Issued on exercise of stock options 15

Shares purchased and held in trust for long-term PSU plan (note 20) (25)

Shares released from trust for 2008 PSU plan (note 20) –

Shares released from trust for long-term PSU plan (note 20) 88

1,639

Balance at beginning of year 191

Issued (note 20) –

191

Balance at beginning of year 186

Settlement of 2008 PSU plan (note 20) –

Settlement of long-term PSU plan grant (note 20) (88)

Share-based payments (note 20) 23

121

Balance at beginning of year 7,292

Net income 132

Actuarial gains (losses) transferred to retained earnings 10

Common share dividends (note 20) (277)

Preferred share dividends (note 20) (9)

7,148

Balance at beginning of year 788

Other comprehensive income (loss) 10

Transfer of accumulated foreign currency loss to net income (note 4) 23

Actuarial (gains) losses transferred to retained earnings (10)

811

57
Years ended December 31 (millions of US$) 2011 2010

OPERATING ACTIVITIES

776 945

278 276

9 –

2,124 1,556

3,187 2,777

(375) 367

Cash provided by operating activities 2,812 3,144

INVESTING ACTIVITIES

Capital expenditures

(4,303) (3,566)

(156) (183)

(737) (1,340)

527 2,194

40 –

18 (630)

54 –

– –

18 274

Cash used in investing activities (4,539) (3,251)

FINANCING ACTIVITIES

(313) (10)

1,044 595

114 55

(94) (75)

191 –

(202) (197)

(277) (249)

– –

(9) (2)

11 (1)

Cash (used in) provided by financing activities 465 116

Effect of translation on foreign currency cash and cash equivalents 23 51

Net increase (decrease) in cash and cash equivalents (1,239) 60

1,653 1,593

Cash and cash equivalents net of bank indebtedness, end of year 414 1,653

Cash and cash equivalents (note 28) 474 1,655

(60) (2)

Cash and cash equivalents net of bank indebtedness, end of year 414 1,653

See accompanying notes.

TALISMAN ENERGY ANNUAL REPORT 2012

CONSOLIDATED STATEMENTS OF CASH FLOWS

2012

Net income 132

Add: Finance costs (cash and non-cash) (note 16) 276

Dividends from equity investments –

Items not involving cash (note 27) 2,433

2,841

Changes in non-cash working capital (note 27) (125)

2,716

Exploration, development and other (3,658)

Corporate acquisitions, net of cash acquired (note 6) –

Property acquisitions (note 5 and note 6) (109)

Proceeds of resource property dispositions (note 4) 964

Repayment of note receivable (note 22) –

Acquisition deposit –

Investments (20)

Proceeds on reduction in UK investment, net of cash disposed (note 4) 1,349

Changes in non-cash working capital 8

(1,466)

Long-term debt repaid (note 17) (1,807)

Long-term debt issued (note 17) 1,336

Common shares issued (note 20) 13

Common shares purchased (note 20) (25)

Preferred shares issued (note 20) –

Finance costs (cash) (190)

Common share dividends (note 20) (277)

Preferred share dividends (note 20) (9)

Deferred credits and other 13

Changes in non-cash working capital (6)

(952)

9

307

Cash and cash equivalents net of bank indebtedness, beginning of year 414

721

721

Bank indebtedness –

721

58
(tabular amounts in millions of US dollars, except as noted)

Talisman Energy Inc. (‘Talisman’ or ‘the Company’) is a public company incorporated pursuant to the laws of Canada and domiciled in

Alberta, Canada, with common shares listed on the Toronto Stock Exchange and the New York Stock Exchange under the symbol

‘TLM’. The registered office is located at Suite 2000, 888 – 3rd Street SW, Calgary, Alberta, Canada, T2P 5C5.

The Company is in the business of exploration, development, production and marketing of crude oil, natural gas and natural gas

liquids (NGLs).

The Consolidated Financial Statements as at and for the year ended December 31, 2012 were authorized for issuance by the Board

of Directors on February 28, 2013.

The Consolidated Financial Statements of Talisman Energy Inc. and its subsidiaries have been prepared in accordance with

International Financial Reporting Standards (IFRS) as issued by the International Accounting Standards Board (IASB).

The Consolidated Financial Statements have been prepared on a going concern basis using the historical cost convention, except for

derivative financial instruments and available-for-sale financial assets that have been measured at fair value.

The preparation of Consolidated Financial Statements in accordance with IFRS requires the use of certain critical accounting

estimates. It also requires management to exercise judgment in applying the Company’s accounting policies. The areas of accounting

that require a high degree of judgment or which are based upon significant estimates are disclosed in note 3(y).

a) Consolidation

The Consolidated Financial Statements include the accounts of Talisman and its subsidiaries, being those companies over which the

Company, either directly or indirectly, has control through a majority of the voting rights or the right to exercise control or to obtain the

majority of the benefits and be exposed to the majority of the risks. Subsidiaries are consolidated from the date on which control is

obtained until the date that such control ceases, using consistent accounting policies. The trust holding common shares, to settle the

Company’s obligation arising from its long-term performance share unit plan, is also consolidated since it is a special purpose entity

controlled by the Company (note 20). All intercompany balances and transactions, including unrealized profits arising from such

transactions, are eliminated upon consolidation. Unrealized losses are also eliminated unless the transaction provides evidence of an

impairment of the asset transferred. The financial statements of the subsidiaries are prepared for the same reporting period as the

parent company, using consistent accounting policies.

b) Joint Ventures and Investments

A jointly controlled asset offers joint ownership by the venturers of the assets contributed to the joint venture, without the formation of

a corporation, partnership or other entity.

A jointly controlled entity is a company, partnership or other entity in which each venturer has an interest and jointly controls the

assets of the entity, earning its own income and incurring its own liabilities and expenses. Interests in jointly controlled entities are

accounted for using proportionate consolidation. For transactions where Talisman contributes a subsidiary to a jointly controlled entity

in exchange for an interest in a joint venture, and this contribution results in a loss of control in the subsidiary, Talisman restricts any

gain arising on the contribution to the ownership interest held by the other party to the joint venture.

Substantially all of Talisman’s activities are conducted jointly with others, and the Consolidated Financial Statements reflect only the

Company’s proportionate interest in such activities.

Interests in entities over which Talisman has significant influence, but not control or joint control, are accounted for using the equity

method. Talisman’s share of the income of equity investments is recorded in the Consolidated Statements of Income. Dividends from

equity investments are included in cash provided by operating activities. Interests in entities over which Talisman does not have

significant influence are accounted for as available-for-sale financial assets. Both equity investments and investments classified as

available-for-sale assets are tested for possible impairment whenever events or changes in circumstances indicate that the carrying

value of the investment may not be recoverable.

TALISMAN ENERGY ANNUAL REPORT 2012

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

1. Corporate Information

2. Basis of Preparation

3. Significant Accounting Policies

59
c) Business Combinations and Goodwill

Business combinations are accounted for using the acquisition method. The cost of an acquisition is the aggregate of the

consideration transferred, measured at acquisition date fair value. Acquisition costs incurred are expensed. When the Company

acquires a business, it assesses the financial assets and liabilities assumed for appropriate classification and designation in

accordance with the contractual terms, economic circumstances and pertinent conditions as at the acquisition date. This includes

the separation of embedded derivatives in host contracts acquired.

Contingent consideration to be transferred by the Company is recognized at fair value at the acquisition date. Subsequent changes to

the fair value of contingent consideration recorded as a financial asset or liability are recognized in net income in accordance with

IAS 39 Financial Instruments: Recognition and Measurement.

Goodwill represents the excess of the consideration transferred over the fair value of identifiable assets acquired and liabilities

assumed in business combinations. Goodwill is not amortized but is subject to impairment reviews annually, or more frequently as

economic events dictate, as described in note 3(i).

Where goodwill forms part of an operating segment and part of the operation within that segment is disposed of, the goodwill

associated with the operation disposed of is included in the carrying amount of the operation when determining the gain or loss on

disposal. Goodwill disposed of in this circumstance is measured based on the relative values of the operation disposed of and the

portion of the segment retained.

d) Accounts Receivable

Accounts receivable are recorded based on the Company’s revenue recognition policy. The allowance for doubtful accounts is

management’s best estimate of accounts receivable balances that may not be collectible, and is reviewed quarterly.

e) Inventories

Inventories are valued at the lower of cost and net realizable value. Cost comprises direct purchase costs, cost of production and

taxes, and is determined using the first-in first-out method for product inventories and by the average cost method for materials and

supplies. Net realizable value is determined by reference to prices existing at the balance sheet date less any costs expected to be

incurred to completion and disposal.

f) Property, Plant and Equipment (PP&E)

PP&E, comprising oil and gas development and production properties and corporate assets, is stated at cost less accumulated

depreciation, depletion and amortization and accumulated impairment losses.

Oil and gas development and production expenditure is generally accounted for using the principles of the successful efforts method

of accounting. Expenditure on the construction, installation and completion of infrastructure facilities such as platforms, pipelines and

the drilling of development wells is capitalized within PP&E.

The initial cost of an asset comprises its purchase price or construction cost, any costs directly attributable to bringing the asset into

operation, the initial estimate of the decommissioning liability and capitalized borrowing costs for qualifying assets. The capitalized

value of a finance lease is also included within PP&E.

Expenditure on turnarounds comprises the cost of replacement assets or parts of assets and inspection and overhaul costs. Where an

asset or part of an asset is replaced and it is probable that future economic benefits will flow to the Company from the replacement,

the expenditure is capitalized and the replaced part is derecognized. Inspection and overhaul costs relating to turnarounds, which

generally occur annually, and all other repairs and maintenance costs are expensed when incurred.

Well injection costs incurred to stimulate depleted wells are charged as an expense when incurred. Certain stimulation costs which

increase production and reserves, extending beyond one year, are deferred in PP&E and depleted using the unit of production

method.

Exchanges of development and production assets are measured at fair value unless the exchange transaction lacks commercial

substance or the fair value of neither the asset received nor the asset exchanged is reliably measurable. The cost of the acquired

asset is measured at the fair value of the asset exchanged, unless the fair value of the asset received is more clearly evident. Where

fair value is not used, the cost of the acquired asset is measured at the carrying amount of the asset exchanged. The gain or loss

arising is recognized in net income.

The Company assesses at each reporting date whether there is an indication that its PP&E may be impaired or subject to impairment

reversals. If any indication exists, the Company estimates the asset’s recoverable amount using the methodology described in

note 3(h).

60 TALISMAN ENERGY ANNUAL REPORT 2012
g) Exploration and Evaluation (E&E) Assets

Exploration well costs are initially capitalized and, if subsequently determined to have not found sufficient reserves to justify

commercial production, are charged to dry hole expense. Exploration well costs that have found sufficient reserves to justify

commercial production, but those reserves cannot be classified as proved, continue to be capitalized as long as sufficient progress is

being made to assess the reserves and economic viability of the well and/or related project. All such carried costs are subject to

technical, commercial and management review at each reporting date to confirm the continued intent to develop or otherwise extract

value from the discovery. When this is no longer the case, the costs are written off. When proved reserves of oil and natural gas are

determined and development is sanctioned, the relevant expenditure is tested for potential impairment and then transferred to PP&E

(see note 3(h) for details of the impairment methodology). If a project no longer meets these criteria, it is tested for impairment and

transferred back from PP&E to E&E assets.

Undeveloped land costs are classified initially as E&E assets and transferred to PP&E as proved reserves are assigned.

All other exploration costs, including geological and geophysical costs and annual lease rentals, are charged to exploration expense

when incurred.

For exchanges or parts of exchanges that involve principally E&E assets, the exchange is accounted for at the carrying amount of the

asset exchanged.

h) Impairment of Assets

The Company tests PP&E and E&E assets for possible impairment whenever events or changes in circumstances indicate that the

carrying amount of an asset may not be recoverable, for example, changes in assumptions relating to future prices, future costs and

reserves. Individual assets are grouped for impairment assessment purposes at the lowest level at which there are identifiable cash

inflows that are largely independent of the cash inflows of other groups of assets, known as a cash-generating unit (CGU). If any such

indication of impairment exists, an estimate of the CGU’s recoverable amount is made. A CGU’s recoverable amount is the higher of

its fair value less costs to sell and its value in use. These assessments require the use of estimates and assumptions regarding

long-term commodity prices, discount rates, future capital expenditures requirements, reserves determination and life of field. In

addition, the Company will consider market data related to recent transactions for similar assets. E&E assets are also tested for

possible impairment when transferred to PP&E.

A previously recognized impairment loss is reversed only if there has been a change in the estimates or assumptions used to

determine the CGU’s recoverable amount since the impairment loss was recognized. If that is the case, the carrying amount of the

CGU is increased to its recoverable amount. That increased amount cannot exceed the carrying amount that would have been

determined, net of depletion, had no impairment loss been recognized for the CGU in prior periods. Such a reversal is recognized in

net income, following which the depletion charge is adjusted in future periods to allocate the CGU’s revised carrying amount on a

systematic basis over its remaining useful life.

i) Goodwill

Goodwill is tested for impairment annually and when circumstances indicate that the carrying amount may be impaired. The

impairment test requires that goodwill be allocated to CGUs, which Talisman has determined by aggregating locations having similar

economic characteristics and/or which are in similar geographic locations, and which correspond with the operating segments

described in note 31, except for locations within the Other segment, which are generally grouped by country. Impairment is

determined for goodwill by assessing the recoverable amount (based on fair value less costs to sell) of each segment or country, as

appropriate, to which the goodwill relates. Where the recoverable amount of the segment or country, as appropriate, is less than the

carrying amount, an impairment loss is recognized. Goodwill impairment losses cannot be reversed.

j) Depreciation, Depletion and Amortization (DD&A)

Capitalized costs of proved oil and gas properties are depleted using the unit of production method. For purposes of these

calculations, production and reserves of natural gas are converted to barrels (bbls) on an energy equivalent basis at a ratio of six

thousand cubic feet (mcf) of natural gas for one barrel (bbl) of oil. Depletion and depreciation rates are updated in each reporting

period that a significant change in circumstances, including reserves revisions, occurs.

Successful exploratory wells and development costs are depleted over proved developed reserves. Significant development costs

incurred in connection with proved undeveloped reserves are excluded from depletion until the reserves are developed.

Acquired resource properties with proved reserves, including offshore platform costs, are depleted over total proved reserves.

Acquisition costs of probable reserves are not depleted or amortized while under active evaluation for commercial reserves. Costs are

transferred to depletable costs as proved reserves are recognized.

TALISMAN ENERGY ANNUAL REPORT 2012 61
Costs associated with significant development projects are not depleted until the asset is substantially complete and ready for its

intended use. Unproved land acquisition costs that are individually material are not amortized, but are assessed for impairment and

transferred to depletable costs as proved reserves are recognized. Unproved land acquisition costs that are individually immaterial are

amortized on a straight-line basis over the average lease term. Gas plants are depreciated on a straight-line basis over their estimated

remaining useful lives, not to exceed the estimated remaining productive lives of related fields. Pipelines and corporate assets are

depreciated using the straight-line method at annual rates of 4% and 5–33%, respectively. Gas plants and pipelines in the North Sea

are depleted using the unit of production method based on the related fields.

k) Non-Current Assets Held for Sale

Non-current assets classified as held for sale and associated liabilities are measured at the lower of carrying amount and fair value

less costs to sell, and are presented as current on the Consolidated Balance Sheets.

Non-current assets are classified as held for sale if their carrying amounts will be recovered through a sale transaction rather than

through continuing use. This condition is regarded as met only when the sale is highly probable and the asset or disposal group is

available for immediate sale in its present condition. Management must be committed to the sale, which should be expected to

qualify for recognition as a completed sale within one year from the date of classification.

PP&E is not depreciated once classified as held for sale.

l) Decommissioning and Environmental Liabilities

Decommissioning liabilities are recognized when the Company has a legal or constructive obligation as a result of past events, it is

probable that an outflow of resources will be required to settle the obligation and a reliable estimate of the amount of the obligation

can be made. A corresponding amount equivalent to the liability is recognized as part of the cost of the related PP&E or E&E asset.

Decommissioning liabilities are carried on the Consolidated Balance Sheet at their discounted present value, which is remeasured

each reporting period in order to reflect the period end discount rate. The liabilities are calculated using a weighted average

credit-adjusted risk free rate, and are accreted over time for the change in their present value, with this accretion expense included in

finance costs on the Consolidated Statements of Income. Actual expenditures incurred are charged against the accumulated

obligation. Any difference between the recorded decommissioning liability and the actual retirement costs incurred is recorded as a

gain or loss.

The increase in capitalized costs is amortized to income on a basis consistent with DD&A of the underlying assets. Subsequent

changes in the estimated decommissioning liabilities are capitalized and amortized over the remaining useful life of the underlying

asset.

Liabilities for environmental costs are recognized when an obligation exists and the associated costs can be reliably estimated.

Generally, the timing of recognition of these liabilities coincides with the commitment to a formal plan of action or, if earlier, on

divestment or on closure of inactive sites. The amount recognized is the best estimate of the expenditure required. Where the liability

will not be settled for a number of years, the amount recognized is the present value of the estimated future expenditure. These

estimates are included in decommissioning liabilities.

m) Finance Costs and Long-Term Debt

Finance costs include interest and other costs that Talisman incurs in connection with the borrowing of funds, as well as accretion

expense relating to the Company’s decommissioning liabilities.

Finance costs associated with major development projects are capitalized and included in the carrying amounts of the related assets

until they are completed and ready for use. These costs are subsequently amortized to income with the related assets. The amount of

borrowing costs capitalized for the period is determined by applying the weighted average interest rate applicable to appropriate

borrowings outstanding during the period to the average amount of capitalized expenditure for the qualifying assets.

All other finance costs are recognized on the Consolidated Statements of Income in the period in which they are incurred.

The classification of debt instruments in the Consolidated Balance Sheets reflects contractual requirements and management’s intent

in respect of the refinancing of those instruments. In particular, the classification of bankers’ acceptances, when outstanding, reflects

management’s intent to refinance a short-term obligation with a committed long-term facility with the same lender.

n) Foreign and Reporting Currency

Talisman’s functional currency is the US$.

Prior to January 1, 2011 in the UK and prior to January 1, 2010 in Canada and Norway, the Company’s operations were translated

from UK£, C$ and NOK, respectively, into US$ using the current rate method whereby assets and liabilities were translated at

62 TALISMAN ENERGY ANNUAL REPORT 2012
year-end exchange rates, while revenues and expenses were converted using average rates for the period. Gains and losses arising on

translation from UK£, C$ and NOK to US$ were deferred and included in a separate component of shareholders’ equity described as

accumulated other comprehensive income.

As a result of changes in the composition of revenue and costs and changes in intercompany loan arrangements, management has

determined that the functional currency of the Company’s UK operation is more closely linked to the US$. Accordingly, effective

January 1, 2011, this operation has been accounted for as a US$ functional currency entity. As a result, foreign currency translation

adjustments remained in accumulated other comprehensive income until Talisman reduced its ownership in its UK subsidiary

(note 4). Following the change in the functional currency of the UK operation on January 1, 2011, the debt denominated in UK£ was

no longer designated as a hedge of Talisman’s net investment in the UK and, accordingly, foreign exchange gains and losses are

recorded on the Consolidated Statements of Income.

The Company’s operations in Canada and Norway are accounted for as US$ functional currency entities. As a result, foreign currency

translation adjustments remain in accumulated other comprehensive income until Talisman reduces its net investment in its

Canadian or Norwegian subsidiaries.

Foreign operations are translated as follows: monetary assets and liabilities at exchange rates in effect at the balance sheet date,

non-monetary assets and liabilities at rates in effect on the dates the assets were acquired or liabilities were assumed, and revenues

and expenses at rates of exchange prevailing on the transaction dates. Gains and losses on translation are reflected in income

when incurred.

o) Employee Benefit Plans

The cost of providing benefits under the Company’s defined benefit pension plans and non-pension post-employment benefit plans is

determined using the projected benefit method pro-rated on service and management’s best estimate of expected plan investment

performance, salary escalation and employee retirement ages. There is uncertainty relating to the assumptions used to calculate the

net benefit expense and accrued benefit obligation, due to their long-term nature.

The discount rate used to determine the accrued benefit obligation is determined by reference to market interest rates at the

measurement date on high quality debt instruments with cash flows that match the timing and amount of expected benefit payments.

The Company recognizes all actuarial gains and losses immediately in other comprehensive income (loss) and transfers them to

retained earnings in the year recorded.

Payments to defined contribution plans are expensed as incurred, which is as the related service is rendered.

The pension benefits of key management personnel represent the attributable amount of the net benefit expense of the plans in

which they participate.

p) Financial Instruments

The Company classifies its financial instruments into one of the following categories: held-for-trading assets and liabilities, assets

available-for-sale, loans and receivables, assets held-to-maturity and other financial liabilities. All financial assets and liabilities are

recognized on the Consolidated Balance Sheets when the Company becomes a party to the contractual requirements of the

instrument. All financial instruments are measured at fair value on initial recognition. Transaction costs are included in the initial

carrying amount of financial instruments except for held-for-trading items, in which case they are expensed as incurred.

Measurement in subsequent periods depends on the classification of the financial instrument.

In conducting its business, the Company may use derivative financial instruments in order to manage risks associated with

fluctuations in commodity prices, interest rates and foreign currency exchange rates.

Non-Hedge Financial Instruments

Held-for-trading financial assets and liabilities are subsequently measured at fair value with changes in fair value recognized in net

income. Financial assets available-for-sale are subsequently measured at fair value with changes in fair value recognized in other

comprehensive income (loss), net of tax. Financial assets held-to-maturity, loans and receivables and other financial liabilities are

subsequently measured at amortized cost using the effective interest rate method.

Cash equivalents are classified as loans and receivables and are measured at carrying value, which approximates fair value, due to

the short-term nature of these instruments. Accounts receivable and certain other assets that are financial instruments are classified

as loans and receivables. Bank indebtedness, accounts payable and accrued liabilities, certain other long-term obligations and

current and long-term debt are classified as other financial liabilities. Financial liabilities are derecognized when the obligation under

the liability is discharged, cancelled or expires. Financial instruments that are derivative contracts are considered held-for-trading

unless they are designated as a hedge. The financial derivative contracts outstanding at December 31, 2012 are disclosed in note 22.

TALISMAN ENERGY ANNUAL REPORT 2012 63
Derivatives embedded in other financial instruments and non-financial host contracts are treated as separate derivatives when their

risks and characteristics are not closely related to those of the host contract. Contracts are assessed for embedded derivatives when

the Company becomes a party to them, including at the date of a business combination. Embedded derivatives requiring separation

are measured at fair value at each balance sheet date and any gains or losses arising from changes in fair value are recognized in

net income.

Hedges

The Company may designate financial instruments as a hedging instrument for accounting purposes. Hedge accounting requires the

designation of a hedging relationship, including a hedged and a hedging item, identification of the risk exposure being hedged and an

expectation that the hedging relationship will be highly effective throughout its term. In addition, in the case of anticipated

transactions, it must also be highly probable that the transaction designated as being hedged will occur. The Company assesses, both

at the hedge’s inception and on an ongoing basis, whether the derivative financial instruments designated as hedges are highly

effective in offsetting changes in fair value or cash flows of the hedged items. If the derivative financial instrument that has been

designated as a hedge is terminated or is no longer designated as part of the hedging relationship, the gain or loss on the hedge at

that date is deferred in other comprehensive income (loss) and recognized in net income concurrently with the anticipated

transaction. If the forecast transaction is no longer expected to occur, the gain or loss on the hedge at that date is recognized

immediately in net income. The Company had the following hedges during the periods covered by these Consolidated Financial

Statements:

Cash flow hedges – Until January 2011, when the cross-currency hedge and related debt were settled, the effective portion of

changes in the fair value of financial instruments designated as cash flow hedges was recognized in other comprehensive

income (loss), net of tax, with any ineffective portion being recognized immediately in net income. Gains and losses were

recovered from other comprehensive income (loss) and recognized in net income in the same period as the hedged item

was realized.

Net investment hedges – Until December 31, 2010, foreign exchange gains and losses on UK£ debt designated as a net

investment hedge would have been recognized in other comprehensive income (loss). These gains and losses would have been

recovered from other comprehensive income (loss) and recognized in net income if the net investment was reduced below the

value of the debt. Since January 1, 2011, following the change in functional currency described in note 3(n), the debt

denominated in UK£ is no longer designated as a hedge of the Company’s net investment.

Own Use Exemption

Contracts that were entered into and continue to be held for the purpose of the receipt or delivery of a non-financial item in

accordance with the Company’s expected purchase, sale or usage requirements fall within the exemption from IAS 32 and IAS 39,

which is known as the ‘own use’ exemption. The Company enters into physical commodity contracts in the normal course of

business, including contracts with fixed terms. The Company’s production is expected to be sufficient to deliver all required volumes

under these contracts. No amounts are recognized in the Consolidated Financial Statements related to these contracts until such time

as the associated volumes are delivered.

q) Comprehensive Income and Equity

The Consolidated Statements of Comprehensive Income reflects net income and items of other comprehensive income (loss) which

comprise changes in the fair value of financial instruments designated as cash flow hedges, to the extent they are effective, gains and

losses recovered from other comprehensive income (loss) and recognized in net income, and actuarial gains and losses arising in

relation to the Company’s employee benefit plans. Until December 31, 2010, foreign currency translation gains or losses arising from

the translation of the Company’s foreign operations or reductions in the net investments therein and translation from the Company’s

functional currency to its presentation currency also gave rise to other comprehensive income (loss). See note 3(n) for more details.

r) Income Taxes

Income taxes comprise current tax, deferred tax and Petroleum Revenue Tax (PRT) and are recognized on the Consolidated

Statements of Income except to the extent they relate to items recognized in other comprehensive income (loss) or directly in equity.

PRT is treated as an income tax and deferred PRT is accounted for on a temporary difference basis.

Interest and penalties assessed by taxing authorities on any underpayment of income tax are accrued and classified as a component

of income taxes on the Consolidated Statements of Income.

Certain of the Company’s contractual arrangements in foreign jurisdictions stipulate that income taxes be paid by the respective

national oil company out of its entitlement share of production. Such amounts are included in income taxes at the statutory tax rate in

effect at the time of production.

64 TALISMAN ENERGY ANNUAL REPORT 2012
The Company recognizes in its financial statements the best estimate of the impact of a tax position by determining if the available

evidence indicates whether it is more likely than not, based solely on technical merits, that the position will be sustained on audit. The

Company estimates the amount to be recorded by weighting all possible outcomes by their associated probabilities.

Current Tax

Current tax is based on estimated taxable income and tax rates which are determined pursuant to the tax laws that are enacted or

substantively enacted at the balance sheet date.

Deferred Tax

Deferred tax is determined using the liability method. Under the liability method, deferred tax is calculated based on the differences

between assets and liabilities reported for financial accounting purposes and those reported for income tax purposes. Deferred tax

assets and liabilities are measured using substantively enacted tax rates. The impact of a change in tax rate is recognized in net

income in the period in which the tax rate is substantively enacted.

