CALGARY, ALBERTA–(Marketwired – Aug. 3, 2016) –

NOT FOR DISTRIBUTION IN THE UNITED STATES. ANY FAILURE TO COMPLY WITH THIS RESTRICTION MAY CONSTITUTE A VIOLATION OF U.S. SECURITIES LAW.

Spartan Energy Corp. (“Spartan” or the “Company”) (TSX:SPE) is pleased to announce that it has completed the acquisition of approximately 450 boe/d (93% oil and liquids) of production in southeast Saskatchewan for a cash purchase price of $24 million (the “Acquisition”).

Spartan is also pleased to announce that it has entered into a bought deal financing agreement with a syndicate of underwriters co-led by Peters & Co. Limited, GMP Securities L.P. and TD Securities Inc. (collectively, the “Underwriters”) pursuant to which the Underwriters have agreed to purchase for resale to the public, on a bought deal basis, 22,100,000 common shares of Spartan (“Shares”) at a price of $3.18 per Share for total gross proceeds of $70,278,000 (the “Offering”). The Underwriters will have an option (the “Underwriters’ Option”) to purchase up to an additional 3,315,000 Shares at a price of $3.18 per Share to cover over-allotments, if any, exercisable in whole or in part at any time until 30 days after the closing date.

ASSET ACQUISITION

The assets acquired pursuant to the Acquisition (the “Assets”) are comprised of approximately 450 boe/d (93% oil and liquids) of low-decline production and 29.2 net sections of land, primarily focused in the Midale fairway of southeast Saskatchewan. The Assets include approximately 21.4 net sections of land complementary to Spartan’s existing acreage at Pinto and Alameda which are prospective for drilling open-hole and fracture stimulated wells in the Midale formation. Spartan has identified 79.5 net frac Midale and open-hole Midale and Frobisher drilling locations on the Assets.

FINANCING

Spartan has entered into an agreement on a “bought-deal” basis with the Underwriters for an offering of 22,100,000 Shares at a price of $3.18 per Share. The Underwriters have been granted the Underwriters’ Option to purchase up to an additional 3,315,000 Shares at a price of $3.18 per Share, exercisable in whole or in part at any time up until 30 days after the closing of the Offering. The net proceeds from the Offering will be used to reduce indebtedness under the Company’s credit facility, which has been drawn on to fund recent acquisitions, and for general corporate purposes.

The Offering will be completed by way of short form prospectus in certain of the provinces of Canada (excluding Québec) and on a private placement basis in the United States pursuant to exemptions from the registration requirements of the U.S securities laws. The Offering is subject to customary conditions including receipt of applicable regulatory approvals and is expected to close on or about August 24, 2016.

UPDATED 2016 CAPITAL BUDGET

Spartan’s 2016 corporate strategy has focused on maintaining balance sheet strength by spending within cash flow and furthering per share production and reserves growth by executing on acquisition opportunities afforded by the downturn in the commodity cycle. Spartan has delivered on this strategy in the first half of the year, executing a cash flow budget while completing four accretive acquisitions within our southeast Saskatchewan core area.

Spartan’s strategy remains unchanged in the second half of the year. Our board of directors has approved a 2016 capital budget of $68 million, which is expected to be approximately cash flow neutral assuming an average WTI oil price of $46.83 over the second half of 2016. We anticipate this spending level will yield average production of approximately 10,700 boe/d (92% oil and liquids) and exit production of approximately 12,500 boe/d (89% oil and liquids), representing debt adjusted per share growth of approximately 8% and 13%, respectively, over 2015. Projected net debt at the end of 2016 is approximately $58 million ($48 million in the event the Underwriters’ Option is exercised in full) with a revolving credit facility of $150 million.

We commenced drilling operations in June following the completion of spring break-up conditions in the field, and we currently have two rigs operating in our southeast Saskatchewan core area. In the first quarter, we drilled 10 (8.5 net) open-hole Mississippian wells and 5 (3.6 net) frac Midale wells, and completed an additional 7 (5.9 net) previously drilled Viking wells. Our capital budget contemplates drilling an additional 46 (38.2 net) open-hole wells and 7 (6.8 net) frac Midale wells. Open-hole wells will primarily target our greater Winmore and Queensdale areas and will focus on infill drilling and pool extensions. Our frac Midale wells will be focused in the Alameda area on lands recently acquired pursuant to the purchase of Wyatt Oil + Gas Inc. Spartan’s capital program remains flexible and we will adjust capital expenditures in the second half of the year depending upon prevailing commodity prices.

Note:

(1) $48 million in the event the Underwriters’ Option is exercised in full.

OUTLOOK

Following the completion of our recent acquisitions and the Offering, Spartan remains well positioned to deliver per share growth in a variable commodity price environment. The majority of our drilling locations remain economic in a depressed price scenario, allowing us to sustain production while using our strong cost of capital and balance sheet flexibility to pursue additional accretive acquisitions. In a rising price environment, the torque to oil prices provided by our light oil production base, together with our deep drilling inventory, provide the ability to deliver significant organic production growth within cash flow.

READER ADVISORY

BOE Disclosure. The term barrels of oil equivalent (“BOE”) may be misleading, particularly if used in isolation. A BOE conversion ratio of six thousand cubic feet per barrel (6mcf/bbl) of natural gas to barrels of oil equivalence is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. All BOE conversions in the report are derived from converting gas to oil in the ratio mix of six thousand cubic feet of gas to one barrel of oil.

Forward Looking Statements. Certain information included in this press release constitutes forward-looking information under applicable securities legislation. Forward-looking information typically contains statements with words such as “anticipate”, “believe”, “expect”, “plan”, “intend”, “estimate”, “propose”, “project” or similar words suggesting future outcomes or statements regarding an outlook. Forward-looking information in this press release may include, but is not limited to, statements concerning expected production and cash flow related to the Acquisition, expected number of future drilling locations related to the Acquisition, the anticipated closing date of the Offering, the use of proceeds from the Offering, future capital spending levels, the number and type of wells to be drilled in 2016, future production levels, future cash flows, 2016 net debt, future balance sheet flexibility and future acquisition opportunities.

The forward-looking statements contained in this press release are based on certain key expectations and assumptions made by Spartan, including expectations and assumptions concerning the success of future drilling, development and completion activities, the performance of existing wells, the performance of new wells, the availability and performance of facilities and pipelines, the geological characteristics of Spartan’s properties, the successful application of drilling, completion and seismic technology, prevailing weather conditions, prevailing legislation affecting the oil and gas industry, commodity prices, royalty regimes and exchange rates, the application of regulatory and licensing requirements, the availability of capital, labour and services, the creditworthiness of industry partners and the ability to source and complete asset acquisitions.

Although Spartan believes that the expectations and assumptions on which the forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because Spartan can give no assurance that they will prove to be correct. Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to, risks associated with the oil and gas industry in general (e.g., operational risks in development, exploration and production; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to production, costs and expenses, and health, safety and environmental risks), constraint in the availability of services, commodity price and exchange rate fluctuations, changes in legislation impacting the oil and gas industry, adverse weather or break-up conditions and uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects or capital expenditures. These and other risks are set out in more detail in Spartan’s Annual Information Form for the year ended December 31, 2015.

Forward-looking information is based on a number of factors and assumptions which have been used to develop such information but which may prove to be incorrect. Although Spartan believes that the expectations reflected in its forward-looking information are reasonable, undue reliance should not be placed on forward-looking information because Spartan can give no assurance that such expectations will prove to be correct. In addition to other factors and assumptions which may be identified in this press release, assumptions have been made regarding and are implicit in, among other things, the timely receipt of any required regulatory approvals (including Court and shareholder approvals) and the satisfaction of all conditions to the completion of the transaction. Readers are cautioned that the foregoing list is not exhaustive of all factors and assumptions which have been used.

The forward-looking information contained in this press release is made as of the date hereof and Spartan undertakes no obligation to update publicly or revise any forward-looking information, whether as a result of new information, future events or otherwise, unless required by applicable securities laws. The forward looking information contained in this press release is expressly qualified by this cautionary statement.

Future Oriented Financial Information: Any financial outlook or future oriented financial information in this press release, as defined by applicable securities legislation, has been approved by management of Spartan. Readers are cautioned that any such future-oriented financial information contained herein should not be used for purposes other than those for which it is disclosed herein. The Company and its management believe that the prospective financial information has been prepared on a reasonable basis, reflecting management’s best estimates and judgments, and represent, to the best of management’s knowledge and opinion, the Company’s expected course of action. However, because this information is highly subjective, it should not be relied on as necessarily indicative of future results.

Non-IFRS Measures. This press release provides certain financial measures that do not have a standardized meaning prescribed by IFRS. These non-IFRS financial measures may not be comparable to similar measures presented by other issuers. Cash flow from operations is not a recognized measure under IFRS. Management believes that in addition to net income (loss), cash flow from operations is a useful supplemental measures that demonstrates the Company’s ability to generate the cash necessary to repay debt or fund future capital investment. Investors are cautioned, however, that this measure should not be construed as an alternative to net income (loss) determined in accordance with IFRS as an indication of Spartan’s performance. Spartan’s method of calculating this measure may differ from other companies and accordingly, they may not be comparable to measures used by other companies. Cash flow from operations is calculated by adjusting net income (loss) for other income, unrealized gains or losses on financial derivative instruments, transaction costs, accretion, share based compensation, impairment and depletion and depreciation.

Drilling Locations. This press release discloses drilling inventory in three categories: (i) proved locations; (ii) probable locations; and (iii) unbooked locations. Proved locations and probable locations are derived from Spartan’s internal evaluation prepared by a qualified reserves evaluator in accordance with NI 51-101 and the COGE Handbook and account for drilling locations that have associated proved and/or probable reserves, as applicable. Unbooked locations are internal estimates based on our prospective acreage and an assumption as to the number of wells that can be drilled per section based on industry practice and internal review. Unbooked locations do not have attributed reserves or resources. Of the 79.5 total net drilling locations identified within the Assets, 28.1 are net proved locations, 3.0 are net probable locations and 48.4 are net unbooked locations. Unbooked locations have been identified by management as an estimation of our multi‐year drilling activities based on evaluation of applicable geologic, seismic, engineering, production and reserves information. There is no certainty that the Company will drill all unbooked drilling locations and if drilled, there is no certainty that such locations will result in additional oil and gas reserves, resources or production. The drilling locations on which we actually drill wells will ultimately depend upon the availability of capital, regulatory approvals, seasonal restrictions, oil and natural gas prices, costs, actual drilling results, additional reservoir information that is obtained and other factors. While certain of the unbooked drilling locations have been de‐risked by drilling existing wells in relative close proximity to such unbooked drilling locations, other unbooked drilling locations are farther away from existing wells where management has less information about the characteristics of the reservoir and therefore there is more uncertainty whether wells will be drilled in such locations and if drilled there is more uncertainty that such wells will result in additional oil and gas reserves, resources or production.

This press release is not an offer of the securities for sale in the United States. The securities have not been registered under the U.S. Securities Act of 1933, as amended, and may not be offered or sold in the United States absent registration or an exemption from registration. This press release shall not constitute an offer to sell or the solicitation of an offer to buy nor shall there be any sale of the securities in any state in which such offer, solicitation or sale would be unlawful.

TORONTO, ONTARIO–(Marketwired – Aug. 3, 2016) – Uranium Participation Corporation (“UPC”) (TSX:U) reports its estimated net asset value at July 31, 2016 was CAD$491.4 million or CAD$4.25 per share. As at July 31, 2016, UPC’s investment portfolio consisted of the following:

On July 29, 2016, the common shares of UPC closed on the TSX at a value of CAD$4.01, which represents a 5.65% discount to the net asset value per share of CAD$4.25.

About Uranium Participation Corporation

Uranium Participation Corporation is a company that invests substantially all of its assets in uranium oxide in concentrates (“U₃O₈“) and uranium hexafluoride (“UF₆“) (collectively “uranium”), with the primary investment objective of achieving appreciation in the value of its uranium holdings through increases in the uranium price. Additional information about Uranium Participation Corporation is available on SEDAR at www.sedar.com and on Uranium Participation Corporation’s website at www.uraniumparticipation.com.

VANCOUVER, BRITISH COLUMBIA–(Marketwired – Aug. 3, 2016) – Redzone Resources Ltd. (“Redzone” or the “Company”) (TSX VENTURE:REZ) is pleased to announce that it has entered into a binding letter agreement (the “Agreement”) with two vendors (the “Vendors”) providing for the grant to the Company of an option to acquire up to a 100% interest in the property known as the Lucky Mica Claim Group (the “Property”).

