EXHIBIT 99.1

Cameco Corporation

2016 Annual Information Form

March 23, 2017

Cameco Corporation

2016 Annual information form

March 23, 2017

Contents

Important information about this document	1
About Cameco	4
Operations and projects	17
Uranium – operating properties	18
Uranium – projects under evaluation	66
Fuel services – refining	70
Fuel services – conversion and fuel manufacturing	71
NUKEM GmbH	73
Mineral reserves and resources	74
Sustainable development	82
The regulatory environment	92
Risks that can affect our business	100
Legal proceedings	118
Investor information	119
Governance	124
Appendix A	129

- i -

Important information about this document

This annual information form (AIF) for the year ended December 31, 2016 provides important information about Cameco Corporation. It describes our history, our markets, our operations and projects, our mineral reserves and resources, sustainability, our regulatory environment, the risks we face in our business and the market for our shares, among other things.

It also incorporates by reference:
•       our management’s discussion and analysis (MD&A) for the year ended December 31, 2016 (2016 MD&A), which is available on SEDAR (sedar.com) and on EDGAR (sec.gov) as an exhibit to our Form 40-F •       our audited consolidated financial statements for the year ended December 31, 2016 (2016 financial statements), which is also available on SEDAR and on EDGAR as an exhibit to our Form 40-F.	Throughout this document, the terms we, us, our, the company and Cameco mean Cameco Corporation and its subsidiaries.

We have prepared this document to meet the requirements of Canadian securities laws, which are different from what US securities laws require.

Reporting currency and financial information

Unless we have specified otherwise, all dollar amounts are in Canadian dollars. Any references to $(US) mean United States (US) dollars.

The financial information in this AIF has been presented in accordance with International Financial Reporting Standards (IFRS).

Caution about forward-looking information

Our AIF and the documents incorporated by reference include statements and information about our expectations for the future. When we discuss our strategy, plans and future financial and operating performance, or other things that have not yet taken place, we are making statements considered to be forward-looking information or forward-looking statements under Canadian and US securities laws. We refer to them in this AIF as forward-looking information.

Key things to understand about the forward-looking information in this AIF:

• It typically includes words and phrases about the future, such as believe, estimate, anticipate, expect, plan, intend, predict, goal, target, forecast, project, scheduled, potential, strategy and proposed (see examples on page 2).

• It is based on a number of material assumptions, including those we have listed below, which may prove to be incorrect.

• Actual results and events may be significantly different from what we currently expect, because of the risks associated with our business. We list a number of these material risks below. We recommend you also review other parts of this document, including Risks that can affect our business starting on page 100, and our 2016 MD&A, which include a discussion of other material risks that could cause our actual results to differ from current expectations.

Forward-looking information is designed to help you understand management’s current views of our near and longer term prospects. It may not be appropriate for other purposes. We will not necessarily update this forward-looking information unless we are required to by securities laws.

2016 ANNUAL INFORMATION FORM    Page 1

Examples of forward-looking information in this AIF

• our expectations about 2017 and future global uranium supply, consumption, demand and number of reactors

• our expectations about 2017 and future consumption for conversion services

• the discussion of our expectations relating to our Canada Revenue Agency (CRA) and United States Internal Revenue Service (IRS) transfer pricing disputes including our estimate of the amount and timing of expected cash taxes and transfer pricing penalties

• our expectations for future tax payments and rates

• our expectations for future royalty payments

• our future plans and expectations for each of our uranium properties and fuel services sites

• our estimated timing, and receipt, of the approvals necessary for the closing of the Implementation Agreement (defined on page 55) and our expectations resulting from the closing

• our mineral reserve and resource estimates

Material risks

• actual sales volumes or market prices for any of our products or services are lower than we expect for any reason, including changes in market prices or loss of market share to a competitor

• we are adversely affected by changes in currency exchange rates, interest rates, royalty rates or tax rates

• our production costs are higher than planned, or our cost reduction strategies are unsuccessful, or necessary supplies are not available, or not available on commercially reasonable terms

• our estimates of production, purchases, costs, care and maintenance, decommissioning or reclamation expenses, or our tax expense estimates, prove to be inaccurate

• we are unable to enforce our legal rights under our existing agreements, permits or licences

• we are subject to litigation or arbitration that has an adverse outcome, including lack of success in our disputes with tax authorities or with Tokyo Electric Power Company Holdings, Inc. (TEPCO)

• we are unsuccessful in our dispute with CRA and/or the IRS and this results in significantly higher cash taxes, interest charges and penalties than the amount of our cumulative tax provision

• we are unable to utilize letters of credit to the extent anticipated in our dispute with CRA

• there are defects in, or challenges to, title to our properties

• our mineral reserve and resource estimates are not reliable, or we face challenging or unexpected geological, hydrological or mining conditions

• we are affected by environmental, safety and regulatory risks, including increased regulatory burdens or delays

• the necessary permits or approvals from government authorities are not obtained or maintained, including AREVA Resources Canada Inc.’s (AREVA) renewal of the McClean Lake mill’s operating licence and the approvals necessary for closing of the Implementation Agreement

• we are affected by political risks

• we are affected by terrorism, sabotage, blockades, civil unrest, social or political activism, accident or a deterioration in political support for, or demand for, nuclear energy

• we are impacted by changes in the regulation or public perception of the safety of nuclear power plants, which

adversely affect the construction of new plants, the relicensing of existing plants and the demand for uranium

• there are changes to government regulations or policies that adversely affect us, including tax and trade laws and policies

• our uranium suppliers fail to fulfill delivery commitments or our uranium purchasers fail to fulfill purchase commitments

• our McArthur River development, mining or production plans are delayed or do not succeed for any reason

• our Cigar Lake development, mining or production plans are delayed or do not succeed for any reason

• any difficulties in milling of Cigar Lake ore at McClean Lake

• our Inkai development, mining or production plans are delayed or do not succeed for any reason

• our expectations relating to Rabbit Lake care and maintenance costs prove to be inaccurate

• we are affected by natural phenomena, including inclement weather, fire, flood and earthquakes

• our operations are disrupted due to problems with our own or our suppliers’ or customers’ facilities, the unavailability of reagents, equipment, operating parts and supplies critical to production, equipment failure, lack of tailings capacity, labour shortages, labour relations issues, strikes or lockouts, underground floods, cave-ins, ground movements, tailings dam failures, transportation disruptions or accidents, unanticipated consequences of our cost reduction strategies, or other development and operating risks

2016 ANNUAL INFORMATION FORM    Page 2

Material assumptions

• our expectations regarding sales and purchase volumes and prices for uranium and fuel services, and that the counterparties to our sales and purchase agreements will honour their commitments

• our expectations regarding the demand for, and supply of, uranium, the pressure for a return to long-term contracting, the construction of new nuclear power plants and the relicensing of existing nuclear power plants not being more adversely affected than expected by changes in regulation or in the public perception of the safety of nuclear power plants

• our expected production levels and production costs, including our expectations regarding the success of our cost reduction strategies

• the assumptions regarding market conditions and other factors upon which we have based our capital expenditures expectations

• our expectations regarding spot prices and realized prices for uranium

• our expectations regarding tax rates and payments, royalty rates, currency exchange rates and interest rates

• our expectations about the outcome of disputes with tax authorities and with TEPCO

• we are able to utilize letters of credit to the extent anticipated in our dispute with CRA

• our decommissioning and reclamation expenses

• our mineral reserve and resource estimates, and the assumptions upon which they are based, are reliable

• our understanding of the geological, hydrological and other conditions at our mines

• our McArthur River development, mining and production plans succeed

• our Cigar Lake development, mining and production plans succeed

• the McClean Lake mill is able to process Cigar Lake ore as expected

• that annual Rabbit Lake care and maintenance costs will be as expected

• our Inkai development, mining and production plans succeed

• our ability to continue to supply our products and services in the expected quantities and at the expected times

• our, and our contractors’, ability to comply with current and future environmental, safety and other regulatory requirements, and to obtain and maintain required regulatory approvals, including AREVA’s renewal of the McClean Lake mill’s operating licence and approvals necessary to close the Implementation Agreement

• our operations are not significantly disrupted as a result of political instability, nationalization, terrorism, sabotage, blockades, civil unrest, social or political activism, breakdown, natural disasters, governmental or political actions, litigation or arbitration proceedings, the unavailability of reagents, equipment, operating parts and supplies critical to production, equipment failure, labour shortages, labour relations issues , strikes or lockouts, underground floods, cave-ins, ground movements, tailings dam failures, lack of tailings capacity, transportation disruptions or accidents, unanticipated consequences of our cost reduction strategies, or other development or operating risks

2016 ANNUAL INFORMATION FORM    Page 3

About Cameco

Our head office is in Saskatoon, Saskatchewan. We are one of the world’s largest uranium producers, with uranium assets on three continents. Nuclear energy plants around the world use our uranium products to generate one of the cleanest sources of electricity available today.

Strategy

Our strategy remains focused on taking advantage of the long-term growth we see coming in our industry, while maintaining the ability to respond to market conditions as they evolve. You can find more information about our strategy at page 8 and in our 2016 MD&A. Cameco Corporation 2121 – 11^th Street West Saskatoon, Saskatchewan Canada S7M 1J3 Telephone: 306.956.6200   This is our head office, registered office and principal place of business.   We are publicly listed on the Toronto and New York stock exchanges, and had a total of 3,580 employees at December 31, 2016.

Business segments

URANIUM

We are one of the world’s largest uranium producers, and in 2016 accounted for about 17% of the world’s production. We have controlling ownership of the world’s largest high-grade reserves, with ore grades up to 100 times the world average, and low-cost operations.

Product

• uranium concentrates (U₃O₈)

Mineral reserves and resources

Mineral reserves

• approximately 415 million pounds proven and probable

Mineral resources

• approximately 487 million pounds measured and indicated

• approximately 248 million pounds inferred

Operating properties

• McArthur River and Key Lake, Saskatchewan

• Cigar Lake, Saskatchewan

• Inkai, Kazakhstan

Curtailed properties

• Rabbit Lake, Saskatchewan

• Smith Ranch-Highland, Wyoming

• Crow Butte, Nebraska

Projects under evaluation

• Millennium, Saskatchewan

• Yeelirrie, Australia

• Kintyre, Australia

Global exploration

• focused on three continents

• approximately 1.5 million hectares of land

2016 ANNUAL INFORMATION FORM    Page 4

FUEL SERVICES

We are an integrated uranium fuel supplier, offering refining, conversion and fuel manufacturing services.

Products

• uranium trioxide (UO₃)

• uranium hexafluoride (UF₆)

(account for about 25% of world conversion capacity)

• uranium dioxide (UO₂)

• fuel bundles, reactor components and monitoring equipment used by CANDU reactors

Operations

• Blind River refinery, Ontario

(refines uranium concentrates to UO₃)

• Port Hope conversion facility, Ontario

(converts UO₃ to UF₆ or UO₂)

• Cameco Fuel Manufacturing Inc. (CFM), Ontario (manufactures fuel bundles and reactor components)

NUKEM

Our ownership of NUKEM GmbH (NUKEM) provides us with access to one of the world’s leading traders of uranium and uranium-related products.

Activity

• physical trading uranium concentrates, conversion and enrichment services

• recovery of natural and enriched non-standard uranium from western facilities and other sources

For information about our revenue and gross profit by business segment for the years ended December 31, 2016 and 2015, see our 2016 MD&A as follows:

• uranium – page 42

• fuel services – page 44

• NUKEM – page 44.

Other fuel cycle investments

ENRICHMENT

GE-Hitachi Global Laser Enrichment (GLE) is testing a third-generation technology that, if successful, will use lasers to commercially enrich uranium. We have a 24% interest in GLE, which is currently undergoing restructuring. Existing partners General Electric (51%) and Hitachi Ltd. (25%) have negotiated an arrangement providing Silex Systems Ltd. (the technology’s licensor), with an exclusive option on their interests.

2016 ANNUAL INFORMATION FORM    Page 5

The nuclear fuel cycle

Our operations and investments span the nuclear fuel cycle, from exploration to fuel manufacturing.

1 Mining

Once an orebody is discovered and defined by exploration, there are three common ways to mine uranium, depending on the depth of the orebody and the deposit’s geological characteristics:

• Open pit mining is used if the ore is near the surface. The ore is usually mined using drilling and blasting.

• Underground mining is used if the ore is too deep to make open pit mining economical. Tunnels and shafts provide access to the ore.

• In situ recovery (ISR) does not require large scale excavation. Instead, holes are drilled into the ore and a solution is used to dissolve the uranium. The solution is pumped to the surface where the uranium is recovered.

1 Milling

Ore from open pit and underground mines is processed to extract the uranium and package it as a powder typically referred to as uranium concentrates (U₃O₈) or yellowcake. The leftover processed rock and other solid waste (tailings) is placed in an engineered tailings facility.

2 Refining

Refining removes the impurities from the uranium concentrate and changes its chemical form to uranium trioxide (UO₃).

3 Conversion

For light water reactors, the UO₃ is converted to uranium hexafluoride (UF₆) gas to prepare it for enrichment. For heavy water reactors like the CANDU reactor, the UO₃ is converted into powdered uranium dioxide (UO₂).

4 Enrichment

Uranium is made up of two main isotopes: U-238 and U-235. Only U-235 atoms, which make up 0.7% of natural uranium, are involved in the nuclear reaction (fission). Most of the world’s commercial nuclear reactors require uranium that has an enriched level of U-235 atoms.

The enrichment process increases the concentration of U-235 to between 3% and 5% by separating U-235 atoms from the U-238. Enriched UF₆ gas is then converted to powdered UO₂.

5 Fuel manufacturing

Natural or enriched UO₂ is pressed into pellets, which are baked at a high temperature. These are packed into zircaloy or stainless steel tubes, sealed and then assembled into fuel bundles.

6 Generation

Nuclear reactors are used to generate electricity. U-235 atoms in the reactor fuel fission, creating heat that generates steam to drive turbines. The fuel bundles in the reactor need to be replaced as the U-235 atoms are depleted, typically after one or two years depending upon the reactor type. The used – or spent – fuel is stored or reprocessed.

Spent fuel management

The majority of spent fuel is safely stored at the reactor site. A small amount of spent fuel is reprocessed. The reprocessed fuel is used in some European and Japanese reactors.

2016 ANNUAL INFORMATION FORM    Page 6

Major developments

2014

January

• We enter into an agreement to sell our 31.6% limited partnership interest in BPLP to BPC Generation Infrastructure Trust, one of the limited partners in Bruce Power Limited Partnership (BPLP).

March

• We complete the sale of our 31.6% limited partnership interest in BPLP to BPC Generation Infrastructure Trust.

• We begin ore production at Cigar Lake.

June

• We issue $500 million of 4.19% unsecured debentures due in 2024.

July

• We redeem $300 million of unsecured debentures due in 2015.

September

• We enter into a four-year collective agreement with approximately 535 unionized employees at our McArthur River/Key Lake operations.

October

• McClean Lake mill starts producing uranium concentrates from ore mined at Cigar Lake.

2015

May

• We begin commercial production at Cigar Lake.

June

• We enter into a three-year collective agreement with approximately 100 unionized employees at our fuel manufacturing operations in Port Hope and Cobourg, Ontario.

2016

April

• We suspend production at our Rabbit Lake operation and curtail production at Cameco Resources’ US operations.

May

We enter into an agreement with Joint Stock Company National Atomic Company Kazatomprom (Kazatomprom) and Joint Venture Inkai LLP (JV Inkai) to restructure and enhance Inkai, subject to acquiring necessary government approvals.

July

• We enter into a three-year collective agreement with approximately 230 unionized employees at our Port Hope conversion facility.

August

• Transition to care and maintenance at our Rabbit Lake operation was completed.

2017 Major developments

On January 17, 2017, we announced planned additional activities for 2017, intended to further reduce costs and improve operational efficiency at our uranium mining operations. The workforce at McArthur River, Key Lake and Cigar Lake is expected to be reduced by 10% or 120 employees in total. Cameco also plans to implement changes to the air commuter service by which employees and contract workers get to and from mine and mill sites in northern Saskatchewan, as well as work schedule changes to achieve additional cost savings.

On January 31, 2017, TEPCO confirmed that it would not accept a uranium delivery scheduled for February 1, 2017, and would not withdraw the contract termination notice it provided to Cameco Inc. on January 24, 2017 with respect to a uranium supply agreement between TEPCO and Cameco Inc. TEPCO alleged that an event of force majeure has occurred because it has been unable to operate its nuclear reactors for 18 consecutive months due to the Fukushima nuclear accident in March 2011 and the resulting government regulations. Cameco Inc. sees no basis for terminating the agreement and will pursue all its legal rights and remedies against TEPCO.

Under the agreement, TEPCO has already received and paid for 2.2 million pounds of uranium since 2014. The termination would affect approximately 9.3 million pounds of uranium deliveries through 2028, worth approximately $1.3 billion in revenue to Cameco, including about $126 million in each of 2017, 2018 and 2019 based on 855,000 pounds of deliveries in each of those years. All estimates and uranium volumes are provided on a consolidated basis for Cameco using expected contract prices and an exchange rate of $1.00 (US) for $1.30 (Cdn) and do not reflect any resale of the cancelled deliveries under the contract with TEPCO.

In May 2016, Cameco, Kazatomprom and JV Inkai signed an Implementation Agreement to restructure and enhance Inkai. The Implementation Agreement is subject to obtaining all required government approvals, including certain amendments to JV Inkai’s resource use contract. In February 2017, we estimated it would take 10 to 18 months to obtain the required approvals. For additional information about the Implementation Agreement, see page 55.

2016 ANNUAL INFORMATION FORM    Page 7

How Cameco was formed

Cameco Corporation was incorporated under the Canada Business Corporations Act on June 19, 1987.

We were formed when two crown corporations were privatized and their assets merged:

• Saskatchewan Mining Development Corporation (uranium mining and milling operations)

• Eldorado Nuclear Limited (uranium mining, refining and conversion operations) (now Canada Eldor Inc.).

There are constraints and restrictions on ownership of shares in the capital of Cameco (Cameco shares) set out in our company articles, and a related requirement to maintain offices in Saskatchewan. These are requirements of the Eldorado Nuclear Limited Reorganization and Divestiture Act (Canada), as amended, and The Saskatchewan Mining Development Corporation Reorganization Act, as amended, and are described on pages 120 and 121.

We have made the following amendments to our articles:

2002	•       increased the maximum share ownership for individual non-residents to 15% from 5% •       increased the limit on voting rights of non-residents to 25% from 20%
2003	•       allowed the board to appoint new directors between shareholder meetings as permitted by the Canada Business Corporations Act, subject to certain limitations •       eliminated the requirement for the chairman of the board to be ordinarily resident in the province of Saskatchewan

We have three main subsidiaries:

• Cameco Europe Ltd., a Swiss company we have 100% ownership of through subsidiaries

• NUKEM Investments GmbH, a German company we have 100% ownership of through subsidiaries

• JV Inkai, a limited liability partnership in Kazakhstan, which we own a 60% interest in.

At December 31, 2016, we do not have any other subsidiaries that are material, either individually or collectively.

For more information

You can find more information about Cameco on SEDAR (sedar.com), EDGAR (sec.gov) and on our website (cameco.com/investors).

See our most recent management proxy circular for additional information, including how our directors and officers are compensated and any loans to them, principal holders of our securities, and securities authorized for issue under our equity compensation plans. We expect the circular for our May 2017 annual meeting of shareholders to be available in April 2017.

See our 2016 financial statements and 2016 MD&A for additional financial information.

Our strategy

Tier-one focus

Our strategy is set within the context of a challenging market environment, which we expect to give way to strong long-term fundamentals driven by increasing population and electricity demand.

We are a pure-play nuclear fuel supplier, focused on taking advantage of the long-term growth we see coming in our industry, while maintaining the ability to respond to market conditions as they evolve. Our strategy is to focus on our tier-one assets and profitably produce at a pace aligned with market signals in order to increase long-term shareholder value, and to do that with an emphasis on safety, people and the environment. Uranium production is central to our strategy, as it is the biggest value driver of the nuclear fuel cycle and our business.

For more information on our strategy, see our annual MD&A.

2016 ANNUAL INFORMATION FORM    Page 8

Market overview and 2016 developments

Cautiously optimistic

Today’s uranium market is challenging, but we are cautiously optimistic that we are starting to see some of the signposts required for a market recovery. The future uncovered uranium requirements of utilities due to low levels of long-term contracting over the past four years are increasing. There have been several announcements on both the supply and demand side that are expected to have a positive impact on the challenging market, and there is renewed interest in nuclear power and uranium from non-traditional market participants. However, we believe it will ultimately be the return of term contracting in a significant way that will signal that market dynamics have turned more positive.

TODAY: A STORY OF OVERSUPPLY

The uranium market continues to be in a state of oversupply. Market recovery has taken longer than anticipated as a result of a slower than expected pace of reactor restarts in Japan, unexpected reactor shutdowns in other regions, delays in reactor construction programs, and reactors under construction but not yet consuming uranium. At the same time, supply has continued to perform well, adding to the delay in market improvement.

On the supply side, secondary supplies, consisting largely of government inventories and enricher underfeeding, continue to provide the industry with an exceptionally low-cost source of uranium supply, where the economics differ considerably from mined production. Similarly, several producers, whose production drivers are not always economic, such as large diversified miners and companies mining uranium for strategic or social purposes, negatively impact the supply-demand balance. The lowest cost – tier-one – production, including our own assets, continues to perform well, with cash costs that allow them to remain economic, even at current prices. Finally, higher-cost production, though sensitive to the uranium price, continues to be supported by higher prices under long-term contracts and/or advantageous foreign exchange rates.

The excess supply has impacted the market in a significant way. Abundant spot material has been available to satisfy utilities’ appetite for low-priced pounds to meet near- to mid-term requirements. As a result, strategic inventories have grown across the industry and the need to sign significant long-term contracts has been deferred.

These industry dynamics make it difficult to predict the timing of a market recovery. However, given that Ux Consulting Company, LLC (UxC) has reported that over the last four years only 245 million pounds have been locked-up in the long-term market, while over 635 million pounds have been consumed in reactors, we remain confident that utilities have a growing gap to fill. As annual supply adjusts and utilities’ uncovered requirements grow, we believe the pounds available in the spot market won’t be enough to satisfy the demand.

OPPORTUNITIES FOR THOSE WHO CAN WAIT

Like other commodities, the uranium industry is cyclical and the low level of contracting at low prices that we’re seeing today is not new. When prices are low, there is no urgency to contract. The heavy contracting that took place during the previous price run, which drove investment in higher-cost sources of production, contributes to the perception that uranium is abundant and

2016 ANNUAL INFORMATION FORM    Page 9

always will be. History demonstrates that the opposite tends to occur when prices rise. After years of low investment in supply, as has been the case so far this decade, security of supply tends to overtake price concerns at some point, and utilities re-enter the long-term market to ensure they have the reliable supply of uranium they need to run their reactors.

The backlog of future contracting needs created by the low-price environment presents a substantial opportunity for suppliers like us that can weather the low-price part of the cycle. As a low-cost producer, we plan our business with these price cycles in mind.

In our industry, customers do not come to the market right before they need to load uranium into their reactors. To operate a reactor that could run for more than 60 years, natural uranium and the downstream services have to be purchased years in advance, allowing time for a number of processing steps before it arrives at the power plant as a finished fuel bundle. At present, we believe there is a significant amount of uranium that needs to be contracted to keep reactors running into the next decade.

Estimates by industry consultants show cumulative uncovered requirements to be about 800 million pounds over the next nine years. While uncovered requirements do not ramp up significantly in the near-term, the longer the delay in the recovery of the long-term market, the less certainty there is around the availability of future supply to fill growing demand. Ultimately, we expect the current price-sensitive sentiment to give way to increasing concerns about the security of future supply.

SUPPLY IS NOT GUARANTEED

Economic difficulties are beginning to take a toll on the supply side. Producers who have been protected from the low market prices under long-term contracts, are beginning to emerge from that protection. As a result, it is not just future supply that is at risk – we are seeing evidence that even existing supply is at risk:

• most recently, Kazatomprom announced its intention to reduce 2017 output from Kazakhstan by 10%, citing market challenges due to the current oversupply situation

• Paladin has announced reduced production from their 75% owned Langer Heinrich mine and modification of the mine plan to reduce costs

• in the conversion space, Honeywell is making permanent adjustments to its operation and lowering nameplate capacity of its facility from 15 million kgU to 7 million kgU as UF₆

• some enrichers are retiring centrifuge capacity, reducing the excess capacity in the enrichment space that is contributing to broader oversupply via underfeeding and tails re-enrichment

• we have suspended and curtailed three operations in addition to taking cost-cutting measures that carry additional supply risk.

Coupled with looming uncovered requirements, we expect the risks to future and existing supply could decrease the availability of spot material and increase the pressure for a return to long-term contracting.

2016 ANNUAL INFORMATION FORM    Page 10

DEMAND SIDE CHALLENGES

There was mixed news for the broader nuclear industry in 2016. On a regional demand basis, there were significant positive and negative developments:

• China struggled with a lower economic growth forecast and excess capacity in the energy sector, although the country remains committed to a fast-paced and growing nuclear power program

• in Japan, a total of 10 reactors now meet the new regulatory standards; however, the pace of restarts continues to be slow

• India made strides in agreements with western nuclear vendors, including engineering and design work, and finalizing contractual arrangements, but the industry continues to face delays in achieving significant progress in nuclear power development

• Russia saw domestic challenges due to weaker demand for electricity, but continues to pursue an aggressive reactor export strategy

• US operators announced additional early reactor closures, but policy developments in some states targeted support for keeping at-risk reactors profitable

• A number of additional reactors remain under threat of early closure subject to political and energy policy support

• It remains to be seen what impact the new US administration will have on the success of their reactor program

• in the United Arab Emirates, construction of four units is proceeding smoothly, with the startup of the first unit expected in 2017, but continued growth remains uncertain

• the United Kingdom approved construction of Hinkley Point C, but the rest of Europe is expecting little to no growth in nuclear power in the next 10 years

• advances were also made in the potential growth of some other existing nuclear programs (South Korea, South Africa) and new nuclear programs (Bangladesh), while steps in the opposite direction occurred in other jurisdictions (Vietnam and Taiwan)

• in Canada, the Province of Ontario has shown a strong commitment to nuclear power for nearly 50 years, but continued support is subject to a successful refurbishment program

• several units in France’s nuclear fleet were taken offline due to regulatory reviews linked to technical issues, though some have been cleared for restart. France is also showing signs of reversing a previously announced intention to reduce reliance on nuclear power.

While 2016 offered some welcome progress in bringing supply and demand closer to equilibrium, uncertainty persists.

WHAT HAS TO CHANGE?

Ultimately, the industry needs to fill the demand gap left by forced and premature shut-downs since March of 2011 by continuing to safely bring reactors online. This means Japanese restarts, successful commissioning of new reactors under construction, and continued development of new construction plans. And we’re seeing positive progress on all fronts:

• Japanese utilities have now successfully navigated through the new, rigorous safety inspection process

• 58 reactors are currently under construction around the world, the majority of which are expected to come online in the next three years

• the growth in nuclear power generation is real, with 10 new reactors connected to the grid in 2016

2016 ANNUAL INFORMATION FORM    Page 11

Global population is on the rise, and with the world’s need for safe, clean, reliable baseload energy, nuclear remains an important part of the mix. We remain confident in the future of the nuclear industry, while at the same time recognizing that uncertainty persists.

With demand coming on in the form of restarts and new reactors, and supply falling on curtailments and lack of investment, we are continuing to expect a market shift. Until that time, we will continue to take the actions we believe are necessary to position the company for long-term success. Therefore, we will undertake contracting activity which aligns with the uncertain timing of a market recovery intended to ensure we have adequate protection under our contract portfolio, while maintaining exposure to the rewards that come from having uncommitted, low-cost supply to deliver into a strengthening market.

Marketing strategy – balanced contract portfolio

The purpose of our marketing strategy is to deliver value. Our approach is to secure a solid base of earnings and cash flow by maintaining a balanced contract portfolio that optimizes our realized price.

Uranium is not traded in meaningful quantities on a commodity exchange. Utilities have historically bought the majority of their uranium and fuel services products under long-term contracts with suppliers, and have met the rest of their needs on the spot market. We sell uranium and fuel services directly to nuclear utilities around the world as uranium concentrates, UO₂ and UF₆, conversion services, or fuel fabrication. This includes utilities in Belgium, Canada, China, Finland, France, Germany, India, Japan, Romania, South Korea, Spain, Sweden, Taiwan, and the US. We are a supplier of UO₂ to CANDU reactors operated in Canada and other countries. We have a solid portfolio of long-term sales contracts that reflect the long-term, trusting relationships we have with our customers.

In addition, we are active in the spot market, buying and selling uranium when it is beneficial for us. Our NUKEM business segment enhances our ability to participate in the market, as they are one of the world’s leading traders of uranium and uranium-related products. We undertake activity in the spot market prudently, looking at the spot price and other business factors to decide whether it is appropriate to purchase or sell into the spot market. Not only is this activity a source of profit, it gives us insight into underlying market fundamentals. We have also bought uranium under long term contracts and may also do so again in the future. At February 1, 2017, we had firm commitments to buy about 21 million pounds of uranium equivalent from 2017 to 2028.

The demand for uranium is directly linked to the level of electricity generated by nuclear power plants. As the number of reactors grows, so too does the demand for uranium and conversion services.

The demand for UO₂ conversion services is linked to the level of electricity generated by heavy water moderated nuclear power plants such as CANDU reactors.

LONG-TERM CONTRACTING

We deliver large volumes of uranium every year, therefore our net earnings and operating cash flows are affected by changes in the uranium price. Market prices are influenced by the fundamentals of supply and demand, geopolitical events, disruptions in planned supply and demand, and other market factors.

2016 ANNUAL INFORMATION FORM    Page 12

The objective of our contracting strategy is to:

• maximize realized price while reducing volatility of our future earnings and cash flow

• focus on meeting the nuclear industry’s growing uncovered requirements with our future uncommitted supply while ensuring adequate regional diversity

• establish and grow market share with strategic customers.

We target a ratio of 40% fixed-pricing and 60% market-related pricing in our portfolio of long-term contracts, including mechanisms to protect us when the market price is declining and allow us to benefit when market prices go up. This is a balanced and flexible approach that allows us to adapt to market conditions and put a floor on our average realized price, and deliver the best value to shareholders over the long term.

This strategy has allowed us to realize prices higher than the market prices during periods of weak uranium demand, and we expect it will enable us to realize increases linked to higher market prices in the future.

Fixed-price contracts: are typically based on the industry long-term price indicator at the time the contract is accepted and escalated over the term of the contract.

Market-related contracts: are different from fixed-price contracts in that they may be based on either the spot price or the long-term price, and that price is as quoted at the time of delivery rather than at the time the contract is accepted. These contracts sometimes provide for discounts, and often include floor prices and/or ceiling prices, all of which are escalated over the term of the contract.

Fuel services contracts: the majority of our fuel services contracts are at a fixed price per kgU, escalated over the term of the contract, and reflect the market at the time the contract is accepted.

OPTIMIZING THE CONTRACT PORTFOLIO

In today’s weak market environment, we have been working with certain customers to optimize the value of our existing contract portfolio. In cases where a customer is seeking relief due to a challenging policy, operating, or economic environment, we evaluate their specific circumstances and assess their long-term sustainability. Where we deem the customer’s long-term demand to be at risk, we may consider options that allow us to benefit from converting that uncertain future value into certain present value. In contrast, where the customer is considered to have a more certain and predictable future, we may offer relief, for example by blending in more market-related volumes in the near term, but only where the customer is willing to extend the terms and conditions of that contract out into the future, and only where it is beneficial to us.

CUSTOMER’S FUTURE OPERATING ENVIRONMENT
UNCERTAIN		OPTIMISTIC
Changing	Policy	Clear pathways
Challenges	Regulatory	Established
Unregulated	Economic	Benefits recognized
Future uncertainty for present certain value	Resulting trade-off considerations	Relief where it is beneficial for us

CONTRACT PORTFOLIO STATUS

Currently, our production is heavily committed under long-term uranium contracts through 2019, so we are being selective when considering new commitments and working to achieve our contracting objectives. We have commitments to sell approximately 150 million pounds of U₃O₈ with 40 customers worldwide in our uranium segment, and over 50 million kilograms as UF₆ conversion with 31 customers worldwide in our fuel services segment.

2016 ANNUAL INFORMATION FORM    Page 13

Customers – U₃O₈:

Five largest customers account for 52% of commitments

COMMITTED U₃O₈ SALES BY REGION

Customers – UF₆ conversion:

Five largest customers account for 56% of commitments

COMMITTED UF₆ SALES BY REGION

NUKEM

We acquired NUKEM in January 2013. NUKEM has access to contracted volumes and inventories in diverse geographic locations as well as scope for opportunistic trading of uranium and uranium products. This enables NUKEM to provide a wide range of solutions to its customers that may fall outside the scope of typical uranium sourcing and selling arrangements. Its trading strategy is non-speculative and seeks to match quantities and pricing structures under its long-term supply and delivery contracts, minimizing exposure to uranium related price fluctuations and locking in profits.

NUKEM’s main customers are commercial nuclear power plants using enriched uranium fuel, typically large utilities that are either government-owned or large-scale utilities with multi-billion dollar market capitalization and strong credit ratings. NUKEM also trades with converters, enrichers, other traders and investors. NUKEM is active in the spot market on an ongoing basis, but also has some uranium and uranium-related products under contract until 2022.

MANAGING OUR CONTRACT COMMITMENTS

To meet our delivery commitments, we use our uranium supply, which includes uranium obtained from:

• our existing production

• purchases under long-term agreements and in the spot market

• our existing inventory.

We allow sales volumes to vary year-to-year depending on:

• the level of sales commitments in our long-term contract portfolio (the annual average sales commitments over the next five years in our uranium segment is 24 million pounds, with commitment levels through 2019 higher than in 2020 and 2021)

• our production volumes

2016 ANNUAL INFORMATION FORM    Page 14

• purchases under existing and/or new arrangements

• discretionary use of inventories

• market opportunities.

Supply Sources

Uranium supply sources include primary production (production from mines that are currently in commercial operation) and secondary supply sources (excess inventories, uranium made available from defense stockpiles and the decommissioning of nuclear weapons, re-enriched depleted uranium tails, and used reactor fuel that has been reprocessed).

Primary production

While the uranium production industry is international in scope, there are only a small number of companies operating in relatively few countries. In addition, there are barriers to entry and bringing on and ramping up production can take between seven and 10 years. A number of new projects have been cancelled or delayed, and some existing production has been discontinued due to the low uranium prices that have persisted since the 2011 events at the Fukushima-Daiichi nuclear power plant in Japan. Today’s uranium prices are not high enough to incent new mine production and not high enough to keep some current mines in operation.

We estimate world mine production in 2016 was about 163 million pounds U₃O₈, up from 157 million pounds in 2015:

• almost 80% of estimated world production came from four countries: Kazakhstan (39%), Canada (22%), Australia (10%) and Niger (7%)

• over 60% of estimated world production was marketed by four producers. We marketed about 17% (27 million pounds) of estimated world production.

Secondary sources

There are a number of secondary sources, but most of these sources are finite and will not meet long-term needs:

• The US government makes some of its inventories available to the market, although in smaller quantities.

• Utilities, mostly in Europe and some in Japan and Russia, use reprocessed uranium and plutonium from used reactor fuel.

• Re-enriched depleted uranium tails and uranium from underfeeding are also generated using excess enrichment capacity.

Trade restraints and policies

The importation of Russian uranium into the US market is regulated by the amended USEC Privatization Act and by the Agreement Suspending the Antidumping Action against Russian Uranium Products, which together impose annual quotas of approximately 12-13 million pounds U₃O₈ equivalent on imports of Russian uranium. These quotas were set at the equivalent of 20% of annual US reactor demand and are scheduled to expire at the end of 2020.

The US restrictions do not affect the sale of Russian uranium to other countries. About 70% of world uranium demand is from utilities in countries that are not affected by the US restrictions. Utilities in some countries, however, adopt policies that limit the amount of Russian uranium they will buy. The Euratom Supply Agency in Europe must approve all uranium related contracts for members of the EU, and limits the use of certain nuclear fuel supplies from any one source to maintain security of supply, although these limits do not apply to uranium sold separately from enriched uranium product.

Uranium from US inventories

We estimate that the US Department of Energy (DOE) has an excess uranium inventory of roughly 100 million pounds U₃O₈ equivalent. We expect a sizeable portion of this uranium will be available to the market over the next two decades, although a significant portion of the inventory requires either further processing or the development of commercial arrangements before it can be brought to market.

DOE Excess Uranium Inventory Management Plan

In March 2008, the DOE issued a policy statement and a general framework for managing this inventory, including the need to dispose of it without disrupting the commercial markets. It was updated in 2013 and is scheduled to be updated again in 2018. Under the 2013 Excess Uranium Inventory Management Plan, the DOE increased the allowable amount of material disposed of in a year to equal 15% or less of annual US nuclear fuel requirements. DOE sales are governed by Secretarial Determinations (issued every 2 years), which require that any such sales not have a material adverse impact on the US uranium, conversion and enrichment industries. The most recent Secretarial Determination was issued on May 1, 2015.

2016 ANNUAL INFORMATION FORM    Page 15

US Congressional Legislation

On May 21, 2015, the Excess Uranium Transparency and Accountability Act was introduced into the House and Senate. The purpose of the bipartisan bill is to restrict the DOE’s inventory sales under a codified structure. The bill has an annual cap on DOE’s uranium transfers of 2,100 MTU (5.5 million pounds U₃O₈) for calendar years 2016 through 2023 and 2,700 MTU (7.1 million pounds U₃O₈) for calendar years 2024 and each year thereafter. The limit includes uranium in all forms. If new legislation is introduced, the limit could be amended.

Conversion services

We account for about 25% of world UF₆ conversion capacity and are a supplier of UO₂ for Canadian-made CANDU reactors. For conversion services, we compete with three other primary commercial suppliers, in addition to the secondary supplies described above, to meet global demand.

2016 ANNUAL INFORMATION FORM    Page 16

Operations and projects

Uranium

Operating properties
McArthur River/Key Lake	18
Cigar Lake	33
Inkai	48
Curtailed properties
Rabbit Lake	63
Smith Ranch-Highland	64
Crow Butte	65
Projects under evaluation
Millennium	66
Yeelirrie	67
Kintyre	68
Exploration	69

Fuel services

Refining
Blind River refinery	70
Conversion and fuel manufacturing
Port Hope conversion services	71
Cameco Fuel Manufacturing Inc.	71

NUKEM

NUKEM GmbH 73

Uranium production

Cameco’s share (million lbs U3O8)	2015		2016		2017 Plan
McArthur River/Key Lake		13.3		12.6		12.6
Cigar Lake		5.7		8.7		9.0
Inkai		3.4		3.4		3.1
Rabbit Lake		4.2		1.1		0.0
Smith Ranch-Highland		1.4		0.9		0.4
Crow Butte		0.4		0.3		0.1
Total		28.4		27.0		25.2

2016 ANNUAL INFORMATION FORM    Page 17

Uranium – operating properties

McArthur River/Key Lake   McArthur River is the world’s largest high-grade uranium mine, and Key Lake is the largest uranium mill in the world.   Ore grades at the McArthur River mine are 100 times the world average, which means it can produce more than 18 million pounds per year by mining only 150 to 200 tonnes of ore per day. We are the operator of both the mine and mill.   McArthur River is one of our three material uranium properties.

Location	Saskatchewan, Canada
Ownership	69.805% - McArthur River 83.33% - Key Lake
End product	uranium concentrate
ISO certification	ISO 14001 certified
Mine type	underground
Estimated mineral reserves (our share)	258.1 million pounds (proven and probable), average grade U3O8 – 9.60%
Estimated mineral resources1 (our share)	3.4 million pounds (measured and indicated), average grade U3O8 – 3.65% 7.7 million pounds (inferred), average grade U3O8 – 5.20%
Mining methods	primary: raiseboring, blasthole stoping secondary: boxhole boring
Licensed capacity	mine and mill: 25 million pounds per year
Total packaged production
2000 to 2016	309.1 million pounds (McArthur River/Key Lake) (100% basis)
1983 to 2002	209.8 million pounds (Key Lake) (100% basis)
2016 production	12.6 million pounds (18.0 million pounds on 100% basis)
2017 production outlook	12.6 million pounds (18.0 million pounds on 100% basis)
Estimated mine life	2037 (based on current mineral reserves)
Estimated decommissioning cost	$48 million – McArthur River
(100% basis)	$218 million – Key Lake

¹ Mineral resources that are not mineral reserves have no demonstrated economic viability.

Business structure

McArthur River is owned by a joint venture (MRJV) between two companies:	Key Lake is owned by a joint venture between the same two companies:
•       Cameco – 69.805%	•       Cameco –83 1⁄3%
•       AREVA – 30.195%	•       AREVA – 16 2⁄3%

2016 ANNUAL INFORMATION FORM    Page 18

History

1976	•       Canadian Kelvin Resources Ltd. and Asamera Oil Corporation Ltd. form an exploration joint venture, which includes the lands that the McArthur River mine is situated on
1977	•       Saskatchewan Mining Development Corporation (SMDC), one of our predecessor companies, acquires a 50% interest
1980	•       McArthur River joint venture is formed •       SMDC becomes the operator •       Active surface exploration begins •       Between 1980 and 1988 SMDC reduces its interest to 43.991%
1988	•       Eldorado Resources Limited merges with SMDC to form Cameco •       We become the operator •       Deposit discovered by surface drilling
1988-1992	•       Surface drilling reveals significant mineralization of potentially economic uranium grades, in a 1,700 metre zone at between 500 to 640 metres
1992	•       We increase our interest to 53.991%
1993	•       Underground exploration program receives government approval – program consists of shaft sinking (completed in 1994) and underground development and drilling
1995	•       We increase our interest to 55.844%
1997-1998	•       Federal authorities issue construction licences for McArthur River after reviewing the environmental impact statement, holding public hearings, and receiving approvals from the governments of Canada and Saskatchewan
1998	•       We acquire all of the shares of Uranerz Exploration and Mining Ltd. (UEM), increasing our interest to 83.766% •       We sell half of the shares of UEM to AREVA, reducing our interest to 69.805%, and increasing AREVA’s to 30.195%
1999	•       Federal authorities issue the operating licence and provincial authorities give operating approval, and mining begins in December
2003	•       Production is temporarily suspended in April because of a water inflow •       Mining resumes in July
2009	•       UEM distributes equally to its shareholders: •       its 27.922% interest in the McArthur River joint venture, giving us a 69.805% direct interest, and AREVA a 30.195% direct interest •       its 33 1⁄3% interest in the Key Lake joint venture, giving us an 83 1⁄3% direct interest, and AREVA a 16 2⁄3% direct interest
2013	•       Federal authorities granted a 10-year renewal of the McArthur River and Key Lake operating licences
2014	•       After a two-week labour disruption, we enter into a four-year collective agreement with unionized employees at McArthur River and Key Lake operations

2016 ANNUAL INFORMATION FORM    Page 19

Technical report

This project description is based on the project’s technical report: McArthur River Operation, Northern Saskatchewan, Canada, dated November 2, 2012 (effective August 31, 2012) except for some updates that reflect developments since the technical report was published. The report was prepared for us in accordance with Canadian National Instrument 43-101 – Standards of Disclosure for Mineral Projects (NI 43-101), by or under the supervision of David Bronkhorst, P. Eng., Alain G. Mainville, P. Geo., Gregory M. Murdock, P. Eng., and Leslie D. Yesnik, P. Eng.; four qualified persons within the meaning of NI 43-101. The following description has been prepared under the supervision of Alain G. Mainville, P. Geo., Gregory M. Murdock, P. Eng., Thomas Saruchera, P. Eng., Baoyao Tang, P. Eng., and Leslie D. Yesnik, P. Eng. They are all qualified persons within the meaning of NI 43-101, but are not independent of us. For information about uranium sales see pages 12 to 15, environmental matters see Safety, Health and Environment starting on page 84, and taxes see page 98.   For a description of royalties payable to the province of Saskatchewan on the sale of uranium extracted from orebodies within the province, see page 98.   For a description of risks that might affect access, title or the right or ability to perform work on the property, see Regulatory risks starting at page 113, Environmental risks starting at page 114 and Legal and other risks starting at page 115.

The conclusions, projections and estimates included in this description are subject to the qualifications, assumptions and exclusions set out in the technical report, except as such qualifications, assumptions and exclusions may be modified in this AIF. We recommend you read the technical report in its entirety to fully understand the project. You can download a copy from SEDAR (sedar.com) or from EDGAR (sec.gov).