Deferred tax assets and liabilities are offset only when a legally enforceable right of offset exists and the deferred tax assets and

liabilities arose in the same tax jurisdiction and relate to the same taxable entity.

s) Revenue Recognition

Revenues associated with the sale of crude oil, natural gas and NGLs are recognized at the fair value of the consideration received or

receivable when the significant risks and rewards of ownership have been transferred, which is when title passes from the Company

to the customer. For the Company’s international operations, generally, customers take title when the crude oil is loaded onto a tanker.

The Company employs the entitlement method in accounting for crude oil and natural gas sales and records a receivable from a joint

interest participant if a participant sells more than its proportionate share of crude oil or natural gas production. Crude oil and natural

gas produced and sold, below or above the Company’s working interest share in the related resource properties, results in production

underliftings, or overliftings. Underliftings are recorded as inventory at the cost to produce and transport the product to storage tanks,

and overliftings are recorded in accounts payable and accrued at the sales value. Underliftings are reversed from inventory when the

crude oil is lifted and sold, with the sales proceeds recorded as revenue and the cost of the inventory expensed. Overliftings are

reversed from accounts payable and accrued liabilities when sufficient volumes are produced to make up the overlifted volume.

Amounts received under take-or-pay gas sales contracts in respect of undelivered volumes are accounted for as deferred income in

accounts payable and accrued liabilities and recognized as revenue when volumes are delivered. Transportation expenses are

reported as a separate expense and are not netted against revenue.

A significant portion of the Company’s operations outside North America and the North Sea are governed by Production Sharing

Contracts (PSCs). Under PSCs, revenues are derived from cost recovery oil and gas and profit oil and gas. Generally, cost recovery oil

and gas allows the Company to recover its capital and production costs and, as appropriate, the costs carried by the Company on

behalf of state oil companies from production. Profit oil and gas is allocated to the host government and contract parties in

accordance with their respective equity interests.

All taxes collected from customers that are remitted to governments are excluded from revenues.

Certain of the Company’s foreign operations are conducted jointly with the respective national oil companies. These operations are

reflected in the Consolidated Financial Statements based on Talisman’s working interest in such activities. All other government takes,

other than income taxes, are considered to be royalty interests. Royalties on production from these joint foreign operations represent

the entitlement of the respective governments to a portion of Talisman’s share of crude oil, natural gas and NGLs production and are

recorded using rates in effect under the terms of contracts at the time of production.

Sales as reported represents the Company’s share of revenues from the sale of crude oil, natural gas and NGLs and is presented after

deduction of royalty payments to governments and other mineral interest owners.

t) Leases

Leases that transfer substantially all of the benefits and risks of ownership to Talisman are accounted for at the commencement of the

lease term as finance leases and recorded as PP&E at the fair value of the leased asset, or, if lower, at the present value of the

minimum lease payments, together with an offsetting liability. Finance charges are allocated to each period so as to achieve a

constant rate of interest on the remaining balance of the liability and are recognized in net income. Capitalized leased assets are

depreciated over the shorter of the estimated useful life of the asset or the lease term.

All other leases are accounted for as operating leases and the lease costs are expensed as incurred.

TALISMAN ENERGY ANNUAL REPORT 2012 65
u) Share-Based Payments

Talisman has stock option plans, cash unit plans, a performance share unit (PSU) plan, deferred share unit plans and restricted share

unit plans, under which it receives services from employees and directors as consideration for cash payments or equity instruments of

the Company. The long-term PSU plan must be settled in shares. The cash unit, deferred share unit and restricted share unit plans

must be settled in cash. The stock option plans may be settled in cash at the option of the holder or the underlying share can

be purchased.

Equity-Settled Awards

The Company uses the Black-Scholes pricing model to estimate the fair value of equity-settled awards.

For the PSU plans, the Company determines the fair value of the units on the date of grant and recognizes the fair value over the

vesting period as share-based payments expense and contributed surplus.

Cash-Settled Awards

The Company uses the Black-Scholes pricing model to estimate the fair value of cash-settled awards. Fair value is established initially

at the grant date and the obligation is revalued each reporting period until the awards are settled with any changes in the obligation

recognized as share-based payments expense (recovery) on the Consolidated Statements of Income, except for the changes related

to deferred share units, which are included in general and administrative expenses.

The stock option plans are classified as liability instruments and remeasured at their fair value at the end of each reporting period.

For plans having vesting conditions, the total expense is recognized over the vesting period, which is the period over which all of the

specified vesting conditions are to be satisfied. At the end of each reporting period, the Company revises its estimates of the number

of options and units that are expected to vest based on the vesting conditions and recognizes the impact of the revision to original

estimates, if any, in net income.

v) Net Income and Diluted Net Income Per Share

Net income per share is calculated by dividing net income less after-tax cumulative preferred share dividends by the weighted

average number of common shares outstanding. Diluted net income per share is calculated giving effect to the potential dilution that

could occur if stock options were exercised in exchange for common shares.

The method the Company uses to determine the dilutive impact of stock options assumes that any proceeds from the exercise of

in-the-money stock options would be used to purchase common shares at the average market price during the period. In periods

when a share-based payments recovery is reported, net income used in the dilution calculation is reduced by the amount of

the recovery.

For stock options that may be settled in cash or shares at the employees’ option, the more dilutive impact of cash settlement and

equity settlement is used in calculating diluted net income per share regardless of how the stock option plan is accounted for. Stock

options that are reported as cash-settled for accounting purposes may require an adjustment to the numerator in the diluted net

income per share calculation for any changes in net income that would result if the stock options had been reported as equity

instruments.

w) Cash and Cash Equivalents

Cash and cash equivalents include cash on deposit with banks and interest-bearing short-term investments with an original maturity

of three months or less. Cash and cash equivalents are stated at cost, which approximates fair value.

For the purpose of the Consolidated Statements of Cash Flows, cash and cash equivalents consist of cash and cash equivalents as

defined above, net of bank indebtedness.

x) Segmented Information

The Company’s reporting segments are established on the basis of having similar economic characteristics and/or which are in similar

geographic locations and those components of the Company that are evaluated regularly by the chief operating decision maker in

deciding how to allocate resources and in assessing performance.

Effective January 1, 2011, the composition of the Company’s segments changed such that the activities in the UK and Norway are

reported as a single North Sea segment since, in management’s judgment, the assets in those locations share similar economic

characteristics. Comparative period balances have been restated accordingly. See note 31 for disclosure of segmented information.

66 TALISMAN ENERGY ANNUAL REPORT 2012
y) Significant Accounting Judgments, Estimates and Assumptions

To facilitate the timely preparation of the Consolidated Financial Statements, management has made estimates and assumptions

regarding certain assets and liabilities and contingent assets and liabilities at the date of the Consolidated Financial Statements and

the reported amounts of revenues and expenses during the periods noted. Such estimates relate primarily to unsettled transactions

and events as of the date of the Consolidated Financial Statements. Accordingly, actual results may differ from estimated amounts.

DD&A, the fair value of PP&E and E&E assets, amounts recognized for impairment charges and reversals and the recognition of

assets acquired and liabilities assumed upon a business combination are impacted by estimates of oil and natural gas reserves,

contingent resources, commodity prices, and capital and operating costs required to develop and produce those reserves. The

Company also used a variety of market metrics, described in note 14, in assessing the fair value of the PP&E and E&E assets. By their

nature, market metrics, estimates of reserves and resources and the related future cash flows are subject to measurement

uncertainty, and the impact of differences between actual and estimated amounts on the Consolidated Financial Statements of future

periods could be material. The measurement of impairment charges and reversals is also dependent upon management’s judgment

in determining CGUs.

Inherent in the calculation of decommissioning liabilities are numerous assumptions and judgments, including the ultimate

settlement amounts, inflation factors, credit-adjusted discount rates, timing of settlement and changes in the legal, regulatory,

environmental and political environments. To the extent future revisions to assumptions impact the amount of decommissioning

liabilities, a corresponding adjustment is made to the PP&E and/or E&E assets balance.

The values of pension assets and obligations and the amount of the net benefit expense charged to net income depend on certain

actuarial and economic assumptions which, by their nature, are subject to measurement uncertainty.

The measurement of income tax expense, and the related provisions on the Consolidated Balance Sheets, is subject to uncertainty

associated with future recoverability of oil and natural gas reserves, commodity prices, the timing of future events and changes in

legislation, tax rates and interpretations by tax authorities.

The fair values of financial instruments are estimated based upon market and third party inputs. These estimates are subject to

change with fluctuations in commodity prices, interest rates, foreign currency exchange rates and estimates of non-performance risk.

The fair values of equity-settled and cash-settled share-based payment awards are estimated using the Black-Scholes pricing model.

These estimates depend on certain assumptions, including share price volatility, risk free interest rate, the term of the awards, the

forfeiture rate and the annual dividend yield which, by their nature, are subject to measurement uncertainty.

The designation of the Company’s functional currency is a management judgment based on the composition of revenue and costs in

the locations in which it operates.

Provisions are recorded when the Company has a present legal or constructive obligation as a result of a past event, it is probable that

an outflow of resources will be required to settle the obligation and a reliable estimate can be made of the amount of the obligation.

Where appropriate, the future cash flow estimates are adjusted to reflect risks specific to the liability.

Contingent liabilities are possible obligations whose existence will only be confirmed by future events not wholly within the control of

the Company. Contingent liabilities are not recognized in the financial statements but are disclosed unless the possibility of an outflow

of economic resources is considered remote. The evaluation of the likelihood of the contingent events requires management

judgment as to the probability of exposure to potential loss.

z) Accounting Standards and Interpretations Issued but Not Yet Effective

The following pronouncements from the IASB are applicable to Talisman and will become effective for future reporting periods, but

have not yet been adopted. The Company intends to adopt these standards, if applicable, when they become effective on

January 1, 2013:

Effective January 1, 2013

IAS 1 Presentation of Items of Other Comprehensive Income – Amendments to IAS 1. The amendments to IAS 1 improve the

quality of the presentation of other comprehensive income (OCI). The amendments require companies preparing financial

statements in accordance with IFRS to group together items within OCI that may be reclassified to the profit or loss section of the

income statement. The amendments also reaffirm existing requirements that items in OCI and profit or loss should be presented as

either a single statement or two consecutive statements. The amendments to IAS 1 are effective for annual periods beginning on or

after July 1, 2012. The amendment affects presentation only and has no impact on the Company’s financial position

or performance;

TALISMAN ENERGY ANNUAL REPORT 2012 67

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IFRS 7 Disclosures – Offsetting Financial Assets and Financial Liabilities – Amendments to IFRS 7. These amendments to IFRS 7

introduce new disclosure requirements about the effects of offsetting financial assets and financial liabilities and related

arrangements on an entity’s financial position. The disclosures will provide users with information that may be useful in evaluating

the effect of any netting arrangements in an entity’s financial position. The amendments to IFRS 7 are effective for annual periods

beginning on or after January 1, 2013. The amendments affect disclosure only and will not impact the Company’s financial position

or performance;

IFRS 10 Consolidated Financial Statements – establishes the accounting principles for consolidated financial statements when one

entity controls other entities and replaces IAS 27 Consolidated and Separate Financial Statements and the related provisions of

SIC-12 Consolidation – Special Purpose Entities. This standard establishes a new control model that applies to all entities. This

standard will have no significant impact on Talisman’s financial results as all subsidiaries are 100% owned, the trust holding

common shares has been consolidated since it is a special purpose entity controlled by the Company and all other results are from

joint operations and ventures;

IFRS 11 Joint Arrangements – establishes the accounting principles for parties to a joint arrangement and replaces IAS 31 Interest

in Joint Ventures and SIC-13 Jointly Controlled Entities: Non-Monetary Contributions by Venturers. This standard requires a party to

assess its rights and obligations from the arrangement in order to determine whether a joint arrangement represents a joint venture

or a joint operation. As at December 31, 2012, the Company proportionately consolidated all its interest in joint arrangements.

Upon adoption of this standard on January 1, 2013, the Company will be required to account for its investments in Talisman

Sinopec Energy UK Limited (TSEUK) and Equion Energ  ́ ıa Limited (Equi  ́ on) using the equity method of accounting and requires  ́

retrospective application;

IFRS 12 Disclosure of Interests in Other Entities – establishes comprehensive disclosure requirements for subsidiaries, joint

arrangements, associates, and unconsolidated structured entities and replaces existing disclosures in related standards. The

impact on Talisman will be increased disclosure regarding its equity interest in TSEUK and Equion;  ́

IFRS 13 Fair Value Measurement – establishes a single framework for fair value measurement and disclosures when fair value is

required or permitted under IFRS. Talisman is currently assessing the impact that this standard will have on the financial position

and performance. Based on the Company’s analysis, this standard is expected to increase the financial statement disclosures, but

is not expected to have a material impact on Talisman’s financial position;

IAS 19 Employee Benefits (revised) – IAS 19 provides the accounting and disclosure requirements by employers for employee

benefits. The amendments to IAS 19 will provide investors and other users of financial statements with a better understanding of an

entity’s obligations resulting from the provision of defined benefit plans and how those obligations will affect its financial position,

financial performance and cash flow. Among other things, the amendment eliminates the option to defer the recognition of gains

and losses, known as the ‘corridor method’, and will impact the net benefit expense as the expected return on plan assets will be

calculated using the same interest rate as applied for the purpose of discounting the benefit obligation. The amendments to IAS 19

are effective for annual periods beginning on or after January 1, 2013. As stated in the Company’s accounting policies actuarial

gains and losses for defined benefit plans are recognized in full in the period in which they occur in OCI and such actuarial gains

and losses are also immediately recognized in retained earnings and are not reclassified to profit and loss in subsequent periods.

Therefore, the amendment which eliminates the ‘corridor method’ will have no impact on the Company’s financial position or

performance. The Company does not expect the net benefit expense to change significantly as a result of applying the rate used to

discount the benefit obligation as the rate used for calculating the Company’s expected return on plan assets. Any adjustment

required to reflect the actual return on plan assets as compared to the expected return on assets will be recorded in OCI. The

amended standard requires retrospective application;

IAS 27 Separate Financial Statements – establishes the accounting and disclosure requirements for investments in subsidiaries,

joint ventures, and associates when an entity prepares separate financial statements and replaces the current IAS 27 Consolidated

and Separate Financial Statements as the consolidation guidance is included in IFRS 10 Consolidated Financial Statements. This

standard is not expected to have an impact on Talisman’s Consolidated Financial Statements; and

IAS 28 Investments in Associates and Joint Ventures – establishes the accounting for investments in associates and defines how

the equity method is applied when accounting for associates and joint ventures. This standard is not expected to have an impact on

Talisman’s Consolidated Financial Statements.

Effective Subsequent to 2013

IAS 32 Offsetting Financial Assets and Financial Liabilities – Amendments to IAS 32, Financial Instruments Presentation. The

amended standard requires entities to disclose both gross information and net information about both instruments and transactions

eligible for offset in the statement of financial position and instruments and transactions subject to an agreement similar to a master

netting arrangement. The scope includes derivatives, sale and repurchase agreements and reverse sale and repurchase

agreements and securities borrowing and securities lending agreements. The amendments to IAS 32 are effective for annual

68 TALISMAN ENERGY ANNUAL REPORT 2012

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periods beginning on or after January 1, 2014 and require retrospective application. The Company is currently evaluating the

impact of adopting this amended standard;

IFRS 9 Financial Instruments – as issued, reflects the first phase of the IASB’s work on the replacement of IAS 39 and applies to

classification and measurement of financial assets and financial liabilities as defined in IAS 39. The standard was initially effective

for annual periods beginning on or after January 1, 2013, but an amendment issued in December 2011 moved the mandatory

effective date to January 1, 2015. In subsequent phases, the IASB will address hedge accounting and impairment of financial

assets. The adoption of the first phase of this standard may have an effect on the classification and measurement of the Company’s

financial assets, but will not have an impact on classification and measurement of financial liabilities. The Company is currently

evaluating the potential impacts and will quantify the effect in conjunction with the other phases, when issued, to present a

comprehensive picture.

On December 17, 2012, Talisman completed the sale of 49% of its equity interest in Talisman Energy (UK) Limited (TEUK), now

renamed TSEUK, which owns substantially all of Talisman’s UK assets, to Addax Petroleum UK Limited (APUK), an indirect whollyowned subsidiary of Sinopec, for cash consideration of $1.5 billion based on an effective date of January 1, 2012. The $1.5 billion

cash consideration is comprised of $1,349 million in cash ($1,467 million in cash received net of $118 million cash disposed) and

$33 million of working capital and other adjustments.

The transaction resulted in a non-taxable gain of $860 million, which is included in the ‘Gain on disposals’ on the Consolidated

Statements of Income. Talisman will continue to hold 51% of the joint venture company, with APUK holding the remaining 49%.

Since TSEUK is a jointly controlled entity, the Company is proportionately consolidating its interest within the North Sea segment for

the period December 17, 2012 through December 31, 2012. As a result of the transaction, $23 million of exchange losses previously

accumulated in other comprehensive income were included in the ‘Gain on disposals’ on the Consolidated Statements of Income.

In 2012, Talisman completed sales of oil and gas producing assets in western Canada for proceeds of $437 million, resulting in gains

of $189 million, net of tax of $67 million.

In 2012, Talisman sold non-core coal assets in northeast British Columbia for cash consideration of $496 million after transaction

costs. The carrying value of these assets was $nil and a gain of $372 million was recorded, net of tax of $124 million.

During 2011, Talisman completed a transaction creating a strategic partnership with Sasol to develop the Farrell Creek assets in

Talisman’s Montney shale play in British Columbia. Talisman sold 50% of its working interests in the Farrell Creek assets for

approximately $1 billion, comprising $238 million in cash and approximately $800 million of certain future development costs. The

transaction resulted in a pre-tax gain of $89 million, which is included in ‘Gain on disposals’ on the Consolidated Statements

of Income.

Also in 2011, Talisman completed an additional transaction with Sasol to develop the Cypress A assets in Talisman’s Montney shale

play in British Columbia. Talisman sold 50% of its working interests in the Cypress A assets for approximately $1.1 billion, comprising

$257 million in cash and approximately $800 million of certain future development costs. The transaction resulted in a pre-tax gain of

$113 million, which is included in ‘Gain on disposals’ on the Consolidated Statements of Income.

During the year ended December 31, 2010, Talisman completed the sale of oil and gas producing properties in North America with a

carrying value of approximately $2 billion for aggregate proceeds of approximately $2.2 billion. The net investment in the Company’s

Canadian operations was reduced as a result of the transactions occurring in 2010 and, accordingly, $367 million of exchange gains

previously accumulated in other comprehensive income were included in the gains of $520 million, which are included in ‘Gain on

disposals’ on the Consolidated Statements of Income. Tax of $38 million was recorded in respect of these transactions.

During 2010, Talisman completed the sale of oil and gas producing assets in Tunisia (included in the Other segment) for proceeds of

$23 million, resulting in a loss of $5 million, net of tax of $nil. The operating results related to these assets held for sale were included

in net income for the year ended December 31, 2010 and the loss was included in ‘Gain on disposals’ on the Consolidated

Statements of Income.

TALISMAN ENERGY ANNUAL REPORT 2012

4. Disposals

Sale of 49% Equity Interest of Talisman Energy (UK) Limited to China Petrochemical Corporation (Sinopec)

North America Dispositions

Asset Sales Completed in 2011

Asset Sales Completed in 2010

69

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During the year ended December 31, 2012, Talisman completed an agreement with the Kurdistan Regional Government for a further

investment of $50 million in the Kurdamir Block arising from the Company’s decision to enter the next exploration sub-period of

the licence.

During the year ended December 31, 2011, the Company acquired additional undeveloped land in the Eagle Ford shale play for

approximately $145 million and undeveloped land in the Alberta Duvernay shale play for approximately $510 million.

During the year ended December 31, 2010, the Company acquired undeveloped land in the Eagle Ford shale play for approximately

$910 million and a 35% working interest in the PL378 Grosbeak discovery and a 20% interest in the PL375 Beta discovery in Norway

for $192 million.

The Company entered into a new PSC with PETRONAS, the national oil company of Malaysia, acquiring ownership of a 60% working

interest in the Kinabalu PSC, as well as assuming operatorship on December 26, 2012. As consideration for receipt of the PSC

interest, the Company paid to PETRONAS a financial commitment in the amount of $50 million in January 2013.

This acquisition, which builds on the Company’s acreage position in Malaysia and is being reported in the Southeast Asia segment,

was accounted for using the acquisition method. The fair values of the identifiable assets acquired and liabilities assumed by

Talisman, after working capital and other adjustments, were preliminarily allocated as follows:

Fair value of share of net assets acquired

Property, plant and equipment 61

Total identifiable net assets at fair value 28

Total cost of acquisition 50

Satisfied by:

The goodwill arising on this acquisition is attributable to the difference between the accounting fair value and the tax basis of the net

assets acquired, and is not expected to be deductible for income tax purposes.

Revenue and net income from Kinabalu PSC did not have a material impact on the Company during 2012, since the effective date of

transaction was December 26, 2012. It is impractical to disclose information of revenue or net income had the transaction closed on

January 1, 2012, as reliable information is not readily available. The Company did not incur any transaction costs as part of the

acquisition.

No contingent consideration or contingent liabilities arose from this transaction.

On January 24, 2011, Talisman, together with Ecopetrol, completed the acquisition of BP Exploration Company (Colombia) Limited,

renamed Equion. Talisman acquired a 49% interest in Equi  ́ on for cash consideration of $785 million. Since Equi  ́ on is a jointly  ́

controlled entity, the Company is proportionately consolidating its interest, which is reported in the Other segment.

The recognition of assets acquired and liabilities assumed has been updated as a result of the completion of the Company’s process

to evaluate the acquired reserves, and reflects additional market-based information for certain acquired assets.

The assets acquired through this transaction include interests in producing properties and investments in companies having interests

in oil and gas pipelines in Colombia.

TALISMAN ENERGY ANNUAL REPORT 2012

5. Property Acquisitions

6. Business Combinations

Kinabalu PSC

Exploration and evaluation assets 39

Decommissioning liability (53)

Deferred tax liability (19)

Goodwill arising on acquisition (note 8) 22

Cash paid in 2013 50

Equion ́

70
This acquisition, which builds on the Company’s acreage position in Colombia, was accounted for using the acquisition method. The

fair values of the identifiable assets acquired and liabilities assumed by Talisman, after working capital and other adjustments, were

as follows:

Fair value of share of net assets acquired

Property, plant and equipment 559

Total identifiable net assets at fair value 623

Total cost of acquisition 785

Satisfied by:

Total cash paid 785

The fair value of the acquired accounts receivable approximates the carrying value due to their short-term nature. None of the

accounts receivable were impaired and the full contractual amount was collected.

The goodwill arising on acquisition is attributable to the difference between the accounting fair value and the tax basis of the net

assets acquired, and is not expected to be deductible for income tax purposes.

From the date of acquisition, Equion contributed revenue of $287 million and net income of $110 million to the Company’s  ́

Consolidated Statements of Income during the year ended December 31, 2011. Had the transaction closed on January 1, 2011, the

incremental revenue and net income reported by Talisman would have been immaterial.

Transaction costs of $11 million were expensed in 2010 and included in other expenses on the Consolidated Statements of Income

and shown as a component of cash provided by operating activities in the Consolidated Statements of Cash Flows.

As part of the purchase transaction, Talisman assumed provisions of $52 million for which the vendor has indemnified the Company.

Accordingly, a non-current asset was recorded in the same amount.

No contingent consideration arose from this transaction.

On January 13, 2010, Talisman acquired 100% of the share capital of Hess (Indonesia-Jambi Merang) Limited, a company which

owns a 25% interest in the Jambi Merang PSC, for cash consideration of $183 million.

TALISMAN ENERGY ANNUAL REPORT 2012

Cash 16

Accounts receivable 81

Inventories 16

Investments 350

Indemnification asset 52

Accounts payable (113)

Other current liabilities (52)

Decommissioning liability (25)

Provisions (52)

Deferred tax liability (209)

Goodwill arising on acquisition (note 8) 162

Cash deposit paid in 2010 613

Cash paid in 2011 172

Jambi Merang

71
This acquisition, which facilitates Talisman’s strategy to increase its presence in Indonesia and is being reported in the Southeast Asia

segment, was accounted for using the acquisition method. The fair values of the identifiable assets acquired and liabilities assumed

by Talisman were as follows:

Fair value of net assets acquired

Property, plant and equipment 181

Total identifiable net assets at fair value 140

Total cost of acquisition 183

Satisfied by:

The fair value of the acquired accounts receivable approximates the carrying value due to their short-term nature. None of the

accounts receivable acquired were impaired and the full contractual amount was collected.

The goodwill recognized above is attributable to the difference between the accounting fair value and the tax basis of the net assets

acquired, and is not expected to be deductible for income tax purposes.

Revenue and net income from Jambi Merang did not have a material impact on the Company during 2010, since first production was

achieved in April 2011.

Transaction costs of $1 million were expensed in 2010 and included in other expenses in the Consolidated Statements of Income and

shown as a component of cash provided by operating activities in the Consolidated Statements of Cash Flows.

No contingent consideration or contingent liabilities arose from this transaction.

Talisman accounts for jointly controlled entities using proportionate consolidation. Summarized financial information for the

Company’s share in jointly controlled entities, comprising Equion (49%), Talisman Sasol Montney Partnership (50%) and TSEUK  ́

(51%), is as follows:

Talisman Sasol

Equion ́ (2) Montney Partnership (2) TSEUK (2) Total

December 31 2011 2011 2011(1) 2011

Current assets 237 130 – 367

1,182 558 – 1,740

Total assets 1,419 688 – 2,107

Current liabilities 274 13 – 287

253 7 – 260

Total liabilities 527 20 – 547

Years ended December 31 2011 2011 2011 2011

Total revenue and other income 287 34 – 321

177 31 – 208

Net income (loss) 110 3 – 113

1) No comparative information as TSEUK was only formed on December 17, 2012.

2) Revenue and expense totals represent Talisman’s interest in the activities incurred from the date Talisman became a party to the joint ventures.

As at and for the year ended December 31, 2012, the Company proportionately consolidated TSEUK and Equion. Upon adoption of  ́

IFRS 11 Joint Arrangements on January 1, 2013, the Company will be required to use the equity method of accounting for its

investments in TSEUK and Equion. Talisman’s interest in the Talisman Sasol Montney Partnership will be accounted for as a joint  ́

TALISMAN ENERGY ANNUAL REPORT 2012

Accounts receivable 26

Other assets 13

Accounts payable (20)

Other current liabilities (17)

Deferred tax liability (43)

Goodwill arising on acquisition (note 8) 43

Cash paid 183

7. Jointly Controlled Entities

2012 2012 2012 2012

272 75 259 606

Non-current assets 794 530 1,799 3,123

1,066 605 2,058 3,729

253 15 306 574

Non-current liabilities 372 4 1,952 2,328

625 19 2,258 2,902

2012 2012 2012 2012

403 58 58 519

Total expenses (including

income taxes) 407 109 104 620

(4) (51) (46) (101)

72
operation and continue to be proportionately consolidated as Talisman shares its interests in the partnership assets based on the

Company’s 50% ownership interest and is jointly and severally liable for the obligations of the partnership.

