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The Alberta Gazette
Part I
Vol. 111	Edmonton, Monday, June 15, 2015	No. 11
PROCLAMATION
[GREAT SEAL] 
CANADA 
PROVINCE OF ALBERTA	Donald S. Ethell, Lieutenant Governor.
ELIZABETH THE SECOND, by the Grace of God, of the United Kingdom, 
Canada, and Her Other Realms and Territories, QUEEN, Head of the 
Commonwealth, Defender of the Faith
P R O C L A M A T I O N
To all to Whom these Presents shall come
G R E E T I N G
Kim Armstrong, 
Deputy Attorney General
WHEREAS 188 of the Chartered Professional Accountants Act provides that that 
Act, except section 168, comes into force on Proclamation; and
WHEREAS it is expedient to proclaim the Chartered Professional Accountants Act, 
except section 168, in force:
NOW KNOW YE THAT by and with the advice and consent of Our Executive 
Council of Our Province of Alberta, by virtue of the provisions of the said Act 
hereinbefore referred to and of all other power and authority whatsoever in Us vested 
in that behalf, We have ordered and declared and do hereby proclaim the Chartered 
Professional Accountants Act, except section 168, in force on July 1, 2015.
IN TESTIMONY WHEREOF We have caused these Our Letters to be made Patent 
and the Great Seal of Our Province of Alberta to be hereunto affixed.
WITNESS: COLONEL (RETIRED) THE HONOURABLE DONALD S. 
ETHELL, Lieutenant Governor of Our Province of Alberta, this 28th day of May in 
the Year of Our Lord Two Thousand Fifteen and in the Sixty-fourth Year of Our 
Reign.
BY COMMAND	Kathleen Ganley, Provincial Secretary.


APPOINTMENTS
Appointment of Non-presiding Justices of the Peace
(Justice of the Peace Act)
April 24, 2015 
Anderson, Gereen Joyce of Edmonton 
Anderson, Shaun Cody of Calgary
Dziedzic, Candyce Tanya of Edmonton
Geba, Vendula of Calgary
Ogle, William Kevin of Calgary 
Urton, Samantha Rae of Lethbridge
Vermesan, Teodora of Calgary
RESIGNATIONS & RETIREMENTS
Retirement of Supernumerary Provincial Court Judge
(Provincial Court Act)
May 25, 2015 
Honourable Judge Lawrence Stuart Witten
GOVERNMENT NOTICES
Agriculture and Forestry
Form 15
(Irrigation Districts Act) 
(Section 88)
Notice to Irrigation Secretariat: 
Change of Area of an Irrigation District
On behalf of the Bow River Irrigation District, I hereby request that the Irrigation 
Secretariat forward a certified copy of this notice to the Registrar of Land Titles for 
the purposes of registration under section 22 of the Land Titles Act and arrange for 
notice to be published in the Alberta Gazette.
The following parcels of land should be added to the irrigation district and a notation 
added to the certificate of title:
LINC Number
Short Legal Description as shown on title
Title Number
0022 436 992
N.W. 21-12-16-W4M
081 125 343 + I
0022 437 008
N .E. 2 1-12-16-W4M
081 125 343
0013 223 748
S.W. 28-12-16-W4M
101 351 125
I certify the procedures required under part 4 of the Irrigation Districts Act have been 
completed and the area of the Bow River Irrigation District should be changed 
according to the above list.
Rebecca Fast, Office Administrator, 
Irrigation Secretariat.
______________
On behalf of the St. Mary River Irrigation District, I hereby request that the 
Irrigation Secretariat forward a certified copy of this notice to the Registrar of Land 
Titles for the purposes of registration under section 22 of the Land Titles Act and 
arrange for notice to be published in the Alberta Gazette.
The following parcels of land should be added to the irrigation district and a notation 
added to the certificate of title:
LINC Number
Short Legal Description as shown on title
Title Number
0022 325 600
4;18;9;18;SW
151 001 456
0029 242 716
4;19;10;15;NE
111 288 648 + 3
0029 242 799
4;19;10;15;NW
111 288 648 + 4
0029 244 498
4;19;10;15;SE
111 288 648 + 5
I certify the procedures required under part 4 of the Irrigation Districts Act have been 
completed and the area of the St. Mary River Irrigation District should be changed 
according to the above list.
Rebecca Fast, Office Administrator, 
Irrigation Secretariat.
Culture and Tourism
Ministerial Order
(Historical Resources Act)
03/15
I, Maureen Kubinec, Minister of Culture and Tourism, pursuant to Section 20(15) of 
the Historical Resources Act, R.S.A. 2000 C. H-9, HEREBY RESCIND that portion 
of the Magrath Canal Provincial Historic Resource designation dated May 14, 1987, 
registered in Alberta Land Titles as instrument 871 088 444, with respect to the lands 
legally described as Plan 9811633, Block 40, Lot 3.
Dated at Edmonton, Alberta, this 1st day of April, 2015.
Maureen Kubinec, Minister of Culture and Tourism
Energy
Declaration of Withdrawal from Unit Agreement
(Petroleum and Natural Gas Tenure Regulations)
The Minister of Energy on behalf of the Crown in Right of Alberta hereby declares 
and states that the Crown in right of Alberta has withdrawn as a party to the 
agreement entitled "Crossfield Wabamun Agreement #1" effective 
December 31, 2010.
Donna Crawford, for Minister of Energy.
Human Services
Office of the Public Trustee
Property being held by the Public Trustee for a period of Ten (10) Years 
(Public Trustee Act)
Section 11 (2)(b)
Name of Person Entitled 
to Property

Description 
of Property  
held and its 
value or 
estimated value

Property part of 
deceased person's  
Estate or held under 
Court Order: 
Deceased's Name 
Judicial District Court 
File Number

Public Trustee 
Office 
 
Additional 
Information 

Missing Beneficiaries of 
George Dick
$94,160.70
George Dick
Beneficiaries 
possible 
located in 
Europe 
OPGT file# 
047,037
Missing Beneficiaries of 
Joseph Jakobovics
$479.78
Joseph Jakobovics 
JD of Lethbridge 
Unknown
OPGT file# 
047,280
Flossie Helen Geno
$779.17
Charles Alexander 
MacAuley 
JD of Edmonton 
37727
OPT file# 
050,211