About the McArthur River property

Location

The McArthur River mine site is located near Toby Lake, approximately 620 kilometres north of Saskatoon. The mine site is in close proximity to other uranium production operations: the Key Lake mill is 80 kilometres northeast by road and the Cigar Lake mine is 46 kilometres northeast by air.

Access

Access to the property is by an all-weather gravel road and by air. Supplies are transported by truck from Saskatoon and elsewhere. There is a 1.6 kilometre unpaved air strip and an air terminal one kilometre east of the mine site, on the surface lease.

Saskatoon, a major population centre south of the McArthur River property, has highway and air links to the rest of North America.

Leases

Surface lease

The MRJV acquired the right to use and occupy the lands necessary to mine the deposit under a surface lease agreement with the province of Saskatchewan. The most recent agreement was signed in November 2010. It covers 1,425 hectares and has a term of 33 years.

We are required to report annually on the status of the environment, land development and progress on northern employment and business development.

Mineral lease

We have the right to mine the deposit under ML 5516, granted to us by the province of Saskatchewan. The lease covers 1,380 hectares and expires in March 2024. We have the right to renew the lease for further 10-year terms.

Mineral claims

A mineral claim gives us the right to explore for minerals and to apply for a mineral lease. There are 21 mineral claims, totaling 83,438 hectares, surrounding the deposit. The mineral claims are in good standing until 2018, or later.

2016 ANNUAL INFORMATION FORM    Page 20

Environment, Social and Community Factors

The climate is typical of the continental sub-arctic region of northern Saskatchewan. Summers are short and cool even though daily temperatures can sometimes reach above 30°C. The mean daily temperature for the coldest month is below -20°C, and winter daily temperatures can reach below -40°C.

The deposit is 40 kilometres inside the eastern margin of the Athabasca Basin in northern Saskatchewan. The topography and environment are typical of the taiga forested lands in the Athabasca Basin.

We are committed to building long-lasting and trusting relationships with the communities in which we operate. One of the ways we implement this commitment is through our Five Pillar CSR Strategy. For more information, see Sustainable development at page 82.

No communities are in the immediate vicinity of McArthur River. The community of Wollaston Lake is approximately 120 kilometres by air to the east of the mine site. The community of Pinehouse is approximately 300 kilometres south of the mine by road.

Athabasca Basin community resident employees and contractors fly from various pick-up points in smaller planes to the mine. Other employees and contractors fly to the mine from Saskatoon with pick-up points in Prince Albert and La Ronge.

Geological Setting

The deposit is in the southeastern portion of the Athabasca Basin in northern Saskatchewan, within the southwest part of the Churchill structural province of the Canadian Shield.

The crystalline basement rocks underlying the deposit are members of the Aphebian-age Wollaston Domain, metasedimentary sequence. These rocks are overlain by flat lying sandstones and conglomerates of the Helikian Athabasca Group. These sediments consist of the A, B, C and D units of the Manitou Falls Formation, and a basal conglomerate containing pebbles and cobbles of quartzite. These sediments are over 500 metres thick in the deposit area.

Mineralization

McArthur River’s mineralization is structurally controlled by a northeast-southwest trending reverse fault (the P2 fault), which dips 40-65 degrees to the southeast. The fault has thrust a wedge of basement rock into the overlying sandstone. There is a vertical displacement of more than 80 metres at the northeast end of the fault, which decreases to 60 metres at the southwest end.

The deposit consists of six distinct mineralized zones with delineated mineral reserves and resources (Zones 1 to 4, Zones A and B), plus one additional area with delineated mineral resources (McArthur north). In addition, there are several mineralized showings over a strike length of 2,700 metres.

The width of the mineralization varies. The main part of the mineralization, generally at the upper part of the wedge, averages 12.7 metres in width and attains a maximum width of 28 metres (Zone 2). The height of the mineralization ranges from 50 metres to 120 metres.

With the exception of Zone 2, the mineralization occurs in both the sandstone and basement rock along the faulted edge of the basement wedge. Zone 2 occurs deeper in the basement rock in a unique area of the deposit, where a massive footwall quartzite unit lies close to the main fault zone.

Although all of the rocks at McArthur River are altered to some degree, the alteration is greatest in or near faults that are often associated with mineralization. Chloritization is common and most intense within a metre of mineralization in the pelitic hanging wall basement rocks above the P2 fault. The predominant alteration characteristic of the sandstone is pervasive silicification, which increases in intensity 375 metres below the surface, and continues to the unconformity. This brittle sandstone is strongly fractured along the path of the main fault zone, resulting in poor ground conditions and high permeability to water.

In general, the high-grade mineralization, characterized by botryoidal uraninite masses and subhedral uraninite aggregates, constitutes the earliest phase of mineralization in the deposit. Pyrite, chalcopyrite, and galena were also deposited during the initial mineralizing event. Later stage, remobilized uraninite occurs as disseminations, veinlets, and fracture coatings within chlorite breccia zones, and along the margins of silt beds in the Athabasca sandstone.

2016 ANNUAL INFORMATION FORM    Page 21

Deposit Type

McArthur River is an unconformity-associated uranium deposit. The geological model was confirmed by underground drilling, development and production activities. Similar deposits include: Rabbit Lake, Key Lake, Cluff Lake, Midwest Lake, McClean Lake, Cigar Lake and Maurice Bay in the Athabasca uranium district (Saskatchewan, Canada), Kiggavik (Lone Gull) Thelon Basin district (Nunavut, Canada), Jabiluka, Ranger, Koongarra and Nabarlek, Alligator River district (Northern Territory, Australia). Although these deposits belong to the unconformity-associated model, all are different. Uranium mineralization in the Nunavut and Australian deposits is all hosted in the basement lithologies whereas in the Athabasca deposits, mineralization is present in both the basement and overlying sandstone. Another key difference is that the Athabasca deposits are of considerably higher grade.

Unconformity-associated uranium deposits comprise massive pods, veins, and/or disseminations of uraninite spatially associated with unconformities between Proterozoic siliciclastic basins and metamorphic basement. The siliciclastic basins are relatively flat-lying, un-metamorphosed, late Paleoproterozoic to Mesoproterozoic, fluvial red-bed strata. The underlying basement rocks comprise tectonically interleaved Paleoproterozoic metasedimentary and Archean to Proterozoic granitoid rocks. Uranium as uraninite (commonly in the form of pitchblende) is the sole commodity in the monometallic sub-type and principle commodity in the polymetallic sub-type that includes variable amounts of Ni, Co, As and traces of Au, Pt, Cu and other elements. Some deposits include both sub-types and transitional types, with the monometallic tending to be basement-hosted, and the polymetallic generally hosted by basal siliciclastic strata and paleo-weathered basement at the unconformity.

About the McArthur River operation

McArthur River is a developed producing property with sufficient surface rights to meet current mining operation needs.

We began construction and development of the McArthur River mine in 1997 and completed it on schedule. Mining began in December 1999 and commercial production on November 1, 2000.

McArthur River currently has six zones with delineated mineral reserves and resources (Zones 1 to 4, Zones A and B) and one additional area with delineated mineral resources (McArthur north). We are currently mining Zone 2 and Zone 4.

Zone 2 has been actively mined since production began in 1999. The ore zone was initially divided into three freeze panels (Panels 1-2, 3 and 5). As the freeze wall was expanded, the inner connecting freeze walls were decommissioned in order to recover the inaccessible uranium around the active freeze pipes. The majority of the remaining Zone 2 mineral reserves are in the upper portion of Panel 5.

Zone 4 is divided into three mining areas: north, central, and south. We are actively mining the lower central, and north areas. The upper central area is currently in the ground freezing stage, which is expected to be complete in 2017. Similar to Zone 2, the inner connecting freeze walls are decommissioned as new panels are brought on line in order to maximize ore recovery.

Zone 1 is under development and freeze hole drilling is in progress. Production from Zone 1 is expected to begin in 2020.

We have successfully extracted over 309 million pounds (100% basis) since we began mining in 1999.

Permits

We need three key permits to operate the McArthur River mine:

• Uranium Mine Operating Licence – renewed in 2013 and expires on October 31, 2023 (from the Canadian Nuclear Safety Commission (CNSC))

• Approval to Operate Pollutant Control Facilities – renewed in 2017 and expires on June 30, 2023 (from the Saskatchewan Ministry of Environment (SMOE))

• Water Rights Licence and Approval to Operate Works – amended in 2011 and valid for an undefined term (from the Saskatchewan Watershed Authority).

Infrastructure

Surface facilities are 550 metres above sea level. The site includes:

2016 ANNUAL INFORMATION FORM    Page 22

• an underground mine with three shafts:

one full surface shaft and two ventilation shafts

• 1.6 kilometre airstrip and air terminal

• waste rock stockpiles

• water containment ponds and treatment plant

• a freshwater pump house

• a powerhouse

• electrical substations

• standby electrical generators

• a warehouse

• freeze plants

• a concrete batch plant

• an administration and maintenance shop building

• a permanent residence and recreation complex

• an ore slurry load out facility.

Water, power and heat

Toby Lake, which is nearby and easy to access, has enough water to satisfy all surface water requirements. Collection of groundwater entering our shafts is sufficient to meet all underground process water requirements. The site is connected to the provincial power grid, and it has standby generators in case there is an interruption in grid power.

McArthur River operates throughout the year despite cold winter conditions. During the winter, we heat the fresh air necessary to ventilate the underground workings using propane-fired burners.

Employees

Employees are recruited with preference given to residents of northern Saskatchewan.

Mining method

We use a number of innovative methods to mine the McArthur River deposit.

Ground freezing

The sandstone that overlays the deposit and metasedimentary basement rocks is water-bearing and more permeable, which results in significant water pressure at mining depths. In order to isolate the high-pressure water, ground freezing is used to form an impermeable wall around the area being mined. This prevents water from entering the mine, and helps stabilize weak rock formations. Ground freezing reduces, but does not eliminate, the risk of water inflows. To date, we have isolated six mining areas with freeze walls and a seventh mining area is expected to be isolated mid-2017.

Raisebore mining

Raisebore mining is an innovative non-entry approach that we adapted to meet the unique challenges at McArthur River, and it has been used since mining began in 1999. It involves:

• establishing a drill chamber above the ore and an extraction chamber below the ore

• setting up a raisebore drill in the drill chamber, drilling a pilot hole down to the extraction chamber, attaching a 3-metre wide reaming head to the drill string, and pulling it back up through the ore zone

• collecting the high-grade broken ore at the bottom of the raises using line-of-sight remote-controlled scoop trams, and transporting it to an underground grinding circuit

• filling each raisebore hole with concrete

• when a series of overlapping raisebore holes in a chamber is complete, removing the equipment and filling the entire chamber with concrete

• starting the process again in an adjacent raisebore.

Blasthole stoping

Our use of blasthole stoping began in 2011 and has expanded; the majority of ore extraction is now carried out with blasthole stoping. The use of this method has allowed the site to improve operating costs by significantly reducing waste rock handling, backfill dilution, and backfill placement.

Similar to raiseboring, blasthole stoping requires establishing drill access above the ore and extraction access below the ore. We begin each stope with a single raisebore hole (explained above). The stope is then formed by expanding the circumference of the raise by drilling longholes around the raisebore hole and blasting the ore. The blasted material funnels into the raisebore hole and drops to the extraction level below. The broken rock is collected on the lower level and removed by line-of-sight remote-controlled scoop trams, and transported to the underground grinding circuit. Once a stope is mined out, it is backfilled with concrete to maintain ground stability and allow the next stope and/or raise to be mined. This mining method has been used extensively in the mining industry, including uranium mining.

2016 ANNUAL INFORMATION FORM    Page 23

Boxhole boring

Boxhole mining was tested at McArthur River between 2012 and 2015 and though it is approved for use as a mining method, the related costs are higher and it is not being actively used. Boxhole boring is similar to the raisebore method, but the drilling machine is located below the mineralization, so development is not required above the mineralization.

New mining areas

We must bring on new mining zones to sustain production, and two new areas are currently under active development: the upper central portion of Zone 4, and Zone 1. In order to support the development of these zones, infrastructure expansions are required related to freeze capacity and ventilation. In 2016, we completed the upgrade of our surface electrical infrastructure as part of our plan to address current and future needs. We also continued construction of the next freeze plant, which is scheduled to begin freezing the south end of the orebody (Zone 4) in 2017.

The mine life of McArthur River/Key Lake has been extended from 2033 to 2037 as a result of changes to the annual production assumptions in our mine plan, and the work completed to upgrade resources to reserves in Zone A. See Mineral reserves and resources on page 74 for more information.

Initial mine processing for transport to Key Lake Mill

Ore processing at McArthur River was commissioned in 2000 following a lengthy period of testing, design, procurement, and construction. Since commissioning, numerous changes have been made to the McArthur River ore processing and water treatment circuits to improve their operational reliability and efficiency.

We carry out initial processing of the extracted ore at McArthur River:

• the underground circuit grinds the ore and mixes it with water to form a slurry

• the slurry is pumped 680 metres to the surface and stored in one of four ore slurry holding tanks

• it is blended and thickened, removing excess water

• the final slurry, at an average grade of 15% U₃O₈, is pumped into transport truck containers and shipped to Key Lake mill on an 80 kilometre all-weather road

Water from this process, including water from underground operations, is treated on the surface. Any excess treated water is released into the environment.

Tailings

McArthur River does not have a tailings management facility because it ships the ore slurry to Key Lake for milling. We expect to have sufficient tailings capacity at Key Lake to mill all the known McArthur River mineral reserves and resources, should they be converted to reserves, with additional capacity to toll mill ore from other regional deposits.

Waste

The waste rock piles are confined to a small footprint on the surface lease. These are separated into three categories:

• clean rock (includes mine development waste, crushed waste, and various piles for concrete aggregate and backfill)

• mineralized waste and low grade ore (>0.03% U₃O₈) – stored on engineered lined pads

• waste with acid-generating potential – stored on engineered lined pads – for concrete aggregate.

Water inflows

Production was temporarily suspended on April 6, 2003, as increased water inflow due to a rock fall in a new development area (located just above the 530 metre level) began to flood portions of the mine. We resumed mining in July 2003 and sealed off the excess water inflow in July 2004.

In November 2008, there was a small water inflow in the lower Zone 4 development area on the 590 metre level. We captured and controlled the inflow, and did not have to alter our mining plan. We completed a freeze wall in this area in 2010, and are now mining in the area.

These two inflows have strongly influenced mine design, inflow risk mitigation and inflow preparedness.

Pumping capacity and treatment limits

Our standard for this mine is to secure pumping capacity of at least one and a half times the estimated maximum sustained inflow. We review our dewatering system and requirements at least once a year and before we begin work on any new zone. We believe we have sufficient pumping, water treatment and surface storage capacity to handle the estimated maximum

2016 ANNUAL INFORMATION FORM    Page 24

sustained inflow. As our mine plan is advanced, we plan to make improvements in our dewatering system and to expand our water treatment capacity.

Production

• 2016: 18.0 million pounds of U₃O₈ was produced by milling McArthur River ore at Key Lake (our share was 12.6 million pounds). Average mill metallurgical recovery was 99.04%.

• 2017 Forecast: 18.0 million pounds of U₃O₈ (our share 12.6 million pounds) (which includes processing downblended material at Key Lake).

• For the remainder of the estimated mine life, the total production forecast as of December 31, 2016 is estimated to be 365 million pounds of U₃O₈ (our share 255 million pounds) based on an overall milling recovery of 98.7% (which does not include processing downblended material at Key Lake).

In alignment with our continued efforts to reduce costs, our 2017 production plan for the McArthur River and Key Lake operations includes an extended shut-down during the third quarter, which is expected to result in reduced flight and camp costs. The shut-down will consist of a four-week vacation period, followed by a two-week maintenance period at McArthur River and a four-week maintenance period at Key Lake, with mill production planned to restart before the end of the third quarter.

We have also planned additional actions for 2017, including a 10% reduction of the workforce at McArthur River and Key Lake, and changes to the commuter flight services at our sites, which are expected to further reduce costs and improve efficiency at the operations.

The operational changes we have made, and plan to make in 2017, which are intended to achieve cost savings and improve efficiency, carry with them increased risk of production disruption.

The collective agreement with the United Steelworkers local 8914 expires at the end of December 2017. We plan to begin contract negotiations prior to the expiration of the current agreement. There is a risk to our 2018 production if we are unable to reach agreement and there is a labour dispute.

McArthur River production expansion potential

In 2012, we completed the feasibility study on the McArthur River extension project and based on the positive results, we revised our mine plan to incorporate a mine expansion.

In 2015, the CNSC approved our application to increase McArthur River’s licensed annual production to 25 million pounds (100% basis), to allow flexibility to match the approved Key Lake mill capacity. The licence conditions handbooks for these operations now allow both operations to produce up to 25 million pounds (100% basis) per year.

In order to successfully meet the planned production in the life of mine schedule, we must continue to successfully transition into new mine areas through mine development and investment in support infrastructure. We plan to:

• improve our dewatering system and expand our water treatment capacity, as required to mitigate capacity losses should mine developments increase background water volumes

• expand the concrete distribution systems and batch plant capacity.

Freeze plant and distribution systems will have to be expanded as new mining areas are developed and brought into production. Freeze plant capacity is expected to be expanded in three stages as follows:

• Expansion of the existing freeze plant: Expansion of the existing freeze plant from 800 tonnes to 1,300 tonnes was completed and commissioned in 2014.

• South freeze plant: A modular freeze plant with initial capacity of 750 tonnes of freeze capacity is planned for the south mining areas and is scheduled to be completed in 2017.

• North freeze plant: A freeze plant with capacity up to 1,250 tonnes is tentatively planned for the north mining areas and is scheduled to be completed by 2024. Final sizing will be determined after the completion of Zone A and Zone B delineation drilling.

We remain focused on taking advantage of the long-term growth we see coming in our industry, while maintaining the ability to respond to market conditions as they evolve. Once the market signals that new supply is needed and a decision is made to begin increasing annual production, we will optimize the capacity of both the McArthur River mine and Key Lake mill with a

2016 ANNUAL INFORMATION FORM    Page 25

view to achieving annual licensed capacity of 25 million pounds per year (100% basis). We expect that this paced approach will allow us to extract maximum value from the operation as the market transitions.

Key Lake mill

Location and access

In northern Saskatchewan, 570 kilometres north of Saskatoon. The site is 9 kilometres long and 5 kilometres wide. It is connected to McArthur River by an 80 kilometre all-weather road. There is a 1.6 kilometre unpaved air strip and an air terminal on the east edge of the site.

Permits

We need four key permits to operate the Key Lake mill:

• Uranium Mill Operating Licence – renewed in 2013 and expires on October 31, 2023 (from the CNSC)

• Approval to Operate Pollutant Control Facilities – renewed in 2014 and expires on November 30, 2021 (from the SMOE)

• Water Rights Licences to use ground water and approval to operate works – last updated in 2008 and expires April 1, 2032 (from the Saskatchewan Watershed Authority)

• Approvals to Operate Works for dewatering wells – last issued/amended in 2015 with no expiry noted (from the Saskatchewan Watershed Authority).

In 2014, the CNSC approved the environmental assessment (EA) for the Key Lake extension project, a project which involves increasing our tailings capacity and Key Lake’s nominal annual production rate. The licence conditions handbook now allows the Key Lake mill to produce up to 25.0 million pounds (100% basis) per year.

With the approved EA and once the Key Lake extension project is complete, mill production can be increased to closely follow production from the McArthur River mine. There will be differences in a given production year between mine and mill production due to the addition of mineralized material stockpiled at Key Lake, processing downblended material (see page 19), year-to-year inventory changes and recovery rate.

Supply

Our share of McArthur River ore is milled at Key Lake. We do not have a formal toll milling agreement with the Key Lake joint venture.

In June 1999, the Key Lake joint venture (Cameco and UEM) entered into a toll milling agreement with AREVA to process their total share of McArthur River ore. The terms of the agreement (as amended in January 2001) include the following:

• processing is at cost, plus a toll milling fee

• the Key Lake joint venture owners are responsible for decommissioning the Key Lake mill and for certain capital costs, including the costs of any tailings management associated with milling AREVA’s share of McArthur River ore.

With the UEM distribution in 2009 (see History on page 19 for more information), we made the following changes to the agreement:

• the fees and expenses related to AREVA’s pro-rata share of ore produced just before the UEM distribution (16.234% – the first ore stream) have not changed. AREVA is not responsible for any capital or decommissioning costs related to the first ore stream.

• the fees and expenses related to AREVA’s pro-rata share of ore produced as a result of the UEM distribution (an additional 13.961% – the second ore stream) have not changed. AREVA’s responsibility for capital and decommissioning costs related to the second ore stream are, however, as a Key Lake joint venture owner under the original agreement.

The agreement was amended again in 2011 and now requires:

• milling of the first ore stream at the Key Lake mill until May 31, 2028

• milling of the second ore stream at the Key Lake mill for the entire life of the McArthur River project.

Process and recovery

The Key Lake mill uses a seven-step process:

• blend McArthur River ore with low grade mineralized material to lower the grade

• dissolve the uranium using a leaching circuit

2016 ANNUAL INFORMATION FORM    Page 26

• clarify the uranium in solution using a counter current decantation circuit

• concentrate it using a solvent extraction circuit

• precipitate it with ammonia

• thicken, dewater and dry/roast it in a calcining kiln

• package it as 98% U₃O₈ (yellowcake).

Key Lake has been achieving annual milling recovery of 98.7% or better over the past 10 years and the forecast is for 99.2% in 2017.

Waste rock

There are five large rock stockpiles at the Key Lake site:

• three contain non-mineralized waste rock. These will be decommissioned when the site is closed.

• two contain low-grade mineralized material. These are used to lower the grade of the McArthur River ore before it enters the milling circuit.

Treatment of effluent

We modified Key Lake’s effluent treatment process to satisfy our licence and permit requirements.

Tailings capacity

There are two tailings management facilities at the Key Lake site:

• an above-ground impoundment facility, where tailings are stored within compacted till embankments. We have not deposited tailings here since 1996, and are looking at several options for decommissioning this facility in the future.

• the Deilmann pit, which was mined out in the 1990s. Tailings from processing McArthur River ore are deposited in the Deilmann tailings management facility (TMF).

In 2009, regulators approved our plan for the long-term stabilization of the Deilmann TMF pitwalls. We implemented the plan in phases based on TMF water level and risk. Work was completed in 2013 on the west wall and 2016 on the south side. The final phase on the north east slope is targeted for completion in 2018.

In 2014, the CNSC approved an increase in Key Lake’s tailings capacity. We now expect to have sufficient tailings capacity to mill all the known McArthur River mineral reserves and resources, should they be converted to reserves, with additional capacity to toll mill ore from other regional deposits.

Mill revitalization

The Key Lake mill began operating in 1983 and we have continually upgraded circuits with new technology to simplify operations, and improve environmental performance, with the objective to increase the mill’s nominal annual production capacity to match the annual production capacity of the McArthur River mine. As part of the mill upgrades, a new calciner was installed at the Key Lake mill to accommodate an eventual annual production increase to 25 million pounds. However, reliability issues were encountered with the new equipment during commissioning. Since market conditions do not currently support a decision to increase production, and as part of our continuing efforts to reduce costs, in 2016, we suspended the commissioning of and transition to the new calciner. We are assessing the cost to resolve the issues and expect to complete commissioning if we determine that there is financial and operational value in adding new calcining capacity. The existing calciner has sufficient capacity to meet our 2017 production target of 18 million pounds (12.6 million pounds our share).

Decommissioning and financial assurances

In 2003, we prepared a preliminary decommissioning plan for both McArthur River and Key Lake, which were approved by the CNSC and the SMOE. In 2008, when we renewed our CNSC licence, we revised the accompanying preliminary decommissioning cost estimates. In 2013, when we again renewed our CNSC licence, we revised the accompanying preliminary decommissioning cost estimates. Our Key Lake preliminary decommissioning cost estimate was further revised and submitted to the CNSC in 2014 and we received final approval from the CNSC in January 2015. These documents include our estimated cost for implementing the decommissioning plan and addressing known environmental liabilities.

We, along with our joint venture participant, have letters of credit posted as financial assurances with the government of Saskatchewan to cover the amount in the 2013 preliminary decommissioning cost estimate for McArthur River ($48 million) and the 2015 preliminary decommissioning cost estimate for Key Lake ($218 million).

2016 ANNUAL INFORMATION FORM    Page 27

Operating and capital costs

The following is a summary of the operating and capital cost estimates for the life of mine, stated in constant 2017 dollars and reflecting a forecast life-of-mine mill production of 366.6 million pounds U₃O_8:

Operating Costs ($Cdn million)	Total (2017 – 2037)
McArthur River Mining
Site administration	$	995.3
Mining costs		1,588.3
Process		305.8
Corporate overhead		187.7
Total mining costs	$	3,077.1
Key Lake Milling
Administration	$	1,070.4
Milling costs		1,261.0
Corporate overhead		119.1
Total milling costs	$	2,450.5
Total operating costs	$	5,527.6
Total operating cost per pound U3O8	$	15.08

Note: presented as total cost to the MRJV (100% basis)

Estimated operating costs to the MRJV consist of annual expenditures at McArthur River to mine the mineral reserves, process it underground, including grinding, density control and pumping the resulting slurry to surface for transportation to Key Lake.

Operating costs at Key Lake consist of costs for receipt of the slurry, up to and including precipitation of the uranium into yellowcake, including cost of disposal of tailings to the Deilmann TMF.

Capital Costs ($Cdn million)	Total (2017 – 2037)
McArthur River Mine Development	$	714.3
McArthur River Mine Capital
Freeze infrastructure	$	226.4
Ventilation		46.6
Concrete batching and delivery		54.3
Other mine capital		330.9
Total mine capital	$	658.2
Key Lake Mill Sustaining
Revitalization	$	7.4
Mill capital		200.5
Total mill capital	$	207.9
Total capital costs	$	1,580.4

Note: presented as total cost to the MRJV (100% basis)

Estimated capital costs to the MRJV include sustaining costs for both McArthur River and Key Lake, as well as underground development at McArthur River to bring mineral reserves into production. Overall, the largest capital at McArthur River is mine development. Other significant capital includes freeze infrastructure costs.

Our expectations and plans regarding McArthur River/Key Lake, including forecasts of operating and capital costs, production and mine life are forward-looking information and are based specifically on the risks and assumptions discussed on pages 2 and 3. We may change operating or capital spending plans in 2017, depending upon uranium

2016 ANNUAL INFORMATION FORM    Page 28

markets, our financial position, results of operation or other factors. Estimates of expected future production and capital and operating costs are inherently uncertain, particularly beyond one year, and may change materially over time.

Exploration, drilling, sampling, data quality and estimates

There are no historical mineral resource estimates within the meaning of NI 43-101 to report. The original McArthur River mineral resource estimates were derived from surface diamond drilling from 1980 to 1992. In 1988 and 1989, this drilling first revealed significant uranium mineralization. By 1992, we had delineated the mineralization over a strike length of 1,700 metres at depths of between 530 to 640 metres. Data included assay results from 42 drillholes. The very high grade found in the drillholes justified the development of an underground exploration project in 1993.

Exploration

In total, exploration drilling of the McArthur River deposit to date consists of over 1,440 drillholes and 277,981 metres. Drilling has been carried out from both surface and underground in order to locate and delineate mineralization. Surface exploration drilling is initially used in areas where underground access is not available and is used to guide the underground exploration programs.

In 2016, we began underground infill definition drilling of Zone B in order to provide the information required for more detailed mining plans. In 2017, we plan to continue with the infill drilling of Zone B.

Greenfield exploration was carried out on the McArthur River property in 2016 and further work is planned for 2017.

Drilling

Surface drilling

We have carried out surface drilling since 2004, to test the extension of mineralization identified from the historical surface drillholes, to new targets along the strike, and to evaluate the P2 trend northeast and southwest of the mine. Surface drilling has delineated mineralization over a strike length of 1,700 metres, generally at between 500 metres to 640 metres below the surface. Surface drilling since 2004 has extended the potential strike length to 2,700 metres.

As of December 31, 2016, we had drilled 258 surface drillholes (both conventional and directional drilling) for a total of approximately 171,400 metres along the P2 trend.

We have completed preliminary drill tests of the P2 trend at 200 metre intervals over 11.5 kilometres (4.3 kilometres northeast and 6.4 kilometres southwest of the McArthur River deposit) of the total 13.75 kilometres strike length of the P2 trend. Surface exploration drilling in 2015 focused on additional evaluation in the southern part of the P2 trend south of the P2 main mineralization. There was no work on the P2 trend in 2016 and none is planned for 2017, although drilling is planned elsewhere on the McArthur River property.

Underground drilling

In 1993, regulators approved an underground exploration program, consisting of shaft sinking, lateral development and drilling. We completed the shaft in 1994.

We have drilled more than 1,182 underground drillholes since 1993, resulting in over 106,581 metres to get detailed information along 1,800 metres of the surface delineation. This data was used to estimate the mineral reserves and resources in six mineralized zones (Zones 1 to 4 and Zones A and B). The drilling was primarily completed from the 530 and 640 metre levels. Data from hundreds of freezeholes and raisebore pilot holes support the estimate. Where there were no underground drillholes (McArthur north in the northeastern part of the deposit), we used surface exploration drillholes to estimate mineral resources.

Other data

In addition to the exploration drilling, geological data is also collected from the underground probe and grout, service, drain, freezeholes and geotechnical programs.

Recent activity

In 2013, we continued advancing the underground exploration drifts in the southwest and northeast directions and focused on

2016 ANNUAL INFORMATION FORM    Page 29

developing Zone 4 and areas at the southwest end of the underground mine workings. The delineation drilling program on Zone A progressed through the year.

In 2014, we completed the planned development advance of the underground exploration drifts and underground delineation drilling.

In 2015, we continued the advancement of our underground exploration drifts in the southwest and northeast directions. The delineation drilling program on Zone A also progressed throughout the year.

In 2016, we continued additional underground drilling to further delineate Zone A and Zone B and identify additional mineral resources in the deposit.

In 2017, we plan to continue with the infill delineation drilling of Zone B.

Sampling, analysis and data verification

Surface samples

• GPS or mine site surveying instruments are used in the field to verify the location of surface drillholes.

• Holes are generally drilled every 12 to 25 metres, on sections that are 50 to 200 metres apart. Drilled depths average 670 metres.

• The orientation of mineralization is variable but, in general, vertical holes generally intersect mineralization at angles of 25 to 45 degrees, resulting in true widths being 40 to 70% of the drilled width. Angled holes usually intercept mineralization closer to perpendicular, giving intercepts that are closer to true width.

• All holes are radiometrically probed, where possible.

• A geologist examines the surface drillhole core in the field, determines its overall characteristics, including mineralization, logs the information, and takes samples that have noteworthy alteration, structures and radiometric anomalies.

• Basement sampling procedures depend on the length of the interval sampled, and attempts are made to avoid having samples cross lithological boundaries.

• All core with radioactivity greater than a set threshold is split and sampled for assay.

• We measure the uranium grade by assaying core. Core recovery is generally considered excellent with some local exceptions. The quality and representativeness of the surface drillhole samples is adequate for estimating mineral resources and mine planning, but we often validate surface drillhole results against underground drilling results in the same vicinity.

Underground samples

• Holes are drilled in stations 30 metres apart. Each station is drilled with three fans of holes, covering 10 metres across the deposit.

• Uranium grade is calculated from the adjusted radiometric probe readings. Radiometric probing is at 0.1 metre spacing in radioactive zones and 0.5 metre spacing in unmineralized zones. The drillhole fans give the gamma probes representative access across the entire deposit.

• A small portion of the data we obtain is from assays, which we use to estimate mineral resources. It is collected to determine the U₃O₈ content past the probe limit of a hole, or to provide correlation samples to compare against a probed interval. In these cases, we log the core, photograph it, and then sample it for uranium analysis. We sample the entire interval instead of splitting the core. This provides very high-quality samples in these areas.

• Core recovery in these areas can be excellent to poor.

• The quality and representativeness of the underground drillhole samples is adequate for estimating mineral resources and mine planning.

2016 ANNUAL INFORMATION FORM    Page 30

Analysis

We record the following for each sample:

• hole number, date and core logger name

• sample number

• from and to intervals and length

• recovered length

• core diameter

• rock type, alteration, and mineralization.

We place each sample in a plastic bag and write its number on the bag. We place the bags in a metal or plastic shipping drum, which is scanned by the radiation department and shipped to the Saskatchewan Research Council Geoanalytical Laboratories (SRC) in Saskatoon for analysis. SRC is independent of the participants of the MRJV.

SRC personnel:

• verify the sample information

• sort the samples by radioactivity

• dry, crush and grind them in secure facilities or in the main laboratory, if they have minimal radioactivity

• dilute the samples and carry out a chemical analysis

• prepare and analyse a quality control sample with each batch

• analyse one of every 40 samples in duplicate.

Quality control and data verification

A data and quality assurance coordinator on staff is responsible for reviewing the quality of geochemical data received from laboratory contractors. The coordinator reviews the analyses provided by the lab using the results of standard reference materials as a benchmark, and, together with project geologists, determines whether it is necessary to reassay.

We use several quality control measures and data verification procedures:

• enter surveyed drillhole collar coordinates and hole deviations in the database, display them in plan views and sections and visually compare them to their planned location

• visually validate core logging information on plan views and sections, and verify it against photographs of the core or the core itself

• compare downhole radiometric probing results with core radioactivity and drilling depth measurements

• validate uranium grade based on radiometric probing with sample assay results, when available

• compare the information in the database against the original data, including paper logs, deviation survey films, assay certificates and original probing data files.

Quality assurance and quality control for underground drillhole information focuses on ensuring quality probing results. We do this by:

• using a software program to check for data errors such as overlapping intervals and out of range values

• entering surveyed drillhole collar coordinates and downhole deviations into the database and visually validating and comparing to the planned location of the holes

• checking the calibration of probes before using them and periodically duplicating probe runs

• comparing downhole radiometric probing results with radioactivity measurements made on the core and drilling depth measurements

• validating uranium grades based on radiometric probing with sample assay results once available.

Since 2000, we have regularly compared information collected from production activities, such as freezeholes, raisebore pilot holes, radiometric scanning of scoop tram buckets and mill feed sampling, to the drillhole data. Reconciling the uranium block model with mine production is a very good indicator that estimated grades in the block model accurately reflect the mined grades.

In 2014, we completed at Cigar Lake a test program of the McArthur River radiometric probes to demonstrate that consistent count rates were being obtained between probes. A total of eight surface freezeholes were probed multiple times with each probe to compare count rates. This test demonstrated that probes with the same equipment configurations and GM tubes produced very consistent count rates. The reliability of the probe readings was last confirmed in January 2015 by comparison with the results of an independent non-Cameco test using a series of probes built by a different manufacturer.

2016 ANNUAL INFORMATION FORM    Page 31

Sample security

Samples include chain of custody documentation that accompanies the samples during transportation to the laboratory for analysis.

All samples collected from McArthur River are prepared and analysed under the close supervision of a qualified geoscientist at the SRC, which is a restricted access laboratory licensed by the CNSC.

We store and ship all samples in compliance with regulations. We consider it unlikely that samples are tampered with because of the high grade of the ore and the process used: the core is scanned immediately after it is received at a sample preparation laboratory and grade is estimated at that point.

Accuracy

We are satisfied with the quality of data obtained from surface exploration and underground drilling at McArthur River and consider it valid for estimating mineral resources and mineral reserves. Results of the quality control measures and data verification procedures are reflected by the fact that for the last five years, our estimation of tonnage, grade and pounds showed differences of -17%, 14% and -5% respectively compared to production. Tonnage and grade variances are partially a result of transitioning to the blasthole stoping mining method with added dilution. Overall, estimated pounds are within 5% of production.

Mineral reserve and resource estimates

Please see page 74 for our mineral reserve and resource estimates for McArthur River.

2016 ANNUAL INFORMATION FORM    Page 32

Uranium – operating properties

	Cigar Lake Cigar Lake is the world’s highest grade uranium mine, with grades that are 100 times the world average. We are a 50% owner and the mine operator. Cigar Lake uranium is milled at AREVA’s McClean Lake mill. Cigar Lake is one of our three material uranium properties.
Location	Saskatchewan, Canada
Ownership	50.025%
End product	uranium concentrate
ISO Certification	ISO 14001 certified
Mine type	underground
Estimated mineral reserves (our share)	107.6 million pounds (proven and probable), average grade U3O8 – 15.90%
Estimated mineral resources1 (our share)	42.3 million pounds (measured and indicated), average grade U3O8 – 16.17% 10.4 million pounds (inferred), average grade U3O8 – 7.36%
Mining method	jet boring system (JBS)
Licensed capacity	mine: 18 million pounds per year (our share 9.0 million pounds per year)
Total production 2014 to 2016	28.9 million pounds (100% basis)
2016 production	8.7 million pounds (17.3 million pounds on 100% basis)
2017 production outlook	9.0 million pounds (18.0 million pounds on 100% basis)
Estimated mine life	2028 (based on current mineral reserves)
Estimated decommissioning cost	$49 million (100% basis)

¹ Mineral resources that are not mineral reserves have no demonstrated economic viability.

Business structure

Cigar Lake is owned by a joint venture of four companies (CLJV):

• Cameco – 50.025% (operator)

• AREVA – 37.100%

• Idemitsu Canada Resources Ltd. – 7.875%

• TEPCO Resources Inc. – 5.000%

2016 ANNUAL INFORMATION FORM    Page 33

History

1976	•       Canadian Kelvin Resources and Asamera Oil Corporation form an exploration joint venture, which includes the lands that the Cigar Lake mine was built on
1977	•       Saskatchewan Mining Development Corporation (SMDC), one of our predecessor companies, acquires a 50% interest
1980	•       Waterbury Lake joint venture formed, includes lands now called Cigar Lake
1981	•       Deposit discovered by surface drilling – it was delineated by a surface drilling program between 1982 and 1986
1985	•       Reorganization of the Waterbury Lake joint venture - Cigar Lake Mining Corporation becomes the operator of the Cigar Lake lands and a predecessor to AREVA becomes the operator of the remaining Waterbury Lands •       SMDC has a 50.75% interest
1987-1992	•       Test mining, including sinking shaft 1 to 500 metres and lateral development on 420 metre, 465 metre and 480 metre levels
1988	•       Eldorado Resources Limited merges with SMDC to form Cameco
1993-1997	•       Canadian and Saskatchewan governments authorize the project to proceed to regulatory licensing stage, based on recommendation of the joint federal-provincial panel after public hearings on the project’s environmental impact
2000	•       Jet boring mining system tested in waste and frozen ore
2001	•       Joint venture approves a feasibility study and detailed engineering begins in June
2002	•       Joint venture is reorganized, new joint venture agreement is signed, Rabbit Lake and JEB toll milling agreements are signed, and we replace Cigar Lake Mining Corporation as Cigar Lake mine operator
2004	•       Environmental assessment process is complete •       CNSC issues a construction licence
2005	•       Development begins in January
2006	•       Two water inflow incidents delay development: •       in April, shaft 2 floods •       in October, underground development areas flood •       In November, we begin work to remediate the underground development areas
2008	•       Remediation interrupted by another inflow in August, preventing the mine from being dewatered
2009	•       Remediation of shaft 2 completed in May •       We seal the 2008 inflow in October
2010	•       We finish dewatering the underground development areas in February, establish safe access to the 480 metre level, the main working level of the mine, and backfill the 465 metre level •       We substantially complete clean-up, inspection, assessment and securing of underground development and resume underground development in the south end of the mine
2011	•       We begin to freeze the ground around shaft 2 and restart freezing the orebody from underground and from the surface •       We resume the sinking of shaft 2 and early in 2012 achieve breakthrough to the 480 metre level, establishing a second means of egress for the mine •       We receive regulatory approval of our mine plan and begin work on our Seru Bay project •       Agreements are signed by the Cigar Lake and McClean Lake joint venture participants to mill all Cigar Lake ore at the McClean Lake mill and the Rabbit Lake toll milling agreement is terminated
2012	•       We achieve breakthrough to the 500 metre level in shaft 2 •       We assemble the first jet boring system unit underground and move it to a production tunnel where we commence preliminary commissioning
2013	•       CNSC issues an eight-year operating licence •       We begin jet boring in ore
2014	•       First Cigar Lake ore shipped to McClean Lake mill •       McClean Lake mill starts producing uranium concentrate from Cigar Lake ore

2016 ANNUAL INFORMATION FORM    Page 34

2015	•       We declared commercial production in May
2016	•       We updated the CNSC on our commissioning activities to satisfy a condition in our federal licence.

Technical report

This project description is based on the project’s technical report: Cigar Lake Operation, Northern Saskatchewan, Canada, dated March 29, 2016 (effective December 31, 2015) except for some updates that reflect developments since the technical report was published. The report was prepared for us in accordance with NI 43-101, by or under the supervision of C. Scott Bishop, P. Eng., Alain G. Mainville, P. Geo., and Leslie D. Yesnik, P. Eng. The following description has been prepared under the supervision of C. Scott Bishop, P. Eng., Alain G. Mainville, P. Geo., and Leslie D. Yesnik, P. Eng. They are all qualified persons within the meaning of NI 43-101, but are not independent of us.   The conclusions, projections and estimates included in this description are subject to the qualifications, assumptions and exclusions set out in the technical report except as such qualifications, assumptions and modifications may be modified in this AIF. We recommend you read the technical report in its entirety to fully understand the project. You can download a copy from SEDAR (sedar.com) or from EDGAR (sec.gov). For information about uranium sales see pages 12 to 15, environmental matters see Safety, Health and the Environment starting on page 84, and taxes see page 98.   For a description of royalties payable to the province of Saskatchewan on the sale of uranium extracted from orebodies within the province, see page 98.   For a description of risks that might affect access, title or the right or ability to perform work on the property, see Regulatory risks starting at page 113, Environmental risks starting at page 114 and Legal and other risks starting at page 115.

About the Cigar Lake property

We began developing the Cigar Lake underground mine in 2005, but development was delayed due to water inflows. In October 2014, the McClean Lake mill produced the first uranium concentrate from ore mined at the Cigar Lake operation. Commercial production was declared in May 2015.

Location

The Cigar Lake mine site is located near Waterbury Lake approximately 660 kilometres north of Saskatoon. The mine site is in close proximity to other uranium production operations: McClean Lake mill is 69 km northeast by road and McArthur River mine is 46 km southwest by air from the mine site.

Access

Access to the property is by an all-weather road and by air. Site activities occur year round, including supply deliveries. There is an unpaved airstrip and air terminal east of the mine site.

Saskatoon, a major population centre south of the Cigar Lake deposit, has highway and air links to the rest of North America.

Leases

Surface lease

The CLJV acquired the right to use and occupy the lands necessary to mine the deposit under a surface lease agreement with the province of Saskatchewan. The lease covers approximately 1,042 hectares and expires in May 2044.

We are required to report annually on the status of the environment, land development and progress on northern employment and business development.

Mineral lease

We have the right to mine the deposit under ML 5521, granted to the CLJV by the province of Saskatchewan. The lease covers 308 hectares and expires December 1, 2021. The CLJV has the right to renew the lease for further 10-year terms.

2016 ANNUAL INFORMATION FORM    Page 35

Mineral claims

A mineral claim gives us the right to explore for minerals and to apply for a mineral lease. There are 25 mineral claims (Nos. S-106540 to 106564), totaling 92,740 hectares, adjoining the mineral lease and surrounding the site. The mineral claims are in good standing until 2023.

Environment, Social and Community Factors

The climate is typical of the continental sub-arctic region of northern Saskatchewan. Summers are short and cool even though daily temperatures can sometimes reach above 30°C. The mean daily temperature for the coldest month is below -20°C, and winter daily temperatures can reach below -40°C.

The deposit is 40 kilometres west of the eastern margin of the Athabasca Basin in northern Saskatchewan. The topography and environment are typical of the taiga forested lands in the Athabasca Basin. This area is covered with 30 to 50 metres of overburden. Vegetation is dominated by black spruce and jack pine. There is a lake known as “Cigar Lake” which, in part, overlays the deposit.

We are committed to building long-lasting and trusting relationships with the communities in which we operate. One of the ways we implement this commitment is through our Five Pillar CSR Strategy. For more information, see Sustainable development at page 82.

The closest inhabited site is Points North Landing, 50 km northeast by road. The community of Wollaston Lake is approximately 80 km by air to the east of the mine site.

Athabasca Basin community resident employees and contractors fly from various pickup points in smaller planes to the mine site. Other employees and contractors fly to site from Saskatoon with pickup points in Prince Albert and La Ronge.