The claims comprising the Property are situated approximately 8 miles south west of the city of Wickenburg in Maricopa County, Arizona. The Property consists of 14 contiguous unpatented lode claims totaling approximately 280 acres. The claims cover the “Fortner and Boyd Lithium Deposit” recorded as such by the USGS (United States Geological Survey) as Deposit 10064183 and catalogued as MRDS (Mineral Resources Data System) ID TC38458, hereby referred to as the “Mineralization”.

The Mineralization occurs within a pegmatite dyke in granitic rocks and schists. The dyke contains lithium bearing micas noted as spodumene, amblygonite, lepidolite and beryl. Field visits by a Company representative confirm that the width of the dyke varies between 10 meters and 25 meters and extends in a north south direction for approximately 600 meters.

The Mineralization has been explored and developed intermittently since 1950 and during that time a small shaft was sunk to a reported depth of 30ft from which two adits were driven along the footwall both to the north and south. The dip of the dyke noted in the shaft was between 65 and 70 degrees. In addition 12 bulldozer trenches were completed in the 1950’s. These are situated at intervals of approximately 50 meters along the strike of the Mineralization varying in depth from 2.0 to 4.0 meters. These have helped define the surface dimensions of the Mineralization.

In the archives of the Arizona Geological Society files from the Arizona Department of Mineral Resources contain information recorded by Department Field Engineers after visiting the Property. The reports are from 1952 through 1964. In the 1964 Field Engineers report it states “75 wagon drill holes were completed at an average depth of 187 feet”. In addition A Mine Owners Report from 1958 states “Wagon drilling shows the ore body extends 110 ft (in depth) from end to end”. Records show the drilling was completed by the Consolidated Uranium Co. of Canada but this has not been verified. A Field Engineers Report dated October 1964 also states that the then owner, Hanley, reports Li grades of between 3.0% and 3.5%.(Arizona Department of Mines and Mineral Resources AZMILS Data – Lucky Mica, Department of Mineral Resources, State Of Arizona Reports.)

The mineral descriptions and grades cited above are presented only in a historical context and use historical terminology which does not conform to current standards and, as such, should not be relied upon. Although the historical data is believed to be based on reasonable assumptions, such data was generated prior to the implementation of National Instrument 43-101 (“NI 43-101″). These historical descriptions do not meet current standards as set forth under NI 43-101 and therefore should not be relied upon.

A Company representative conducted sampling on the Property and submitted 4 samples from the Property to ALS Minerals in Reno Nevada for analysis. The samples were crushed, split, a portion was pulverized and a one (1) gram aliquot analyzed by ALS Chemex method ME-MS61 (48 element, including lithium, four acid ICP-MS). Duplicates of all samples have been retained by the Company in a secure location. As a check the pulps from all four samples were analyzed by ALS Chemex method “Li-OG63″ Four Acid Digestion with an ICP finish.

A select grab sample taken by the Company representative of hand sorted micas on the side of a bulldozer trench returned an assay of 2.67% Li, a chip sample across 1.2 meters from the face of one of the trenches returned 0.427% Li, two further grab samples from two of the faces of the trenches assayed 408 parts per million (“ppm”) Li and 380 ppm Li. Other anomalous elements noted in the samples were Rubidium and Phosphorus. Potential quantity and grade is conceptual in nature. There has been insufficient exploration to define a mineral resource at the Property to date and it is uncertain if further exploration will result in the target being defined as a mineral resource.

The Company plans to conduct further sampling, deposit scale mapping and mineralogical studies on the micas and other constituent minerals at the Property, as well as to conduct trenching and geophysics initially comprised of magnetics to assist with geological mapping, as well as EM and radiometrics if appropriate.

In order to earn an initial 75% interest in the Property, subject to a 0.5% net smelter return royalty (“NSR”), the Company is required to (i) issue an aggregate of 400,000 common shares to the Vendors over a two year period, of which 300,000 common shares must be issued in the first 15 months; (ii) make aggregate cash payments to the Vendors of US$37,500, of which US$17,500 must be paid in the first 15 months; and (iii) complete exploration expenditures of US$100,000 on the Property over the first year. As of July 29, 2016, the Company’s total current assets (cash and cash equivalents) were approximately $500,000.

Upon exercising its initial option to earn a 75% interest in the Property, the Company shall have the further option to acquire the remaining 25% interest in the Property, subject to an aggregate .667% NSR on the Property (which may be purchased by the Company in consideration of a cash payment of $1,000,000). The Company can exercise this further option to earn the remaining 25% interest by (i) making an additional cash payment of US$25,000 to the Vendors; (ii) issuing an additional 100,000 common shares to the Vendors; and (iii) completing additional exploration expenditures on the Property in the aggregate amount of US$400,000 over the ensuing two year period.

The Agreement remains subject to, among other things, the receipt of all applicable regulatory approvals, including the approval of the TSX Venture Exchange. One of the Vendors, Alan Matthews, is a non-arm’s length party to the Company, as he is also a director of the Company.

All scientific and technical information set forth herein concerning the Property has been prepared under the supervision of Richard A. Graham, P. Geol., who is a consulting geologist to Redzone and is a “qualifying person” within the meaning of NI 43-101. Mr. Graham has verified all of the scientific and technical information respecting the Property set forth herein, other than information obtained from the archives of the Arizona Geological Society as he did not have access to the necessary historical data to verify the information set forth in such archives.

About Redzone Resources Ltd.

Redzone is a mineral exploration company. Redzone is listed on the TSX Venture Exchange (REZ) and more information can be found at www.redzoneresources.ca.

The TSX Venture Exchange does not accept responsibility for the adequacy or accuracy of this release.

Forward Looking Statements – Certain information set forth in this news release may contain forward-looking statements that involve substantial known and unknown risks and uncertainties. These forward-looking statements are subject to numerous risks and uncertainties, certain of which are beyond the control of Redzone, including, but not limited to the impact of general economic conditions, industry conditions, dependence upon regulatory approvals, and the availability of financing. Readers are cautioned that the assumptions used in the preparation of such information, although considered reasonable at the time of preparation, may prove to be imprecise and, as such, undue reliance should not be placed on forward-looking statements.

CALGARY, AB–(Marketwired – August 02, 2016) – Husky Energy’s (TSX: HSE) China subsidiary has signed a Heads of Agreement (HOA) with CNOOC Limited and relevant companies for the price adjustment of natural gas from the Liwan 3-1 and Liuhua 34-2 fields that would see the price set at $12.50-15.00 Cdn per thousand cubic feet (mcf) at current exchange rates.

“Long term fundamentals remain strong for natural gas demand in China. The price adjustment will allow Husky and CNOOC to maintain their market share in a competitive gas market,” said CEO Asim Ghosh. “We reached this agreement in the spirit of the longstanding relationship between Husky and CNOOC that brought to life the first deepwater development offshore China.”

Gross take-or-pay volumes from the fields remain unchanged in the range of 300-330 million cubic feet per day (mmcf/day). Liquids production, net to Husky, is also expected to remain in the range of 5,000-6,000 barrels per day. The price adjustment under the HOA is effective as of November 20, 2015 and the settlement of outstanding payments is calculated from that date.

“Husky and CNOOC plan to further deepen their cooperation and have undertaken to jointly create more value with the advancement of the Liuhua 29-1 gas field,” said Ghosh.

Plans will get underway to finalize the commercial and development approach to tie the Liuhua 29-1 field into the Liwan infrastructure. Liuhua 29-1 gross gas sales volumes are expected to add approximately 80 mmcf/day.

Husky holds a 49 percent interest in the Production Sharing Contract (PSC) for the Liwan Gas Project and operates the deepwater infrastructure. CNOOC Limited holds a 51 percent interest in the PSC and operates the shallow water facilities and the onshore gas terminal.

Husky and CNOOC continue to advance a rich portfolio of opportunities in the Asia Pacific Region, including several shallow water natural gas and liquids developments offshore Indonesia.

Husky Energy is one of Canada’s largest integrated energy companies. It is headquartered in Calgary, Alberta, Canada and its common shares are publicly traded on the Toronto Stock Exchange under the symbol HSE. More information is available at www.huskyenergy.com

FORWARD-LOOKING STATEMENTS

Certain statements in this news release are forward-looking statements and information (collectively “forward-looking statements”), within the meaning of the applicable Canadian securities legislation, Section 21E of the United States Securities Exchange Act of 1934, as amended, and Section 27A of the United States Securities Act of 1933, as amended. The forward-looking statements contained in this news release are forward-looking and not historical facts.

Some of the forward-looking statements may be identified by statements that express, or involve discussions as to, expectations, beliefs, plans, objectives, assumptions or future events or performance (often, but not always, through the use of words or phrases such as “will likely result”, “are expected to”, “will continue”, “is anticipated”, “is targeting”, “estimated”, “intend”, “plan”, “projection”, “remain”, “could”, “aim”, “vision”, “goals”, “objective”, “target”, “schedules” and “outlook”). In particular, forward-looking statements in this news release include, but are not limited to, references to: long term fundamentals remaining strong for natural gas demand in China; take-or-pay volumes and liquids production from the Liwan fields; and anticipated gross gas sales volumes for Liuhua 29-1.

There are numerous uncertainties inherent in projecting future sales volumes. The total amount of actual sales volumes may vary from initial estimates.

Although the Company believes that the expectations reflected by the forward-looking statements presented in this news release are reasonable, the Company’s forward-looking statements have been based on assumptions and factors concerning future events that may prove to be inaccurate. Those assumptions and factors are based on information currently available to the Company about itself and the businesses in which it operates. Information used in developing forward-looking statements has been acquired from various sources including third-party consultants, suppliers, regulators and other sources.

Because actual results or outcomes could differ materially from those expressed in any forward-looking statements, investors should not place undue reliance on any such forward-looking statements. By their nature, forward-looking statements involve numerous assumptions, inherent risks and uncertainties, both general and specific, which contribute to the possibility that the predicted outcomes will not occur. Some of these risks, uncertainties and other factors are similar to those faced by other oil and gas companies and some are unique to Husky.

The Company’s Annual Information Form for the year ended December 31, 2015 and other documents filed with securities regulatory authorities (accessible through the SEDAR website www.sedar.com and the EDGAR website www.sec.gov) describe risks, material assumptions and other factors that could influence actual results and are incorporated herein by reference.

Any forward-looking statement speaks only as of the date on which such statement is made, and, except as required by applicable securities laws, the Company undertakes no obligation to update any forward-looking statement to reflect events or circumstances after the date on which such statement is made or to reflect the occurrence of unanticipated events. New factors emerge from time to time, and it is not possible for management to predict all of such factors and to assess in advance the impact of each such factor on the Company’s business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statement. The impact of any one factor on a particular forward-looking statement is not determinable with certainty as such factors are dependent upon other factors, and the Company’s course of action would depend upon its assessment of the future considering all information then available.

CALGARY, ALBERTA–(Marketwired – Aug. 2, 2016) –

NOT FOR DISTRIBUTION TO U.S. NEWS WIRE SERVICES OR DISSEMINATION IN THE UNITED STATES.

Pine Cliff Energy Ltd. (“Pine Cliff” or the “Company“) (TSX:PNE) is pleased to announce that it has issued subordinated floating charge debentures to insiders of the Company for a total of $11 million (the “Debentures“), entered into a purchase and sale agreement to sell a non-core oil asset for $5.5 million (the Disposition“) and extended its semi-annual borrowing base redetermination with its banking syndicate of Canadian Financial Institutions (the “Syndicate“) until August 10, 2016.

The Debentures mature on July 29, 2018, can be repaid at any time without penalty and will bear interest at 0.25% less than the monthly average effective interest rate paid to the Syndicate. The proceeds from the Debentures will be used to pay down bank indebtedness resulting in a permanent reduction to the Company’s borrowing facility.

The Disposition will be effective July 1, 2016 and is anticipated to close on August 10, 2016. The agreement related to the Disposition is subject to various standard conditions and there is no assurance that the Disposition will close at all. The Disposition assets currently produce approximately 130 barrels per day of oil.

About Pine Cliff

Pine Cliff is a natural gas company with a long-term view of creating shareholder value. Further information relating to Pine Cliff may be found on www.sedar.com as well as on Pine Cliff’s website at www.pinecliffenergy.com.