Legislative Assembly
Office of the Chief Electoral Officer
Notice: Members Elected to Serve in the Legislative Assembly of Alberta
Edmonton, June 5, 2015
Notice is hereby given, under the provisions of the Election Act, that I have received 
the Certificate and Return from the 87 Provincial Returning Officers appointed to 
conduct a Provincial General Election on the 5th day of May, 2015 in the following 
electoral divisions, and the said Returns show that the following Members were duly 
elected:
Electoral Division	Member Elected
Dunvegan-Central Peace-Notley	Margaret McCuaig-Boyd
Lesser Slave Lake	Danielle Larivee
Calgary-Acadia	Brandy Payne
Calgary-Bow	Deborah Drever
Calgary-Buffalo	Kathleen Ganley
Calgary-Cross	Ricardo Miranda
Calgary-Currie	Brian Malkinson
Calgary-East	Robyn Luff
Calgary-Elbow	Greg Clark
Calgary-Fish Creek	Richard Gotfried
Calgary-Foothills	Jim Prentice * disclaimed
Calgary-Fort	Joe Ceci
Calgary-Glenmore	Anam Kazim
Calgary-Greenway	Manmeet Bhullar
Calgary-Hawkwood	Michael Connolly
Calgary-Hays	Ric McIver
Calgary-Klein	Craig Coolahan
Calgary-Lougheed	Dave Rodney
Calgary-Mackay-Nose Hill	Karen McPherson
Calgary-McCall	Irfan Sabir
Calgary-Mountain View	David Swann
Calgary-North West	Sandra Jansen
Calgary-Northern Hills	Jamie Kleinsteuber
Calgary-Shaw	Graham D. Sucha
Calgary-South East	Rick Fraser
Calgary-Varsity	Stephanie McLean
Calgary-West	Mike Ellis
Edmonton-Beverly-Clareview	Deron Bilous
Edmonton-Calder	David Eggen
Edmonton-Castle Downs	Nicole Goehring
Edmonton-Centre	David Shepherd
Edmonton-Decore	Chris Nielsen
Edmonton-Ellerslie	Rod Loyola
Edmonton-Glenora	Sarah Hoffman
Edmonton-Gold Bar	Marlin Schmidt
Edmonton-Highlands-Norwood	Brian Mason
Edmonton-Manning	Heather Sweet
Edmonton-McClung	Lorne Dach
Edmonton-Meadowlark	Jon Carson
Edmonton-Mill Creek	Denise Woollard
Edmonton-Mill Woods	Christina Gray
Edmonton-Riverview	Lori Sigurdson
Edmonton-Rutherford	Richard Feehan
Edmonton-South West	Thomas Dang
Edmonton-Strathcona	Rachel Notley
Edmonton-Whitemud	Bob Turner
Airdrie	Angela Pitt
Athabasca-Sturgeon-Redwater	Colin Piquette
Banff-Cochrane	Cameron Westhead
Barrhead-Morinville-Westlock	Glenn Van Dijken
Battle River-Wainwright	Wes Taylor
Bonnyville-Cold Lake	Scott Cyr
Cardston-Taber-Warner	Grant Hunter
Chestermere-Rocky View	Leela Sharon Aheer
Cypress-Medicine Hat	Drew Barnes 
Drayton Valley-Devon	Mark Smith
Drumheller-Stettler	Rick Strankman
Fort McMurray-Conklin	Brian Michael Jean
Fort McMurray-Wood Buffalo	Tany Yao
Fort Saskatchewan-Vegreville	Jessica Littlewood
Grande Prairie-Smoky	Todd Loewen
Grande Prairie-Wapiti	Wayne Drysdale
Highwood	Wayne Anderson
Innisfail-Sylvan Lake	Don MacIntyre
Lac La Biche-St. Paul-Two Hills	David B. Hanson
Lacombe-Ponoka	Ron J.N. Orr
Leduc-Beaumont	Shaye Anderson
Lethbridge-East	Maria Fitzpatrick
Lethbridge-West	Shannon Phillips
Little Bow	David A. Schneider
Livingstone-Macleod	Pat Stier
Medicine Hat	Robert Wanner
Olds-Didsbury-Three Hills	Nathan M. Cooper
Peace River	Debbie Jabbour
Red Deer-North	Kim Schreiner
Red Deer-South	Barb Miller
Rimbey-Rocky Mountain House-Sundre	Jason Nixon 
Sherwood Park	Annie McKitrick
Spruce Grove-St. Albert	Trevor Horne
St. Albert	Marie Renaud
Stony Plain	Erin Babcock
Strathcona-Sherwood Park	Estefania Cortes-Vargas
Strathmore-Brooks	Derek Gerhard Fildebrandt
Vermilion-Lloydminster	Richard Starke
West Yellowhead	Eric Rosendahl
Wetaskiwin-Camrose	Bruce Hinkley
Whitecourt-Ste. Anne	Oneil Carlier
Glen Resler, Chief Electoral Officer.
Safety Codes Council
Corporate Accreditation 
(Safety Codes Act)
Pursuant to section 28 of the Safety Codes Act it is hereby ordered that
Seven Generations Ltd, Accreditation No. C000881, Order No. 2944
Having satisfied the terms and conditions of the Safety Codes Council is authorized to 
administer the Safety Codes Act including applicable Alberta amendments and 
regulations within the Corporation's industrial facilities for the discipline of 
Electrical
Consisting of all parts of the Canadian Electrical Code, Code for Electrical 
Installations at Oil & Gas Facilities and Alberta Electrical Utility Code.
Accredited Date: May 25, 2015	Issued Date: May 25, 2015.
Municipal Accreditation
(Safety Codes Act)
Pursuant to Section 26 of the Safety Codes Act it is hereby ordered that
Town of Taber, Accreditation No. M000118, Order No. 0474
Having satisfied the terms and conditions of the Safety Codes Council is authorized to 
administer the Safety Codes Act including applicable Alberta amendments and 
regulations within the Municipality's boundaries for the discipline of Fire
Consisting of all parts of the Alberta Fire Code including investigations.  Excluding 
any or all things, processes or activities located on all existing and future industrial 
facilities that are owned by or are under the care and control of an accredited 
corporation.
Accredited Date: December 5, 2002	Issued Date: May 28, 2015.
Alberta Securities Commission
AMENDMENTS TO NATIONAL INSTRUMENT 41-101  
GENERAL PROSPECTUS REQUIREMENTS
(Securities Act)
Made as a rule by the Alberta Securities Commission on March 11, 2015 pursuant to 
sections 223 and 224 of the Securities Act.
Amendments to National Instrument 41-101 
GENERAL PROSPECTUS REQUIREMENTS
1.	National Instrument 41-101 General Prospectus Requirements is amended 
by this Instrument.
2.	Section 1.1 is amended by adding the following definition:
"Form 51-102F6V" means Form 51-102F6V Statement of Executive 
Compensation - Venture Issuers of NI 51-102;.
3.	Subsection 1.9(4) of Form 41-101F1 is amended by adding "(" after "the 
United States of America" and by adding ")" after "PLUS Markets Group 
plc.".
4.	Subsections 5.1(2) and (3) of Form 41-101F1 are amended by adding ", if the 
issuer is a venture issuer or an IPO venture issuer, the two most recently 
completed financial years, or" after "within the three most recently completed 
financial years or".
5.	The heading of section 5.2 of Form 41-101F1 is amended by replacing 
"Three-year history" with "History".
6.	Subsection 5.2(1) of Form 41-101F1 is amended by adding  "or, if the issuer 
is a venture issuer or an IPO venture issuer, the last two completed financial 
years," after "over the last three completed financial years".
7.	Section 8.2 of Form 41-101F1 is amended by adding the following guidance 
after subsection (3): 
GUIDANCE
Under section 2.2.1 of Form 51-102F1, for financial years beginning on or 
after July 1, 2015, venture issuers, or IPO venture issuers, have the option of 
meeting the requirement to provide interim MD&A under section 2.2 of Form 
51-102F1 by providing quarterly highlights disclosure..
8.	Paragraph 8.6(3)(b) of Form 41-101F1 is amended by adding "if the issuer is 
not providing disclosure in accordance with section 2.2.1 of Form 51-102F1," 
before "the most recent year-to-date".
9.	Paragraph 8.8(2)(b) of Form 41-101F1 is amended by adding "if the issuer is 
not providing disclosure in accordance with section 2.2.1 of Form 51-102F1," 
before "the most recent year-to-date".
10.	Section 17.1 of Form 41-101F1 is amended by adding "or, if the issuer is a 
venture issuer or an IPO venture issuer, in accordance with Form 51-102F6 or 
Form 51-102F6V" after "in accordance with Form 51-102F6".
11.	Section 20.11 of Form 41-101F1 is amended by adding ")" after "the United 
States of America" and adding ")" after "PLUS Markets Group plc.".
12.	Subsection 32.4(1) of Form 41-101F1 is amended by replacing paragraph (a) 
with the following: 
(a)	the statement of comprehensive income, the statement of changes in 
equity, and the statement of cash flows for the third most recently 
completed financial year, if the issuer is
(i)  an IPO venture issuer, or
(ii) a reporting issuer in at least one jurisdiction immediately before 
filing the prospectus,.
13.	This Instrument comes into force on June 30, 2015.
Alberta Securities Commission
AMENDMENTS TO NATIONAL INSTRUMENT 51-101  
Standards of Disclosure for Oil and Gas Activities
(Securities Act)
Made as a rule by the Alberta Securities Commission on November 12, 2014 pursuant 
to sections 223 and 224 of the Securities Act.
Amendments to National Instrument 51-101 
Standards of Disclosure for Oil and Gas Activities 
1.	National Instrument 51-101 Standards of Disclosure for Oil and Gas 
Activities is amended by this Instrument.
2.	Section 1.1 is amended by 
(a)	deleting the paragraph numbering scheme,
(b)	adding the following definitions:
"abandonment and reclamation costs" means all costs associated with 
the process of restoring a reporting issuer's property that has been 
disturbed by oil and gas activities to a standard imposed by applicable 
government or regulatory authorities;
"alternate reference point" means a location at which quantities and 
values of a product type are measured before the first point of sale;
"bitumen" means a naturally occurring solid or semi-solid hydrocarbon
(a)	consisting mainly of heavier hydrocarbons, with a viscosity 
greater than 10,000 millipascal-seconds (mPa*s) or 10,000 
centipoise (cP) measured at the hydrocarbon's original 
temperature in the reservoir and at atmospheric pressure on 
a gas-free basis, and
(b)	that is not primarily recoverable at economic rates through 
a well without the implementation of enhanced recovery 
methods;
"by-product" means a substance that is recovered as a consequence of 
producing a product type;
"coal bed methane" means natural gas that  
(a)	primarily consists of methane, and
(b)	is contained in a coal deposit;,
(c)	replacing the definition of "COGE Handbook" with the following:
"COGE Handbook" means the "Canadian Oil and Gas Evaluation 
Handbook" maintained by the Society of Petroleum Evaluation 
Engineers (Calgary Chapter), as amended from time to time;,
(d)	adding the following definitions:
"contingent resources data" means
(a)	an estimate of the volume of contingent resources, and
(b)	the risked net present value of future net revenue of 
contingent resources; 
"conventional natural gas" means natural gas that has been generated 
elsewhere and has migrated as a result of hydrodynamic forces and is 
trapped in discrete accumulations by seals that may be formed by 
localized structural, depositional or erosional geological features;
"first point of sale" means the first point after initial production at which 
there is a transfer of ownership of a product type;
"Form 51-101F5" means Form 51-101F5 Notice of Ceasing to Engage 
in Oil and Gas Activities;
"future net revenue" means a forecast of revenue, estimated using 
forecast prices and costs or constant prices and costs, arising from the 
anticipated development and production of resources, net of the 
associated royalties, operating costs, development costs, and 
abandonment and reclamation costs;