Geological Setting

The deposit is at the unconformity contact separating late Paleoproterozoic to Mesoproterozoic sandstone of the Athabasca Group from middle Paleoproterozoic metasedimentary gneiss and plutonic rocks of the Wollaston Group. The Key Lake, McClean Lake and Collins Bay deposits all have a similar structural setting. While Cigar Lake shares many similarities with these deposits (general structural setting, mineralogy, geochemistry, host rock association and the age of the mineralization), it is distinguished from other similar deposits by its size, very high grade, and the high degree of clay alteration.

Cigar Lake’s geological setting is similar to McArthur River’s: the permeable sandstone, which overlays the deposit and basement rocks, contains large volumes of water at significant pressure. Unlike McArthur River, however, the deposit is flat lying.

Mineralization

The Cigar Lake deposit has the shape of a flat- to cigar-shaped lens and is approximately 1,950 metres in length, 20 to 100 metres in width, and ranges up to 13.5 metres thick, with an average thickness of about 5.4 metres. It occurs at depths ranging between 410 to 450 metres below the surface. Phase 1, the eastern part of Cigar Lake, is approximately 670 metres long by 100 metres wide and Phase 2, the western part, is approximately 1,280 metres long by 75 metres wide.

The deposit has two distinct styles of mineralization:

• high-grade mineralization at the unconformity which includes all of the mineral resources and mineral reserves

• fracture controlled, vein-like mineralization which is located either higher up in the sandstone or in the basement rock mass.

Most of the uranium metal is in the high-grade mineralization at the unconformity, which has massive clays and high-grade uranium concentrations. This is currently the only economically viable style of mineralization, in the context of the selected mining method and ground conditions.

The unconformity mineralization consists primarily of three dominant rock and mineral facies occurring in varying proportions: quartz, clay (primarily chlorite with lesser illite) and metallic minerals (oxides, arsenides, sulphides). In the relatively higher grade Phase 1 area, the ore consists of approximately 50% clay matrix, 20% quartz and 30% metallic minerals, visually estimated by volume. In this area, the unconformity mineralization is overlain by a weakly mineralized contiguous clay cap one to 10 metres thick. In the relatively lower grade Phase 2 area, the proportions change to approximately 20% clay, 60% quartz and 20% metallic minerals.

2016 ANNUAL INFORMATION FORM    Page 36

Deposit Type

Cigar Lake is an unconformity-associated uranium deposit. Deposits of this type are believed to have formed through an oxidation-reduction reaction at a contact where oxygenated fluids meet with reducing fluids.

About the Cigar Lake operation

Cigar Lake is a developed producing property with sufficient surface rights to meet current mining operation needs. We are currently mining in the eastern part of the ore body (referred to as Phase 1), and surface delineation drilling continues for the western portion (Phase 2).

Permits

Please see page 42 for more information about regulatory approvals for Cigar Lake.

Infrastructure

Surface facilities are 490 metres above sea level. The site includes:

• an underground mine with two shafts

• access road joining the provincial highway and McClean Lake

• site roads and site grading

• airport and terminal

• employee residence and construction camp

• Shaft No. 1 and No. 2 surface facilities

• freeze plants and brine distribution equipment

• surface freeze pads

• water supply, storage and distribution for industrial water, potable water and fire suppression

• propane, diesel and gasoline storage and distribution

• electrical power substation and distribution

• compressed air supply and distribution

• mine water storage ponds and water treatment

• sewage collection and treatment

• surface and underground pumping system installation

• waste rock stockpiles

• garbage disposal landfill

• administration, maintenance and warehousing facilities

• underground tunnels

• ore load out facility

• concrete batch plant

• Seru Bay pipeline

• emergency power generating facilities.

The Cigar Lake mine site contains all the necessary services and facilities to operate a remote underground mine, including personnel accommodation, access to water, airport, site roads and other necessary buildings and infrastructure.

Water, power and heat

Waterbury Lake, which is nearby, provides water for the industrial activities and the camp. The site is connected to the provincial electricity grid, and it has standby generators in case there is an interruption in grid power.

Cigar Lake operates throughout the year despite cold winter conditions. During the winter, we use propane-fired burners to heat the fresh air necessary to ventilate the underground workings.

Employees

Employees are recruited with preference given to residents of northern Saskatchewan.

Mining methods

We use the JBS method to mine the Cigar Lake deposit.

Bulk freezing

The permeable sandstone that overlays the deposit and basement rocks contains large volumes of water under significant pressure. We freeze the ore zone and surrounding ground in the area to be mined to prevent water from entering the mine and to help stabilize weak rock formations. This system freezes the deposit and underlying basement rock in two to four years, depending on water content and geological conditions. To manage our risks and to meet our production schedule, the area being mined must meet specific ground freezing requirements before we begin jet boring. Bulk freezing reduces but does not eliminate the risk of water inflows.

2016 ANNUAL INFORMATION FORM    Page 37

Prior to the mine inflow events in 2006, we had been pursuing a strategy of bulk freezing exclusively from underground. Following mine remediation and a surface freeze test program in 2010, we shifted to a hybrid freezing strategy combining freezing from both surface and underground. However, based on additional studies and experience gained with surface freezing since the 2010 test, we decided in 2015 to pursue a strategy of freezing exclusively from surface.

The costs related to each technique are similar; however, there are significant advantages to freezing the ground from the surface. With surface freezing, less mine development is required, which results in less waste rock and greater ground stability, since freeze tunnels are not required between production tunnels. In addition, congestion is reduced and underground development for freeze infrastructure is no longer a critical path mine activity.

Artificial ground freezing is accomplished by drilling a systematic grid of boreholes through the orebody from surface. A network of supply and return pipes on surface convey a calcium chloride brine to and from each hole. The warm brine returning from each hole is chilled to a temperature of -30ºC at the surface freeze plant and recirculated.

Jet boring

After many years of test mining, we selected the jet boring mining system, a non-entry mining method, which we have developed and adapted specifically for this deposit. This method involves:

• drilling a pilot hole into the frozen orebody, inserting a high pressure water jet and cutting a 4.5 to 6 metre diameter cavity out of the frozen ore resulting in cylindrical void with a height corresponding to the thickness of the ore body up to 13.5 metres

• collecting the ore and water mixture (slurry) from the cavity and pumping it to storage (sump storage), allowing it to settle

• using a clamshell, transporting the ore from the sump storage to a grinding and processing circuit, eventually loading a tanker truck with ore slurry for transport to the mill

• filling each cavity in the orebody with concrete once mining is complete

• starting the process again with the next cavity.

This is a non-entry method, which means mining is carried out from headings in the basement rock below the deposit, so employees are not exposed to the ore. This mining approach is highly effective at managing worker exposure to radiation levels. Combined with ground freezing and the cuttings collection and hydraulic conveyance system, jet boring reduces radiation exposure to acceptable levels that are below regulatory limits.

Ore shipments started in March 2014 and the McClean Lake mill started producing uranium concentrates from the ore in October 2014.

The mine equipment fleet is currently comprised of three JBS units plus other equipment to support mine development, drilling and other services, and is sufficient to meet the needs of the mine plan for the next few years. The current mine plan, with its underlying productivity assumptions, assumes that a fourth JBS unit is required later in the mine life. We are currently investigating if there are opportunities for productivity improvements that could negate the need for the fourth JBS unit.

As we ramp up production, there may be some technical challenges, which could affect our production plans including, but not limited to, variable or unanticipated ground conditions, ground movement and cave-ins, water inflows and variable dilution, recovery values, chemical ore characteristics, performance of the water treatment system, mining productivity and equipment reliability. There is a risk that the ramp up to full production may take longer than planned and that the full production rate may not be achieved on a sustained and consistent basis. We are confident we will be able to solve challenges that may arise, but failure to do so would have a significant impact on our business.

Mine development

Mine development for construction and operation uses two basic approaches: for good quality, competent rock mass, drill and blast with conventional ground support is applied. Most permanent areas of the mine which contain the majority of the installed equipment and infrastructure are hosted in competent rock mass and are excavated and supported conventionally. The production tunnels immediately below the orebody are primarily in poor, weak rock mass and are excavated and supported using the New Austrian Tunnelling Method (NATM). NATM was adopted as the primary method of developing new production cross-cuts, replacing the former Mine Development System (MDS).

NATM, as applied at Cigar Lake, involves a multi-stage sequential mechanical excavation, extensive external ground support and a specialized shotcrete liner. The liner system incorporates yielding elements which permit controlled deformation required

2016 ANNUAL INFORMATION FORM    Page 38

to accommodate additive pressure from mining and ground freezing activities. The production tunnels have an inside diameter of five metres and are approximately circular in profile.

Since 2010, when the mine was dewatered, significant spalling, cracking and deterioration of the tunnel segments was identified in all four crosscuts excavated with the former MDS tunnel boring technique. Steps were taken to halt the deterioration and the affected area was reinforced. Two geotechnical consultants were retained to provide advice on the need for any possible further tunnel reinforcement or change in excavation and ground support methodology. Based on their recommendations, we have retrofitted the 781 and 737 production tunnels using NATM techniques, which effectively extended their life to allow the safe recovery of the ore above them. The remaining two MDS crosscuts at Cigar Lake were decommissioned and backfilled in 2016. They were originally intended to be used for ground freezing and are no longer required.

We plan our mine development to take place away from known groundwater sources whenever possible. In addition, we assess all planned mine development for relative risk and apply extensive additional technical and operating controls for all higher risk development.

Mine access

There are two main levels in the mine: the 480 and 500 metre levels. Both levels are located in the basement rocks below the unconformity. Mining is conducted from the 480 metre level which is located approximately 40 metres below the ore zone. The main underground processing and infrastructure facilities are located on this level. The 500 metre level is accessed via a ramp from the 480 metre level. The 500 metre level provides for the main ventilation exhaust drift for the mine, the mine dewatering sump and additional processing facilities. All construction required for production has been completed.

Processing

Cigar Lake ore slurry is processed in two steps:

High density ore slurry – The ore slurry produced by the jet boring mining system is pumped to Cigar Lake’s underground crushing, grinding and thickening facility. The resulting finely ground, high density ore slurry is pumped to surface storage tanks, thickened and loaded into truck mounted containers like the ones used at McArthur River.

Processing – Containers of ore slurry are trucked to AREVA’s McClean Lake mill, 70 kilometres to the northeast for processing. See Toll Milling Agreement below for a discussion of this arrangement.

Recovery and Metallurgical Testing

Extensive metallurgical test work was performed on core samples of Cigar Lake ore over a seven year period from 1992 to 1999. This work was used to design the McClean Lake mill circuits relevant to Cigar Lake ore and associated modifications. Samples used for metallurgical test work may not be representative of the deposit as a whole. Additional test work, completed in 2012 with drill core samples, verified that a high uranium recovery rate could be achieved regardless of the variability of the ore. Test work also concluded that more hydrogen gas evolution took place than previously anticipated, which resulted in modifications to the leaching circuit. Leaching modifications began in 2013 and were completed in 2014, with mill start-up in September 2014.

The 1992 – 1999 work was performed in France at AREVA’s (formerly Cogema) SEPA test centre. The results of this test work have provided the core process criteria for the design of the additions and modifications required at the McClean Lake mill for processing Cigar Lake ore. A range of ore grades, as high as 26% uranium, have been processed at the McClean Lake milling facility. Based on the test results and mill performance in 2015 and 2016, an overall uranium recovery of 98.5% is expected.

There is a risk that elevated arsenic concentration in the mill feed may result in increased leaching circuit solution temperatures. The leach process cooling system was updated in 2016 and testing confirmed solution temperature control. Leaching temperature will continue to be monitored in the future through the full range of arsenic grades within the orebody.

Tailings

Cigar Lake site does not have a tailings management facility. The ore is processed at the McClean Lake mill. See Toll Milling Agreement below for a discussion of the McClean Lake tailings management facility.

2016 ANNUAL INFORMATION FORM    Page 39

Waste

The waste rock piles are separated into three categories:

• clean rock – will remain on the mine site for use as aggregate for roads, concrete backfill and future site reclamation

• mineralized waste (>0.03% U₃O₈) – will be disposed of underground at the Cigar Lake mine

• waste with acid-generating potential – temporarily stored on engineered lined pads.

The latter two stockpiles are contained on lined pads; however, no significant mineralized waste has been identified in development to date.

Water discharged from the mine had historically been treated and released to Aline Creek. We began discharging treated water to Seru Bay in August 2013 following receipt of approval from the CNSC and the SMOE.

Production

In 2016, total packaged production from Cigar Lake was 17.3 million pounds U₃O₈; our share was 8.7 million pounds. The operation exceeded our forecast of 16 million pounds (100% basis) as a result of higher productivity and our intention to adjust annual production as necessary, based on our operating experience during ramp up. In 2017, we expect to reach full annual production of 18 million pounds (100% basis, 9 million pounds our share).

The mining plan is designed to extract all of the current mineral reserves. The following is a general summary of the production schedule guideline and parameters on a 100% basis:

Total mill production	•       211.8 million pounds of U3O8, based on current mineral reserves and an overall milling recovery of 98.5% •       Full annual production of 18 million pounds of U3O81
Total mine production	•       613 thousand tonnes of ore
Average annual mine production	•       100 to 200 tonnes per day during peak production, depending on ore grade
Average mill feed grade	•       15.9% U3O8

¹ In 2016, AREVA received approval to increase the annual production of the mill to 24 million pounds U₃O_8.

In alignment with our continued efforts to reduce costs, our 2017 production plan for the Cigar Lake mine includes an extended shut-down during the third quarter, which is expected to result in reduced flight and camp costs. The shut-down will consist of a four-week vacation period, followed by a two-week maintenance period with mine start-up planned before the end of the third quarter.

We have also planned additional actions for 2017, including a 10% reduction of the workforce at Cigar Lake, changes to the shift rotation schedule, and changes to the commuter flight services at the site, which are expected to further reduce costs and improve efficiency at the operation.

The operational changes we have made, and plan to make in 2017, which are intended to achieve cost savings and improve efficiency, carry with them increased risk of production disruption.

Commercial production

Commercial production signals a transition in the accounting treatment for costs incurred at the mine. Cigar Lake met all of the criteria for commercial production, including cycle time and process specifications, in the second quarter of 2015. Therefore, effective May 1, 2015, we began charging all production costs, including depreciation, to inventory and subsequently recognizing them in cost of sales as the product is sold.

Production Increase

In order to accommodate processing all of Cigar Lake’s current mineral reserves and ramp up to the target production rate of 18 million pounds U₃O₈ per year, the McClean Lake mill required expansion and a licence increase. In 2016, construction to expand the facility was completed and AREVA received CNSC approval to increase the mill’s licensed production capacity from 13 million pounds to 24 million pounds U₃O₈ per year. AREVA was also successful in negotiating a collective agreement with its union local in 2016.

2016 ANNUAL INFORMATION FORM    Page 40

Decommissioning and financial assurances

In 2002, our preliminary decommissioning plan for Cigar Lake was approved by the CNSC and the SMOE. We revised this plan and the accompanying preliminary decommissioning cost estimate when we renewed our federal licence in 2008. We revised this plan and the accompanying preliminary decommissioning cost estimate again when we received our operating licence in 2013.

We, along with our joint venture participants have letters of credit posted as financial assurances with the government of Saskatchewan, to cover the amount in the 2013 preliminary decommissioning cost estimate ($49 million).

The reclamation and remediation activities associated with waste rock and tailings at the McClean Lake mill are covered by the plans and cost estimates for this facility.

Water inflow and mine/mill development

Cigar Lake water inflow incidents

From 2006 through 2008, the Cigar Lake project suffered several setbacks as a result of three water inflow incidents. The first occurred in April of 2006 resulting in the flooding of the then partially completed Shaft No. 2. The two subsequent incidents involved inflows in the mine workings connected to Shaft No. 1 and resulted in flooding of the mine workings completed to that point in time. We developed and successfully executed recovery and remediation plans for all three inflows. Through 2010 and 2011, we developed a comprehensive plan and successfully proceeded with remediation to restore the underground workings at Cigar Lake. Successful re-entry into the main mine workings was achieved in early 2010 and work to secure the mine was completed in 2011.

The mine is fully remediated, and entered commercial production in 2015. Lessons learned from the inflows have been applied to the subsequent mine plan and development in order to reduce the risk of future inflows and improve our ability to manage water inflows.

Increased pumping capacity

In 2012, we increased the installed mine dewatering capacity to 2,500 cubic metres per hour. Mine water treatment capacity has been increased to 2,550 cubic metres per hour, and regulatory approval to discharge routine and non-routine treated water to Seru Bay is in place. As a result, we believe we have sufficient pumping, water treatment and surface storage capacity to handle the estimated maximum inflow.

Current status of development

Construction of all major permanent underground development and process facilities required for the duration of the mine life is complete. A number of underground access drifts and production cross-cuts remain to be driven as part of ongoing mine development to sustain production rates.

On surface, construction of all permanent infrastructure required to achieve nameplate capacity has been completed. As mine production progresses, a significant expansion to the surface freeze plant capacity will be required. It is planned to be completed in 2018.

The McClean Lake mill has been expanded to process and package all Cigar Lake ore. Construction of the expanded facility began in 2013 and was completed in 2016. Upgrades to the tails neutralization circuit were substantially completed in 2016.

During 2016, we:

• discontinued use of the underground freeze infrastructure and backfilled two redundant crosscuts related to underground freezing

• completed a freeze pad extension to enable surface freeze drilling to resume in 2017

• advanced the freeze plant expansion project through the prefeasibility stage.

In 2016, we began advancing two new production crosscuts tunnels to ensure we maintain continuous access to frozen ore inventory once mining in the current crosscuts is complete.

2016 ANNUAL INFORMATION FORM    Page 41

Toll milling agreement

The McClean Lake joint venture has agreed to process Cigar Lake’s ore slurry at its McClean Lake mill, according to the terms in its agreement with the CLJV: JEB toll milling agreement (effective January 1, 2002 and amended and restated effective November 30, 2011). The McClean Lake joint venture has agreed to dedicate at the McClean Lake mill the necessary mill capacity to process and package 18 million pounds of Cigar Lake uranium concentrate annually.

The CLJV will pay a toll milling fee and its share of milling expenses.

The McClean Lake mill started receiving Cigar Lake ore in March 2014 and produced its first drum of Cigar Lake yellowcake in October 2014. All of Cigar Lake’s ore slurry from current mineral reserves will be processed at the McClean Lake mill, operated by AREVA. The McClean Lake mill required modification and expansion to process and package all of Cigar Lake’s current mineral reserves. In 2014, the McClean Lake mill completed the first stage of mill upgrades. These initial modifications primarily focused on upgrades to the existing leach circuit and associated hydrogen mitigation systems to allow them to process high-grade ore.

In order to meet Cigar Lake’s ramp up schedule, McClean Lake needed to be expanded. These upgrades included: a second solvent extraction circuit to accommodate the increased uranium pregnant aqueous flows; an expanded tailings neutralization circuit; an additional crystallization plant to handle the increased ammonium sulphate flow; and new diesel generators. All upgrades are complete and the mill has sufficient capacity to meet Cigar Lake’s production schedule.

The McClean Lake joint venture commenced work in 2012 to optimize its tailings management facility to accommodate all of Cigar Lake’s current mineral reserves. Subject to a capped contribution of $4.6 million from the CLJV, the McClean Lake joint venture is responsible for the cost to optimize its tailings management facility.

The McClean Lake joint venture is responsible for all costs of decommissioning the McClean Lake mill. As well, the joint venture is responsible for the liabilities associated with tailings produced from processing Cigar Lake ore at the McClean Lake mill.

Regulatory approvals

There are three key permits that are required to operate the mine.

Operating and processing licences

Federally, Cigar Lake holds a “Uranium Mine Licence” from the CNSC with a corresponding Licence Conditions Handbook (LCH). Provincially, Cigar Lake holds an “Approval to Operate Pollutant Control Facilities” from the SMOE and a “Water Rights Licence to Use Surface Water and Approval to Operate Works” from the Saskatchewan Watershed Authority.

The CNSC licence was issued for an eight-year term in June 2013 and expires on June 30, 2021. The SMOE approval was renewed in 2012 and expires on December 31, 2017. The Saskatchewan Watershed Authority water rights licence was obtained in 1988 and was last amended in July 2011. It is valid for an undefined term.

The current Cigar Lake LCH authorizes an annual production rate up to 18 million pounds per year. In 2016, AREVA received approval to increase annual production of the McClean Lake mill to 24 million pounds per year.

Water treatment/effluent discharge system

The mine dewatering system was designed and constructed to handle both routine and non-routine water treatment and effluent discharge, and it has been approved and licensed by the CNSC and the SMOE.

We began discharging treated water to Seru Bay in August 2013 following the receipt of regulatory approvals.

We continue to optimize our mine water treatment process and system to attain the effluent concentrations that form part of the licensing basis, including detailed technical work as required.

2016 ANNUAL INFORMATION FORM    Page 42

Operating and capital costs

The following is a summary of the Cigar Lake operating and capital cost estimates for the remaining life of mine, stated in constant 2017 dollars and reflecting a forecast life-of-mine mill production of 211.7 million pounds:

Operating Costs ($Cdn million)	Total (2017 – 2028)
Cigar Lake Mining
Site administration	$	468.7
Mining costs		896.8
Process		231.3
Corporate overhead		105.0
Total mining costs	$	1,701.8
McClean Lake Milling
Administration	$	510.9
Milling costs		821.2
Corporate overhead		48.6
Toll milling		255.1
Total milling costs	$	1,635.8
Total operating costs	$	3,337.6
Total operating cost per pound U3O8	$	15.77

Note: presented as total cost to the CLJV (100% basis)

Operating costs consist of annual expenditures at Cigar Lake to mine the ore, treat the ore underground, including crushing, grinding and density control, followed by pumping the resulting slurry to surface for transportation to McClean Lake.

Operating costs at McClean Lake consist of the cost of offloading and leaching the Cigar Lake ore slurry into uranium solution and further processing into calcined U₃O₈ product.

Capital Costs ($Cdn million)	Total (2017 – 2028)
Cigar Lake Mine Development	$	367.3
Cigar Lake Mine Capital
Sustaining capital	$	99.7
Capacity replacement capital		234.3
Growth capital		—
Reclamation		1.0
Total mine capital	$	335.0
McClean Lake mill modifications	$	101.8
McClean Lake mill sustaining capital		179.6
Total mill capital	$	281.4
Total capital costs	$	983.7

Note: presented as total cost to the CLJV (100% basis)

Estimated capital costs to the CLJV include sustaining capital for Cigar Lake and McClean Lake mill, as well as underground development at Cigar Lake to bring mineral reserves into production. Overall, the largest capital cost at Cigar Lake is surface freeze drilling and brine distribution infrastructure. Other significant capital includes tunnel outfitting and mine development costs.

Our expectations and plans regarding Cigar Lake, including forecasts of operating and capital costs, production and mine life are forward-looking information, and are based specifically on the risks and assumptions discussed on pages 2 and 3. We may change operating or capital spending plans in 2017, depending on uranium markets, our financial position, results of

2016 ANNUAL INFORMATION FORM    Page 43

operation and other factors. Estimates of expected future production and capital and operating costs are inherently uncertain, particularly beyond one year, and may change materially over time.

Exploration, drilling, sampling, data quality and estimates

There are no historical estimates within the meaning of NI 43-101 to report. The Cigar Lake uranium deposit was discovered in 1981 by surface exploration drilling.

We focus most of our exploration activities on mineral lease ML 5521. AREVA is responsible for exploration activity on the 25 surrounding mineral claims. The data from the exploration program on the 25 mineral claims is not part of the database used for the estimate of the mineral resources and mineral reserves at Cigar Lake.

Exploration

After the 2006 water inflow events, it was recognized that more detailed geophysical information in the immediate deposit area was required. Since 2006, a number of geophysical surveys over the Cigar Lake deposit provided additional knowledge on geological structures and fault zones. In the fall of 2007, a supplementary geophysical program was conducted over a portion of the Phase 1 area of the deposit to identify major structures within the sandstone column. This has allowed for better mine planning and mitigation of potential risk.

Drilling

Surface drilling – mineral lease

The last diamond drillhole of the 1981 program was located south of Cigar Lake and was the discovery hole for the Cigar Lake uranium deposit. The deposit was subsequently delineated by surface drilling during the period 1982 to 1986, and followed by several small campaigns of drilling for geotechnical and infill holes to 2007. Additional diamond drilling campaigns over Phase 1 and Phase 2 were conducted by us between 2007 and 2012, which targeted a broad range of technical objectives, including geotechnical, geophysical, delineation and ground freezing. Since 2012, diamond drilling managed by us has mainly focused on surface ground freezing programs at Phase 1 until 2016 when we initiated a surface delineation program over Phase 2 of the deposit.

Average drill depths for surface delineation holes range from approximately 460 m to 500 m, with the majority of surface freezeholes drilled to a depth of approximately 462 m. Delineation drilling in the Phase 1 area has been done at a nominal drillhole fence spacing of 25 to 50 m (east-west), with holes at 20 to 25 m (north-south) spacing on the fences. However, the central portion of the Phase 1 deposit has had surface freezeholes installed at a nominal 6 × 6 m pattern.

The Phase 2 area was historically drilled at a nominal drillhole fence spacing of 200 m, with holes at 20 m spacing on the fences. An additional 32 infill drillholes were completed in 2011 and 2012 by Cameco for select areas of Phase 2, locally reducing the drillhole spacing down to an approximate 15 × 15 m pattern.

In 2015, a surface geotechnical drill program was conducted by us over the western portion of the Phase 1 deposit. Down-hole cross-well seismic was conducted within these boreholes in an attempt to image major fault structures and geotechnical characteristics of this portion of the deposit. The majority of exploration and delineation drilling completed by us on the surface of the mineral lease consists of wireline diamond drilling recovering NQ size (47.6 millimetres) drill core. All surface freezehole core is of PQ size (85.0 millimetres).

Drilling results have been used to delineate and interpret the 3-dimensional geometry of the mineralized areas, the litho-structural settings, the geotechnical conditions, and to estimate the distribution and content of uranium and other elements within the Phase 1 mineral resource and reserve and Phase 2 mineral resource.

In 2016, we temporarily ceased our surface freezehole drilling program. In 2017, we plan to resume it.

In 2016, we completed 29,000 metres of diamond drilling as part of the first year of a three-year, 65,000-metre surface drilling program to confirm and update mineral resources contained in Phase 2. The objective of the program is to complete a detailed geological and geotechnical interpretation, a mineral resource estimate, and a prefeasibility study for Phase 2.

Surface drilling – mineral claims

AREVA operates the exploration activities on the 25 mineral claims outside of ML 5521. Between 1981 and 2016, 116,527 metres of exploration drilling have been completed in 264 drill holes. Numerous airborne and ground geophysical surveys,

2016 ANNUAL INFORMATION FORM    Page 44

geochemical surveys and geological studies have been completed over the same period. In 2006, drilling discovered the Cigar East zone that is located outside ML 5521, approximately 650 metres east of Phase 1 mineralization. Further exploration has been conducted in this area since 2006 and has delineated a zone of unconformity style uranium mineralization approximately 210 metres in length and 30 metres in width. No mineral resource has been reported for the Cigar East zone.

Underground drilling – mineral lease

Diamond drilling from underground is primarily to ascertain rock mass characteristics in advance of development and mining. Cigar Lake Mining Corporation, the previous operator, and Cameco have conducted underground geotechnical drilling since 1989 at Cigar Lake, with the exception of the period from 2007 to 2009 during which time the mine was flooded.

Freezeholes were drilled from underground into the deposit for the purposes of freezing the ground prior to mining. A total of 83 holes at a spacing of 1.0 to 1.5 m were drilled in two periods of drilling in 1991 and again in 1999. Generally, these upward holes were rotary drilled holes from which no core was recovered; however, in a limited number of cases, core was recovered and sampled. Freezehole drilling started up again in late 2004 with the start of the construction phase of development. During this phase, over 300 freeze and temperature monitoring holes were drilled. The latter freezeholes were all drilled by percussion methods so no core was available for assays. No underground freezeholes have been drilled since 2006. None of the underground freezeholes are currently used for freezing purpose and for mineral resource and reserve estimation.

Sampling, analysis and data verification

Sampling

Vertical surface drilling generally represented the true thickness of the zone since the mineralization is flat. All holes were core drilled and gamma probed whenever possible. Cigar Lake uses a high-flux gamma probe designed and constructed by alphaNUCLEAR (aN), a member of the Cameco group of companies. This high-flux gamma probe utilizes two Geiger Müller tubes to detect the amount of gamma radiation emanating from the surroundings. The count rate obtained from the high-flux probe is compared against chemical assay results to establish a correlation to convert corrected probe count rates into equivalent %U₃O₈ grades. The consistency between probe data and chemical assays demonstrates that secular equilibrium exists within the deposit.

To validate the core depth, the down-hole gamma survey results were compared to hand-held scintillometer surveys on core. Down-hole gamma surveys and hand-held scintillometer surveys guided sampling of drill core for assay purposes. In the early stages of exploration drilling, sampling intervals were of various lengths, up to 50 centimetres, based on geological differences in the character of the mineralization. Starting in 1983, sampling intervals were fixed at a standard interval of 50 centimetres. All sample results have since been composited to the standard interval of 50 centimetres for mineral resources estimation purpose. On each of the upper and lower contacts of the mineralized zone, at least one additional 50 centimetres sample was taken to ensure that the zone was fully sampled at the 0.10% U₃O₈ cut-off. Starting in 1983, all drilling and sample procedures were standardized and documented. This gives us a high degree of confidence in the accuracy and reliability of results of all phases of the work.

When sampled, the entire core from each sample interval was taken for assay, except for some of the earliest sampling in 1981 and 1982. This reduced the sample bias inherent when splitting core. Core recovery throughout the deposit has generally been very good. However, in areas of poor core recovery uranium grade determination is based on radiometric probe results.

The typical sample collection process at our operations included the following procedures:

• marking the sample intervals on the core boxes, at the nominal 50 cm sample length, by a geologist

• collection of the samples in plastic bags, taking the entire core

• documentation of the sample location, including assigning a sample number, and description of the sample, including radiometric values from a hand-held device

• bagging and sealing, with sample tags inside bags and sample numbers on the bags

• placement of samples in steel drums for shipping.

Analysis

Since 2002, sample preparation has been done at SRC, which is independent of the participants of CLJV. It involves jaw crushing to 60% @ -2 mm and splitting out a 100 – 200 g sub-sample using a riffle splitter. The sub-sample is pulverized to

2016 ANNUAL INFORMATION FORM    Page 45

90% @ -106 microns using a puck and ring grinding mill. The pulp is then transferred to a labelled plastic snap top vial. Assaying by SRC involved digesting an aliquot of pulp in a 100 ml volumetric flask in concentrated 3:1 HCI:HNO3, on a hot plate for approximately one hour. The lost volume is then made up using deionized water prior to analysis by ICP-OES. Instruments used in the analysis are calibrated using certified commercial solutions.

Quality control and data verification

The quality assurance and quality control procedures used during the early drilling programs were typical for the time. The majority of uranium assays in the database were obtained from Loring Laboratories Ltd., which is independent of the participants of CLJV. For uranium assays up to 5% U₃O₈, 12 standards and two blanks were run with each batch of samples and for uranium assays over 5% U₃O₈, a minimum of four standards were run with each batch of samples.

More recent sample preparation and assaying is being completed under the close supervision of a qualified geoscientist at SRC and includes preparing and analysing standards, duplicates and blanks. A standard is prepared and analysed for each batch of samples and one out of every 40 samples is analysed in duplicate.

The original database, which forms part of the database used for the current mineral resource and mineral reserve estimates, was compiled by previous operators. Many of the original signed assay certificates are available and have been reviewed by Cameco geologists.

In 2013, Cigar Lake implemented an SQL server based centralized geological data management system to manage all drillhole and sample related data. All core logging, sample collection, downhole probing and sample dispatching activities are carried out and managed within this system. All assay and geochemical analytical results obtained from the external laboratory are uploaded directly into the centralized database, thereby mitigating potential for manual data transfer errors.

Additional data quality control measures taken include:

• entering surveyed drillhole collar coordinates and downhole deviations into the database and visually validating and comparing to the planned location of the holes

• random survey spot checks of drillhole collar locations, which were reviewed in detail if differences were encountered (non-material collar location discrepancies were identified late in the May 2012 Phase 2 mineral resource estimate process, and will be addressed in the next Phase 2 mineral resource estimate update)

• using a software program to check for data errors such as overlapping intervals and out of range values

• comparing downhole radiometric probing results with radioactivity measurements made on the core and drilling depth measurements

• validating uranium grades based on radiometric probing with sample assay results once available.

In 2014, we completed a thorough test program of our high-flux probes to demonstrate that consistent count rates were being obtained between probes. A total of eight surface freezeholes were probed multiple times with each probe to compare count rates. This test demonstrated that probes with the same equipment configurations and GM tubes produced very consistent count rates. The reliability of the probe readings was last confirmed in January 2015 by comparison with the results of an independent non-Cameco test using a series of probes built by a different manufacturer. For drillholes completed prior to 2011, the reliance on down-hole radiometric probing for determination of uranium grades for mineral resource estimation is minimal. Boreholes completed prior to 2011 were consistently sampled to obtain U₃O₈ chemical assays when uranium mineralization was encountered.

Sample security

Current sampling protocols dictate that all samples are collected and prepared under the close supervision of a qualified geoscientist in a restricted core processing facility. The core samples are collected and transferred from the core boxes to high-strength plastic sample bags, then sealed. The sealed bags are then placed in steel drums and shipped under the Transport of Dangerous Goods regulations through the Cameco warehouse facilities directly to the laboratory.

We are satisfied with all aspects of sample preparation and assaying. The sampling records are meticulously documented and samples are whole core assayed to reduce bias. The assaying was done to a high standard and the QA/QC procedures employed by the laboratories are adequate.

We are not aware of the historic security measures in place at the time of the deposit delineation – 1981 to 1986. Sample security is largely defined by regulation and, since 1987, all samples have been stored and shipped in compliance with

2016 ANNUAL INFORMATION FORM    Page 46

regulations. We believe that sample security was and is maintained throughout the process. There has been no indication of significant inconsistencies in the data used for the latest update of the mineral reserve and resource estimates.

Accuracy

We are satisfied with the quality of data obtained from the exploration and freezehole drilling programs and consider it valid for estimating mineral resources and mineral reserves. Results of the quality control measures and data verification procedures are reflected by the fact that since 2014, the mineral reserves estimate is within 7% on tonnage, 5% on grade and 2% on uranium content of the mill feed and inventories.

Mineral reserve and resource estimates

Please see page 74 for our mineral reserve and resource estimates for Cigar Lake.

2016 ANNUAL INFORMATION FORM    Page 47

Uranium – operating properties

	Inkai Inkai is a very significant uranium deposit, located in Kazakhstan. There are two production areas (blocks 1 and 2) and an exploration area (block 3). The operator is Joint Venture Inkai Limited Liability Partnership (JV Inkai), which we jointly own (60%) with Kazatomprom (40%). Inkai is one of our three material uranium properties.
Location	South Kazakhstan
Ownership1	60%
End product	uranium concentrate
Certifications	BSI OHSAS 18001
	ISO 14001 certified
Estimated mineral reserves	46.3 million pounds (proven and probable), average grade U3O8 – 0.06%
(our share) 2
Estimated mineral resources	81.3 million pounds (measured and indicated), average grade U3O8 – 0.06%
(our share) 3	86.2 million pounds (inferred), average grade U3O8 – 0.05%
Mining method	in situ recovery (ISR)
Licensed capacity	5.2 million pounds per year
	(our share 3.0 million pounds per year)
Total production 2009 to 2016	36.7 million pounds (100% basis)
2016 production	3.4 million pounds (5.9 million pounds 100% basis)
2017 forecast production	3.1 million pounds (5.4 million pounds 100% basis)
Estimated mine life	2030 (based on current licence term)
Estimated decommissioning cost	$10 million (US)
(100% basis)

¹  We signed an agreement with our partner Kazatomprom and JV Inkai to restructure and enhance Inkai. As part of the agreement, subject to closing, our ownership interest in JV Inkai will reduce to 40%. For more information, see Production expansion on page 55.

² Our share of uranium in the mineral reserves is based on our interest in planned production (57.5%) assuming an annual production rate of 5.2 million pounds, which differs from our ownership interest in JV Inkai (60%).

³ Our share of uranium in the mineral resources is based on our interest in potential production (57.5%), which differs from our ownership interest in JV Inkai (60%). Mineral resources that are not mineral reserves have no demonstrated economic viability.

2016 ANNUAL INFORMATION FORM    Page 48

Business structure

JV Inkai is a Kazakhstan limited liability partnership between two companies:

• Cameco – 60%

• Kazatomprom – 40% (a Kazakhstan Joint Stock Company owned by the Republic of Kazakhstan)

History

1976-78	•       Deposit is discovered •       Exploration drilling continues until 1996
1979	•       Regional and local hydrogeology studies begin •       Borehole tests characterize the four aquifers within the Inkai deposit (Uvanas, Zhalpak, Inkuduk and Mynkuduk)
1988	•       Pilot test in the northeast area of block 1 begins, lasts 495 days and recovers 92,900 pounds of uranium
1993	•       First Kazakhstan estimates of uranium resources for block 1
1996	•       First Kazakhstan estimates of uranium resources for block 2 •       Kazakhstan regulators registers JV Inkai, a joint venture among us, Uranerzbergbau-GmbH and KATEP
1997	•       Kazatomprom is established
1998	•       KATEP transfers all of its interest in JV Inkai to Kazatomprom •       We acquire all of Uranerzbergbau-GmbH’s interest in JV Inkai, increasing our interest to 66 2/3% •       We agree to transfer a 6 2/3% interest to Kazatomprom, reducing our holdings to a 60% interest
1999	•       JV Inkai receives a mining licence for block 1 and an exploration with subsequent mining licence for blocks 2 and 3 from the government of Kazakhstan
2000	•       JV Inkai and the government of Kazakhstan sign a subsoil use contract (called the resource use contract), which covers the licences issued in 1999 (see above)
2002	•       Pilot leach test in the north area of block 2 begins
2005	•       Construction of ISR commercial processing facility at block 1 begins
2006	•       Complete pilot leach test at block 2 •       Exploration-delineation drilling initiated at block 3
2007	•       Sign Amendment No.1 to the resource use contract, extending the exploration period at blocks 2 and 3
2008	•       Commission front half of the main processing plant in the fourth quarter, and begin processing solution from block 1
2009	•       Sign Amendment No. 2 to the resource use contract, which approves the mining licence at block 2, extends the exploration period for block 3 to July 13, 2010, and requires JV Inkai to adopt the new tax code and meet the Kazakhstan content thresholds for human resources, goods, works and services •       Commission the main processing plant, and started commissioning the first satellite plant
2010	•       Receive regulatory approval for commissioning of the main processing plant •       File a notice of potential commercial discovery at block 3 •       Receive approval in principle for the extension of block 3 exploration for a five-year appraisal period that expires July 2015, and an increase in annual production from blocks 1 and 2 to 3.9 million pounds (100% basis)
2011	•       Receive regulatory approval for commissioning of the first satellite plant •       Sign Amendment No. 3 to the resource use contract, which extends the exploration period for block 3 to July 2015 and provides government approval to increase annual production from blocks 1 and 2 to 3.9 million pounds (100% basis) •       Sign a memorandum of agreement with Kazatomprom to increase annual production from blocks 1 and 2 from 3.9 million pounds to 5.2 million pounds (100% basis)
2012	•       Sign a memorandum of agreement with Kazatomprom setting out the framework to increase annual production from blocks 1 and 2 to 10.4 million pounds (100% basis), to extend the term of JV Inkai’s resource use contract through 2045 and to cooperate on the development of uranium conversion capacity, with the primary focus on uranium refining rather than uranium conversion •       Start construction of a test leach facility at block 3
2013	•       Sign Amendment No. 4 to the resource use contract, which provides government approval to increase annual production from blocks 1 and 2 to 5.2 million pounds (100% basis)
2015	•       At block 3, construction of the test leach facility is completed and the pilot leach test initiated

2016 ANNUAL INFORMATION FORM    Page 49

2016 •       Sign an agreement with Kazatomprom and JV Inkai to restructure and enhance Inkai, subject to closing, increasing Kazatomprom’s holdings to a 60% interest and reducing our holdings to a 40% interest. For more information, see Production expansion on page 55   •       Sign Amendment No. 5 to the resource use contract, which extends the exploration period for block 3 to July 2018

Technical report

This project description is based on the project’s technical report: Inkai Operation, South Kazakhstan Oblast, Republic of Kazakhstan, dated March 23, 2017 (effective December 31, 2016). The report was prepared for us in accordance with NI 43-101, by or under the supervision of Alain G. Mainville, P. Geo., Darryl Clark, P. Geo., Stuart B. Soliz, P. Geo., and Robert J. Sumner, P. Eng. They are all qualified persons within the meaning of NI 43-101, but are not independent of us.

For information about environmental matters, see Safety, Health and the Environment starting on page 84. For a description of royalties payable to the government of Kazakhstan on the sale of uranium extracted from orebodies within the country and taxes, see pages 98 and 99.

The conclusions, projections and estimates included in this description are subject to the qualifications, assumptions and exclusions set out in the technical report. We recommend you read the technical report in its entirety to fully understand the project. You can download a copy from SEDAR (sedar.com) or from EDGAR (sec.gov).

For a description of risks that might affect access, title or the right or ability to perform work on the property, see Political risks starting at page 110, Regulatory risks starting at page 113, Environmental risks starting at page 114, and Legal and other risks starting at page 115.

About the Inkai property

Location

Inkai is located in the Suzak District of South Kazakhstan Oblast, Kazakhstan near the town of Taikonur, 350 kilometres northwest of the city of Shymkent and 155 kilometres east of the city of Kyzl-Orda. JV Inkai’s corporate office is located in Shymkent.

Access

The road to Taikonur is the primary road for transporting people, supplies and uranium product to and from the mine. It is a paved road that crosses the Karatau Mountains. Rail transportation is available from Almaty to Shymkent, then northwest to Shieli, Kyzl-Orda and beyond. A rail line also runs from the town of Dzhambul to a Kazatomprom facility to the south of Taikonur. From Almaty and Astana, commercial airline services are available to Shymkent and Kyzl-Orda.

Licences

JV Inkai holds the rights to three contiguous licence blocks, blocks 1, 2 and 3, based on the licences it has received and its resource use contract with the Kazakhstan government. JV Inkai has to meet certain obligations to maintain these rights. See page 53 for more information.

Surface Leases

A subsoil use contract gives the contractor a right to use the surface of the property while exploring, mining and reclaiming the land. However, this right must be set forth in a surface lease agreement with applicable local administrative authorities.

On a regular basis, JV Inkai obtains from local authorities the necessary surface lease agreements for new buildings and infrastructure. JV Inkai does not hold surface leases for the entire area subject to its licences for blocks 1, 2 and 3. It obtains them gradually only for surface area required for exploration, mining or construction of new infrastructure.

Environment, Social and Community Factors

Inkai lies in the Betpak Dala Desert, which has a semi-arid climate, minimal precipitation and relatively high evaporation. The average precipitation varies from 130 to 140 millimetres per year, and 22 to 40% of this is snow. The surface elevation within the Inkai property boundary ranges from 140 to 300 metres above mean sea level.

The area also has strong winds. The prevailing winds are northeast. Dust storms are common. The major water systems in the area include the Shu, Sarysu and Boktykaryn rivers.

2016 ANNUAL INFORMATION FORM    Page 50

The resource use contract prescribes that a certain level of employees be from Kazakhstan. See resource use contract on page 56 for more information.

JV Inkai must give preference to local producers, as long as the goods, works and services comply with the requirements of the respective project documentation and Kazakhstan law. See Kazakhstan government and legislation – local content – on page 59 for more information.

We are committed to building long-lasting and trusting relationships with the communities in which we operate. One of the ways we implement this commitment is through our Five Pillar CSR Strategy. For more information, see Sustainable development at page 82.

Geological Setting

South-central Kazakhstan geology is comprised of a large relatively flat basin of Cretaceous to Quaternary age continental clastic sedimentary rocks. The Chu-Sarysu basin extends for more than 1,000 kilometres from the foothills of the Tien Shan Mountains located on the south and southeast sides of the basin, and merges into the flats of the Aral Sea depression to the northwest. The basin is up to 250 kilometres wide, bordered by the Karatau Mountains on the southwest and the Kazakh Uplands on the northeast. The basin is composed of gently dipping to nearly flat-lying fluvial-derived unconsolidated sediments composed of inter-bedded sand, silt and local clay horizons.