Changes in the carrying amount of the Company’s goodwill are as follows:

Continuity of goodwill 2011

Balance, beginning of year 1,164

162

(9)

–

Balance, end of year 1,317

Goodwill has no tax basis.

December 31 2011

Trade receivables 1,617

(67)

1,550

1) Allowance included 51% of allowance taken for UK doubtful accounts.

The fair value of accounts receivable approximates the carrying amount due to their short term to maturity. Trade receivables are

non-interest bearing and are generally on 30-90 day terms.

At December 31, the analysis of trade receivables that were due or past due, but not impaired, was as follows:

Past due but not impaired

Less than

Total 90 days 91-120 days > 120 days

2011 1,550 1,483 12 55

December 31 2011

Materials and supplies 56

108

164

December 31 2011

Accrued pension asset (note 30) 1

38

52

10

Total 101

TALISMAN ENERGY ANNUAL REPORT 2012

8. Goodwill

2012

1,317

Acquisitions 22

Disposals (325)

Foreign currency translation –

1,014

9. Accounts Receivable

2012

1,243

Allowance for doubtful accounts (33)(1)

1,210

2012 1,210 1,106 47 57

10. Inventories

2012

57

Product 93

150

11. Other Assets

2012

3

Decommissioning sinking fund (note 15) 50

Indemnification asset (note 6) 52

Other 10

115

73
December 31 2011

Investment in Oleoducto Central S.A (Ocensa) 325

25

34

11

395

Investments comprise Talisman’s interests accounted for using the equity method and as available-for-sale financial assets. The

available-for-sale assets are recorded at the estimated fair values and are categorized as level 3 of the fair value hierarchy referred to

in note 22.

The investment in Ocensa was acquired as part of the Equion business combination described in note 6. Ocensa has an interest in a  ́

pipeline in Colombia. From the date of acquisition until November 2012, the investment in Ocensa was held by Equion and was  ́

accounted for using the equity method. In November 2012, Talisman, together with Ecopetrol SA, completed a restructuring of

Equion whereby the investment in Ocensa was distributed to the shareholders as a non-cash dividend. This distribution has been  ́

recorded at fair value and the difference between the fair value of the investment in Ocensa and the previous carrying amount has

resulted in a pre-tax gain of $365 million ($245 million post-tax), which is included in ‘Gain on revaluation of investment’ on the

Consolidated Statements of Income. In determining the value to be placed on Ocensa, Talisman considered recent market

transactions and the value of the transportation cost savings as well as the value of excess transportation capacity in the Colombian

markets.

At December 31, 2012, Ocensa is accounted for as an available-for-sale financial asset.

Three other investments were acquired pursuant to the Equion business combination, one of which is accounted for using the equity  ́

method and two using the cost method.

The investment in Transasia Pipeline Company Pvt. Ltd. is accounted for as an available-for-sale financial asset.

TALISMAN ENERGY ANNUAL REPORT 2012

12. Investments

2012

662

Other investments acquired pursuant to the Equion business combination  ́ 18

Investment in Transasia Pipeline Company Pvt. Ltd. 34

Other 33

747

74
The cost and accumulated DD&A of the Company’s PP&E (including corporate assets) and E&E assets are as follows:

E&E

PP&E assets Total

COST

At December 31, 2011 29,900 4,198 34,098

At December 31, 2012

ACCUMULATED DD&A

At December 31, 2011 13,991 244 14,235

At December 31, 2012

NET BOOK VALUE

At December 31, 2011 15,909 3,954 19,863

At January 1, 2010 13,266 3,442 16,708

TALISMAN ENERGY ANNUAL REPORT 2012

13. Oil and Gas Assets

At December 31, 2010 25,217 3,758 28,975

Acquisitions through business combinations (note 6) 559 – 559

Additions 3,491 1,527 5,018

Disposals and derecognition (384) (192) (576)

Transfers from E&E assets to PP&E 654 (654) –

Change in decommissioning liabilities 363 – 363

Expensed to dry hole – (241) (241)

Acquisitions through business combinations (note 6) 61 39 100

Additions 3,115 621 3,736

Disposals and derecognition (759) (43) (802)

Transfers from E&E assets to PP&E 549 (549) –

Transfers from PP&E to E&E assets (1,751) 1,751 –

Change in decommissioning liabilities 648 45 693

Expensed to dry hole – (269) (269)

Disposals – TEUK (4,701) (19) (4,720)

27,062 5,774 32,836

At December 31, 2010 11,951 316 12,267

Charge for the year 1,949 – 1,949

Disposals and derecognition (88) (119) (207)

Impairment losses 313 47 360

Impairment reversal (134) – (134)

Charge for the year 2,508 – 2,508

Disposals and derecognition (551) (24) (575)

Impairment losses 2,280 464 2,744

Transfers from PP&E to E&E assets (1,574) 1,574 –

Disposals – TEUK (2,597) – (2,597)

14,057 2,258 16,315

At December 31, 2012 13,005 3,516 16,521

75
The Company reclassified the cost of certain properties in the North Sea segment, net of impairment charges from the PP&E category

to the E&E category as a result of previously sanctioned development plans being re-evaluated and the associated proved reserves

being reclassified to probable and contingent resources.

Included in PP&E are capitalized interest costs of $233 million (2011 – $161 million) relating to projects under construction and

development. During the year ended December 31, 2012, interest costs of $110 million (2011 – $85 million; 2010 – $81 million)

were capitalized.

An incremental DD&A expense of $224 million was booked in the fourth quarter of 2012 to reflect reserves revisions, of which

$187 million related to the elimination of proved reserves and full write-off of the book values of the associated fields. For 2011, the

impact of adjusting the DD&A expense in the fourth quarter for reserves revisions was an incremental $24 million.

PP&E and E&E assets include the following costs that were not subject to DD&A:

December 31 2011

Undeveloped land

2,240

304

219

–

224

9

130

194

314

320

E&E assets 3,954

–

486

1,714

362

6,516

1) Acquisition costs of unproved reserves are not depleted while under active evaluation for commercial reserves.

2) Exploration costs consist of drilling in progress and wells awaiting determination of proved reserves and are not depleted pending approval of development plans.

3) Development projects are not depleted until the asset is substantially complete and ready for its intended use.

Costs relating to wells drilled prior to 2012 continue to be capitalized, since management’s ongoing assessment includes further

planned activity. The number of wells drilled prior to 2012 and related costs are as follows:

Years Number of wells(1) Cost

Southeast Asia 2007 – 2011 24 141

66 819

1) No costs associated with North American wells drilled prior to 2012 continue to be capitalized as at December 31, 2012.

North Sea and other international wells relate to projects that are in the process of being evaluated, including the drilling of additional

appraisal wells and the completion of additional seismic analysis. Some of these projects are in the final stages of project sanction.

TALISMAN ENERGY ANNUAL REPORT 2012

Non-Depleted Capital

2012

North America 2,060

Southeast Asia 304

Other 207

Acquired unproved reserve costs not associated with producing fields(1)

Southeast Asia 46

North Sea 204

Other –

Exploration costs(2)

North America 19

Southeast Asia 176

North Sea 247

Other 253

3,516

Development projects(3)

North America 552

Southeast Asia 753

North Sea 240

Other 376

5,437

North Sea 2007 – 2011 11 435

Other 2009 – 2011 31 243

76
Years ended December 31 2011 2010

Impairment losses

47 112

313 189

360 301

Impairment reversals

– –

134 –

134 –

Net impairment 226 301

At December 31, 2012, the Company assessed the carrying amount of its oil and gas assets for indicators of impairment such as

changes in future prices, future costs and reserves. The Company generally calculates the recoverable amount as the fair value less

costs to sell using a discounted cash flow model. The discount rate is derived from the Company’s post-tax weighted average cost of

capital. Any country-specific risks are adjusted for within the cash flows. The rate to be applied is reassessed each year. The

calculation is sensitive to the following assumptions which have been based on a long-term view of global oil and gas supply and

demand as well as extensive industry experience:

Production volumes;

Discount rates;

Commodity prices;

Reserve and resource quantities;

Operating costs;

Royalty rates;

Future capital cost estimates;

Foreign exchange rates; and

Income taxes.

The following assumptions were used in developing the cash flow model and applied over the expected life of the respective fields

within each cash-generating unit:

2014 and

2013 beyond

WTI ($/bbl) 90.00 88.63

In addition to discounted cash flows, the Company also considered a variety of market metrics in assessing fair value less cost to sell

in certain areas. Market metric information was obtained from recent transactions involving similar assets. In determining the fair

value of the Company’s investment in shale properties, the Company considered the price per flowing barrel and the land values per

undeveloped acre based on comparable transactions as well as contingent resource valuation from publicly available information.

TALISMAN ENERGY ANNUAL REPORT 2012

14. Impairment

Impairment of Assets

2012

E&E assets 464

PP&E 2,280

2,744

E&E assets –

PP&E –

–

2,744

Dated Brent ($/bbl) 100.00 95.36

Henry Hub natural gas ($/mmbtu) 3.60 4.88

AECO (C$/gj) 2.82 4.00

US$/C$ 1.00 1.00

US$/UK£ 1.60 1.60

Post-tax discount rate 10% 10%

77

•

•

•

•

•

•

•

•

•
During 2012, the Company recorded impairment expense of $363 million in North America of which $194 million pre-tax

($138 million after-tax) relates to lower long-term gas price assumptions and reserves reduction in conventional areas, and

impairment expense of $60 million pre-tax ($45 million after-tax) was recorded in respect of conventional assets disposed of in the

third quarter. In addition, the Company concluded during the third quarter that it would not commit capital in the foreseeable future to

exploration and evaluation activities in Quebec, where the prohibition regarding hydraulic fracturing for shale gas developments has

been reaffirmed. Accordingly, the Company fully impaired its Quebec exploration and evaluation assets and recorded an impairment

expense of $109 million pre-tax ($82 million after-tax).

Impairments of $2.1 billion were recorded for the North Sea, primarily related to the Yme project in Norway. In 2012, the Yme project

experienced significant delays, quality issues and cost overruns and is subject to arbitration with the platform contractor. In the third

quarter, Talisman made a decision to de-man the platform for safety related reasons and it has not been re-manned since. Given the

uncertainty of the timing for first oil, Talisman removed Yme from its forward projections and recorded impairment losses of

$1,475 million pre-tax ($373 million after-tax). At the end of the third quarter, this represented an impairment of the remaining book

value of the property, plant and equipment of Yme, leaving a deferred tax asset of $521 million relating to the investment in the

project. Capital expenditures incurred during the fourth quarter, capitalized interest and revised decommissioning liabilities totaling

$99 million pre-tax ($28 million after-tax) were also impaired in full. Management continues to work with all stakeholders to evaluate

project options.

During the year, the Rev field in Norway experienced a significant drop in reservoir pressure, resulting in a decline in production. As a

result, the Company made a downward revision of its estimates of recoverable reserves and recorded an impairment expense of

$250 million pre-tax ($55 million after-tax). During 2012, the Company also recorded an impairment expense of $74 million pre-tax

($17 million after-tax) in respect of other Norwegian exploration assets upon completion of the commercial feasibility studies of these

assets. In addition, a revision to decommissioning cost estimates in Gyda resulted in the Company recording an impairment expense

of $41 million pre-tax ($9 million after-tax).

In the UK, impairment expense of $158 million pre-tax ($66 million after-tax) was recorded in respect of certain development areas

largely due to fourth quarter reserves revisions and increased future cost estimates.

In 2012, the Company decided to cease exploration activities in the Maranon Basin in northern Peru and exit the country. As a result,  ̃

$171 million of impairment expense was recorded. The Company will fulfil its outstanding legal obligations as it exits Peru. In addition,

impairment expense of $41 million was recorded during the year ended December 31, 2012, in respect of exploration and evaluation

assets in Poland.

During the year ended December 31, 2012, the Company recorded $72 million of impairment related to exploration acreage being

relinquished in the Kurdistan Region of Iraq.

During the year ended December 31, 2011, the Company recorded impairment of $129 million in North America due principally to

reduced third party tariffs in the Company’s midstream operations and lower conventional natural gas reserves. Impairments of

$231 million in the North Sea were recorded in respect of oil and gas PP&E ($184 million) and E&E assets ($47 million). Of the

$231 million, $102 million was as a result of a change in legislation announced by the UK government in March 2011 that raises the

combined corporation tax and supplementary charge rate from 50% to 62% for oil and gas companies with fields not subject to PRT,

and 75% to 81% with fields subject to PRT. See note 26 for further details. Additional impairment expense of $129 million in the

North Sea arose due to a reduction in year-end reserves in a field in Norway.

Also during 2011, an impairment reversal of $134 million resulted from price increases and an increase in estimated reserves for oil

and gas assets that were previously impaired in the North Sea and Southeast Asia.

During the year ended December 31, 2010, the Company recorded $301 million of impairments, of which $189 million related to

PP&E and $112 million to E&E assets. In North America, natural gas assets of $92 million were written down due to the decline in

natural gas price assumptions and $24 million of exploration acreage was relinquished. In the North Sea, oil and gas assets of

$76 million and E&E assets of $23 million were written down due to a change in reserves estimates, a change in the estimated timing

of cash flows and changes in investment decisions. In addition, $65 million of exploration acreage was relinquished. In Southeast

Asia, $21 million was recorded relating to oil assets due to an increase in estimated future costs.

As part of impairment testing, goodwill is allocated to the CGU or groups of CGU to which it relates. Goodwill was assessed for

impairment as at December 31, 2012 using fair value less costs to sell. Fair value less costs to sell was estimated for each CGU, with

allocated goodwill, based on the assumptions used in the asset impairment test.

No reasonably possible change in assumptions would cause goodwill to become impaired.

TALISMAN ENERGY ANNUAL REPORT 2012

Impairment of Goodwill

78
Continuity of decommissioning liabilities 2011

Balance, beginning of year 2,610

115

(44)

76

204

74

–

Balance, end of year 3,035

Expected to be settled within one year 53

2,982

3,035

Revisions in estimated cash flows occurring in 2012 related to cost increases in the North Sea as well as cost increases and a revision

of the expected timing of settlement of liabilities in North America. The liabilities incurred during the year related principally to new

wells and facilities in the North Sea and Southeast Asia, as well as the addition of the decommissioning liabilities at Kinabalu.

The Company provides for the future cost of decommissioning oil and natural gas properties and facilities on a discounted basis. At

December 31, 2012, the estimated undiscounted decommissioning liabilities associated with oil and gas properties and facilities were

$4.1 billion (2011 – $5.0 billion). The majority of the payments to settle this provision will occur over a period of 35 years and will be

funded from the general resources of the Company as they arise. The provision for the costs of decommissioning production facilities

and pipelines at the end of their economic lives has been estimated using existing technology, at current prices or long-term

assumptions and based upon the expected timing of the activity. The provision has been discounted using a weighted average creditadjusted risk free rate of 2.3% (2011 – 3.1%), which excludes the impact of inflation. Total accretion expense for the year ended

December 31, 2012 of $85 million (2011 – $76 million) has been included in finance costs on the Consolidated Statements

of Income.

While the provision is based on the best estimate of future costs and the economic lives of the facilities and pipelines, there is

uncertainty regarding both the amount and timing of the costs to be incurred.

The Company provided letters of credit at January 1, 2013 in an amount of $1.6 billion as security for the costs of decommissioning

obligations in the UK. Under the contractual arrangements pursuant to which APUK acquired 49% of the share capital of TEUK,

APUK’s parent company, Sinopec, has provided an unconditional and irrevocable guarantee for 49% of the UK decommissioning

obligations.

The Company has established a decommissioning sinking fund of $50 million at December 31, 2012 (2011 – $38 million) that

represents secured funding for its decommissioning obligations in Southeast Asia.

Years ended December 31 2011 2010

Interest on long-term debt 240 235

47 43

76 79

(85) (81)

278 276

The interest rate applied in determining the amount of interest capitalized in 2012 was approximately 6.1% (2011 – 6.1%; 2010 –

6.4%).

TALISMAN ENERGY ANNUAL REPORT 2012

15. Decommissioning Liabilities

2012

3,035

Liabilities incurred during the year 190

Liabilities settled during the year (53)

Accretion expense (note 16) 85

Revisions in estimated cash flows 251

Change in discount rate 307

Disposals (1,023)

2,792

49

Expected to be settled in more than one year 2,743

2,792

16. Finance Costs

2012

256

Miscellaneous interest expense and other fees 45

Accretion expense (note 15) 85

Less: interest capitalized (110)

276

79
December 31 2011

Bank Credit Facilities 648

402

97

50

374

150

385

694

592

300

123

493

587

–

Gross debt(3) 4,895

(410)

Long-term debt 4,485

1) Interest on debentures and notes is payable semi-annually except for interest on the 6.625% notes, which is payable annually, and interest on the 8.25% and 8.50%

notes, which is payable quarterly.

2) The interest rate on $300 million of these notes has been swapped to a floating rate obligation bearing interest at three-month LIBOR plus 0.43% (0.74% at

December 31, 2011). See note 22 for details.

3) Financing costs of $52 million and $41 million have been netted against the individual debt facilities as at December 31, 2012 and 2011, respectively.

At December 31, 2012, Talisman had unsecured credit facilities totaling $4.1 billion, consisting of facilities of $3.9 billion (Facility

No. 1) and $200 million (Facility No. 2). These facilities mature in November 2014, although the maturity date may be extended from

time to time upon agreement between the Company and the respective lenders. Prior to the maturity date, the Company may borrow,

repay and reborrow at its discretion. All facilities must be repaid on the maturity date.

Borrowings under Facility No. 1 are available in the form of prime loans, C$ or US$ bankers’ acceptances, US$ base rate loans or

LIBOR-based loans. In addition, drawings to a total of $1 billion are available in the form of letters of credit. Borrowings under Facility

No. 2 are available in the form of prime loans, C$ or US$ guaranteed notes, US$ base rate loans and LIBOR-based loans. During

2012, the Company repaid the outstanding bankers’ acceptance program in full.

The Company established a US commercial paper program in November 2011. The authorized amount under this program is

$1 billion. The amount available under the commercial paper program is limited to the availability of backup funds under the

Company’s bank credit facilities. During 2012, the Commercial Paper program was repaid in full.

At December 31, 2012, available borrowing capacity under the bank credit facilities was $4 billion.

In connection with the acquisition of its interest in the Tangguh LNG Project, Talisman became a participant in a series of project

financing facilities, the Company’s share of which is up to $105 million. Approximately $89 million was outstanding under these

facilities at December 31, 2012 (2011 – $97 million), of which $8 million is due for repayment in 2013. The amount outstanding is

secured by Talisman’s interest in the Tangguh LNG Project, having a net book value of $245 million. Draws under these facilities bear

interest at LIBOR plus 0.19% through to LIBOR plus 0.33% per annum and will mature in 2021.

On May 15, 2012, Talisman completed a $600 million offering of 5.5% notes due May 15, 2042. Proceeds, net of the discount and

issuance costs were $583 million. Interest on the notes is payable semi-annually. The notes are redeemable at the option of the

Company at a make-whole premium. The notes are unsecured and unsubordinated and rank equally with all of the Company’s other

unsecured and unsubordinated indebtedness.

TALISMAN ENERGY ANNUAL REPORT 2012

17. Long-Term Debt

2012

–

Commercial Paper –

Tangguh Project Financing 89

Debentures and Notes (Unsecured)(1)

8.25% notes (US$50 million), due 2014 50

5.125% notes (US$375 million), due 2015 (2) 374

8.50% notes (US$150 million), due 2016 150

6.625% notes (UK£250 million), due 2017 404

7.75% notes (US$700 million), due 2019 695

3.75% notes (US$600 million), due 2021 593

7.25% debentures (US$300 million), due 2027 300

5.75% notes (US$125 million), due 2035 123

5.85% notes (US$500 million), due 2037 494

6.25% notes (US$600 million), due 2038 587

5.50% notes (US$600 million), due 2042 583

4,442

Less: current portion (8)

4,434

Bank Credit Facilities and Commercial Paper

Tangguh Project Financing

Debentures and Notes

80
The Company has a financing structure whereby subsidiaries have $1.3 billion drawn on bank facilities that have been offset against

equal amounts of cash deposited by another subsidiary with the same bank under a right of offset agreement. The Company intends

to offset these amounts at maturity.

The Company’s contractual minimum repayments of gross long-term debt are as follows:

Year

2013 8

Gross debt 4,442

December 31 2011

Accrued pension and other post-employment benefits liability (note 30) 163

25

66

14

52

26

346

The fair value of financial liabilities included above approximates the carrying amount.

The Company has entered into two leasing arrangements for the modification, refitting and use of Floating Storage Offloading (FSO)

vessels for use in its operations. Elements of the leasing arrangements have been defined by the Company as finance leases. The

imputed rates of interest on these leases, which expire in 2016 and 2019, are 6% and 10%, respectively. Of the total discounted

liability of $73 million (2011 – $84 million), $18 million (2011 – $18 million) is included in accounts payable and accrued liabilities.

The future minimum lease payments for finance leases and the present value of minimum finance lease payments by payment date

are as follows:

2011

Present

Minimum value of

payments payments

Within one year 18 18

68 51

28 15

Total minimum lease payments 114 84

(30) –

Present value of minimum lease payments 84 84

TALISMAN ENERGY ANNUAL REPORT 2012

Other

Repayment Schedule

2014 59

2015 384

2016 161

2017 415

Subsequent to 2017 3,415

18. Other Long-Term Obligations

2012

129

Deferred credits 21

Long-term portion of discounted obligations under finance leases 55

Long-term portion of share-based payments liability (note 20) 21

Acquired provisions (note 6) 52

Other 35

313

Finance Leases

2012

Present

Minimum value of

payments payments

18 18

After one year but not more than five years 63 46

More than five years 15 9

96 73

Less amounts representing accretion (23) –

73 73

81
Talisman’s objective in managing capital is to retain access to capital markets, ensure its ability to meet all financial obligations and

meet its operational and strategic objectives.

Talisman’s capital structure consists of shareholders’ equity and debt. The Company makes adjustments to its capital structure based

on changes in economic conditions and its planned requirements. Talisman has the ability to adjust its capital structure by issuing

new equity or debt, selling assets to reduce debt, controlling the amount it returns to shareholders and making adjustments to its

capital expenditure program.

Talisman monitors its balance sheet with reference to its liquidity and a debt-to-cash flow ratio. The main factors in assessing the

Company’s liquidity are cash flow (defined below), cash provided by and used in investing activities and available bank credit

facilities. The debt-to-cash flow ratio at December 31, 2012 and 2011 was as follows:

2011

Debt 4,967

3,572

Debt-to-cash flow 1.39:1

The calculation of debt is as follows:

2011

Gross debt and bank indebtedness 4,955

109

(97)

Debt 4,967

The calculation of cash flow is as follows:

2011

Cash provided by operating activities 2,812

375

427

(42)

Cash flow 3,572

Talisman is in compliance with all of its debt covenants. The Company’s principal financial covenant under its primary bank credit

facility is a debt-to-cash flow ratio of less than 3.5:1, calculated quarterly on a trailing 12-month basis as of the last day of each

fiscal quarter.

Talisman’s authorized share capital consists of an unlimited number of common shares without nominal or par value and an unlimited

number of first and second preferred shares. 

1) Dollar amounts in share-based payments tables are provided in C$.

TALISMAN ENERGY ANNUAL REPORT 2012

19. Capital Disclosures

2012

4,446

Cash flow 3,149

1.41:1

2012

4,442

Add: Production payments and finance leases 93

Less: Non-recourse debt (89)

4,446

2012

2,716

Changes in non-cash operating working capital 125

Add: Exploration expenditure 346

Less: Amounts attributable to assets subject to non-recourse debt (38)

3,149

20. Share Capital and Share-Based Payments(1)

Authorized

82
Continuity of common shares 2011 2010

Shares Amount Shares Amount

Balance, beginning of year 1,019,290,939 1,480 1,014,876,564 1,401

7,500,131 175 4,835,056 95

(5,368,600) (94) (4,482,681) (81)

– – 4,062,000 65

–– ––

Balance, end of year 1,021,422,470 1,561 1,019,290,939 1,480

During 2012, Talisman declared common share dividends of $0.27 per share (2011 – $0.27 per share; 2010 – C$0.25 per share) for

an aggregate dividend of $277 million (2011 – $277 million; 2010 – $249 million). Subsequent to December 31, 2012, 1,313,810

stock options were exercised for shares and no further common shares were purchased and held in trust for the long-term PSU plan.

There were 1,026,763,540 common shares outstanding at February 28, 2013.

Holders of common shares are entitled to receive notice of and to attend all meetings of shareholders. Each common share carries

with it the right to one vote. Subject to the rights of holders of other classes of shares who are entitled to receive dividends in priority to

or rateably with the common shares, the Board of Directors may declare dividends on the common shares to the exclusion of any

other class of shares of the Company. In the event of liquidation, dissolution or winding up of the Company or any other distribution of

assets of the Company among its shareholders for the purpose of winding up its affairs, and subject to the rights of other classes of

shares on a priority basis, the holders of common shares are entitled to participate rateably in any distribution of any assets of

the Company.

Continuity of preferred shares 2011 2010

Shares Amount Shares Amount

Cumulative Redeemable Rate Reset First

Preferred Shares, 4.2% Series 1:

–– ––

8,000,000 191 – –

Balance, end of year 8,000,000 191 – –

On December 13, 2011, Talisman issued 8,000,000 Cumulative Redeemable Rate Reset First Preferred Shares, Series 1 at a price of

C$25 per share for aggregate gross proceeds of C$200 million. Net proceeds, after deducting underwriting fees, were C$194 million

($191 million).

Holders of Series 1 preferred shares are entitled to receive a cumulative quarterly fixed dividend of 4.2% annually for the initial period

ending December 31, 2016, as and when declared by the Board of Directors. Thereafter, the dividend rate will be reset every five

years at a rate equal to the five-year Government of Canada bond yield plus 2.77%.

The Company may redeem all or a portion of the outstanding Series 1 preferred shares for C$25 per share plus accrued and unpaid

dividends, on December 31, 2016 and on December 31 every five years thereafter. Holders of Series 1 preferred shares will have the

right to convert their shares into Cumulative Rate Reset First Preferred Shares, Series 2 (Series 2 preferred shares), subject to certain

conditions, on December 31, 2016 and on December 31 every five years thereafter. Holders of Series 2 preferred shares will be

entitled to receive cumulative quarterly floating rate dividends at a rate equal to the three-month Government of Canada Treasury Bill

yield plus 2.77%.

In the event of the liquidation, dissolution or winding up of the Company, the holders of Series 1 preferred shares will be entitled to

receive C$25 per share together with all dividends accrued and unpaid to the date of payment before any amount will be paid or any

assets of the Company distributed to the holders of any shares ranking junior to the Series 1 preferred shares. The holders of Series 1

preferred shares will not be entitled to share in any further distribution of the assets of the Company.

Holders of Series 1 preferred shares are not entitled to voting rights or to receive notice of or to attend shareholders’ meetings unless

dividends on the Series 1 preferred shares are in arrears to the extent of eight quarterly dividends, whether or not consecutive.