"gas hydrate" means a naturally occurring crystalline substance 
composed of water and gas in an ice-lattice structure;
"heavy crude oil" means crude oil with a relative density greater than 10 
degrees API gravity and less than or equal to 22.3 degrees API gravity;
"hydrocarbon" means a compound consisting of hydrogen and carbon, 
which, when  naturally occurring, may also contain other elements such 
as sulphur;
"light crude oil" means crude oil with a relative density greater than 
31.1 degrees API gravity;
"medium crude oil" means crude oil with a relative density greater than 
22.3 degrees API gravity and less than or equal to 31.1 degrees API 
gravity;
"natural gas" means a naturally occurring mixture of hydrocarbon gases 
and other gases; 
"natural gas liquids" means those hydrocarbon components that can be 
recovered from natural gas as a liquid including, but not limited to, 
ethane, propane, butanes, pentanes plus, and condensates;,
(e)	replacing the definition of "oil and gas activities" with the following:
"oil and gas activities" includes the following:
(a)	searching for a product type in its natural location;
(b)	acquiring property rights or a property for the purpose of 
exploring for or removing product types from their natural 
locations; 
(c)	any activity necessary to remove product types from their 
natural locations, including construction, drilling, mining 
and production, and the acquisition, construction, 
installation and maintenance of field gathering and storage 
systems including treating, field processing and field 
storage;
(d)	producing or manufacturing of synthetic crude oil or 
synthetic gas; 
but does not include any of the following:
(e)	any activity that occurs after the first point of sale;
(f)	any activity relating to the extraction of a substance other 
than a product type and their by-products;
(g)	extracting hydrocarbons as a consequence of the extraction 
of geothermal steam;,
(f)	adding the following definition:
"oil and gas metric" means a numerical measure of a reporting issuer's 
oil and gas activities;,
(g)	repealing of the definition of "production group",
(h)	replacing the definition of "product type" with the following:
"product type" means any of the following:
(a)	bitumen;
(b)	coal bed methane;
(c)	conventional natural gas;
(d)	gas hydrates; 
(e)	heavy crude oil;
(f)	light crude oil and medium crude oil combined;
(g)	natural gas liquids; 
(h)	shale gas; 
(i)	synthetic crude oil; 
(j)	synthetic gas; 
(k)	tight oil;,
(i)	in the definition of "professional organization" replacing  "Canadian 
jurisdiction" with "jurisdiction of Canada",
(j)	adding the following definition:
"prospective resources data" means 
(a)	an estimate of the volume of prospective resources, and
(b)	the risked net present value of future net revenue of 
prospective resources;,
(k)	in the definition of "reserves data" replacing  "; and" with ";",
(l)	adding the following definitions:
"risked" means adjusted for the probability of loss or failure in 
accordance with the COGE Handbook;
"shale gas" means natural gas
(a)	contained in dense organic-rich rocks, including low-
permeability shales, siltstones and carbonates, in which the 
natural gas is primarily adsorbed on the kerogen or clay 
minerals, and 
(b)	that usually requires the use of hydraulic fracturing to 
achieve economic production rates;,
(m)	in the definition of "supporting filing" by replacing "." with ";", and
(n)	adding the following definitions:
"synthetic crude oil" means a mixture of liquid hydrocarbons derived by 
upgrading bitumen, kerogen or other substances such as coal, or derived 
from gas to liquid conversion and may contain sulphur or other 
compounds;
"synthetic gas" means a gaseous fluid
(a)	generated as a result of the application of an in-situ 
transformation process to coal or other hydrocarbon-
bearing rock; and
(b)	comprised of not less than 10% by volume of methane;
"tight oil" means crude oil 
(a)	contained in dense organic-rich rocks, including low-
permeability shales, siltstones and carbonates, in which the 
crude oil is primarily contained in microscopic pore spaces 
that are poorly connected to one another, and
(b)	that typically requires the use of hydraulic fracturing to 
achieve economic production rates..
3.	Paragraph (b) of item 2 of section 2.1 is replaced with the following:
(b)	executed by one or more qualified reserves evaluators or auditors 
each of whom is independent of the reporting issuer and who 
must have,
(i)	in the aggregate, 
(A)	evaluated or audited at least 75 percent of the future 
net revenue, calculated using a discount rate of 10 
percent, attributable to proved plus probable 
reserves, as reported in the statement filed or to be 
filed under item 1, and
(B)	reviewed the balance of that future net revenue, and
(ii)	evaluated or audited the contingent resources data or 
prospective resources data reported in the statement filed 
or to be filed under item 1..
4.	Paragraph (B) of item 3(e)(ii) of section 2.1 is replaced with the following:
(B)	if the reporting issuer has only three directors, two of whom are 
the persons referred to in subparagraph (i), all of the directors of 
the reporting issuer..
5.	Subsection 2.4(1) is amended by
(a)	deleting "on reserves data",
(b)	inserting "on reserves data, contingent resources data or prospective 
resources data" after "without reservation", and
(c)	inserting ", contingent resources data, or prospective resources data" 
after "on the reserves data".
6.	Section 3.2 is replaced with the following:
3.2	Reporting Issuer to Appoint Independent Qualified Reserves 
Evaluator or Independent Qualified Reserves Auditor
(1)	A reporting issuer must appoint one or more qualified reserves 
evaluators, or qualified reserves auditors, each of whom is 
independent of the reporting issuer, and must direct each 
appointed evaluator or auditor to report to the board of directors 
of the reporting issuer on the reserves data disclosed in the 
statement prepared for the purpose of item 1 of section  2.1.
(2)	If a reporting issuer discloses contingent resources data or 
prospective resources data in a statement prepared for the 
purpose of item 1 of section 2.1, the reporting issuer must appoint 
one or more qualified reserves evaluators or qualified reserves 
auditors and must direct each appointed evaluator or auditor to 
report to the board of directors of the reporting issuer on all 
contingent resources data and prospective resources data 
included in the statement..
7.	Section 3.4 is amended by adding ", contingent resources data or prospective 
resources data" after each instance of "reserves data".
8.	Section 5.2 is amended by renumbering it as subsection 5.2(1) and by adding 
the following subsection:
(2)	Disclosure referred to under subsection (1) must indicate whether 
the estimates of reserves or future net revenue were prepared by 
an independent qualified reserves evaluator or qualified reserves 
auditor.. 
9.	Section 5.3 is amended by replacing "categories" with "category".
10.	Section 5.4 is replaced with the following:
5.4	Oil and Gas Resources and Sales
(1)	Disclosure of resources or of sales of product types or associated 
by-products must be made with respect to the first point of sale.
(2)	Despite subsection (1), a reporting issuer may disclose resources 
or sales of product types or associated by-products with respect to 
an alternate reference point if, to a reasonable person, the 
resources, product types or associated by-products would be 
marketable at the alternate reference point.
(3)	If a reporting issuer discloses resources or sales of product types 
or associated by-products with respect to an alternate reference 
point, the reporting issuer must
(a)	state that the disclosure is made with respect to an alternate 
reference point,
(b)	disclose the location of the alternate reference point, and
(c)	explain why disclosure is not being made with respect to 
the first point of sale..
11.	Section 5.5 is replaced with the following:
5.5	Recovery of Product Types or By-Products - Disclosure of product 
types or by-products, including natural gas liquids and sulphur must be 
made in respect only of volumes that have been or are to be recovered 
prior to the first point of sale, or an alternate reference point, as 
applicable..
12.	Section 5.7 is repealed.
13.	Section 5.9 is amended by
(a)	in paragraph (2)(d), adding the following:
(iii.1) a description of the applicable project or projects including 
the following:
(A) the estimated total cost required to achieve 
commercial production;
(B) the general timeline of the project, including the 
estimated date of first commercial production;
(C) the recovery technology; 
(D) whether the project is based on a conceptual or 
pre-development study;, 
(b)	in clause (2)(d)(v)(A) replacing "no certainty" with "uncertainty",
(c)	in subsection (3), replacing "(2)(c)(iii)" with "(2)(d)(iii), (iii.1)", and 
(d)	adding the following:
(4)	Any disclosure made under subsection (1) or (2) must indicate 
whether the anticipated results from resources which are not 
currently classified as reserves or the estimate of a quantity of 
resources other than reserves were prepared by an independent 
qualified reserves evaluator or auditor..
14.	Sections 5.11, 5.12 and 5.13 are repealed.
15.	Section 5.14 is replaced with the following:
5.14   Disclosure Using Oil and Gas Metrics
(1)	If a reporting issuer discloses an oil and gas metric, other than an 
estimate of the volume or value of resources prepared in 
accordance with section 5.2, 5.9 or 5.18 or a comparative or 
equivalency measure under Part 2, 3, 4, 5, 6 or 7 of Form 51-
101F1, the reporting issuer must include disclosure that
(a)	identifies the standard and source of the oil and gas metric, 
if any,
(b)	provides a brief description of the method used to 
determine the oil and gas metric,
(c)	provides an explanation of the meaning of the oil and gas 
metric, and
(d)	cautions readers as to the reliability of the oil and gas 
metric. 
(2)	If there is no identifiable standard for an oil and gas metric, the 
reporting issuer must also include disclosure that
(a)	provides a brief description of the parameters used in the 
calculation of the oil and gas metric, and
(b)	states that the oil and gas metric does not have any 
standardized meaning and should not be used to make 
comparisons..
16.	Section 5.15 is repealed.
17.	Paragraph 5.16(3)(b) is amended by replacing "5.9(2)(c)(v)(A)" with 
"5.9(2)(d)(v)(A)" and by replacing "5.9(2)(c)(v)(B)" with "5.9(2)(d)(v)(B)".
18.	Part 5 is amended by adding the following:
5.18  Supplementary Disclosure of Resources Using Evaluation Standards 
other than the COGE Handbook