The Cretaceous and Paleogene sediments contain several stacked and relatively continuous, sinuous “roll-fronts” or oxidation-reduction (redox) fronts hosted in the more porous and permeable sand and silt units. Several uranium deposits and active uranium ISR mines are located at these regional oxidation roll-fronts, developed along a regional system of superimposed mineralization fronts. The overall stratigraphic horizon of interest in the basin is approximately 200 to 250 metres in vertical section.

The Inkai deposit is one of these roll-front deposits. It is hosted within the Inkuduk and Mynkuduk Formations which comprise fine, medium and coarse-grained sands, gravels and clays. The redox boundary can be readily recognised in core by a distinct colour change from grey and greenish-grey on the reduced side to light-grey with yellowish stains on the oxidized side, stemming from the oxidation of pyrite to limonite.

The sands have high horizontal hydraulic conductivities. Hydrogeological parameters of the deposit play a key role in ISR mining. Studies and mining results indicate Inkai has favourable hydrogeological conditions for ISR mining.

Mineralization

Ten mineralized zones have been identified on blocks 1, 2 and 3, including four zones in the Mynkuduk horizon and six zones in the Inkuduk horizon.

Mineralization includes sooty pitchblende (85%) and coffinite (15%). The pitchblende occurs as micron-sized globules and spherical aggregates. The coffinite occurs as small crystals. Both uranium minerals are commonly associated with pyrite, and occur in pores on interstitial materials like clay minerals, as films around and in cracks within sand grains, and as replacements of rare organic matter.

Block 1

• Bulk of the uranium mineralization is contained in the Mynkuduk horizon and extends over more than 10 kilometres

• A small portion is contained in the Lower Inkuduk horizon

• Depth to the bottom of mineralization in the Mynkuduk horizon ranges from 450 to 528 metres. Average depth is 490 metres

• Mineralization width in plan view ranges from 40 to 600 metres and averages 250 metres

• Mineralized levels are generally at the lower part of the horizon, close to the Permian-Upper Cretaceous unconformity, but may also be found at a higher level, above the oxidized part of the Mynkuduk

Block 2

• Bulk of the mineralization is contained in the Lower and Middle Inkuduk horizons and extends over more than 35 kilometres

• A small portion is contained in the Mynkuduk horizon

• Depth to the bottom of mineralization in the Inkuduk horizons ranges from 300 to 426 metres. Average depth for Lower Inkuduk is 390 metres and 340 metres for the Middle Inkuduk

• Mineralization width for the Inkuduk horizon in plan view ranges from 40 to 1400 metres and averages 350 metres

2016 ANNUAL INFORMATION FORM    Page 51

Block 3

• Bulk of mineralization is contained in the Lower and Middle Inkuduk horizons and extends over more than 25 kilometres

• A small portion is contained in the Mynkuduk horizon

• Depth to the bottom of mineralization for the Middle Inkuduk horizon ranges from 278 to 415 metres. Average depth is 330 metres. Width in plan view ranges from 40 to 1600 metres and averages 350 metres

• Depth to the bottom of the Lower Inkuduk horizon is 331 to 445 metres. Average depth is 360 metres. Width in plan view ranges from 40 to 1600 metres and averages 250 metres

• Depth to the bottom of the Mynkuduk horizon is 360 to 516 metres. Average depth is 430 metres. Width in plan view ranges from 40 to 350 metres and averages 200 metres

Block 3 Appraisal Program

Exploration work on block 3 has identified extensive mineralization hosted by several horizons in the lower and middle parts of the Upper Cretaceous stratigraphic level and traced along 25 kilometres from block 2 of the Inkai deposit in the southwest through to the Mynkuduk deposit in the northeast. This discovery requires further assessment of its commercial viability. In February 2010, JV Inkai filed a notice of the discovery with regulators. A Cameco subsidiary funded JV Inkai’s block 3 work. JV Inkai is operating a test mine at block 3. The exploration period expires July 13, 2018 unless extended.

Approvals

In 2009, Amendment No. 2 to the resource use contract was signed, extending the exploration period at block 3 to July 13, 2010.

In 2011, Amendment No. 3 to the resource use contract was signed, giving JV Inkai government approval to carry out a five year assessment program that included delineation drilling, uranium resource estimation, construction and operation of a test leach facility, and completion of a feasibility study.

In 2012, JV Inkai received regulatory approval for the detailed block 3 delineation drilling and test leach work programs

In November 2016, Amendment No.5 to the resource use contract was signed, extending the exploration period at block 3 until July 13, 2018.

Appraisal work

Extensive exploration and delineation work was completed at block 3 by JV Inkai from 2006 to 2016. For information on drilling at block 3 see Exploration, drilling, sampling, data quality and estimates at page 60.

In 2011, JV Inkai began infrastructure development and completed engineering for a test leach facility for the block 3 assessment program. In addition, a preliminary estimate of the mineralization in the southwest corner of block 3 was prepared, which was reviewed and approved by the SRC.

In 2012, JV Inkai started drilling at test wellfields and started construction of the test leach facility.

In 2013, JV Inkai continued construction of the test leach facility and test wellfields, and started work on an appraisal of mineral potential according to Kazakhstan standards.

In 2014, JV Inkai continued construction of the test leach facility and test wellfields, and advanced work on a preliminary appraisal of the mineral potential according to Kazakhstan standards. An interim report on exploration results and estimate of the mineralization at block 3 was reviewed and conditionally approved by the SRC.

In 2015, JV Inkai completed construction of the test leach facility, began pilot production from test wellfields, as well as advanced work on a preliminary appraisal of the mineral potential of block 3 according to Kazakhstan standards.

At December 31, 2016, total production from test mining at block 3 was 865,000 pounds.

In February 2017, JV Inkai submitted an updated estimate of the in-situ uranium mineralization and a study, similar to a preliminary feasibility study, to the State Reserve Commission of Kazakhstan (SRC) for their approval. During 2017, JV Inkai plans to continue with pilot production from the test leach facility.

2016 ANNUAL INFORMATION FORM    Page 52

Deposit type

The Inkai uranium deposit is a roll-front type deposit. Roll-front deposits are a common example of stratiform deposits that form within permeable sandstones in localized reduced environments. The Cretaceous and Paleogene sediments contain several stacked and relatively continuous, sinuous “roll-fronts”, or redox fronts hosted in the more porous and permeable sand and silt units. Microcrystalline uraninite and coffinite are deposited during diagenesis by ground water, in a crescent-shaped lens that cuts across bedding and forms at the interface between oxidized and reduced ground. Sandstone host rocks are medium to coarse grained were highly permeable at the time of mineralization. There are several uranium deposits and active ISR uranium mines at these regional oxidation roll-fronts, developed along a regional system of superimposed mineralization fronts.

About the Inkai operation

Inkai is a developed producing property with sufficient surface rights to meet future mining operation needs for the current mineral reserves.

Licences

JV Inkai needs a number of licences to operate the Inkai mine:

• Licence Series AY 1370D, April 20, 1999, expires in April 2024

For uranium extraction in block 1 (16.6 square kilometres)

• Licence Series AY 1371D, April 20, 1999

For exploration and uranium extraction in block 2 (230 square kilometres) and in block 3 (240 square kilometres) (expires in April 2030) (the block 3 deposit exploration period has been extended to July 13, 2018).

Other material licences

• Licence for radioactive substances handling expires January 23, 2020

• Licence for operation of mining production and mineral raw material processing has an indefinite term

• Licence for transportation of radioactive substances within the territory of the Republic of Kazakhstan expires January 23, 2020

• Licence for dealing with radioactive wastes expires January 23, 2020

JV Inkai’s material environmental permits are described on page 57.

Infrastructure

JV Inkai facilities in Taikonur

• a camp for 429 employees, with catering and leisure facilities

• perimeter fence for security

• space for recreational activities

Block 1	Block 2	Block 3
•       main processing plant, which includes an ion exchange product recovery, drying and packaging facility that produces yellowcake •       administrative office, shops, garage, laboratory, emergency response building, waste disposal enclosures for low-level radioactive waste and domestic waste, engineering and construction offices •       food services facility •       holding ponds	•       satellite processing plant, which includes an ion exchange product recovery facility that produces uranium loaded ion exchange resin and eluate •       holding ponds •       office, shops, and a food services facility •       roads and power lines •       pipelines and header houses •       reagent storage tanks	•       test leach facility •       holding ponds •       office, shops, and a food services facility •       roads and power lines •       pipelines and header houses •       reagent storage tanks

2016 ANNUAL INFORMATION FORM    Page 53

•       roads and power lines

•       pipelines and header houses

•       reagent storage tanks

Water, power and heat

Groundwater wells provide sufficient water for all planned industrial activities. Shallow wells on site have potable water for use at the camp. The site is connected to the national power grid. In case of power outages, there are standby generators. Operations continue throughout the year despite cold winters (lows of -35°C) and hot summers (highs of +40°C).

Employees

Taikonur has a population of about 680 who are mainly employed in uranium development and exploration. Whenever possible, JV Inkai hires personnel from Taikonur and surrounding villages.

Mining

Mining at Inkai is based upon a conventional and well-established ISR process. ISR mining of uranium is defined by the International Atomic Energy Agency as:

“The extraction of ore from a host sandstone by chemical solutions and the recovery of uranium at the surface. ISR extraction is conducted by injecting a suitable leach solution into the ore zone below the water table; oxidizing, complexing and mobilizing the uranium; recovering the pregnant solutions through production wells; and finally, pumping the uranium bearing solution to the surface for further processing.”

ISR mining at Inkai is comprised of the following components to produce a uranium-bearing lixiviant (an aqueous solution which includes sulphuric acid), which goes to settling ponds and then to the processing plants for production as yellowcake:

• Determination of the GT (grade x thickness) cut-off for the initial design and the operating period. The design sets a lower limit to the pounds per pattern required to warrant installation of a pattern before funds are committed, and the operating cut-off applies to individual producer wells and dictates the lower limit of operation once a well has entered production.

• Preparation of a production sequence which will deliver the uranium-bearing lixiviant to meet production requirements, considering the rate of uranium recovery, lixiviant uranium head grades, and wellfield flow rates.

• Wellfield development practices, using an optimal pattern design, distribute barren lixiviant to the wellfield injectors, and then collect lixiviant, which carries the dissolved uranium, back to the processing plant or satellite plant, as the case may be.

The above factors are used to estimate the number of operating wellfields, wellfield patterns and wellfield houses over the production life. They also determine the unit cost of each of the mining components required to achieve the production schedule, including drilling, wellfield installation and wellfield operation.

There is ongoing wellfield development in both blocks 1 and 2 to support the current production plan.

Processing

As a result of extensive test work and operational experience, a very efficient process for uranium recovery has been established. The process consists of the following major steps:

• leach the uranium in-situ with a lixiviant

• recover it from solution with ion exchange resin

• elution of uranium from resin with ammonium nitrate

• precipitate uranium as yellowcake with hydrogen peroxide and ammonia

• thicken, dewater, and dry it

• package it in drums.

All plants load and eluate uranium from resin while the resulting eluate is converted to yellowcake at the main processing plant. Inkai is designed to produce a dry uranium product that meets the quality specifications of uranium refining and conversion facilities.

2016 ANNUAL INFORMATION FORM    Page 54

Production

Total production	Based on current mineral reserves, we expect Inkai to produce a total of 68.5 million pounds of U3O8 (100% basis, recovered after processing) over the life of the mine.
Average annual production	The main processing plant has the capacity to produce more than 5.2 million pounds per year (100% basis) depending on the grade of the production solution.

Production increases

In April 2011, JV Inkai received government approval to produce 3.9 million pounds per year (100% basis).

In August 2011, we entered into a memorandum of agreement (2011 MOA) with Kazatomprom to increase annual uranium production at Inkai from blocks 1 and 2 to 5.2 million pounds (100% basis). Under the 2011 MOA, our share of Inkai’s annual production is 2.9 million pounds with the processing plant near full capacity. We are also entitled to receive profits on 3.0 million pounds, defining the basis of our 57.5% share of mineral resources and mineral reserves (assuming annual production of 5.2 million pounds).

In December 2013, JV Inkai received government approval to produce 5.2 million pounds per year (100% basis).

During 2015, the subsoil use law in Kazakhstan was amended to allow producers to produce within 20% (above or below) their licensed production rate in a year.

Production expansion

In 2012, we entered into a memorandum of agreement (2012 MOA) with Kazatomprom setting out a framework to:

• increase Inkai’s annual production from blocks 1 and 2 to 10.4 million pounds (our share 5.2 million pounds) and sustain it at that level

• extend the term of JV Inkai’s resource use contract through 2045.

In May 2016, Cameco, Kazatomprom and JV Inkai signed an implementation agreement (Implementation Agreement) to restructure and enhance Inkai. The Implementation Agreement replaces the 2012 MOA and, subject to closing, provides as follows:

• JV Inkai will have the right to produce 4,000 tonnes of uranium (tU) (10.4 million pounds of U₃O₈) per year (Cameco’s share 4.2 million pounds), an increase from the current 5.2 million pounds (Cameco’s share 3.0 million pounds)

• JV Inkai will have the right to produce from blocks 1, 2 and 3 until 2045 (currently, the licence terms are to 2024 for block 1 and to 2030 for blocks 2 and 3)

• subject to further adjustments tied to the construction of a refinery as described below, Cameco’s ownership interest in JV Inkai will be adjusted to 40%, and Kazatomprom’s ownership interest in JV Inkai will be adjusted to 60%. However, the Implementation Agreement ensures that during production rampup, our share of annual production remains at 57.5% on the first 5.2 million pounds. As annual production increases above 5.2 million pounds, we will be entitled to 22.5% of any incremental production, to the maximum annual share of 4.2 million pounds. Once the rampup to 10.4 million pounds annually is complete, our interest in production will be adjusted to match our ownership interest at 40%.

• a governance framework that provides protection for Cameco as a minority owner of JV Inkai

• the current boundaries of blocks 1, 2 and 3 will be adjusted to match the agreed production profile for Inkai to 2045

• the loan made by a Cameco subsidiary to JV Inkai to fund exploration and evaluation of block 3 will be paid on a priority basis.

The Implementation Agreement is subject to obtaining all required government approvals, including certain amendments to JV Inkai’s resource use contract. In February 2017, we estimated it would take 10 to 18 months to obtain the required approvals. The government approvals are conditional upon submission of certain technical reports and other documents. The Implementation Agreement provides for annual production at the Inkai operation to be ramped up to 10.4 million pounds U₃O₈ over three years following receipt of required approvals. Since signing the agreement, we have been working with Kazatomprom and JV Inkai to prepare the various documents required to obtain the necessary government approvals.

The Implementation Agreement also provides that Cameco and Kazatomprom will complete a feasibility study for the purpose of evaluating the design, construction and operation of a uranium refinery in Kazakhstan with the capacity to produce 6,000 tU annually as uranium trioxide (UO₃). The Implementation Agreement includes provisions that would make Cameco’s proprietary uranium refining technology available to Kazatomprom on a royalty-free basis, and grants Kazatomprom a five-year option to

2016 ANNUAL INFORMATION FORM    Page 55

license Cameco’s proprietary uranium conversion technology for purposes of constructing and operating a UF₆ conversion facility in Kazakhstan.

If Cameco and Kazatomprom decide to build the refinery, the agreement also provides that Cameco’s ownership interest in JV Inkai will be increased to 42.5% upon commissioning of the refinery and, depending on the level of commercial support Cameco provides, may be increased further to 44%. Further, if Cameco and Kazatomprom decide to build the refinery, Kazatomprom will have the option to obtain UF₆ conversion services at Cameco’s Port Hope facility for a period of 10 years and receive other commercial support.

If the Implementation Agreement closes, the estimated mineral resources and mineral reserves of Inkai, and Cameco’s share of them, will change materially.

Sales

There are annual uranium sales contracts entered into between JV Inkai and a Cameco subsidiary to purchase Cameco’s share of Inkai production for each year, as well as similar contracts between JV Inkai and Kazatomprom. JV Inkai currently has no other forward-sales commitments for its uranium production.

In accordance with the Kazakhstan government’s resolution on uranium concentrate pricing regulations (effective February 3, 2011), product is currently purchased from JV Inkai at a price equal to the uranium spot price, less a 5% discount (maximum allowable).

Funding

We advanced funds for JV Inkai’s exploration and evaluation work on block 3. As of December 31, 2016, the principal and interest amounted to $168 million (US). Under the loan agreement, JV Inkai is to repay us from the sale of its production. On January 20, 2017, a payment of $30 million (US) was received.

Resource use contract

In 2000, JV Inkai and the Republic of Kazakhstan signed the resource use contract, which covers the licences issued in 1999 (resource use contract). JV Inkai has to meet the obligations under these licences and the resource use contract to maintain its rights to blocks 1, 2 and 3.

In 2007, JV Inkai and the relevant government authority signed Amendment No.1 to the resource use contract to extend the exploration period at blocks 2 and 3.

In 2009, JV Inkai and the relevant government authority signed Amendment No. 2 to the resource use contract, which:

• extended the exploration period for block 3 to July 13, 2010

• approved mining at block 2

• combined blocks 1 and 2 for mining and reporting purposes

• required JV Inkai to adopt the new tax code that took effect January 1, 2009

• required JV Inkai to adopt current Kazakhstan legal and policy requirements for subsoil users to procure goods, works and services under certain prescribed procedures and foster greater local content

• required a certain level of Kazakhstan employment by JV Inkai: over the life of the resource use contract, 100% of the workers, at least 70% of technical and engineering staff and at least 60% of the management staff must be from Kazakhstan.

In 2011, JV Inkai and the relevant government authority signed Amendment No. 3 to the resource use contract which:

• approved an increase to annual production from blocks 1 and 2 to 3.9 million pounds (100% basis)

• provided for a five-year appraisal period to July 2015 at block 3 to carry out delineation drilling, uranium resource estimation, construction and operation of a test leach facility, and to complete a feasibility study.

In 2013, JV Inkai and the relevant government authority signed Amendment No. 4 to the resource use contract, which approved an increase to annual production from blocks 1 and 2 to 5.2 million pounds (100% basis).

In November 2016, JV Inkai and the relevant government authority signed Amendment No. 5 to the resource use contract, which extended the exploration period at block 3 to July 13, 2018.

Work programs

JV Inkai is required to follow the work program appended to the resource use contract, which applies to mining operations over the life of the mine. To comply with the subsoil law, JV Inkai developed a life of mine work plan and submitted it to the relevant

2016 ANNUAL INFORMATION FORM    Page 56

government authority who approved it in April 2011 as part of the approval of Amendment No. 3 to the resource use contract (see Project documentation on page 59). An updated work program was submitted to the relevant government authority in 2012 in support of the Amendment No. 4 application and was approved in December 2013. An updated work program for the block 3 appraisal project was submitted to the relevant government authority and approved in connection with Amendment No. 5.

Environment

JV Inkai has to comply with environmental requirements during all stages of the operation, and develop an environmental impact assessment for examination by a state environmental expert before making any legal, organizational or economic decisions that could have an effect on the environment and public health.

Under Kazakhstan law, JV Inkai needs an environmental permit to operate. JV Inkai has a permit for environmental emissions and discharges for the operation that is valid until December 31, 2022. JV Inkai also holds certain water use permits.

Insurance

JV Inkai carries environmental insurance, as required by the resource use contract and environmental law, as well as civil liability insurance.

Decommissioning

JV Inkai’s decommissioning obligations are largely defined by the resource use contract. It has deposited the required contributions into a separate bank account as security to ensure it will meet its obligations. Contributions are capped at $500,000 (US). JV Inkai has funded the full amount.

Under the resource use contract, JV Inkai must submit a plan for decommissioning the mine to the government six months before mining activities are complete. It developed a preliminary decommissioning plan to estimate total decommissioning costs, and updates the plan every five years, or when there is a significant change at the operation that could affect decommissioning estimates. The preliminary decommissioning cost estimate is $10 million (US).

Groundwater is not actively restored post-mining in Kazakhstan. See page 86 for additional details.

Kazakhstan government and legislation

Subsoil law

The principal legislation governing subsoil exploration and mining activity in Kazakhstan is the Law on the Subsoil and Subsoil Use dated June 24, 2010, which took effect July 7, 2010, and was most recently amended in 2016 (the subsoil law). It replaces the Law on the Subsoil and Subsoil Use, dated January 27, 1996, as amended (the old law).

In general, JV Inkai’s licences are governed by the version of the subsoil law that was in effect when the licences were issued in April 1999, and new legislation applies to JV Inkai only if it does not worsen JV Inkai’s position. Changes to legislation related to national security, among other criteria, however, are exempt from the stabilization clause in the resource use contract. The Kazakhstan government interprets the national security exemption broadly.

The subsoil law defines the framework and procedures connected with the granting of subsoil rights, and the regulation of the activities of subsoil users. The subsoil, including mineral resources in their underground state, are Kazakhstan state property. Resources brought to the surface belong to the subsoil user, unless otherwise provided by contract or law. The state has pre-emptive and approval rights with regards to strategic deposits with some exceptions (for example, for inter-group transfers in certain circumstances), if a subsoil user transfers its subsoil rights or if there is a transfer (direct or indirect) of an ownership interest in a subsoil user.

Subsoil rights go into effect when a contract with the relevant government authority is finalized and registered. Pursuant to the subsoil law, the subsoil user is given, among other things, the exclusive right to conduct mining operations, to build production facilities, to freely dispose of its share of production and to negotiate extensions of the contract, subject to restrictions and requirements set out in the subsoil law.

Currently, the Ministry of Energy of the Republic of Kazakhstan is the competent authority under the subsoil law. We refer to the competent authority as the relevant government authority.

To date, the subsoil law has not had a significant impact on JV Inkai, however, we continue to assess the impact. Some of the general impact is described below.

2016 ANNUAL INFORMATION FORM    Page 57

Stabilization clause

The general stability provision has been changed in the subsoil law. Under the old law, changes in legislation that worsened the position of the subsoil user did not apply to resource use contracts signed before the changes were adopted.

Under the subsoil law, contracts are only protected from changes in legislation if the changes worsen the results of business operations of the subsoil user. The subsoil law expands the list of exceptions from stabilization to include taxation and customs regulation. These are in addition to exceptions in the old law for defence, national security, environmental protection and public health.

With the subsoil law, the government continues to weaken its stabilization guarantee. The government is broadly applying the national security exception to encompass security over strategic national resources.

Amendment No. 2 to the resource use contract eliminated the tax stabilization provision that applied to JV Inkai.

The resource use contract contains significantly broader stabilization provisions than the subsoil law, and these contract provisions currently apply to us.

Transfer of subsoil rights and pre-emptive rights

The subsoil law strengthens the state’s control over transactions involving subsoil rights and the direct and indirect ownership interests in a subsoil user.

Like the old law, transfers of subsoil rights, transfers of shares (interests) in subsoil users and the grant of security over subsoil rights require consent of the relevant government authority. The subsoil law expands the list of transactions that require consent and also spells out in more detail the circumstances, documentation and information that must accompany the request for consent. It also contains a new provision requiring notification to the relevant government authority within five business days of completion of the transaction.

Similar to the old law, the state has a priority right on terms not worse than those offered by other buyers. However, this right is now limited to strategic deposits. Inkai is a strategic deposit and therefore transactions related to it are subject to this pre-emptive right.

Failing to obtain the state’s waiver of its pre-emptive right or the consent of the relevant government authority or to provide the completion notification, are grounds for the state to invalidate a transfer.

Dispute resolution

The dispute resolution procedure in the subsoil law does not specifically disallow international arbitration. Instead it states that if a dispute related to a resource use contract cannot be resolved by negotiation, the parties can resolve the dispute according to the laws of Kazakhstan and international treaties ratified by the Republic of Kazakhstan.

The resource use contract allows for international arbitration. We believe the subsoil law does not affect this right.

Contract termination

Under the old law, the relevant government authority could terminate a contract if, for example, the subsoil user materially breached its obligations established by the contract or work program.

Under the subsoil law, the relevant government authority can unilaterally terminate a contract before it expires if:

• a subsoil user does not fix more than two breaches of its contractual obligations specified in a notice by the relevant government authority within a specific period (non-compliance with project documents are excluded from the grounds for termination)

• subsoil rights or direct and indirect ownership interests in a subsoil user are transferred without consent of the relevant government authority if such consent was required

• less than 30% of the financial obligations under a contract are fulfilled during the previous two years

• activities of a subsoil user exploring or developing a strategic deposit entails such changes in the economic interests of the Republic of Kazakhstan that it poses a threat to national security and the subsoil user does not satisfy the relevant government authority’s request to amend the contract in this regard.

Under the resource use contract, if JV Inkai breaches its obligations, the relevant government authority has to notify JV Inkai of the breach and provide a reasonable period for JV Inkai to fix the breach before it can terminate the contract. We believe that the terms of the resource use contract should continue to apply unless the state seeks to apply the national security or environmental protection exception to stabilization.

2016 ANNUAL INFORMATION FORM    Page 58

Local content

Subsoil users must procure goods, works and services in compliance with the subsoil law. Procurement is carried out through a specially created register of the goods, works and services and of the entities (producers) providing them. Subsoil users must give preference to local producers. This local content provision applies to JV Inkai. However, due to Kazakhstan’s accession to the World Trade Organization, it only applies to goods procured by JV Inkai until January 1, 2021 unless the resource use contract is amended earlier to remove this requirement.

Project documentation

Subsoil users who received subsoil rights before the subsoil law was introduced were required to:

• develop new project documentation to be approved by July 7, 2011

• develop a new work program in accordance with the project documentation to be approved by January 7, 2012.

JV Inkai submitted the required documentation and received approval of its new life of mine work program as part of the April 2011 approval of Amendment No. 3 to the resource use contract.

The subsoil law repealed the previous requirement for annual work plans. Instead, expected exploration and/or production volumes for each year are now set out in one work program. JV Inkai revised its work program to support the application to increase the annual production rate to 5.2 million pounds (100% basis).

Proposed new Subsoil Law

The Kazakhstan government is developing a new subsoil use law, the Subsoil and Subsoil Use Code, to replace the subsoil law. A draft dated December 22, 2016 has been issued and we are assessing the potential impact. The draft does not address licences issued and resource use contracts executed before its enactment. Therefore, the status of JV Inkai’s resource use contract and licences is unclear under the proposed law. Currently, the new law is expected to be enacted in the second half of 2017.

Strategic deposits

According to a governmental resolution On Determination of the List of Subsoil (Deposit) Areas having Strategic Importance dated August 13, 2009, 231 deposits are considered to be strategic deposits, including blocks 1, 2 and 3. The government re-approved this list in 2011 and Inkai’s blocks remained on it.

Under the subsoil law, if any actions by a subsoil user relating to a strategic deposit leads to a change in the economic interests of the Republic of Kazakhstan that creates a threat to national security, the relevant government authority has the right to demand a change to a contract that will restore the economic interests of the Republic of Kazakhstan. The parties have to agree on and make the change within a specific time period, or the relevant government authority can unilaterally terminate the contract.

Currency control regulations

In 2009, specific amendments to existing currency regulations were adopted. These amendments are aimed at preventing possible threats to the economic security and stability of the Kazakhstan financial system. The President of Kazakhstan was granted the power to establish a special currency regime that can:

• require foreign currency holders to deposit a certain portion of their foreign currency interest free with a resident Kazakhstan bank or the National Bank of Kazakhstan

• require the permission of the National Bank of Kazakhstan for currency transactions

• require the sale of foreign currency received by residents

• restrict overseas transfers of foreign currency.

While the special currency regime has not been imposed, it has the potential to prevent Kazakhstan companies, like JV Inkai, from being able to pay dividends to their shareholders abroad or repatriating any or all of its profits in foreign currency. It can also impose additional administrative procedures, and Kazakhstan companies could be required to hold a portion of their foreign currency in local banks.

In 2015, the National Bank of Kazakhstan amended the rules on currency operations. The rules regulate foreign exchange operations, the regime of foreign investments into Kazakhstan, and cross border and domestic currency payments.

A new law, Law on Currency Regulation and Currency Control, has been proposed and could be adopted by the end of 2017. The proposed law envisages substantial changes to Kazakhstan currency control. In particular, the contemplated changes relate to: amendment to the definition of Kazakhstan residents; the sale and purchase of currency by residents in the

2016 ANNUAL INFORMATION FORM    Page 59

Kazakhstan market; and requirements applicable to export/import operations with custom clearance in the territory of Kazakhstan.

The resource use contract grants JV Inkai a measure of protection from currency control regulations, granting it the right to freely transfer funds, in state and other currencies, inside and outside of Kazakhstan.

Operating and capital costs

The following is a summary of the operating and capital cost estimates for the remaining life of mine, stated in constant 2017 dollars and reflecting a forecast life-of-mine production of 68.5 million pounds U₃O₈ and a 245 Kazakhstan Tenge to 1 Cdn dollar exchange rate assumption:

Operating Costs ($Cdn million)	Total (2017 – 2030)
Site administration	$	233.9
Processing costs		148.8
Mining costs		300.0
Corporate overhead		188.0
Total operating costs	$	870.7
Average cost per pound U3O8	$	12.71

Note: presented as total cost to JV Inkai (100% basis)

Estimated operating costs consist of annual expenditures to mine and process the mineral reserves into U₃O₈ as well as site administration and corporate overhead costs.

Capital Costs ($Cdn million)	Total (2017 – 2030)
Total wellfield development	$	217.3
Construction and maintenance capital		55.5
Sustaining capital		24.1
Total capital costs	$	296.9

Note: presented as total cost to JV Inkai (100% basis)

Estimated capital costs includes wellfield development to mine the mineral reserves as well as construction and maintenance capital along with sustaining capital. Construction capital is heavily weighted to the first three years due to the major repairs and modernization planned for facilities at both block 1 and block 2. Pending closing of the Implementation Agreement, there are no other major construction projects anticipated.

Our expectations and plans regarding Inkai, including forecasts of operating and capital costs, production and mine life are forward-looking information, and are based specifically on the risks and assumptions discussed on pages 2 and 3. We may change operating or capital spending plans in 2017, depending on uranium markets, our financial position, results of operation and other factors. Estimates of expected future production and capital and operating costs are inherently uncertain, particularly beyond one year, and may change materially over time.

Exploration, drilling, sampling, data quality and estimates

Exploration at Inkai began in the 1970s and progressed until 1996. Since 2006, exploration and delineation drilling is conducted by JV Inkai, with the main focus block 3. From 2013 to 2016, delineation drilling was conducted at block 1 and block 2 to better establish the mineralization distribution and to support further development and wellfield design.

We have relied on historic data to estimate mineral reserves and resources at blocks 1 and 2. There are no historical mineral resources and reserves estimates within the meaning of NI 43-101 to report.

Exploration

Historical drilling

• Historical drilling at Inkai included 3,662 holes in blocks 1 and 2, and 489 in block 3.

2016 ANNUAL INFORMATION FORM    Page 60

• Drilling was vertical, on grids at prescribed density of 3.2 to 1.6-kilometre line spacing by 200 to 50-metre (3.2-1.6-kilometres × 200-50-metres) hole spacing. Additional drilling at grids of 800-400 × 200-50-metres and 200-100 × 50-25-metre grid increased the level of geological knowledge and confidence.

• Vertical holes were drilled with a triangular drill bit for use in unconsolidated formations down to a certain depth and the rest of the hole were cored.

Exploration drilling

• All exploration drilling has been confined to block 3 for delineation purposes.

• JV Inkai’s geology department oversees exploration, including the drilling program and management of contractors. JV Inkai has retained a contractor, JSC Volkovgeology, to direct and coordinate day-to-day drilling activities, and to ensure the quality of drilling, core recovery, surveying, geological logging, sampling, assaying and daily data processing.

• Drilling carried out at block 3 includes 489 holes drilled prior to JV Inkai obtaining its licenses and 3,748 holes drilled by JV Inkai from 2006 to 2013.

Recent activity

• The first phase of the drilling program, from 2006 through 2009, was focused on drilling on an 800 × 50-metre grid pattern in the southwestern part of block 3. The mineralization trends were also followed along the northwestern border using sparser drilling patterns.

• The second phase of the drilling program from 2010 to May 2011 was aimed at developing an 800 × 50-metre infill drilling grid pattern throughout the mineralized trend identified along the northwestern border, as well as the trend developed along the southern border. In addition, 200 × 50-metre grids patterns started to be developed in the southwestern part of block 3 with the goal of identifying sites and designing test wellfields in the Lower Inkuduk and Lower Mynkuduk horizons.

• The third phase of drilling started in June 2011 and continued until the end of 2013. Progressively tightening drilling grids (from 800 × 50-metre to 400 to 200 × 50-metre) were used to delineate mineralization in the southwestern, western and northern parts of block 3.

• In the fourth phase of drilling, during the second half of 2016, 69 infill delineation holes were drilled on a 100 × 50-metre grid on a selected site to confirm the continuity of the mineralization and its categorization. Thirty-nine drillholes were drilled at the ISR test wellfields to study the recovery process.

• Results of exploration and delineation:

• traced the presence of mineralization throughout block 3 with greater certainty. There was a significant increase in the extent of mineralization in many places, compared to results of predecessors, which were based on sparser historical drilling grids

• used the mineralization delineation from 800 × 50-metre and 200 × 50-metre drilling grids in block 3 to form a preliminary estimate of the mineralization for most of the area covered

• led to a preliminary estimate in 2011 of the mineralization on the southwestern corner of block 3, which was reviewed and approved by the SRC

• confirmed the need for additional drilling to close off mineralization zones and better define their morphology and continuity

• interim report in 2014 on exploration results and estimate of the mineralization at block 3, which was reviewed and conditionally approved by the SRC

• in February 2017, JV Inkai submitted an updated estimate of the in-situ uranium mineralization and a study, similar to a preliminary feasibility study, to the SRC for their approval.

Sampling analysis and data verification

Sampling

• Detailed sampling procedures guide the sampling interval within the mineralization. Holes are drilled on progressively tightening grids: 3.2 to 1.6 kilometre × 200-50 metre, 800-400 metre × 200-50 metre and 200-100 metre x 50-25 metre. When core recoveries are higher than 70% and radioactivity greater than 40 micro-roentgen per hour, core samples are taken at irregular intervals of 0.2 to 1.2 metres. Sample intervals are also differentiated by barren or low permeability material.

• The drillholes are nearly vertical and the mineralized horizons are almost horizontal, so the mineralized intercepts represent the true thickness of the mineralization.

2016 ANNUAL INFORMATION FORM    Page 61

• JV Inkai surveys the drillholes, logging radiometric, electrical (spontaneous potential and resistivity), caliper and deviation data.

• Sampling is done on half of the core. The average core sample length is 0.4 metres.

• The split core is tested for grainsize and carbonate content.

• Core recovery is considered acceptable given the unconsolidated state of the mineralized material.

Analysis

• The core samples for uranium and radium determination are ground down to 1.0 mm grain size and are further subdivided by one or three times quartering until the final representative weight of samples and duplicates is reached (0.2 kg).

• The laboratory tests for uranium and radium were performed by the Central Analytical Laboratory of JSC Volkovgeology, a company related to Kazatomprom, the other owner of JV Inkai. The laboratory is certified and licensed by the National Centre for Accreditation of the Republic of Kazakhstan.

• The uranium content was determined by using the X-ray fluorescence spectrum analysis. The radium content was determined from the gamma-X-ray spectrum analysis.

Quality control and data verification

• Our geoscientists, including a qualified person as such term is defined in NI 43-101, have witnessed core handling, logging and sampling used at the Inkai mine and consider the methodologies to be very satisfactory and the results representative and reliable.

• We confirmed the correlation between radioactive readings and calculated radium grades.

• We carried out a data verification process that validated the historic Kazakh mineral resource and reserve estimate.

• All drilling, logging, core drilling, and subsequent core splitting and assaying, were completed under the direction of various geological expeditions of the USSR Ministry of Geology and later under the supervision of JSC Volkovgeology.

• Based on numerous QA/QC controls applied by JSC Volkovgeology, including internal checks and inter-laboratory checks, the repeatability of the results for uranium and radium confirmed the accuracy required and no significant systematic deviations were found.

• Sampling and analysis procedures have been examined by an independent consultant and found to be detailed and thorough.

• Geologists with JV Inkai, JSC Volkovgeology, the State Reserves Commission and Cameco, have validated the current database a number of times. Our geologists consider it relevant and reliable.

• The findings are supported by results of the leach tests, past and recent production, and wellfield drilling results on blocks 1 and 2 and exploration drilling in block 3.

Sample security

JV Inkai’s current sampling process follows the strict regulations imposed by the Kazakhstan government, and includes the highest level of security measures, quality assurance and quality control. We have not been able to locate the documents describing sample security for historic Kazakhstan exploration on blocks 1, 2 and 3, but we believe the security measures taken to store and ship samples were of the same high quality.

Accuracy

We consider the historic Kazakhstan exploration data adequate and reliable for estimating mineral reserves and resources, based on our 2003 and 2007 validation of Kazakhstan estimated uranium reserves for blocks 1 and 2 (see sampling analysis and data verification) and actual production results over the last eight years.

Block 3 data has been validated by JSC Volkovgeology, JV Inkai and the SRC. Cameco has not reviewed their validation results. The block 3 data is currently being reviewed by Cameco.

Mineral reserve and resource estimates

Please see page 74 for our mineral reserve and resource estimates for Inkai.

2016 ANNUAL INFORMATION FORM    Page 62

Uranium – curtailed properties

	Rabbit Lake The Rabbit Lake operation, which opened in 1975, is the longest operating uranium production facility in North America, and the second largest uranium mill in the world.
Location	Saskatchewan, Canada
Ownership	100%
End product	uranium concentrate
ISO certification	ISO 14001 certified
Mine type	underground
Estimated mineral reserves	none
Estimated mineral resources	39.7 million pounds (indicated), average grade U3O8 – 0.79% 33.6 million pounds (inferred), average grade U3O8 – 0.58%
Mining method	vertical blasthole stoping
Licensed capacity	mill: maximum 16.9 million pounds per year; currently 11 million
Total production 1975 to 2016	203.3 million pounds
2016 production	1.1 million pounds
Estimated decommissioning cost	$203 million

Business structure

We own 100% of Rabbit Lake.

Given current market conditions, and our belief they will continue to be depressed in the near term, we suspended production at Rabbit Lake during the second quarter of 2016. Prior to the decision to suspend production, the operation produced 1.1 million pounds in 2016. The facilities are now in a state of safe and sustainable care and maintenance. The transition to care and maintenance was completed in August, 2016. Care and maintenance costs for the year totaled $55.4 million and related severance totaled $10.6 million.

A workforce of 120 (down from 650) continues to maintain the facilities, manage ongoing treatment and release of site water effluent, and sustain environmental monitoring and reclamation activities.

We are continually weighing the value of maintaining the operation in standby, against the cost of doing so. However, as long as production is suspended, we expect care and maintenance costs to range between $35 million and $40 million annually for the first few years. The estimated decommissioning cost for the Rabbit Lake mine site is $203 million, based on the preliminary decommissioning cost estimate that has been accepted by the Province of Saskatchewan and the CNSC.

2016 ANNUAL INFORMATION FORM    Page 63

Uranium – curtailed properties

	Smith Ranch-Highland & Satellite Facilities We operate Smith Ranch and Highland as a combined operation. Each has its own processing facility, but the Smith Ranch central plant currently processes all the uranium, including uranium from satellite facilities. The Highland plant is currently idle. Together, they form the largest uranium production facility in the United States.
Location	Wyoming, US
Ownership	100%
End product	uranium concentrate
ISO certification	ISO 14001 certified
Estimated mineral reserves	Smith Ranch-Highland: 1.1 million pounds (proven and probable), average grade U3O8 – 0.10%
	North Butte-Brown Ranch:
	0.7 million pounds (proven), average grade U3O8 – 0.08%
Estimated mineral resources	Smith Ranch-Highland:
	24.0 million pounds (measured and indicated), average grade U3O8 – 0.06%
	7.7 million pounds (inferred), average grade U3O8 – 0.05%
	North Butte-Brown Ranch:
	9.4 million pounds (measured and indicated), average grade U3O8 – 0.07%
	0.4 million pounds (inferred), average grade U3O8 – 0.07%
Mining method	in situ recovery (ISR)
Licensed capacity	wellfields: 3 million pounds per year processing plants: 5.5 million pounds per year including Highland mill
Total production 2002 to 2016	22.7 million pounds
2016 production	0.9 million pounds
2017 production outlook	0.4 million pounds
Estimated decommissioning cost	Smith Ranch-Highland $188 million (US); North Butte $23 million (US)

Business structure

We own 100% of Smith Ranch-Highland through a wholly owned subsidiary.

At Smith Ranch-Highland, production for the year was 36% lower than in 2015. Production was lower due to the decision to curtail production in 2016. The US Nuclear Regulatory Commission (NRC) license renewal for Smith Ranch-Highland continues. Although we have now taken actions to curtail production, due to the nature of ISR mining and our wellfield restoration requirements, production at Smith Ranch-Highland is expected to continue, but at a decreasing rate over time as head grade and flow rate declines. In 2017, we expect to produce 0.4 million pounds at Smith Ranch-Highland.

2016 ANNUAL INFORMATION FORM    Page 64

Uranium – curtailed properties

	Crow Butte Crow Butte was discovered in 1980 and began production in 1991.
Location	Nebraska, US
Ownership	100%
End product	uranium concentrate
ISO certification	ISO 14001 certified
Estimated mineral reserves	0.4 million pounds (proven), average grade U3O8 – 0.03%
Estimated mineral resources	15.2 million pounds (measured and indicated), average grade U3O8 – 0.25%
	2.9 million pounds (inferred), average grade U3O8 – 0.12%
Mining method	in situ recovery (ISR)
Licensed capacity	2.0 million pounds per year
(processing plant and wellfields)
Total production 2002 to 2016	10.4 million pounds
2016 production	0.3 million pounds
2017 production outlook	0.1 million pounds
Estimated decommissioning cost	$46 million (US)

Business structure

We own 100% of Crow Butte through a wholly owned subsidiary.

At Crow Butte, 2016 production was 25% lower than in 2015. Production was lower due to the decision to curtail production in 2016. The licence for Crow Butte has been renewed. Although we have now taken actions to curtail production, due to the nature of ISR mining and our wellfield restoration requirements, production at Crow Butte is expected to continue, but at a decreasing rate over time as head grade and flow rate declines. In 2017, we expect to produce 0.1 million pounds at Crow Butte.

2016 ANNUAL INFORMATION FORM    Page 65

Uranium – projects under evaluation

	Millennium Millennium is a uranium deposit in northern Saskatchewan. We are the operator.
Location	Saskatchewan, Canada
Ownership	69.9%
End product	uranium concentrate
Mine type	underground
Estimated mineral resources	53.0 million pounds (indicated), average grade U3O8 – 2.39%
(our share)	20.2 million pounds (inferred), average grade U3O8 – 3.19%

Business structure

Millennium is owned by a joint venture of two companies:

• Cameco – 69.9% (operator)

• JCU Exploration (Canada) Co. Ltd. – 30.1%

See our 2016 MD&A for more information.

2016 ANNUAL INFORMATION FORM    Page 66

Uranium – projects under evaluation

	Yeelirrie Yeelirrie is a near-surface calcrete-style deposit that is amenable to open pit mining techniques. We are the operator.
Location	Western Australia
Ownership	100%
End product	uranium concentrate
Mine type	open pit
Estimated mineral resources	128.1 million pounds (measured and indicated), average grade U3O8 – 0.15%

Business structure

Yeelirrie is owned 100% by a Cameco subsidiary.

See our 2016 MD&A for more information.

2016 ANNUAL INFORMATION FORM    Page 67

Uranium – projects under evaluation

	Kintyre Kintyre is a uranium deposit that is amenable to open pit mining techniques. We are the operator.
Location	Western Australia
Ownership	70%
End product	uranium concentrate
Mine type	open pit
Estimated mineral resources	37.5 million pounds (indicated), average grade U3O8 – 0.62%
(our share)	4.2 million pounds (inferred), average grade U3O8 – 0.53%

Business structure

Kintyre is owned by two companies:

• A Cameco subsidiary – 70%

• Mitsubishi Development Pty Ltd. – 30%

See our 2016 MD&A for more information.

2016 ANNUAL INFORMATION FORM    Page 68

Exploration

Our exploration program is directed at replacing mineral resources as they are depleted by our production, and is key to sustaining our business. We have maintained an active program even during periods of weak uranium prices, which has helped us secure land with exploration and development prospects that are among the best in the world, mainly in Canada, Australia, Kazakhstan and the US. Globally, our land holdings total 1.5 million hectares (3.6 million acres). In northern Saskatchewan alone, we have direct interests in 650,000 hectares (1.6 million acres) of land covering many of the most prospective exploration areas of the Athabasca Basin. Many of our prospects are located close to our existing operations where we have established infrastructure and capacity to expand.