TALISMAN ENERGY ANNUAL REPORT 2012

Common Shares Issued

2012

Shares Amount

1,021,422,470 1,561

Issued on exercise of stock options 1,190,223 15

Shares purchased and held in trust for

long-term PSU plan (see below) (2,022,000) (25)

Shares released from trust for 2008 PSU

plan – –

Shares released from trust for long-term

PSU plan 4,859,037 88

1,025,449,730 1,639

Preferred Shares Issued

2012

Shares Amount

Balance, beginning of year 8,000,000 191

Issued – –

8,000,000 191

83
During the year ended December 31, 2012, Talisman declared preferred share dividends of C$1.10 per share (2011 – C$nil; 2010 –

C$nil), including dividends for the full year of 2012 and a pro-rata amount from the date of issuance of the Series 1 preferred shares

on December 13, 2011 until December 31, 2011, for an aggregate dividend of $9 million (2011 – $nil; 2010 – $nil).

Talisman has stock option plans that govern the granting of options to employees and directors. All options issued by the Company

permit the holder to purchase one common share of the Company at the stated exercise price per share or to receive a cash payment

equal to the appreciated value of the shares underlying the stock option. Options granted under the plans are generally exercisable

after three years and expire 10 years after the grant date. Commencing in 2006, options granted to new employees vest evenly on an

annual basis over a three-year period. Option exercise prices approximate the market price for the common shares on the date the

options are granted.

Continuity of stock options 2011 2010

Number Weighted Number Weighted

of shares average of shares average

underlying exercise underlying exercise

options price (C$) options price (C$)

Outstanding, beginning of year 62,959,223 15.89 69,489,526 15.22

6,686,170 23.29 7,743,117 17.42

(7,500,131) 14.54 (4,835,056) 11.75

(642,889) 15.62 (6,254,804) 12.59

(2,410,329) 17.40 (3,183,560) 17.81

Outstanding, end of year 59,092,044 16.82 62,959,223 15.89

Exercisable, end of year 39,242,566 16.33 35,790,358 15.59

Options available for future grants

pursuant to Stock Option Plans 39,523,835 42,653,842

The range of exercise prices of the Company’s outstanding stock options is as follows:

December 31, 2012 Outstanding options Exercisable options

Number Number

of shares of shares

underlying Weighted average Weighted average underlying Weighted average

Range of exercise prices (C$) options exercise price (C$) years to expiry options exercise price (C$)

6.60 – 9.99 3,853,924 7.43 1 3,853,924 7.43

6.60 – 23.92 59,836,097 16.28 5 41,565,657 16.00

The fair value of the liability for the stock option plans at December 31, 2012 was $140 million (2011 – $209 million), of which

$121 million (2011 – $196 million) is included in accounts payable and accrued liabilities on the Consolidated Balance Sheets.

Subsequent to December 31, 2012, 259,500 stock options were surrendered for cash, 1,313,810 were exercised for shares,

117,270 were granted and 1,922,532 were forfeited or expired, with 56,457,525 stock options outstanding at February 28, 2013.

TALISMAN ENERGY ANNUAL REPORT 2012

Stock Option Plans

2012

Number Weighted

of shares average

underlying exercise price

options (C$)

59,092,044 16.82

Granted 8,985,070 12.53

Exercised for common shares (1,190,223) 9.03

Surrendered for cash (192,712) 10.24

Expired or forfeited (6,858,082) 17.22

59,836,097 16.28

41,565,657 16.00

37,388,284

10.00 – 12.99 9,085,530 12.32 8 1,800,140 11.76

13.00 – 15.99 13,874,788 13.62 5 12,889,247 13.61

16.00 – 18.99 16,767,521 17.75 6 11,691,071 17.94

19.00 – 21.99 10,667,134 20.04 4 10,540,154 20.05

22.00 – 23.92 5,587,200 23.84 8 791,121 23.44

84
In addition to the Company’s stock option plans, Talisman’s subsidiaries issue stock appreciation rights under cash unit plans. Cash

units are similar to stock options except that the holder does not have a right to purchase the underlying shares of the Company. Units

granted under the cash unit plans are generally exercisable after three years and expire 10 years after the grant date. Commencing in

2007, cash units granted to new employees vest evenly on an annual basis over a three-year period. Cash unit exercise prices

approximate the market price for the common shares on the date the options are granted.

Continuity of cash units 2011 2010

Weighted Weighted

average average

Number exercise Number exercise

of units price (C$) of units price (C$)

Outstanding, beginning of year 10,112,792 16.64 10,078,102 16.42

1,547,670 22.34 1,170,920 17.38

(1,636,458) 17.42 (826,175) 14.39

(562,840) 18.33 (310,055) 17.49

––––

Outstanding, end of year 9,461,164 17.35 10,112,792 16.64

Exercisable, end of year 6,234,650 16.90 6,180,730 16.83

The range of exercise prices of the Company’s cash units is as follows:

December 31, 2012 Outstanding units Exercisable units

Number Weighted average Weighted average Number Weighted average

Range of exercise prices (C$) of units exercise price (C$) years to expiry of units exercise price (C$)

6.60 – 9.99 407,507 7.71 1 407,507 7.71

6.60 – 24.47 6,795,106 16.06 6 3,974,245 16.40

The fair value of the liability for the cash unit plan at December 31, 2012 was $14 million (2011 – $28 million), of which $12 million

(2011 – $27 million) is included in accounts payable and accrued liabilities on the Consolidated Balance Sheets.

Subsequent to December 31, 2012, 143,306 cash units were exercised, 57,007 were granted and 191,104 were forfeited or expired,

with 6,517,703 cash units outstanding at February 28, 2013.

In 2009, the Company implemented a long-term PSU plan that allows for the granting of PSUs to employees, vesting after three years

to varying degrees (0% – 150%) subject to predetermined performance measures being achieved. Each PSU represents the right,

subject to performance, to receive one common share of the Company. Participants in the PSU plan are credited with additional PSUs

corresponding to any associated dividend payments (referred to as ‘dividend equivalent PSUs’).

Continuity of long-term PSU plan 2011 2010

Number Number

of units of units

Outstanding, beginning of year 8,173,762 5,520,158

3,450,930 3,768,840

(605,949) (1,221,258)

– –

200,284 106,022

Outstanding, end of year 11,219,027 8,173,762

TALISMAN ENERGY ANNUAL REPORT 2012

Cash Unit Plan

2012

Weighted

average

Number exercise price

of units (C$)

9,461,164 17.35

Granted 2,703,360 12.38

Exercised (100,576) 9.19

Expired or forfeited (1,136,965) 16.62

Divested (4,131,877) 16.54

6,795,106 16.06

3,974,245 16.40

10.00 – 12.99 1,634,270 12.27 9 57,675 10.78

13.00 – 15.99 1,434,922 13.80 5 1,142,762 13.71

16.00 – 18.99 1,209,480 17.66 6 849,083 17.84

19.00 – 21.99 1,470,527 20.00 4 1,455,232 20.00

22.00 – 24.47 638,400 24.09 8 61,986 23.78

Long-Term Performance Share Unit (PSU) Plan

2012

Number

of units

11,219,027

Granted 11,652,041

Expired or forfeited (2,056,761)

Released (4,672,151)

Dividend equivalent PSUs 394,544

16,536,700

85
To satisfy the Company’s obligations to deliver common shares to settle the PSUs, Talisman has arranged for a third party trustee to

hold common shares which were purchased on the open market. During 2012, the Company purchased 2,022,000 common shares

on the open market for $25 million. For accounting purposes, the cost of the purchase of the common shares held in trust has been

accounted for as a reduction in outstanding common shares and the trust has been consolidated since it is a special purpose entity

controlled by the Company. The Company is not exposed to fluctuations in the stock price in respect of the shares held in trust.

Additional purchases of common shares to satisfy the Company’s obligations are contemplated.

The 2010 long-term PSU grant vested on December 31, 2012 and settlement is expected to occur during the first quarter of 2013.

Based on the Company’s performance relative to the predetermined performance measures, the Board of Directors approved the

vesting of 90% of the PSUs granted.

Subsequent to December 31, 2012, 622,578 PSUs were granted and 1,186,873 were forfeited or expired with

15,972,405 outstanding at February 28, 2013. Between January 1 and February 28, 2013, no further common shares were

purchased on the open market.

Talisman issues DSUs to directors in lieu of cash compensation. Each DSU represents the right to receive a cash payment on

retirement equal to the market value of the Company’s shares at the time of surrender. Dividends are credited as additional DSUs

when paid. At December 31, 2012, there were 565,751 (2011 – 394,655) units outstanding and the fair value of the liability was

$6 million (2011 – $5 million), which is included in accounts payable and accrued liabilities on the Consolidated Balance Sheets.

Recovery of $1 million (2011 – $1 million recovery; 2010 – $3 million expense) related to the DSUs is recognized in general and

administrative expenses on the Consolidated Statements of Income.

Talisman has RSU plans that grant RSUs to eligible employees. All RSUs issued by the Company permit the holder to receive a cash

payment equal to the market value of the stock. Participants are also credited with additional RSUs corresponding to any associated

notional dividend payments (referred to as ‘dividend equivalent RSUs’). Typically, RSUs granted under the plans are paid three years

after the grant date. At December 31, 2012, there were 529,367 (2011 – 404,863) units outstanding (including dividend equivalent

RSUs) and the fair value of the liability was $3 million (2011 – $2 million), which is included in accounts payable and accrued

liabilities on the Consolidated Balance Sheets.

The Company uses the Black-Scholes option pricing model to estimate the fair value of equity-settled share-based payment plans,

with the following assumptions:

2011 2010

Expected volatility 45% 42%

1.3% 2.6%

5 5

3.5% 3.4%

1.2% 1.1%

The expected volatility is based on the historical volatility of the Company’s common shares over a historical period that matches the

expected term of the share-based payment plans. The risk free rate is based on Government of Canada bond yields for terms that

match the expected term of the share-based payment plans. The expected term for each option tranche is estimated at the end of

each reporting period. The expected dividend rate takes into account historical dividend payments and the Company’s expectation for

future payments.

During the year ended December 31, 2012, the Company recorded share-based payments recovery of $62 million (2011 –

$310 million recovery; 2010 – $212 million expense) in respect of the plans described above as follows: stock options – $82 million

recovery (2011 – $332 million recovery; 2010 – $146 million expense), cash units – $4 million recovery (2011 – $56 million recovery;

2010 – $18 million expense), 2008 PSU plan – $nil (2011 – $nil; 2010 – $3 million recovery), long-term PSU plan – $23 million

expense (2011 – $78 million expense; 2010 – $51 million expense) and RSUs – $1 million expense (2011 – $nil; 2010 – $nil).

During the year ended December 31, 2012, the Company recorded a net decrease in contributed surplus of $65 million relating to its

long-term PSU plan ($88 million related to settlement offset by expenses of $23 million), compared to a net increase of $78 million for

the year ended December 31, 2011 which related to share-based payment expenses of the long-term PSU plan and a net decrease of

$9 million for the year ended December 31, 2010 which related to the settlement of the 2008 PSU plan.

TALISMAN ENERGY ANNUAL REPORT 2012

Deferred Share Unit (DSU) Plan

Restricted Share Unit (RSU) Plans

Share-Based Payments Expense

2012

42%

Risk free interest rate 1.4%

Expected term (years) 5

Expected forfeiture rate 4.2%

Expected annual dividend yield 1.6%

86
During the year ended December 31, 2012, the Company paid cash of $2 million (2011 – $14 million; 2010 – $54 million) to

employees in settlement of fully accrued option liabilities for options exercised. In addition, the Company capitalized share-based

payments expense of $15 million (2011 – $9 million; 2010 – $3 million).

Of the combined liability for cash-settled stock option, cash unit, DSU and RSU plans of $163 million (2011 – $244 million),

$142 million (2011 – $230 million) is included in accounts payable and accrued liabilities on the Consolidated Balance Sheets and

$21 million (2011 – $14 million) is included in other long-term obligations.

The total number of options and cash units expected to vest as at December 31, 2012 was 67 million, with a weighted average

remaining contractual life of six years, a weighted average exercise price of $16.28 and an aggregate intrinsic value of $16 million.

The components of accumulated other comprehensive income are as follows:

2011 2010

Balance, beginning of year

2 –

786 1,194

788 1,194

Other comprehensive income (loss) for the year

– 13

– (11)

– (408)

– –

(26) (12)

(26) (418)

Actuarial (gains) losses transferred to retained earnings 26 12

Balance, end of year

2 2

786 786

788 788

Talisman’s financial assets and liabilities at December 31, 2012 consisted of cash and cash equivalents, accounts receivable,

non-equity accounted investments, bank indebtedness, accounts payable and accrued liabilities, long-term debt (including the

current portion) and risk management assets and liabilities arising from the use of derivative financial instruments.

The Company is exposed to financial risks arising from its financial assets and liabilities. The financial risks include market risk related

to foreign exchange rates, interest rates and commodity prices, credit risk and liquidity risk.

The fair values of cash and cash equivalents, accounts receivable, bank indebtedness, and accounts payable and accrued liabilities

approximate their carrying values due to the short-term maturity of those instruments.

Borrowings under bank credit facilities are short-term in nature and are market rate-based, thus, carrying value approximates fair

value. The fair value of public debentures and notes is based on market quotations, which reflect the discounted present value of the

principal and interest payments using the effective yield for instruments having the same term and risk characteristics. The fair values

of private notes are based on estimations provided by third parties. The fair value of Talisman’s floating rate debt is determined by

discounting future estimated coupon payments at the current market interest rate. The fair value of Talisman’s long-term debt at

December 31, 2012 was $5.2 billion (2011 – $5.1 billion), while the carrying value was $4.4 billion (2011 – $4.9 billion).

The fair values of all other financial assets and liabilities approximate their carrying values.

Risk management assets and liabilities are recorded at their estimated fair values. To estimate fair value, the Company uses quoted

market prices when available, or models that utilize observable market data. In addition to market information, the Company

incorporates transaction-specific details that market participants would utilize in a fair value measurement, including the impact of

TALISMAN ENERGY ANNUAL REPORT 2012

21. Accumulated Other Comprehensive Income

2012

Derivative financial instruments designated as cash flow hedges 2

Foreign currency translation adjustments 786

788

Derivative financial instruments designated as cash flow hedges

Gains arising during the year –

Gains recognized in net income –

Foreign currency translation adjustments –

Transfer of accumulated foreign currency loss to net income (note 4) 23

Actuarial gains (losses) relating to pension and other post-employment benefits 10

33

(10)

Derivative financial instruments designated as cash flow hedges 2

Foreign currency translation adjustments 809

811

22. Financial Instruments

Fair Value of Financial Assets and Liabilities

87
non-performance risk. The Company’s non-performance risk is determined based on third party quotes for the Company’s debt

instruments with maturity dates that are similar, or in close approximation, to the maturity dates of the corresponding financial

instrument. The Company’s risk management liabilities decreased by $2 million as a result of incorporating non-performance risk.

The Company characterizes inputs used in determining fair value using a hierarchy that prioritizes inputs depending on the degree to

which they are observable. The three levels of the fair value hierarchy are as follows:

Level 1 – inputs represent quoted prices in active markets for identical assets or liabilities (for example, exchange-traded

commodity derivatives). Active markets are those in which transactions occur in sufficient frequency and volume to provide pricing

information on an ongoing basis;

Level 2 – inputs other than quoted prices included within level 1 that are observable, either directly or indirectly, as of the reporting

date. Level 2 valuations are based on inputs, including quoted forward prices for commodities, market interest rates and volatility

factors, which can be observed or corroborated in the marketplace. The Company obtains information from sources such as the

New York Mercantile Exchange (NYMEX) and independent price publications; and

Level 3 – inputs that are less observable, unavailable or where the observable data does not support the majority of the instrument’s

fair value, such as the Company’s internally developed assumptions about market participant assumptions used in pricing an asset

or liability, for example, an estimate of future cash flows used in the Company’s internally developed present value of future cash

flows model that underlies the fair value measurement.

In forming estimates, the Company utilizes the most observable inputs available for valuation purposes. If a fair value measurement

reflects inputs of different levels within the hierarchy, the measurement is categorized based upon the lowest level of input that is

significant to the fair value measurement. The valuation of over the counter financial swaps and collars is based on similar

transactions observable in active markets or industry standard models that rely primarily on market observable inputs. Substantially

all of the assumptions for industry standard models are observable in active markets throughout the full term of the instrument. These

are categorized as level 2.

Fair values for cross-currency and interest rate derivative instruments are determined based on the estimated cash payment or

receipt necessary to settle the contract. Cash payments or receipts are based on discounted cash flow analysis using current market

rates and prices. Fair values for commodity price derivatives are based on discounted cash flow analysis using current market rates

and prices and option pricing models using forward pricing curves and implied volatility, as appropriate, which are compared to

quotes received from financial institutions for reasonability.

The following table presents the Company’s risk management assets and liabilities measured at fair value for each hierarchy level at

December 31, 2012:

Fair value measurements using

Level 1 inputs Level 2 inputs Level 3 inputs Total fair value

ASSETS

LIABILITIES

The following table sets forth a reconciliation of changes in the fair value of the assets classified as level 3 in the fair value hierarchy

during 2012:

2011

Balance, beginning of year 42

(2)

(40)

Balance, end of year –

During the year ended December 31, 2011, a note receivable relating to a 2008 asset disposition and classified as level 3 in the fair

value hierarchy was settled for $40 million and a deferred gain of $15 million was recognized, which is included in ‘Gain on disposals’

on the Consolidated Statements of Income. No other transfers in or out of level 3 occurred during 2012 or 2011.

Unobservable inputs utilized to determine the fair value of the note receivable included the weighted average cost of capital and

volatility of the common shares of the counterparty.

TALISMAN ENERGY ANNUAL REPORT 2012

Interest rate swaps – 32 – 32

Commodity contracts – 40 – 40

2012

–

Realized and unrealized gains (losses) –

Cash received –

–

88

•

•

•
Derivative instrument Balance sheet presentation 2011

Interest rate swaps Current assets 12

24

–

30

–

Risk management assets 66

Commodity contracts Current liabilities –

–

Risk management liabilities –

During the year ended December 31, 2012, the Company recorded a loss on held-for-trading financial instruments of $93 million

(2011 – $210 million loss; 2010 – $87 million gain).

Talisman operates internationally and is therefore exposed to foreign exchange risk. Talisman’s primary exposure is from fluctuations

in the US$ relative to the C$, UK£, and NOK.

Talisman manages its foreign exchange exposure in a number of ways. By denominating most of its borrowings in US$, the Company

is able to reduce some of its economic exposure to currency fluctuations. Talisman also manages its translation exposure by generally

matching internal borrowings with its subsidiaries’ functional currencies. The Company purchases foreign currencies, mostly at spot

value, to meet its current foreign currency obligations as they come due.

Prior to 2011, the Company designated loans denominated in UK£ as an effective net investment hedge of its UK operations. During

the year ended December 31, 2010, losses of $14 million were included in other comprehensive loss. These losses are attributable to

the translation of Talisman’s UK£250 million denominated debt. Following a change in the functional currency of the UK operations

on January 1, 2011, foreign exchange gains of $2 million were recorded as a reduction of other expenses during the year ended

December 31, 2011. In 2012, as a result of the sale of 49% equity interest of TEUK to Sinopec, $23 million of exchange losses

previously accumulated in other comprehensive income were included in the ‘Gain on disposals’ on the Consolidated Statements of

Income (note 4).

In respect of financial instruments existing at December 31, 2012, a 1% strengthening of the US$ against the other currencies noted

above, with all other variables assumed constant, would have resulted in an increase of $5 million in net income and a $nil impact on

other comprehensive loss during the year ended December 31, 2012. A similar weakening of the US$ would have had the opposite

impact.

In conjunction with the issuance of the C$350 million 4.44% medium term notes in January 2006, the Company entered into a crosscurrency swap in order to hedge the foreign exchange exposure on this C$ denominated liability. As a result, the Company was

effectively paying interest semi-annually in US$ at a rate of 5.054% on a notional amount of $304 million. The cross-currency swap

was designated as a cash flow hedge. The notes were repaid in January 2011 and the hedge was settled.

Talisman is exposed to interest rate risk principally by virtue of its borrowings. Borrowing at floating rates exposes Talisman to

short-term movements in interest rates. Borrowing at fixed rates exposes Talisman to reset risk (i.e. at debt maturity). Risk

management activities aim to manage the mix of fixed-to-floating debt to best manage the trade-off between longer term interest rate

reset risk and shorter term volatility in interest rates.

In order to mitigate its exposure to interest rate changes, Talisman enters into interest rate swaps from time to time to manage the ratio

of fixed rate debt to floating rate debt. At December 31, 2012, the Company had fixed-to-floating interest rate swap contracts with a

total notional amount of $300 million that expire on May 15, 2015. During the year ended December 31, 2012, the fair value of the

fixed-to-floating interest rate swaps decreased by $4 million.

In respect of financial instruments existing at December 31, 2012, a 1% increase in interest rates would have resulted in a $5 million

decrease in net income and a $nil impact on other comprehensive income during the year ended December 31, 2012.

TALISMAN ENERGY ANNUAL REPORT 2012

Risk Management Assets, Liabilities, Gains and Losses

2012

13

Interest rate swaps Non-current assets 19

Cross-currency swaps Current assets –

Commodity contracts Current assets 35

Commodity contracts Non-current assets 7

74

81

Commodity contracts Non-current liabilities 1

82

Currency Risk

Interest Rate Risk

89
Talisman is exposed to credit risk, which is the risk that a customer or counterparty will fail to perform an obligation or settle a liability,

resulting in financial loss to the Company. Talisman manages exposure to credit risk by adopting credit risk guidelines approved by

the Board of Directors that limit transactions according to counterparty creditworthiness. The Company routinely assesses the

financial strength of its joint participants and customers, in accordance with the credit risk guidelines. Talisman’s credit policy

requires collateral to be obtained from counterparties considered to present a material risk of non-payment, which would include

entities internally assessed as high risk or those with ratings below investment grade. Collateral received from customers at

December 31, 2012 included $135 million of letters of credit. At December 31, 2012, an allowance of $33 million, representing the

Company’s 51% share of the $65 million allowance recorded in TEUK in 2011, consisted of a balance due from a counterparty that

had filed for bankruptcy.

A significant proportion of Talisman’s accounts receivable balance is with customers in the oil and gas industry and is subject to

normal industry credit risks. At December 31, 2012, approximately 91% of the Company’s trade accounts receivable was current and

the largest single counterparty exposure, accounting for 21% of the total, was with a very highly rated counterparty. Concentration of

credit risk is mitigated by having a broad domestic and international customer base of highly rated counterparties.

The Company also has credit risk arising from cash and cash equivalents held with banks and financial institutions. The Company’s

policy allows it to deposit cash balances at financial institutions subject to a sliding scale limit, depending on creditworthiness.

The maximum credit exposure associated with financial assets is the carrying values.

Talisman is exposed to liquidity risk, which is the risk that the Company may be unable to generate or obtain sufficient cash to meet its

commitments as they come due. Talisman mitigates this risk through its management of cash, debt, committed credit capacity and its

capital program.

Talisman manages its liquidity requirements by use of both short-term and long-term cash forecasts, and by maintaining appropriate

undrawn capacity under committed bank credit facilities. The Company has in place facilities totaling $4.1 billion that are fully

committed through 2014. At December 31, 2012, $nil of commercial paper and $nil in the form of bankers’ acceptances was drawn

and $91 million was supporting letters of credit. Available borrowing capacity was $4 billion at December 31, 2012.

In addition, the Company utilizes letters of credit pursuant to letter of credit facilities, most of which are uncommitted. At January 1,

2013, letters of credit totaling $2.1 billion had been issued under these facilities, of which $1.6 billion were provided as security for

the costs of decommissioning obligations in the UK. Under the contractual arrangements pursuant to which APUK acquired 49% of

the share capital of TEUK, APUK’s parent company, Sinopec, has provided an unconditional and irrevocable guarantee for 49% of the

UK decommissioning obligations. The remaining outstanding letters of credit relate primarily to a retirement compensation

arrangement, guarantees of minimum work commitments and decommissioning obligations in other areas.

The Company has no significant debt maturities until 2014.

Except for commodity price derivative contracts that mature as noted below, long-term debt that matures as outlined in note 17

and other long-term obligations detailed in note 18, all of the Company’s financial liabilities are due within one year.

TALISMAN ENERGY ANNUAL REPORT 2012

Credit Risk

Liquidity Risk

90
Talisman is exposed to commodity price risk since its revenues are dependent on the price of crude oil, natural gas and NGLs.

Talisman enters into derivative instruments from time to time to mitigate commodity price risk volatility under guidelines approved by

the Board of Directors. The Company may hedge a portion of its future production to protect cash flows to allow it to meet its strategic

objectives.

The Company had the following commodity price derivative contracts outstanding at December 31, 2012, none of which are

designated as hedges:

Floor/ceiling Fair value asset

Two-way collars (Oil) Term bbls/d $/bbl (liability)

Dated Brent oil index Jan – Dec 2013 6,000 90.00/121.63 –

(50)

Fair value asset

Fixed price swaps (Oil) Term bbls/d $/bbl (liability)

Dated Brent oil index Jan – Dec 2013 7,500 110.01 6

(20)

Floor/ceiling

Two-way collars (Gas) Term mcf/d $/mcf Fair value asset

NYMEX HH LD Jan – Dec 2013 47,468 3.16/4.67 1

30

Subsequent to December 31, 2012, the Company entered into a Dated Brent swap for the first quarter of 2014 of 1,000 bbls/d for

$104.15/bbl, a Dated Brent swap for the first half of 2014 of 10,000 bbls/d for $103.06/bbl, a Dated Brent swap for the second half of

2014 of 9,000 bbls/d for $103.67/bbl, a WTI swap for 2014 of 2,500 bbls/d for $91.91 and a NYMEX swap for 2014 of 85,443 mcf/d

for $4.25/mcf.

In respect of outstanding financial instruments and assuming forward commodity prices in existence at December 31, 2012, an

increase of $1/bbl in the price of oil and an increase of $0.10/mcf in the price of gas would have reduced the net fair value of

commodity derivatives, thereby resulting in a decrease in net income of $21 million during the year ended December 31, 2012. A

similar decrease in commodity prices would result in an increase in net income of approximately $24 million during the year ended

December 31, 2012.

Talisman’s provision for decommissioning is presented in note 15. With the exception of the provisions acquired as part of the Equion ́

acquisition described in note 6, the other provisions recorded by the Company are not material.

From time to time, Talisman is the subject of litigation arising out of the Company’s operations. Damages claimed under such litigation

may be material or may be indeterminate and the outcome of such litigation may materially impact the Company’s financial condition

or results of operations. While Talisman assesses the merits of each lawsuit and defends itself accordingly, the Company may be

required to incur significant expenses or devote significant resources to defend itself against such litigation. These claims are not

currently expected to have a material impact on the Company’s financial position.