(1)	A reporting issuer may supplement disclosure provided in accordance 
with section 5.2, 5.3 or 5.9 with an estimate of the volume or the value 
of resources prepared in accordance with an alternative resources 
evaluation standard that
(a)	has a comprehensive framework for the evaluation of resources,
(b)	defines resources using terminology and categories in a manner 
that is consistent with the terminology and categories of the 
COGE Handbook,
(c)	has a scientific basis, and
(d)	requires that estimates of volume and value of resources be based 
on reasonable assumptions.
(2)	If disclosure is made under subsection (1) and that disclosure is required 
under the laws of or by a foreign jurisdiction, the reporting issuer must, 
proximate to the disclosure,
(a)	disclose the effective date of the estimate,
(b)	describe any significant differences, and the reasons those 
differences exist, between the estimate prepared in accordance 
with the alternative resources evaluation standard and the 
estimate prepared in accordance with the COGE Handbook, and
(c)	include a reference to the location on the SEDAR website of the 
estimate prepared
(i)	in accordance with section 5.2, 5.3 or 5.9, as applicable, 
and
(ii)	at the same effective date as the alternative disclosure.
(3)	If disclosure is made under subsection (1) and the disclosure is not 
required by a foreign jurisdiction, the reporting issuer must, proximate 
to the disclosure,
(a)	disclose the effective date of the estimate,
(b)	provide a description of the alternative resources evaluation 
standard, 
(c)	describe any significant differences, and the reasons those 
differences exist, between the estimate prepared in accordance 
with the alternative resources evaluation standard and the 
estimate prepared in accordance with the COGE Handbook, and
(d)	disclose the estimate prepared
(i)	in accordance with section 5.2, 5.3 or 5.9, as applicable, 
and
(ii)	at the same effective date as the disclosure provided under 
subsection (1).
(4)	An estimate under subsection (1) must have been prepared or audited by 
a qualified reserves evaluator or auditor..
19.	Part 6 is amended by 
(a)	adding "AND CEASING TO ENGAGE IN OIL AND GAS 
ACTIVITIES" after "MATERIAL CHANGE DISCLOSURE" in the 
heading, 
(b)	replacing "Part" with "section" in section 6.1, and
(c)	adding the following:
6.2	Ceasing to Engage in Oil and Gas Activities - A reporting issuer 
must file with the securities regulatory authority a notice 
prepared in accordance with Form 51-101F5 not later than 10 
days after ceasing to be engaged, directly or indirectly, in oil and 
gas activities..
20.	Section 8.1 is amended by adding the following:
(3)	Except in Ontario, an exemption referred to in subsection (1) is granted 
under the statute referred to in Appendix B of National Instrument 14-
101 Definitions, opposite the name of the local jurisdiction..
21.	General Instruction (2) of Form 51-101F1 is amended by replacing "its 
financial year then ended" with "the financial year then ended". 
22.	General Instruction (5) of Form 51-101F1 is amended by adding ", and that 
contingent resource data and prospective resource data only appears in an 
appendix to Form 51-101F1" after "not omitted".
23.	Instruction (4) of Item 1.1 of Form 51-101F1 is amended by inserting 
"statement" after "should ensure that its financial".
24.	Subsection 3(c) of Item 2.1 of Form 51-101F1 is replaced with the following:
(c)	Disclose, by product type, in each case with associated by-products, and 
on a unit value basis for each product type, in each case with associated 
by-products (e.g., $/Mcf or $/bbl using net reserves), the net present 
value of future net revenue (before deducting future income tax 
expenses) estimated using forecast prices and costs and calculated using 
a discount rate of 10 percent..
25.	Item 2.1 of Form 51-101F1 is amended by inserting the following at the end 
of the item:
INSTRUCTIONS
(1)	Disclose all of the reserves in respect of  which the reporting issuer has 
a direct or indirect ownership, working or royalty interest.  These 
concepts are explained in sections 5.5.4(a) "Ownership Considerations" 
and 7.5 "Interests" of volume 1 of the COGE Handbook, section 5.2 
"Ownership Considerations" of volume 2 of the COGE Handbook and, 
with respect to an entitlement to share production under a production 
sharing agreement, section 4.0 "Fiscal Regimes" of the chapter entitled 
"Reserves Recognition For International Properties" of volume 3 of the 
COGE Handbook. 
(2)	Do not include, in the reserves data a product type that is subject to 
purchase under a long-term supply, purchase or similar agreement.  
However, if the reporting issuer is a party to such an agreement with a 
government or governmental authority, and participates in the operation 
of the properties in which the product type is situated or otherwise 
serves as producer of the reserves (in contrast to being an independent 
purchaser, broker, dealer or importer), disclose separately the reporting 
issuer's interest in the reserves that are subject to such agreements at 
the effective date and the net quantity of the product type received by 
the reporting issuer under the agreement during the year ended on the 
effective date.
(3)	Future net revenue includes the portion attributable to the reporting 
issuer's interest under an agreement referred to in Instruction (2).
(4)	If the reporting issuer's disclosure of reserves would, to a reasonable 
person, be misleading, if stated without an explanation of the reporting 
issuer's ownership of or control over those reserves, explain the nature 
of the reporting issuer's ownership of or control over reserves disclosed 
in the statement filed or to be filed under item 1 of section 2.1 of NI 51-
101..  
26.	Items 2.3 and 2.4 of Form 51-101F1 are repealed.
27.	Item 3.2 of Form 51-101F1 is amended by repealing Instruction (3).
28.	Subsections 2(b) and (c) of Item 4.1 of Form 51-101F1 are replaced with the 
following:
(b)	for each of the following:
(i)	bitumen;
(ii)	coal bed methane;
(iii)	conventional natural gas;
(iv)	gas hydrates; 
(v)	heavy crude oil;
(vi)	light crude oil and medium crude oil combined;
(vii)	natural gas liquids; 
(viii)	shale gas; 
(ix)	synthetic crude oil; 
(x)	synthetic gas;
(xi)	tight oil;
(c)	separately identifying and explaining each of the following:
(i)	extensions and improved recovery;
(ii)	technical revisions;
(iii)	discoveries;
(iv)	acquisitions;
(v)	dispositions;
(vi)	economic factors;
(vii)	production..
29.	Item 5.1 of Form 51-101F1 is amended by 
(a)	deleting "and, in the aggregate, before that time" wherever it occurs,
(b)	replacing "not planning to develop particular" with "deferring the 
development of particular" wherever it occurs,
(c)	replacing "during the following two years" with "beyond two years" 
wherever it occurs, and
(d)	adding the following instructions:
INSTRUCTIONS
(1)	The phrase "first attributed" refers to the initial allocation of an 
undeveloped volume of oil or gas reserves by a reporting issuer. 
Only previously unassigned undeveloped volumes of oil or gas 
reserves may be included in the first attributed volumes for the 
applicable financial year. For example, if in 2011 a reporting 
issuer allocated by way of acquisition, discovery, extension and 
improved recovery 300 MMcf of proved undeveloped 
conventional natural gas reserves, that would be the first 
attributed volume for 2011.  
(2)	The discussion of a reporting issuer's plans for developing 
undeveloped reserves, or the reporting issuer's reasons for 
deferring the development of undeveloped reserves, must enable a 
reasonable investor to assess the efforts made by the reporting 
issuer to convert undeveloped reserves to developed reserves..
30.	Item 5.2 of Form 51-101F1 is replaced with the following:
Item 5.2	Significant Factors or Uncertainties Affecting Reserves 
Data
Identify and discuss significant economic factors or significant 
uncertainties that affect particular components of the reserves data.
INSTRUCTIONS
(1)	A reporting issuer must, under this Item, include a discussion of 
any significant abandonment and reclamation costs, unusually 
high expected development costs or operating costs, or 
contractual obligations to produce and sell a significant portion 
of production at prices substantially below those which could be 
realized but for those contractual obligations.
(2)	If the information required by this Item is presented in the 
reporting issuer's financial statements and notes thereto for the 
most recent financial year ended, the reporting issuer satisfies 
this Item by directing the reader to that presentation..
31.	Item 6.2.1 of Form 51-101F1 is replaced with the following:
Item 6.2.1	Significant Factors or Uncertainties Relevant to 
Properties with No Attributed Reserves
Identify and discuss significant economic factors or significant 
uncertainties that have affected or are reasonably expected to affect the 
anticipated development or production activities on properties with no 
attributed reserves.
INSTRUCTIONS
(1)	A reporting issuer must, under this Item, include a discussion of 
any significant abandonment and reclamation costs, unusually 
high expected development costs or operating costs, or 
contractual obligations to produce and sell a significant portion 
of production at prices substantially below those which could be 
realized but for those contractual obligations.
(2)	If the information required by this Item is presented in the 
reporting issuer's financial statements and notes thereto for the 
most recent financial year ended, the reporting issuer satisfies 
this Item by directing the reader to that presentation..
32.	Item 6.4 of Form 51-101F1 is repealed.
33.	Item 6.6 of Form 51-101F1 is replaced with the following:
Item 6.6	Costs Incurred 
Disclose by country for the most recent financial year ended each of the 
following:
(a)	property acquisition costs, separately for proved properties 
and unproved properties;
(b)	exploration costs;
(c)	development costs.
INSTRUCTION
If the costs specified in paragraphs (a), (b) and (c) are presented in the 
reporting issuer's financial statements and the notes to those statements 
for the most recent financial year ended, the reporting issuer satisfies 
this Item by directing the reader to that presentation..
34.	Item 6.9 of Form 51-101F1 is amended by replacing "To the extent not 
previously disclosed in financial statements by the reporting issuer, disclose" 
with "Disclose,".
35.	Form 51-101F1 is amended by adding the following:
PART 7	OPTIONAL DISCLOSURE OF CONTINGENT 
RESOURCES DATA AND PROSPECTIVE RESOURCES DATA
INSTRUCTIONS