For properties that meet our investment criteria, we may partner with other companies through strategic alliances, equity holdings and traditional joint venture arrangements. Our leadership position and industry expertise in both exploration and corporate social responsibility make us a partner of choice.

In 2016, we continued our exploration strategy of focusing on the most prospective projects in our portfolio. Exploration is key to ensuring our long-term growth.

2016 UPDATE

Brownfield exploration

Brownfield exploration is uranium exploration near our existing operations, and includes expenses for advanced exploration projects where uranium mineralization is being defined.

In 2016, we spent $10 million on brownfield exploration projects under evaluation in Saskatchewan and Australia. At Inkai and our US operations, we spent $2 million.

Regional exploration

We spent approximately $31 million on regional exploration programs (including support costs), primarily in Saskatchewan and Australia.

PLANNING FOR THE FUTURE

In 2017, we plan to reduce our regional exploration spending by over 35%. We will maintain an active uranium exploration program and continue to focus on our core projects in Saskatchewan under our long-term exploration strategy.

2016 ANNUAL INFORMATION FORM    Page 69

Fuel services – refining

	Blind River refinery Blind River is the world’s largest commercial uranium refinery, refining uranium concentrates from mines around the world into UO3.
Location	Ontario, Canada
Ownership	100%
End product	UO3
ISO certification	ISO 14001 certified
Licensed capacity	24 million kgU as UO3 per year (subject to the completion of certain equipment upgrades)
Estimated decommissioning cost	$48 million (this updated estimate is currently under regulatory review)

Markets

UO₃ is shipped to Port Hope for conversion into either UF₆ or UO₂.

Capacity

In 2012, the CNSC granted an increase to our annual licensed production capacity from 18 million kgU per year as UO₃ to 24 million kgU as UO₃, subject to the completion of certain equipment upgrades. These upgrades will be advanced based on market conditions.

Licensing

In February 2012, the CNSC granted our Blind River refinery a 10-year operating licence.

2016 ANNUAL INFORMATION FORM    Page 70

Fuel services – conversion and fuel manufacturing

	Port Hope conversion services Port Hope is the only uranium conversion facility in Canada and a supplier of UO2 for Canadian-made CANDU reactors.
Location	Ontario, Canada
Ownership	100%
End product	UF6, UO2
ISO certification	ISO 14001 certified
Licensed capacity	12.5 million kgU as UF6 per year
	2.8 million kgU as UO2 per year
Estimated decommissioning cost	$129 million

Cameco Fuel Manufacturing Inc. (CFM)

CFM produces fuel bundles and reactor components for CANDU reactors.

Location	Ontario, Canada
Ownership	100%
End product	CANDU fuel bundles and components
ISO certification	ISO 9001 certified, ISO 14001 certified
Licensed capacity	1.2 million kgU as UO2 as finished bundles
Estimated decommissioning cost	$21 million (this updated estimate is currently under regulatory review)

Port Hope and CFM produced a total of 8.4 million kgU in 2016, 13% lower than 2015. This was the result of our decision to decrease production in response to weak market conditions.

Licensing

In February 2012, the CNSC approved a ten-year licence for CFM.

In February 2017, the CNSC approved a ten-year operating licence for the Port Hope conversion facility.

Conversion services

At its UO₂ plant, Port Hope produces UO₂ powder, used to make pellets for Canadian CANDU reactors and CANDU reactors in other countries and blanket fuel for light water nuclear reactors.

At its UF₆ plant, Port Hope converts UO₃ to UF₆, and then ships it to enrichment plants primarily in the United States and Europe. There, it is processed to become low enriched UF₆, which is subsequently converted to enriched UO₂ and used as reactor fuel for light water nuclear reactors.

2016 ANNUAL INFORMATION FORM    Page 71

Anhydrous hydrofluoric acid (AHF) is a primary feed material for the production of UF₆. We have agreements with multiple suppliers of AHF to provide us with diversity of supply.

Environment

In 2009, we completed a site-wide environmental investigation of subsurface contamination and a site-wide risk assessment to identify contaminants that could pose a potential risk to the environment. We used the results to develop an environmental management plan to mitigate potential risks. In 2010, we enhanced the plan by adding a number of groundwater retrieval wells. In 2011, we added four additional wells. The environmental management plan met expectations between 2012 and 2015. In 2014, we also met with the regulatory authorities to discuss and agree on the adequacy of the environmental management plan and opportunities to further enhance it through the Vision in Motion project.

Port Hope conversion facility clean-up and modernization (Vision in Motion)

The Vision in Motion project completed the feasibility stage and was part of the CNSC licensing process in 2016. The project will now be undergoing detailed engineering work and some early implementation aspects in 2017.

Labour relations

In July 2016, our unionized employees at the Port Hope conversion facility accepted a three-year collective agreement. The previous agreement expired on June 30, 2016.

Fuel manufacturing

CFM’s main business is making fuel bundles for CANDU reactors. CFM presses UO₂ powder into pellets that are loaded into tubes, manufactured by CFM, and then assembled into fuel bundles. These bundles are ready to insert into a CANDU reactor core.

Manufacturing services agreements

A substantial portion of CFM’s business is the supply of fuel bundles to the Bruce Power A and B nuclear units in Ontario. We supply the UO₂ for these fuel bundles.

Labour relations

In June 2015, unionized employees at CFM’s operations in Port Hope and Cobourg, Ontario accepted a new three-year collective agreement. The previous agreement expired on June 1, 2015.

2016 ANNUAL INFORMATION FORM    Page 72

NUKEM GmbH

NUKEM is one of the world’s leading traders of uranium and uranium-related products.

Offices	Alzenau, Germany (NUKEM GmbH)
	Connecticut, US (subsidiary NUKEM Inc.)
Ownership	100%
Activity	trading of uranium and uranium-related products
2016 sales	7.1 million lbs U3O8
2017 forecast sales	5 to 6 million lbs U3O8

For more information, see our 2016 MD&A.

2016 ANNUAL INFORMATION FORM    Page 73

Mineral reserves and resources

Our mineral reserves and resources are the foundation of our company and fundamental to our success.

We have interests in a number of uranium properties. The tables in this section show our estimates of the proven and probable mineral reserves, and measured, indicated and inferred mineral resources at those properties. However, only three of the uranium properties listed in those tables are material uranium properties for us: McArthur River/Key Lake, Cigar Lake and Inkai.

We estimate and disclose mineral reserves and resources in five categories, using the definitions adopted by the Canadian Institute of Mining, Metallurgy and Petroleum, and in accordance with NI 43-101, developed by the Canadian Securities Administrators. You can find out more about these categories at www.cim.org.

About mineral resources

Mineral resources that are not mineral reserves have no demonstrated economic viability but do have reasonable prospects for eventual economic extraction. They fall into three categories: measured, indicated and inferred. Our reported mineral resources do not include mineral reserves.

• Measured and indicated mineral resources can be estimated with sufficient confidence to allow the appropriate application of technical, economic, marketing, legal, environmental, social and governmental factors to support evaluation of the economic viability of the deposit.

• measured resources: we can confirm both geological and grade continuity to support detailed mine planning

• indicated resources: we can reasonably assume geological and grade continuity to support mine planning

• Inferred mineral resources are estimated on the basis of limited geological evidence and sampling, sufficient to imply but not verify geological and grade continuity. They have a lower level of confidence than that applied to an indicated mineral resource and must not be directly converted to a mineral reserve. We do not have enough confidence to evaluate their economic viability in a meaningful way. You should not assume that all or any part of an inferred mineral resource will be upgraded to an indicated or measured mineral resource, but it is reasonably expected that the majority of inferred mineral resources could be upgraded to indicated mineral resources with continued exploration.

Our share of uranium in the mineral resource tables below is based on our respective ownership interests, except for Inkai which is based on our interest in potential production (57.5%), which differs from our ownership interest in JV Inkai (60%).

About mineral reserves

Mineral reserves are the economically mineable part of measured and/or indicated mineral resources demonstrated by at least a preliminary feasibility study. The reference point at which mineral reserves are defined is the point where the ore is delivered to the processing plant, except for ISR operations where the reference point is where the mineralization occurs under the existing or planned wellfield pattern. Mineral reserves fall into two categories:

• proven reserves: the economically mineable part of a measured resource for which at least a preliminary feasibility study demonstrates that, at the time of reporting, economic extraction could be reasonably justified.

• probable reserves: the economically mineable part of a measured and/or indicated resource for which at least a preliminary feasibility study demonstrates that, at the time of reporting, economic extraction could be reasonably justified.

We use current geological models, constant dollar average uranium prices per operation of $40 to $51 (US) per pound U₃O₈, depending on the varying production schedules and the annual forecast realized prices, and current or projected operating costs and mine plans to estimate our mineral reserves, allowing for dilution and mining losses. For ISR operations, dilution does not impact the tonnage and mining losses are included in the metallurgical recovery. We apply our standard data verification process for every estimate.

Our share of uranium in the mineral reserves table below is based on our respective ownership interests, except for Inkai which is based on our interest in planned production (57.5%) assuming an annual production rate of 5.2 million pounds, which differs from our ownership interest in JV Inkai (60%).

2016 ANNUAL INFORMATION FORM    Page 74

Qualified persons

The technical and scientific information discussed in this AIF, including mineral reserve and resource estimates, for our material properties (McArthur River/Key Lake, Cigar Lake and Inkai) was approved by the following individuals who are qualified persons for the purposes of NI 43-101:

McArthur River/Key Lake

• Alain G. Mainville, director, mineral resources management, Cameco

• Greg Murdock, operations manager, McArthur River, Cameco

• Thomas Saruchera, technical superintendent, Key Lake, Cameco

• Baoyao Tang, technical superintendent, McArthur River, Cameco

• Leslie D. Yesnik, general manager, mining operations, Key Lake and McArthur River, Cameco

Cigar Lake

• Scott Bishop, manager, technical services, Cameco

• Alain G. Mainville, director, mineral resources management, Cameco

• Leslie D. Yesnik, general manager, mining operations, Key Lake and McArthur River, Cameco

Inkai

• Darryl Clark, managing director, Cameco Kazakhstan LLP

• Alain G. Mainville, director, mineral resources management, Cameco

• Stuart B. Soliz, principal geologist, Cameco Resources

• Robert J. Sumner, principal metallurgist, technical services, Cameco

Important information about mineral reserve and resource estimates

Although we have carefully prepared and verified the mineral reserve and resource figures in this document, the figures are estimates, based in part on forward-looking information.

Estimates are based on our knowledge, mining experience, analysis of drilling results, the quality of available data and management’s best judgment. They are, however, imprecise by nature, may change over time, and include many variables and assumptions including:

• geological interpretation

• extraction plans

• commodity prices and currency exchange rates

• recovery rates

• operating and capital costs.

There is no assurance that the indicated levels of uranium will be produced, and we may have to re-estimate our mineral reserves based on actual production experience. Changes in the price of uranium, production costs or recovery rates could make it unprofitable for us to operate or develop a particular site or sites for a period of time. See page 1 for information about forward-looking information, and page 100 for a discussion of the risks that can affect our business.

Please see pages 80, 81 and 82 for the specific assumptions, parameters and methods used for the McArthur River, Cigar Lake and Inkai mineral reserve and resource estimates.

Our estimate of mineral resources and mineral reserves may be materially affected by the occurrence of one or more of the risks described under the heading Reserve and resource estimates are not precise on page 107. In addition to those risks, our estimates of mineral resources and mineral reserves for certain properties may be materially affected by the occurrence of one or more of the following risks or factors:

McArthur River and Cigar Lake Mineral Resource and Reserve Estimates

• Water inflows – see Flooding at our Saskatchewan mines at page 101

• Technical challenges – see Technical challenges at Cigar Lake and McArthur River at page 102

2016 ANNUAL INFORMATION FORM    Page 75

Inkai Mineral Resource and Reserve Estimates

• The closing of the Implementation Agreement – see page 55

• Political risks – see page 110

The extent to which our estimates of mineral resources and mineral reserves may be affected by the foregoing issues could vary from material gains to material losses.

Important information for US investors

While the terms measured, indicated and inferred mineral resources are recognized and required by Canadian securities regulatory authorities, the US Securities and Exchange Commission (SEC) does not recognize them. Under US standards, mineralization may not be classified as a ‘reserve’ unless it has been determined at the time of reporting that the mineralization could be economically and legally produced or extracted. US investors should not assume that:

• any or all of a measured or indicated mineral resource will ever be converted into proven or probable mineral reserves

• any or all of an inferred mineral resource exists or is economically or legally mineable, or will ever be upgraded to a higher category. Under Canadian securities regulations, estimates of inferred resources may not form the basis of feasibility or pre-feasibility studies. Inferred resources have a great amount of uncertainty as to their existence and economic and legal feasibility.

The requirements of Canadian securities regulators for identification of “reserves” are also not the same as those of the SEC, and mineral reserves reported by us in accordance with Canadian requirements may not qualify as reserves under SEC standards.

Other information concerning descriptions of mineralization, mineral reserves and resources may not be comparable to information made public by companies that comply with the SEC’s reporting and disclosure requirements for US domestic mining companies, including Industry Guide 7.

Mineral reserves

As at December 31, 2016 (100% basis – only the second last column shows Cameco’s share)

Proven and probable (tonnes in thousands; pounds in millions)

			Proven						Probable						Total mineral reserves
Property	Mining method		Tonnes		Grade %U3O8		Content (M lbs U3O8)		Tonnes		Grade %U3O8		Content (M lbs U3O8)		Tonnes		Grade %U3O8		Content (M lbs U3O8)		Cameco’s share of content (M lbs U3O8)		Metallurgical recovery (%)
Cigar Lake		underground		209.6		19.86		91.8		403.8		13.84		123.2		613.4		15.90		215.0		107.6		98.5
Key Lake		open pit		61.1		0.52		0.7		—		—		—		61.1		0.52		0.7		0.6		98.7
McArthur River		underground		1,184.9		9.57		250.1		562.5		9.64		119.5		1,747.4		9.60		369.7		258.1		98.7
Crow Butte		ISR		583.0		0.03		0.4		—		—		—		583.0		0.03		0.4		0.4		85
Inkai		ISR		33,193.4		0.07		48.6		30,717.0		0.05		32.0		63,910.3		0.06		80.6		46.3		85
North Butte-Brown Ranch		ISR		364.5		0.08		0.7		—		—		—		364.5		0.08		0.7		0.7		60
Smith Ranch-Highland		ISR		444.7		0.10		1.0		34.2		0.13		0.1		478.9		0.10		1.1		1.1		80
Total				36,041.2		—		393.3		31,717.5		—		274.8		67,758.7		—		668.1		414.7		—

Notes

ISR – in situ recovery

Estimates in the above table:

• use constant dollar average uranium prices per property, varying over time, from $40 to $51 (US)/lb U₃O₈

• are based on an average exchange rate of $1.00 US=$1.20 to $1.25 Cdn and 245 Kazakhstan Tenge to $1.00 Cdn.

Totals may not add up due to rounding.

2016 ANNUAL INFORMATION FORM    Page 76

Metallurgical recovery

We report mineral reserves as the quantity of contained ore supporting our mining plans, and provide an estimate of the metallurgical recovery for each uranium property. The estimate of the amount of valuable product that can be physically recovered by the metallurgical extraction process is obtained by multiplying quantity of contained metal (content) by the planned metallurgical recovery percentage. The content and our share of uranium in the table above are before accounting for estimated metallurgical recovery.

Changes this year

The table below shows the change in our share of mineral reserves for each property in 2016. The change was primarily the result of:

• new and updated mining plans for two zones at McArthur River, which contributed 8 million pounds to proven mineral reserves and 33 million pounds to probable mineral reserves

• revised mineral reserve and resource classifications in Kazakhstan, which resulted in an increase of 27 million pounds in proven mineral reserves, and a decrease of 20 million pounds in probable mineral reserves

partially offset by:

• production, which removed 28 million pounds from our mineral inventory

• conversion of 16 million pounds of reserves to resources, due to economic considerations related to our curtailed US and Rabbit Lake operations.

(thousands of pounds U3O8)	December 31, 2015		Throughput(1)		Additions (deletions)(2)		December 31, 2016
Proven mineral reserves
Cigar Lake		54,696		-8,749		-30		45,917
Crow Butte		700		-264		11		447
Inkai		1,207		-96		26,842		27,953
Key Lake		584						584
McArthur River		177,003		-9,320		6,929		174,612
North Butte-Brown Ranch		1,152		-433		-39		680
Rabbit Lake		79		-79
Smith Ranch-Highland		2,459		-786		-708		965
Total		237,880		-19,727		33,005		251,158
Probable mineral reserves
Cigar Lake		56,162				5,477		61,639
Inkai		41,894		-3,912		-19,592		18,390
McArthur River		57,926		-3,266		28,789		83,449
North Butte-Brown Ranch		692				-692
Rabbit Lake		11,843		-950		-10,893
Smith Ranch-Highland		3,758				-3,661		97
Total		172,275		-8,128		-572		163,575
Total mineral reserves		410,155		-27,855		32,433		414,733

Notes

(1) Throughput corresponds to mill feed. The difference between 2016 mill feed and Cameco’s share of pounds U₃O₈ produced in 2016 is due to mill recovery, mill inventory and processing of low-grade material.

(2) Changes in reserves or resources, as applicable, include reassessment of geological data, results of information provided by mining and milling, and reclassification of reserves or resources, as applicable.

(3) Crow Butte, Three Crow, Marsland and North Trend are reported under Crow Butte.

2016 ANNUAL INFORMATION FORM    Page 77

Mineral resources

As at December 31, 2016 (100% basis – only the last column shows Cameco’s share)

Measured and indicated (tonnes in thousands; pounds in millions)

			Measured						Indicated						Total measured and indicated
Property	Mining method		Tonnes		Grade % U3O8		Content (M lbs  U3O8)		Tonnes		Grade % U3O8		Content (M lbs  U3O8)		Content (M lbs  U3O8)		Cameco’s share (M lbs U3O8)
Cigar Lake		underground		1.3		4.71		0.1		235.7		16.24		84.4		84.5		42.3
Kintyre		open pit		—		—		—		3,897.7		0.62		53.5		53.5		37.5
McArthur River		underground		43.4		4.36		4.2		16.8		1.79		0.7		4.8		3.4
Millennium		underground		—		—		—		1,442.6		2.39		75.9		75.9		53.0
Wheeler River		underground		—		—		—		166.4		19.13		70.2		70.2		21.1
Rabbit Lake		underground		—		—		—		2,281.5		0.79		39.7		39.7		39.7
Tamarack		underground		—		—		—		183.8		4.42		17.9		17.9		10.3
Yeelirrie		open pit		27,172.9		0.16		95.9		12,178.3		0.12		32.2		128.1		128.1
Crow Butte		ISR		1,418.2		0.21		6.6		1,354.9		0.29		8.6		15.2		15.2
Gas Hills - Peach		ISR		687.2		0.11		1.7		3,626.1		0.15		11.6		13.3		13.3
Inkai		ISR		34,885.4		0.07		55.3		77,914.4		0.05		86.0		141.3		81.3
North Butte-Brown Ranch		ISR		604.2		0.08		1.1		5,530.3		0.07		8.4		9.4		9.4
Ruby Ranch		ISR		—		—		—		2,215.3		0.08		4.1		4.1		4.1
Shirley Basin		ISR		89.2		0.16		0.3		1,638.2		0.11		4.1		4.4		4.4
Smith Ranch - Highland		ISR		3,354.0		0.10		7.1		14,338.1		0.05		16.9		24.0		24.0
Total				68,225.8		—		172.3		127,020.2		—		514.1		686.4		487.00

Inferred (tonnes in thousands; pounds in millions)

Property	Mining method	Tonnes		Grade % U3O8		Content (M lbs  U3O8)		Cameco’s share (M lbs U3O8)		Notes ISR – in situ recovery Mineral resources do not include amounts that have been identified as mineral reserves. Mineral resources do not have demonstrated economic viability. Totals may not add up due to rounding.
Cigar Lake	underground		128.4		7.36		20.8		10.4
Fox Lake	underground		386.7		7.99		68.1		53.3
Kintyre	open pit		517.1		0.53		6.0		4.2
McArthur River	underground		95.9		5.20		11.0		7.7
Millennium	underground		412.4		3.19		29.0		20.2
Wheeler River	underground		842.5		2.38		44.1		13.2
Rabbit Lake	underground		2,631.4		0.58		33.6		33.6
Tamarack	underground		45.6		1.02		1.0		0.6
Crow Butte	ISR		1,135.2		0.12		2.9		2.9
Gas Hills - Peach	ISR		3,307.5		0.08		6.0		6.0
Inkai	ISR		151,583.1		0.05		149.9		86.2
North Butte-Brown Ranch	ISR		294.5		0.07		0.4		0.4
Ruby Ranch	ISR		56.2		0.14		0.2		0.2
Shirley Basin	ISR		508.0		0.10		1.1		1.1
Smith Ranch - Highland	ISR		6,861.0		0.05		7.7		7.7
Total			168,805.5		—		382.0		247.9

2016 ANNUAL INFORMATION FORM    Page 78

Changes this year

The table below shows the change in our share of mineral resources for each property in 2016. The change was mostly the result of:

• revised mineral reserve and resource classifications in Kazakhstan, which resulted in increases of 32 million pounds and 19 million pounds in measured and indicated resources respectively, and a decrease of 58 million pounds in inferred resources

• surface delineation drilling at Cigar Lake, resulting in the re-classification of 41 million pounds from inferred to indicated mineral resources

• delineation drilling at McArthur River to increase geological knowledge, moving 33 million pounds from the inferred to the indicated mineral resources category, subsequently converted to probable reserves

• the reclassification of 16 million pounds of reserves as 18 million pounds of resources, due to economic considerations related to our curtailed US and Rabbit Lake operations.

(thousands of pounds U3O8)	December 31, 2015		Additions (deletions)		December 31, 2016
Measured mineral resources
Cigar Lake		181		-113		68
Crow Butte		6,595				6,595
Gas Hills – Peach		1,667				1,667
Inkai				31,792		31,792
McArthur River		3,660		-744		2,916
North Butte-Brown Branch		400		692		1,092
Shirley Basin		304				304
Smith Ranch-Highland		2,909		4,224		7,133
Yeelirrie		92,382		3,567		95,949
Total		108,098		39,418		147,516
Indicated mineral resources
Cigar Lake		1,468		40,742		42,210
Crow Butte		8,599				8,599
Gas Hills – Peach		11,632				11,632
Inkai		30,256		19,216		49,472
Kintyre		37,464				37,464
McArthur River		222		239		461
Millennium		53,040				53,040
North Butte – Brown Ranch		8,357				8,357
Wheeler River		21,060				21,060
Rabbit Lake		26,707		12,958		39,665
Ruby Ranch		4,078				4,078
Shirley Basin		4,085				4,085
Smith Ranch-Highland		16,901				16,901
Tamarack		10,288				10,288
Yeelirrie		34,935		-2,734		32,201
Total		269,092		70,421		339,513
Total measured and indicated mineral resources		377,190		109,839		487,029

2016 ANNUAL INFORMATION FORM    Page 79

(thousands of pounds U3O8)	December 31, 2015		Additions (deletions)(1)		December 31, 2016
Inferred mineral resources
Cigar Lake		51,592		-41,170		10,422
Crow Butte		2,893				2,893
Fox Lake		53,284				53,284
Gas Hills – Peach		6,041				6,041
Inkai		144,333		-58,133		86,200
Kintyre		4,194				4,194
McArthur River		40,898		-33,204		7,694
Millennium		20,243				20,243
North Butte/Brown Ranch		422				422
Wheeler River		13,241				13,241
Rabbit Lake		33,707		-60		33,647
Ruby Ranch		167				167
Shirley Basin		1,132				1,132
Smith Ranch-Highland		7,728				7,728
Tamarack		591				591
Total inferred mineral resources		380,466		-132,567		247,899

Notes

(1) Additions and (deletions) come from reassessing geological data, gathering data from drilling, mining and milling, and reclassifying material as either a mineral reserve or a mineral resource, as applicable.

(2) Mineral resources do not include amounts that have been identified as mineral reserves.

Key assumptions, parameters and methods

McArthur River

Key assumptions

• Mineral reserves have been estimated with an allowance of approximately 5% dilution from backfill. Mineralized waste dilution is included into each individual planned excavation tonnage. Mineral reserves have been estimated based on 99.1% mining recovery. Mineral resources do not include such allowances.

• Mineral resources are estimated at a minimum mineralized thickness of 1.0 metre and at a minimum grade of 0.1% to 0.5% U₃O₈ depending upon the underground extraction methods. Reported mineral reserves are based on pounds U₃O₈ recovered per excavation, translating into an average cut-off grade of 0.82% U₃O₈.

• Based on the current life of mine plan, a $1.20 (Cdn) fixed exchange rate was used with an average uranium price of $48 (US).

Key parameters

• The uranium grade is determined from assay samples where available, or by converting radiometric probing values to equivalent % U₃O₈ based on a correlation between radiometric counts and assay values.

• When not measured, densities are determined using formulas based on the relation between density measurements of drill core and chemical assay grades.

• Mineral reserves are estimated based on the use of raisebore and blasthole stope mining methods in conjunction with freeze curtains.

• Between 2017 and 2036, the production schedule assumes 18 million pounds U₃O₈ (which includes processing downblended material at Key Lake) mined and processed annually. Production of 9.8 million pounds U₃O₈ is forecast (which includes processing downblended material at Key Lake) at end of the mine life in 2037.

• Reasonable expectation for eventual economic extraction of the mineral resources is based on the long-term forecast uranium price, the average grade of the mineralized areas and the proximity of surface and mining infrastructure on the site.

Key methods

• Mineral resources were estimated using 3-dimensional block models and cross-sectional method. Mineral reserves were estimated with 3-dimensional block models.

2016 ANNUAL INFORMATION FORM    Page 80

• The models were created from the geological interpretation on section and plan views and in 3D derived from surface and underground drillhole information. Estimates of block grade and density were obtained with ordinary kriging or inverse squared distance methods.

• The mining application used was Maptek Vulcan and Leapfrog Geo.

Cigar Lake

Key assumptions

• Mineral reserves have been estimated with an average allowance of 30% dilution at 0% U₃O₈, inclusive of 0.5 m of dilution material above and below the planned cavity.

• Mineral reserves have been estimated based on 90% mining recovery. Mineral resources do not include dilution and mining recovery.

• Mining rate is assumed to vary between 100 and 200 tonnes per day and a full mill production rate of approximately 18 million pounds U₃O₈ per year.

• Areas being mined must meet specific ground freezing requirements before jet boring begins.

• An average uranium price of $50 (US) per pound U₃O₈ with a $1.00 (US) = $1.20 – $1.25 (Cdn) fixed exchange rate was used to estimate the mineral reserves, taking into account the annual planned production and the annual forecast realized prices.

Key parameters

• Grades of U₃O₈ were obtained from chemical assaying of drill core or from equivalent % U₃O₈ grades obtained from radiometric probing results. In areas of poor core recovery (< 75%) or missing samples, the grade was determined from probing.

• A correlation between uranium, nickel, cobalt and clay content and density was applied where the density was not directly measured for each sample.

• Mineral resources have been estimated using a minimum mineralization thickness of 1.0 metre and a minimum grade of 1.0% U₃O₈.

• Mineral reserves have been estimated on the basis of designed JBS cavities with positive economics from the estimated recovered uranium.

• Reasonable expectation for eventual economic extraction of the mineral resources is based on the long-term forecast uranium price, the average grade of the mineralized areas and the proximity of surface and mining infrastructure on the site.

Key methods

• The geological interpretation of the orebody was done on section and plan views and in 3D derived from drillhole information. Mineral resources and mineral reserves were estimated using a 3-dimensional block model. Geostatistical conditional simulation (with sequential Gaussian simulation) and inverse distance squared were used to estimate the grade and density of the different areas.

• The mining applications used were Maptek Vulcan and Leapfrog Geo.

Inkai

Key assumptions

• Mineral resources were estimated based on the use of the ISR extraction method and yellowcake production.

• Reasonable expectation for eventual economic extraction of the mineral resources is based on average forecast price of $32.80 (US) per pound U₃O₈, realistic production costs and the proximity of surface and mining infrastructure on the site.

• Average metallurgical recovery of 85% is based on the production results so far.

• To estimate the mineral reserves, an average uranium price of $51.00 (US) per pound U₃O₈ was used, derived from the production schedule and annual forecast realized prices, with exchange rates of $1.00 US = $1.20 to $1.25 Cdn and 245 Kazakhstan Tenge to $1.00 Cdn.

Key parameters

• Grades (% U₃O₈) were obtained from gamma radiometric probing of drillholes, checked against assay results and prompt-fission neutron logging results to account for disequilibrium.

2016 ANNUAL INFORMATION FORM    Page 81

• Mineral resources are estimated using a minimum grade of 0.012% U₃O₈ per drillhole interval and minimum Grade x Thickness (GT) of 0.071 m% U₃O₈ and 0.047 m% U₃O₈ per hole for blocks 1 and 2, respectively.

• Mineral reserves have been estimated at a minimum GT of 0.130 m% U₃O₈.

• Average density of 1.70 tonnes per cubic metre was used, based on historical and current sample measurements.

• Mineral reserves represent the in-situ ore that can be extracted within the term of the block 1 and block 2 licenses.

• The production rate is planned for 5.4 million pounds of U₃O₈ for 2017, then 5.2 million pounds per year for 2018 to 2028 and then decreasing till 2030.

Key methods

• The geological interpretation of the orebody outlines was done on section and plan views derived from surface drillhole information.

• Mineral resources were estimated with the GT method, where the estimated variable is the uranium grade multiplied by the thickness of the interval, and using two-dimensional block models.

• A resource block must be confined to one aquifer taking into consideration the distribution of local aquitards.

• Only indicated and measured mineral resources are considered for conversion to mineral reserves.

• Considerations of the rate of in-situ uranium recovery, lixiviant uranium head grades, wellfield flow rates and production requirements to define the production sequence.

• The geological modelling and mining applications used were AtomGeo, MapInfo and Maptek Vulcan.

Sustainable development

Social responsibility and environmental protection are top priorities for us, so much so that we have built our corporate objectives around them within our four measures of success: a safe, healthy and rewarding workplace, a clean environment, supportive communities, and outstanding financial performance. For us, sustainability is not an add-on for our company; it is at the core of our company culture. It helps us:

• build trust, credibility and corporate reputation

• gain and enhance community support for our operations and plans

• attract and retain employees

• manage risk

• drive innovation and continual improvement to build competitive advantage.

Because they are so important, we integrate sustainable development principles and practices at each level of our organization, from our overall corporate strategy to individual employee practice in day-to-day operations.

We have developed a corporate social responsibility policy (CSR policy) that defines our standards and expectations for sustainable development throughout the company. Under the CSR policy:

• our goal is to be recognized as a leader in corporate social responsibility by proactively addressing the social, environmental and financial aspects of our business with key stakeholders; and

• we seek to integrate corporate social responsibility in our day to day business, and achieve strong performance in our four key measures of success: a safe, healthy and rewarding workplace, a clean environment, supportive communities and outstanding financial performance.

We seek to implement our CSR policy by including commitments based upon these four key measures of success:

Safe, healthy and rewarding workplace

We are committed to having a safe, healthy and rewarding workplace that reflects the diversity of the communities in which we operate. One of the ways we implement this commitment is through our safety, health, environment and quality policy. See Safety, Health and Environment starting at page 84 for more information about this policy.

Clean environment

We are committed to continually improving our overall environmental performance throughout the lifecycle of our operations. See Safety, Health and Environment starting at page 84 for how we implement this commitment.

2016 ANNUAL INFORMATION FORM    Page 82

Supportive communities

We are committed to building long-lasting and trusting relationships with the communities in which we operate. One of the ways we implement this commitment is through our Five Pillar CSR Strategy, which is described below.

Outstanding financial performance

We are committed to managing our business in a way that ensures long-term financial stability and profitability.

Our CSR policy describes further what we do to implement these commitments.

Our chief executive officer is responsible for ensuring compliance with our CSR policy and implementation of its supporting policies and programs.

Five Pillar CSR Strategy

Over more than 27 years of operation and partnership in northern Saskatchewan, we have developed a comprehensive Five Pillar CSR Strategy aimed at ensuring the support of the communities with whom we work, all across our operations globally. The strategy is flexible and is implemented by our global operations at a local level to reflect the needs of the local communities.

While developed in part as a result of some of the socio-economic obligations that are contained in our surface lease agreements with the Saskatchewan government, the bulk of the strategy has evolved as a result of the commercial benefits we see from ensuring strong support among local communities wherever we operate. The pillars are:

1.    The Workforce Development pillar delivers programming that aims to build educational and skills capacity in local communities. The goal of this pillar is to ensure that students stay in school, have the means to attend post-secondary education, and receive training to facilitate employment opportunities in our industry.

2.    The Business Development pillar is designed to promote the involvement of locally-owned businesses in contracting opportunities at our operations, and to provide additional jobs, revenue streams and capacity building at the local community level. We work with local contractors in a variety of ways, including by providing updates on contracting opportunities. In Saskatchewan, we also have a northern contractor strategy, which gives preference to majority-owned northern companies and helps to build a long-term relationship between northern contractors and ourselves.

3.    The Community Engagement pillar is designed with the objective to ensure that we secure support for our operations from local communities and satisfy the obligations placed on us by regulators and laws. While the main activities here are focused specifically on the communities in closest proximity to our operations, in northern Saskatchewan, we also ensure that the greater region is kept informed of our operations, whether it is through our yearly community tours or community focused websites.

4.    The Community Investment pillar is designed to help local communities with much-needed funding for community programming and infrastructure. Through this pillar, we look to support community initiatives that are focused on youth, education and literacy, health and wellness and community development.

5.    The Environmental Stewardship pillar, the most recent addition to the strategy, is designed to support our overall environmental programming. It is intended to provide communities with a voice in both the formal environmental assessment regulatory process, as well as ongoing monitoring activities.

Impact of Organizational Changes

We recognize that changes in our operations and support functions, including the suspension of production at Rabbit Lake, curtailment at Cameco Resources’ US operations, and the reduction of the workforce at our northern Saskatchewan operations and at our corporate office, all have a significant impact on the communities where we operate. While we regret the negative impact that these carefully deliberated decisions have on affected employees and other stakeholders, these actions are deemed necessary for the long-term health of the company in a uranium market that continues to be weak and oversupplied. Improving operational efficiency is part of our strategy to effectively manage costs and remain competitive through these low times, while positioning the company and our stakeholders to benefit as the market improves.

2016 ANNUAL INFORMATION FORM    Page 83

Safety, Health and Environment

We introduced our safety, health, environment and quality (SHEQ) policy (SHEQ Policy) in 1991. We have refined our approach over the years and have since developed our overall integrated SHEQ management system.

The SHEQ Policy, which was reviewed and reissued in 2015, includes our statement of principles and identifies the seven programs that comprise the SHEQ management system, which implements the SHEQ Policy and supports these principles. The next review is scheduled for 2018.

Our principles

• prevent injury, ill health and pollution

• comply with and move beyond legal and other requirements

• keep risks at levels as low as reasonably achievable, accounting for social and economic factors

• ensure quality of processes, products and services

• continually improve our overall performance.

SHEQ management system

The seven programs that comprise Cameco’s SHEQ management system are as follows:

• Quality management program

• Safety and health management program

• Radiation protection program

• Environmental management program

• Management system audit program

• Emergency preparedness and response program

• Contractor management program.

We benchmark our system against those used by other companies in the mining and nuclear power generation sectors. On behalf of the board, the safety, health and environment committee oversees our SHEQ Policy and management system as well as our safety and environmental performance. Our chief executive officer is responsible for ensuring this system is established and maintained across the company.

Our SHEQ management system is centralized and managed at the corporate level. It is implemented across the corporation as a whole with a focus on our operations.

Corporate SHEQ activity at our operations focuses on consistent application of programs and procedures, as well as carrying out certain centralized functions and providing support for identified issues. Our sites are regularly audited to safety health and environmental requirements and to ensure the site-based programs meet Cameco requirements. The SHEQ management system is also part of our program to manage environmental risks at our operations and meet the requirements of ISO 14001. All of our operating sites are ISO 14001 certified. In addition, we have now transitioned from individual site-based ISO 14001 certifications to a single corporate certification. We have started the process to roll the majority of our operations into this single certification.

In 2016, we invested:

• $80 million in environmental protection, monitoring and assessment programs, slightly more than 2015

• $27 million in health and safety programs (or 30% less than in 2015 due to major safety improvement projects being completed in 2015).

Spending on environmental as well as health and safety programs is expected to decrease in 2017 as a result of the decisions to transition Rabbit Lake into care and maintenance and to reduce production at our US operations.

There were no environmentally significant incidents in 2016.

In 2016, we continued to achieve solid and improving safety performance at our operations. Highlights included the McArthur River operation winning the John T. Ryan award for safety performance at a metal mine for the 3^rd year in a row and 4^th time in

2016 ANNUAL INFORMATION FORM    Page 84

the last 6 years. As well, our Blind River and Crow Butte operations celebrated significant safety milestones reaching the 10^th and 9^th year in a row respectively without a lost time injury. Further, we continued to have strong safety and environmental performance while transitioning our Rabbit Lake operation into care and maintenance.

Focus on the environment

Our business by its nature has an impact on the environment, so environmental performance is a key area of focus for us.

Our focus in this regard is reinforced by our systematic approach to SHEQ issues. We have integrated this approach into activities at our operating properties and our planning process for major projects. We also have conceptual decommissioning plans in place for all of our operating sites.

We report our performance annually. You can find this information on our website (cameco.com) and in our sustainable development report, which is also available on our website.

Reducing our impact

We have been carrying out our long-term plan to reduce the impact we have on the environment. This includes assessing, monitoring and looking for opportunities to reduce our effect on air, water and land, optimize the amount of energy we consume, and manage the effects of waste.

We are investing in management systems and safety initiatives to achieve operational excellence and reliability, and this continues to improve our safety and environmental performance and operating efficiency. We have also incorporated life cycle value assessment (LCVA) into our project management and engineering processes to ensure social, environmental and financial risks have been more fully considered when designing new facilities.

Like other large industrial organizations, we use chemicals in our operations that could be hazardous to our health and the environment if they are not handled correctly. We train our employees in the proper use of hazardous substances and in emergency response techniques.

We work with communities who are affected by our activities by informing them of what we are doing and to obtain feedback and further input, to build and sustain their trust. In Saskatchewan, we participate in the Athabasca Working Group and Northern Saskatchewan Environmental Quality Committee.

In Ontario, we liaise with the community by regularly holding educational and environment-focused activities including through our Community Forum series, our presence at the Port Hope Fair, our regular community newsletters and ongoing communication with local elected officials and community leaders.

Land

Cameco’s North American operating sites affect a relatively small area compared to what would be required to generate the same amount of energy using other technologies.

Our mines in northern Saskatchewan are underground mines so the impact on the surface land is minimal. We use ISR mining in our US operations to extract uranium from underground non-potable, brackish aquifers, so the impact on the surface there is also minimal. We also use ISR mining at Inkai so the impact on the surface there is minimal as well.

Water

We look to improve processes and adopt new technologies to improve how we manage water, and the effect it has on receiving water bodies. In 2016, Cameco completed decommissioning and reclamation of select crossings and borrow areas on the Fox Lake road near McArthur River that were no longer in use by Cameco.

2016 ANNUAL INFORMATION FORM    Page 85

United States

The ISR method we use in our US operations involves extracting uranium from underground non-potable aquifers by dissolving the uranium with a carbonate-based water solution and pumping it to a processing facility on the surface. After mining has been completed, an ISR wellfield must be restored according to regulatory requirements. This generally involves restoring the groundwater to its pre-mining state or equivalent class of use water standard. In the US, we are not only working to improve the groundwater restoration process, but also on waste reduction programs. Smith Ranch-Highland completed a pipeline that allowed the optimization of its existing wastewater disposal capacity, as part of efforts to improve and optimize groundwater restoration in Cameco Resources. We also continued to be involved in industry leading research and innovation in groundwater restoration at in situ recovery operations.

We have 14 wellfields under restoration. See pages 88 and 89 for more information.

Kazakhstan

The ISR mining method we use at Inkai uses an acid in the mining solution to extract uranium from underground non-potable aquifers. The injection and recovery system is engineered to prevent the mining solution from migrating to the aquifer above the orebody, which has water with higher purity.

Kazakhstan does not require active restoration of post-mining groundwater. After a number of decommissioning steps are taken, natural attenuation of the residual acid in the mined out horizon, as a passive form of groundwater restoration, has been accepted. Attenuation is a combination of neutralization of the groundwater residual acid content by interaction with the host rock minerals and other chemical reactions which immobilize residual groundwater contaminants in the mined-out subsoil horizon. This approach is considered acceptable because it results in water quality similar to the pre-mining baseline status.

Air

The table below shows our most recent data on our greenhouse gas emissions. We follow the general guidelines outlined by the Intergovernmental Panel on Climate Change to qualify greenhouse gas emissions.

	2016		2015		2014
Greenhouse gas emissions(1) of tonnes of CO2 equivalent (CO2e)		492,296		521,834		548,247

Notes

(1) Greenhouse gas emissions include carbon dioxide, methane, nitrous oxide, sulphur hexafluoride, hydrofluorocarbons (HFCs), and perfluorocarbons (PFCs) expressed as a carbon equivalent (CO₂e).

While greenhouse gas emissions have been slowly increasing since 2005, in 2015 and 2016 overall corporate greenhouse gas emissions have declined due to a number of factors, including decreasing project activity as well as the decisions in 2016 to suspend production at our Rabbit Lake uranium mine and mill and to curtail production at Cameco Resources.

Port Hope

In 2011, we lowered emissions of uranium and hydrofluoric acid to the air by installing new equipment and changing the operating procedures. Our fuel services division has since focused on improving the monitoring of some emission sources and in 2014 established a process for setting an objective for reducing uranium in air emissions. These efforts are seeing positive results. Further, after installing a scrubber in 2014, we managed to sustain a nearly 50% reduction in uranium in air emissions in 2015 and even further in 2016.

McArthur River

McArthur River has a large refrigeration plant that produces cold brine used for freezing the area of the deposit to be mined. The plant uses refrigerants, but they are not ozone-depleting chemicals that harm the earth’s atmosphere.

2016 ANNUAL INFORMATION FORM    Page 86

Cigar Lake

Cigar Lake has a large refrigeration plant that produces cold brine used for freezing the area of the deposit to be mined. The plant uses refrigerants, but they are not ozone-depleting chemicals that harm the earth’s atmosphere.

Waste

Our mines and the Key Lake mill in northern Saskatchewan account for most of the tailings and waste rock our operations generate.

We treat the mill tailings at Key Lake to stabilize contaminants before depositing them in tailings management facilities (in mined-out open pits near the mill).

We divert groundwater and surface water around the tailings management facilities, monitor the water to make sure it is not impacted by the tailings, and treat it if necessary. We monitor runoff and treat water from waste rock piles as needed. We stockpile some waste rock to blend with higher grade ores. We contour other waste rock piles and revegetate them before decommissioning the site. We plan to continue to monitor groundwater after the facility has been decommissioned.

In 2015, we took steps to address legacy waste at several of our operations. In particular, our legacy waste management plan at fuel services included the shipment of over 4,000 historically contaminated drums to a licensed facility and 1600 drum equivalents of contaminated combustibles to be processed at the Blind River Refinery incinerator. In 2016, we continued implementing this plan, shipping over 6,700 historically contaminated drums and two sea containers containing machinery to licensed facilities. The 2015 and 2016 shipments represent about 17% of the total number of drums remaining for disposal. In addition, all of our Saskatchewan mining operations continued efforts to address historical laydown areas of contaminated material.

Complying with environmental regulations

Our business is required to comply with laws and regulations that are designed to protect the environment and control the management of hazardous wastes and materials. Some laws and regulations focus on environmental issues in general, and others are specifically related to mining and the nuclear sector. They change often, with requirements increasing, and existing standards are being applied more stringently. While this dynamic promotes continuous improvement, it can increase expenses and capital expenditures, or limit or delay our activities.

Government legislation and regulation in various jurisdictions establish standards for system performance, standards, objectives and guidelines for air and water quality emissions, and other design or operational requirements for the various SHEQ components of our operations and the mines that we plan to develop. In addition, we must complete an environmental assessment before we begin developing a new mine or start processing activities, or make any significant change to our operations. Once we have permanently stopped mining and processing activities, we are required to decommission and reclaim the operating site to the satisfaction of the regulators, and we may be required to actively manage former mining properties for many years.

Canada

Not only is there ongoing regulatory oversight by the CNSC, the SMOE, the Ontario Ministry of the Environment, and Environment and Climate Change Canada, but there is also public scrutiny of the impact our operations have on the environment.