Cautionary Statements

Certain statements contained in this news release include statements which contain words such as “anticipate”, “could”, “should”, “expect”, “seek”, “may”, “intend”, “likely”, “will”, “believe” and similar expressions, statements relating to matters that are not historical facts, and such statements of our beliefs, intentions and expectations about development, results and events which will or may occur in the future, constitute “forward-looking information” within the meaning of applicable Canadian securities legislation and are based on certain assumptions and analysis made by us derived from our experience and perceptions. In particular, this news release contains statements regarding the operational, economic and financial impacts of the Disposition on Pine Cliff, anticipated use of the net proceeds of the Disposition and the anticipated closing date of the Disposition. The foregoing statements assume all the conditions, including applicable regulatory approvals and to completion of the Disposition will be satisfied. There is no assurance that all of the conditions to the Disposition will be met and therefore there is a risk that the Disposition will not be completed in the form described above or at all. In the event the Disposition does not close as presently anticipated, Pine Cliff will not realize the anticipated benefits of the Disposition. As such, many factors could cause the performance or achievement of Pine Cliff to be materially different from any future results, performance or achievements that may be expressed or implied by such forward-looking statements. Because of the risks, uncertainties and assumptions contained herein, readers should not place undue reliance on these forward-looking statements.

Actual results, performance or achievements could differ materially from those expressed in, or implied by, this forward-looking information and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking information will transpire or occur, or if any of them do, what benefits will be derived there from. Except as required by law, Pine Cliff disclaims any intention or obligation to update or revise any forward-looking information, whether as a result of new information, future events or otherwise.

Certain information contained herein is based on Pine Cliff internal estimates. Although Pine Cliff believes such information is accurate and reliable, at this time such information has not been verified by any independent sources and Pine Cliff does not make any representations as to the accuracy of such estimates.

The forward-looking information contained in this release is expressly qualified by this cautionary statement.

VANCOUVER, BRITISH COLUMBIA–(Marketwired – Aug. 2, 2016) – Advantage Lithium Corp. (the “Company” or “Advantage Lithium“) (TSX VENTURE:AAL), is pleased to announce it has received conditional approval, from the TSX.V Venture Exchange (“TSX.V”), to close the financing announced June 20^th. The Company has received subscription agreements for 16 million shares to raise $4.0 million. Final approval is expected in conjunction with TSX approval of the farm-in agreement with Nevada Sunrise.

The working capital from this financing will allow the Company to fund anticipated corporate overheads, initial acquisition costs, tenure payments and all initial work programs for the lithium brine projects in Nevada, including:

• Clayton NE, adjacent to Albemarle’s Silver Peak mine in the Clayton Valley Basin – N. America’s only brine-hosted lithium production.
• Jackson Wash, located in the Lida Valley of Nevada – potential to host reservoir of continental brine-based lithium
• Gemini, located in the Lida Valley Basin – a flat, desert basin with a similar geological setting to the lithium-rich Clayton Valley basin.

David Sidoo, Proposed President and Director, of Advantage Lithium, commented, “We are pleased to have attracted the investors to close out the full financing and raise $ 4 million, this confirms the investors’ confidence in our team and strategy. The funds will finance exploration programs on our highly-prospective lithium brine projects in Nevada and we will continue to review additional opportunities. With Tesla’s $5 billion Gigafactory now open for business, the timing for Advantage Lithium, and the sector in general, couldn’t be better”.

The technical information in this news release has been prepared in accordance with the Canadian regulatory requirements set out in National Instrument 43-101 and reviewed on behalf of the company by Ross McElroy, P.Geol., Technical Advisor to Advantage Lithium Corp., and the Designated Qualified person for the company.

About Advantage Lithium Corp.

Advantage Lithium Corp. is a resource company specializing in the strategic acquisition, exploration and development of lithium properties and is headquartered in Vancouver, British Columbia. Common Shares are listed on the TSX Venture Exchange under the symbol “AAL.H”.

ADVANTAGE LITHIUM CORP.

Nick DeMare, Corporate Secretary

Cautionary Statement:

Completion of the transaction is subject to a number of conditions, including but not limited to, Exchange acceptance and if applicable pursuant to Exchange Requirements, majority of the minority shareholder approval. Where applicable, the transaction cannot close until the required shareholder approval is obtained. There can be no assurance that the transaction will be completed as proposed or at all.

Investors are cautioned that, except as disclosed in the management information circular or filing statement to be prepared in connection with the transaction, any information released or received with respect to the transaction may not be accurate or complete and should not be relied upon. Trading in the securities of a capital pool company should be considered highly speculative.

The TSX Venture Exchange Inc. has in no way passed upon the merits of the proposed transaction and has neither approved nor disapproved the contents of this press release.

Certain information contained in this press release constitutes “forward-looking information”, within the meaning of Canadian legislation. Generally, these forward-looking statements can be identified by the use of forward-looking terminology such as “plans”, “expects” or “does not expect”, “is expected”, “budget”, “scheduled”, “estimates”, “forecasts”, “intends”, “anticipates” or “does not anticipate”, or “believes”, or variations of such words and phrases or state that certain actions, events or results “may”, “could”, “would”, “might” or “will be taken”, “occur”, “be achieved” or “has the potential to”. Forward looking statements contained in this press release may include statements regarding the future operating or financial performance of Advantage Lithium which involve known and unknown risks and uncertainties which may not prove to be accurate. Actual results and outcomes may differ materially from what is expressed or forecasted in these forward-looking statements. Such statements are qualified in their entirety by the inherent risks and uncertainties surrounding future expectations. Among those factors which could cause actual results to differ materially are the following: market conditions and other risk factors listed from time to time in our reports filed with Canadian securities regulators on SEDAR at www.sedar.com. The forward-looking statements included in this press release are made as of the date of this press release and the Company and Advantage Lithium disclaim any intention or obligation to update or revise any forward-looking statements, whether as a result of new information, future events or otherwise, except as expressly required by applicable securities legislation.

Neither TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this release.

KELOWNA, BRITISH COLUMBIA–(Marketwired – Aug. 2, 2016) – FISSION URANIUM CORP. (TSX:FCU)(OTCQX:FCUUF)(FRANKFURT:2FU) (“Fission” or “the Company“) is pleased to announce results from nine holes at its award-winning PLS project, host to the shallow, high-grade Triple R deposit, in Canada’s Athabasca Basin region: four holes drilled on R840W zone, four on R1620E zone and one within the gap between the R600W and R00E zones. Of key importance, wide, high-grade, shallow mineralization has been drilled at both R840W and R1620E – the westernmost and easternmost zones on Fission’s 2.58km trend. Of additional note, the high-grade core of R1620E zone has now reached over 95.0m in strike length. Drill Hole PLS16-500 hit 43.0m total composite mineralization, including 8.48m of >10,000 cps.

The high-grade R840W and R1620E zones have not yet been assessed for a resource estimate, but the significant intersections encountered on both zones indicate the potential to add to a resource estimate.

Ross McElroy, President, COO, and Chief Geologist for Fission, commented:

“Our strategy of targeting both ends of our 2.58km mineralized trend – the largest in the Athabasca Basin region – is proving to be very successful. Results at the R840W and R1620E zones include thick, high-grade mineralization near-to-surface. We have also grown the R1620E’s high-grade core to over 95m, which speaks to the potential of this rapidly-growing zone.”

Drilling Highlights Include:

• PLS16-500 (line 1545E)
  • 43.0m total composite mineralization over a 60.5m interval (between 86.0m to 146.5m), including
  • 8.48m of total composite >10,000 cps

• PLS16-498 (line 1515E)
  • 31.0m total composite mineralization (between 73.0m to 104.0m), including
  • 4.72m of total composite >10,000 cps

• PLS16-495 (line 855W)
  • 66.0m total composite mineralization over a 80.0m interval (between 137.0m to 217.0m), including
  • 3.00m of total composite >10,000 cps

R840W

R600W

R1620E

Natural gamma radiation in drill core that is reported in this news release was measured in counts per second (cps) using a hand held RS-121 Scintillometer manufactured by Radiation Solutions, which is capable of discriminating readings to 65,535 cps. Natural gamma radiation in down-hole drill hole surveys that are reported in this news release were measured in counts per second (cps) using a Mount Sopris 2GHF-1000 Triple Gamma probe, which allows for more accurate measurements in high grade mineralized zones. The Triple Gamma probe is preferred in zones of high grade mineralization. The reader is cautioned that scintillometer readings are not directly or uniformly related to uranium grades of the rock sample measured, and should be used only as a preliminary indication of the presence of radioactive materials. The degree of radioactivity within the mineralized intervals is highly variable and associated with visible pitchblende mineralization. All intersections are down-hole. All depths reported of core interval measurements including radioactivity and mineralization intervals widths are not always representative of true thickness and true thicknesses are yet to be determined in zones outside of the Triple R deposit. Within the Triple R deposit, individual zone wireframe models constructed from assay data and used in the resource estimate indicate that both the R780E and R00E zones have a complex geometry controlled by and parallel to steeply south-dipping lithological boundaries as well as a preferential sub-horizontal orientation.

PLS Mineralized Trend & Triple R Deposit Summary

Uranium mineralization at PLS occurs within the Patterson Lake Conductive Corridor and has been traced by core drilling approximately 2.58km of east-west strike length in five separated mineralized “zones”. From west to east, these zones are: R840W, R600W, R00E, R780E and R1620E. Thus far only the R00E and R780E have been included in the Triple R deposit resource estimate.

The discovery hole of what is now referred to as the Triple R uranium deposit was announced on November 05, 2012 with drill hole PLS12-022, from what is considered part of the R00E zone. Through successful exploration programs completed to date, it has evolved into a large, near surface, basement hosted, structurally controlled high-grade uranium deposit.

The Triple R deposit consists of the R00E zone on the western side and the much larger R780E zone further on strike to the east. Within the deposit, the R00E and R780E zones have an overall combined strike length validated by a resource estimate of approximately 1.05km with the R00E measuring approximately 105m in strike length and the R780E zones measuring approximately 945m in strike length. A 225m gap separates the R00E zone to the west and the R780E zones to the east, though sporadic narrow, weakly mineralized intervals from drill holes within this gap suggest the potential for further significant mineralization in this area. The R780E zone is located beneath Patterson Lake which is approximately six metres deep in the area of the deposit. The entire Triple R deposit is covered by approximately 50m to 60m of overburden.

Mineralization remains open along strike both to the western and eastern extents. Previous logging of drill core had interpreted certain sequences of basement rocks to be meta-sedimentary (meta-pelitic and meta-semi-pelitic gneiss) but recent observations have changed this interpretation and these lithologies are now believed to represent varying degrees of altered mafic volcanic rocks. Mineralization is both located within and associated with mafic volcanic intrusives with varying degrees of silicification, metasomatic mineral assemblages and hydrothermal graphite. The graphitic sequences are, associated with the PL-3B basement Electro-Magnetic (EM) Conductor. Recent very positive drill results returning wide and strongly mineralized intersections from the R600W zone and the R840W zone, located 480m and 765m respectively to the west along strike have significantly upgraded the prospectivity of these areas for further growth of the PLS resource on land to the west of the Triple R deposit. The recently discovered high-grade mineralization in the R1620E zone, located 270m to the east along strike has significantly upgraded the prospectivity for further growth of the PLS resource to the east of the Triple R deposit.

Updated maps, scint tables, gamma logs and cross sections can be found on the Company’s website at http://fissionuranium.com/project/pls/.

Patterson Lake South Property

The 31,039 hectare PLS project is 100% owned and operated by Fission Uranium Corp. PLS is accessible by road with primary access from all-weather Highway 955, which runs north to the former Cluff Lake mine and passes through the nearby UEX-Areva Shea Creek discoveries located 50km to the north, currently under active exploration and development.

The technical information in this news release has been prepared in accordance with the Canadian regulatory requirements set out in National Instrument 43-101 and reviewed on behalf of the company by Ross McElroy, P.Geol., President and COO for Fission Uranium Corp., a qualified person.

About Fission Uranium Corp.

Fission Uranium Corp. is a Canadian based resource company specializing in the strategic exploration and development of the Patterson Lake South uranium property – host to the class-leading Triple R uranium deposit – and is headquartered in Kelowna, British Columbia. Fission’s common shares are listed on the TSX Exchange under the symbol “FCU” and trade on the OTCQX marketplace in the U.S. under the symbol “FCUUF.”