(1)	A reporting issuer may disclose contingent resources data or 
prospective resources data in a statement of the reserves data and 
other information filed under item 1 of section 2.1 of NI 51-101, 
however, that data must only be disclosed as an appendix to that 
statement.
(2)	The following cautionary statement must be included in bold font 
and appear proximate to the risked net present value of future net 
revenue associated with contingent resources or prospective 
resources:
An estimate of risked net present value of future net 
revenue of [contingent resources][and][prospective 
resources] is preliminary in nature and is provided to assist 
the reader in reaching an opinion on the merit and 
likelihood of the company proceeding with the required 
investment.  It includes [contingent 
resources][and][prospective resources] that are considered 
too uncertain with respect to the [chance of 
development][and][chance of discovery] to be classified as 
reserves.  There is uncertainty that the risked net present 
value of future net revenue will be realized.
(3)	A reporting issuer may not rely on subsection 5.9(3) of NI 51-101 
for disclosure required to be included in this Part.
(4)	If a reporting issuer's disclosure of contingent resources or 
prospective resources would, to a reasonable person, be 
misleading if not accompanied by an explanation of the reporting 
issuer's ownership of or control over those resources, explain the 
nature of the reporting issuer's ownership of or control over all 
contingent resources and prospective resources disclosed in the 
statement filed or to be filed under item 1 of section 2.1 of NI 51-
101.
(5)	A reporting issuer's disclosure respecting the value of 
prospective resources or contingent resources that are not in the 
development pending project maturity sub-class must be risked 
and must include an explanation of the factors considered 
respecting the chance of commerciality, which includes both 
chance of discovery and chance of development in the case of 
prospective resources and chance of development in the case of 
contingent resources.
GUIDANCE
(1)	A reporting issuer is subject to sections 5.9 and 5.17 of NI 51-
101 when providing disclosure of contingent resources data or 
prospective resources data in this Form..
(2)	A reporting issuer providing disclosure of contingent resources 
data or prospective resources data in this Form must have an 
evaluation process for contingent resources or prospective 
resources that
(a)	is at least as rigorous as would be the case for reserves 
data, and
(b)	is recognized as well-established in the oil and gas 
industry.
(3)	An evaluation process described in subsection (2) is not needed if 
a reasonable qualified evaluator or auditor would conclude that 
it is not necessary in the circumstances.
(4)	All public disclosure by reporting issuers is subject to the general 
prohibition against misleading statements. The disclosure of 
development on-hold, development unclarified or development not 
viable contingent resources, or prospective resources, in the 
statement of reserves data and other oil and gas information 
might be misleading where there is a significant degree of 
uncertainty and risk associated with those estimates.
Item 7.1	Contingent Resources Data
1.	If a reporting issuer discloses contingent resources in the 
statement filed under item 1 of section 2.1 of NI 51-101, the 
reporting issuer must disclose all of the following:
(a)	the risked 2C contingent resources volumes, gross and net, 
for each product type, and classified in each applicable 
project maturity sub-class;
(b)	if contingent resources in the development pending project 
maturity sub-class are disclosed, the risked net present 
value of future net revenue of the 2C contingent resources 
in the development pending project maturity sub-class, 
calculated using forecast prices and costs for each product 
type, before deducting future income taxes and using 
discount rates of 0 percent, 5 percent, 10 percent, 15 
percent and 20 percent.
2.	Disclose the numeric value of the chance of development risk and 
describe the method of all of the following:
(a)	quantifying the chance of development risk;
(b)	estimating the contingent resources adjusted for chance of 
development risk and the associated risked net present 
value of future net revenue.
Item 7.2	Prospective Resources Data
1.	If a reporting issuer discloses prospective resources in the 
statement filed under item 1 of section 2.1 of NI 51-101, disclose 
the best estimate prospective resources, gross and net, for each 
product type.
2.	Disclose the numeric value of the chance of discovery and chance 
of development and describe the method of all of the following:
(a)	quantifying the chance of discovery and chance of 
development;
(b)	estimating the prospective resources adjusted for chance of 
discovery and chance of development.
Item 7.3	Forecast Prices Used in Estimates
1.	For each product type, disclose the pricing assumptions used in 
estimating contingent resources data and prospective resources 
data disclosed in response to Item 7.1 for each of the five years 
following the most recently completed financial year.
2.	The disclosure in response to section 1 must include the 
benchmark reference pricing schedules for the countries or 
regions in which the reporting issuer operates, and inflation and 
other forecast factors used.
3.	The pricing assumptions included in section 1 must be the same 
as the pricing assumptions disclosed in response to Part 3 of this 
Form 51-101F1.  
INSTRUCTIONS
(1)	Benchmark reference prices may be obtained from sources 
such as public product trading exchanges or prices posted 
by purchasers.
(2)	The defined term "forecast prices and costs" includes any 
fixed or presently determinable future prices or costs to 
which the reporting issuer is legally bound by a 
contractual or other obligation to supply a physical 
product, including those for an extension period of a 
contract that is likely to be extended.  Such contractually 
committed prices must be used, instead of benchmark 
reference prices for the purpose of estimating contingent 
resources data and prospective resources data, unless a 
reasonable investor would find the use those contractually 
committed prices misleading.
Item 7.4	Supplemental Contingent Resources Data
The reporting issuer may supplement its disclosure of contingent 
resources data under Item 7.1 by also disclosing estimates of 
contingent resources together with estimates of associated risked 
net present value of future net revenue, determined using constant 
prices and costs rather than forecast prices and costs for each 
applicable product type..
36.	Form 51-101F2 is replaced with the following:
FORM 51-101F2
REPORT ON [RESERVES DATA][,][CONTINGENT RESOURCES 
DATA][AND] [PROSPECTIVE RESOURCES DATA]
BY
INDEPENDENT QUALIFIED RESERVES
EVALUATOR OR AUDITOR
This is the form referred to in item 2 of section 2.1 of National Instrument 51-101 
Standards of Disclosure for Oil and Gas Activities ("NI 51-101").
1.	Terms to which a meaning is ascribed in NI 51-101 have the same meaning in 
this form.
2.	The report on reserves data, contingent resources data or prospective 
resources data, if applicable, referred to in item 2 of section 2.1 of NI 51-101, 
to be executed by one or more qualified reserves evaluators or auditors 
independent of the reporting issuer, must in all material respects be in the 
following form:
Report on [Reserves Data]][,][Contingent Resources 
Data][and][Prospective Resources Data] by Independent 
Qualified Reserves Evaluator or Auditor
To the board of directors of [name of reporting issuer] (the "Company"):
1.	We have [audited][,][and][evaluated][or reviewed] the 
Company's [reserves data][,][contingent resources 
data][and][prospective resources data] as at [last day of the 
reporting issuer's most recently completed financial year].  [If the 
Company has reserves, include the following sentence: The 
reserves data are estimates of proved reserves and probable 
reserves and related future net revenue as at [last day of the 
reporting issuer's most recently completed financial year], 
estimated using forecast prices and costs.] [If the Company has 
disclosed contingent resources data or prospective resources 
data, include the following sentence: The [contingent resources 
data] [and] [prospective resources data] are risked estimates of 
volume of [contingent resources][and][prospective resources] and 
related risked net present value of future net revenue as at [last 
day of the reporting issuer's most recently completed financial 
year], estimated using forecast prices and costs.]
2.	The [reserves data][,][contingent resources data][and][prospective 
resources data] are the responsibility of the Company's 
management.  Our responsibility is to express an opinion on the 
[reserves data][,][contingent resources data][and][prospective 
resources data] based on our [audit][,][and][evaluation][and 
review].  
3.	We carried out our [audit][,][and][evaluation][and review] in 
accordance with standards set out in the Canadian Oil and Gas 
Evaluation Handbook as amended from time to time (the "COGE 
Handbook") maintained by the Society of Petroleum Evaluation 
Engineers (Calgary Chapter).
4.	Those standards require that we plan and perform an 
[audit][,][and][evaluation][and review] to obtain reasonable 
assurance as to whether the [reserves data][,][contingent resources 
data][and][prospective resources data] are free of material 
misstatement.  An [audit][,][and][evaluation] [and review] also 
includes assessing whether the [reserves data] [,][contingent 
resources data][and][prospective resources data] are in accordance 
with principles and definitions presented in the COGE Handbook.
5.	[If the Company has reserves, include this paragraph:] The 
following table shows the net present value of future net revenue 
(before deduction of income taxes) attributed to proved plus 
probable reserves, estimated using forecast prices and costs and 
calculated using a discount rate of 10 percent, included in the 
reserves data of the Company [audited][,][and][evaluated][and 
reviewed] for the year ended [last day of the reporting issuer's 
most recently completed financial year], and identifies the 
respective portions thereof that we have [audited][,][and] 
[evaluated] [and reviewed] and reported on to the Company's 
[management/board of directors]:
Independent 
Qualified 
Reserves 
Evaluator or 
Auditor
Effective 
Date of 
[Audit/ 
Evaluation/ 
Review] 
Report
Location of 
Reserves 
(Country or 
Foreign 
Geographic 
Area)
Net Present Value of Future Net Revenue
(before income taxes, 10% discount rate)