The CNSC, an independent regulatory authority established by the federal government under the Nuclear Safety and Control Act (NSCA), is our main federal regulator in Canada. It regulates our compliance with the NSCA and is the federal lead for environmental assessments required to be carried out under the Canadian Environmental Assessment Act, 2012, which was introduced as part of the federal government’s responsible resource development policy.

2016 ANNUAL INFORMATION FORM    Page 87

The primary objectives of an environmental assessment are to ensure that:

• potential adverse environmental effects are considered before proceeding with a project

• projects that cause unjustifiable, significant adverse environmental effects are not permitted to proceed

• appropriate measures are implemented, where necessary, to mitigate risk.

Plans to expand production or build new mines in Saskatchewan are subject to this process. In certain cases, a review panel may be appointed and public hearings held.

Over the past few years, CNSC audits of our operations have focused on the following SHEQ programs:

•       radiation protection   •       environmental monitoring   •       fire protection   •       operational quality assurance   •       organization and management systems effectiveness •       transportation systems   •       geotechnical monitoring   •       training   •       ventilation systems.

Improving our environmental performance is challenging and we have a number of activities underway:

• improving uranium emissions from different systems at the Port Hope conversion facility to meet the newly established objective

• focusing on maintaining our excellent water quality while maintaining production at our facilities.

Efforts like these often require additional environmental studies near the operations, and we will continue to undertake these as required.

It can take a significant amount of time for regulators to make requested changes to a licence or grant a requested approval because the activity may require an environmental assessment or an extensive review of supporting technical data, management programs and procedures. We are improving the quality of our proposals and submissions and have introduced a number of programs to ensure we continue to comply with regulatory requirements, but this has also increased our capital expenditures and our operating costs.

As our SHEQ management system matures, regulators continue to review our programs and recommend ways to improve our SHEQ performance. These recommendations are generally procedural and do not involve large capital costs, although systems applications can be significant and result in higher operating costs.

We believe that regulatory expectations of the CNSC and other federal and provincial regulators will continue to evolve, and lead to changes to both requirements and the regulatory framework. This will likely increase our expenses.

United States

Our ISR operations in the US have to meet federal, state and local regulations governing air emissions, water discharges, handling and disposal of hazardous materials and site reclamation, among other things.

Mining activities have to meet comprehensive environmental regulations from the NRC, Bureau of Land Management, Environmental Protection Agency (EPA) and state environmental agencies. The process of obtaining mine permits and licences generally takes several years, and involves environmental assessment reports, public hearings and comments. We have the permits and licences for the US operations that we need to meet our 2017 production plans.

After mining is complete, ISR wellfields have to be restored according to regulatory requirements. This generally involves restoring the groundwater to its pre-mining state or equivalent class of use water standard. Restoration of Crow Butte wellfields is regulated by the Nebraska Department of Environmental Quality and the NRC. Restoration of Smith Ranch-Highland wellfields is regulated by the Wyoming Department of Environmental Quality and the NRC.

The EPA is proposing to add new health and environmental protection standards to regulate by-product materials produced by uranium in situ recovery. The proposed rule includes surface and subsurface standards, with a primary focus on groundwater protection, restoration and stability. One of the most significant proposed requirements is that groundwater must be monitored for 30 years after restoration. We are working with other industry participants and associations to respond to the proposed requirements, including making written submissions and appearing at the EPA hearings in 2015. In our view, as argued in

2016 ANNUAL INFORMATION FORM    Page 88

written submissions and in the EPA hearings, the proposed rulemaking will result in a regulatory framework that is more subjective and arbitrary than protective. In early 2017, the EPA withdrew its rule, but then proposed a new rule for public comment, which is less onerous though still has a number of problematic aspects. Ultimately, the decision on moving forward with the EPA’s new proposal will be decided by the new administration.

Also in late 2016, the EPA released a proposed rule that would impose additional financial responsibility requirements on owners and operations, along with various recordkeeping and notification requirements. If finalized as proposed, it would apply to Crow Butte and Smith Ranch-Highland, and the amount of Cameco Resources’ financial responsibility could be material.

See page 91 for the status of wellfield restoration and regulatory approvals.

Kazakhstan

In its resource use contract with the Kazakhstan government, JV Inkai committed to conducting its operations according to good international mining practices. It complies with the environmental requirements of Kazakhstan legislation and regulations, and, as an industrial company, it must also reduce, control or eliminate various kinds of pollution and protect natural resources. JV Inkai is required to submit annual reports on pollution levels to the Kazakhstan environmental, tax and statistics authorities. The authorities conduct tests to validate JV Inkai’s results.

Environmental protection legislation in Kazakhstan has evolved rapidly, especially in recent years. As the subsoil use sector has evolved, there has been a trend towards greater regulation, heightened enforcement and greater liability for non-compliance. The most significant development was the adoption of the Ecological Code, dated January 9, 2007 and in effect as of February 3, 2007. This code replaced the three main laws that had related to environmental protection. Amendments were made to the code in December 2011 that include more stringent environmental protection regulations, particularly relating to the control of greenhouse gas emissions, obtaining environmental permits, state monitoring requirements and other similar matters.

JV Inkai is required to comply with environmental requirements during all stages of the project, and must develop an environmental impact assessment for examination by a state environmental expert before making any legal, organizational or economic decisions that could have an effect on the environment and public health.

Under the Ecological Code, JV Inkai needs an environmental permit to operate. The permit certifies the holder’s right to discharge emissions into the environment, provided that it complies with the requirements of the permit and the Ecological Code. JV Inkai has a permit for environmental emissions and discharges for the operation that is valid until December 31, 2022. JV Inkai also holds the required permits under the Water Code.

Government authorities and the courts enforce compliance with these permits, and violations can result in the imposition of administrative, civil or criminal penalties, the suspension or stopping of operations, orders to pay compensation, orders to remedy the effects of violations and orders to take preventive steps against possible future violations. In certain situations, the issuing authority may suspend or revoke the permits.

JV Inkai has environmental insurance, as required by the Ecological Code and the resource use contract, as well as civil liability insurance.

Nuclear waste management and decommissioning

Once we have permanently stopped mining and processing activities, we are required to decommission the operating sites. This includes reclaiming all waste rock and tailings management facilities and the other areas of the site affected by our activities to the satisfaction of regulatory authorities.

Estimating decommissioning and reclamation costs

We develop conceptual decommissioning plans for our operating sites and use them to estimate our decommissioning costs. We also submit them to regulators to determine the amount of financial assurance we must provide to secure our decommissioning obligations. Our plans include reclamation techniques that we believe generate reasonable environmental

2016 ANNUAL INFORMATION FORM    Page 89

and radiological performance. Regulators give “conceptual approval” to a decommissioning plan if they believe the concept is reasonable.

We started conducting reviews of our conceptual decommissioning plans for all Canadian sites in 1996. We typically review them every five years, or when we amend or renew an operating licence. We review our cost estimates for both accounting purposes and licence applications. For our US sites, they are reviewed annually. A preliminary decommissioning plan has been established for Inkai. The plan is updated every five years or as significant changes take place, which would affect the decommissioning estimate.

As properties approach or go into decommissioning, regulators review the detailed decommissioning plans. This can result in additional regulatory process, requirements, costs and financial assurances.

At the end of 2016, our estimate of total decommissioning and reclamation costs was $1.04 billion. This is the undiscounted value of the obligation and is based on our current operations. We had accounting provisions of $894 million at the end of 2016 (the present value of the $1.04 billion). Since we expect to incur most of these expenditures at the end of the useful lives of the operations they relate to, our expected costs for decommissioning and reclamation for the next five years are not material.

We provide financial assurances for decommissioning and reclamation as letters of credit to regulatory authorities, as required. We had a total of $998 million in letters of credit supporting our reclamation liabilities at the end of 2016. All of our North American operations have letters of credit in place that provide financial assurance in connection with our preliminary plans for decommissioning for the sites.

Please also see note 15 to our 2016 financial statements for our estimate of decommissioning and reclamation costs and related letters of credit.

Canada

Decommissioning estimates

(100% basis)
McArthur River	$	48 million
Rabbit Lake	$	203 million
Key Lake	$	218 million
Cigar Lake	$	49 million

As part of the licensing process in 2013 for McArthur River, Rabbit Lake, Key Lake and Cigar Lake, the preliminary decommissioning plans for each facility were updated and submitted to the CNSC staff. Our Key Lake decommissioning estimate was further revised and submitted to the CNSC in 2014 and we received final approval of the decommissioning estimate from the CNSC in January 2015. Letters of credit for McArthur River, Key Lake, Rabbit Lake, and Cigar Lake are in place and reflect the current decommissioning cost estimate.

The reclamation and remediation activities associated with waste rock and tailings from processing Cigar Lake ore and uranium solution are covered in the plans and cost estimates for the facility that will be processing it.

Decommissioning estimates

(100% basis)
Port Hope	$129 million
Blind River	an updated estimate of $48 million is currently under regulatory review
CFM	an updated estimate of $21 million is currently under regulatory review

We renewed our licences for Blind River and CFM in 2012. As part of that process, in 2011, the preliminary decommissioning plans for each facility were accepted by the CNSC staff and two letters of credit were updated in April 2012 after the licence renewals were granted. Updated preliminary decommissioning plans and estimates are under regulatory review.

2016 ANNUAL INFORMATION FORM    Page 90

We renewed our licence for Port Hope in 2017. As part of that process, an update to the Port Hope Conversion Facility preliminary decommissioning plan was finalized and accepted in February 2017. The letter of credit was updated in March 2017 and reflects the current decommissioning estimate.

Historical waste

When Cameco was formed, we assumed ownership and primary responsibility for managing the waste already existing at the time of the reorganization. This historical waste was all in Ontario, at the historical facilities, which include the Port Hope Conversion Facility, Blind River Refinery, Port Granby Waste Management Facility, Welcome Waste Management Facility and the Centre Pier in Port Hope.

In March 2004, we reached an agreement to transfer two historical facilities and their associated liabilities to the Government of Canada: the Welcome Waste Management Facility and the Port Granby Waste Management Facility. We transferred the Welcome Waste Management Facility and the Port Granby Waste Management Facility to Natural Resources Canada on March 31, 2010 and March 29, 2012, respectively.

In March 2012, we entered into a settlement with Canada Eldor Inc., the entity established by the federal government to assume the historical liabilities and obligations of Eldorado Nuclear Limited, regarding liability for historical waste located at the historical facilities. We are now responsible for all liabilities and costs and expenses related to historical waste and the remaining historical facilities owned or leased by us, which are the Port Hope Conversion Facility, the Blind River Refinery and the Centre Pier in Port Hope.

Recycling uranium byproducts

We have arrangements with two facilities for processing certain uranium-bearing byproducts from Blind River and Port Hope. An agreement has been in place with the White Mesa mill in Blanding, Utah for a number of years. Arrangements for recycling of this material are also in place at our Key Lake mill. We received regulatory approval from the Saskatchewan government for this process in 2003, and were advised by the CNSC in 2011 that the project could proceed. Recycled byproduct material has been successfully processed at Key Lake since 2014.

United States

After mining has been completed, an ISR wellfield has to be restored according to regulatory requirements. This generally involves restoring the groundwater to its pre-mining state or equivalent class of water standard.

For wellfield restoration to be complete, regulatory approval is required. It is difficult for us to estimate the timing for wellfield restoration due to the uncertainty in timing for receiving final regulatory approval.

Crow Butte

Restoration of Crow Butte wellfields is regulated by the Nebraska Department of Environmental Quality and the NRC. There are five wellfields being restored at Crow Butte. The groundwater at mine unit #1 has been restored to pre-mining quality standards, all wells are plugged and the piping removed.

Our estimated cost of decommissioning the property is $46 million (US). We have provided the State of Nebraska with a $46 million (US) letter of credit as security for decommissioning the property.

Smith Ranch-Highland

Restoration of Smith Ranch-Highland wellfields is regulated by the Wyoming Department of Environmental Quality (WDEQ) and the NRC. There are nine wellfields being restored at Smith Ranch-Highland, one wellfield in stability, and two wellfields (mine unit A and mine unit B) that have been fully restored.

Restoration of mine unit B was approved by the WDEQ in 2008, while NRC approval has not yet been attained. An Alternate Concentration Limit (ACL) request was submitted to the NRC in May 2013. The NRC subsequently requested additional information, and that additional sampling be conducted. Additional quarterly groundwater sampling of the monitor production wells was undertaken through 2016 for an anticipated revised ACL submission.

2016 ANNUAL INFORMATION FORM    Page 91

Our estimated cost of decommissioning the property is $201 million (US), including North Butte. We have provided the State of Wyoming with $248 million (US) in letters of credit as security for decommissioning the property.

Kazakhstan

JV Inkai is subject to decommissioning liabilities, largely defined by the terms of the resource use contract. JV Inkai has established a separate bank account and made the required contributions to the account as security for decommissioning. Contributions are set as a percentage of gross revenue and are capped at $500,000 (US). JV Inkai has funded the full amount.

Under the resource use contract, JV Inkai must submit a plan for decommissioning the property to the government six months before mining activities are complete. JV Inkai has established a preliminary plan and an estimate of total decommissioning costs of $10 million (US). It updates the plan every five years, or when there is a significant change at the operation that could affect decommissioning estimates.

Groundwater is not actively restored post-mining in Kazakhstan. See page 86 for additional details.

The regulatory environment

This section, and the section Complying with environmental regulations starting on page 87, discuss some of the more significant government controls and regulations that have a material effect on our business. A significant part of our economic value depends on our ability to comply with the extensive and complex laws and regulations that govern our activities. We are not aware of any proposed legislation or changes to existing legislation that could have a material effect on our business.

International treaty on the non-proliferation of nuclear weapons

The Treaty on the Non-Proliferation of Nuclear Weapons (NPT) is an international treaty that was established in 1970. It has three objectives:

• to prevent the spread of nuclear weapons and weapons technology

• to foster the peaceful uses of nuclear energy

• to further the goal of achieving general and complete disarmament.

The NPT establishes a safeguards system under the responsibility of the International Atomic Energy Agency. Almost all countries are signatories to the NPT, including Canada, the US, the United Kingdom and France. We are therefore subject to the NPT and comply with the International Atomic Energy Agency’s requirements.

Industry regulation and permits

Canada

Our Canadian operations have regulatory obligations to both the federal and provincial governments. There are four main regulatory agencies that issue licences and approvals:

• CNSC (federal)

• Fisheries and Oceans Canada (federal)

• SMOE

• Ontario Ministry of Environment.

Environment and Climate Change Canada (federal) is also a main regulatory agency, but does not issue licences and approvals.

Uranium industry regulation

The government of Canada recognizes the special importance of the uranium industry to Canada’s national interest, and regulates the industry through legislation and regulations, and exerts additional control through government policy.

2016 ANNUAL INFORMATION FORM    Page 92

Federal legislation applies to any work or undertaking in Canada for the development, production or use of nuclear energy or for the mining, production, refinement, conversion, enrichment, processing, reprocessing, possession or use of a nuclear substance. Federal policy requires that any property or plant used for any of these purposes must be legally and beneficially owned by a company incorporated in Canada.

Mine ownership restrictions

The federal government has instituted a policy that restricts ownership of Canadian uranium mining properties to:

• a minimum of 51% ownership by residents

• a basic maximum limit of 49% ownership by non-residents of uranium properties at the first stage of production.

The government may grant exceptions. For example, resident ownership may be less than 51% if the property is Canadian-controlled. Exceptions will only be granted in cases where it is demonstrated that Canadian partners cannot be found, and it must receive Cabinet approval.

The government issued a letter to the Canadian uranium industry on December 23, 1987, outlining the details of this ownership policy. On March 3, 2010, the government announced its intention to liberalize the foreign investment restrictions on Canada’s uranium mining sector to “ensure that unnecessary regulation does not inhibit the growth of Canada’s uranium mining industry by unduly restricting foreign investment”. After striking an expert panel to study the issue and soliciting feedback from various stakeholders, the federal government stated in October 2011 that it would not be changing the policy.

In 2013, it was announced that the proposed Canada-EU Trade Agreement (CETA) contemplates that the Canadian uranium mine ownership requirement would be relaxed for all European companies. In Canada, a bill to implement CETA is going through the final stages of the parliamentary approval process and the Canadian government is targeting the spring of 2017 for royal assent. On February 15, 2017, the European Parliament voted to ratify CETA. For final ratification and implementation each of the EU member countries must vote to ratify the agreement. This waiver will not come into effect until the Canadian bill receives royal assent and each of the EU member countries ratifies CETA.

Cameco ownership restriction

We are subject to ownership restrictions under the Eldorado Nuclear Limited Reorganization and Divestiture Act, which restricts the issue, transfer and ownership, including joint ownership, of Cameco shares to prevent both residents and non-residents of Canada from owning or controlling more than a certain percentage of shares. See pages 120 and 121 for more information.

Industry governance

The NSCA is the primary federal legislation governing the control of the mining, extraction, processing, use and export of uranium in Canada. It authorizes the CNSC to make regulations governing all aspects of the development and application of nuclear energy, including uranium mining, milling, conversion, fuel fabrication and transportation. It grants the CNSC licensing authority. A person may only possess or dispose of nuclear substances and build, operate and decommission its nuclear facilities according to the terms and conditions of a CNSC licence. Licensees must satisfy specific conditions of the licence in order to maintain the right to operate their nuclear facilities.

The NSCA emphasizes the importance of environmental as well as health and safety matters, and requires licence applicants and licensees to have adequate provisions for protection.

Regulations made under the NSCA include those dealing with the specific licence requirements of facilities, radiation protection, physical security for all nuclear facilities and the transport of radioactive materials. The CNSC has also issued regulatory documents to assist licensees in complying with regulatory requirements, such as decommissioning, emergency planning, and optimizing radiation protection measures.

All of our Canadian operations are governed primarily by licences granted by the CNSC and are subject to all federal statutes and regulations that apply to us, and all the laws that generally apply in the province where the operation is located, unless there is a conflict with the terms and conditions of the licence or the federal laws that apply to us.

Uranium export

We must secure export licences and export permits from the CNSC and Global Affairs Canada in order to export our uranium. These arrangements are governed by the bi-lateral and multi-lateral agreements that are in place between governments.

2016 ANNUAL INFORMATION FORM    Page 93

Land tenure

Most of our uranium reserves and resources are located in the province of Saskatchewan:

• a mineral claim from the province gives us the right to explore for minerals (other government approvals are required to carry out surface exploration)

• a crown lease with the province gives us the right to mine the minerals on the property

• a surface lease with the province gives us the right to use the land for surface facilities and mine shafts while mining and reclaiming the land.

A mineral claim has a term of two years, with the right to renew for successive one-year periods. Generally, the holder has to spend a certain amount on exploration to keep the mineral claim in good standing. If we spend more than the amount required, the extra amount can be applied to future years.

A holder of a mineral claim in good standing has the right to convert it into a crown lease. A crown lease is for 10 years, with a right to renew for additional 10-year terms. The lessee must spend a certain amount on work during each year of the crown lease. The lease cannot be terminated unless the lessee defaults on any terms of the lease, or under any provisions of The Crown Minerals Act (Saskatchewan) or regulations under it, including any prescribed environmental concerns. Crown leases can be amended unilaterally by the lessor by an amendment to The Crown Minerals Act (Saskatchewan) or The Mineral Disposition Regulations, 1986 (Saskatchewan).

A surface lease can be for up to 33 years, as necessary for operating the mine and reclaiming the land. The province also uses surface leases to specify other requirements relating to environmental and radiation protection as well as socioeconomic objectives.

United States

Uranium industry regulation

In the US, uranium recovery is regulated primarily by the NRC according to the Atomic Energy Act of 1954, as amended. Its primary function is to:

• ensure employees, the public and the environment are protected from radioactive materials

• regulate most aspects of the uranium recovery process.

The NRC’s regulations for uranium recovery facilities are codified in Title 10 of the Code of Federal Regulations (10 CFR). It issues Domestic Source Material Licences under 10 CFR, Part 40. The National Environmental Policy Act (NEPA) governs the review of licence applications, which is implemented through 10 CFR, Part 51.

At Smith Ranch-Highland and Crow Butte, safety is regulated by the federal Occupational Safety and Health Administration.

Other governmental agencies are also involved in the regulation of the uranium recovery industry.

The NRC also regulates the export of uranium from the US and the transport of nuclear materials within the US. It does not review or approve specific sales contracts. It also grants export licences to ship uranium outside the US.

Wyoming

The uranium recovery industry is also regulated by the WDEQ, the Land Quality Division according to the Wyoming Environmental Quality Act (WEQA) and the Land Quality Division Non-Coal Rules and Regulations under the WEQA. According to the state act, the WDEQ issues a permit to mine. The Land Quality Division administers the permit.

The state also administers a number of EPA programs under the Clean Air Act and the Clean Water Act. Some of the programs, like the Underground Injection Control Regulations, are incorporated in the Land Quality Division Non-Coal Rules and Regulations. Wyoming currently requires wellfield decommissioning to the standard of pre-mining use.

Nebraska

The uranium recovery industry is regulated by the NRC, and the Nebraska Department of Environmental Quality according to the Nebraska Environmental Protection Act. The Nebraska Department of Environmental Quality issues a permit to mine. The state requires wellfield groundwater be restored to the class of use water standard.

2016 ANNUAL INFORMATION FORM    Page 94

Land tenure

Our uranium reserves and resources in the US are held by subsidiaries that are located in Wyoming and Nebraska. The right to mine or develop minerals is acquired either by leases from the owners (private parties or the state) or mining claims located on property owned by the US federal government. Our subsidiaries acquire surface leases that allow them to install wellfields and conduct ISR mining.

Kazakhstan

See Kazakhstan government and legislation starting on page 57.

Taxes and Royalties

Transfer pricing disputes

We have been reporting on our transfer pricing disputes with CRA since 2008, when it originated, and with the IRS since the first quarter of 2015. Below, we discuss the general nature of transfer pricing disputes and, more specifically, the ongoing disputes we have.

Transfer pricing is a complex area of tax law, and it is difficult to predict the outcome of cases like ours. However, tax authorities generally test two things:

• the governance (structure) of the corporate entities involved in the transactions

• the price at which goods and services are sold by one member of a corporate group to another.

We have a global customer base and we established a marketing and trading structure involving foreign subsidiaries, including Cameco Europe Limited (CEL), which entered into various intercompany arrangements, including purchase and sale agreements, as well as uranium purchase and sale agreements with third parties. Cameco and its subsidiaries made reasonable efforts to put arm’s-length transfer pricing arrangements in place, and these arrangements expose the parties to the risks and rewards accruing to them under these contracts. The intercompany contract prices are generally comparable to those established in comparable contracts between arm’s-length parties entered into at that time.

For the years 2003 to 2011, CRA has shifted CEL’s income (as recalculated by CRA) back to Canada and applied statutory tax rates, interest and instalment penalties, and, from 2007 to 2010, transfer pricing penalties. There has not yet been a decision regarding a transfer pricing penalty for 2011. The IRS is also proposing to allocate a portion of CEL’s income for the years 2009 through 2012 to the US, resulting in such income being taxed in multiple jurisdictions. Taxes of approximately $350 million for the 2003 – 2016 years have already been paid in a jurisdiction outside Canada and the US. Bilateral international tax treaties contain provisions that generally seek to prevent taxation of the same income in both countries. As such, in connection with these disputes, we are considering our options, including remedies under international tax treaties that would limit double taxation; however, there is a risk that we will not be successful in eliminating all potential double taxation. The expected income adjustments under our tax disputes are represented by the amounts claimed by CRA and IRS and are described below.

CRA dispute

Since 2008, CRA has disputed our corporate structure and the related transfer pricing methodology we used for certain intercompany uranium sale and purchase agreements. To the end of 2015, we received notices of reassessment for our 2003 through 2010 tax returns, and, in the fourth quarter of 2016, we received a notice of reassessment for our 2011 tax year. We have recorded a cumulative tax provision of $58 million, where an argument could be made that, based on our methodology, our transfer price may have fallen outside of an appropriate range of pricing in uranium contracts for the period from 2003 through 2016. We are confident that we will be successful in our case and continue to believe the ultimate resolution of this matter will not be material to our financial position, results of operations and cash flows in the year(s) of resolution.

For the years 2003 through 2011, CRA issued notices of reassessment for approximately $4.1 billion of additional income for Canadian tax purposes, which would result in a related tax expense of about $1.2 billion. CRA has also issued notices of reassessment for transfer pricing penalties for the years 2007 through 2010 in the amount of $292 million. The Canadian income tax rules include provisions that require larger companies like us to remit or otherwise secure 50% of the cash tax plus

2016 ANNUAL INFORMATION FORM    Page 95

related interest and penalties at the time of reassessment. To date, under these provisions, after applying elective deductions, we have paid a net amount of $264 million in cash. In addition, we have provided $420 million in letters of credit (LC) to secure 50% of the cash taxes and related interest amounts reassessed after 2014. The amounts paid or secured are shown in the table below.

YEAR PAID ($ MILLIONS)	CASH TAXES		INTEREST AND INSTALMENT PENALTIES		TRANSFER PRICING PENALTIES		TOTAL		CASH REMITTANCE		SECURED BY LC
Prior to 2013		—		13		—		13		13		—
2013		1		9		36		46		46		—
2014		106		47		—		153		153		—
2015		202		71		79		352		20		332
2016		51		38		31		120		32		88
Total		360		178		146		684		264		420

Using the methodology we believe CRA will continue to apply, and including the $4.1 billion already reassessed, we expect to receive notices of reassessment for a total of approximately $8.1 billion of additional income taxable in Canada for the years 2003 through 2016, which would result in a related tax expense of approximately $2.4 billion. As well, CRA may continue to apply transfer pricing penalties to taxation years subsequent to 2010. As a result, we estimate that cash taxes and transfer pricing penalties for these years would be between $1.75 billion and $1.95 billion. In addition, we estimate there would be interest and instalment penalties applied that would be material to us. While in dispute, we would be responsible for remitting or otherwise providing security for 50% of the cash taxes and transfer pricing penalties (between $875 million and $975 million), plus related interest and instalment penalties assessed, which would be material to us.

Under the Canadian federal and provincial tax rules, the amount required to be paid or secured each year will depend on the amount of income reassessed in that year and the availability of elective deductions and tax loss carryovers. CRA has decided to disallow the use of any loss carry-backs for any transfer pricing adjustment, starting with the 2008 tax year. This does not impact the anticipated income tax expense for a particular year, but does impact the timing of any required security or payment. As noted above, beginning with the 2010 tax year, as an alternative to paying cash, we used letters of credit to satisfy our obligations related to the reassessed income tax and related interest amounts. We believe we will be able to continue to provide security in the form of letters of credit to satisfy these requirements. The estimated amounts summarized in the table below reflect actual amounts paid or secured and estimated future amounts owing based on the actual and expected reassessments for the years 2003 through 2016, and include the expected timing adjustment for the inability to use any loss carry-backs starting in 2008. We will update this table annually to include the estimated impact of reassessments expected for completed years subsequent to 2016.

$ MILLIONS	2003-2016		2017-2018		2019-2023		TOTAL
50% of cash taxes and transfer pricing penalties paid, secured or owing in the period
Cash payments		187		65 - 90		145 - 170		390 - 445
Secured by letters of credit		319		10 - 35		150 - 175		480 - 530
Total paid1		506		75 - 125		295 - 345		875 - 975

¹ These amounts do not include interest and instalment penalties, which totaled approximately $178 million to December 31, 2016.

In light of our view of the likely outcome of the case as described above, we expect to recover the amounts remitted, including the $684 million already paid or otherwise secured to date.

The trial related to the 2003, 2005 and 2006 reassessments commenced in October, 2016. Final arguments are expected in the second half of 2017. If this timing is adhered to, we expect to receive a Tax Court decision within six to 18 months after the trial is complete.

2016 ANNUAL INFORMATION FORM    Page 96

IRS dispute

We received Revenue Agents Reports (RARs) from the IRS for the 2009 though 2012 tax years, whereby the IRS has challenged the transfer pricing used under certain intercompany transactions pertaining to the above tax years for certain of our US subsidiaries. The RARs list the adjustments proposed by the IRS and calculate the tax and any penalties owing based on the proposed adjustments.

The audit position of the IRS is that a portion of the non-US income reported under our corporate structure and taxed in non-US jurisdictions should be recognized and taxed in the US on the basis that:

• the prices received by our US mining subsidiaries for the sale of uranium to CEL are too low

• the compensation earned by Cameco Inc., one of our US subsidiaries, is inadequate.

The proposed adjustments result in an increase in taxable income in the US of approximately $419 million (US) and a corresponding increased income tax expense of approximately $122 million (US) for the 2009 through 2012 taxation years, with interest being charged thereon. In addition, the IRS proposed cumulative penalties of approximately $8 million (US) in respect of the adjustment.

We believe that the conclusions of the IRS in the RARs are incorrect and we are contesting them in an administrative appeal, during which we are not required to make any cash payments. Until this matter progresses further, we cannot provide an estimation of the likely timeline for a resolution of the dispute.

We believe that the ultimate resolution of this matter will not be material to our financial position, results of operations and cash flows in the year(s) of resolution.

Overview of disputes

The table below provides an overview of some of the key points with respect to our CRA and IRS tax disputes.

	CRA	IRS
Basis for dispute	•       Corporate structure/governance •       Transfer pricing methodology used for certain intercompany uranium sale and purchase agreements •       Allocates CEL income (as adjusted) for 2003 through 2011 to Canada (same income we paid tax on in foreign jurisdictions and includes income that IRS is proposing to tax)	•       Income earned on sales of uranium by the US mines to CEL is inadequate •       Compensation earned by Cameco Inc., one of our US subsidiaries, is inadequate •       Allocates a portion of CEL’s income for the years 2009 through 2012 to the US (a portion of the same income we paid tax on in foreign jurisdictions and which the CRA is proposing to tax)
Years under consideration	•       CRA reassessed 2003 to 2011 •       Auditing 2012 to 2014	•       IRS has proposed adjustments for 2009 through 2012 •       Auditing 2013 to 2015
Timing of resolution	•       The trial related to the 2003, 2005 and 2006 reassessments commenced in October 2016, with final arguments expected in the second half of 2017 •       Expect Tax Court decision six to 18 months after completion of trial	•       Contesting proposed adjustments in an administrative appeal •       We cannot yet provide an estimate as to the timeline for resolution
Required payments	•       Expect to provide security in form of letters of credit and/or make cash payments for 50% of cash taxes, interest and penalties as reassessed •       Paid $264 million in cash to date •       Secured $420 million using letters of credit	•       No security or cash payments required while under administrative appeal

Caution about forward-looking information relating to our CRA and IRS tax dispute

This discussion of our expectations relating to our tax disputes with CRA and IRS and future tax reassessments by CRA and IRS is forward-looking information that is based upon the assumptions and subject to the material risks discussed under the heading Caution about forward-looking information beginning on page 2 and also on the more specific assumptions and risks listed below. Actual outcomes may vary significantly.

2016 ANNUAL INFORMATION FORM    Page 97

Assumptions

• CRA will reassess us for the years 2012 through 2016 using a similar methodology as for the years 2003 through 2011, and the reassessments will be issued on the basis we expect

• we will be able to apply elective deductions and utilize letters of credit to the extent anticipated

• CRA will seek to impose transfer pricing penalties (in a manner consistent with penalties charged in the years 2007 through 2010) in addition to interest charges and instalment penalties

• we will be substantially successful in our dispute with CRA and the cumulative tax provision of $58 million to date will be adequate to satisfy any tax liability resulting from the outcome of the dispute to date

• IRS may propose adjustments for later years subsequent to 2012

• we will be substantially successful in our dispute with IRS

Material risks that could cause actual results to differ materially

• CRA reassesses us for years 2012 through 2016 using a different methodology than for years 2003 through 2011, or we are unable to utilize elective deductions or letters of credit to the extent anticipated, resulting in the required cash payments or security provided to CRA pending the outcome of the dispute being higher than expected

• the time lag for the reassessments for each year is different than we currently expect

• we are unsuccessful and the outcomes of our dispute with CRA and/or IRS result in significantly higher cash taxes, interest charges and penalties than the amount of our cumulative tax provision, which could have a material adverse effect on our liquidity, financial position, results of operations and cash flows

• cash tax payable increases due to unanticipated adjustments by CRA or IRS not related to transfer pricing

• IRS proposes adjustments for years 2013 through 2015 using a different methodology than for 2009 through 2012

• we are unable to effectively eliminate all double taxation

Canadian royalties

We pay royalties on the sale of all uranium extracted at our mines in the province of Saskatchewan.

Two types of royalties are paid:

• Basic royalty: This royalty is calculated as 5% of gross sales of uranium, less the Saskatchewan resource credit of 0.75%.

• Profit royalty: A 10% royalty is charged on profit up to and including $22.62/kg U₃O₈ ($10.26/lb) and a 15% royalty is charged on profit in excess of $22.62/kg U₃O₈. Profit is determined as revenue less certain operating, exploration, reclamation and capital costs. Both exploration and capital costs are deductible at the discretion of the producer.

As a resource corporation in Saskatchewan, we also pay a corporate resource surcharge of 3.0% of the value of resource sales.

During the period from 2013 to 2015, transitional rules for the new profit royalty regime were applied whereby only 50% of capital costs were deductible. The remaining 50% was accumulated and was deductible beginning in 2016. In addition, the capital allowance related to Cigar Lake under the previous system was grandfathered and was also deductible beginning in 2016. As a result, only the first tier of the profit royalty (10%) applied in 2016 and we expect only the first tier (10%) to apply in 2017 as well. Beyond 2017, the applicable profit royalty tier(s) will depend on both profitability and the optional use of capital cost deductions.

Canadian income taxes

We are subject to federal income tax and provincial taxes in Saskatchewan and Ontario. Current income tax expense for 2016 was $3.45 million.

Our Ontario fuel services operations are eligible for a manufacturing and processing tax credit.

US taxes

Our subsidiaries in Wyoming and Nebraska pay severance taxes, property taxes and Ad Valorem taxes in those states. They incurred $4.28 million (US) in taxes in 2016.

Our US subsidiaries are subject to US federal and state income tax. They may also be subject to the Alternative Minimum Tax (AMT) at a rate of 20%. We can carry forward AMT paid in prior years indefinitely, and apply it as credit against future regular income taxes.

Kazakhstan taxes

The resource use contract lists the taxes, duties, fees, royalties and other governmental charges JV Inkai has to pay, subject to changes due to the elimination of the tax stabilization provision in October 2009 noted below.

2016 ANNUAL INFORMATION FORM    Page 98

On January 1, 2009, a new tax code of the Republic of Kazakhstan went into effect that includes a number of changes to the taxation regime of subsoil users. The most significant changes involve eliminating the stable tax regime, imposing a mineral extraction tax and changing the payment rate for commercial discovery.

Tax stabilization eliminated

In October 2009, at the request of the Kazakhstan Ministry of Energy and Mineral Resources, JV Inkai signed an amendment to the resource use contract to adopt the new tax code, eliminating the tax stabilization provision. While we do not expect this to have a material impact on JV Inkai at this time, eliminating the tax stabilization provision could be material in the future. See page 56 for more information about the resource use contract.

Corporate income tax rate

JV Inkai is subject to corporate income tax at a rate of 20%.

Mineral extraction tax

The tax code includes a Tax on Production of Useful Minerals, a mineral extraction tax replacing the previous royalty. The mineral extraction tax must be paid on each type of mineral and certain other substances that are extracted. The rate used to calculate the mineral extraction tax on uranium is currently 18.5%.

Payment for commercial discovery

Under the resource use contract, a one-time commercial discovery bonus of 0.05% of the value of Kazakh-defined recoverable reserves is paid when there is confirmation that Kazakh-defined recoverable reserves are located in a particular licence area. Under the tax code, the rate increased to 0.1%.

Excess profits tax

The tax code has changed the calculation of excess profits tax. JV Inkai believes it will not have to pay this tax for the foreseeable future.

2016 ANNUAL INFORMATION FORM    Page 99

Risks that can affect our business

There are risks in every business.

The nature of our business means we face many kinds of risks and hazards – some that relate to the nuclear energy industry in general, and others that apply to specific properties, operations or planned operations. These risks could have a significant impact on our business, earnings, cash flows, financial condition, results of operations or prospects.

The following section describes the risks that are most material to our business. This is not, however, a complete list of the potential risks we face – there may be others we are not aware of, or risks we feel are not material today that could become material in the future. Our risk policy and process involves a broad, systematic approach to identifying, assessing, reporting and managing the significant risks we face in our business and operations. However, there is no assurance that we will be successful in preventing the harm that any of these risks could cause.

Please also see the risk discussion in our 2016 MD&A.

Types of risk

Operational	100
Financial	105
Political	110
Regulatory	113
Environmental	114
Legal and other	115
Industry	116

1 – Operational risks

General operating risks and hazards

We are subject to a number of operational risks and hazards, many of which are beyond our control.

These risks and hazards include:

• environmental damage (including hazardous emissions from our refinery and conversion facilities, such as a release of UF₆ or a leak of anhydrous hydrogen fluoride used in the UF₆ conversion process)

• industrial and transportation accidents, which may involve radioactive or other hazardous materials

• labour shortages, disputes or strikes

• cost increases for labour, contracted or purchased materials, supplies and services

• shortages of required equipment, materials and supplies (including anhydrous hydrofluoric acid at our conversion facilities)

• transportation disruptions

• electrical power interruptions

• equipment failures

• catastrophic accident

• fires

• blockades or other acts of social or political activism

• regulatory constraints and non-compliance with laws and licences

• natural phenomena, such as inclement weather conditions, floods and earthquakes

• unusual or unexpected geological or hydrological conditions

• underground floods

• ground movement or cave-ins

• tailings pipeline or dam failures

• adverse mining conditions

• technological failure of mining methods.

• unanticipated consequences of our cost reduction strategies.

The operational changes we have made, and plan to make in 2017, carry with them an increase in our operational risk.

There is no assurance that any of the above risks will not result in:

2016 ANNUAL INFORMATION FORM    Page 100

• damage to or destruction of our properties and facilities located on these properties

• personal injury or death

• environmental damage

• delays in, or interruptions of, our exploration or development activities or transportation of our products

• delays in, interruptions of, or decrease in production at our operations

• costs, expenses or monetary losses

• legal liability

• adverse government action.

Any of these events could result in one or more of our operations becoming unprofitable, cause us not to receive an adequate return on invested capital, or have a material and adverse effect on our earnings, cash flows, financial condition, results of operations or prospects.

Insurance coverage

We buy insurance to cover losses or liabilities arising from some of the operating risks and hazards listed above, as well as other business risks. We believe we have a reasonable amount of coverage for the risks we choose to insure against. There is no assurance, however, that this coverage will be adequate in all circumstances, that it will continue to be available, that premiums will be economically feasible, or that we will maintain this coverage. Like other nuclear energy and mining companies, we do not have insurance coverage for certain environmental losses or liabilities and other risks, either because it is not available, or because it cannot be purchased at a reasonable cost. We may also be required to increase the amount of our insurance coverage due to changes in the regulation of the nuclear industry.

Not having the right insurance coverage or the right amount of coverage, or having to increase the amount of coverage or choosing not to insure against certain risks, could have a material and adverse effect on our earnings, cash flows, financial condition, results of operations or prospects.

Flooding at our Saskatchewan mines

All of our mines in Saskatchewan have had water inflows.

McArthur River

The sandstone that overlays the deposit and metasedimentary basement rock is water-bearing and more permeable, which results in significant water pressure at mining depths. Ground freezing at McArthur River generally prevents water from flowing into the area being mined and reduces, but does not eliminate, the risk of water inflows. There are technical challenges with the groundwater and rock properties.

We temporarily suspended production at our McArthur River mine in April 2003 because increased water inflow from an area of collapsed rock in a new development area began to flood portions of the mine. This caused a major setback in the development of new mining zones.

Cigar Lake

The Cigar Lake deposit has hydro-geological characteristics and technical challenges that are similar to those at McArthur River. We have had three water inflows at Cigar Lake since 2006 (please see page 41 for details).

These water inflows have caused:

• a significant delay in development and production at the property

• a significant increase in capital costs

• the need to notify many of our customers of the interruption in planned uranium supply.

Rabbit Lake

We temporarily reduced our underground activities at Rabbit Lake in November 2007, because there was an increase in water flow from a mining area while an equipment upgrade was limiting surface water-handling system capacity. Rabbit Lake resumed normal mining operations in late December 2007, after the source of the water inflow was plugged. We suspended mining activities at Rabbit Lake in 2016.

There is no guarantee that there will not be water inflows at McArthur River, Cigar Lake or Rabbit Lake in the future.

A water inflow could have a material and adverse effect on us, including:

2016 ANNUAL INFORMATION FORM    Page 101

• significant delays or interruptions in production or lower production

• significant delays or interruptions in mine development or remediation activities

• loss of mineral reserves

• a material increase in capital or operating costs.

It could also have a material and adverse effect on our earnings, cash flows, financial condition, results of operations or prospects. The degree of impact depends on the magnitude, location and timing of the flood or water inflow. Floods and water inflows are generally not insurable.

Technical challenges at Cigar Lake and McArthur River

The unique nature of the deposits at Cigar Lake and McArthur River pose many technical challenges, including groundwater management, unstable rock properties, radiation protection, ore-handling and transport and other mining-related challenges.

As we ramp up production at Cigar Lake, there may be some technical challenges, which could affect our production plans, including, but not limited to, variable or unanticipated ground conditions, ground movement and cave-ins, water inflows and variable dilution, recovery values, chemical ore characteristics, performance of the water treatment system, mining productivity, and equipment reliability. There is a risk that the ramp up to full production may take longer than planned and that the full production rate may not be achieved on a sustained and consistent basis.

The areas being mined at Cigar Lake must meet specific ground freezing requirements before we begin jet boring. We have identified greater variation of the freeze rates of different geological formations encountered in the mine, based on information obtained through surface freeze drilling.

The Cigar Lake orebody contains elements of concern with respect to water quality and the receiving environment. The distribution of elements such as arsenic, molybdenum, selenium and others is non-uniform throughout the orebody, and this can result in complications in attaining the effluent concentrations included in the licensing basis.

Metallurgical test work has been used to design the McClean Lake mill circuits and associated modifications relevant to Cigar Lake ore. Samples used for metallurgical test work may not be representative of the deposit as a whole. There is a risk that elevated arsenic concentration in the mill feed may result in increased leaching circuit solution temperatures.

If any of these technical challenges are not resolved, it could have a material and adverse effect on our earnings, cash flows, financial condition, results of operations or prospects.

Mine Concentration Risk

With our Tier One strategy, our main sources of uranium production are our mines at McArthur River (47% of 2016 production), Cigar Lake (32% of 2016 production) and Inkai (13% of 2016 production). Any disruption in or reduction in production from one or more of these mines could have a material and adverse effect on our earnings, cash flows, financial condition, results of operations or prospects.

Information Technology Systems

We have become increasingly dependent on the availability and integrity of our electronic information and the reliability of our information technology systems and infrastructure. We rely on our information technology to process, transmit and store electronic information, including information we use to safely operate our assets.

Cyber attackers may use a range of techniques, from manipulating people to using sophisticated malicious software and hardware on a single or distributed basis. Often, advanced cyber attackers use a combination of techniques in their attempt to evade safeguards and delay discovery of a cyber-attack. We take measures to secure our infrastructure against potential cyber-attacks that may damage our infrastructure, systems and data. We have implemented a defense in depth security program to secure and protect our information and business operations including formalizing and implementing an information security policy, user awareness training, introducing system security configuration standards and access control measures.

To reduce the risk of successful cyber-attacks and to reduce the impact of any successful cyber-attacks, we have implemented several layers of perimeter and endpoint security defense and response mechanisms, security event logging and monitoring of network activities, and developed a cyber incident response process.

2016 ANNUAL INFORMATION FORM    Page 102

Despite the measures put in place to protect our systems and data, there can be no assurance that these measures will be sufficient and that such security breaches will not occur or, if they do occur, that they will be adequately addressed in a timely manner.

Such a breach could result in unauthorized access to proprietary or sensitive information, destruction or corruption of data, disruption or delay in our business activities, and a negative effect on our reputation. Disruption of critical information technology services or breaches of information security could have a material and adverse effect on our earnings, cash flows, financial condition or results of operations.

Replacement of depleted reserves

The McArthur River, Cigar Lake and Inkai mines are currently our main sources of mined uranium concentrates. We must replace mineral reserves depleted by production at these mines to maintain or increase our annual production levels over the long term. Reserves can be replaced by expanding known orebodies, locating new deposits or making acquisitions. Substantial expenditures are required to establish new mineral reserves. We may not be able to sustain or increase production if:

• we do not identify, discover or acquire other deposits

• we do not find extensions to existing ore bodies

• we do not convert resources to reserves at our mines or other projects.