ON BEHALF OF THE BOARD

Ross McElroy, President and COO

Cautionary Statement:

Certain information contained in this press release constitutes “forward-looking information”, within the meaning of Canadian legislation. Generally, these forward-looking statements can be identified by the use of forward-looking terminology such as “plans”, “expects” or “does not expect”, “is expected”, “budget”, “scheduled”, “estimates”, “forecasts”, “intends”, “anticipates” or “does not anticipate”, or “believes”, or variations of such words and phrases or state that certain actions, events or results “may”, “could”, “would”, “might” or “will be taken”, “occur”, “be achieved” or “has the potential to”. Forward-looking statements contained in this press release may include statements regarding the future operating or financial performance of Fission and Fission Uranium which involve known and unknown risks and uncertainties which may not prove to be accurate. Actual results and outcomes may differ materially from what is expressed or forecasted in these forward-looking statements. Such statements are qualified in their entirety by the inherent risks and uncertainties surrounding future expectations. Among those factors which could cause actual results to differ materially are the following: market conditions and other risk factors listed from time to time in our reports filed with Canadian securities regulators on SEDAR at www.sedar.com. The forward-looking statements included in this press release are made as of the date of this press release and the Company and Fission Uranium disclaim any intention or obligation to update or revise any forward-looking statements, whether as a result of new information, future events or otherwise, except as expressly required by applicable securities legislation.

TORONTO, ONTARIO–(Marketwired – Aug. 2, 2016) – Plateau Uranium Inc. (“Plateau Uranium” or the “Company“) (TSX VENTURE:PLU)(FRANKFURT:QG1) is pleased to announce previously unreleased metallurgical test work results from the Macusani Plateau Uranium Project in Peru. The work was completed by Cameco Research Centre personnel in Ontario as part of their previous investigation into processing options available for the treatment of the Macusani uranium mineralization. Data and reports were acquired as part of the acquisition of the projects previously worked by Cameco, and are owned by the Company. The Company is also pleased to announce the commencement of another phase of testwork expanding this comminution work to its other uranium deposit resource areas, and examine if similar factors may apply to the lithium and potassium present in the same material.

The Company also announces the award of shares and stock options to management, directors, employees and consultants.

Highlights

• Scrubbing work was undertaken previously by Cameco on Macusani uranium mineralization to explore the option to increase the uranium grade through selective comminution and rejection of a barren or waste grade material
• Tests were limited to 1/2 inch crush products on samples from Tantamaco and Isivilla uranium deposits
• Samples were prepared to represent two feed grades with ranges of 260-570 ppm and 580-800 ppm U₃O₈, which are in the typical ranges of the Macusani uranium deposits
• The tests identify an opportunity to reject 50-60% of the process feed mass in a coarse (+2mm) low grade fraction while 80-85% of the contained uranium was recoverd to the fines fraction (-2mm)
• Plateau Uranium has now commissioned Hydromet Pty Limited, which has reviewed the Cameco reports and will investigate repeating this test work on a larger sample set from the Company’s other, previously untested uranium deposits areas, in particular, the Chilcuno Chico and Colibri II-III deposits
• 60% upgrade factor based on example 80% uranium reporting to the fines fraction within only 50% of the original feed mass, which represents an equivalent increase in U₃O₈ grade of 60%

Ted O’Connor, CEO of Plateau Uranium commented:

“These results are extremely positive reflecting a significant (60%) grade increase in only 50% of the initial feed material. The original upgrading work and results were originally ignored because of the excellent metallurgical characteristics and heap leach amenability of the Macusani mineralization, and the resulting low potential operating costs. We are revisiting upgrading to potentially decrease capital and operating costs below the current PEA cash cost results of $17.28/lb U₃O₈ produced in light of continuing depressed uranium market conditions. The 2016 PEA 43-101 Technical Report identified the optimum feed grade over life of mine at 288 ppm U₃O₈ fully diluted, and 450 ppm U₃O₈ in the case of the smaller throughput High Grade option. The upgrade factor, if confirmed through additional work, would result in the process plant feed grade of 460 ppm U₃O₈ for the base case (approx. 1lb U₃O₈ per tonne) and 720 ppm for the High Grade option (approx. 1.57lbs U₃O₈ per tonne).

Extrapolating the upgrading potential to the entire resource should have a significant positive impact on the projected operating and capital costs reported in the PEA Study yielding a more positive economic project even in this current low uranium price environment, especially as we investigate vat and tank leach process options more seriously to integrate the Li-K by product recovery into the uranium story.

The next step we are initiating now is to extend this upgrading testwork to the remaining uranium deposits within the currently defined resource inventory, and also to confirm if the potential by-product lithium and potassium resources reported on May 6^th 2016 follow uranium in the same upgrading comminution step. The results of this test work will be reported when complete.”

Share Awards and Stock Option Grants

The Company also announces the approval of an award of shares to directors, officers and consultants in recognition of compensation concessions made to the Company during the difficult market conditions over the past several years. A total of 340,000 common shares have been awared, representing approximately 0.65% of the outstanding common shares.

In addition, a total of 2,440,000 stock options have been granted to directors, officers, employees and consultants of the Company under the Company’s stock option plan. Each stock option entitles the recipient to acquire one common share during the five-year period following the date of grant at a purchase price of $0.35. The option vest as to one-quarter immediately and a further one-quarter on the six, twelve and eighteen month anniversaries of the date of grant.

The share awards and stock option grants are subject to regulatory approval.

Qualified Persons

Mr. Grenvill Dunn, Pr Eng (RSA), C Eng (UK), MSAIMM, MSAIChE of Hydromet Pty Ltd, a consultant to the Company is a Qualified Person as defined under National Instrument 43-101 Standards of Disclosure for Mineral Projects, and has reviewed and approved the scientific and technical information contained in this release.

About Hydromet Pty Ltd

Hydromet Pty Limited is an international consulting company for the metals and mining industry. The company is based in South Africa and was established in 2000 by its director Grenvil Dunn. Mr Dunn is a Chemical Engineer with over 45 years of experience, particularly in mineral processing, flow sheet design and development with direct experience in uranium.

About Plateau Uranium

Plateau Uranium Inc. is a Canadian uranium exploration and development company focused on its properties on the Macusani Plateau in southeastern Peru. The Company controls all reported uranium resources known in Peru and mineral concessions that cover over 100,000 hectares (1,000 km²) situated near significant infrastructure. Plateau Uranium is listed on the TSX Venture Exchange under the symbol ‘PLU’ and the Frankfurt Exchange under the symbol ‘QG1′. For more information please visit www.plateauuranium.com.

Neither TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this release.

Website: www.plateauuranium.com

Facebook: www.facebook.com/plateauuranium/

Twitter: www.twitter.com/plateauuranium/

CALGARY, ALBERTA–(Marketwired – July 29, 2016) –

Q2 HIGHLIGHTS

(all financial figures are unaudited and in Canadian dollars unless otherwise noted)

• Earnings were $67 million or $0.57 per common share for the second quarter and $119 million or $1.11 per common share for the six-month period
• Fund Group available cash flow from operations (ACFFO) was $383 million and $898 million for the second quarter and six-month period, respectively
• Oil sands production that was curtailed for northeastern Alberta wildfires has substantially come back on line with the Fund Group’s liquids mainline system utilization returning to more anticipated levels
• Appointments of Laura A. Cillis and M. George Lewis as independent directors and trustees

Enbridge Income Fund Holdings Inc. (the Company or ENF) (TSX:ENF) announced today second quarter earnings of $67 million or $0.57 per common share representing a quarter-over-quarter increase in earnings per share of 32.6%. The increase in quarterly earnings per share was underpinned by the growth in cash flows generated by the businesses within the Fund Group.

The Fund Group is comprised of Enbridge Income Fund (the Fund), Enbridge Commercial Trust (ECT), Enbridge Income Partners LP (EIPLP) and the subsidiaries and investees of EIPLP. EIPLP holds the operating entities of the Fund Group and grew significantly in scope and scale after the transformative acquisition of certain Canadian liquids pipelines, storage and renewable energy assets from Enbridge Inc. (Enbridge) in September 2015 (the 2015 Transaction).

Fund Group ACFFO was $383 million and $898 million for the three and six months ended June 30, 2016, respectively, representing significant increases period-over-period. The increase in quarterly Fund Group ACFFO was driven primarily by stronger contributions from EIPLP’s Liquids Pipelines segment, reflecting the impacts of the 2015 Transaction, and new system expansion projects coming into service in late 2015. Volume throughput on the mainline system reached record levels in the first quarter of 2016 on the strength of these system expansions, driving growth in Fund Group ACFFO; however, extreme wildfires in northeastern Alberta in May 2016 adversely impacted Fund Group ACFFO in the second quarter. Oil sands production from facilities in the vicinity of Fort McMurray, Alberta was curtailed longer than originally anticipated, given the severity and longevity of the wildfires, which adversely impacted EIPLP’s mainline system deliveries during the quarter. On average, deliveries were lower by approximately 255,000 barrels per day (bpd) during the months of May and June. This represents an approximate 10% decrease in throughput compared with the throughput EIPLP was delivering prior to the wildfires.

The impact of reduced system deliveries on revenues negatively impacted EIPLP’s adjusted earnings before interest and income taxes (EBIT) and ACFFO in the second quarter by $36 million. Oil sands production substantially came back on line by the end of June and throughput on EIPLP’s mainline system and overall system utilization are expected to return to levels anticipated at the outset of the year, during the third quarter. Notwithstanding the impact of the wildfires, Fund Group ACFFO is still expected to be within the full-year 2016 guidance range of $1.75 billion to $2.05 billion.

“The safety of our people, the community that we operate in and the environment is, as always, our primary focus. We are committed to join with the residents, communities and industry of northern Alberta as they work to rebuild from the devastating wildfires.

“We’ve also worked closely with our customers, supporting their efforts to bring production back on line. By the end of May, most of our systems had returned to normal operation,” said Company President, Perry Schuldhaus.

“While the wildfires tempered a record start to the year, the impact was transitory and is not expected to have a lasting effect. Our financial performance through this challenging period for industry serves to reinforce the strength and resilience of our business model. We hold the premier position in Canadian liquids pipelines; an investment in a fully contracted and highly utilized natural gas pipeline; and a growing renewables-based power generation business which all support the reliability and predictability of the cash flow we generate and the dividends we pay to our shareholders. Looking forward, we are on track to complete close to $9 billion of growth capital projects over the next three years, approximately $4 billion of which will come into service in 2017. On the strength of this organic growth, and growing cash flow from recently completed projects, we continue to expect the Company to generate annual dividend growth of approximately 10% through 2019.”

The Company is pleased to announce the appointments of Laura A. Cillis and M. George Lewis to the Board of Directors of the Corporation, the Board of Trustees of ECT and the Board of Directors of Enbridge Pipelines Inc. (EPI), a subsidiary of EIPLP. Ms. Cillis and Mr. Lewis have joined the ECT Conflicts Committee and the Audit Committee of the Company and the Audit, Finance and Risk Committees of both ECT and EPI. Please refer to the Company’s website for full biographies of Ms. Cillis and Mr. Lewis.

“I am very pleased with the appointments of our new directors and trustees, which will add significant expertise, depth and strength to the Corporation and the Fund Group,” concluded Mr. Schuldhaus.

The Company’s Board of Directors declared a cash dividend of $0.1555 per common share to be paid on August 15, 2016 to shareholders of record at the close of business on August 2, 2016. On July 26, 2016 the Company’s Board of Directors declared a cash dividend of $0.1555 per common share to be paid on September 15, 2016 to shareholders of record at the close of business on August 31, 2016. The dividends are designated eligible dividends for Canadian tax purposes which qualify for the enhanced dividend tax credit. The Company offers a Dividend Reinvestment and Share Purchase Plan (DRIP) to enable participants to reinvest their dividends in common shares of the Company at a 2% discount to market price and to make additional optional cash payments to purchase common shares at the market price, free of brokerage or other charges. The DRIP participation rate for the dividend paid on July 15, 2016 was approximately 27%.