Audited
Evaluat
ed
Revie
wed
Total
Evaluator A
xxx xx, 20xx
Xxxx
$xxx
$xxx
$xxx
$xxx
Evaluator B
xxx xx, 20xx
Xxxx
$xxx
$xxx
$xxx
$xxx
Totals


$xxx
$xxx
$xxx
$xxx1
1.	This amount must be the amount disclosed by the 
reporting issuer in its statement of reserves data 
filed under item 1 of section 2.1 of NI 51-101, as its 
future net revenue (before deducting future income 
tax expenses) attributed to proved plus probable 
reserves, estimated using forecast prices and costs 
and calculated using a discount rate of 10 percent 
(required by section 2 of Item 2.1 of Form 51-
101F1).
6.	[If the Company has disclosed contingent resources data or 
prospective resources data, include this paragraph and the 
tables:] The following tables set forth the risked volume and 
risked net present value of future net revenue of [contingent 
resources][and][prospective resources] (before deduction of 
income taxes) attributed to [contingent 
resources][and][prospective resources], estimated using forecast 
prices and costs and calculated using a discount rate of 10%, 
included in the Company's statement prepared in accordance with 
Form 51-101F1 and identifies the respective portions of the 
[contingent resources data][and][prospective resources data] that 
we have [audited][and][evaluated] and reported on to the 
Company's [management/board of directors]: 
Classification
Independent 
Qualified 
Reserves 
Evaluator or 
Auditor
Effective 
Date of 
[Audit/ 
Evaluation] 
Report
Location of 
Resources 
Other than 
Reserves 
(Country or 
Foreign 
Geographic 
Area)
Risked 
Volume
Risked Net Present Value 
of Future Net Revenue 
(before income taxes, 
10% discount rate)