This could have a material and adverse effect on our ability to maintain production to or beyond currently contemplated mine lives, as well as a material and adverse effect on our earnings, cash flows, financial condition, results of operations or prospects.

Although we have successfully replenished reserves in the past through ongoing exploration, development and acquisition programs, there is no assurance that we will be successful in our current or future exploration, development or acquisition efforts.

Tailings management

Our Key Lake mill produces tailings. Managing these tailings is integral to uranium production.

If sloughing, regulatory, or other issues prevent us from maintaining or increasing the existing tailings management capacity at our Key Lake mill, or if these issues prevent AREVA from maintaining or increasing tailing capacity at the McClean Lake mill, uranium production could be constrained and this could have a material and adverse effect on our earnings, cash flows, financial condition or results of operations.

Reliance on development and expansion projects to sustain production and fuel growth

Our ability to sustain and increase our uranium production depends in part on successfully developing new mines and/or expanding existing operations.

Several factors affect the economics and success of these projects:

•       capital and operating costs   •       metallurgical recoveries   •       the accuracy of reserve estimates   •       government regulations   •       availability of appropriate infrastructure, particularly power and water •       future uranium prices   •       the accuracy of feasibility studies   •       acquiring surface or other land rights   •       receiving necessary government permits.

Generally development projects have no operating history that can be used to estimate future cash flows. We have to invest a substantial amount of capital and time to develop a project and achieve commercial production. A change in costs or construction schedule can affect the economics of a project. Actual costs could increase significantly and economic returns could be materially different from our estimates. We could fail to obtain the necessary governmental approvals for construction or operation. In any of these situations, a project might not proceed according to its original timing, or at all.

2016 ANNUAL INFORMATION FORM    Page 103

It is not unusual in the nuclear energy or mining industries for new or expanded operations to experience unexpected problems during start-up or ramp-up, resulting in delays, higher capital expenditures than anticipated and reductions in planned production. Delays, additional costs or reduced production could have a material and adverse effect on our earnings, cash flows, financial condition, results of operations or prospects.

There is no assurance we will be able to complete the development of new mines, or expand existing operations, economically or on a timely basis.

Aging facilities

Our Port Hope fuel services facilities are aging. This exposes us to a number of risks, including the potential for higher maintenance and operating costs, the need for significant capital expenditures to upgrade and refurbish these facilities, the potential for decreases or delays in, or interruption of, fuel services production, and the potential for environmental damage.

These risks could have a material and adverse effect on our earnings, cash flows, financial condition or results of operations.

Labour and employment

People are core to our business. We compete with other nuclear energy and mining companies for talented, quality people, and we may not always be able to fill positions on a timely basis. There is a limited pool of skilled people and competition is intense. We also experience employee turnover because of an aging workforce.

If we cannot attract and train qualified successors for our senior and operating positions, it could reduce the efficiency of our operations and have an adverse effect on our earnings, cash flows, financial condition or results of operations.

We have unionized employees and face the risk of strikes. At December 31, 2016, we had 3,580 employees (including employees of our subsidiaries). This includes 830 unionized employees at McArthur River, Key Lake, Port Hope and at CFM’s facilities, who are members of four different locals of the United Steelworkers trade union.

Collective agreements

• The collective agreements with the bargaining unit employees at our conversion facilities at Port Hope expires June 2019.

• The collective agreement with the bargaining unit employees at the McArthur River and Key Lake operations expires December 31, 2017.

• The collective agreement with the bargaining unit employees at CFM expires June 2018.

We cannot predict whether we will reach new collective agreements with these and other employees without a work stoppage or work interruptions while negotiations are underway.

From time to time, the mining or nuclear energy industry experiences a shortage of tradespeople and other skilled or experienced personnel globally, regionally or locally. We have a comprehensive strategy to attract and retain high calibre people, but there is no assurance this strategy will protect us from the effects of a labour shortage.

A lengthy work interruption or labour shortage could have an adverse effect on our earnings, cash flows, financial condition or results of operations.

Joint ventures

We participate in McArthur River, Key Lake, Cigar Lake, Inkai, Millennium, Kintyre and GLE through joint ventures with third parties. Some of these joint ventures are unincorporated and some are incorporated (like JV Inkai and GLE). We have other joint ventures and may enter into more in the future.

There are risks associated with joint ventures, including:

• disagreement with a joint venture participant about how to develop, operate or finance a project

• a joint venture participant not complying with a joint venture agreement

• possible litigation between joint venture participants about joint venture matters

• the inability to exert control over decisions related to a joint venture we do not have a controlling interest in.

2016 ANNUAL INFORMATION FORM    Page 104

Our joint venture participant in Kazakhstan is a state entity, so its actions and priorities could be dictated by government policies instead of commercial considerations.

These risks could result in legal liability, affect our ability to develop or operate a project under a joint venture, or have a material and adverse effect on our earnings, cash flows, financial condition or results of operations.

Supplies and contractors

Supplies

We buy reagents and other production inputs and supplies from suppliers around the world. If there is a shortage of any of these supplies, including parts and equipment, or their costs rise significantly, it could limit or interrupt production or increase production costs. It could also have an adverse effect on our ability to carry out operations or have a material and adverse effect on our earnings, cash flows, financial condition or results of operations. We examine our entire supply chain as necessary to identify areas to diversify or add inventory where we may be vulnerable, but there is no assurance that we will be able to mitigate the risk.

Contractors

In some cases we rely on a single contractor to provide us with reagents or other production inputs and supplies. Relying on a single contractor is a security supply risk because we may not receive quality service, timely service, or service that otherwise meets our needs. These risks could have a material and adverse effect on our earnings, cash flows, financial condition or results of operations.

Uranium exploration is highly speculative

Uranium exploration is highly speculative and involves many risks, and few properties that are explored are ultimately developed into producing mines.

Even if mineralization is discovered, it can take several years in the initial phases of drilling until a production decision is possible, and the economic feasibility of developing an exploration property may change over time. We are required to make a substantial investment to establish proven and probable mineral reserves, to determine the optimal metallurgical process to extract minerals from the ore, to construct mining and processing facilities (in the case of new properties) and to extract and process the ore. We might abandon an exploration project because of poor results or because we feel that we cannot economically mine the mineralization.

Given these uncertainties, there is no assurance that our exploration activities will be successful and result in new reserves to expand or replace our current mineral reserves.

Infrastructure

Mining, processing, development and exploration can only be successful with adequate infrastructure. Reliable roads, bridges, power sources and water supply are important factors that affect capital and operating costs and the ability to deliver products on a timely basis.

Our activities could be negatively affected if unusual weather, interference from communities, government or others, aging, sabotage or other causes affect the quality or reliability of the infrastructure.

A lack of adequate infrastructure could have a material and adverse effect on our earnings, cash flows, financial condition or results of operations.

2 – Financial risks

Volatility and sensitivity to prices

We are concentrated in the nuclear fuel business, with our primary focus on uranium mining. As such, our earnings and cash flow are closely related to, and sensitive to, fluctuations in the long and short-term market prices of U₃O₈ and uranium conversion services.

2016 ANNUAL INFORMATION FORM    Page 105

Many factors beyond our control affect these prices, including the following, among others:

• demand for nuclear power

• forward contracts of U₃O₈ supplies for nuclear power plants

• political and economic conditions in countries producing and buying uranium

• reprocessing of used reactor fuel and the re-enrichment of depleted uranium tails

• sales of excess civilian and military inventories of uranium by governments and industry participants

• levels of uranium production and production costs

• significant interruptions in production or delays in expansion plans or new mines going into production

• investment and hedge fund activity in the uranium market.

We cannot predict the effect that any one or all of these factors will have on the price of U₃O₈ and uranium conversion services. Prices have fluctuated widely in the last several years, and there have been significant declines in U₃O₈ prices since 2011.

The table below shows the range in spot prices over the last five years.

Range of spot uranium prices US$/lb of U3O8
	2012		2013		2014		2015		2016
High	$	52.13	$	43.88	$	39.50	$	39.45	$	34.70
Low		41.75		34.50		28.23		34.23		18.00
Spot UF6 conversion values US$/kg U
High	$	10.50	$	10.50	$	8.25	$	8.25	$	6.88
Low		6.63		8.50		7.25		6.88		5.93

The next table shows the range in term prices over the last five years.

Range of term uranium prices US$/lb of U3O8
	2012		2013		2014		2015		2016
High	$	61.25	$	57.00	$	50.00	$	49.50	$	44.00
Low		56.50		50.00		44.00		44.00		30.00
Term UF6 conversion values US$/kg U
High	$	16.75	$	16.75	$	16.00	$	16.00	$	12.75
Low		16.75		16.00		16.00		13.50		12.25

Notes

(1) Spot and term uranium prices are the average of prices published monthly by Ux Consulting and from The Nuexco Exchange Value, published by TradeTech.

(2) Spot and term UF₆ conversion values are the average of the North American prices published monthly by Ux Consulting and from The Nuexco Conversion Value, published by TradeTech.

If prices for U₃O₈ or uranium conversion services fall below our own production costs for a sustained period, continued production or conversion at our sites may cease to be profitable. This would have a material and adverse effect on our earnings, cash flows, financial condition, results of operations or prospects. In 2016, we suspended production at Rabbit Lake and curtailed production at our US mines.

Declines in U₃O₈ prices could also delay or deter a decision to build or begin commercial production at one or more of our development projects, or adversely affect our ability to finance these development projects. Either of these could have an adverse effect on our future earnings, cash flows, financial condition, results of operations or prospects.

2016 ANNUAL INFORMATION FORM    Page 106

A sustained decline in U₃O₈ prices may require us to write down our mineral reserves and mineral resources, and any significant write downs may lead to material write downs of our investment in the mining properties affected, and an increase in charges for amortization, reclamation and closures.

In our uranium segment, we use a uranium marketing strategy as a way to reduce volatility in our future earnings and cash flow from exposure to fluctuations in uranium prices. It involves building a portfolio that consists of fixed-price contracts and market-related contracts with terms of 5 to 10 years (on average). This strategy can create opportunity losses because we may not benefit fully if there is a significant increase in U₃O₈ prices. This strategy also creates currency risk since we receive payment under the majority of our sales contracts in US$. In addition, this strategy has provided us with a measure of protection for our business through the low uranium prices experienced since 2011. Based upon our current contract portfolio and current level of production, we are heavily committed under long-term contracts through 2019, however those commitments begin to decrease starting in 2020. As a result, we may become more exposed to fluctuations in uranium prices and this could have an adverse effect on our future earnings, cash flows, financial condition, results of operations or prospects. There is no assurance that our contracting strategy will be successful.

Through our uranium segment and NUKEM, we make purchases on the spot market and under long-term agreements so we can put material into higher priced contracts. There are, however, risks associated with these purchases, including the risk of losses, which could have an adverse effect on our earnings, cash flows, financial condition or results of operations.

Reserve, resource, production, capital and operating cost estimates

Reserve and resource estimates are not precise

Our mineral reserves and resources are the foundation of our uranium mining operations. They dictate how much uranium concentrate we can produce, and for how many years.

The uranium mineral reserves and resources reported in this AIF are estimates, and are therefore subjective. There is no assurance that the indicated tonnages or grades of uranium will be mined or milled or that we will receive the uranium price we used in estimating these reserves.

While we believe that the mineral reserve and resource estimates included in this AIF are well established and reflect management’s best estimates, reserve and resource estimates, by their nature, are imprecise, do not reflect exact quantities and depend to a certain extent on statistical inferences that may ultimately prove unreliable. The volume and grade of reserves we actually recover, and rates of production from our current mineral reserves, may be less than the estimate of the reserves. Fluctuations in the market price of uranium, changing exchange rates and operating and capital costs can make reserves uneconomic to mine in the future and ultimately cause us to reduce our reserves.

Short-term operating factors relating to mineral reserves, like the need for orderly development of orebodies or the processing of different ore grades, can also prompt us to modify reserve estimates or make reserves uneconomic to mine in the future, and can ultimately cause us to reduce our reserves. Reserves also may have to be re-estimated based on actual production experience.

Mineral resources may ultimately be reclassified as proven or probable mineral reserves if they demonstrate profitable recovery. Estimating reserves or resources is always affected by economic and technological factors, which can change over time, and experience in using a particular mining method. There is no assurance that any resource estimate will ultimately be reclassified as proven or probable reserves. If we do not obtain or maintain the necessary permits or government approvals, or there are changes to applicable legislation, it could cause us to reduce our reserves.

Mineral resource and reserve estimates can be uncertain because they are based on data from limited sampling and drilling and not from the entire orebody. As we gain more knowledge and understanding of an orebody, the resource and reserve estimate may change significantly, either positively or negatively.

If our mineral reserve or resource estimates for our uranium properties are inaccurate or are reduced in the future, it could:

• require us to write down the value of a property

• result in lower uranium concentrate production than previously estimated

• require us to incur increased capital or operating costs, or

• require us to operate mines or facilities unprofitably.

2016 ANNUAL INFORMATION FORM    Page 107

This could have a material and adverse effect on our earnings, cash flows, financial condition or results of operations or prospects.

Production, capital and operating cost estimates may be inaccurate

We prepare estimates of future production, capital costs and operating costs for particular operations, but there is no assurance we will achieve these estimates. Estimates of expected future production, capital costs and operating costs are inherently uncertain, particularly beyond one year, and could change materially over time.

Production, capital cost and operating cost estimates for:

• McArthur River assume that development, mining and production plans proceed as expected

• Cigar Lake assume that development, mining and production plans proceed as expected

• Inkai assume that development, mining and production plans proceed as expected.

Production estimates for uranium refining, conversion and fuel manufacturing assume there is no disruption or reduction in supply from us or third party sources, and that estimated rates and costs of processing are accurate, among other things.

Our actual production and costs may vary from estimates for a variety of reasons, including, among others:

• actual ore mined varying from estimated grade, tonnage, dilution, metallurgical and other characteristics

• mining and milling losses greater than planned

• short-term operating factors relating to the ore, such as the need for sequential development of orebodies and the processing of new or different ore grades

• risk and hazards associated with mining, milling, uranium refining, conversion and fuel manufacturing

• failure of mining methods and plans

• failure to obtain and maintain the necessary regulatory and participant approvals

• natural phenomena, such as inclement weather conditions or floods

• labour shortages or strikes

• development, mining or production plans for McArthur River are delayed or do not succeed for any reason

• development, mining or production plans for Cigar Lake are delayed or do not succeed for any reason

• difficulties in milling Cigar Lake ore at McClean Lake

• development, mining or production plans for Inkai are delayed or do not succeed for any reason

• delays, interruption or reduction in production or construction activities due to fires, failure or unavailability of critical equipment, shortage of supplies, underground floods, earthquakes, tailings dam failures, lack of tailings capacity, ground movements and cave-ins, unanticipated consequences of our cost reduction strategies, or other difficulties.

Operating costs may also be affected by a variety of factors including: changing waste to ore ratios, ore grade metallurgy, labour costs, costs of supplies and services (for example, fuel and power), general inflationary pressures and currency exchange rates.

Failure to achieve production or cost estimates or a material increase in costs could have a material and adverse effect on our earnings, cash flows, financial condition or results of operations.

Currency fluctuations

Our earnings and cash flow may also be affected by fluctuations in the exchange rate between the Canadian and US dollar. Our sales of uranium and conversion services are mostly denominated in US dollars, while the production costs of both are denominated primarily in Canadian dollars. Our consolidated financial statements are expressed in Canadian dollars.

Any fluctuations in the exchange rate between the US dollar and Canadian dollar can result in favourable and unfavourable foreign currency exposure, which can have a material effect on our future earnings, cash flows, financial condition or results of operations, as has been the case in the past. While we use a hedging program to limit any adverse effects of fluctuations in foreign exchange rates, there is no assurance that these hedges will eliminate the potential material negative impact of fluctuating exchange rates.

2016 ANNUAL INFORMATION FORM    Page 108

Customers

Our main business relates to the production and sale of uranium concentrates (our uranium segment) and providing uranium conversion services (our fuel services segment). We rely heavily on a small number of customers to purchase a significant portion of our uranium concentrates and conversion services.

From 2017 through 2019, we expect:

• in our uranium segment, our five largest customers to account for 53% of our contracted supply of U₃O₈

• in our fuel services segment, our five largest UF₆ conversion customers to account for 51% of our contracted supply of UF₆ conversion services.

We are a supplier of UO₂ used by Canadian CANDU heavy water reactors. Our sales to our largest customer accounted for 35% of our UO₂ sales in 2016.

In addition, revenues in 2016 from one customer of our uranium, conversion and NUKEM segments represented $223 million (9%) of our total revenues from those businesses. Sales for the Bruce A and B reactors represent a substantial portion of our fuel manufacturing business.

We are currently involved in a dispute with TEPCO regarding its contract termination notice, alleging force majeure, with respect to a uranium supply agreement that it would not withdraw. See 2017 Major Developments on page 7 for details

If we lose any of our largest customers or if any of them curtails their purchases, it could have a material and adverse effect on our earnings, cash flows, financial condition or results of operations.

Counterparty and credit risk

Our business operations expose us to the risk of counterparties not meeting their contractual obligations, including:

• customers

• suppliers

• financial institutions and other counterparties to our derivative financial instruments and hedging arrangements relating to foreign currency exchange rates and interest rates

• financial institutions which hold our cash on deposit

• insurance providers.

Credit risk is the risk that counterparties will not be able to pay for services provided under the terms of the contract. If a counterparty to any of our significant contracts defaults on a payment or other obligation or becomes insolvent, it could have a material and adverse effect on our cash flows, earnings, financial condition or results of operations.

Uranium products, conversion and fuel services

In our uranium and fuel services segments, we manage the credit risk of our customers for uranium products, conversion and fuel services by:

• monitoring their creditworthiness

• asking for pre-payment or another form of security if they pose an unacceptable level of credit risk.

As of February 1, 2017, 97% of our forecast revenue under contract for the period 2017 to 2019 is with customers whose creditworthiness meets our standards for unsecured payment terms.

Other

We manage the credit risk on our derivative and hedging arrangements, cash deposits and insurance policies by dealing with financial institutions and insurers that meet our credit rating standards and by limiting our exposure to individual counterparties.

We diversify or increase inventory in our supply chain to limit our reliance on a single contractor, or limited number of contractors. We also monitor the creditworthiness of our suppliers to manage the risk of suppliers defaulting on delivery commitments.

There is no assurance, however, that we will be successful in our efforts to manage the risk of default or credit risk.

2016 ANNUAL INFORMATION FORM    Page 109

Liquidity and financing

Nuclear energy and mining are extremely capital intensive businesses, and companies need significant ongoing capital to maintain and improve existing operations, invest in large scale capital projects with long lead times, and manage uncertain development and permitting timelines and the volatility associated with fluctuating uranium and input prices.

We believe our current financial resources are sufficient to support the projects we have planned for 2017. If we expand our projects or programs overall, we may need to raise additional financing through joint ventures, debt financing, equity financing or other means.

There is no assurance that we will obtain the financing we need, when we need it. Volatile uranium markets, a claim against us, an adverse decision by the court in our CRA litigation, a significant event disrupting our business or operations, or other factors may make it difficult or impossible for us to obtain debt or equity financing on favourable terms, or at all.

Operating and capital plans

We establish our operating and capital plans based on the information we have at the time, including expert opinions. There is no assurance, however, that these plans will not change as new information becomes available or there is a change in expert opinion.

Pre-feasibility and feasibility studies contain estimated capital and operating costs, production and economic returns and other estimates that may be significantly different than actual results, and there is no assurance that they will not be different than anticipated or than what was disclosed in the studies. Our estimates may also be different from those of other companies, so they should not be used to project operating profit.

Internal controls

We use internal controls over financial reporting to provide reasonable assurance that we authorize transactions, safeguard assets against improper or unauthorized use, and record and report transactions properly. This gives us reasonable assurance that our financial reporting is reliable, and prepared in accordance with IFRS.

It is impossible for any system to provide absolute assurance or guarantee reliability, regardless of how well it is designed or operated. We continue to evaluate our internal controls to identify areas for improvement and provide as much assurance as reasonably possible. We conduct an annual assessment of our internal controls over financial reporting and produce an attestation report of their effectiveness by our independent auditors to meet the requirement of Section 404 of the Sarbanes-Oxley Act of 2002.

If we do not satisfy the requirements for internal controls on an ongoing, timely basis, it could negatively affect investor confidence in our financial reporting, which could have an impact on our business and the trading price of our common shares. If a deficiency is identified and we do not introduce new or better controls, or have difficulty implementing them, it could harm our financial results or our ability to meet reporting obligations.

Carrying values of assets

We evaluate the carrying value of our assets to decide whether current events and circumstances indicate whether or not we can recover the carrying amount. This involves comparing the estimated fair value of our reporting units to their carrying values.

We base our fair value estimates on various assumptions, however, the actual fair values can be significantly different than the estimates. If we do not have any mitigating valuation factors or experience a decline in the fair value of our reporting units, it could ultimately result in an impairment charge.

3 – Political risks

Foreign investments and operations

We do business in countries and jurisdictions outside of Canada and the United States, including the developing world. Doing business in these countries poses risks because they have different economic, cultural, regulatory and political environments.

2016 ANNUAL INFORMATION FORM    Page 110

Future economic and political conditions could also cause the governments of these countries to change their policies on foreign investments, development and ownership of resources, or impose other restrictions, limitations or requirements that we may not foresee today.

Risks related to doing business in a foreign country can include:

• uncertain legal, political and economic environments

• strong governmental control and regulation

• lack of an independent judiciary

• war, terrorism and civil disturbances

• crime, corruption, making improper payments or providing benefits that may violate Canadian or United States law or laws relating to foreign corrupt practices

• unexpected changes in governments and regulatory officials

• uncertainty or disputes as to the authority of regulatory officials

• changes in a country’s laws or policies, including those related to mineral tenure, mining, imports, exports, tax, duties and currency

• cancellation or renegotiation of permits or contracts

• royalty and tax increases or other claims by government entities, including retroactive claims

• expropriation and nationalization

• delays in obtaining the necessary permits or the inability to obtain or maintain them

• currency fluctuations

• high inflation

• joint venture participants falling out of political favour

• restrictions on local operating companies selling their production offshore, and holding US dollars or other foreign currencies in offshore bank accounts

• import and export regulations, including restrictions on the export of uranium

• limitations on the repatriation of earnings

• increased financing costs.

If one or more of these risks occur, it could have a material and adverse effect on our earnings, cash flows, financial condition, results of operations or prospects.

We also risk being at a competitive disadvantage to companies from countries that are not subject to Canadian or United States law or laws relating to foreign corrupt practices.

We enter into joint venture arrangements with local participants from time to time to mitigate political risk. There is no assurance that these joint ventures will mitigate our political risk in a foreign jurisdiction.

We assess the political risk associated with each of our foreign investments and have political risk insurance to mitigate part of the losses that can arise from some of these risks. From time to time, we assess the costs and benefits of maintaining this insurance and may decide not to buy this coverage in the future. There is no assurance that the insurance will be adequate to cover every loss related to our foreign investments, that coverage will continue to be available or that premiums will be economically feasible. These losses could have a material and adverse effect on our earnings, cash flows, financial condition, results of operations or prospects if they are not adequately covered by insurance.

Kazakhstan

JV Inkai has a contract with the Kazakhstan government and was granted licences to conduct mining and exploration activities there. Its ability to conduct these activities, however, depends on licences being renewed and other government approvals being granted.

To maintain and increase production at Inkai, we need ongoing support, agreement and co-operation from Kazatomprom and from the Kazakhstan government. Kazakhstan foreign investment, environmental and mining laws and regulations are complex and still developing, so it can be difficult to predict how they will be applied. JV Inkai’s best efforts may therefore not always reflect full compliance with the law, and non-compliance can lead to an outcome that is disproportionate to the nature of the breach.

Subsoil law

Amendments to the subsoil law in 2007 allow the government to reopen resource use contracts in certain circumstances, and in 2009, the Kazakhstan government passed a resolution that classified 231 blocks, including all three Inkai blocks, as strategic deposits. The Kazakhstan government re-approved this list in 2011 and the three Inkai blocks remain on it. These actions may increase the government’s ability to expropriate JV Inkai’s properties in certain situations. In 2009, at the request of the Kazakhstan government, JV Inkai amended the resource use contract to adopt a new tax code, even though the government had agreed to tax stabilization provisions in the original contract.

2016 ANNUAL INFORMATION FORM    Page 111

A new subsoil use law which went into effect in 2010 and was amended most recently in 2016 weakens the stabilization guarantee of the prior law. This development reflects increased political risk in Kazakhstan.

The Kazakhstan government is developing a new subsoil law to replace the current subsoil law. The December 2016 draft of the new law does not address licences issued and resource use contracts executed before its enactment. Therefore, the status of JV Inkai’s resource use contract and licences under the proposed law is unclear. This development also reflects increased political risk in Kazakhstan.

Nationalization

Industries like mineral production are regarded as nationally or strategically important, but there is no assurance they will not be expropriated or nationalized. Government policy can change to discourage foreign investment and nationalize mineral production, or the government can implement new limitations, restrictions or requirements.

There is no assurance that our assets in Kazakhstan will not be nationalized, taken over or confiscated by any authority or body, whether the action is legitimate or not. While there are provisions for compensation and reimbursement of losses to investors under these circumstances, there is no assurance that these provisions would restore the value of our original investment or fully compensate us for the investment loss. This could have a material and adverse effect on our earnings, cash flows, financial condition, results of operations or prospects.

Government regulations

Our operations in Kazakhstan may be affected in varying degrees by government regulations restricting production, price controls, export controls, currency controls, taxes and royalties, expropriation of property, environmental, mining and safety legislation, and annual fees to maintain mineral properties in good standing. There is no assurance that the laws in Kazakhstan protecting foreign investments will not be amended or abolished, or that these existing laws will be enforced or interpreted to provide adequate protection against any or all of the risks described above. There is also no assurance that the resource use contract can be enforced or will provide adequate protection against any or all of the risks described above.

2016 Implementation Agreement

In 2016, we signed the Implementation Agreement with Kazatomprom and JV Inkai to restructure and enhance Inkai. (See page 55 for details). The Implementation Agreement is subject to obtaining all required government approvals, including amendments to the resource use contract, which in February 2017, we estimated it would take 10 to 18 months to obtain. There is a risk that all required government approvals to close, or give effect to, the contemplated transactions, including approval of the amendments to the resource use contract from Kazakhstan state authorities, will not be received or will not be received on a timely basis. This could have a material and adverse effect on our earnings, cash flows, financial condition, results of operations or prospects.

Block 3 Exploration Period Expiry

The block 3 exploration area at Inkai is governed by an exploration licence granted by the Kazakhstan government. Amendment No. 5 to JV Inkai’s resource use contract granted an extension of the exploration period to July 13, 2018. There is a risk that JV Inkai may not complete the work on the final appraisal of block 3’s mineral potential prior to July 13, 2018 and a further extension may be required. There is no assurance that a further extension will be granted or what the terms and conditions of such an extension would be. This may result in the loss of block 3 without compensation for the loss of JV Inkai’s investment.

Cameco, through a subsidiary, advanced funds for JV Inkai’s exploration and evaluation work on block 3 and, as of December 31, 2016, the principal and interest amounted to $168 million (US). Under the loan agreement, JV Inkai is to repay Cameco from the proceeds of the sale of its production. On January 20, 2017, a payment of $30 million (US) was received. If the loan remains outstanding on July 13, 2018, and an extension of the block 3 exploration period is required to complete the final appraisal, there is a risk we may not be repaid.

Cameco believes that the risk will be mitigated if the Implementation Agreement closes prior to July 13, 2018 as the Implementation Agreement provides, subject to closing, that the loan made by a Cameco subsidiary to JV Inkai to fund exploration and evaluation of block 3 will be restructured to provide payment on a priority basis.    

See pages 57 to 60 for a more detailed discussion of the regulatory and political environment in Kazakhstan.

2016 ANNUAL INFORMATION FORM    Page 112

Australia

Western Australian Government’s uranium policy

State governments in Australia have prohibited uranium mining or uranium exploration from time to time, and from 2002 to 2008, uranium mining was banned in Western Australia, where our Kintyre and Yeelirrie projects are located. A prohibition or restriction on uranium exploration or mining in the future that interferes with the development of Kintyre or Yeelirrie could have a material and adverse effect on our earnings, cash flows, financial condition, results of operations or prospects.

4 – Regulatory risks

Government laws and regulation

Our business activities are subject to extensive and complex laws and regulations.

There are laws and regulations for uranium exploration, development, mining, milling, refining, conversion, fuel manufacturing, transport, exports, imports, taxes and royalties, labour standards, occupational health, waste disposal, protection and remediation of the environment, decommissioning and reclamation, safety, hazardous substances, emergency response, land use, water use and other matters.

Significant financial and management resources are required to comply with these laws and regulations, and this will likely continue as laws and government regulations become more and more strict. We are unable to predict the ultimate cost of compliance or its effect on our business because legal requirements change frequently, are subject to interpretation and may be enforced to varying degrees.

Some of our operations are regulated by government agencies that exercise discretionary powers conferred by statute. If these agencies do not apply their discretionary authority consistently, then we may not be able to predict the ultimate cost of complying with these requirements or their effect on operations.

Existing, new or changing laws, regulations and standards of regulatory enforcement could increase costs, lower, delay or interrupt production or affect decisions about whether to continue with existing operations or development projects. This could have a material and adverse effect on our earnings, cash flows, financial condition, results of operations or prospects.

If we do not comply with the laws and regulations that apply to our business, or it is alleged we do not comply then regulatory or judicial authorities could take any number of enforcement actions, including:

• corrective measures that require us to increase capital or operating expenditures or install additional equipment

• remedial actions that result in temporary or permanent shut-down or reduction of our operations

• requirements that we compensate communities that suffer loss or damage because of our activities

• civil or criminal fines or penalties.

Legal and political circumstances are different outside North America, which can change the nature of regulatory risks in foreign jurisdictions when compared with regulatory risks associated with operations in North America.

Permitting and licensing

All mining projects and processing facilities around the world require government approvals, licences or permits, and our operations and development projects in Canada, the US, Kazakhstan and Australia are no exception. Depending on the location of the project, this can be a complex and time consuming process involving multiple government agencies.

We have to obtain and maintain many approvals, licences and permits from the appropriate regulatory authorities, but there is no assurance that they will grant or renew them, approve any additional licences or permits for potential changes to our operations in the future or in response to new legislation, or that they will process any of the applications on a timely basis. Stakeholders, like environmental groups, non-government organizations (NGOs) and aboriginal groups claiming rights to traditional lands, can raise legal challenges. A significant delay in obtaining or renewing the necessary approvals, licences or permits, or failure to receive the necessary approvals, licences or permits, could interrupt our operations or prevent them from operating, which could have a material and adverse effect on our earnings, cash flows, financial condition, results of operations or prospects.

2016 ANNUAL INFORMATION FORM    Page 113

5 – Environmental risks

Complex legislation and environmental, health and safety risk

Our activities have an impact on the environment, so our operations are subject to extensive and complex laws and regulations relating to the protection of the environment, employee health and safety and waste management. We also face risks that are unique to uranium mining, processing and fuel manufacturing. Laws to protect the environment as well as employee health and safety are becoming more stringent for members of the nuclear energy industry.

Our facilities operate under various operating and environmental approvals, licences and permits that have conditions that we must meet as part of our regular business activities. In a number of instances, our right to continue operating these facilities depends on our compliance with these conditions.

Our ability to obtain approvals, licences and permits, maintain them, and successfully develop and operate our facilities may be adversely affected by the real or perceived impact of our activities on the environment and human health and safety at our development projects and operations and in the surrounding communities. The real or perceived impact of activities of other nuclear energy or mining companies can also have an adverse effect on our ability to secure and maintain approvals, licences and permits.

Our compliance with laws and regulations relating to the protection of the environment, employee health and safety, and waste management requires significant expenditures and can cause delays in production or project development. This has been the case in the past and may be so in the future. Failing to comply can lead to fines and penalties, temporary or permanent suspension of development and operational activities, clean-up costs, damages and the loss of, or the inability to obtain, key approvals, permits and licences. We are exposed to these potential liabilities for our current development projects and operations as well as operations that have been closed. There is no assurance that we have been or will be in full compliance with all of these laws and regulations, or with all the necessary approvals, permits and licences.

Laws and regulations on the environment, employee health and safety, and waste management continue to evolve and this can create significant uncertainty around the environmental, employee health and safety, and waste management costs we incur. If new legislation and regulations are introduced in the future, they could lead to additional capital and operating costs, restrictions and delays at existing operations or development projects, and the extent of any of these possible changes cannot be predicted in a meaningful way.

Environmental and regulatory review is a long and complex process that can delay the opening, modification or expansion of a mine, conversion facility or refining facility, or extend decommissioning activities at a closed mine or other facility.

Our ability to foster and maintain the support of local communities and governments for our development projects and operations is critical to the conduct and growth of our business, and we do this by engaging in dialogue and consulting with them about our activities and the social and economic benefits they will generate. There is no assurance, however, that this support can be fostered or maintained. There is an increasing level of public concern relating to the perceived effect that nuclear energy and mining activities have on the environment and communities affected by the activities. Some NGOs are vocal critics of the nuclear energy and mining industries, and oppose globalization, nuclear energy and resource development. Adverse publicity generated by these NGOs or others, related to the nuclear energy industry or the extractive industry in general, or our operations in particular, could have an adverse effect on our reputation or financial condition and may affect our relationship with the communities we operate in. While we are committed to operating in a socially responsible way, there is no guarantee that our efforts will mitigate this risk.

These risks could delay or interrupt our operations or project development activities, delay, interrupt or lower our production and have a material and adverse effect on our earnings, cash flows, financial condition, results of operations or prospects.

Decommissioning and reclamation obligations

Environmental regulators are demanding more and more financial assurances so that the parties involved, and not the government, bear the cost of decommissioning and reclaiming sites.

We have filed conceptual decommissioning plans for some of our properties with the regulators. We review these plans for Canadian facilities every five years, or at the time of an amendment or renewal of an operating licence. Plans for our US sites are reviewed every year. Regulators review our conceptual plans on a regular basis. As the sites approach or go into

2016 ANNUAL INFORMATION FORM    Page 114

decommissioning, regulators review the detailed decommissioning plans, and this can lead to additional requirements, costs and financial assurances. It is not possible to predict what level of decommissioning and reclamation and financial assurances regulators may require in the future.

If we must comply with additional regulations, or the actual cost of decommissioning and reclamation in the future is significantly higher than our current estimates, this could have a material and adverse effect on our future earnings, cash flows, financial condition or results of operations.

6 – Legal and other risks

Litigation

We are currently subject to litigation or threats of litigation, and may be involved in disputes with other parties in the future that result in litigation. This litigation may involve joint venture participants, suppliers, customers, governments, regulators, tax authorities or other persons.

We cannot accurately predict the outcome of any litigation. The costs of defending or settling such litigation can be significant. If a dispute cannot be resolved favourably, it may have a material and adverse effect on our earnings, cash flows, financial condition, results of operations or prospects. See Legal proceedings on page 118 for more information.

We are currently involved in a dispute with TEPCO regarding its contract termination notice, alleging force majeure, with respect to a uranium supply agreement that it would not withdraw. See 2017 Major Developments on page 7 for details.

We are also currently involved in tax litigation with CRA and have received RARs from the IRS. See Transfer pricing disputes at pages 95 to 98. In addition, we are subject to the risk that CRA or the IRS may challenge or seek to reassess our income tax returns on a similar basis for other previously reported periods, and the risk that CRA, the IRS or other tax authorities in other countries may seek to challenge or reassess our income tax returns on a different basis for the same periods or other previously reported periods. Substantial success for CRA would be material, and other unfavourable outcomes of challenges or reassessments initiated by the IRS or the tax authorities in other countries could be material, to our cash flows, financial condition, results of operations or prospects.

Legal rights

If a dispute arises at our foreign operations, it may be under the exclusive jurisdiction of foreign courts, or we may not be successful in subjecting foreign persons to the jurisdiction of courts in Canada. We could also be hindered or prevented from enforcing our rights relating to a government entity or instrumentality because of the doctrine of sovereign immunity.

The dispute resolution provision of the resource use contract for JV Inkai stipulates that any dispute between the parties is to be submitted to international arbitration. There is no assurance, however, that a particular government entity or instrumentality will either comply with the provisions of this or any other agreements, or voluntarily submit a dispute to arbitration. If we are unable to enforce our rights under these agreements, this could have a material and adverse effect on our earnings, cash flows, financial condition or results of operations.

Defects in title

We have investigated our rights to explore and exploit all of our material properties, and those rights are in good standing to the best of our knowledge. There is no assurance, however, that these rights will not be revoked or significantly altered to our detriment, or that our rights will not be challenged by third parties, including local governments and by indigenous groups, such as First Nations and Métis in Canada.

Indigenous rights, title claims and consultation

Managing indigenous rights, title claims and consultation is an integral part of our exploration, development and mining activities, and we are committed to managing them effectively. Cameco has signed agreements, or is in negotiations, with the communities closest to our operations to help mitigate the risks associated with potential First Nations and Métis land or consultation claims that could impact our operations. These agreements provide substantial socioeconomic opportunities to these communities and also provide us with support for our operations from those communities. There is no assurance,

2016 ANNUAL INFORMATION FORM    Page 115

however, that we will not face material adverse consequences because of the legal and factual uncertainties inherent with indigenous rights, title claims and consultation.

Saskatchewan

Exploration, development, mining, milling and decommissioning activities at our various properties in Saskatchewan may be affected by claims by the First Nations and Métis, and related consultation issues.

We also face similar issues with our exploration activities in other provinces and countries.

It is generally acknowledged that under historical treaties, First Nations in northern Saskatchewan ceded title to most traditional lands in the region in exchange for treaty benefits and reserve lands. Some First Nations in Saskatchewan, however, assert that their treaties are not an accurate record of their agreement with the Canadian government and that they did not cede title to the minerals when they ceded title to their traditional lands.

Fuel fabrication defects and product liability

We fabricate nuclear fuel bundles, other reactor components and monitoring equipment. These products are complex and may have defects that can be detected at any point in their product life cycle. Flaws in the products could materially and adversely affect our reputation, which could result in a significant cost to us and have a negative effect on our ability to sell our products in the future. We could also incur substantial costs to correct any product errors, which could have an adverse effect on our operating margins. While we have introduced significant automation to limit the potential for quality issues, there is no guarantee that we will detect all defects or errors in our products.

It is possible that some customers may demand compensation if we deliver defective products. If there are a significant number of product defects, it could have a significant impact on our operating results.

Agreements with some customers may include specific terms limiting our liability to customers. Even if there are limited liability provisions in place, existing or future laws, or unfavourable judicial decisions may make them ineffective. We have not experienced any material product liability claims to date, however, they could occur in the future because of the nature of nuclear fuel products. A successful product liability claim could result in significant monetary liability and could seriously disrupt our fuel manufacturing business and the company overall.

7 – Industry risks

Major nuclear incident risk

Although the safety record of nuclear reactors has generally been very good, there have been accidents and other unforeseen problems in the former USSR, the United States, Japan and in other countries. The consequences of a major incident can be severe and include loss of life, property damage and environmental damage. An accident or other significant event at a nuclear plant could result in increased regulation, less public support for nuclear energy, lower demand for uranium and lower uranium prices. This could have a material and adverse effect on our earnings, cash flows, financial condition, results of operations or prospects.

Public acceptance of nuclear energy is uncertain

Maintaining the demand for uranium at current levels and achieving any growth in demand in the future will depend on society’s acceptance of nuclear technology as a means of generating electricity.

On March 11, 2011, a significant earthquake struck the northeast coast of Japan, producing a tsunami and causing massive damage and destruction along the Pacific coastline of Japan. This included damage to the Fukushima-Daiichi nuclear power plant, located in the town of Okuma, about 210 kilometres north of Tokyo. The plant suffered a series of power and equipment failures affecting the cooling water systems and released radioactive material into the environment. The incident at the Fukushima-Daiichi nuclear power plant has called into question public confidence in nuclear energy in Japan and elsewhere around the world. This had an immediate and sustained negative impact on uranium prices and the share price of companies involved in the uranium industry.

2016 ANNUAL INFORMATION FORM    Page 116

Prior to the events of March 11, 2011, Japan had 54 nuclear reactors, which represented 12% of global nuclear generating capacity. As of February 23, 2017, Japan has three reactors operating. Before any reactors can be restarted, they must demonstrate an ability to meet new safety standards that were developed by Japan’s Nuclear Regulatory Authority (NRA). An additional nine reactors, as of February 23, 2017, are under various stages of review under these standards.

Germany has decided to revert to its previous phase out policy, shutting down eight of its reactors and plans to shut down the remaining nine reactors by 2022.

Lack of public acceptance of nuclear technology would have an adverse effect on the demand for nuclear power and potentially increase the regulation of the nuclear power industry. We may be impacted by changes in regulation and public perception of the safety of nuclear power plants, which could adversely affect the construction of new plants, the re-licensing of existing plants, the demand for uranium and the future prospects for nuclear generation. These events could have a material adverse effect on our earnings, cash flows, financial condition, results of operations or prospects.

Industry Concentration Risk

We are concentrated in the nuclear fuel business, with our primary focus on uranium mining. As such, we are sensitive to changes in, and our performance and future prospects, will depend to a greater extent on, the overall condition of the nuclear energy industry and the public acceptance of nuclear energy. We may be susceptible to increased risks, compared to diversified metals trading companies or diversified mining companies, as a result of the fact that our operations are concentrated in the nuclear fuel business.

Because we derive the majority of our revenues from sales of nuclear fuel, our results of operations and cash flows will fluctuate as the price of nuclear fuel increases or decreases. See “Financial risks – Volatility and sensitivity to prices”. A sustained period of declining nuclear fuel prices would materially and adversely affect our results of operations and cash flows. Additionally, if the market price for nuclear fuel declines or remains at relatively low levels for a sustained period of time, we may have to revise our operating plans, including reducing operating costs and capital expenditures, terminating or suspending mining operations at one or more of our properties and discontinuing certain exploration and development plans. In a sustained period of low prices, we may be unable to decrease our costs in an amount sufficient to offset reductions in revenues, and may incur losses.

Alternate sources of energy

Nuclear energy competes with other sources of energy like oil, natural gas, coal and hydro-electricity. These sources are somewhat interchangeable with nuclear energy, particularly over the longer term.

If lower prices of oil, natural gas, coal and hydro-electricity are sustained over time, it may result in lower demand for uranium concentrates and uranium conversion services, which could lead to lower uranium prices. Growth of the uranium and nuclear power industry will depend on continuing and growing acceptance of nuclear technology to generate electricity. Unique political, technological and environmental factors affect the nuclear industry, exposing it to the risk of public opinion, which could have a negative effect on the demand for nuclear power and increase the regulation of the nuclear power industry. An accident at a nuclear reactor anywhere in the world could affect the acceptance of nuclear energy and the future prospects for nuclear generation, which could have a material and adverse effect on our future earnings, cash flows, financial condition, results of operations or prospects.

Industry competition and international trade restrictions

The international uranium industry, which includes supplying uranium concentrates and providing uranium conversion services, is highly competitive. We market uranium to utilities, and directly compete with a relatively small number of uranium mining and enrichment companies in the world. Their supply may come from mining uranium, excess inventories, including inventories made available from decommissioning of nuclear weapons, reprocessed uranium and plutonium derived from used reactor fuel, and from using excess enrichment capacity to re-enrich depleted uranium tails.

The supply of uranium is affected by a number of international trade agreements and policies. These and any similar future agreements, governmental policies or trade restrictions are beyond our control and may affect the supply of uranium available in the US, Europe and Asia, the world’s largest markets for uranium. If we cannot supply uranium to these important markets, it could have a material and adverse effect on our earnings, cash flows, financial condition or results of operations.

2016 ANNUAL INFORMATION FORM    Page 117

For conversion services, we compete with three other primary commercial suppliers. In addition, we compete with the availability of additional supplies from excess inventories, including those from decommissioning nuclear weapons and using excess enrichment capacity to re-enrich depleted uranium tails.

Any political decisions about the uranium market can affect our future prospects. There is no assurance that the US or other governments will not enact legislation or take other actions that restricts who can buy or supply uranium, or facilitates a new supply of uranium.

Competition for sources of uranium

There is competition for mineral acquisition opportunities throughout the world, so we may not be able to acquire rights to explore additional attractive uranium mining properties on terms that we consider acceptable.