FORWARD-LOOKING INFORMATION

Forward-looking information, or forward-looking statements, have been included in this news release to provide information about the Company and its investee, the Fund, and the Fund’s direct and indirect investments and joint ventures (collectively, the Fund Group), including management’s assessment of future plans and operations of the Company and the Fund Group. This information may not be appropriate for other purposes. Forward-looking statements are typically identified by words such as “anticipate”, “expect”, “project”, “estimate”, “forecast”, “plan”, “intend”, “target”, “believe”, “likely” and similar words suggesting future outcomes or statements regarding an outlook. Forward-looking information or statements included or incorporated by reference in this document include, but are not limited to, statements with respect to the following: expected EBIT or expected adjusted EBIT; expected earnings/(loss) or adjusted earnings/(loss); expected earnings/(loss) per share; expected or target ACFFO; expected future cash flows; expected costs related to projects under construction; expected in-service dates for projects under construction; expected capital expenditures; expected equity funding requirements for the Fund Group’s commercially secured growth program; estimated future dividends or distributions; expectations regarding the impact of the wildfires in northeastern Alberta, including on adjusted EBIT and ACFFO; expected future actions of regulators; expected costs related to leak remediation and potential insurance recoveries; expectations regarding commodity prices; supply forecasts; future distributions to the Company by the Fund and dividend payout expectation.

Although the Company and the Fund Group believe these forward-looking statements are reasonable based on the information available on the date such statements are made and processes used to prepare the information, such statements are not guarantees of future performance and readers are cautioned against placing undue reliance on forward-looking statements. By their nature, these statements involve a variety of assumptions, known and unknown risks and uncertainties and other factors, which may cause actual results, levels of activity and achievements to differ materially from those expressed or implied by such statements. Material assumptions include assumptions about the following: the expected supply of and demand for crude oil, natural gas, natural gas liquids (NGL) and renewable energy; prices of crude oil, natural gas, NGL and renewable energy; exchange rates; completion of growth projects; inflation; interest rates; availability and price of labour and construction materials; operational reliability; impact of the wildfires in northeastern Alberta; customer and regulatory approvals; maintenance of support and regulatory approvals for the Fund Group’s projects; anticipated in-service dates; weather; the impact of the dividend policy on the Company’s or the Fund Group’s future cash flows; capital project funding; the Fund Group’s credit ratings; expected EBIT or expected adjusted EBIT; expected earnings/(loss) or adjusted earnings/(loss); expected earnings/(loss) per share; expected future cash flows and expected future ACFFO; and estimated future dividends or distributions. Assumptions regarding the expected supply of and demand for crude oil, natural gas, NGL and renewable energy, and the prices of these commodities, are material to and underlie all forward-looking statements.
These factors are relevant to all forward-looking statements as they may impact current and future levels of demand for the Fund Group’s services. Similarly, exchange rates, inflation and interest rates impact the economies and business environments in which the Company and the Fund Group operate and may impact levels of demand for the Fund Group’s services and cost of inputs, and are therefore inherent in all forward-looking statements. Due to the interdependencies and correlation of these macroeconomic factors, the impact of any one assumption on a forward-looking statement cannot be determined with certainty, particularly with respect to expected earnings/(loss), adjusted EBIT, ACFFO and associated per share amounts or estimated future dividends or distributions. The most relevant assumptions associated with forward-looking statements on projects under construction, including estimated completion dates and expected capital expenditures include the following: the availability and price of labour and construction materials; the effects of inflation and foreign exchange rates on labour and material costs; the effects of interest rates on borrowing costs; the impact of weather; and customer and regulatory approvals on construction and in-service schedules.

The Company’s and the Fund Group’s forward-looking statements are subject to risks and uncertainties pertaining to ACFFO guidance, operating performance, regulatory parameters, project approval and support, weather, economic and competitive conditions, public opinion, changes in tax law and tax rate increases, exchange rates, interest rates, commodity prices and supply of and demand for commodities, including but not limited to those risks and uncertainties discussed in this news release and in the Company’s and the Fund Group’s other filings with Canadian securities regulators. The impact of any one risk, uncertainty or factor on a particular forward-looking statement is not determinable with certainty as these are interdependent and the Company’s or the Fund Group’s future course of action depends on management’s assessment of all information available at the relevant time. Except to the extent required by applicable law, the Company and the Fund Group assume no obligation to publicly update or revise any forward-looking statements made in this news release or otherwise, whether as a result of new information, future events or otherwise. All subsequent forward-looking statements, whether written or oral, attributable to the Company or the Fund Group or persons acting on the Company’s or the Fund Group’s behalf, are expressly qualified in their entirety by these cautionary statements.

NON-GAAP MEASURES

This news release contains references to adjusted EBIT and ACFFO. Adjusted EBIT represents EIPLP EBIT, adjusted for unusual, non-recurring or non-operating factors on both a consolidated and segmented basis. These factors, referred to as adjusting items, are reconciled and discussed in the financial results sections.

Fund Group ACFFO consists of adjusted EBIT further adjusted for non-cash items, representing cash flow from the Fund Group’s underlying businesses, less deductions for maintenance capital expenditures, interest expense, applicable taxes and further adjusted for unusual, non-recurring or non-operating factors not indicative of the underlying or sustainable cash flows of the business. ACFFO is important to unitholders as the Fund Group’s objective is to provide a predictable flow of distributions to unitholders. ACFFO represents the Fund Group’s cash available to fund distributions to unitholders, as well as for debt repayments and reserves.

Management believes the presentation of adjusted EBIT and ACFFO give useful information to investors and unitholders as they provide increased transparency and insight into the performance of the Company and the Fund Group. Management uses adjusted EBIT and ACFFO to set targets, including the distribution payout target, and to assess the performance of the Company and the Fund Group. Adjusted EBIT and ACFFO are not measures that have standardized meanings prescribed by generally accepted accounting principles in the United States of America (U.S. GAAP) and are not U.S. GAAP measures. Therefore, these measures may not be comparable with similar measures presented by other issuers.

Please see the tables in the Performance Overview section which summarize the reconciliations of the GAAP and non-GAAP measures.

SECOND QUARTER 2016 PERFORMANCE OVERVIEW

For more information on the operating results of the Company, the Fund and EIPLP, please see the respective Management’s Discussion and Analysis (MD&A) on the Company’s website at http://www.enbridgeincomefund.com/Find-Shareholder-Information/Reports-and-Filings/English.aspx. The documents are also filed on SEDAR under Enbridge Income Fund Holding Inc.’s profile for the Company and under Enbridge Income Fund’s profile for the Fund and EIPLP.

Earnings Before Interest and Income Taxes

EIPLP’s EBIT for the second quarter of 2016 decreased to $348 million from $715 million in the same period of 2015 primarily driven by a reduced contribution from its Liquids Pipelines segment given a lower average International Joint Tariff Residual Benchmark Toll, which decreased effective April 1, 2016, as well as changes in unrealized derivative fair value losses recognized during the current quarter.

For the six months ended June 30, 2016, EBIT was $1,445 million compared with $297 million in the same period of 2015. The Canadian Mainline contribution increased primarily due to higher throughput that resulted from strong oil sands production in western Canada combined with contributions from the new assets placed into service in 2015, offset by the factors discussed previously for the discrete second quarter.

Adjusted Earnings Before Interest and Income Taxes

Excluding the impacts of the retrospective adjustments and significant unusual, non-recurring or non-operating factors, including changes in unrealized derivative fair value losses and system restart costs incurred as a result of the wildfires, EIPLP’s adjusted EBIT for the three and six months ended June 30, 2016 were $406 million and $959 million, respectively. The significant increases over the same periods of 2015 reflected the impact of the assets acquired in 2015 from Enbridge as well as increased capacity as a result of the expansion of EIPLP’s mainline system in the third quarter of 2015 and the reversal and expansion of Line 9B in the fourth quarter of 2015, which have provided access to the eastern Canada markets. However, the positive effect of the increased capacity on liquids pipelines throughput was substantially negated in the second quarter by the impact of the extreme wildfires in northeastern Alberta. The wildfires resulted in a curtailment of production from oil sands facilities and certain of EIPLP’s upstream pipelines and terminal facilities were temporarily shut down resulting in a disruption of service on EIPLP’s Regional Oils Sands System, with corresponding impacts on EIPLP’s downstream pipelines deliveries, including the Canadian Mainline. Reduced system deliveries resulted in a negative impact of approximately $36 million to EIPLP’s adjusted EBIT for the second quarter of 2016.

Fund Group ACFFO underpins its ability to pay distributions to its unitholders, including the Company. For the three and six months ended June 30, 2016, Fund Group ACFFO increased to $383 million and $898 million, respectively, from $82 million and $178 million for the comparable periods of 2015 primarily due to the significant cash flow contributions from the 2015 Transaction. These increases were partially offset by higher interest and current income taxes expenses in EIPLP attributable to higher business activity associated with the increased asset base, which also resulted in increased maintenance capital expenditures over the comparable period. Maintenance capital expenditures are expected to further increase in the second half of 2016. The impact of the wildfires in northeastern Alberta, mentioned previously, also partially offset the increase in Fund Group ACFFO.

The Fund Group’s payout ratio for the first half of 2016 was consistent with the comparable period of 2015 reflecting an increase in Fund Group ACFFO and distributions, both driven by the substantial increase in the scale and scope of the Fund Group’s operations as a result of the 2015 Transaction.

ENBRIDGE INCOME FUND HOLDINGS INC.

The Company’s distribution income represents substantially all of the Company’s earnings and cash flows and is derived from the Fund Group distributions paid to the Company. For the three and six months ended June 30, 2016, distribution income increased significantly over the comparable periods of 2015 reflecting the Company’s additional investments in the Fund Group in late 2015 and the first half of 2016 combined with an increase in the distribution rate on ordinary trust units of the Fund (Fund Units), which is underpinned by Fund Group ACFFO.

The following table summarizes the dividends declared by the Company for the six months ended June 30, 2016 and 2015 and the quarters therein.

CONFERENCE CALL

The Company will hold a joint conference call with Enbridge on Friday, July 29, 2016 at 9 a.m. Eastern Time (7 a.m. Mountain Time) to discuss the 2016 second quarter results. Analysts, members of the media and other interested parties can access the call toll-free at 1-866-215-5508 or within and outside North America at 1-514-841-2157 using the access code 42767653#. The call will be audio webcast live at http://edge.media-server.com/m/p/hghgffou. A webcast replay and podcast will be available approximately two hours after the conclusion of the event and a transcript will be posted to the website within 24 hours. The replay will be available at toll-free 1-888-843-7419 or within and outside North America at 1-630-652-3042 (access code 42767653#) for seven days after the call.

The conference call will begin with a presentation by Enbridge’s President and Chief Executive Officer and the Chief Financial Officer, followed by a question and answer period with Enbridge and ENF management for investment analysts. A question and answer period for members of the media will then immediately follow.

Enbridge Income Fund Holdings Inc. is a publicly traded corporation. The Company, through its investment in Enbridge Income Fund, which holds an indirect investment in Enbridge Income Partners LP, holds high quality, low risk energy infrastructure assets. Enbridge Income Partners LP’s assets include a portfolio of liquids transportation and storage businesses, including the Canadian Mainline, a 50% interest in the Canadian and United States portions of Alliance Pipeline, which transports natural gas, and renewable and alternative power generation assets. Enbridge Income Fund Holdings Inc. shares trade on the Toronto Stock Exchange under the symbol ENF. For more information visit www.enbridgeincomefund.com. None of the information contained in, or connected to, the Company’s website is incorporated in or otherwise forms part of this news release.

CALGARY, ALBERTA–(Marketwired – July 28, 2016) – Anterra Energy Inc. (“Anterra” or the “Company”) (TSX VENTURE:AE.A) announces that it has filed on SEDAR the following:

1. Financial Statements and related MD&A for the year ended December 31, 2015,
2. Financial Statements and related MD&A for the three months ended March 31, 2016, and
3. Statement of Reserve Data and Other Oil and Gas Information as Of December 31, 2015, NI 51-101 Form F1.

About Anterra Energy Inc.

Anterra is an independent oil focused junior exploration and production company with operating in the Western Canadian Sedimentary Basin. The Company is actively engaged in the acquisition, development and production of oil and natural gas complemented by the operation of fee-based midstream facilities. Anterra is headquartered in Calgary, Alberta, is listed and trades on the TSX-V under the symbol “AE.A”. Additional information is available on the Company’s website at www.anterraenergy.com.

Reader Advisories

Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this News Release.

LEWIS CENTER, OH–(Marketwired – July 28, 2016) – Midwest Energy Emissions Corp. (OTCQB: MEEC) (“ME₂C” or the “Company”), an emerging leader in mercury emissions control for the global power industry, will report its financial results before the market opens on Monday, August 8, 2016, for the three and six months ended June 30, 2016.