Audited
Evaluated
Total
Development 
Pending 
Contingent 
Resources 
(2C)
Evaluator
xxx xx, 
20xx
xxxx
xxx
$xxx
$xxx
$xxx

Classification
Independent 
Qualified 
Reserves 
Evaluator or 
Auditor
Effective 
Date of  
[Audit/ 
Evaluation] 
Report
Location of 
Resources 
Other than 
Reserves 
(Country or 
Foreign 
Geographic 
Area)
Risked 
Volume
Prospective 
Resources
Evaluator
xxx xx, 
20xx
xxxx
xxx
Contingent 
Resources
[project 
maturity sub-
classes other 
than 
Development 
Pending]
Evaluator
xxx xx, 
20xx
xxxx
xxx
7.	In our opinion, the [reserves data][,][contingent resources 
data][and][prospective resources data] respectively 
[audited][and][evaluated] by us have, in all material respects, been 
determined and are in accordance with the COGE Handbook, 
consistently applied.  We express no opinion on the [reserves 
data][,][contingent resources data][and] [prospective resources data] that 
we reviewed but did not audit or evaluate.
8.	We have no responsibility to update our reports referred to in 
paragraph[s] [4][and][4.1] for events and circumstances occurring after 
the effective date of our reports.
9.	Because the [reserves data][,][contingent resources 
data][and][prospective resources data] are based on judgements 
regarding future events, actual results will vary and the variations may 
be material.  
Executed as to our report referred to above:
Evaluator A, City, Province or State / Country, Execution Date                
								      [signed]
Evaluator B, City, Province or State / Country, Execution Date                	
								       [signed]
37.	Form 51-101F3 is replaced with the following:
FORM 51-101F3 
REPORT OF 
MANAGEMENT AND DIRECTORS 
ON OIL AND GAS DISCLOSURE
This is the form referred to in item 3 of section 2.1 of National Instrument 51-101 
Standards of Disclosure for Oil and Gas Activities ("NI 51-101").  
1.	Terms to which a meaning is ascribed in NI 51-101 have the same meaning in 
this form.
2.	The report referred to in item 3 of section 2.1 of NI 51-101 must in all material 
respects be in the following form:
Report of Management and Directors  
on Reserves Data and Other Information
Management of [name of reporting issuer] (the "Company") are responsible for 
the preparation and disclosure of information with respect to the Company's oil 
and gas activities in accordance with securities regulatory requirements.  This 
information includes reserves data [and includes, if disclosed in the statement 
required by item 1 of section 2.1 of NI 51-101, other information such as 
contingent resources data or prospective resources data].
[Alternative A: Reserves Data to Report or Contingent Resources Data or 
Prospective Resources Data to Report]
[An] independent [qualified reserves evaluator[s] or qualified reserves 
auditor[s]] [has/have] [audited][,][and][evaluated][and reviewed] the 
Company's [reserves data][,][contingent resources data][and][prospective 
resources data].  The report of the independent [qualified reserves evaluator[s] 
or qualified reserves auditor[s] ] [is presented below / will be filed with 
securities regulatory authorities concurrently with this report].
The [Reserves Committee of the] board of directors of the Company has
(a)	reviewed the Company's procedures for providing information to the 
independent [qualified reserves evaluator[s] or qualified reserves 
auditor[s]];
(b)	met with the independent [qualified reserves evaluator[s] or qualified 
reserves auditor[s]] to determine whether any restrictions affected the 
ability of the independent [qualified reserves evaluator[s] or qualified 
reserves auditor[s]] to report without reservation [and, in the event of a 
proposal to change the independent [qualified reserves evaluator[s] or 
qualified reserves auditor[s]], to inquire whether there had been disputes 
between the previous independent [qualified reserves evaluator[s] or 
qualified reserves auditor[s] and management]]; and  
(c)	reviewed the [reserves data][,][contingent resources 
data][and][prospective resources data] with management and the 
independent [qualified reserves evaluator[s] or qualified reserves 
auditor[s]].
The [Reserves Committee of the] board of directors has reviewed the 
Company's procedures for assembling and reporting other information 
associated with oil and gas activities and has reviewed that information with 
management.  The board of directors has [, on the recommendation of the 
Reserves Committee,] approved
(a)	the content and filing with securities regulatory authorities of Form 51-
101F1 containing [reserves data][,][contingent resources 
data][and][prospective resources data] and other oil and gas information; 
(b)	the filing of Form 51-101F2 which is the report of the independent 
[qualified reserves evaluator[s] or qualified reserves auditor[s]] on the 
reserves data, contingent resources data, or prospective resources data; 
and 
(c)	the content and filing of this report.
Because the [reserves data][,][contingent resources data][and][prospective 
resources data] are based on judgements regarding future events, actual results 
will vary and the variations may be material.
[Alternative B: No Reserves to Report and No Resources Other than 
Reserves to Report]
The [Reserves Committee of the] board of directors of the Company has 
reviewed the oil and gas activities of the Company and has determined that the 
Company had no reserves as of [last day of the reporting issuer's most recently 
completed financial year].
An independent qualified reserves evaluator or qualified reserves auditor has 
not been retained to evaluate the Company's reserves data.  No report of an 
independent qualified reserves evaluator or qualified reserves auditor will be 
filed with securities regulatory authorities with respect to the financial year 
ended on [last day of the reporting issuer's most recently completed financial 
year].
The [Reserves Committee of the] board of directors has reviewed the 
Company's procedures for assembling and reporting other information 
associated with oil and gas activities and has reviewed that information with 
management. The board of directors has [, on the recommendation of the 
Reserves Committee,] approved
(a)	the content and filing with securities regulatory authorities of 
Form 51-101F1 containing information detailing the Company's 
oil and gas activities; and
(b)	the content and filing of this report.
						
[signature, name and title of chief executive officer]
						
[signature, name and title of an officer other than the chief executive officer]
						
[signature, name of a director]
						
[signature, name of a director]
[Date]
38.	The Instrument is amended by adding the following:
FORM 51-101F5 
NOTICE OF 
CEASING TO ENGAGE IN OIL AND GAS ACTIVITIES
This is the form referred to in section 6.2 of National Instrument 51-
101 Standards of Disclosure for Oil and Gas Activities ("NI 51-101").
1.	Terms to which a meaning is ascribed in NI 51-101 have the same 
meaning in this form.
2.	The notice referred to in section 6.2 of NI 51-101 must in all 
material respects be in the following form:
Notice of 
Ceasing to Engage in Oil and Gas Activities
Management and the board of directors of [name of reporting issuer] 
(the "Company") have determined that as of [date] the Company is no 
longer engaged, directly or indirectly, in oil and gas activities.
						