There is no assurance that we will acquire any interest in additional uranium properties, or buy additional uranium concentrates from the decommissioning of nuclear weapons or the release of excess government inventory, that will result in additional uranium concentrates we can sell. If we are not able to acquire these interests or rights, it could have a material and adverse effect on our future earnings, cash flows, financial condition or results of operations. Even if we do acquire these interests or rights, the resulting business arrangements may ultimately prove not to be beneficial.

Deregulation of the electrical utility industry

A significant part of our future prospects is directly linked to developments in the global electrical utility industry.

Deregulation of the utility industry, particularly in the US, Japan and Europe, could affect the market for nuclear and other fuels and could lead to the premature shutdown of some nuclear reactors.

Deregulation has resulted in utilities improving the performance of their reactors to record capacity, but there is no assurance this trend will continue.

Deregulation can have a material and adverse effect on our future earnings, cash flows, financial condition or results of operations.

Legal proceedings

We discuss any legal proceedings that we or our subsidiaries are a party, as at December 31, 2016, in note 20 to the 2016 financial statements.

We are currently involved in a dispute with TEPCO regarding its contract termination notice, alleging force majeure, with respect to a uranium supply agreement it would not withdraw. See 2017 Major Developments on page 7 for details.

2016 ANNUAL INFORMATION FORM    Page 118

Investor information

Share capital

Our authorized share capital consists of:

• first preferred shares

• second preferred shares

• common shares

• one class B share.

Preferred shares

We do not currently have any preferred shares outstanding, but we can issue an unlimited number of first preferred or second preferred shares with no nominal or par value, in one or more series. The board must approve the number of shares, and the designation, rights, privileges, restrictions and conditions attached to each series of first or second preferred shares.

Preferred shares can carry voting rights, and they rank ahead of common shares and the class B share for receiving dividends and distributing assets if the company is liquidated, dissolved or wound up.

First preferred shares

Each series of first preferred shares ranks equally with the shares of other series of first preferred shares. First preferred shares rank ahead of second preferred shares, common shares and the class B share.

Second preferred shares

Each series of second preferred shares ranks equally with the shares of other series of second preferred shares. Second preferred shares rank after first preferred shares and ahead of common shares and the class B share.

Common shares

We can issue an unlimited number of common shares with no nominal or par value. Only holders of common shares have full voting rights in Cameco.

If you hold our common shares, you are entitled to vote on all matters that are to be voted on at any shareholder meeting, other than meetings that are only for holders of another class or series of shares. Each Cameco share you own represents one vote, except where noted below. As a holder of common shares, you are also entitled to receive any dividends that are declared by our board of directors.

Common shares rank after preferred shares with respect to the payment of dividends and the distribution of assets if the company is liquidated, dissolved or wound up, or any other distribution of our assets among our shareholders if we were to wind up our affairs.

Holders of our common shares have no pre-emptive, redemption, purchase or conversion rights for these shares. Except as described under Ownership and voting restrictions, non-residents of Canada who hold common shares have the same rights as shareholders who are residents of Canada.

As at December 31, 2016, we had 395,792,522 common shares outstanding. These were fully paid and non-assessable.

As of March 1, 2017, there were 9,302,291 stock options outstanding, which includes the grant on March 1, 2017, to acquire common shares of Cameco under the company’s stock option plan with exercise prices ranging from $14.70 to $39.53.

In 2016, we granted the following stock options:

March 1, 2016 – 1,273,340 stock options to acquire common shares of Cameco at an exercise price of $16.38.

In 2017, we granted the following stock options:

March 1, 2017 – 1,373,040 stock options to acquire common shares of Cameco at an exercise price of $14.70.

2016 ANNUAL INFORMATION FORM    Page 119

Our articles of incorporation have provisions that restrict the issue, transfer and ownership of voting securities of Cameco (see Ownership and voting restrictions below).

Class B shares

The province of Saskatchewan holds our one class B share outstanding. It is fully paid and non-assessable.

The one class B share entitles the province to receive notices of and attend all meetings of shareholders, for any class or series.

The class B shareholder can only vote at a meeting of class B shareholders, and only as a class if there is a proposal to:

• amend Part 1 of Schedule B of the articles, which states that:

• Cameco’s registered office and head office operations must be in Saskatchewan

• the vice-chairman of the board, chief executive officer (CEO), president, chief financial officer (CFO) and generally all of the senior officers (vice-presidents and above) must live in Saskatchewan

• all annual meetings of shareholders must be held in Saskatchewan

• amalgamate, if it would require an amendment to Part 1 of Schedule B of the articles, or

• amend the articles in a way that would change the rights of class B shareholders.

The class B shareholder can request and receive information from us to determine whether or not we are complying with Part 1 of Schedule B of the articles.

The class B shareholder does not have the right to receive any dividends declared by Cameco. The class B share ranks after first and second preferred shares, but equally with common shareholders, with respect to the distribution of assets if the company is liquidated, dissolved or wound up. The class B shareholder has no pre-emptive, redemption, purchase or conversion rights with its class B share, and the share cannot be transferred.

Ownership and voting restrictions

The federal government established ownership restrictions when Cameco was formed so we would remain Canadian controlled. There are restrictions on issuing, transferring and owning Cameco common shares whether you own the shares as a registered shareholder, hold them beneficially or control your investment interest in Cameco directly or indirectly. These are described in the Eldorado Nuclear Limited Reorganization and Divestiture Act (Canada) (ENL Reorganization Act) and our company articles.

The following is a summary of the restrictions listed in our company articles.

Residents

A Canadian resident, either individually or together with associates, cannot hold, beneficially own or control shares or other Cameco securities, directly or indirectly, representing more than 25% of the votes that can be cast to elect directors.

Non-residents

A non-resident of Canada, either individually or together with associates, cannot hold, beneficially own or control shares or other Cameco securities, directly or indirectly, representing more than 15% of the total votes that can be cast to elect directors.

Voting restrictions

All votes cast at the meeting by non-residents, either beneficially or controlled directly or indirectly, will be counted and pro-rated collectively to limit the proportion of votes cast by non-residents to no more than 25% of the total shareholder votes cast at the meeting.

There have been instances in prior years, including 2016, when we have limited the counting of votes by non-residents of Canada at our annual meeting of shareholders to abide by this restriction. This has resulted in non-residents receiving less than one vote per share.

Enforcement

The company articles allow us to enforce the ownership and voting restrictions by:

• suspending voting rights

• forfeiting dividends and other distributions

2016 ANNUAL INFORMATION FORM    Page 120

• prohibiting the issue and transfer of Cameco shares

• requiring the sale or disposition of Cameco shares

• suspending all other shareholder rights.

To verify compliance with restrictions on ownership and voting of Cameco shares, we require existing shareholders, proposed transferees or other subscribers for voting shares to declare their residency, ownership of Cameco shares and other things relating to the restrictions. Nominees such as banks, trust companies, securities brokers or other financial institutions who hold the shares on behalf of beneficial shareholders need to make the declaration on their behalf.

We cannot issue or register a transfer of any voting shares if it would result in a contravention of the resident or non-resident ownership restrictions.

If we believe there is a contravention of our ownership restrictions based on any shareholder declarations filed with us, or our books and records or those of our registrar and transfer agent or otherwise, we can suspend all shareholder rights for the securities they hold, other than the right to transfer them. We can only do this after giving the shareholder 30 days’ notice, unless he or she has disposed of the holdings and we have been advised of this.

Understanding the terms

Please see our articles for the exact definitions of associate, resident, non-resident, control, and beneficial ownership which are used for the restrictions described above.

Other restrictions

The ENL Reorganization Act imposes some additional restrictions on Cameco. We must maintain our registered office and our head office operations in Saskatchewan. We are also prohibited from:

• creating restricted shares (these are generally defined as a participating share with restrictive voting rights)

• applying for continuance in another jurisdiction

• enacting articles of incorporation or bylaws that have provisions that are inconsistent with the ENL Reorganization Act.

We must maintain our registered office and head office operations in Saskatchewan under the Saskatchewan Mining Development Corporation Reorganization Act. This generally includes all executive, corporate planning, senior management, administrative and general management functions.

Credit ratings

Credit ratings provide an independent, professional assessment of a corporation’s credit risk. They are not a comment on the market price of a security or suitability for an individual investor and are, therefore, not recommendations to buy, hold or sell our securities.

We provide rating agencies DBRS Limited (DBRS) and Standard & Poor’s (S&P) with confidential, in-depth information to support the credit rating process.

The credit ratings assigned to our securities by external ratings agencies are important to our ability to raise capital at competitive pricing to support our business operations and liquidity position.

The rating agencies may revise or withdraw these ratings if they believe circumstances warrant. A material downgrade in our credit ratings would likely increase our cost of funding significantly and our ability to access funding and capital through the capital markets could be reduced.

We have four series of senior unsecured debentures outstanding:

• $500 million of debentures issued on September 2, 2009 that have an interest rate of 5.67% per year and mature on September 2, 2019

• $400 million of debentures issued on November 14, 2012 that have an interest rate of 3.75% per year and mature on November 14, 2022

• $100 million of debentures issued on November 14, 2012 that have an interest rate of 5.09% per year and mature on November 14, 2042

• $500 million of debentures issued on June 24, 2014 that have an interest rate of 4.19% per year and mature on June 24, 2024.

2016 ANNUAL INFORMATION FORM    Page 121

We have a commercial paper program which is supported by a $1.25 billion unsecured revolving credit facility that matures November 1, 2020. As of December 31, 2016, there were no amounts outstanding under the commercial paper facility.

The table below shows the current DBRS and S&P ratings and the rating trends/outlooks of our commercial paper and senior unsecured debentures:

Rating Agency	Rating	Rating Trend/Outlook
Commercial paper
DBRS	R-2 (high)	Stable
S&P	A-21	Stable
Senior Unsecured Debentures
DBRS	BBB (high)	Stable
S&P	BBB	Stable

¹ Canadian National Scale Rating. The Global Scale Rating is A-2.

DBRS provides guidance for the outlook of the assigned rating using the rating trend. The rating trend is an indication of the likelihood and direction that the rating could change in the future, should present tendencies continue, or in some cases, if challenges are not overcome.

S&P uses rating outlooks to assess the potential direction of a long-term credit rating over the intermediate term. The outlook is an indication of the likelihood that the rating could change in the future.

The rating agencies may revise or withdraw these ratings if they believe circumstances warrant. A change in our credit ratings could affect our cost of funding and our access to capital through the capital markets.

DBRS identified our current dispute with the CRA and de-stocking of customer inventories as a result of further delay of Japanese reactors re-starts, as factors giving rise to unusual risks. In addition, DBRS identified the high ore grade and challenging mining conditions at certain key operations as giving rise to higher project and development risks than those faced by other miners.

S&P identified our current dispute with the CRA and the company’s financial risk profile being comparatively less stable with greater sensitivity to potential industry-related challenges as factors giving rise to unusual risks.

Commercial paper

Rating scales for commercial paper are meant to indicate the risk that a borrower will not fulfill its near-term debt obligations in a timely manner.

The table below explains the credit ratings of our commercial paper in more detail:

	Rating	Ranking
DBRS rates commercial paper by categories ranging from a high of R-1 to a low of D	R-2 (high)	•       upper end of the R-2 category •       represents “adequate credit quality” •       fourth highest of 10 available credit ratings
S&P rates commercial paper by categories ranging from a high of A-1 (high) to a low of D	A-2	•       represents “satisfactory capacity to meet its financial commitments on the obligation” •       fourth highest of eight available credit ratings

Senior unsecured debentures

Long-term debt rating scales are meant to indicate the risk that a borrower will not fulfill its full obligations, with respect to interest and principal, in a timely manner.

The table below explains the credit ratings of our senior unsecured debentures in more detail:

2016 ANNUAL INFORMATION FORM    Page 122

	Rating	Ranking
DBRS   rates senior unsecured debentures by categories   ranging from a high of AAA to a low of D	BBB (high)	•  higher end of the BBB category •  represents “adequate credit quality” •  fourth highest of 10 available credit ratings •  capacity for the payment of financial obligations is considered acceptable •  may be vulnerable to future events
S&P   rates senior unsecured debentures by categories   ranging from a high of AAA to a low of D	BBB	•  middle of the BBB category •  exhibits “adequate protection parameters” •  fifth highest of 10 available credit ratings •  adverse economic conditions or changing circumstances are more likely to lead to a weakened capacity to meet financial commitment •  “stable” outlook means the rating is not likely to be changed

Payments to Credit Rating Agencies

Over the last two years, we paid $399,000 in connection with the credit ratings disclosed above.

Material contracts

Below is a list of material contracts entered into and still in effect, which have been filed on SEDAR in accordance with National Instrument 51-102 Continuous Disclosure requirements:

Supplemental indentures

We entered into the Fourth supplemental indenture with CIBC Mellon Trust Company (CIBC Mellon) on September 2, 2009, relating to the issue of $500 million in unsecured debentures at an interest rate of 5.67% per year and due in 2019.

We entered into the Fifth supplemental indenture with CIBC Mellon on November 14, 2012, relating to the issue of $400 million in unsecured debentures at an interest rate of 3.75% per year and due in 2022.

We entered into the Sixth supplemental indenture with CIBC Mellon on November 14, 2012, relating to the issue of $100 million in unsecured debentures at an interest rate of 5.09% per year and due in 2042.

We entered into the Seventh supplemental indenture with CIBC Mellon on June 24, 2014, relating to the issue of $500 million in unsecured debentures at an interest rate of 4.19% per year and due in 2024.

See Senior unsecured debentures, above for more information about these debentures.

US Trust Indenture

We entered into an indenture with The Bank of New York Mellon on May 22, 2012 to set forth the general terms and provisions of debt securities. The terms of this indenture were fully described in our final short form base shelf prospectus dated December 9, 2014. We have not issued any debt securities under this indenture. The specific terms of any offering of debt securities under this indenture would be set forth in a shelf prospectus supplement.

Market for our securities

Our common shares are listed and traded on the Toronto Stock Exchange (TSX) (under the symbol CCO) and the New York Stock Exchange (under the symbol CCJ).

We have a registrar and transfer agent in Canada and the US for our common shares:

Canada CST Trust Company P.O. Box 700, Station B Montreal, Quebec H3B 3K3 US American Stock Transfer & Trust Company, LLC 6201 15^th Avenue Brooklyn, New York United States of America 11219

2016 ANNUAL INFORMATION FORM    Page 123

Trading activity

The table below shows the high and low closing prices and trading volume for our common shares on the TSX in 2016.

2016	High ($)		Low ($)		Volume
January		17.03		15.06		21,091,548
February		17.19		14.56		22,176,338
March		17.67		15.50		24,986,546
April		17.00		15.52		22,626,246
May		15.73		14.75		19,312,997
June		15.75		13.62		22,723,955
July		14.39		12.31		19,797,466
August		12.82		11.94		24,791,811
September		12.30		11.05		25,151,681
October		11.31		9.88		22,741,126
November		12.65		9.93		32,458,485
December		14.63		12.41		34,559,454

Dividend

Our board of directors has established a quarterly dividend of $0.10 ($0.40 per year) per common share. The dividend is reviewed quarterly based on our cash flow, earnings, financial position, strategy and other relevant factors.

The table below shows the dividends per common share for the last three fiscal years.

	2016		2015		2014
Cash dividends	$	0.40	$	0.40	$	0.40
Total dividends paid (millions)	$	158	$	158	$	158

Governance

Directors

Director	Board committees	Principal occupation or employment
Ian Bruce Calgary, Alberta, Canada Director since 2012	Human resources and compensation (Chair) Audit and finance	Corporate director as of 2010 2010 to 2011 – Co-Chairman, Peters & Co. Limited
Daniel Camus Geneva, Switzerland Director since 2011	Audit and finance Human resources and compensation Nominating, corporate governance and risk	Corporate director as of 2011 2012 to present – Chief Financial Officer of The Global Fund to Fight Aids, Tuberculosis and Malaria 2005 to 2010 – Head of Strategy and International Activities of Electricité de France SA
John Clappison Toronto, Ontario, Canada Director since 2006	Audit and finance (Chair) Nominating, corporate governance and risk	Corporate director as of 2006

2016 ANNUAL INFORMATION FORM    Page 124

Director	Board committees	Principal occupation or employment
Donald Deranger Prince Albert, Saskatchewan, Canada Director since 2009	Reserves oversight Safety, health and environment	May 2013 to present – non-executive chair of the board of Points Athabasca Contracting LP, a civil, earthworks and industrial contracting company 1997 to present – Advisor to First Nations Communities 2001 to May 2013 – President of Points Athabasca Contracting LP 2003 to 2012 – Athabasca Vice Chief of the Prince Albert Grand Council
Catherine Gignac Mississauga, Ontario, Canada Director since 2014	Reserves oversight (Chair) Audit and finance Safety, health and environment	Corporate director as of 2011 September 2011 to 2015 – principal of Catherine Gignac & Associates April 2009 to September 2011 – mining equity research analyst with NCP Northland Capital Partners
Tim Gitzel Saskatoon, Saskatchewan, Canada Director since 2011	None	July 2011 to present – President and Chief Executive Officer May 2010 to June 2011 – President
James Gowans Surrey, British Columbia, Canada Director since 2009	Safety, health and environment (Chair) Nominating, corporate governance and risk Reserves oversight	January 2016 to present – President and CEO of Arizona Mining Inc., an exploration and development company August to December 2015 – Senior Advisor to the Chair of the Board of Barrick Gold Corporation July 2014 to August 2015 – Co-President of Barrick Gold Corporation January 2014 to July 2014 – Executive Vice-President and Chief Operating Officer of Barrick Gold Corporation January 2011 to January 2014 – Managing Director, Debswana Diamond Company
Kathryn Jackson Sewickley, Pennsylvania, USA Director since 2017	None	Corporate director as of 2008 2015 to present – Director, Energy & Technology Consulting, KeySource, Inc. 2014 to 2015 – Senior Vice-President and Chief Technology Officer of RTI International Metals Inc. 2008 to 2014 – Senior Vice-President and Chief Technology Officer of Westinghouse Electric Company
Donald Kayne Tsawwassen, British Columbia, Canada Director since 2016	Human resources and compensation Reserves oversight Safety, health and environment	September 2012 to present – Chief Executive Officer of Canfor Pulp Products Incorporated, an integrated forest products company May 2011 to present – President and Chief Executive Officer of Canfor Corporation 2000 – 2011 – Vice-President, Sales and Marketing, Canfor Corporation
Anne McLellan Edmonton, Alberta, Canada Director since 2006	Nominating, corporate governance and risk (Chair) Human resources and compensation	May 2015 to present – Chancellor of Dalhousie University July 2006 to present – Senior Advisor at Bennett Jones LLP July 2006 to June 2013 – Distinguished Scholar in Residence at Alberta Institute for American Studies, University of Alberta
Neil McMillan Saskatoon, Saskatchewan, Canada Director since 2002	Chair	Corporate director as of April 2014 2004 to March 2014 – President and Chief Executive Officer, Claude Resources Inc.

Each director is elected for a term of one year, and holds office until the next annual meeting unless he or she steps down, as required by corporate law.

2016 ANNUAL INFORMATION FORM    Page 125

Officers

Officer	Principal occupation or employment for past five years
Neil McMillan Chair of the Board Saskatoon, Saskatchewan, Canada	Corporate director as of April 2014 2004 to March 2014 – President and Chief Executive Officer, Claude Resources Inc.
Tim Gitzel President and Chief Executive Officer Saskatoon, Saskatchewan, Canada	Assumed current position July 2011 May 2010 to June 2011 – President
Grant Isaac Senior Vice-President and Chief Financial Officer Saskatoon, Saskatchewan, Canada	Assumed current position July 2011 July 2009 to July 2011 – Senior Vice-President, Corporate Services
Sean Quinn Senior Vice-President, Chief Legal Officer and Corporate Secretary Saskatoon, Saskatchewan, Canada	Assumed current position April 2014 May 2004 to March 2014 – Vice-President, Law and General Counsel
Robert Steane Senior Vice-President and Chief Operating Officer Saskatoon, Saskatchewan, Canada	Assumed current position May 2010
Alice Wong Senior Vice-President and Chief Corporate Officer Saskatoon, Saskatchewan, Canada	Assumed current position July 2011 October 2008 to July 2011 – Vice-President, Safety, Health, Environment, Quality and Regulatory Relations

To our knowledge, the total number of common shares that the directors and executive officers as a group either: (i) beneficially owned; or (ii) exercised direction or control over, directly or indirectly, was 539,338 as at March 3, 2017. This represents less than 1% of our outstanding common shares.

To the best of our knowledge, none of the directors, executive officers or shareholders that either: (i) beneficially owned; or (ii) exercised direction or control of, directly or indirectly, over 10% of any class of our outstanding securities, nor their associates or affiliates, have or have had within the three most recently completed financial years, any material interests in material transactions which have affected, or will materially affect, the company.

Other information about our directors and officers

None of our directors or officers, or a shareholder with significant holdings that could materially affect control of us, is or was a director or executive officer of another company in the past 10 years that:

• was the subject of a cease trade or similar order, or an order denying that company any exemption under securities legislation, for more than 30 consecutive days while the director or executive officer held that role with the company

• was involved in an event that resulted in the company being subject to one of the above orders after the director or executive officer no longer held that role with the company

• while acting in that capacity, or within a year of acting in that capacity, became bankrupt, made a proposal under any legislation relating to bankruptcy or insolvency or was subject to or instituted any proceedings, arrangement or compromise with creditors or had a receiver, receiver manager or trustee appointed to hold the assets of that company, except for:

• Ian Bruce who has been a director of Laricina Energy Limited (Laricina), a junior oilsands private company, since 2013. Laricina was under a CCAA protection order from March 26, 2015 to February 1, 2016.

None of them in the past 10 years:

• became bankrupt

• made a proposal under any legislation relating to bankruptcy or insolvency

• has been subject to or launched any proceedings, arrangement or compromise with any creditors, or

2016 ANNUAL INFORMATION FORM    Page 126

• had a receiver, receiver manager or trustee appointed to hold any of their assets.

None of them has ever been subject to:

• penalties or sanctions imposed by a court relating to securities legislation or by a securities regulatory authority or has entered into a settlement agreement with a securities regulatory authority, or

• any other penalties or sanctions imposed by a court or regulatory body that would likely be considered important to a reasonable investor in making an investment decision.

About the audit and finance committee

Audit and finance committee charter

See appendix A for a copy of the audit and finance committee charter. You can also find a copy on our website (cameco.com/about/governance/board_committees).

Composition of the audit and finance committee

The committee is made up of four members: John Clappison (chair), Ian Bruce, Daniel Camus, and Catherine Gignac. Each member is independent and financially literate using criteria that meet the standards of the Canadian Securities Administrators as set out in National Instrument 52-110.

Relevant education and experience

John Clappison, a corporate director, is the former managing partner of the Greater Toronto Area office of PricewaterhouseCoopers LLP (PwC). He is our committee chair and currently serves on the boards of two other publicly-traded companies, on one of which he is the chair of the audit committee. Mr. Clappison has over 35 years of experience as a practicing chartered accountant and was an audit partner at PwC. He serves on boards of other private and not-for-profit organizations. Mr. Clappison is a chartered accountant and a Fellow of the Chartered Professional Accountants of Ontario.

Ian Bruce, a corporate director, is the former President and CEO of Peters & Co. Limited, an independent investment dealer. He was a past member of the Expert Panel on Securities Regulation for the Minister of Finance of Canada. Mr. Bruce was a board member and chair of the Investment Industry Association of Canada, and also served as a director of the public companies Hardy Oil & Gas plc from 2008 to 2012 and Taylor Gas Liquids Ltd. from 1997 to 2008. He currently serves on the board of two other publicly-traded companies, on one of which he is the chair of the audit committee and one of which he is a member of the audit committee, and three private companies. Mr. Bruce is a Fellow of the Chartered Professional Accountants (CPA) of Alberta, a recognized Specialist in Valuation under Canadian CPA rules and is a Chartered Business Valuator.

Daniel Camus is the former group chief financial officer and former head of strategy and international activities of Electricité de France SA (EDF), a France-based integrated energy operator active in the generation, distribution, transmission, supply and trading of electrical energy with international subsidiaries. He currently serves on the boards of two other publicly-traded companies, on one of which he is the chair of the audit committee. He is the Chief Financial Officer of the humanitarian finance organization, The Global Fund to Fight AIDS, Tuberculosis and Malaria. Mr. Camus received his PhD in Economics from Sorbonne University and an MBA in finance and economics from the Institute d’Études Politiques de Paris.

Catherine Gignac, a corporate director, is a former mining equity research analyst with leading global brokerage firms including, NCP Northland Capital Partners. She currently serves on the boards of two other publicly-traded companies, on one of which she is the chair of its board and on the other she is a member of its audit committee. She has more than 30 years’ experience as a mining equity research analyst and geologist. She held senior positions with leading firms, including Merrill Lynch Canada, RBC Capital Markets, UBS Investment Bank and Dundee Capital Markets Inc. and Loewen Ondaatje McCutcheon Limited. Ms. Gignac was the principal of Catherine Gignac & Associates from 2011 to 2015.

2016 ANNUAL INFORMATION FORM    Page 127

Auditors’ fees

The table below shows the fees we paid to the external auditors for services in 2016 and 2015:

	2016 ($)		% of total fees (%)		2015 ($)		% of total fees (%)
Audit fees
Cameco		1,559,400		57.7		1,939,000		57.3
Subsidiaries		628,500		23.3		904,900		26.7
Total audit fees		2,187,900		81.0		2,843,900		84.0
Audit-related fees
Translation services		—		—		—		0.0
Pensions and other		28,700		1.1		27,300		0.8
Total audit-related fees		28,700		1.1		27,300		0.8
Tax fees
Compliance		158,000		5.8		150,500		4.5
Planning and advice		327,300		12.1		362,600		10.7
Total tax fees		485,300		17.9		513,100		15.2
All other fees		—		0.0		—		0.0
Total fees		2,701,900		100.00		3,384,300		100.00

Approving services

The audit and finance committee must pre-approve all services the external auditors will provide to make sure they remain independent. This is according to our audit and finance committee charter and consistent with our corporate governance practices. The audit and finance committee pre-approves services up to a specific limit. If we expect the fees to exceed the limit, or the external auditors to provide new audit or non-audit services that have not been pre-approved in the past, then this must be pre-approved separately.

Any service that is not generally pre-approved must be approved by the audit and finance committee before the work is carried out, or by the committee chair, or board chair in his or her absence, as long as the proposed service is presented to the full audit and finance committee at its next meeting.

The committee has adopted a written policy that describes the procedures for implementing these principles.

Interest of experts

Our auditor is KPMG LLP, independent chartered accountants, who have audited our 2016 financial statements.

KPMG LLP are the auditors of Cameco and have confirmed with respect to Cameco that they are independent within the meaning of the relevant rules and related interpretations prescribed by the relevant professional bodies in Canada and any applicable legislation or regulations and also that they are independent accountants with respect to Cameco under all relevant US professional and regulatory standards.

The individuals who are qualified persons for the purposes of NI 43-101 and employees of Cameco are listed under Mineral reserves and resources on page 74. As a group, they beneficially own, directly or indirectly, less than 1% of any class of the outstanding securities of Cameco and our associates and affiliates.

2016 ANNUAL INFORMATION FORM    Page 128

Appendix A

Audit and finance committee of the Board of Directors

Mandate

Purpose

The primary purpose of the audit and finance committee (the “committee”) is to assist the board of directors (the “board”) in fulfilling its oversight responsibilities for (a) the accounting and financial reporting processes, (b) the internal controls, (c) the external auditors, including performance, qualifications, independence, and their audit of the corporation’s financial statements, (d) the performance of the corporation’s internal audit function, (e) financial matters and risk management of financial risks as delegated by the board, (f) the corporation’s process for monitoring compliance with laws and regulations (other than environmental and safety laws) and its code of conduct and ethics, and (g) prevention and detection of fraudulent activities. The committee shall also prepare such reports as required to be prepared by it by applicable securities laws.

In addition, the committee provides an avenue for communication between each of the internal auditor, the external auditors, management, and the board. The committee shall have a clear understanding with the external auditors that they must maintain an open and transparent relationship with the committee and that the ultimate accountability of the external auditors is to the board and the committee, as representatives of the shareholders. The committee, in its capacity as a committee of the board, subject to the requirements of applicable law, is directly responsible for the appointment, compensation, retention, and oversight of the external auditors.

The committee has the authority to communicate directly with the external auditors and internal auditor.

The committee shall make regular reports to the board concerning its activities and in particular shall review with the board any issues that arise with respect to the quality or integrity of the corporation’s financial statements, the performance and independence of the external auditors, the performance of the corporation’s internal audit function, or the corporation’s process for monitoring compliance with laws and regulations other than environmental and safety laws.

Composition

The board shall appoint annually, from among its members, a committee and its chair. The committee shall consist of at least three members and shall not include any director employed by the corporation.

Each committee member will be independent pursuant to the standards for independence adopted by the board.

Each committee member shall be financially literate with at least one member having accounting or related financial expertise, using the terms defined as follows:

“Financially literate” means the ability to read and understand a set of financial statements that present a breadth and level of complexity of accounting issues that are generally comparable to the breadth and complexity of issues that can reasonably be expected to be raised by the corporation’s financial statements; and

“Accounting or related financial expertise” means the ability to analyse and interpret a full set of financial statements, including the notes attached thereto, in accordance with Canadian generally accepted accounting principles.

In addition, where possible, at least one member of the committee shall qualify as an “audit committee financial expert” within the meaning of applicable securities law.

Members of the committee may not serve on the audit and finance committees of more than three public companies (including Cameco’s) without the approval of the board.

Meetings

The committee will meet at least four times annually and as many additional times as the committee deems necessary to carry out its duties effectively. The committee will meet separately in private with the external auditors, the internal auditor and management at each regularly scheduled meeting.

2016 ANNUAL INFORMATION FORM    Page 129

A majority of the members of the committee shall constitute a quorum. No business may be transacted by the committee except at a meeting of its members at which a quorum of the committee is present.

The committee may invite such officers, directors and employees of the corporation as it may see fit from time to time to attend at meetings of the committee and assist thereat in the discussion and consideration of any matter.

A meeting of the committee may be convened by the chair of the committee, a member of the committee, the external auditors, the internal auditor, the chief executive officer or the chief financial officer. The secretary, who shall be appointed by the committee, shall, upon direction of any of the foregoing, arrange a meeting of the committee. The committee shall report to the board in a timely manner with respect to each of its meetings.

Duties and responsibilities

To carry out its oversight responsibilities, the committee shall:

Financial reporting process

1. Review with management and the external auditors any items of concern, any proposed changes in the selection or application of major accounting policies and the reasons for the change, any identified risks and uncertainties, and any issues requiring management judgement, to the extent that the foregoing may be material to financial reporting.

2. Consider any matter required to be communicated to the committee by the external auditors under applicable generally accepted auditing standards, applicable law and listing standards, including the external auditors’ report to the committee (and management’s response thereto) on: (a) all critical accounting policies and practices used by the corporation; (b) all material alternative accounting treatments of financial information within generally accepted accounting principles that have been discussed with management, including the ramifications of the use of such alternative treatments and disclosures and the treatment preferred by the external auditors; and (c) any other material written communications between the external auditors and management.

3. Require the external auditors to present and discuss with the committee their views about the quality, not just the acceptability, of the implementation of generally accepted accounting principles with particular focus on accounting estimates and judgements made by management and their selection of accounting principles.

4. Discuss with management and the external auditors (a) any accounting adjustments that were noted or proposed (i.e. immaterial or otherwise) by the external auditors but were not reflected in the financial statements, (b) any material correcting adjustments that were identified by the external auditors in accordance with generally accepted accounting principles or applicable law, (c) any communication reflecting a difference of opinion between the audit team and the external auditors’ national office on material auditing or accounting issues raised by the engagement, and (d) any “management” or “internal control” letter issued, or proposed to be issued, by the external auditors to the corporation.

5. Discuss with management and the external auditors any significant financial reporting issues considered during the fiscal period and the method of resolution. Resolve disagreements between management and the external auditors regarding financial reporting.

6. Review with management and the external auditors (a) any off-balance sheet financing mechanisms being used by the corporation and their effect on the corporation’s financial statements and (b) the effect of regulatory and accounting initiatives on the corporation’s financial statements, including the potential impact of proposed initiatives.

7. Review with management and the external auditors and legal counsel, if necessary, any litigation, claim or other contingency, including tax assessments, that could have a material effect on the financial position or operating results of the corporation, and the manner in which these matters have been disclosed or reflected in the financial statements.

8. Review with the external auditors any audit problems or difficulties experienced by the external auditors in performing the audit, including any restrictions or limitations imposed by management, and management’s response. Resolve any disagreements between management and the external auditors regarding these matters.

2016 ANNUAL INFORMATION FORM    Page 130

9. Review the results of the external auditors’ audit work including findings and recommendations, management’s response, and any resulting changes in accounting practices or policies and the impact such changes may have on the financial statements.

10. Review and discuss with management and the external auditors the audited annual financial statements and related management discussion and analysis, make recommendations to the board with respect to approval thereof, before being released to the public, and obtain an explanation from management of all significant variances between comparable reporting periods.

11. Review and discuss with management and the external auditors all interim unaudited financial statements and related interim management discussion and analysis and make recommendations to the board with respect to the approval thereof, before being released to the public.

12. Obtain confirmation from the chief executive officer and the chief financial officer (and considering the external auditors’ comments, if any, thereon) to their knowledge:

(a) that the audited financial statements, together with any financial information included in the annual MD&A and annual information form, fairly present in all material respects the corporation’s financial condition, cash flow and results of operation, as of the date and for the periods presented in such filings; and

(b) that the interim financial statements, together with any financial information included in the interim MD&A, fairly present in all material respects the corporation’s financial condition, cash flow and results of operation, as of the date and for the periods presented in such filings.

13. Review news releases to be issued in connection with the audited annual financial statements and related management discussion and analysis and the interim unaudited financial statements and related interim management discussion and analysis, before being released to the public. Discuss the type and presentation of information to be included in news releases (paying particular attention to any use of “pro-forma” or “adjusted” non-GAAP, information).

14. Review any news release, before being released to the public, containing earnings guidance or financial information based upon the corporation’s financial statements prior to the release of such statements.

15. Review the appointment of the chief financial officer and have the chief financial officer report to the committee on the qualifications of new key financial executives involved in the financial reporting process.

16. Consult with the human resources and compensation committee on the succession plan for the chief financial officer and controller. Review the succession plans in respect of the chief financial officer and controller.

Internal Controls

1. Receive from management a statement of the corporation’s system of internal controls over accounting and financial reporting.

2. Consider and review with management, the internal auditor and the external auditors, the adequacy and effectiveness of internal controls over accounting and financial reporting within the corporation and any proposed significant changes in them.

3. Consider and discuss the scope of the internal auditors’ and external auditors’ review of the corporation’s internal controls, and obtain reports on significant findings and recommendations, together with management responses.

4. Discuss, as appropriate, with management, the external auditors and the internal auditor, any major issues as to the adequacy of the corporation’s internal controls and any special audit steps in light of material internal control deficiencies.

5. Review annually the disclosure controls and procedures, including (a) the certification timetable and related process and (b) the procedures that are in place for the review of the corporation’s disclosure of financial information extracted from the corporation’s financial statements and the adequacy of such procedures. Receive confirmation from the chief executive officer and the chief financial officer of the effectiveness of disclosure controls and procedures, and whether there are any significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the corporation’s ability to record, process, summarize and report

2016 ANNUAL INFORMATION FORM    Page 131

financial information or any fraud, whether or not material, that involves management or other employees who have a significant role in the corporation’s internal control over financial reporting. In addition, receive confirmation from the chief executive officer and the chief financial officer that they are prepared to sign the annual and quarterly certificates required by applicable securities law.

6. Review management’s annual report and the external auditors’ report on the assessment of the effectiveness of the corporation’s internal control over financial reporting.

7. Receive a report, at least annually, from the reserves oversight committee of the board on the corporation’s mineral reserves.

External Auditors

(i) External Auditors’ Qualifications and Selection

1. Subject to the requirements of applicable law, be solely responsible to select, retain, compensate, oversee, evaluate and, where appropriate, replace the external auditors, who must be registered with agencies mandated by applicable law. The committee shall be entitled to adequate funding from the corporation for the purpose of compensating the external auditors for completing an audit and audit report.

2. Instruct the external auditors that:

(a) they are ultimately accountable to the board and the committee, as representatives of shareholders; and

(b) they must report directly to the committee.

3. Ensure that the external auditors have direct and open communication with the committee and that the external auditors meet regularly with the committee without the presence of management to discuss any matters that the committee or the external auditors believe should be discussed privately.

4. Evaluate the external auditors’ qualifications, performance, and independence. As part of that evaluation:

(a) at least annually, request and review a formal report by the external auditors describing: the firm’s internal quality-control procedures; any material issues raised by the most recent internal quality-control review, or peer review, of the firm, or by any inquiry or investigation by governmental or professional authorities, within the preceding five years, respecting one or more independent audits carried out by the firm, and any steps taken to deal with any such issues; and (to assess the auditors’ independence) all relationships between the external auditors and the corporation, including the amount of fees received by the external auditors for the audit services and for various types of non-audit services for the periods prescribed by applicable law; and

(b) annually review and confirm with management and the external auditors the independence of the external auditors, including the extent of non-audit services and fees, the extent to which the compensation of the audit partners of the external auditors is based upon selling non-audit services, the timing and process for implementing the rotation of the lead audit partner, reviewing partner and other partners providing audit services for the corporation, whether there should be a regular rotation of the audit firm itself, and whether there has been a “cooling off” period of one year for any former employees of the external auditors who are now employees with a financial oversight role, in order to assure compliance with applicable law on such matters; and

(c) annually review and evaluate senior members of the external audit team, including their expertise and qualifications. In making this evaluation, the audit and finance committee should consider the opinions of management and the internal auditor.

Conclusions on the independence of the external auditors should be reported to the board.

5. Review and approve the corporation’s policies for the corporation’s hiring of employees and former employees of the external auditors. Such policies shall include, at minimum, a one-year hiring “cooling off” period.

(ii) Other Matters

2016 ANNUAL INFORMATION FORM    Page 132

6. Meet with the external auditors to review and approve the annual audit plan of the corporation’s financial statements prior to the annual audit being undertaken by the external auditors, including reviewing the year-to-year co-ordination of the audit plan and the planning, staffing and extent of the scope of the annual audit. This review should include an explanation from the external auditors of the factors considered by the external auditors in determining their audit scope, including major risk factors. The external auditors shall report to the committee all significant changes to the approved audit plan.

7. Review and approve the basis and amount of the external auditors’ fees with respect to the annual audit in light of all relevant matters.

8. Review and pre-approve all audit and non-audit service engagement fees and terms in accordance with applicable law, including those provided to the subsidiaries of the corporation by the external auditors or any other person in its capacity as external auditors of such subsidiary. Between scheduled committee meetings, the chair of the committee, on behalf of the committee, is authorised to pre-approve any audit or non-audit service engagement fees and terms. At the next committee meeting, the chair shall report to the committee any such pre-approval given. Establish and adopt procedures for such matters.

Internal Auditor

1. Review and approve the appointment or removal of the internal auditor.

2. Review and discuss with the external auditors, management, and internal auditor the responsibilities, budget and staffing of the corporation’s internal audit function.

3. Review and approve the mandate for the internal auditor and the scope of annual work planned by the internal auditor, receive summary reports of internal audit findings, management’s response thereto, and reports on any subsequent follow-up to any identified weakness.

4. Ensure that the internal auditor has direct and open communication with the committee and that the internal auditor meets regularly with the committee without the presence of management to discuss any matters that the committee or the internal auditor believe should be discussed privately, such as problems or difficulties which were encountered in the course of internal audit work, including restrictions on the scope of activities or access to required information, and any disagreements with management.

5. Review and discuss with the internal auditor and management the internal auditor’s ongoing assessments of the corporation’s business processes and system of internal controls.

6. Review the effectiveness of the internal audit function, including staffing, organizational structure and qualifications of the internal auditor and staff.

Compliance

1. Monitor compliance by the corporation with all payments and remittances required to be made in accordance with applicable law, where the failure to make such payments could render the directors of the corporation personally liable.

2. The receipt of regular updates from management regarding compliance with laws and regulations and the process in place to monitor such compliance, excluding, however, legal compliance matters subject to the oversight of the safety, health and environment committee of the board. Review the findings of any examination by regulatory authorities and any external auditors’ observations relating to such matters.

3. Establish and oversee the procedures in the code of conduct and ethics policy to address:

(a) the receipt, retention and treatment of complaints received by the corporation regarding accounting, internal accounting or auditing matters; and

(b) confidential, anonymous submissions by employees of concerns regarding questionable accounting and auditing matters.

2016 ANNUAL INFORMATION FORM    Page 133

Receive periodically a summary report from the senior vice-president, chief legal officer and corporate secretary on such matters as required by the code of conduct and ethics.

4. Review and recommend to the board for approval a code of conduct and ethics for employees, officers and directors of the corporation. Monitor management’s implementation of the code of conduct and ethics and the international business conduct policy and review compliance therewith by, among other things, obtaining an annual report summarizing statements of compliance by employees pursuant to such policies and reviewing the findings of any investigations of non-compliance. Periodically review the adequacy and appropriateness of such policies and make recommendations to the board thereon.

5. Monitor management’s implementation of the anti-fraud policy; and review compliance therewith by, among other things, receiving reports from management on:

(a) any investigations of fraudulent activity;

(b) monitoring activities in relation to fraud risks and controls; and

(c) assessments of fraud risk.

Periodically review the adequacy and appropriateness of the anti-fraud policy and make recommendations to the board thereon.

6. Review all proposed related party transactions and situations involving a director’s, senior officer’s or an affiliate’s potential or actual conflict of interest that are not required to be dealt with by an “independent committee” pursuant to securities law rules, other than routine transactions and situations arising in the ordinary course of business, consistent with past practice. Between scheduled committee meetings, the chair of the committee, on behalf of the committee, is authorised to review all such transactions and situations. At the next committee meeting, the chair shall report the results of such review. Ensure that political and charitable donations conform with policies and budgets approved by the board.

7. Monitor management of hedging, debt and credit, make recommendations to the board respecting policies for management of such risks, and review the corporation’s compliance therewith.

8. Approve the review and approval process for the expenses submitted for reimbursement by the chief executive officer.

9. Oversee management’s mitigation of material risks within the committee’s mandate and as otherwise assigned to it by the nominating, corporate governance and risk committee.

Financial Oversight

1. Assist the board in its consideration and ongoing oversight of matters pertaining to:

(a) capital structure and funding including finance and cash flow planning;

(b) capital management planning and initiatives;

(c) property and corporate acquisitions and divestitures including proposals which may have a material impact on the corporation’s capital position;

(d) the corporation’s annual budget and two-year business plan;

(e) the activities of the corporation’s trading group including financial results, compliance with approval limits, any significant breaches of policies, and risk measures on significant positions and the portfolio in aggregate;

(f) the corporation’s insurance program;

(g) directors’ and officers’ liability insurance and indemnity agreements;

(h) the annual approval to elect the end-user exception under Dodd Frank; and

(i) matters the board may refer to the committee from time to time in connection with the corporation’s capital position.

2016 ANNUAL INFORMATION FORM    Page 134

Organizational matters

1. The procedures governing the committee shall, except as otherwise provided for herein, be those applicable to the board committees as set forth in Part 7 of the General Bylaws of the corporation.

2. The members and the chair of the committee shall be entitled to receive remuneration for acting in such capacity as the board may from time to time determine.

3. The committee shall have the resources and authority appropriate to discharge its duties and responsibilities, including the authority to:

(a) select, retain, terminate, set and approve the fees and other retention terms of special or independent counsel, accountants or other experts, as it deems appropriate; and

(b) obtain appropriate funding to pay, or approve the payment of, such approved fees;

without seeking approval of the board or management.

4. Any member of the committee may be removed or replaced at any time by the board and shall cease to be a member of the committee upon ceasing to be a director. The board may fill vacancies on the committee by appointment from among its members. If and whenever a vacancy shall exist on the committee, the remaining members may exercise all its powers so long as a quorum remains in office. Subject to the foregoing, each member of the committee shall remain as such until the next annual meeting of shareholders after that member’s election.

5. The committee shall annually review and assess the adequacy of its mandate and recommend any proposed changes to the nominating, corporate governance and risk committee for recommendation to the board for approval.

6. The committee shall participate in an annual performance evaluation, the results of which will be reviewed by the board.

7. The committee shall perform any other activities consistent with this mandate, the corporation’s governing laws and the regulations of stock exchanges, as the committee or the board deems necessary or appropriate.

8. A standing invitation will be issued to all non-executive directors to attend the financial oversight portion of each committee meeting.

2016 ANNUAL INFORMATION FORM    Page 135