Management will host a conference call at 11:30 a.m. Eastern time on August 8, 2016, to discuss ME₂C’s second quarter 2016 results, provide a corporate update, and conclude with a Q&A from participants. To participate, please use the following information:

Conference Call and Webcast
Date: Monday, August 8, 2016
Time: 11:30 a.m. Eastern time
U.S. Dial-in: 1-877-874-1571
International Dial-in: 1-719-325-4835
Conference ID: 9078914
Webcast: http://public.viavid.com/index.php?id=120542

Please dial in at least 10 minutes before the start of the call to ensure timely participation.

A playback of the call will be available through October 8, 2016. To listen, call 1-877-870-5176 within the United States or 1-858-384-5517 when calling internationally. Please use the replay pin number 9078914.

About Midwest Energy Emissions Corp. (ME₂C)

Midwest Energy Emissions Corp. (OTCQB: MEEC) delivers patented and proprietary solutions to the global coal-power industry to remove mercury from power plant emissions, providing performance guarantees, and leading-edge emissions services. The U.S. Environmental Protection Agency (EPA) MATS rule, which has been subject to legal challenges, requires that all coal- and oil-fired power plants in the U.S., larger than 25 mega-watts, must remove roughly 90% of mercury from their emissions starting April 15, 2015. ME₂C has developed patented technology and proprietary products that have been shown to achieve mercury removal levels compliant with MATS at a significantly lower cost and with less operational impact than currently used methods, while preserving the marketability of fly-ash for beneficial use. For more information, please visit www.midwestemissions.com.

VANCOUVER, BC–(Marketwired – July 28, 2016) – Zadar Ventures Ltd. (TSX VENTURE: ZAD) (FRANKFURT: ZAV) (OTCQB: ZADDF) (the “Company”) is pleased to announce that it has initiated due diligence on the previously announced MOU with Macarthur Minerals Limited, (See Company News Release dated July 12, 2016) on the Ravensthorpe Lithium Project, in the Ravensthorpe region of South Western Australia.

RAVENSTHORPE LITHIUM PROJECT ACREAGE

The Ravensthorpe acreage comprises of two exploration license applications E74/587 and E74/588, which together cover an area of 91 square kilometers.

The Ravensthorpe acreage is, at its closest point, approximately seven kilometers from the Galaxy Resources’ Mount Cattlin Lithium development project, which is currently mining and processing spodumene and tantalum concentrate near Ravensthorpe in South Western Australia, with reported targeted production of approximately 150,000 tonnes for 2017. The Mount Cattlin Lithium Project is owned by Australian Securities Exchange listed Galaxy Resources Limited (ASX: GXY), who announced a merger with its joint venture partner, Australian Securities Exchange listed company, General Mining Corporation Limited (ASX: GMM) on May 30, 2016.

The Ravensthorpe acreage is located within the Cocanarup Terrane, which is dominated by intensely sheared and isoclinally folded Archean ultramafic rocks including spinifex-textured komatiite and pelitic metasediments.

HIGH GRADE LITHIUM OF ADJACENT PROJECTS

The Ravensthorpe Lithium Project is immediately adjacent to Australian Securities Exchange (ASX) listed Lithium Australia NL’s (LIA) Horseshoe, Phillips South and Deep Purple Prospects. LIA has announced the presence of lithium pegmatites from which rock chips have been taken with assays ranging between 2.4% Li₂0 up to 4.1% Li₂0 (See LIA News Release Dated July 12, 2016).

Company President Paul D. Gray, P.Geo. commented, “The timing of Zadar’s MOU for ground in these highly prospective geologic terranes for hard rock lithium mineralization could not have been better considering Lithium Australia’s recent announcement of high-grade lithium mineralization in pegamatites. Zadar is excited to get boots on the ground in this rapidly developing district, and moreover is distinctly keen to begin a fruitful working relationship with the quality in-County technical team of Macarthur Minerals.”

Due diligence of the Ravensthorpe acreage by Zadar will be conducted in unison with Macarthur Minerals and will begin in the near term where the initial concentratation of activities will focus on those areas that have had pegmatites previously identified and mapped by the Geological Survey of Western Australia (GSWA).

This news release has been reviewed and approved by Mr. Gray, PGeo, who is the company’s qualified person as defined by National Instrument 43-101.

ON BEHALF OF THE BOARD OF DIRECTORS,

Paul D. Gray, P. Geo.

President & CEO

Neither the TSX Venture Exchange nor its Regulation Service Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this release. This press release may contain certain forward-looking information. All statements included herein, other than statements of historical fact, forward-looking information and such information involves various risks and uncertainties. There can be no assurance that such information will prove to be accurate, and actual results and future events could differ materially from those anticipated in such information. A description of assumptions used to develop such forward-looking information and a description of risk factors that may cause actual results to differ materially from forward-looking information can be found in the company’s disclosure documents on the SEDAR website at www.sedar.com. The company does not undertake to update any forward-looking information except in accordance with applicable securities laws.

VANCOUVER, BRITISH COLUMBIA–(Marketwired – July 28, 2016) – Skyharbour Resources Ltd. (TSX VENTURE:SYH)(OTC:SYHBD)(FRANKFURT:SC1N) (the “Company”) is pleased to announce Mr. Paul Matysek, M.Sc., P.Geo, will be joining Skyharbour’s Advisory Board. Mr. Matysek is a mining entrepreneur, professional geochemist and geologist with over 35 years of experience in the mining industry. He has held senior executive and director positions with several natural resource exploration and development companies and is a proven company builder.

Mr. Matysek was the Founder, President and CEO of Energy Metals Corporation (“EMC”), a premier uranium company that traded on the New York and Toronto Stock Exchanges. Mr. Matysek led EMC as one of the fastest growing Canadian companies in recent years, increasing its market capitalization from $10 million in 2004 to approximately $1.8 billion when it was acquired by a larger uranium producer, Uranium One Inc., in 2007. Mr. Matysek is currently the President and CEO of Goldrock Mines Corp. (TSX VENTURE:GRM) which on June 7^th, 2016 announced it had entered into a definitive agreement to be acquired by Fortuna Silver Mines (NYSE:FSM)(TSX:FVI). Goldrock’s principal asset is the 100% owned Lindero Project located in Salta Province, Argentina and the transaction values Goldrock at $129 million on a fully-diluted in-the-money basis. Mr. Matysek is also the Executive Chairman and on the Board of Directors of Lithium X (TSX VENTURE:LIX), a lithium resource explorer with projects in Salta, Argentina and Clayton Valley, Nevada. Previously, Mr. Matysek was the President and CEO of Lithium One Inc., which developed a high quality lithium project in northern Argentina. In July 2012, Lithium One and Galaxy Resources merged with a $112 million plan to create a fully integrated lithium company. Prior to Lithium One, Mr. Matysek was the President and CEO of Potash One Inc. where he was the architect of the $434 million friendly takeover of Potash One by K+S Ag, which closed in early 2011.

Skyharbour’s, President and CEO, Jordan Trimble commented, “We are very pleased that Paul Matysek has agreed to join Skyharbour’s Advisory Board. He is an incredibly well respected leader in the resource industry and his expertise will be invaluable to the future development of the Company and our portfolio of projects in the Athabasca Basin. Having recently completed a significant deal with Denison Mines to acquire a 100% interest in the Moore Lake Uranium Project, we remain focused on building a preeminent uranium company with a strong management and advisory team. Paul’s specific experience in building and selling uranium company Energy Metals to Uranium One, his knowledge of the capital markets and his proven ability to maximize the value of resource assets for the benefit of all stakeholders will be of great value to Skyharbour going forward.”

About Skyharbour Resources Ltd.:

Skyharbour holds an extensive portfolio of uranium and thorium exploration projects in Canada’s Athabasca Basin and is well positioned to benefit from improving uranium market fundamentals with five drill-ready projects. In July 2016, Skyharbour acquired an option from Denison Mines to acquire 100% of the Moore Lake Uranium Project which is located 20 kilometres east of Denison’s Wheeler River project and 39 kilometres south of Cameco’s McArthur River mine. Moore Lake is an advanced stage uranium exploration property with over $30 million in historical exploration, 370 drill holes, and a high grade zone known as the Maverick Zone with drill results including 4.03% e U₃O₈ over 10 metres at a depth of 265 metres. The Company owns a 100% interest in the Falcon Point (formerly Way Lake) Uranium Project on the eastern perimeter of the Basin which hosts an NI 43-101 inferred resource totaling 7.0 million pounds of U₃O₈ at 0.03% and 5.3 million pounds of ThO₂ at 0.023%. The project also hosts a high grade surface showing with up to 68% U₃O₈ in grab samples from a massive pitchblende vein, the source of which has yet to be discovered. Skyharbour also has a 50% interest in the large, geologically prospective Preston Uranium Project proximal to Fission Uranium’s Triple R deposit as well as NexGen Energy’s Arrow deposit. The Company’s 100% owned Mann Lake Uranium project on the east side of the Basin is strategically located adjacent to the Mann Lake Joint Venture operated by Cameco with partners Denison Mines and AREVA, where high-grade uranium mineralization was recently discovered. Skyharbour’s goal is to maximize shareholder value through new mineral discoveries, committed long-term partnerships, and the advancement of exploration projects in geopolitically favourable jurisdictions.

To find out more about Skyharbour Resources Ltd. (TSX VENTURE:SYH) visit the Company’s website at www.skyharbourltd.com.

SKYHARBOUR RESOURCES LTD.

Jordan Trimble
President and CEO

NEITHER THE TSX VENTURE EXCHANGE NOR ITS REGULATION SERVICES PROVIDER ACCEPTS RESPONSIBILITY FOR THE ADEQUACY OR ACCURACY OF THE CONTENT OF THIS NEWS RELEASE.

This release includes certain statements that may be deemed to be “forward-looking statements”. All statements in this release, other than statements of historical facts, that address events or developments that management of the Company expects, are forward-looking statements. Although management believes the expectations expressed in such forward-looking statements are based on reasonable assumptions, such statements are not guarantees of future performance, and actual results or developments may differ materially from those in the forward-looking statements. The Company undertakes no obligation to update these forward-looking statements if management’s beliefs, estimates or opinions, or other factors, should change. Factors that could cause actual results to differ materially from those in forward-looking statements, include market prices, exploration and development successes, continued availability of capital and financing, and general economic, market or business conditions. Please see the public filings of the Company at www.sedar.com for further information.

TUCSON, AZ–(Marketwired – July 28, 2016) – Liberty Star Uranium & Metals Corp. (“Liberty Star” or the “Company”) (OTCBB: LBSR) (OTC PINK: LBSR) announces payment for all Company Federal lands for 2016-2017. Other State payments are current.

Liberty Star has completed payment on all Bureau of Land Management federal lode-mining claims (unpatented) for its properties located in Arizona. Liberty Star projects are located in Cochise County, Pima County, and, Mohave County:

Located in Cochise County, southeast Arizona, the 42 square mile Tombstone Super Project area of interest includes the Company’s premier property, the Hay Mountain Project (“Hay Mountain”). Hay Mountain is a multi-target, multi-metal, variable depth exploration project for porphyry copper — gold — moly and multiple potential by product metals including lead, zinc, manganese, silver (?), uranium, thorium, and rare earth elements. Surface studies (geochemistry, geophysics, x-ray fluorescence) indicate the potential for discovery of a high grade and large sediment and porphyry hosted copper, gold, and moly ore body of the same type as the nearby Bisbee deposit and other commercially important ore bodies throughout southeast Arizona. Liberty Star plans to engage in exploratory drilling as soon as possible.

The East Silver Bell Porphyry Copper Project (“Silver Bell”) is located in Pima County, northwest of Tucson, Arizona within the Silver Bell Mining District. Asarco Mining operates open-pit mines and a solvent extraction plant (SXEW) about 4 ½ miles west of the Silver Bell property. The Company maintains claims covering a previously unrecognized porphyry copper center. The claims currently are within the Ironwood National Monument, established after the claims were staked.

The exploration-stage North Pipes Super Project is located in Mohave County, northwest Arizona near the Utah border on the Arizona Strip. The US Geological Survey notes the Arizona Strip is rich in uranium bearing breccia pipes. While uranium is the most commercially important metal, the pipes contain numerous other metals including copper, silver, vanadium, molybdenum, cobalt and nickel. Exploration at North Pipes is for high-grade uranium ore bodies that can be mined economically by underground methods. Eleven claims have been retained over what geophysically appears to be a very large or perhaps a triple breccia pipe.

“James A. Briscoe”
James A. Briscoe, Professional Geologist, AZ CA
CEO/Chief Geologist
Liberty Star Uranium & Metals Corp.