TALISMAN ENERGY ANNUAL REPORT 2012

Commodity Price Risk

Dated Brent oil index Jan – Dec 2013 10,000 90.00/101.91 (30)

Dated Brent oil index Jan – Dec 2013 10,000 90.00/105.33 (23)

WTI Jan – Dec 2013 10,000 85.00/104.05 3

Dated Brent oil index Jan – Dec 2013 26,500 105.22 (25)

Dated Brent oil index Jan – Mar 2014 9,000 103.12 (1)

NYMEX HH LD Jan – Dec 2013 94,936 3.16/4.74 1

NYMEX HH LD Jan – Dec 2013 94,936 3.69/4.86 10

NYMEX HH LD Jan – Dec 2013 94,936 3.79/4.69 11

NYMEX HH LD Jan – Dec 2014 94,936 4.21/4.71 7

23. Contingencies and Commitments

Provisions and Contingencies

91
The New York Attorney General has commenced an investigation, pursuant to the Martin Act, into the disclosure practices of

companies engaged in hydraulic fracturing in the New York state area. The Martin Act provides broad authority to commence and

conduct investigations, whether upon receipt of a complaint, or on the Attorney General’s own initiative. Subpoenas have been issued

to a number of companies, including Talisman. The Company has been cooperating with the New York Attorney General in the

investigation. No enforcement action has been taken against Talisman, nor has the Company been advised that any enforcement

action is imminent.

Estimated future commitments for 2013 and beyond are as follows:

Subsequent

2013 2014 2015 2016 2017 to 2017 Total

Office leases 49 44 19 14 11 54 191

1,213 821 653 669 505 4,801 8,662

1) Future minimum payments denominated in foreign currencies have been translated into US$ based on the December 31, 2012 exchange rate.

2) Commitment amounts include the Company’s proportionate share of commitments from jointly controlled assets and jointly controlled entities.

3) Certain of the Company’s transportation commitments are tied to firm gas sales contracts.

4) PP&E and E&E include drilling rig commitments to meet a portion of the Company’s future drilling requirements, as well as minimum work commitments.

There have been no significant changes in the Company’s expected future payment commitments, and the timing of those payments,

since December 31, 2012.

Talisman’s estimated undiscounted decommissioning liabilities at December 31, 2012 were $4.1 billion (2011 – $5.0 billion),

approximately 40% of which relates to its UK operations. At December 31, 2012, Talisman had accrued $2.8 billion (2011 –

$3.0 billion), representing the discounted amount of this liability. The Company had provided letters of credit at January 1, 2013 in an

amount of $1.6 billion as security for the costs of decommissioning obligations in the UK. Under the contractual arrangements

pursuant to which APUK acquired 49% of the share capital of TEUK, APUK’s parent company, Sinopec, has provided an

unconditional and irrevocable guarantee for 49% of the UK decommissioning obligations. The Company has also issued guarantees

as security for certain minimum work, future dismantlement, site restoration and abandonment obligations in lieu of letters of credit.

Talisman has $280 million of abandonment letters of credit in place from January 1, 2013 until December 31, 2013 in respect of

assets held by third parties.

Talisman leases certain of its ocean-going vessels and corporate offices, all of which, with the exception of the leasing arrangements

described in note 18, are accounted for as operating leases. In addition to the minimum lease payments, Talisman has ongoing

operating commitments associated with the vessels. The majority of the vessel leases have an average life of five years, the office

leases have an average life of 10 years and the transportation commitment contracts have average lives of between 10 and 15 years.

Talisman has firm commitments for gathering, processing and transportation services that require the Company to pay tariffs to third

parties for processing or shipment of certain minimum quantities of crude oil, natural gas and NGLs. The Company has recorded a

provision for any commitments where sufficient production would not be met.

In the case of an operating lease entered into by Talisman as the operator of a jointly controlled asset, the amounts reported represent

the net operating lease expense and net future minimum lease payments. These net amounts are after deducting amounts

reimbursed, or to be reimbursed, by joint venture partners, whether the joint venture partners have co-signed the lease or not. Where

Talisman is not the operator of a jointly controlled asset, Talisman’s share of the lease expense and future minimum lease payments is

included in the amounts shown, whether Talisman has co-signed the lease or not. Where lease rentals are dependent on a variable

factor, the future minimum lease payments are based on the factor as at the inception of the lease.

During the year ended December 31, 2012, Talisman incurred net rental expense of $369 million (2011 – $461 million; 2010 –

$578 million) in respect of its operating leases.

In order to support the Company’s investments in natural gas projects outside of North America and the North Sea, Talisman has

entered into a number of long-term sales contracts.

TALISMAN ENERGY ANNUAL REPORT 2012

Estimated Future Minimum Commitments(1)(2)

Vessel leases 125 19 90 86 97 154 571

Transportation and processing commitments(3) 329 276 260 339 205 939 2,348

Decommissioning liabilities 49 83 77 103 117 3,645 4,074

PP&E and E&E assets(4) 413 232 128 66 11 – 850

Other service contracts 248 167 79 61 64 9 628

Long-Term Sales Contracts

92
The majority of Talisman’s Corridor natural gas production in Indonesia is currently sold under long-term sales agreements with PT

Chevron Pacific Indonesia (Chevron), Gas Supply Pte. Ltd. (Gas Supply) and PT Perusahaan Gas Negara (Persero), Tbk (PGN).

Under two sales agreements with Chevron, the majority of sales are priced at approximately 76% of the equivalent value of the

Indonesia Crude Price for Duri crude oil. One of the agreements with Chevron is currently scheduled to expire in 2013 while the

second agreement is due to expire in 2021. The minimum volume commitment under the second agreement is approximately

294 bcf over its remaining nine-year life.

Under the sales agreement with Gas Supply, sales to Singapore from Corridor are referenced to the spot price of high sulphur fuel oil

in Singapore. The minimum volume commitment is approximately 197 bcf over the remaining 11-year life of the contract. Sales from

Corridor to PGN for their markets in West Java are sold under a long-term contract with no associated transportation costs. The

minimum volume commitment is approximately 523 bcf over the remaining 11-year life of the contract. Subsequent to December 31,

2012, an agreement has been reached with PGN to increase the contract price for the sale of Corridor gas under the PGN West Java

Gas Sales Agreement. Under the new agreement, the gas price will increase in stages effective September 2012.

The balance of the gas production from Corridor is sold under medium to long-term agreements which vary in length from two to

seven years and are generally at fixed prices with fixed annual escalation.

At Jambi Merang, the majority of gas production is sold under long-term agreements which contain fixed prices with fixed annual

escalation and are in place until the current termination date of the PSC, which is February 2019.

The Company is subject to volume delivery requirements for approximately 90 mmcf/d at a price that is referenced to the Singapore

high sulphur fuel oil spot market in relation to a long-term sales contract in Malaysia, currently scheduled to end in 2018. In the event

these delivery requirements are not met in a contract year, volumes delivered in the subsequent contract year are subject to a 25%

price discount for the equivalent volume of unexcused shortage that was not delivered in the prior year.

Currently, the Company anticipates having sufficient production to meet future delivery requirements.

Years ended December 31 2011 2010

Pipeline and customer treating tariffs 53 75

6 11

19 21

78 107

Years ended December 31 2011 2010

Foreign exchange (gain) loss (12) (15)

26 28

18 5

8 1

65 –

56 53

161 72

TALISMAN ENERGY ANNUAL REPORT 2012

24. Other Income

2012

46

Investment income 9

Marketing income 28

83

25. Other Expenses, Net

2012

33

PP&E derecognition 20

Taxes, interest and penalties 1

Inventory writedowns 1

Allowance for doubtful accounts –

Other miscellaneous 70

125

93
North America Southeast Asia North Sea Other Total

Year ended December 31, 2012

Year ended December 31, 2011

17 444 834 146 1,441

Year ended December 31, 2010

13 336 729 58 1,136

North America Southeast Asia North Sea Other Total

Year ended December 31, 2012

Year ended December 31, 2011

(225) 56 467 (70) 228

Year ended December 31, 2010

(8) (36) (47) (19) (110)

During 2011, the Company made elections for its Canadian subsidiaries to file tax returns in US$ with effect from the beginning of

their 2011 and 2012 tax years. Tax on foreign exchange on tax pools has not been recorded since the effective dates of these

elections.

TALISMAN ENERGY ANNUAL REPORT 2012

26. Income Taxes

Current Tax Expense (Recovery)

Current tax (4) 500 117 153 766

Adjustments related to prior years 2 (1) – 5 6

Petroleum Revenue Tax – 46 56 – 102

(2) 545 173 158 874

Current tax 6 402 769 149 1,326

Adjustments related to prior years 11 (10) (4) (3) (6)

Petroleum Revenue Tax – 52 69 – 121

Current tax 13 292 624 69 998

Adjustments related to prior years – 5 20 (11) 14

Petroleum Revenue Tax – 39 85 – 124

Deferred Tax Expense (Recovery)

Origination (reversal) of temporary differences (352) (8) (1,463) 76 (1,747)

Adjustments related to prior years (2) 6 – 18 22

Petroleum Revenue Tax – (1) (33) – (34)

Changes in tax rates 5 – 137 8 150

Derecognized asset 429 – – – 429

80 (3) (1,359) 102 (1,180)

Origination (reversal) of temporary differences (206) 34 202 (73) (43)

Adjustments related to prior years (15) 10 – 3 (2)

Petroleum Revenue Tax – 12 40 – 52

Changes in tax rates (4) – 225 – 221

Origination (reversal) of temporary differences 40 (19) (39) (30) (48)

Adjustments related to prior years (48) (5) – 11 (42)

Petroleum Revenue Tax – (12) (8) – (20)

94
The most significant components of the net deferred tax liability are as follows:

PP&E and Decommissioning Tax loss

E&E assets liabilities carryforward Other Total

At December 31, 2010 4,125 (1,317) (430) (127) 2,251

At December 31, 2011 5,361 (1,743) (947) (11) 2,660

At December 31, 2012

Other movements in the net deferred tax liability relate mostly to reclassifications between assets and liabilities, currency adjustments

and risk management assets and liabilities.

At December 31, 2012, Talisman had unused non-capital tax losses of $2.3 billion (2011 – $2.6 billion) in respect of which a deferred

tax asset was recorded. These majority of losses arose in the US and expire between 2028 and 2032. The remaining losses are

generated from Canada and expire starting 2014. Income projections based upon discounted cash flow models, using assumptions

consistent with those presented in note 14, show sufficient taxable income to utilize these losses within the carryforward period.

The majority of the $1.3 billion (2011 – $480 million; 2010 – $294 million) of unused non-capital tax losses in respect of which no

deferred tax asset has been recognized arose in US and Southeast Asia.

No deferred tax liability has been recognized for temporary differences associated with investments in subsidiaries, associates,

branches and joint ventures since the Company is in a position to control or jointly control the entity and it is considered probable that

these temporary differences will not reverse in the foreseeable future.

The Company has experienced cumulative losses from its US operations in recent years. As a result, during 2012, the Company

derecognized deferred taxes assets of $429 million related to its US operations.

The following provides a reconciliation of the Canadian statutory tax rate of 25.05% (2011 – 26.76%; 2010 – 28.26%) to the effective

tax rate on the Company’s total income before income taxes.

Years ended December 31 2011 2010

Income (loss) before taxes 2,445 1,971

26.76% 28.26%

654 557

221 –

(54) (187)

(81) (46)

799 533

– –

(72) 163

(74) (72)

103 (26)

Income tax (recovery) expense (excluding PRT) 1,496 922

On December 17, 2012, Talisman completed the sale of a 49% equity interest in TEUK, which owns substantially all of the UK assets.

The sale was non-taxable resulting in a significant reduction in the effective tax rate. In addition, the UK government restricted tax

TALISMAN ENERGY ANNUAL REPORT 2012

Deferred Tax Assets and Liabilities

Charged (credited) to tax expense, net 1,017 (418) (517) 146 228

Credited to equity – – – (15) (15)

Acquisition adjustments 219 (8) – – 211

Other – – – (15) (15)

Charged (credited) to tax expense, net (1,603) 334 129 (40) (1,180)

Credited to equity – – – 11 11

Acquisition adjustments (1,385) 578 – 23 (784)

Other – ––11

2,373 (831) (818) (16) 708

Effective Tax Rate

2012

(174)

Statutory income tax rate (%) 25.05%

Income taxes calculated at the Canadian statutory rate (44)

Increase (decrease) in income taxes resulting from:

Change in statutory tax rates, net 137

Non-taxable income (602)

Deductible PRT expense (26)

Higher foreign tax rates (270)

Derecognition of deferred tax asset 429

Share-based payments (17)

Uplift (60)

Other 79

(374)

95
relief for decommissioning expenditures to a 50% tax rate from the UK tax rate of 62%. This measure was substantively enacted in

July 2012 and the deferred income tax expense associated with the legislative change was approximately $137 million.

In March 2011, the UK government announced that, from March 24, 2011, the rate of supplementary charge levied on ring fence

profits increased from 20% to 32%. Supplementary charge is levied on ring fence profits in addition to the ring fence corporation tax

rate of 30%, which remains unchanged. Consequently, there is now a combined UK corporation tax and supplementary charge rate

of 62% for oil and gas companies with fields not subject to PRT and 75% to 81% with fields subject to PRT. If the price of oil falls

below a certain level (currently expected to be $75/bbl) for a sustained period of time, the UK government has indicated that it will

reduce the supplementary charge rate back towards 20% on a ‘‘staged and affordable basis’’ while prices remain low. As a result of

this legislative change, the Company recorded additional current income tax expense of $101 million and additional deferred tax

expense of $225 million during the year ended December 31, 2011.

In 2010, changes to Canadian and foreign statutory tax rates did not materially impact the Company’s income tax expense.

Changes in the Company’s unrecognized tax benefit are as follows:

2011

Unrecognized tax benefit, beginning of year 49

22

(7)

(18)

Unrecognized tax benefit, end of year 46

Talisman’s entire unrecognized tax benefit as at December 31, 2012 and December 31, 2011, if recognized, would affect the

Company’s effective tax rate.

The settlement with taxation authorities occurring in 2011 was the result of the Company settling a tax position in Norway regarding

the deductibility of insurance premiums.

No significant change in the total unrecognized tax benefit is expected in 2013.

Years ended December 31 2011 2010

Depreciation, depletion and amortization 1,949 1,788

226 301

241 113

(324) 158

(192) (520)

(61) (258)

228 (110)

(11) 3

26 28

– –

42 53

2,124 1,556

TALISMAN ENERGY ANNUAL REPORT 2012

Unrecognized Tax Benefit

2012

46

Increase due to prior period tax positions 12

Decrease due to prior period tax positions –

Decrease due to settlement with taxation authorities –

58

27. Supplemental Cash Flow Information

Items Not Involving Cash

2012

2,501

Impairment, net of reversals 2,744

Dry hole 269

Share-based payments expense (recovery) (65)

Gains on disposals (1,624)

Unrealized (gain) loss on held-for-trading financial instruments 48

Deferred income tax (recovery) (1,180)

Foreign exchange 40

PP&E derecognition 20

Gain on revaluation of investment (note 12) (365)

Other 45

2,433

96
Years ended December 31 2011 2010

Accounts receivable (292) (47)

(26) (14)

(4) (12)

(34) (17)

142 294

(161) 163

(375) 367

1) $53 million of the decommissioning expenditures in 2012 were to settle liabilities that were recorded in accounts payable and accrued liabilities at December 31, 2011.

Years ended December 31 2011 2010

Cash interest paid 254 240

Cash interest received 5 11

Cash income taxes paid 1,592 974

In respect of its exploration and evaluation activities, the Company has included exploration expenditure of $346 million within cash

provided by operating activities, and exploration capital expenditure and acquisitions of $551 million and $78 million, respectively,

within cash used in investing activities.

Of the cash and cash equivalents balance of $721 million, $564 million has been invested in bank deposits and the remainder in

highly rated investments with original maturities of less than three months.

(millions) 2011 2010

Weighted average number of common shares outstanding – basic 1,023 1,018

15 –

Weighted average number of common shares outstanding – diluted 1,038 1,018

Outstanding stock options and PSUs are the only instruments that are dilutive to net income per share.

Basic net income per share is calculated by dividing net income less after-tax cumulative preferred share dividends, by the weighted

average number of common shares outstanding during the year, excluding shares held in trust to settle long-term PSU plan

obligations.

For the diluted net income per share calculation, the net income is adjusted for the change in the fair value of stock options. The

weighted average number of shares outstanding during the year is adjusted for options expected to be exercised and management’s

best estimate of shares expected to be issued in settlement of the Company’s obligations pursuant to the long-term PSU plan.

The Company sponsors both defined benefit and defined contribution pension arrangements covering substantially all employees in

Canada, the UK, Norway, the US and Indonesia. The Company also provides non-pension post-employment benefits to its Canadian

retirees.

Defined benefit pension plans are based on years of service and final average salary. The defined benefit pensions in the UK and

Norway, which account for 48% of the accrued benefit obligation at December 31, 2012, will increase at the rate of inflation. Although

the Company has no commitment to provide for increases related to inflation on its Canadian defined benefit pension plans, the

benefits have generally been increased annually by one-half of the rate of inflation since 2003.

Talisman uses actuarial reports prepared by independent actuaries on the defined benefit pension plans for funding and accounting

purposes. The Company uses a December 31 measurement date to value its benefit plan assets and obligations. The most recent

actuarial valuation of the Canadian employee and executive registered pension plans for funding purposes was at December 31,

TALISMAN ENERGY ANNUAL REPORT 2012

Changes in Non-Cash Operating Working Capital

2012

262

Inventories (15)

Prepaid expenses 1

Decommissioning expenditures(1) (56)

Accounts payable and accrued liabilities (29)

Income and other taxes payable (288)

(125)

Other Cash Flow Information

2012

291

8

1,159

28. Cash and Cash Equivalents

29. Net Income Per Share – Basic and Diluted

2012

1,025

Dilution effect of stock options and PSUs 8

1,033

30. Employee Benefits

97
2010, with the next valuation no later than December 31, 2013. The most recent actuarial valuation of the UK pension scheme for

funding purposes was at March 31, 2012, with the next valuation at March 31, 2015.

The following significant actuarial assumptions were employed to determine the net benefit expense and the accrued benefit

obligations:

2011 2010

Accrued benefit obligation

4.3 5.2

4.7 4.8

5.2 5.8

5.9 6.1

10 10

5 5

2036 2036

The discount rate assumptions reflect the prevailing rates available on high quality, fixed-income debt instruments.

The expected long-term rate of return on plan assets is established by developing a forward-looking, long-term return assumption for

each asset class, taking into account factors such as the expected real return for the specific asset class and inflation. A single,

long-term rate of return is then calculated as the weighted average of the target asset allocation and the long-term return assumption

for each asset class.

The Canadian defined benefit registered pension plan’s investment policy provides a framework for managing the plan assets, without

undue risk of capital loss and with a reasonable expectation of a rate of return or appreciation in value. Investment managers must

manage the plan assets to reasonably track the return of the appropriate index. Equity investments are passively managed to replicate

the S&P/TSX Index, the S&P 500 Index and the MSCI EAFE Index. Foreign equity investments are hedged to the Canadian dollar.

Investments in bonds and debentures are managed passively to replicate the DEX Long Term Bond Index and are limited to those

meeting minimum credit ratings. Assets are periodically re-balanced to the target asset allocation described below.

The UK pension scheme’s investment policy is designed to invest the plan’s assets in such a manner that the members’ benefit

entitlements can be paid as and when they fall due. This is achieved through asset diversification so as to limit the impact of any

single risk. Asset classes considered for the UK pension scheme’s investments are UK government and corporate bonds, UK and

global equities and diversified growth funds. Most plan assets are actively managed, with assets re-balanced to the target asset

allocation, described below, within a 5% tolerance range.

The approximate target allocation percentage for the Canadian defined benefit registered pension plans, which account for 32% of

total plan assets, is 50% equities and 50% bonds. The approximate target allocation for the UK defined benefit pension plan, which

accounts for 45% of total defined benefit plan’s assets, is 45% UK equities, 35% diversified growth fund and 20% UK bonds. Plan

assets do not include any common shares of Talisman, other than through Canadian or US equity pooled funds, or any assets used by

the Company.

The allocation of the assets of the defined benefit plans is as follows:

2011 2010

Equity securities (%) 61 64

31 30

6 4

2 2

– –

100 100

TALISMAN ENERGY ANNUAL REPORT 2012

Actuarial Assumptions

2012

Discount rate (%) 4.3

Rate of compensation increase (%) 4.4

Benefit expense

Discount rate (%) 4.2

Expected long-term rate of return on plan assets (%) 5.0

Assumed health care cost trend rates

Initial health care cost trend rate (%) 9

Health care cost trend rate declines to (%) 5

Year that cost trend reaches final rate 2036

Investment Policies

Plan Assets

2012

38

Fixed income (%) 35

Cash (%) 8

Real estate (%) 3

Other (%) 16

100

98
The Company characterizes inputs used in determining fair value using a hierarchy that prioritizes inputs depending on the degree to

which they are observable. Refer to note 22 for details concerning the three levels of the fair value hierarchy.

The fair values of defined benefit plan assets at December 31, 2012 by asset category were as follows:

Level 1 inputs Level 2 inputs Level 3 inputs Total fair value

Cash 17 – – 17

17 204 8 229

Information about the Company’s defined benefit pension plans is as follows:

2011

Pension plans grouped

by funded status

Surplus Deficit

Accrued benefit obligation

209 139

– –

(145) 145

– –

– 28

3 15

2 39

– 1

(5) (8)

(1) (4)

– –

Accrued benefit obligation, end of year 63 355

Plan assets

214 43

– –

(146) 146

– –

4 12

– (15)

– 26

– 1

(5) (8)

(3) –

– –

Fair value of plan assets, end of year 64 205

Funded status – surplus (deficit)(1) 1 (150)

1) The net accrued benefit asset and net accrued benefit liability are included in other assets and other long-term obligations, respectively, on the Consolidated

Balance Sheets.

During 2013, the Company expects to make contributions of $21 million to its defined benefit pension plans.

TALISMAN ENERGY ANNUAL REPORT 2012

Pooled Funds:

Canadian companies – 7 – 7

US companies – 15 – 15

International companies – 65 – 65

Bonds – 81 – 81

Real estate – – 8 8

Other – 36 – 36

Obligation, Assets and Funded Status

2012

Pension plans grouped

by funded status

Surplus Deficit

Accrued benefit obligation, beginning of year 63 355

Divestitures (note 4) – (93)

Transition of plans from a surplus to a deficit position – –

Transition of plans from a deficit to a surplus position – –

Current service cost – 24

Interest cost 3 11

Actuarial (gain) loss 2 (20)

Plan participants’ contributions – 1

Benefits paid (5) (16)

Foreign currency translation 2 11

Other – 4

65 277

Fair value of plan assets, beginning of year 64 205

Divestitures (note 4) – (77)

Transition of plans from a surplus to a deficit position – –

Transition of plans from a deficit to a surplus position – –

Expected return on plan assets 3 7

Actuarial gain (loss) on plan assets 3 3

Employer contributions – 33

Plan participants’ contributions – 1

Benefits paid (5) (16)

Foreign currency translation 2 7

Other 1 (2)

68 161

3 (116)

99
At December 31, 2012, the actuarial net present value of the accrued benefit obligation for non-pension post-employment benefits

was $13 million (2011 – $13 million). Non-pension post-employment benefits include medical, dental and life insurance benefits for

current and future Canadian retired employees.

Of the aggregate accrued benefit obligation of $340 million at December 31, 2012, $106 million related to plans that are unfunded.

The $96 million deficit of three unfunded plans is secured by letters of credit in the amount of $125 million.

Years ended December 31 2011 2010

Accrued benefit obligation at December 31 418 348

269 257

Net deficit (149) (91)

Experience gain (loss) on plan liabilities (41) (28)

(16) 16

The net benefit expense for the pension plans recognized in the Consolidated Statements of Income is as follows:

Years ended December 31 2011 2010

Current service cost – defined benefit 28 24

18 17

(16) (13)

2 1

Defined benefit plan expense 32 29

14 13

Net benefit expense 46 42

The actual return on plan assets in 2012 was $16 million (2011 – $nil; 2010 – $29 million).

During the year ended December 31, 2012, the net benefit expense for non-pension post-employment benefits was $1 million

(2011 – $1 million; 2010 – $1 million).

The pension and non-pension post-employment benefits of key management personnel are disclosed in note 32.

A 1% increase or decrease in the assumed medical cost trend rate would have an immaterial impact on both the accrued benefit

obligation at December 31, 2012 and the aggregate of current service and interest costs during the year ended December 31, 2012.

TALISMAN ENERGY ANNUAL REPORT 2012

History of Deficit and Experience Gains and Losses

2012

340

Fair value of plan assets at December 31 229

(111)

18

Actual return less expected return on plan assets 6

Net Benefit Expense

2012

24

Interest cost 14

Expected return on plan assets (10)

Other 3

31

Defined contribution plan expense 19

50

Sensitivity Information

100
Talisman’s activities are conducted in four geographic segments: North America, the North Sea, Southeast Asia and Other. The North

America segment includes operations in Canada and the US. The Southeast Asia segment includes operations and exploration

activities in Indonesia, Malaysia, Vietnam and Papua New Guinea and non-operated production in Australia/Timor-Leste. The North

Sea segment includes operations and exploration activities in the UK and Norway. The Company also has non-operated production in

Algeria, operations and exploration activities in Colombia, and exploration activities in Sierra Leone and the Kurdistan Region of Iraq.

In 2012, the Company announced its intent to exit Peru and expects to complete the process in 2013. For ease of reference, the

activities in Algeria, Colombia, Peru, Poland, Sierra Leone and the Kurdistan Region of Iraq are referred to collectively as the Other

geographic segment. All activities relate to the exploration, development, production and transportation of oil, liquids and natural gas.

North America (1) Southeast Asia (2) North Sea (3) Other (4) Total

(millions of US$) 2011 2010 2011 2010 2011 2010 2011 2010 2011 2010

Revenue

1,695 1,679 1,882 1,476 4,074 3,526 543 194 8,194 6,875

63 85 1 1 14 21 – – 78 107

Total revenue and other income 1,758 1,764 1,883 1,477 4,088 3,547 543 194 8,272 6,982

Segmented expenses

454 487 372 280 1,292 1,096 72 27 2,190 1,890

68 59 55 60 84 95 9 7 216 221

852 717 305 277 671 766 121 28 1,949 1,788

129 116 (16) 21 113 164 – – 226 301

6 (11) 127 31 106 70 2 23 241 113

70 52 208 116 40 47 109 159 427 374

22 (25) 17 16 105 91 29 5 173 87

Total segmented expenses 1,601 1,395 1,068 801 2,411 2,329 342 249 5,422 4,774

Segmented income (loss) before taxes 157 369 815 676 1,677 1,218 201 (55) 2,850 2,208

Non-segmented expenses

431 371

278 276

(310) 212

(12) (15)

210 (87)

(192) (520)

– –

Total non-segmented expenses 405 237

Income (loss) before taxes 2,445 1,971

Capital expenditures

198 216 257 125 128 133 138 119 721 593

1,960 1,481 230 317 1,077 984 157 95 3,424 2,877

(3) 3 – – – – – – (3) 3

Exploration and development 2,155 1,700 487 442 1,205 1,117 295 214 4,142 3,473

Acquisitions 1,319 1,530

(569) (2,273)

159 78

Net capital expenditures 5,051 2,808

Property, plant and equipment 6,740 5,351 2,501 2,296 5,809 5,368 859 251 15,909 13,266

2,370 1,886 498 627 538 540 548 389 3,954 3,442

140 149 149 149 866 866 162 – 1,317 1,164

987 2,389 560 628 645 920 788 141 2,980 4,078

Segmented assets 10,237 9,775 3,708 3,700 7,858 7,694 2,357 781 24,160 21,950

66 144

Total assets 24,226 22,094

Decommissioning liabilities 394 210 208 189 2,390 2,196 43 15 3,035 2,610

TALISMAN ENERGY ANNUAL REPORT 2012

31. Segmented Information

2012 2012 2012 2012 2012

Sales 1,435 2,190 2,981 623 7,229

Other income 72 3 8 – 83

1,507 2,193 2,989 623 7,312

Operating 564 418 1,383 87 2,452

Transportation 92 53 69 7 221

DD&A 1,140 427 796 138 2,501

Impairment 363 – 2,097 284 2,744

Dry hole 22 77 45 125 269

Exploration 29 92 47 178 346

Other 81 (19) 42 (12) 92

2,291 1,048 4,479 807 8,625

(784) 1,145 (1,490) (184) (1,313)

General and administrative 510

Finance costs 276

Share-based payments (recovery) expense (62)

Currency translation 33

(Gain) loss on held-for-trading financial

instruments 93

Gain on disposals (1,624)

Gain on revaluation of investment (365)

(1,139)

(174)

Exploration 157 59 86 249 551

Development 1,404 362 1,087 106 2,959

Midstream 1–––1

1,562 421 1,173 355 3,511

160

Proceeds on dispositions (964)

Other non-segmented 138

2,845

7,145 2,582 2,449 829 13,005

Exploration and evaluation assets 2,078 527 451 460 3,516

Goodwill 133 170 549 162 1,014

Other 685 637 1,675 1,252 4,249

10,041 3,916 5,124 2,703 21,784

Non-segmented assets 74

21,858

476 347 1,897 72 2,792

101
1 North America 2011 2010 2 Southeast Asia 2011 2010

Canada 1,127 1,454 Indonesia 1,126 839

631 310 532 481

Total revenue and other income 1,758 1,764 65 52

Canada 3,937 3,920 160 105

2,803 1,431 Total revenue and other income 1,883 1,477

Property, plant and equipment 6,740 5,351 Indonesia 1,023 986

Canada 1,207 685 883 1,053

1,163 1,201 297 19

47 26 Exploration and evaluation assets 2,370 1,886

251 212

Property, plant and equipment 2,501 2,296

Indonesia 12 27

41 29

5 253

440 318

Exploration and evaluation assets 498 627

3 North Sea 2011 2010 4 Other 2011 2010

UK 2,835 2,190 Algeria 256 194

1,253 1,357 287 –

Total revenue and other income 4,088 3,547 Total revenue and other income 543 194

UK 3,927 3,763 Algeria 284 251

1,882 1,605 575 –

Property, plant and equipment 5,809 5,368 Property, plant and equipment 859 251

UK 210 260 Colombia 75 49

328 280 303 239

Exploration and evaluation assets 538 540 133 98

37 3

Exploration and evaluation assets 548 389

TALISMAN ENERGY ANNUAL REPORT 2012

2012 2012

853 1,157

US 654 Malaysia 549

1,507 Vietnam 72

3,588 Australia 415

US 3,557 2,193

7,145 1,040

1,070 Malaysia 852

US 1,008 Vietnam 494

Papua New Guinea 44 2,078

Australia 152

2,582

11

Malaysia 72

Vietnam 14

Papua New Guinea 430

527

2012 2012

2,075 213

Norway 914 Colombia 410

2,989 623

1,989 273

Norway 460 Colombia 556

2,449 829

197 124

Norway 254 Kurdistan 323

451 Peru –

Other 13

460

102
The Consolidated Financial Statements include the financial statements of Talisman Energy Inc. and the directly or indirectly owned

subsidiaries. Transactions between subsidiaries are eliminated on consolidation. There were no related party transactions with entities

or other parties outside the consolidated group during the years ended December 31, 2012 and 2011. The following table lists the

material operating subsidiaries owned directly or indirectly by Talisman as at December 31:

Jurisdiction of Percentage of Voting

Name of Subsidiary Incorporation Securities Owned

Talisman Energy Canada Partnership Alberta 100%

Talisman Energy USA Inc Delaware 100%

Talisman Energy Norge AS Norway 100%

Talisman (Corridor) Ltd Barbados 100%

Talisman (Vietnam 15-2/01) Ltd. Alberta 100%

Talisman Malaysia Limited Barbados 100%

Talisman Malaysia (PM3) Limited Barbados 100%

Talisman (Algeria) BV The Netherlands 100%

1) In addition to the above list of material subsidiaries, Talisman also holds a 51% equity interest in Talisman Sinopec Energy UK Limited, a 49% equity interest in Equion ́

Energia Limited and a 50% equity interest in the Sasol Montney Limited Partnership. Talisman’s interest in these jointly controlled entities was accounted for using

proportional consolidation for the year ended December 31, 2012.

The compensation of key management personnel, consisting of the Company’s directors and executive officers, is as follows:

Years ended December 31 2011 2010

Short-term benefits 15 14

5 4

4 –

11 15

35 33

Short-term benefits comprise salaries and fees, annual bonuses, cash, vehicle and other benefits.

The amount of pension benefits reported represents the attributable amount of the net benefit expense of the plans in which the key

management personnel participate.

Termination benefits comprise amounts paid and accrued.

The share-based payments amount reported represents the cost to the Company of key management’s participation in share-based

payment plans, as measured by the fair value that the individual received based on the value of the shares exercised in the

current period.

TALISMAN ENERGY ANNUAL REPORT 2012

32. Related Party Disclosures

Major Subsidiaries(1)

Key Management Personnel Compensation

2012

15

Pension and other post-employment benefits 6

Termination benefits 15

Share-based payments 13

49

103
SEC

The supplemental data on the Company’s oil and gas activities was prepared in accordance with the FASB standard Extractive

Activities – Oil & Gas. Activities not directly associated with conventional crude oil and natural gas production are excluded from all

aspects of this supplementary oil and gas information. Comparable information prepared in accordance with Canadian disclosure

requirements (National Instrument 51-101 of the Canadian Securities Administrators) is contained in Appendix A of Talisman’s

Annual Information Form. Refer to the annual information form for additional disclosures under the Canadian Oil and Gas Evaluation

Handbook (COGEH) rules.

North America North Sea Southeast Asia

Years ended December 31 Other

($ millions) Canada USA UK(2) Norway Indonesia SEA(3) Other(4) Total

2012

Net oil and gas revenue derived from

proved reserves(1)

Results of operations

2011

Net oil and gas revenue derived from

proved reserves(1) 1,040 633 2,823 1,252 1,126 756 543 8,173

Results of operations 30 60 462 74 373 (5) 144 1,138

2010

Net oil and gas revenue derived from

proved reserves(1) 1,365 304 2,172 1,354 852 624 194 6,865

Results of operations 216 7 321 114 291 54 (63) 940

1) Net oil and gas revenue derived from proved reserves is net of applicable royalties.

2) UK includes 100% of TSEUK’s results of operations to December 17, 2012 and 51% thereafter.

3) Other Southeast Asia includes operations in Malaysia, Vietnam, Australia/Timor-Leste and Papua New Guinea.

4) The reporting segment entitled ‘‘Other’’ refers to Algeria, Colombia (49% of Equion’s results of operations subsequent to January 2011 as well as Talisman’s other  ́

Colombia assets), Peru, Poland, Sierra Leone, the Kurdistan Region of Iraq and, prior to its sale in 2010, Tunisia.

TALISMAN ENERGY ANNUAL REPORT 2012

SUPPLEMENTARY OIL AND GAS INFORMATION

(Unaudited)

Results of Operations from Oil and Gas Producing Activities

755 654 2,068 912 1,157 1,033 623 7,202

Less: Production costs 333 222 1,035 348 167 251 87 2,443

Transportation 34 58 28 41 52 1 7 221

Exploration and dry hole expense 39 12 12 80 28 142 303 616

Depreciation, depletion,

amortization, accretion and

impairment expense 909 610 788 2,166 96 326 425 5,320

Tax expense (recovery) (130) – 105 (1,429) 372 167 67 (848)

(430) (248) 100 (294) 442 146 (266) (550)

Less: Production costs 328 121 921 367 146 226 72 2,181

Transportation 35 33 37 47 55 – 9 216

Exploration and dry hole expense 54 29 64 81 114 218 107 667

Depreciation, depletion,

amortization, accretion and

impairment expense 581 352 492 354 73 217 120 2,189

Tax expense 12 38 847 329 365 100 91 1,782

Less: Production costs 421 59 793 296 127 153 27 1,876

Transportation 48 11 33 62 60 – 7 221

Exploration and dry hole expense 43 2 76 41 55 90 179 486

Depreciation, depletion,

amortization, accretion and

impairment expense 562 221 553 440 50 247 29 2,102

Tax expense 75 4 396 401 269 80 15 1,240

104
SEC

North America North Sea Southeast Asia

Years ended December 31 Other

($ millions) Canada USA UK(1) Norway Indonesia SEA(2) Other(3) Total

2012

Proved properties

Less: Accumulated depreciation, depletion

and amortization

Net capitalized costs

2011

Proved properties 7,037 3,798 8,730 3,890 1,415 3,110 1,323 29,303

8,241 4,963 8,940 4,218 1,608 3,414 1,873 33,257

Less: Accumulated depreciation, depletion

and amortization 3,660 1,040 4,806 2,012 577 1,463 476 14,034

Net capitalized costs 4,581 3,923 4,134 2,206 1,031 1,951 1,397 19,223

2010

Proved properties 6,554 2,113 8,092 3,280 1,358 2,556 611 24,564

7,238 3,315 8,373 3,554 1,511 3,157 1,000 28,148

Less: Accumulated depreciation, depletion

and amortization 3,152 693 4,347 1,669 499 1,251 364 11,975

Net capitalized costs 4,086 2,622 4,026 1,885 1,012 1,906 636 16,173

1) UK includes 100% of TSEUK’s costs to December 17, 2012 and 51% thereafter.

2) Other Southeast Asia includes operations in Malaysia, Vietnam, Australia/Timor-Leste, and Papua New Guinea.

3) The reporting segment entitled ‘‘Other’’ refers to Algeria, Colombia (49% of Equion’s costs subsequent to January 2011 as well as Talisman’s other Colombia assets),  ́

Peru, Poland, Sierra Leone the Kurdistan Region of Iraq and, prior to its sale in 2010, Tunisia.

TALISMAN ENERGY ANNUAL REPORT 2012

Capitalized Costs Relating to Oil and Gas Activities

6,938 5,171 4,770 2,902 1,457 3,503 1,068 25,809

Unproved properties 1,186 1,006 197 1,968 194 330 891 5,772

Incomplete wells and facilities 8 – 8 2 2 6 170 196

8,132 6,177 4,975 4,872 1,653 3,839 2,129 31,777

4,075 1,646 2,795 4,165 602 1,792 850 15,925

4,057 4,531 2,180 707 1,051 2,047 1,279 15,852

Unproved properties 1,196 1,165 195 276 192 259 389 3,672

Incomplete wells and facilities 8 – 15 52 1 45 161 282

Unproved properties 669 1,202 253 258 137 574 346 3,439

Incomplete wells and facilities 15 – 28 16 16 27 43 145

105
SEC

North America North Sea Southeast Asia

Years ended December 31 Other

($ millions) Canada USA UK(1) Norway Indonesia SEA(2) Other(3) Total

2012

Property acquisition costs

Proved

Total costs incurred

2011

Property acquisition costs

Proved properties 3 208 – 15 – 11 570 807

Total costs incurred 1,391 1,735 640 746 247 485 990 6,234

2010

Property acquisition costs

Proved 5 133 – – 117 – – 255

Total costs incurred 854 2,079 1,060 781 323 469 393 5,959

1) UK includes 100% of TSEUK’s costs to December 17, 2012 and 51% thereafter.

2) Other Southeast Asia includes operations in Malaysia, Vietnam, Australia/Timor-Leste, and Papua New Guinea.

3) The reporting segment entitled ‘‘Other’’ refers to Algeria, Colombia (49% of Equion’s costs subsequent to January 2011 as well as Talisman’s other Colombia assets),  ́

Peru, Poland, Sierra Leone the Kurdistan Region of Iraq and, prior to its sale in 2010, Tunisia.

TALISMAN ENERGY ANNUAL REPORT 2012

Costs Incurred in Oil and Gas Activities

– 2 – – – 19 – 21

Unproved 7 37 – – – 91 66 201

Exploration costs 191 11 53 79 32 117 351 834

Development costs 324 1,097 608 502 103 264 105 3,003

Decommissioning costs 81 53 305 156 3 78 33 709

603 1,200 966 737 138 569 555 4,768

Unproved properties 590 51 – – – 26 17 684

Exploration costs 93 14 52 116 105 349 248 977

Development costs 528 1,427 554 520 129 96 157 3,411

Decommissioning costs 177 35 34 95 13 3 (2) 355

Unproved 3 1,029 – 191 54 39 52 1,368

Exploration costs 199 19 93 87 72 163 234 867

Development costs 581 909 497 485 74 250 100 2,896

Decommissioning costs 66 (11) 470 18 6 17 7 573

106
SEC

Future net cash flows were calculated by applying the prescribed average annual prices to the Company’s estimated future

production of proved reserves and deducting estimates of future development, asset retirement, production and transportation costs,

and income taxes. Future costs have been estimated based on existing economic and operating conditions. Future income taxes have

been estimated based on statutory tax rates enacted at year-end using existing tax and cost pools. The present values of the estimated

future cash flows were determined by applying a 10% discount rate prescribed by the US Financial Accounting Standards Board.

In order to increase the comparability between companies, the standardized measure of discounted future net cash flows necessarily

employs uniform assumptions that do not necessarily reflect management’s best estimate of future events and anticipated outcomes.

There are numerous uncertainties inherent in estimating quantities of proved reserves and projecting future rates of production and

timing of development expenditures. Accordingly, the Company does not believe that the standardized measure of discounted future

net cash flows will be representative of actual future net cash flows and should not be considered to represent the fair market value of

the oil and gas properties. Actual future net cash flows will differ significantly from estimates due to, but not limited to, the following:

production rates will differ from those estimated both in terms of timing and amount. For example, future production may include

significant additional volumes from unproved reserves;

future prices and economic conditions will differ from those used in the preparation of the estimates;

future production and development costs will be determined by future events and will differ from those used in the preparation of

the estimates; and

estimated income taxes will differ in terms of amounts and timing dependent on the above factors, changes in enacted rates and

the impact of future expenditures on unproved properties.

TALISMAN ENERGY ANNUAL REPORT 2012

DISCOUNTED FUTURE NET CASH FLOWS

Standardized Measure of Discounted Future Net Cash Flows from Proved Reserves

107

•

•

•

•
SEC

The standardized measure of discounted future net cash flows was prepared using the following prices:

Average Prices 2011 2010

Crude oil & liquids US$/bbl

76.79 62.25

74.91 57.66

111.01 78.97

108.34 78.21

111.89 78.71

112.11 75.83

108.69 78.10

Total Company 104.26 75.79

Natural gas US$/mcf

3.92 4.05

4.19 4.63

6.51 4.57

7.25 4.95

7.64 6.61

7.61 5.65

3.65 –

Total Company 5.27 5.22

1) The price for Talisman’s oil in North America is lower than other oil prices as it is a heavier grade.

2) Other Southeast Asia includes Malaysia, Vietnam and Australia/Timor-Leste.

3) Other refers to Algeria, Colombia, and prior to its sale in 2010, Tunisia.

In order to derive the prices in the cash flow, the following benchmark prices and exchange rates were used:

2011 2010

WTI ($/bbl) 96.19 79.42

110.96 79.02

4.12 4.37

3.57 3.82

1.01 0.97

1.61 1.60

TALISMAN ENERGY ANNUAL REPORT 2012

2012

Canada (1) 61.51

USA (1) 73.76

UK 111.19

Norway 103.21

Indonesia 102.57

Other Southeast Asia (2) 115.83

Other(3) 106.92

96.11

Canada (1) 2.48

USA (1) 2.81

UK 7.75

Norway 6.78

Indonesia 8.31

Other Southeast Asia (2) 7.78

Other(3) 4.09

4.86

2012

94.71

Dated Brent ($/bbl) 111.13

HH gas ($/mmbtu) 2.76

AECO-C (C$/GJ) 2.23

US$/C$ 1.00

US$/UK£ 1.59

108
SEC

North America North Sea Southeast Asia

Years ended December 31 Other

(millions of $) Canada US UK Norway Indonesia SEA(2) Other(3) Total

2012

Future costs

Future Inflows before Income taxes

Net cash flows

Less 10% annual discount for estimated

timing of cash flows.

Discounted cash flows

2011

Future costs (5,381) (4,800) (21,232) (4,237) (2,552) (2,305) (918) (41,425)

Future inflows before income taxes 4,570 4,975 6,094 1,958 7,312 2,406 2,402 29,717

Net cash flows 3,761 4,617 1,647 1,616 4,251 1,622 1,638 19,152

Less 10% annual discount for estimated

timing of cash flows (1,516) (2,144) (236) (318) (1,551) (365) (448) (6,578)

Discounted cash flows 2,245 2,473 1,411 1,298 2,700 1,257 1,190 12,574

2010

Future costs (5,879) (2,492) (16,405) (3,141) (2,727) (1,617) (437) (32,698)

Future inflows before income taxes 4,148 3,537 4,547 1,410 6,885 1,548 1,042 23,117

Net cash flows 3,145 3,100 1,760 1,365 4,040 1,219 695 15,324

Less 10% annual discount for estimated

timing of cash flows (1,258) (1,588) (18) (202) (1,709) (222) (219) (5,216)

Discounted cash flows 1,887 1,512 1,742 1,163 2,331 997 476 10,108

1) Net oil and gas revenue derived from proved reserves is net of applicable royalties.

2) Other Southeast Asia includes Malaysia, Vietnam and Australia/Timor-Leste.

3) Other refers to Algeria and Colombia (49% of Equion’s cash flow as well as Talisman’s cash flow from other Colombia assets), and prior to its sale in 2010, Tunisia.  ́

TALISMAN ENERGY ANNUAL REPORT 2012

Standardized Measure of Discounted Future Net Cash Flows from Proved Reserves

Future Cash Inflows(1) 6,192 5,625 11,305 1,720 9,241 4,479 3,071 41,633

Future Costs

Transportation (262) (438) (200) (36) (489) (26) (95) (1,546)

Production (2,644) (1,538) (6,465) (1,031) (1,397) (1,540) (473) (15,088)

Development and Site Restoration (1,517) (1,406) (3,428) (832) (613) (547) (238) (8,581)

(4,423) (3,382) (10,093) (1,899) (2,499) (2,113) (806) (25,215)

1,769 2,243 1,212 (179) 6,742 2,366 2,265 16,418

Future Income & Production revenue taxes (104) – (990) 1,209 (2,803) (715) (696) (4,099)

1,665 2,243 222 1,030 3,939 1,651 1,569 12,319

(462) (816) 79 (736) (1,386) (342) (364) (4,027)

1,203 1,427 301 294 2,553 1,309 1,205 8,292

Future cash inflows(1) 9,951 9,775 27,326 6,195 9,864 4,711 3,320 71,142

Future costs

Transportation (315) (480) (414) (150) (540) – (75) (1,974)

Production (3,576) (1,984) (14,327) (2,811) (1,207) (1,526) (479) (25,910)

Development and site restoration (1,490) (2,336) (6,491) (1,276) (805) (779) (364) (13,541)

Future income & production revenue taxes (809) (358) (4,447) (342) (3,061) (784) (764) (10,565)

Future cash inflows(1) 10,027 6,029 20,952 4,551 9,612 3,165 1,479 55,815

Future costs

Transportation (381) (189) (398) (166) (794) – (48) (1,976)

Production (3,801) (1,014) (11,037) (2,123) (1,103) (1,143) (268) (20,489)

Development and site restoration (1,697) (1,289) (4,970) (852) (830) (474) (121) (10,233)

Future income & production revenue taxes (1,003) (437) (2,787) (45) (2,845) (329) (347) (7,793)

109
SEC

Year ended December 31 ($ millions) 2011 2010

Sales of oil & gas produced net of production costs (5,776) (4,768)

8,351 5,416

62 (197)

(2,755) 391

(2,052) (27)

1,560 1,603

2,132 1,990

513 679

1,039 189

(75) (893)

1,556 1,099

(1,847) (2,453)

(242) (37)

Net change 2,466 2,992

TALISMAN ENERGY ANNUAL REPORT 2012

Principal Sources of Changes in Standardized Measure of Discounted Future Net Cash Flows

2012

(4,538)

Net change in prices (2,198)

Net change in transportation costs (91)

Net changes in production costs (668)

Net changes in future development & site restoration costs (887)

Development costs incurred during year 2,176

Extensions, discoveries and improved recovery (195)

Revisions of previous reserve estimates (642)

Net purchases 2

Net sales of reserves in place (3,066)

Accretion of discount 1,987

Net change in taxes 3,947

Other (109)

(4,282)

110
SEC

Other

Southeast Latin

Canada US UK Norway Indonesia Asia America Other Total

Oil and Liquids (mmbbls)

Proved reserves at December 31, 2010 70.0 3.2 263.9 53.2 12.8 25.6 – 18.9 447.6

Proved reserves at December 31, 2011 62.0 17.3 245.0 52.7 15.5 30.3 12.8 15.5 451.1

Proved reserves at December 31, 2012

Proved developed

December 31, 2012

TALISMAN ENERGY ANNUAL REPORT 2012

Continuity of Net Proved Reserves

Total Proved

Proved reserves at December 31, 2009 89.4 – 266.1 55.9 12.7 28.6 – 21.0 473.7

Discoveries, additions and extensions 4.7 2.5 6.8 9.7 1.4 2.5 – 1.0 28.6

Purchase of reserves – 0.9 – – 1.5 – – – 2.4

Sale of reserves (15.1) (0.2) – – – – – (0.5) (15.8)

Net revisions and transfers (2.4) 0.1 18.0 1.8 (0.8) 0.6 – (0.2) 17.1

2010 Production (6.6) (0.1) (27.0) (14.2) (2.0) (6.1) – (2.4) (58.4)

Discoveries, additions and extensions 2.1 13.7 (4.1) 2.3 0.4 9.7 – (0.9) 23.2

Purchase of reserves – 0.6 – – – – 15.1 – 15.7

Sale of reserves (0.3) – – – – – – – (0.3)

Net revisions and transfers (3.5) 0.3 10.4 7.2 4.1 0.5 – (0.1) 18.9

2011 Production (6.3) (0.5) (25.2) (10.0) (1.8) (5.5) (2.3) (2.4) (54.0)

Discoveries, additions and extensions 10.3 11.4 9.4 (26.2) 0.2 1.5 3.9 (0.9) 9.6

Purchase of reserves – – – – – 1.1 – – 1.1

Sale of reserves (11.8) – (114.5) (2.7) (1.1) – – – (130.1)

Net revisions and transfers 5.1 (1.5) (21.6) (2.1) (2.0) 1.5 0.1 0.2 (20.3)

2012 Production (1) (5.7) (2.5) (18.9) (7.2) (2.1) (7.2) (3.3) (1.9) (48.8)

59.9 24.7 99.4 14.5 10.5 27.2 13.5 12.9 262.6

December 31, 2009 82.1 – 196.0 26.1 11.0 21.2 – 13.0 349.4

December 31, 2010 65.6 0.7 210.6 21.6 8.6 18.6 – 9.8 335.5

December 31, 2011 59.9 7.3 201.9 17.0 9.9 19.0 6.7 9.0 330.7

55.8 10.3 84.0 8.4 7.0 15.0 8.8 7.6 196.9

111
SEC

Other

Southeast Latin

Canada US UK Norway Indonesia Asia America Other Total

Natural Gas (bcf)

Proved reserves at December 31, 2010 1,354.5 1,257.9 23.8 79.6 1,269.2 225.8 – – 4,210.8

Proved reserves at December 31, 2011 1,292.7 1,985.8 18.7 67.6 1,107.2 188.8 83.5 – 4,744.3

Proved reserves at December 31, 2012

Proved developed

1) 2012 Production numbers reflect the best estimate of calendar year production and do not include out of period accounting adjustments.

TALISMAN ENERGY ANNUAL REPORT 2012

Continuity of Net Proved Reserves (continued)

Total Proved

Proved reserves at December 31, 2009 2,043.0 566.2 24.5 93.0 1,374.1 261.4 – 1.7 4,363.9

Discoveries, additions and extensions 263.7 738.6 0.1 6.7 8.1 (22.6) – – 994.6

Purchase of reserves – 17.5 – – 42.4 – – – 59.9

Sale of reserves (772.5) (5.8) – – – – – (1.6) (779.9)

Net revisions and transfers 11.2 10.3 4.9 12.1 (57.2) 14.3 – (0.1) (4.5)

2010 Production (190.9) (68.9) (5.7) (32.2) (98.2) (27.3) – – (423.2)

Discoveries, additions and extensions 251.1 799.4 (0.2) 4.6 36.1 9.2 – – 1,100.2

Purchase of reserves – 3.6 – – – – 93.5 – 97.1

Sale of reserves (165.5) – – – – – – – (165.5)

Net revisions and transfers 3.5 66.8 (1.4) (1.3) (94.1) (13.0) 0.2 – (39.3)

2011 Production (150.9) (141.9) (3.5) (15.3) (104.0) (33.2) (10.2) – (459.0)

Discoveries, additions and extensions 65.4 (550.0) 35.6 17.1 0.3 2.7 (9.6) – (438.5)

Purchase of reserves – – – – – 1.9 – – 1.9

Sale of reserves (97.2) – (20.3) – (9.1) – – – (126.6)

Net revisions and transfers (101.4) 66.0 0.9 (42.0) (3.9) 7.5 3.8 – (69.1)

2012 Production (1) (137.2) (176.8) (1.9) (9.6) (99.8) (32.3) (11.5) – (469.1)

1,022.3 1,325.0 33.0 33.1 994.7 168.6 66.2 – 3,642.9

December 31, 2009 1,663.5 171.1 22.4 91.2 915.2 225.5 – 0.8 3,089.7

December 31, 2010 1,011.4 584.9 22.0 73.3 763.7 187.2 – – 2,642.5

December 31, 2011 936.5 814.7 18.2 63.1 688.5 149.7 62.3 – 2,733.0

December 31, 2012 712.3 839.6 8.2 13.8 591.5 125.3 66.2 – 2,356.9

112
SEC

The following financial ratios are provided in connection with the Company’s shelf prospectuses filed with Canadian and US securities

regulatory authorities and are based on the Company’s Consolidated Financial Statements that are prepared in accordance with

International Financial Reporting Standards.