RISK FACTORS FOR OUR COMPANY ARE SET OUT IN OUR 10-K AND OTHER PERIODIC FILINGS FILED WITH THE SEC ON EDGAR.

Follow Liberty Star Uranium & Metals Corp. on Agoracom, Facebook, LinkedIn & Twitter@LibertyStarLBSR.

SASKATOON, SASKATCHEWAN–(Marketwired – July 28, 2016) –

ALL AMOUNTS ARE STATED IN CDN $ (UNLESS NOTED)

• Maintaining annual delivery and cost of sales guidance
• Signed an agreement with Kazatomprom to restructure and enhance JV Inkai
• Continued focus on controlling costs amid difficult market conditions

Cameco (TSX:CCO)(NYSE:CCJ) today reported its consolidated financial and operating results for the second quarter ended June 30, 2016 in accordance with International Financial Reporting Standards (IFRS).

“Our quarterly results were again influenced by a quiet market, as well as a number of notable and one-time items,” said president and CEO, Tim Gitzel. “However, our annual sales guidance and cost of sales expectations remain unchanged, our long-term contract portfolio continues to keep our average realized price above market prices, and we remain focused on controlling costs across the organization.

“Market conditions have become increasingly challenging over the past five years. Primary supply has simply not responded to decreased demand, and coupled with an abundance of secondary material available today, the uranium market continues to be oversupplied. As a result, prices have remained under pressure, and because we don’t know how long the current weak conditions will persist, we must manage the company with that uncertainty in mind.

“Despite the current market challenges, we remain confident in nuclear power as an important part of the long-term global energy mix. Based on the reactor construction that is underway around the world today, we continue to expect uranium demand to increase in the long-term.”

SECOND QUARTER

Net losses attributable to equity holders this quarter were $137 million (losses of $0.35 per share diluted) compared to net earnings of $88 million ($0.22 per share diluted) in the second quarter of 2015 due to:

• impairment of our Rabbit Lake operation
• mark-to-market losses on foreign exchange derivatives compared to gains in the second quarter of 2015
• lower gross profit from our uranium and NUKEM segments
• higher administration expenditures

partially offset by:

• higher foreign exchange gains

On an adjusted basis, our losses this quarter were $57 million (losses of $0.14 per share diluted) compared to earnings of $46 million ($0.12 per share diluted) (non-IFRS measure, see below) in the second quarter of 2015. The change was mainly due to:

• lower gross profit from our uranium and NUKEM segments
• higher administration expenditures

partially offset by:

• higher foreign exchange gains

See Financial results by segment below for more detailed discussion.

FIRST SIX MONTHS

Net losses in the first six months of the year were $59 million (losses of $0.15 per share diluted) compared to earnings of $79 million ($0.20 per share diluted) in the first six months of 2015 mainly due to:

• impairment of our Rabbit Lake operation
• lower gross profit from our uranium and NUKEM segments
• higher administration costs
• higher foreign exchange losses

partially offset by:

• higher gross profit from our fuel services segment
• mark-to-market gains on foreign exchange derivatives compared to losses in the first six months of 2015
• higher tax recovery

On an adjusted basis, our losses for the first six months of this year were $64 million (losses of $0.16 per share diluted) compared to earnings of $115 million ($0.29 per share diluted) (non-IFRS measure, see below) for the first six months of 2015. Key variances include:

• lower gross profit from our uranium and NUKEM segments
• higher administration costs
• higher foreign exchange losses

partially offset by:

• higher gross profit from our fuel services segment
• higher tax recovery

ADJUSTED NET EARNINGS (NON-IFRS MEASURE)

Adjusted net earnings is a measure that does not have a standardized meaning or a consistent basis of calculation under IFRS (non-IFRS measure). We use this measure as a more meaningful way to compare our financial performance from period to period. We believe that, in addition to conventional measures prepared in accordance with IFRS, certain investors use this information to evaluate our performance. Adjusted net earnings is our net earnings attributable to equity holders, adjusted to better reflect the underlying financial performance for the reporting period. The adjusted earnings measure reflects the matching of the net benefits of our hedging program with the inflows of foreign currencies in the applicable reporting period, and has also been adjusted for NUKEM purchase price inventory write-downs and recoveries, impairment charges, and income taxes on adjustments.

Adjusted net earnings is non-standard supplemental information and should not be considered in isolation or as a substitute for financial information prepared according to accounting standards. Other companies may calculate this measure differently, so you may not be able to make a direct comparison to similar measures presented by other companies.

The following table reconciles adjusted net earnings with our net earnings.

See Financial results by segment below for more detailed discussion.

Also of note:

IMPAIRMENT

Production was suspended at our Rabbit Lake operation during the second quarter, requiring us to determine the excess carrying value of the mine and mill over the fair value less costs to sell. As a result, we have recognized an impairment charge for the full carrying value of $124.4 million.

CONTRACTING

In July, we agreed to terminate a long-term supply contract with one of our utility customers, which had product deliveries from 2016 through 2021. The resulting gain on contract settlement of $46.7 million will be reflected in our financial results for the third quarter as other income.

Our strategy

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 profitably produce from our tier-one assets at a pace aligned with market signals to increase long-term shareholder value, and to do that with an emphasis on safety, people and the environment.

We believe the best way to create value is to focus our investible capital on maintaining a strong balance sheet and on preserving the production flexibility of our tier-one assets. This approach provides us with the opportunity to meet rising demand with increased production from our best margin assets, and helps to mitigate risk during a prolonged period of uncertainty. In the context of continued depressed market conditions, we have positioned our production to come from our lower-cost operations.

Going forward, we plan to:

• ensure continued safe, reliable, low-cost production from our tier-one assets – McArthur River/Key Lake, Cigar Lake and Inkai
• complete ramp up of production at Cigar Lake
• continue to evaluate the position of the other sources of supply in our portfolio, including Rabbit Lake and the US operations, and retain the flexibility to respond to market signals and take advantage of value adding opportunities, including expanded production capacity at McArthur River/Key Lake and at Inkai
• maintain our low-cost advantage by focusing on execution and operational excellence

You can read more about our strategy in our 2015 annual management’s discussion and analysis (MD&A).

Uranium market update

The second quarter of 2016 continued much the same as the first – with demand remaining low and uranium prices depressed. That is as expected, given that there have been no events to catalyze a change in the current state of the market. In Japan, reactors continue to progress towards restart at a very slow pace, facing further challenges in the form of injunctions from the lower courts. Adding pressure to the market were a number of premature reactor retirement announcements in the United States, as well as the vote by the United Kingdom to leave the European Union, which has increased uncertainty around their new build program.

On the other side of the equation, supply continued to be readily available, with secondary supplies abundant and no interruptions to primary supply.

Making positive news for the industry were two new reactor startups – one in China and one in the United States – bringing the total for the year to five.

Longer term, strong fundamentals underpin a positive outlook for the industry. With 60 reactors under construction today and additional units planned over the next decade, uranium demand is expected to increase as those reactors come online. In addition, as future supply continues to be negatively affected by current depressed market conditions and utilities refrain from contracting replacement volumes, we expect to see a shift from the currently over-supplied market we are experiencing today to a demand-driven market that requires more primary supply. Demand growth combined with the timing, development and execution of new supply projects and the continued performance of existing supply, will determine the pace of that shift.

Caution about forward-looking information relating to our uranium market update

This discussion of our expectations for the nuclear industry, including its growth profile, future global uranium supply and demand 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 below.

Outlook for 2016

Our outlook for 2016 reflects the expenditures necessary to help us achieve our strategy. Our outlook for our consolidated tax rate, and NUKEM’s delivery volumes, revenue and gross profit, has changed. We do not provide an outlook for the items in the table that are marked with a dash.

See 2016 Financial results by segment below for details.

We have increased our uranium production outlook to 25.8 million pounds U₃O₈ (previously 25.7 million pounds) to reflect the final 2016 production from Rabbit Lake following the operational changes made in April. See Uranium 2016 Q2 updates below for more information.

We have decreased our outlook for NUKEM sales volumes to 7 million to 8 million pounds U₃O₈ (previously 9 million to 10 million pounds) due to continued light activity in the market. This change, along with the inventory write-down that we recognized during the second quarter, has also resulted in a change to our outlook for NUKEM’s revenue and gross profit. We now expect NUKEM’s revenue to decrease 5% to 10% (previously increase 5% to 10%) and gross profit to be a maximum of 1% (previously 4% to 5%).

We have adjusted our outlook for the consolidated tax rate to a recovery of 175% to 200% (previously 50% to 55%) due to the changes to our NUKEM outlook noted above, and a change in the distribution of earnings between jurisdictions.

In our uranium and fuel services segments, our customers choose when in the year to receive deliveries, so our quarterly delivery patterns, delivery volumes and revenue can vary significantly. We expect remaining 2016 uranium deliveries to be more heavily weighted to the fourth quarter.

REVENUE AND EARNINGS SENSITIVITY ANALYSIS

For the rest of 2016:

• an increase of $5 (US) per pound in both the Ux spot price ($25.00 (US) per pound on July 25, 2016) and the Ux long-term price indicator ($38.00 (US) per pound on July 25, 2016) would increase revenue by $37 million and net earnings by $29 million. Conversely, a decrease of $5 (US) per pound would decrease revenue by $28 million and net earnings by $21 million.
• a one-cent change in the value of the Canadian dollar versus the US dollar would change adjusted net earnings by $5 million, with a decrease in the value of the Canadian dollar versus the US dollar having a positive impact. Cash flow would change by $1 million, with a decrease in the value of the Canadian dollar versus the US dollar having a negative impact.

TRANSFER PRICING DISPUTES

We have been reporting on our transfer pricing disputes with Canada Revenue Agency (CRA) since 2008, when it originated, and with the Internal Revenue Service (IRS) since the first quarter of 2015. Please see our second quarter MD&A for a discussion of the general nature of transfer pricing disputes and, more specifically, the ongoing disputes we have.

Financial results by segment

SECOND QUARTER

Production volumes this quarter were 30% higher compared to the second quarter of 2015, mainly due to higher production from Cigar Lake, Inkai and Rabbit Lake. See Uranium 2016 Q2 updates below for more information.

The 40% decrease in uranium revenues was a result of a 37% decrease in sales volume and a 4% decrease in the Canadian dollar average realized price. Sales in the second quarter were lower than in 2015 due to the timing of deliveries, which are driven by customer requests and can vary significantly.

The US dollar average realized price decreased by 8% compared to 2015 mainly due to lower prices on market-related contracts, while the lower Canadian dollar realized prices this quarter were a result of that decrease, partially offset by the weakening of the Canadian dollar compared to 2015. This quarter the exchange rate on the average realized price was $1.00 (US) for $1.30 (Cdn) compared to $1.00 (US) for $1.25 (Cdn) in the second quarter of 2015.

Total cost of sales (including D&A) decreased by 27% ($218 million compared to $297 million in 2015) due to a 37% decrease in sales volume, partially offset by a 17% increase in the unit cost of sales. The increase in the unit cost of sales was mainly the result of care and maintenance costs and severance costs related to the curtailment of production at Rabbit Lake and in the US, partially offset by lower production costs related to higher production from Cigar Lake compared to the second quarter of 2015.

The net effect was an $89 million decrease in gross profit for the quarter.

FIRST SIX MONTHS

Production volumes for the first six months of the year were 33% higher than in the previous year due to the addition of production from Cigar Lake and higher production at McArthur/Key Lake, and Inkai, partially offset by lower production at our US operations. See Uranium 2016 Q2 updates below for more information.

Uranium revenues decreased 24% compared to the first six months of 2015 due to a 27% decrease in sales volumes, partially offset by a 3% increase in the Canadian dollar average realized price, in the first six months.

In our uranium and fuel services segments, our customers choose when in the year to receive deliveries, so our quarterly delivery patterns, sales volumes and revenue can vary significantly. We are on track to meet our 2016 uranium sales targets, and, therefore, expect to deliver between 20 million and 22 million pounds in the remainder of the year.

Our Canadian dollar realized prices for the first six months of 2016 were higher than 2015, primarily as a result of the weakening of the Canadian dollar compared to 2015. For the first six months of 2016, the exchange rate on the average realized price was $1.00 (US) for $1.34 (Cdn) compared to $1.00 (US) for $1.23 (Cdn) for the same period in 2015.