The interest coverage ratio is for the 12-month period ended December 31, 2012.

December 31, 2012

Interest coverage (times)

1) Net income plus income taxes and interest expense, divided by the sum of interest expense and capitalized interest.

Years ended December 31

(millions of $ unless otherwise stated) 2011 (1) 2010 (1) 2009 (2) 2008 (2)

Net income 776 945 437 3,519

3,434 2,954 3,961 6,163

Exploration and development expenditure 4,142 3,473 4,245 5,106

1,319 1,530 438 452

569 2,273 2,774 442

33 31 26 26

1.4 1.4 1.0 0.7

0.76 0.93 0.43 3.46

3.36 2.90 3.90 6.06

0.152 0.150 0.153 0.160

1.45 1.36 1.39 1.41

Average royalty rate (%)(5) 19 16 15 18

14.17 12.44 12.91 13.57

12.55 11.76 17.28 16.44

7.4 10.0 4.1 26.6

13.4 16.2 6.2 38.7

Return on equity (%)(8) 8.1 10.5 3.9 36.8

1) Presented in US$ and in accordance with International Financial Reporting Standards.

2) Presented in C$ and in accordance with Canadian GAAP.

3) Non-GAAP measure. See advisory provided.

4) Calculated in accordance with SEC methodology.

5) 2009 and 2008 restated for operations classified as discontinued in 2010.

6) Net income plus tax effected interest/(average shareholders’ equity + average debt).

7) Net income plus tax effected interest/(average shareholders’ equity + average debt – average non-depleted capital).

8) Net income/average shareholders’ equity.

TALISMAN ENERGY ANNUAL REPORT 2012

ADDITIONAL INFORMATION

Consolidated Financial Ratios

(Unaudited)

Income(1) (0.01)

Ratios and Key Indicators

2012 (1)

132

Cash flow(3) 3,022

3,511

Acquisitions 160

Dispositions 964

Debt/debt + equity (%) 31

Debt/cash flow (times) 1.4

Per common share

Net income ($) 0.12

Cash flow ($)(3) 2.95

Production (boe) 0.152

Proved gross reserves (at year-end) (boe)(4) 1.06

21

Unit operating costs ($/boe) 15.83

Unit DD&A ($/boe)(5) 16.09

Return on capital employed (%)(6) 2.2

Return on active capital employed (%)(7) 3.9

1.3

113
Years ended December 31 2011 2010 2009 2008

Daily average production before royalties

17 17 25 30

30 35 38 32

96 109 117 123

23 14 16 21

6 6 9 10

4434

2433

Total oil and liquids 178 189 211 224

Natural gas (mmcf/d)

899 778 803 856

506 485 403 334

52 104 77 57

34 – – –

Total natural gas 1,491 1,367 1,283 1,247

Total (mboe/d) 426 417 425 432

WTI (average $/bbl) 95.13 79.53 61.79 99.65

4.07 4.39 4.05 8.95

0.9833 1.0054 0.9555 0.8166

TALISMAN ENERGY ANNUAL REPORT 2012

Historical Operations Summary

2012

Oil (mbbls/d)

North America 19

Southeast Asia 37

North Sea 70

Other 22

Natural gas liquids (mbbls/d)

North America 8

Southeast Asia 5

North Sea 1

162

North America 985

North Sea 524

Southeast Asia 31

Other 42

1,582

426

94.22

NYMEX gas (average $/mmbtu) 2.80

US$/C$ exchange rate (year-end) 1.0051

114
SEC

Information on Net Production and Product Netbacks in US$ is provided for US readers.

Year ended December 31 2011 2010 2009 2008

Oils and liquids (bbls/d)

19 18 27 32

17 22 26 17

97 113 120 127

13 7 9 11

Total oil and liquids 146 160 182 187

Natural gas (mmcf/d)

803 718 720 712

351 339 286 223

52 104 77 57

27 – – –

Total natural gas 1,233 1,161 1,083 992

Total mboe/d 351 353 362 352

TALISMAN ENERGY ANNUAL REPORT 2012

Net Production – After Royalties

2012

North America 23

Southeast Asia 24

North Sea 70

Other 14

131

North America 871

Southeast Asia 357

North Sea 31

Other 33

1,292

347

115
SEC

Net of Royalties ($) 2011 2010

North America

Oil and liquids (US$/bbl)

75.19 62.59

1.08 0.90

13.40 14.25

60.71 47.44

Natural gas (US$/mcf)

3.93 4.79

0.21 0.20

1.21 1.48

2.51 3.11

North Sea (2)

Oil and liquids (US$/bbl)

110.75 80.13

1.71 1.44

35.78 25.75

73.26 52.94

Natural gas (US$/mcf)

8.62 6.35

1.24 0.95

1.90 0.79

5.48 4.61

Southeast Asia (3)

Oil and liquids (US$/bbl)

115.82 80.54

1.20 0.88

40.99 25.07

73.63 54.59

Natural gas (US$/mcf)

9.30 6.72

0.37 0.43

0.98 0.72

7.95 5.57

Other(4)

Oil (US$/bbl)

110.32 82.69

1.76 2.87

11.82 11.41

96.74 68.41

TALISMAN ENERGY ANNUAL REPORT 2012

Product Netbacks After Royalties(1)

2012

Sales price 69.39

Transportation 1.32

Operating costs 13.24

54.83

Sales price 2.63

Transportation 0.25

Operating costs 1.40

0.98

Sales price 111.83

Transportation 1.90

Operating costs 53.69

56.24

Sales price 9.77

Transportation 1.83

Operating costs 1.32

6.62

Sales price 111.69

Transportation 1.05

Operating costs 34.09

76.55

Sales price 9.28

Transportation 0.33

Operating costs 0.94

8.01

Sales price 113.52

Transportation 1.39

Operating costs 12.58

99.55

116
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Net of Royalties ($) 2011 2010

Natural Gas (US$/mcf)

4.22 –

0.06 –

1.86 –

2.30 –

Total Company

Oil and liquids (US$/bbl)

107.04 78.19

1.58 1.35

31.49 23.74

73.97 53.10

Natural gas (US$/mcf)

5.92 5.59

0.31 0.34

1.24 1.22

4.37 4.03

1) Pursuant to US reporting practice, netbacks are calculated using US$ and production after deduction of royalty volumes.

2) North Sea includes Norway and the UK, which includes 100% of TSEUK’s netbacks prior to December 17, 2012 and 51% thereafter.

3) Southeast Asia includes Indonesia, Vietnam, Malaysia and Australia/Timor-Leste.

4) Other refers to Algeria, Colombia (49% of Equion’s netbacks subsequent to January 2011 as well as the netbacks from Talisman’s other Colombia assets) and Peru.  ́

TALISMAN ENERGY ANNUAL REPORT 2012

Product Netbacks After Royalties(1) (continued)

2012

Sales price 4.30

Transportation –

Operating costs 2.00

2.30

Sales price 104.82

Transportation 1.59

Operating costs 38.78

64.45

Sales price 5.01

Transportation 0.33

Operating costs 1.38

3.30

117
SEC

2012 2011 2010 2009 2008

Oil and liquids (mmbbls)

509.7 531.9 544.5 749.3

34.8 33.5 29.0 36.9

19.5 4.7 1.2 0.3

(0.3) (19.4) (53.7) (19.5)

19.1 27.8 87.8 (140.8)

(64.8) (68.8) (76.9) (81.7)

Closing balance 518.0 509.7 531.9 544.5

Natural gas (bcf)

5,236.9 5,272.7 5,338.4 5,464.2

1,235.5 1,151.7 861.7 395.3

121.7 83.7 24.6 18.1

(180.3) (876.4) (426.6) (65.3)

(52.5) 104.3 (56.9) (17.6)

(543.6) (499.1) (468.5) (456.3)

Closing balance 5,817.7 5,236.9 5,272.7 5,338.4

boe (mmboe)(2)

1,382.5 1,410.7 1,434.3 1,659.8

240.7 225.5 172.6 102.8

39.8 18.6 5.3 3.3

(30.3) (165.5) (124.8) (30.3)

10.3 45.2 78.3 (143.5)

(155.4) (152.0) (155.0) (157.8)

Closing balance 1,487.6 1,382.5 1,410.7 1,434.3

1) For definitions of reserves, see notes found on page 125 of this Annual Report.

2) Six mcf of natural gas equals one boe.

TALISMAN ENERGY ANNUAL REPORT 2012

Historical Gross Proved Reserves(1)

Opening balance 518.0

Discoveries, additions and extensions 16.6

Purchase of reserves 2.1

Sale of reserves (134.7)

Net revisions and transfers (18.7)

Production (59.7)

323.6

Opening balance 5,817.7

Discoveries, additions and extensions (524.8)

Purchase of reserves 2.6

Sale of reserves (135.1)

Net revisions and transfers (98.2)

Production (580.1)

4,482.1

Opening balance 1,487.6

Discoveries, additions and extensions (71.0)

Purchase of reserves 2.5

Sale of reserves (157.2)

Net revisions and transfers (35.1)

Production (156.2)

1,070.6

118
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Other

Southeast Latin

Canada US UK Norway Indonesia Asia America Other Total

Oil and Liquids (mmbbls)

Total Proved

Proved reserves at December 31, 2010 79.3 4.3 265.3 53.2 32.1 39.9 – 35.6 509.7

Discoveries, additions and extensions 3.1 18.3 (4.2) 2.3 1.0 13.7 – 0.6 34.8

Proved reserves at December 31, 2011 72.7 23.1 246.3 52.7 28.9 46.2 15.9 32.2 518.0

Discoveries, additions and extensions

Proved reserves at December 31, 2012

Proved developed

December 31, 2012

TALISMAN ENERGY ANNUAL REPORT 2012

Continuity of Gross Proved Reserves

Proved reserves at December 31, 2009 101.0 – 267.5 55.9 28.6 39.9 – 39.0 531.9

Discoveries, additions and extensions 5.0 3.4 6.8 9.7 3.4 3.0 – 2.2 33.5

Purchase of reserves – 1.2 – – 3.5 – – – 4.7

Sale of reserves (18.5) (0.2) – – – – – (0.7) (19.4)

Net revisions and transfers 0.2 – 18.0 1.8 0.9 6.7 – 0.2 27.8

2010 Production (8.4) (0.1) (27.0) (14.2) (4.3) (9.7) – (5.1) (68.8)

Purchase of reserves – 0.7 – – – – 18.8 – 19.5

Sale of reserves (0.3) – – – – – – – (0.3)

Net revisions and transfers (1.7) 0.6 10.7 7.2 (0.2) 1.1 (0.1) 1.5 19.1

2011 Production (7.7) (0.8) (25.5) (10.0) (4.0) (8.5) (2.8) (5.5) (64.8)

12.7 15.0 9.4 (26.2) 0.1 2.0 4.8 (1.2) 16.6

Purchase of reserves – – – – – 2.1 – – 2.1

Sale of reserves (15.3) – (115.0) (2.7) (1.7) – – – (134.7)

Net revisions and transfers 3.9 (2.1) (21.8) (2.1) 1.0 2.5 0.1 (0.2) (18.7)

2012 Production (1) (6.8) (3.3) (19.1) (7.2) (4.1) (10.9) (4.0) (4.3) (59.7)

67.2 32.7 99.8 14.5 24.2 41.9 16.8 26.5 323.6

December 31, 2009 92.6 – 197.1 26.1 23.2 31.2 – 23.7 393.9

December 31, 2010 74.6 0.9 211.9 21.6 21.4 30.8 – 19.6 380.8

December 31, 2011 70.3 9.7 203.1 17.0 20.0 31.1 8.3 19.8 379.3

62.3 13.7 84.4 8.4 16.0 25.3 11.0 15.8 236.9

119
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Other

Southeast Latin

Canada US UK Norway Indonesia Asia America Other Total

Natural Gas (bcf)

Total Proved

Proved reserves at December 31, 2010 1,497.2 1,473.1 23.8 79.6 1,815.2 348.0 – – 5,236.9

Discoveries, additions and extensions 265.9 953.7 (0.2) 4.6 4.2 7.3 – – 1,235.5

Proved reserves at December 31, 2011 1,391.2 2,351.4 18.8 67.6 1,568.7 315.6 104.4 – 5,817.7

Discoveries, additions and extensions

Proved reserves at December 31, 2012

Proved developed

December 31, 2012

1) 2012 production numbers reflect the best estimate of calendar year production and do not include out of period accounting adjustments.

TALISMAN ENERGY ANNUAL REPORT 2012

Continuity of Gross Proved Reserves (continued)

Proved reserves at December 31, 2009 2,248.5 650.7 24.5 93.0 1,877.5 376.7 – 1.8 5,272.7

Discoveries, additions and extensions 286.4 874.7 0.1 6.7 21.2 (37.4) – – 1,151.7

Purchase of reserves – 23.0 – – 60.7 – – – 83.7

Sale of reserves (867.3) (7.3) – – – – – (1.8) (876.4)

Net revisions and transfers 33.2 12.5 4.9 12.1 (3.0) 44.6 – – 104.3

2010 Production (203.6) (80.5) (5.7) (32.2) (141.2) (35.9) – – (499.1)

Purchase of reserves – 4.8 – – – – 116.9 – 121.7

Sale of reserves (180.3) – – – – – – – (180.3)

Net revisions and transfers (31.6) 87.3 (1.2) (1.3) (107.3) 1.6 – – (52.5)

2011 Production (160.0) (167.5) (3.6) (15.3) (143.4) (41.3) (12.5) – (543.6)

63.3 (640.4) 35.6 17.1 0.6 4.3 (5.3) – (524.8)

Purchase of reserves – – – – – 2.6 – – 2.6

Sale of reserves (104.8) – (20.4) – (9.9) – – – (135.1)

Net revisions and transfers (129.9) 77.5 0.9 (42.0) (1.1) (1.6) (2.0) – (98.2)

2012 Production (1) (152.1) (209.7) (1.9) (9.6) (148.1) (44.3) (14.4) – (580.1)

1,067.7 1,578.8 33.0 33.1 1,410.2 276.6 82.7 – 4,482.1

December 31, 2009 1,840.9 197.9 22.4 91.2 1,231.6 320.8 – 0.8 3,705.6

December 31, 2010 1,134.7 687.5 22.0 73.3 1,083.1 281.3 – – 3,281.9

December 31, 2011 1,016.8 965.0 18.3 63.1 965.9 250.4 77.9 – 3,357.4

754.2 997.3 8.2 13.8 809.8 214.2 82.7 – 2,880.2

120
SEC

Year ended December 31, 2012

(thousand acres) Developed Undeveloped Total

Property Gross Net Gross Net Gross Net

North America (1)

Total North America

North Sea

Total North Sea

Southeast Asia

Total Southeast Asia

Latin America

Total Latin America

Other

Total Other

Total Worldwide

1) ‘‘Developed’’ acreage consists of acreage assigned to productive wells. Each productive shale well has been allocated 80 acres of spacing and, for non-shale wells, the

actual Drilling Spacing Unit has been used.

2) Canada undeveloped acreage includes ‘‘Frontier’’ acreage of 4,932.7 gross (2,790.2 net) thousand acres in the Northwest Territories, Yukon and Nunavut.

3) UK acreage reflects 51% of the acreage of TSEUK as at December 31, 2012.

4) The Corridor PSC constitutes a significant portion of the Company’s acreage in Indonesia.

5) Equion acreage includes 49% of the acreage of Equi  ́ on as at December 31, 2012.  ́

6) Rest of World includes the Kurdistan Region of Iraq, Sierra Leone and Poland.

TALISMAN ENERGY ANNUAL REPORT 2012

DETAILED PROPERTY REVIEWS

2012 Acreage

Canada (Including Frontier)(2) 811.5 511.6 7,791.6 4,863.7 8,603.1 5,375.3

United States 118.8 93.7 864.5 708.9 983.3 802.6

930.3 605.3 8,656.1 5,572.6 9,586.4 6,177.9

United Kingdom(3) 265.7 188.4 542.4 260.7 808.1 449.1

Norway 43.0 18.1 1,644.8 582.9 1,687.8 601.0

308.7 206.5 2,187.2 843.6 2,495.9 1,050.1

Indonesia (4) 277.3 66.5 13,852.6 4,476.1 14,129.9 4,542.6

Malaysia 116.1 48.1 3,522.6 2,336.5 3,638.7 2,384.6

Vietnam 19.8 2.2 8,349.0 3,620.8 8,368.8 3,623.0

Australia/Timor-Leste 11.0 4.1 259.8 71.1 270.8 75.2

Papua New Guinea – – 7,336.7 3,210.4 7,336.7 3,210.4

424.2 120.9 33,320.7 13,714.9 33,744.9 13,835.8

Colombia

Equion ́ (5) 17.9 3.3 123.5 24.8 141.4 28.1

Other Colombia – – 9,887.9 4,606.4 9,887.9 4,606.4

Peru – – 8,639.3 3,361.1 8,639.3 3,361.1

17.9 3.3 18,650.7 7,992.3 18,668.6 7,995.6

Algeria 196.0 34.4 – – 196.0 34.4

Rest of World(6) – – 1,367.0 461.6 1,367.0 461.6

196.0 34.4 1,367.0 461.6 1,563.0 496.0

1,877.1 970.4 64,181.7 28,585.0 66,058.8 29,555.4

121
SEC

The following tables set forth the number of wells 1 Talisman has drilled and tested or participated in drilling and testing, and the net 2

interest of Talisman in such wells for each of the last three fiscal years. The number of wells drilled refers to the number of wells

completed at any time during the fiscal years, regardless of when drilling was initiated.

Exploration Development Total

Year ended December 31, 2012 Oil Gas Dry(3) Total Oil Gas Dry(3) Total Oil Gas Dry(3) Total

North America

North Sea

Southeast Asia

Latin America

Other

Total Gross

1) The number of wells refers to gross wellbores, which is the total number of wells Talisman has drilled or participated in drilling, with a working interest. Service wells,

including water injection, gas injection, water source and water disposal wells are not included. Multilaterals from the same wellbore are counted as a single wellbore.

Stratigraphic test wells are included.

2) ‘‘Net’’ wellbores are the aggregate of the percentage working interest of the Company in each of the gross wellbores. Data is rounded to the nearest decimal

and summed.

3) A dry well (hole) is an exploratory, development or extension well found to be incapable of producing either oil or gas in sufficient quantities to justify completion as an oil

or gas well. The term ‘‘completion’’ refers to the installation of permanent equipment for the production of oil and gas, or, in the case of a dry hole, to reporting of

abandonment to the appropriate agency or authority. A productive oil or gas well is an exploratory, development or extension well that is not a dry well.

4) UK includes 100% of TSEUK’s activity to December 17, 2012 and 51% thereafter.

5) Colombia includes 49% of Equion’s activities as well as Talisman’s other Colombia activities.  ́

6) Rest of World includes Poland, Sierra Leone and the Kurdistan Region of Iraq.

TALISMAN ENERGY ANNUAL REPORT 2012

2012 Drilling Activity

Canada Gross 11 6 – 17 29 75 – 104 40 81 – 121

Net 10.1 4.9 – 15.0 19.6 47.6 – 67.2 29.7 52.5 – 82.2

United States Gross – – – – 55 153 – 208 55 153 – 208

Net – – – – 26.7 73.9 – 100.6 26.7 73.9 – 100.6

United Kingdom(4) Gross 1 – – 1 3 – – 3 4 – – 4

Net 0.4 – – 0.4 0.9 – – 0.9 1.3 – – 1.3

Norway Gross – – 2221–32125

Net – – 0.6 0.6 1.3 0.7 – 2.0 1.3 0.7 0.6 2.6

Indonesia Gross 3 – – 3 18 4 – 22 21 4 – 25

Net 0.2 – – 0.2 3.1 0.9 – 4.0 3.3 0.9 – 4.2

Malaysia Gross ––––32–532–5

Net – – – – 1.2 0.8 – 2.0 1.2 0.8 – 2.0

Vietnam Gross – – 2 2 7 – – 7 7 – 2 9

Net – – 0.8 0.8 0.1 – – 0.1 0.1 – 0.8 0.9

Australia/Timor-Leste Gross ––––––––––––

Net – – – – – – – – – – – –

Papua New Guinea Gross – 3 2 5 –––––325

Net – 1.3 1.2 2.5 – – – – – 1.3 1.2 2.5

Colombia (5) Gross 4 – 3 7 6 – – 6 10 – 3 13

Net 2.0 – 0.8 2.8 1.0 – – 1.0 3.0 – 0.8 3.8

Peru Gross – – 1 1 – – – 1 1

Net – – 0.5 0.5 – – – 0.5 0.5

Algeria Gross – 4 – – 4 4 – – 4

Net – 0.3 – – 0.3 0.3 – – 0.3

Rest of World (6) Gross 1 – 1 2 – 1 – 1 2

Net 0.4 – 0.3 0.7 – 0.4 – 0.3 0.7

20 9 11 40 127 235 – 362 147 244 11 402

Net 13.1 6.2 4.2 23.5 54.2 123.9 – 178.1 67.3 130.1 4.2 201.6

122
2012 2011 2010 2009 2008 2012 2011 2010 2009 2008

North America International

Total oil wells 100 65 5 138 Total oil wells 47 57 59 73

327 243 154 286 Total gas wells 10 11 12 37

100 100 98 100 Drilling success (%) 83 85 86 89

TALISMAN ENERGY ANNUAL REPORT 2012

Five Year Drilling Results

95 52

Total gas wells 234 10

Drilling success (%) 100 85

123
This Annual Report contains information that constitutes ‘‘forward-looking information’’ or ‘‘forward-looking statements’’ (collectively

‘‘forward-looking information’’) within the meaning of applicable securities legislation. Forward-looking information is included

throughout this Annual Report. This forward-looking information includes, but is not limited to, statements regarding business

strategy, plans and priorities; expected production, company-wide; regionally and by product; expected divestitures and/or JVs and

targeted timing and targeted value of disposals; potential share repurchase and other potential reinvestment alternatives; targeted

debt to cash flow ratio; expected G&A reductions; expected cash flow – company-wide, regionally and by product-type; expected free

cash flow; expected benefits of the partnership with Sinopec in the UK; expected improvement in drilling performance in the Eagle

Ford and expected associated benefits; planned drilling and rigs and drilling strategy in North America; expected completion of the

Deep Cut facility; expected seismic, drilling, testing and other activity in Colombia; expected benefits of the ownership share in the

Ocensa pipeline; expected exploration and development activities in Talisman’s Asia-Pacific region; possible exploration upside in the

Sabah basin; potential sanction of production train at the Suban field; expected completion of and production at HST/HSD; targeted

first production at Stanley; planned focus and strategy in the UK, including infill program; planned drilling in Kurdistan; expected

capital expenditures and planned focus of such spending; expected outcomes and events as a result of the elements of the business

strategy; the estimated impact on Talisman’s financial performance from changes in production volumes, commodity prices and

exchange rates; the effects of the hedging program; expected capital sources to fund the Company’s capital program and

acquisitions; anticipated funding of the decommissioning liabilities; expected future payment commitments and the estimated timing

of such payments, including share-based payment expenses in future periods; expectation that the Company’s counterparties will be

able to meet their obligations; planned fulfilment of the Company’s legal obligations as the Company exits Peru; and other

expectations, beliefs, plans, goals, objectives, assumptions, information and statements about possible future events, conditions,

results of operations or performance. The company priorities disclosed in this Annual Report are objectives only and their

achievement cannot be guaranteed. Indicative capital estimates for 2013, which are provided in this Annual Report, are subject to

change. Statements concerning oil and gas reserves contained in this Annual Report may be deemed to be forward-looking

information as they involve the implied assessment that the resources described can be profitably produced in the future.

The factors or assumptions on which the forward-looking information is based include: assumptions inherent in current guidance;

projected capital investment levels; the flexibility of capital spending plans and the associated sources of funding; the successful and

timely implementation of capital projects; the continuation of tax, royalty and regulatory regimes; ability to obtain regulatory and

partner approval; commodity price and cost assumptions; and other risks and uncertainties described in the filings made by the

Company with securities regulatory authorities. The Company believes the material factors, expectations and assumptions reflected in

the forward-looking information are reasonable but no assurance can be given that these factors, expectations and assumptions will

prove to be correct. Forward-looking information for periods past 2013 assumes escalating commodity prices. Closing of any

transactions will be subject to receipt of all necessary regulatory approvals and completion of definitive agreements.

Undue reliance should not be placed on forward-looking information. Forward-looking information is based on current expectations,

estimates and projections that involve a number of risks which could cause actual results to vary and in some instances to differ

materially from those anticipated by Talisman and described in the forward-looking information contained in this MD&A. The material

risk factors include, but are not limited to: the risks of the oil and gas industry, such as operational risks in exploring for, developing

and producing crude oil and natural gas; risks and uncertainties involving geology of oil and gas deposits; risks associated with project

management, project delays and/or cost overruns; uncertainty related to securing sufficient egress and access to markets; the

uncertainty of reserves and resources estimates, reserves life and underlying reservoir risk; the uncertainty of estimates and

projections relating to production, costs and expenses, including decommissioning liabilities; risks related to strategic and capital

allocation decisions, including potential delays or changes in plans with respect to exploration or development projects or capital

expenditures; fluctuations in oil and gas prices, foreign currency exchange rates, interest rates and tax or royalty rates; the outcome

and effects of any future acquisitions and dispositions; health, safety, security and environmental risks, including risks related to the

possibility of major accidents; environmental, regulatory and compliance risks, including with respect to greenhouse gases and

hydraulic fracturing; uncertainties as to the availability and cost of credit and other financing and changes in capital markets; risks in

conducting foreign operations (for example, civil, political and fiscal instability and corruption); risks related to the attraction, retention

and development of personnel; changes in general economic and business conditions; the possibility that government policies,

regulations or laws may change or governmental approvals may be delayed or withheld; and results of the Company’s risk mitigation

strategies, including insurance and any hedging activities.

The foregoing list of risk factors is not exhaustive. Additional information on these and other factors which could affect the Company’s

operations or financial results or strategy are included in the Company’s most recent AIF. In addition, information is available in the

Company’s other reports on file with Canadian securities regulatory authorities and the SEC. Forward-looking information is based on

the estimates and opinions of the Company’s management at the time the information is presented. The Company assumes no

obligation to update forward-looking information should circumstances or management’s estimates or opinions change, except as

required by law.