Total cost of sales (including D&A) decreased by 18% ($454 million compared to $552 million in 2015) mainly due to a 27% decrease in sales volume for the first six months, partially offset by a 12% increase in the unit cost of sales. The increase in the unit cost of sales was mainly the result of care and maintenance costs and severance costs related to the curtailment of production at Rabbit Lake and in the US.

The net effect was a $92 million decrease in gross profit for the first six months.

The table below shows the costs of produced and purchased uranium incurred in the reporting periods (which are non-IFRS measures, see the paragraphs below the table). These costs do not include care and maintenance costs, selling costs such as royalties, transportation and commissions, nor do they reflect the impact of opening inventories on our reported cost of sales.

The average cash cost of production this quarter was 40% lower than the comparable period in 2015, primarily due to increased low-cost production from Cigar Lake, and the impact of our first quarter production changes at Rabbit Lake.

Although purchased pounds are transacted in US dollars, we account for the purchases in Canadian dollars. In the second quarter, the average cash cost of purchased material in US dollar terms was $29.20 (US) per pound with an average exchange rate of $1.00 (US) for $1.31 (Cdn), compared to $36.48 (US) per pound at an average exchange rate of $1.00 (US) for $1.25 (Cdn) in the second quarter of 2015. For the first six months, the average cash cost of purchased material was $36.18 (US) per pound at an average exchange rate of $1.00 (US) for $1.38 (Cdn), compared to $37.40 per pound at an average exchange rate of 1.00 (US) for $1.25 (Cdn) in the same period in 2015.

Cash cost per pound, non-cash cost per pound and total cost per pound for produced and purchased uranium presented in the above table are non-IFRS measures. These measures do not have a standardized meaning or a consistent basis of calculation under IFRS. We use these measures in our assessment of the performance of our uranium business. We believe that, in addition to conventional measures prepared in accordance with IFRS, certain investors use this information to evaluate our performance and ability to generate cash flow.

These measures are non-standard supplemental information and should not be considered in isolation or as a substitute for measures of performance prepared according to accounting standards. These measures are not necessarily indicative of operating profit or cash flow from operations as determined under IFRS. Other companies may calculate these measures differently, so you may not be able to make a direct comparison to similar measures presented by other companies.

To facilitate a better understanding of these measures, the following table presents a reconciliation of these measures to our unit cost of sales for the second quarter and the first six months of 2016 and 2015.

SECOND QUARTER

Total revenue for the second quarter of 2016 increased to $81 million from $70 million for the same period last year. A 21% increase in sales volumes was partially offset by a 7% decrease in average realized price, primarily due to mix of products sold partially offset by the weakening of the Canadian dollar compared to 2015.

The total cost of products and services sold (including D&A) increased by 24% ($62 million compared to $50 million in the second quarter of 2015) due to the increase in sales volumes, partially offset by a decrease in the average unit cost of sales. When compared to 2015, the average unit cost of sales was 1% lower.

Gross profit remained unchanged at $19 million.

FIRST SIX MONTHS

In the first six months of the year, total revenue increased by 3% due to a 6% increase in realized price that was the result of the weakening of the Canadian dollar and the mix of products sold, partially offset by a 4% decrease in sales volumes.

The total cost of products and services sold (including D&A) decreased 1% ($108 million compared to $109 million in 2015) due to the 4% decrease in sales volume, partially offset by a 3% increase in the average unit cost of sales, which resulted from an increase in the unit opening inventory rate.

The net effect was a $5 million increase in gross profit.

SECOND QUARTER

During the second quarter of 2016, NUKEM delivered 2.4 million pounds of uranium, an increase of 60% from the same period last year due largely to the timing of customer requirements. The majority of the deliveries in the quarter were under existing contracts with utilities. Activity in the spot market continued to be light, as was the case in the first quarter. Total revenues increased by 59% as a result of higher sales volumes.

NUKEM recorded a gross loss of $10 million in the second quarter of 2016, compared to an $11 million gross profit in the second quarter of 2015. Included in the 2016 gross loss is a $14 million net write-down of inventory. The write-down was a result of a decline in the spot price during the period.

FIRST SIX MONTHS

During the six months ended June 30, 2016, NUKEM delivered 2.4 million pounds of uranium, a decrease of 40%, due to very light market activity with a lack of profitable opportunities, and the timing of customer requirements. Total revenues decreased 26% due to a decrease in sales volumes, partially offset by a 22% increase in average realized price. The increase in realized price was mainly the result of deliveries under contracts negotiated in prior years when market prices were higher.

Gross profit percentage was a loss of 8% for the first six months of 2016, a decrease from a profit of 12% in the same period in 2015. Included in the 2015 margin was a $3 million recovery compared to a $14 million net write-down of inventory in 2016. The write-down in 2016 was a result of a decline in the spot price during the period.

The net effect was a $32 million decrease in gross profit.

Uranium 2016 Q2 updates

MCARTHUR RIVER/KEY LAKE

Production for the second quarter was 3% lower compared to the same period last year due to a longer mill maintenance shut down. Production for the first six months was slightly higher than last year when unplanned mill maintenance affected our first quarter production.

A new calciner has been installed at the Key Lake mill to accommodate an annual production increase to 25 million pounds when the market signals that more production is needed. However, reliability issues have been encountered with the new equipment during commissioning. Since market conditions do not currently support increased production at McArthur River/Key Lake, and as part of our continuing efforts to reduce costs, we have suspended the commissioning of and transition to the new calciner. We are assessing the cost to resolve the issues and expect to complete commissioning at a time when we see the need for the new calcining capacity. The existing calciner has sufficient capacity to meet our 2016 production target of 18 million pounds (12.6 million pounds our share).

CIGAR LAKE

Total packaged production from Cigar Lake was 67% higher in the second quarter, and 169% higher in the first six months compared to the same periods last year. The increases are related to the scheduled rampup of the operation. We are on track to achieve our target of 16 million pounds of production (8 million pounds our share) in 2016, and full production of 18 million pounds (9 million pounds our share) in 2017.

In the second quarter, AREVA’s application to increase the capacity of the McClean Lake mill from 13 million to 24 million pounds of annual production was approved by the Canadian Nuclear Safety Commission.

The unionized employees at AREVA’s McClean Lake mill accepted a new three-year collective agreement during the second quarter. The previous contract expired in May, 2016.

INKAI

Production was 83% higher for the quarter and 83% higher for the first six months compared to the same periods last year, due to the timing of new wellfield development in our 2016 mine plan. The operation remains on track to achieve our planned 2016 production.

As previously disclosed, we also signed an agreement with our partner Kazatomprom and JV Inkai to restructure and enhance JV Inkai. Please see our second quarter MD&A for more information.

RABBIT LAKE

Given the continued depressed market conditions in the near term, we suspended production at our Rabbit Lake operation during the second quarter. Production was 250% higher than the same period last year due to the timing of maintenance in 2015. Production for the first six months was 1.1 million pounds, unchanged from the comparable period in 2015. The facilities are now in care and maintenance.

We expect to complete the transition of the Rabbit Lake operation to care and maintenance by the end of August, at a cost of about $45 million. We then expect the cost to maintain the site in a safe care and maintenance state for the remainder of the year to be about $15 million. We previously estimated the total cost of transition and care and maintenance activities to be about $35 million in 2016. However, due to an accelerated start for transition of the mill to care and maintenance, and the timing of workforce reductions, additional costs were incurred and categorized as care and maintenance costs. Previously, we expected some of those costs to be categorized as operating or capital costs.

As long as production is suspended, we expect care and maintenance costs to range between $40 million and $45 million annually for the first few years. A workforce of 120 is remaining on site (down from 650) to maintain the facilities and sustain environmental monitoring and reclamation activities. The related severance cost of $11.8 million is included in our cost of sales and reflected in our results.

Qualified persons

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

MCARTHUR RIVER/KEY LAKE

• David Bronkhorst, vice-president, mining and technology, Cameco

CIGAR LAKE

• Les Yesnik, general manager, Cigar Lake, Cameco

INKAI

• Darryl Clark, general director, JV Inkai

Caution about forward-looking information

This document includes statements and information about our expectations for the future. When we discuss our strategy, plans, 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 United States securities laws. We refer to them in this document as forward-looking information.

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

• It typically includes words and phrases about the future, such as: anticipate, believe, estimate, expect, plan, will, intend, goal, target, forecast, project, strategy and outlook (see examples below).
• It represents our current views, and can change significantly.
• 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, due to the risks associated with our business. We list a number of these material risks beginning below. We recommend you also review our annual information form, first quarter and second quarter MD&A, and annual MD&A, which includes a discussion of other material risks that could cause actual results to differ significantly from our current expectations.
• Forward-looking information is designed to help you understand management’s current views of our near and longer term prospects, and it may not be appropriate for other purposes. We will not necessarily update this information unless we are required to by securities laws.

Examples of forward-looking information in this document

• the discussion under the heading Our strategy
• our expectations about 2016 and future global uranium supply and demand including the discussion under the heading Uranium market update
• our consolidated outlook for the year and the outlook for our uranium, fuel services and NUKEM segments for 2016
• our expectations for uranium deliveries for the balance of 2016
• our expectations for 2016 capital expenditures
• our future plans and expectations for each of our uranium operating properties
• our expectations related to the suspension of production at Rabbit Lake and transitioning the operation to care and maintenance

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 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
• 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
• we cannot obtain or maintain necessary permits or approvals from government authorities
• 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 fulfil delivery commitments
• our expectations relating to suspending Rabbit Lake production and transitioning the operation to care and maintenance prove to be inaccurate
• 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, including as a result of any difficulties freezing the deposit to meet production targets, or any difficulties with the McClean Lake mill modifications or expansion or milling of Cigar Lake ore
• 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, or other development and operating risks

Material assumptions

• our expectations regarding sales and purchase volumes and prices for uranium and fuel services
• our expectations regarding the demand for uranium, 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 level and production costs
• the assumptions regarding market conditions 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 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, and the deposit freezes as planned
• modification and expansion of the McClean Lake mill are completed as planned and the mill is able to process Cigar Lake ore as expected
• that we will be able to implement the transition of the Rabbit Lake operation to care and maintenance within the time line and at the costs anticipated
• our ability to continue to supply our products and services in the expected quantities and at the expected times
• our ability to comply with current and future environmental, safety and other regulatory requirements, and to obtain and maintain required regulatory approvals
• our operations are not significantly disrupted as a result of political instability, nationalization, terrorism, sabotage, blockades, civil unrest, breakdown, natural disasters, governmental or political actions, litigation or arbitration proceedings, the unavailability of reagents, equipment, operating parts and supplies critical to production, labour shortages, labour relations issues, strikes or lockouts, underground floods, cave-ins, ground movements, tailings dam failure, lack of tailings capacity, transportation disruptions or accidents or other development or operating risks

Quarterly dividend notice

We announced today that our board of directors approved a quarterly dividend of $0.10 per share on the outstanding common shares of the corporation that is payable on October 14, 2016, to shareholders of record at the close of business on September 30, 2016.

Conference call

We invite you to join our second quarter conference call on Thursday, July 28, 2016 at 1:00 p.m. Eastern.

The call will be open to all investors and the media. To join the call, please dial (800) 769-8320 (Canada and US) or (416) 340-8530. An operator will put your call through. The slides and a live webcast of the conference call will be available from a link at cameco.com. See the link on our home page on the day of the call.

A recorded version of the proceedings will be available:

• on our website, cameco.com, shortly after the call
• on post view until midnight, Eastern, August 28, 2016, by calling (800) 408-3053 (Canada and US) or (905) 694-9451 (Passcode 6067397)

Additional information

You can find a copy of our second quarter MD&A and interim financial statements on our website at www.cameco.com, on SEDAR at sedar.com and on EDGAR at www.sec.gov/edgar.shtml.

Additional information, including our 2015 annual management’s discussion and analysis, annual audited financial statements and annual information form, is available on SEDAR at sedar.com, on EDGAR at www.sec.gov/edgar.shtml and on our website at cameco.com.

Profile

We are one of the world’s largest uranium producers, a significant supplier of conversion services and one of two CANDU fuel manufacturers in Canada. Our competitive position is based on our controlling ownership of the world’s largest high-grade reserves and low-cost operations. Our uranium products are used to generate clean electricity in nuclear power plants around the world. We also explore for uranium in the Americas, Australia and Asia. Our shares trade on the Toronto and New York stock exchanges. Our head office is in Saskatoon, Saskatchewan.

As used in this news release, the terms we, us, our, the Company and Cameco mean Cameco Corporation and its subsidiaries; including NUKEM Energy GmbH, unless otherwise indicated.