TALISMAN ENERGY ANNUAL REPORT 2012

Advisories

Forward-Looking Statements

124
Talisman’s disclosure of reserves data and other oil and gas information in accordance with US disclosure standards is made in

reliance on an exemption granted to Talisman by Canadian securities regulatory authorities, which permits Talisman to provide such

disclosure in order to allow comparison of oil and gas disclosure with that provided by US and other peers. The primary differences

between the US disclosure standards and the Canadian disclosure mandated under NI 51-101 are that:

a) NI 51-101 requires disclosure of gross and net reserves using forecast prices, whereas the SEC rules require the disclosure of

net reserves estimated using a historical 12-month average price;

b) NI 51-101 requires the disclosure of the net present value of future net revenue attributable to all of the disclosed reserve

categories, estimated using forecast prices and costs, before and after deducting income tax expenses, calculated without

discount and using discount rates of 5%, 10%, 15% and 20%, whereas the SEC rules require disclosure of the present value of

future net cash flows attributable to proved reserves only, estimated using a constant price (the historical 12-month average

price) and a 10% discount rate;

c) NI 51-101 requires a one-year reconciliation of gross proved reserves, gross probable reserves and gross proved plus probable

reserves, based on forecast prices and costs, for various product types, whereas the SEC rules require a three-year reconciliation

of net proved reserves, based on constant prices and costs, for less specific product types;

d) NI 51-101 requires reserves to show a hurdle rate of return, whereas the SEC rules require reserves to be only cash flow positive

on an undiscounted basis.

Further information on the differences between the US standards and NI 51-101 requirements is set forth under the heading ‘Note

Regarding Reserves Data and Other Oil and Gas Information’ in Talisman’s most recent AIF.

In addition to the reserves data and certain other oil and gas information included in this annual report which is provided in

accordance with NI 51-101, there is data and information provided in accordance with US disclosure standards.

A separate exemption granted to Talisman also permits it to disclose internally evaluated reserves data. Any reserves and resources

data contained in this annual report reflects Talisman’s estimates of its reserves and resources. While Talisman annually obtains an

independent audit of a portion of its proved and probable reserves, no independent qualified reserves evaluator or auditor was

involved in the preparation of the reserves and resources data disclosed in this annual report.

In this Annual Report, Talisman also discloses contingent resources, prospective resources and PIIP as at February 28, 2013. Where

not otherwise indicated, in this annual report, the contingent resources provided are 2C and the prospective resources are unrisked

best estimates.

Contingent resources are defined as 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. The contingencies that prevent the resources from being classified as

reserves are: lack of gas sales contract; additional testing; production and performance appraisal activities; development time frame

too far in the future; demonstration of economic viability; facilities and egress; access to equipment and services; hydraulic fracturing

technology; commodity prices and regulatory approvals. There is no certainty that it will be commercially viable to produce any portion

of the resources. In addition to these contingencies and uncertainties the development of commerciality of resources is also subject to

a number of risk factors, as discussed more fully above.

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. Unrisked prospective resources are not risked for change

of development or chance of discovery. If a discovery is made, there is no certainty that it will be developed or, if it is developed, there

is no certainty as to the timing of such development. In this Annual Report risked prospective resources have been risked for chance

of discovery but have not been risked for chance of development. If a discovery is made, there is no certainty that it will be developed

or, if it is developed, there is no certainty as to the timing of such development.

PIIP is defined as petroleum initially in place and is that quantity of petroleum that is estimated to exist originally in naturally occurring

accumulations. It is the total quantity of petroleum that is estimated, as of a given date, to be contained in known accumulations, prior

to production. PIIP estimates may contain all resource classifications, both discovered and undiscovered. 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.

TALISMAN ENERGY ANNUAL REPORT 2012

Reserves Data and Other Oil and Gas Information

Resources

125
The reserves life index (‘‘RLI’’) of 12 years for proved plus probable reserves in the Americas and Asia-Pacific was calculated by

dividing the year-end proved plus probable reserves by the 2013 production guidance in the Americas and Asia-Pacific.

In this Annual Report, all references to ‘‘core’’ or ‘‘non-core’’ assets and properties align with the Company’s current public disclosures

regarding its assets and properties.

Throughout this Annual Report, Talisman makes reference to production volumes. Such production volumes are stated on a gross

basis, which means they are stated prior to the deduction of royalties and similar payments. In the US, net production volumes are

reported after the deduction of these amounts. US readers may refer to the table headed ‘Net Production After Royalties’ in Talisman’s

most recent AIF for a statement of Talisman’s net production volumes by reporting segment that are comparable to those made by US

companies subject to SEC reporting and disclosure requirements.

Talisman discloses its Company netbacks in this Annual Report. Netbacks per boe are calculated by deducting from sales price

associated royalties, operating and transportation costs.

Included in this Annual Report is the Company’s financial outlook. Its purpose is to enrich management’s discussion and analysis.

This information may not be appropriate for other purposes.

This Annual Report also contains discussions of anticipated cash flow and anticipated free cash flow both on an aggregate and per

share basis. The material assumptions used in determining estimates of cash flow are: the anticipated production volumes; estimates

of realized sales prices, which are in turn driven by benchmark prices, quality differentials and the impact of exchange rates;

estimated royalty rates; estimated operating expenses; estimated transportation expenses; estimated general and administrative

expenses; estimated interest expense, including the level of capitalized interest; and the anticipated amount of cash income tax and

petroleum revenue tax. The amount of is inherently difficult to predict.

Anticipated production volumes are, in turn, based on the midpoint of the estimated production range and do not reflect the impact of

any potential asset dispositions or acquisitions. The completion of any contemplated asset acquisitions or dispositions is contingent

on various factors including favourable market conditions, the ability of the Company to negotiate acceptable terms of sale and receipt

of any required approvals for such acquisitions or dispositions.

In addition to the assumptions that underpin forecasted cash flow, forecasted free cash flow also includes assumptions around capital

investments and financing activities.

Included in this Annual Report are references to financial measures used in the oil and gas industry such as free cash flow, cash flow,

capital expenditure and net debt. These terms are not defined by IFRS. Consequently, these are referred to as non-GAAP measures.

Talisman’s reported results of such measures may not be comparable to similarly titled measures reported by other companies.

Free Cash Flow is used by management to assess the amount of funds available for reinvestment or to reduce debt levels or return to

shareholders. Free cash flow is the net of cash provided by operating, investing and financing activities before the repayment or

issuance of long-term debt.

Cash Flow represents net income before exploration costs, DD&A, impairment, deferred taxes and other non-cash expenses. Cash

flow is used by the Company to assess operating results between years and between peer companies using different accounting

policies. Cash flow should not be considered an alternative to, or more meaningful than, cash provided by operating, investing and

financing activities or net income as determined in accordance with IFRS as an indicator of the Company’s performance or liquidity.

The Company’s 2013 cash provided by operating activities is expected to be $1.8 billion.

TALISMAN ENERGY ANNUAL REPORT 2012

Non-Core Assets/Properties

Gross Production

Netbacks

Financial Outlook

Forecasted Cash Flow and Forecasted Free Cash Flow

Non-GAAP Financial Measures

126
Capital expenditure (or ‘‘exploration and development spending’’ or ‘‘capital spend’’) is calculated by adjusting the capital expenditure

per the financial statements for exploration costs that were expensed as incurred, including the capital spend of the jointly controlled

entities of the Company.

Year Ended

(US$ millions) December 31, 2012

Exploration, development and other 3,658

Exploration expensed 346

The company’s 2013 estimated capital expenditure, pursuant to IFRS, is expected to be $2 billion.

Net debt is calculated by adjusting the company’s long-term debt per the financial statements for bank indebtedness, cash and cash

equivalents. The company uses this information to assess its true debt position and eliminate the impact of timing differences.

TALISMAN ENERGY ANNUAL REPORT 2012

Capital spend 4,004

127
The following abbreviations and definitions are used in this Annual Report:

AIF Annual Information Form

bbl barrel

bbls barrels

bbls/d barrels per day

bcf billion cubic feet

boe barrels of oil equivalent

boe/d barrels of oil equivalent per day

C$ Canadian dollar

CO2 Carbon dioxide

E&E Exploration and evaluation

EU European Union

G&A General and administrative

GAAP Generally Accepted Accounting Principles

gj Gigajoule

IFRS International Financial Reporting Standards

LIBOR London Interbank Offered Rate

LNG Liquefied Natural Gas

mbbls/d thousand barrels per day

mboe/d thousand barrels of oil equivalent per day

mcf thousand cubic feet

mcf/d thousand cubic feet per day

mmbbls million barrels

mmboe million barrels of oil equivalent

mmbtu million British thermal units

mmcf/d million cubic feet per day

mmcfe/d million cubic feet equivalent per day

NGL Natural Gas Liquids

NI National Instrument

NOK Norwegian kroner

NYMEX New York Mercantile Exchange

PGN PT Perusahaan Gas Negara (Persero), Tbk

PP&E Property, plant and equipment

PRT Petroleum Revenue Tax

PSC Production Sharing Contract

PSU Performance share unit

SEC US Securities and Exchange Commission

tcf trillion cubic feet

UK United Kingdom

UK£ Pound sterling

US United States of America

US$ or $ United States dollar

WTI West Texas Intermediate

Gross acres means the total number of acres in which Talisman has a working interest. Net acres means the sum of the fractional

working interests owned in gross acres expressed as whole numbers and fractions thereof.

Gross production means Talisman’s interest in production volumes (through working interests and royalty interests) before the

deduction of royalties. Net production means Talisman’s interest in production volumes after deduction of royalties payable

by Talisman.

Gross wells means the total number of wells in which the Company has a working interest. Net wells means the sum of the fractional

working interests owned in gross wells expressed as whole numbers and fractions thereof.

Conversion and equivalency factors

Imperial Metric

1 ton = 0.907 tonnes

1 acre = 0.40 hectares

1 barrel = 0.159 cubic metres

1 cubic foot = 0.0282 cubic metres

TALISMAN ENERGY ANNUAL REPORT 2012

Abbreviations and Definitions

128
TALISMAN ENERGY ANNUAL REPORT 2012 129

CORPORATE GOVERNANCE

Talisman’s commitment to corporate governance and corporate responsibility contributes to the 

creation of long-term value for the company’s stakeholders.

RESPONSIBILITIES

The principal role of Talisman’s Board of Directors is stewardship of the company, and its fundamental objective is the creation of 

shareholder value, including the protection and enhancement of the value of the company’s assets. The Board oversees the conduct 

of the business and management, which, in turn, is responsible for developing long-term strategy and conducting the company’s 

day-to-day business. In addition, the Board ensures systems are in place to manage the risks and, through the Chief Executive 

Officer, sets the outlook and direction of the company toward environmental, health and safety policies, regulatory compliance and 

financial practices and reporting.

INDEPENDENCE

At year-end 2012, Talisman had 10 directors, all of whom, with the exception of the President and Chief Executive Officer, were 

independent. The majority of Talisman’s Board committees are also composed entirely of independent directors.

EFFECTIVENESS

Talisman ensures the continuing effectiveness of its Chairman, committees and individual directors through annual assessments. 

In addition, ongoing succession and recruitment processes are in place to ensure the continuing effectiveness of the Board and 

its committees. The Governance and Nominating Committee has established a comprehensive director selection process, which is 

integrated with the annual assessment process.

STOCK EXCHANGE AND REGULATORY COMPLIANCE

Talisman’s corporate governance practices satisfy all the existing guidelines for effective corporate governance established by the 

Canadian Securities Administrators, all of the NYSE corporate governance listing standards applicable to non-US companies and a 

substantial majority of the NYSE corporate governance listing standards applicable to US companies.

Talisman has disclosed the significant differences between its corporate governance practices and the requirements applicable to 

US companies listed on the NYSE on the company’s website at www.talisman-energy.com.
130 TALISMAN ENERGY ANNUAL REPORT 2012

INVESTOR INFORMATION

COMMON SHARES

Transfer Agent

Computershare Trust Company of Canada

Calgary, Toronto, Montreal, Vancouver

US Co-transfer Agent

Computershare Trust Company N.A.

Authorized

Unlimited number of common shares

Unlimited number of preferred shares 

issuable in series

Issued 

1,032,463,974 1 common shares at 

December 31, 2012

8,000,000 Cumulative Redeemable

Rate Reset First Preferred Shares,

Series 1, at December 31, 2012

STOCK EXCHANGE LISTINGS

Common Shares

Symbol: TLM

Canada: Toronto Stock Exchange

United States: New York Stock Exchange

Preferred Shares

Symbol: TLM.PR.A

Canada: Toronto Stock Exchange

PUBLIC DEBT

Trustee

Computershare Trust Company of Canada

7.25% (US$) unsecured debentures

Trustee

JP Morgan Chase, London Branch

6.625% (UK£) unsecured notes 

Trustee

Bank of Nova Scotia Trust Company of 

New York

3.75% (US$) unsecured notes

5.125% (US$) unsecured notes

5.50% (US$) unsecured notes

5.75% (US$) unsecured notes

5.85% (US$) unsecured notes

6.25% (US$) unsecured notes

7.75% (US$) unsecured notes

Private Debt

8.25% (US$) unsecured notes

8.5% (US$) unsecured notes

Dividends

In 2012, the company paid dividends 

on Talisman’s common shares totaling 

US$0.27 per share. The dividends 

were paid on June 29 (semi-annual), 

September 28 (quarterly) and December 

31 (quarterly). While a quarterly dividend 

is Talisman’s current practice, Talisman 

does not have a specific dividend policy 

and the declaration of dividends is at the 

sole discretion of its Board of Directors.

Over the last three-year period, Talisman 

paid semi-annual dividends on its 

common shares, totaling C$0.25/share 

in 2010, US$0.27/share in 2011 and 

US$0.27/share in 2012.

In 2012, the Company paid dividends on 

its Series 1 First Preferred Shares totaling 

C$1.011 per Series 1 First Preferred 

Share, which relects a quarterly dividend 

rate of C$0.2625 per Series 1 First 

Preferred Share plus the pro rata portion 

of that rate from the issuance of the Series 

1 First Preferred Shares on December 13, 

2011 to December 31, 2011.

Holders of Series 1 preferred shares are 

entitled to receive a cumulative quarterly 

fixed dividend of 4.2% annually for the 

initial period ending December 31,2016, 

as and when declared by the Board of 

Directors. Thereafter, the dividend rate will 

be reset every five years at a rate equal 

to the five-year Government of Canada 

bond yield plus 2.77%. Holders of the 

Series 1 preferred shares will have the 

right to convert all or any of their shares 

into an equal number of Series 2 preferred 

shares, subject to certain conditions, on 

December 31, 2016 and on December 31 

in every fifth year thereafter, and will then 

be entitled to receive quarterly floating rate 

cumulative preferential cash dividends 

equal to the sum of the average rate on 

90-day Government of Canada treasury 

bills plus 2.77%.

Annual Meeting 

The annual meeting of shareholders of 

Talisman Energy Inc. will be held at 

11:00 a.m. on Wednesday, May 1, 2013 

in Macleod Hall, South Building; Lower 

Level of the TELUS Convention Centre, 

120-9th Avenue SE, Calgary, Alberta. 

Shareholders are encouraged to attend 

the meeting, but those who are unable to 

do so are requested to participate by 

voting, using one of the three available 

methods: (i) telephone, (ii) the internet, or 

(iii) signing and returning the Form of 

Proxy or Voting Instruction Form mailed 

with the Management Proxy Circular.

1. Includes shares held in trust relating to the company’s Performance Share Unit Plan.
TALISMAN ENERGY ANNUAL REPORT 2012 131

CORPORATE INFORMATION

BOARD OF DIRECTORS

a Christiane Bergevin 3,4

Quebec, Canada

Christiane Bergevin has been the 

Executive Vice-President, Strategic 

Partnerships, Office of the President, of 

Desjardins Group since August 2009. 

Prior to that, she was Senior VicePresident and General Manager, Corporate 

Projects, with SNC-Lavalin Group Inc. For 

the 18 years prior to that, Ms. Bergevin 

held executive finance positions with 

various SNC-Lavalin subsidiaries, 

including President of SNC-Lavalin Capital 

Inc., its project finance advisory arm, 

between 2001 and 2008.

b Donald Carty 1,5

Texas, United States 

Donald Carty served as Vice Chairman 

and Chief Financial Officer of Dell Inc. 

from January 2007 until mid-2008. From 

1998 to 2003, he was the Chairman and 

Chief Executive Officer of AMR Corp. and 

American Airlines. Prior to that, Mr. Carty 

served as President of AMR Airline Group 

and American Airlines. Mr. Carty was the 

President and Chief Executive Officer of 

Canadian Pacific Airlines from March 

1985 to March 1987. 

c William Dalton 1,3,6

Arizona, United States

William Dalton was Chief Executive of 

HSBC Bank plc from 1998 to 2004, 

Executive Director of HSBC Holdings plc 

from 1998 to 2004, Global Head of 

Personal Financial Services for HSBC 

Group from 2002 to 2004 and held 

various positions in the Canadian 

operations of HSBC prior to 1998. 

d Kevin Dunne 4,6

Tortola, British Virgin Islands

Kevin Dunne has held various 

international senior and executive 

management positions with BP plc, 

including General Manager of Abu Dhabi 

Company for Onshore Oil Operations 

(ADCO), a BP joint venture, from 1994 

to 2001, Corporate Associate President 

of BP Indonesia from 1991 to 1994 

and Corporate Head of Strategy for 

the BP Group based in London from 

1990 to 1991. 

e Harold Kvisle 2

Alberta, Canada

Harold Kvisle was appointed President 

and Chief Executive Officer of Talisman 

Energy Inc. on September 10, 2012. 

Mr. Kvisle was the President and Chief 

Executive Officer of TransCanada 

Corporation or its predecessor 

TransCanada Pipelines Limited from 

May 2001, until his retirement in 

June 2010. Prior to his employment with 

TransCanada, Mr. Kvisle was the President 

of Fletcher Challenge Energy Canada Inc. 

from 1990 to 1999. Mr. Kvisle has worked 

in the oil and gas industry since 1975 

and in the pipeline and power industries 

since 1999.

f Brian M. Levitt 3,5

Quebec, Canada

Brian Levitt is Chairman of the TorontoDominion Bank and non-executive 

co-Chair of Osler, Hoskin & Harcourt LLP. 

Mr. Levitt joined Osler in 1976. In 1991, 

he became President and was 

subsequently named CEO of Imasco 

Limited. Imasco was sold in 2000 and Mr. 

Levitt returned to Osler in 2001. Mr. Levitt 

holds a law degree from the University of 

Toronto, where he also completed his 

Bachelor of Applied Science degree in 

Civil Engineering. 

a b c d e f
132 TALISMAN ENERGY ANNUAL REPORT 2012

g Lisa Stewart 5,6

Texas, United States

Lisa Stewart became the Chief Executive 

Officer of Sheridan Production Partners in 

September 2006. Prior to that, Ms. 

Stewart was President of EI Paso 

Exploration & Production from February 

2004 to August 2006. Prior to her time at 

El Paso, Ms. Stewart worked for Apache 

Corporation for 20 years beginning in 

1984 in a number of capacities. Her last 

position with Apache was Executive 

Vice-President of Business Development 

and E&P Services.

h Peter Tomsett 4,5

British Columbia, Canada 

Peter Tomsett was the President and Chief 

Executive Officer of Placer Dome Inc. from 

September 2004 to January 2006. Mr. 

Tomsett was with Placer Dome for 20 

years in a number of capacities. Prior to 

becoming President and CEO, he was 

Executive Vice-President of Placer Dome 

Asia Pacific and Africa.

i Michael Waites 1,6

British Columbia, Canada

Michael Waites, President and Chief 

Executive Officer of Finning International 

Inc. since May 2008, announced his 

retirement from Finning in 2013, but will 

continue to serve as President and CEO 

until a replacement is appointed. Prior to 

that, Mr. Waites was Executive Vice 

President and Chief Financial Officer of 

Finning. He also served as a member of 

the board of directors of Finning for three 

years prior to his appointment as 

Executive Vice President and Chief 

Financial Officer. Prior to joining Finning in 

May 2006, Mr. Waites was Executive Vice 

President and Chief Financial Officer at 

Canadian Pacific Railway from July 2000, 

and was also Chief Executive Officer U.S. 

Network of Canadian Pacific Railway. 

Previously, he was Vice President and 

Chief Financial Officer at Chevron Canada 

Resources. 

j Charles Williamson 2

Chairman of the Board

California, United States

Charles Williamson was the Executive 

Vice-President of Chevron Corporation 

from August to December 2005. From 

2001 to 2005, he was Chairman and 

Chief Executive Officer of Unocal 

Corporation and held various executive 

positions within Unocal, including 

Executive Vice President, International 

Energy Operations and Group Vice 

President, Asia Operations prior to 2001. 

k Charles Winograd 1,3

Ontario, Canada

Charles Winograd is Senior Managing 

Partner of Elm Park Credit Opportunities 

Fund. He is also President of Winograd 

Capital Inc. From 2001 to 2008, he was 

Chief Executive Officer of RBC Capital 

Markets. When RBC Dominion Securities 

acquired Richardson Greenshields in 

1996, Mr. Winograd became Deputy 

Chairman and a director. He was 

appointed to the position of President 

and Chief Operating Officer of RBC 

Dominion Securities in 1998. Mr. 

Winograd held several executive postings 

in Richardson Greenshields until 

becoming President and Chief Executive 

Officer in 1987 and Chairman and Chief 

Executive Officer in 1991. 

1 Member of Audit Committee

2 Member of Executive Committee

3 Member of Governance and Nominating Committee

4 Member of Health, Safety, Environment and 

Corporate Responsibility Committee

5 Member of Human Resources Committee 

6 Member of Reserves Committee

g h i ij k
TALISMAN ENERGY ANNUAL REPORT 2012 133

EXECUTIVES 

a Harold Kvisle

President and Chief 

Executive Officer

b Paul Blakeley

Executive Vice-President

Asia - Pacific

c Richard Herbert

Executive Vice-President

Exploration and Development

d Bob Rooney

Executive Vice-President

Legal and General Counsel

e Paul Smith

Executive Vice-President

North America

f Scott Thomson

Executive Vice-President

Finance and Chief Financial Officer

g Paul Warwick

Executive Vice-President

Europe - Atlantic

h Helen Wesley

Executive Vice-President

Corporate Services

INVESTOR RELATIONS CONTACTS

Scott Thomson

Executive Vice-President

Finance and Chief Financial Officer

p: 403.231.2786

Lyle Mcleod

Vice-President

Investor Relations

p: 403.237.1020

David Mann

Vice-President

Corporate and Investor Communications

p: 403.237.1196

EXECUTIVE OFFICE

Talisman Energy Inc.

2000, 888 - 3rd Street SW

Calgary, Alberta Canada T2P 5C5 

p: 403.237.1234

f: 403.237.1902

www.talisman-energy.com

e: tlm@talisman-energy.com

a b

d f g

c

e h
134 TALISMAN ENERGY ANNUAL REPORT 2012

MARKET INFORMATION

COMMON SHARES

The following table summarizes selected consolidated financial information for the Company for the preceding eight quarters: 

2012 2011 2010

TSX 

(C$)

NYSE 

(US$)

TSX 

(C$)

NYSE 

(US$)

TSX 

(C$)

NYSE 

(US$)

Share Price ($) High 14.57 15.00 24.44 25.11 22.25 22.25

Low 9.97 9.83 11.55 11.23 15.8 15.09

Close 11.25 11.33 12.98 12.75 22.12 22.19

Shares traded (millions) First quarter 403.00 334.91 247.42 186.81 332.76 202.01 

Second quarter 390.20 354.33 291.15 197.53 402.61 268.83 

Third Quarter 354.48 327.75 380.19 294.96 280.43 146.34 

Fourth Quarter 384.65 235.10 395.79 329.55 249.62 169.04 

Year 1,532.33 1,252.10 1,314.55 1,008.85 1,265.42 786.22 

Year-end shares outstanding (millions) 1,032 (1) 1,031(1) 1,023(1)

Year-end stock options outstanding (millions) 59.8 59.0 63.0

(1) includes shares held in trust relating to the company’s Performance Share Unit Plan. 

SHARE PRICE GROWTH (PERCENTAGE CHANGE FROM JANUARY 1, 2003)

-100

-50

0

50

100

150

200

250

300

Talisman Common Shares (TSX)

Dow Jones Industrial Average (US$)

S&P/TSX Composite Index

Dec 31

12

03 04 05 06 07 08 09 10 11
International Offices

Talisman Energy USA Inc.

50 Pennwood Place

Warrendale, Pennsylvania

USA 15086

p: +724.814.5300

f: +724.814.5301

www.talismanusa.com

Talisman Energy USA Inc.

337 Daniel Zenker Drive

Horseheads, New York

USA 14845

p: +607.562.4000

f: +607.562.4001

www.talismanusa.com

Talisman Energy USA Inc.

Talisman Energy Services Inc.

4 Waterway Square Plaza

The Woodlands, Texas

USA 77380

p: +281.210.2100

Talisman Energy USA Inc.

9320 Lakeside Blvd.

The Woodlands, Texas

USA 77381

p: +832.663.3400

Talisman Energy Norge AS

Verven 4

2000, N4014 Stavanger, Norway

p: +47.5200.2000

f: +47.5200.1500

Talisman Energy Polska sp. zo.o

Warsaw Financial Center

13th Floor, Ul. Emilli Plater 53

Warsaw, Poland

p: +48.22.370.6070

f: +48.22.370.6087

e: warsaw@talisman-energy.com

Talisman (Asia) Ltd.

Indonesia Stock Exchange Building

Tower 1, 11th Floor

JI.Jend. Sudirman Kav.

52-53 Jakarta 12190, Indonesia

p: +62.21.515.1601

f: +62.21.515.1602

Talisman Malaysia Limited

Suite 31.01, Level 33

Menara Citibank 165 Jalan Ampang, 

50450

Kuala Lumpur, Malaysia

p: +603.2162.6970

f: +603.2162.6972

Talisman SEA Pte. Ltd.

Level 14, Marina Bay Financial Centre

Tower 2

10 Marina Boulevard

Singapore 018983

p: +65.6808.1000

Talisman Vietnam Limited

Saigon Tower, Level 18 and 19

29 Le Duan Street, District 1,

Ho Chi Minh City, Vietnam

p: +848.3823.8232

f: +848.3823.8237

Talisman Australasia Pty Ltd.

Level 21, AMP Place

10 Eagle Street

Brisbane, QLD Australia 4000

Talisman International Holdings B.V.

Atrium Building

Strawinskylaan 3159

1077 ZX Amsterdam

The Netherlands

p: +31.20.540.8840

f: +31.20.540.8854

TE Holding S.à r.l.

Axento Building

Unit B., 4th Floor

3, rue Marcel Fischbach, L-1547

Luxembourg

p: +352.2876.0070

Talisman Sinopec Energy UK Limited

Talisman House

163 Holburn Street

Aberdeen, Scotland AB10 6BZ

United Kingdom

p: +1224.352.500

f: +1224.353.400

Talisman (Colombia) Oil & Gas Ltd.

Carrera 7 No. 77-07, Piso 12

Bogota, Colombia

p: +571.640.5552

f: +571.317.9293

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The inks used are environmentally friendly canola-based inks. Please recycle.

PM-3 CAA, Malaysia

Talisman Energy Inc.

Suite 2000, 888 – 3rd Street SW

Calgary, Alberta, Canada T2P 5C5

p: 403.237.1234

f: 403.237.1902

e: tlm@talisman-energy.com

FSC logo
Talisman Energy Inc.

Suite 2000, 888 – 3rd Street SW

Calgary, Alberta, Canada T2P 5C5

P 403.237.1234 F 403.237.1902

E tlm@talisman-energy.com

www.talisman-energy.com