[signature, name and title of chief executive officer]
						
[signature, name and title of an officer other than the chief executive 
officer]
						
[signature, name of a director]
						
[signature, name of a director]
[Date]
39.	All footnotes and references to footnotes are repealed.
40. 	This Instrument comes into force on July 1, 2015.
Alberta Securities Commission
AMENDMENTS TO  
NATIONAL INSTRUMENT 51-102  
CONTINUOUS DISCLOSURE OBLIGATIONS
(Securities Act)
Made as a rule by the Alberta Securities Commission on March 11, 2015 pursuant to 
sections 223 and 224 of the Securities Act.
Amendments to 
National Instrument 51-102 Continuous Disclosure Obligations
1.	National Instrument 51-102 Continuous Disclosure Obligations is amended 
by this Instrument.
2.	Paragraph 5.3(2)(b) is amended by adding "for an issuer that is not providing 
disclosure in accordance with section 2.2.1 of Form 51-102F1" after "interim 
MD&A".
3.	Subsection 5.4(1) is amended by replacing "MD&A" with "annual MD&A 
and, if the issuer is not providing disclosure in accordance with section 2.2.1 of 
Form 51-102F1, its interim MD&A,".
4.	Paragraph 5.7(2)(b) is amended by adding "for an issuer that is not providing 
disclosure in accordance with section 2.2.1 of Form 51-102F1" after "interim 
MD&A".
5.	Paragraphs 8.3(1)(b) and (3)(b) are amended by replacing "40 percent" with 
"100 percent".
6.	Subsection 8.4(5) is amended by adding "issuer other than a venture" after "a 
reporting".
7.	Section 9.3.1 is amended
(a)	in subsection (1) by replacing "sends" with "is required to send", 
(b)	in paragraph (1)(b) by deleting ", applying reasonable effort,",
(c)	in subsection (2) by replacing ", in accordance with, and subject to any 
exemptions set out in, Form 51-102F6 Statement of Executive Compensation, 
which came into force on December 31, 2008" with "and in accordance with 
Form 51-102F6 Statement of Executive Compensation",
(d)	by adding the following subsections:
(2.1)	Despite subsection (2), a venture issuer may provide the 
disclosure required by subsection (1) for the periods set out in and in 
accordance with  Form 51-102F6V Statement of Executive 
Compensation - Venture Issuers. 
(2.2)	The disclosure required under subsection (1) must be filed
(a)	not later than 140 days after the end of the issuer's most 
recently completed financial year, in the case of an issuer 
other than a venture issuer, or
(b)	not later than 180 days after the end of the issuer's most 
recently completed financial year, in the case of a venture 
issuer.,
(e)	in subsection (3) by replacing ", which came into force on December 
31, 2008" with "or, for a venture issuer relying on subsection (2.1), in Form 
51-102F6V Statement of Executive Compensation - Venture Issuers", 
(f)	by repealing subsection (4), and
(g)	by adding the following subsection: 
(5)	Subsection (2.2) applies to an issuer in respect of a financial year 
beginning on or after July 1, 2015..
8.	Section 11.6 is amended 
(a)	in subsection (1) by replacing "does not send to its securityholders" 
with "is not required to send to its securityholders an information circular and 
does not send", and
(b)	in paragraph (1)(b) by deleting ", applying reasonable effort,",
(c)	in subsection (2) by striking out ", which came into force on December 
31, 2008",
(d)	by adding the following subsection:
(2.1) Despite subsection (2), a reporting issuer that is a venture issuer 
may provide the disclosure required under subsection (1) for the periods 
set out in and  in accordance with   Form 51-102F6V Statement of 
Executive Compensation - Venture Issuers., 
(e)	in subsection (4) by deleting ", which came into force on December 31, 
2008" and replacing it with "or, for a venture issuer relying on subsection 
(2.1), in Form 51-102F6V Statement of Executive Compensation - Venture 
Issuers", and
(f)	by repealing subsection (6).
9.	Paragraph (g) of Part 1 of Form 51-102F1 is replaced by the following:
(g) Venture Issuers 
If your company is a venture issuer, you have the option of meeting the 
requirement to provide interim MD&A under section 2.2 by instead 
providing quarterly highlights disclosure. Refer to Companion Policy 
51-102CP for guidance on quarterly highlights.
If your company is a venture issuer without significant revenue from 
operations, in your MD&A including any quarterly highlights, focus 
your discussion and analysis of financial performance on expenditures 
and progress towards achieving your business objectives and 
milestones..
10.	Item 2 of Part 2 of Form 51-102F1 is amended by adding the following 
section:
2.2.1 Quarterly Highlights
If your company is a venture issuer, you have the option of meeting the 
requirement to provide interim MD&A under section 2.2 by instead providing 
a short discussion of all material information about your company's operations, 
liquidity and capital resources.  Include in your discussion:
*	an analysis of your company's financial condition, financial 
performance and cash flows and any significant factors that have caused 
period to period variations in those measures;
*	known trends, risks or demands; 
*	major operating milestones; 
*	commitments, expected or unexpected events,  or uncertainties that have 
materially affected your company's operations, liquidity and capital 
resources in the interim period or are reasonably likely to have a 
material effect going forward;
*	any significant changes from disclosure previously made about how the 
company was going to use proceeds from any financing and an 
explanation of variances;
*	any significant transactions between related parties that occurred in the 
interim period.
INSTRUCTIONS
(i)	If the first MD&A you file in this Form (your first MD&A) is an 
interim MD&A, you cannot use quarterly highlights. Rather, you 
must provide all the disclosure called for in Item 1 in your first 
MD&A. Base the disclosure, except the disclosure for section 1.3, 
on your interim financial report. Since you do not have to update 
the disclosure required in section 1.3 in your interim MD&A, 
your first MD&A will provide disclosure under section 1.3 based 
on your annual financial statements. 
(ii)	Provide a short, focused discussion that gives a balanced and 
accurate picture of the company's business activities during the 
interim period. The purpose of the quarterly highlights reporting 
is to provide a brief narrative update about the business activities, 
financial condition, financial performance and cash flow of the 
company. While summaries are to be clear and concise, they are 
subject to the normal prohibitions against false and misleading 
statements. 
(iii)	Quarterly highlights prepared in accordance with section 2.2.1 
are not required for your company's fourth quarter as relevant 
fourth quarter content will be contained in your company's 
annual MD&A prepared in accordance with Item 1 (see section 
1.10).
(iv)	You must title your quarterly highlights "Interim MD&A - 
Quarterly Highlights".
(v)	If there was a change to the company's accounting policies 
during the interim period, include a description of the material 
effects resulting from the change. 
2.2.2 Quarterly Highlights - Transition
Section 2.2.1 applies to an issuer in respect of a financial year beginning on or 
after July 1, 2015..
11.	Item 5.4 of Form 51-102F2 is replaced with the following: 
5.4	Companies with Mineral Projects 
If your company had a mineral project, provide the following 
information, by summary if applicable, for each project material to your 
company: 
(1)	Current Technical Report - The title, author(s), and date of the 
most recent technical report on the property filed in accordance 
with National Instrument 43-101 Standards of Disclosure for 
Mineral Projects.
(2)	Project Description, Location, and Access 
(a)	The location of the project and means of access. 
(b)	The nature and extent of your company's title to or interest 
in the project, including surface rights, obligations that 
must be met to retain the project, and the expiration date of 
claims, licences and other property tenure rights. 
(c)	The terms of any royalties, overrides, back-in rights, 
payments or other agreements and encumbrances to which 
the project is subject. 
(d)	To the extent known, any significant factors or risks that 
might affect access or title, or the right or ability to perform 
work on, the property, including permitting and 
environmental liabilities to which the project is subject. 
(3)	History 
(a)	To the extent known, the prior exploration and 
development of the property, including the type, amount, 
and results of any exploration work undertaken by previous 
owners, any significant historical estimates, and any 
previous production on the property. 
(4)	Geological Setting, Mineralization, and Deposit Types 
(a)	The regional, local, and property geology. 
(b)	The significant mineralized zones encountered on the 
property, the surrounding rock types and relevant 
geological controls, and the length, width, depth and 
continuity of the mineralization together with a description 
of the type, character and distribution of the mineralization. 
(c)	The mineral deposit type or geological model or concepts 
being applied. 
(5)	Exploration - The nature and extent of all relevant exploration 
work other than drilling, conducted by or on behalf of your 
company, including a summary and interpretation of the relevant 
results. 
(6)	Drilling - The type and extent of drilling and a summary and 
interpretation of all relevant results. 
(7)	Sampling, Analysis, and Data Verification - The sampling and 
assaying including, without limitation, 
(a)	sample preparation methods and quality control measures 
employed before dispatch of samples to an analytical or 
testing laboratory, 
(b)	the security measures taken to ensure the validity and 
integrity of samples taken, 
(c)	assaying and analytical procedures used and the 
relationship, if any, of the laboratory to your company, and 
(d)	quality control measures and data verification procedures, 
and their results. 
(8)	Mineral Processing and Metallurgical Testing - If mineral 
processing or metallurgical testing analyses have been carried out, 
describe the nature and extent of the testing and analytical 
procedures, and provide a summary of the relevant results and, to 
the extent known, provide a description of any processing factors 
or deleterious elements that could have a significant effect on 
potential economic extraction. 
(9)	Mineral Resource and Mineral Reserve Estimates - The 
mineral resources and mineral reserves, if any, including, without 
limitation, 
(a)	the effective date of the estimates, 
(b)	the quantity and grade or quality of each category of 
mineral resources and mineral reserves, 
(c)	the key assumptions, parameters, and methods used to 
estimate the mineral resources and mineral reserves, and 
(d)	the extent to which the estimate of mineral resources and 
mineral reserves may be materially affected by 
metallurgical, environmental, permitting, legal, title, 
taxation, socio-economic, marketing, political, and other 
relevant issues. 
(10)	Mining Operations - For advanced properties, the current or 
proposed mining methods, including a summary of the relevant 
information used to establish the amenability or potential 
amenability of the mineral resources or mineral reserves to the 
proposed mining methods. 
(11)	Processing and Recovery Operations - For advanced 
properties, a summary of current or proposed processing methods 
and reasonably available information on test or operating results 
relating to the recoverability of the valuable component or 
commodity. 
(12)	Infrastructure, Permitting, and Compliance Activities - For 
advanced properties, 
(a)	the infrastructure and logistic requirements for the project, 
and 
(b)	the reasonably available information on environmental, 
permitting, and social or community factors related to the 
project. 
(13)	Capital and Operating Costs - For advanced properties, 
(a)	a summary of capital and operating cost estimates, with the 
major components set out in tabular form, and 
(b)	an economic analysis with forecasts of annual cash flow, 
net present value, internal rate of return, and payback 
period, unless exempted under Instruction (1) to Item 22 of 
Form 43-101F1. 
(14)	Exploration, Development, and Production - A description of 
your company's current and contemplated exploration, 
development or production activities. 
INSTRUCTIONS 
(i)	Disclosure regarding mineral exploration, development or production 
activities on material projects must comply with  National Instrument 
43-101 Standards of Disclosure for Mineral Projects, including the 
limitations set out in it. You must use the appropriate terminology to 
describe mineral reserves and mineral resources. You must base your 
disclosure on information prepared by, under the supervision of, or 
approved by, a qualified person. 
(ii)	You are permitted to satisfy the disclosure requirements in section 5.4 by 
reproducing the summary from the technical report on the material 
property and incorporating the detailed disclosure in the technical 
report into the AIF by reference..
12.	Paragraph (c) of Part 1 of Form 51-102F5 is amended by adding "or Form 
51-102F6V Statement of Executive Compensation - Venture Issuers" after 
"Form 51-102F6 Statement of Executive Compensation". 
13.	Item 8 of Part 2 of Form 51-102F5 is amended by adding "or, in the case of a 
venture issuer, a completed Form 51-102F6 Statement of Executive 
Compensation or a completed Form 51-102F6V Statement of Executive 
Compensation - Venture Issuers" after "Form 51-102F6 Statement of 
Executive Compensation".
14.	Subsection 1.3(10) of Form 51-102F6 is amended by deleting ", applying 
reasonable effort,".
15.	Commentary 1 of section 2.1 of Form 51-102F6 is amended by deleting ", 
applying reasonable effort,".
16.	Commentary 2 of subsection 3.1(10) of Form 51-102F6 is amended by 
deleting "still". 
17.	Subsection 8.1(1) of Form 51-102F6 is amended by replacing "required by" 
with "they are required to disclose in the United States under".  
18.	The following form is added: 
Form 51-102F6V
Statement of Executive Compensation - Venture Issuers
ITEM 1 - GENERAL PROVISIONS
1.1	Objective
All direct and indirect compensation provided to certain executive officers and 
directors for, or in connection with, services they have provided to the 
company or a subsidiary of the company must be disclosed in this form.
The objective of this disclosure is to communicate the compensation the 
company paid, made payable, awarded, granted, gave or otherwise provided to 
each named executive officer and director for the financial year, and the 
decision-making process relating to compensation. This disclosure will provide 
insight into executive compensation as a key aspect of the overall stewardship 
and governance of the company and will help investors understand how 
decisions about executive compensation are made.
A company's executive compensation disclosure under this form must satisfy 
this objective and subsections 9.3.1(1) or 11.6(1) of the Instrument.
While the objective of this disclosure is the same as the objective in section 1.1 
of Form 51-102F6, this form is to be used by venture issuers only.  Reporting 
issuers that are not venture issuers must complete Form 51-102F6.
1.2	Definitions 
If a term is used in this form but is not defined in this section, refer to 
subsection 1.1(1) of the Instrument or to National Instrument 14-101 
Definitions. 
In this form,
"company" includes other types of business organizations such as 
partnerships, trusts and other unincorporated business entities;
"compensation securities" includes stock options, convertible securities, 
exchangeable securities and similar instruments including stock appreciation 
rights, deferred share units and restricted stock units granted or issued by the 
company or one of its subsidiaries for services provided or to be provided, 
directly or indirectly, to the company or any of its subsidiaries;
"external management company" includes a subsidiary, affiliate or associate 
of the external management company;
"named executive officer" or "NEO" means each of the following 
individuals:
(a)	each individual who, in respect of the company, during any part of the 
most recently completed financial year, served as chief executive officer, 
including an individual performing functions similar to a chief executive 
officer;
(b)	each individual who, in respect of the company, during any part of the 
most recently completed financial year, served as chief financial officer, 
including an individual performing functions similar to a chief financial 
officer;
(c)	in respect of the company and its subsidiaries, the most highly 
compensated executive officer other than the individuals identified in 
paragraphs (a) and (b) at the end of the most recently completed 
financial year whose total compensation was more than $150,000, as 
determined in accordance with subsection 1.3(5), for that financial year; 
(d)	each individual who would be a named executive officer under 
paragraph (c) but for the fact that the individual was not an executive 
officer of the company, and was not acting in a similar capacity, at the 
end of that financial year; 
"plan" includes any plan, contract, authorization, or arrangement, whether or 
not set out in any formal document, where cash, compensation securities or any 
other property may be received, whether for one or more persons;
"underlying securities" means any securities issuable on conversion, 
exchange or exercise of compensation securities.
1.3	Preparing the form
(1)	All compensation to be included
(a)	When completing this form, the company must disclose all 
compensation paid, payable, awarded, granted, given, or otherwise 
provided, directly or indirectly, by the company, or a subsidiary of the 
company, to each named executive officer and director, in any capacity, 
including, for greater certainty, all plan and non-plan compensation, 
direct and indirect pay, remuneration, economic or financial award, 
reward, benefit, gift or perquisite paid, payable, awarded, granted, given, 
or otherwise provided to the named executive officer or director for 
services provided and for services to be provided, directly or indirectly, 
to the company or a subsidiary of the company.
(b)	If an item of compensation is not specifically mentioned or described in 
this form, disclose it in the column "Value of all other compensation" of 
the table in section 2.1. 
Commentary
1.	Unless otherwise specified, information required to be disclosed under 
this form may be prepared in accordance with the accounting principles 
the company uses to prepare its financial statements, as permitted by 
National Instrument 52-107 Acceptable Accounting Principles and 
Auditing Standards. 
2.	The definition of "director" under securities legislation includes an 
individual who acts in a capacity similar to that of a director.
(2)	Departures from format
(a)	Although the required disclosure must be made in accordance with this 
form, the disclosure may 
(i)	omit a table, column of a table, or other prescribed information, if 
it does not apply, and
(ii)	add a table, column, or other information if 
(A)	necessary to satisfy the objective in section 1.1, and
(B)	to a reasonable person, the table, column, or other 
information does not detract from the prescribed 
information in the table in section 2.1.
(b)	Despite paragraph (a), a company must not add a column to the table in 
section 2.1.
(3)	Information for full financial year
(a)	If a named executive officer acted in that capacity for the company 
during part of a financial year for which disclosure is required in the 
table in section 2.1, provide details of all of the compensation that the 
named executive officer received from the company for that financial 
year. This includes compensation the named executive officer earned in 
any other position with the company during the financial year.
(b)	Do not annualize compensation in a table for any part of a year when a 
named executive officer was not in the service of the company. 
Annualized compensation may be disclosed in a footnote.
(4)	Director and named executive officer compensation
(a)	Disclose any compensation awarded to, earned by, paid to, or payable to 
each director and named executive officer, in any capacity with respect 
to the company. Compensation to directors and named executive officers 
must include all compensation from the company and its subsidiaries. 
(b)	Disclose any compensation awarded to, earned by, paid to, or payable to, 
a named executive officer, or director, in any capacity with respect to the 
company, by another person or company.
(5)	Determining if an individual is a named executive officer
For the purpose of calculating  total compensation awarded to, earned by, paid 
to, or payable to an executive officer under paragraph (c) of the definition of 
named executive officer, 
(a)	use the total compensation that would be reported for that executive 
officer in the table in section 2.1, as if the executive officer were a 
named executive officer for the company's most recently completed 
financial year, and
(b)	exclude any compensation disclosed in the column "Value of all other 
compensation" of the table in section 2.1.
Commentary
The $150,000 threshold in paragraph (c) of the definition of named executive 
officer only applies when determining who is a named executive officer in a 
company's most recently completed financial year. If an individual is a named 
executive officer in the most recently completed financial year, disclosure of 
compensation in the prior years must be provided even if total compensation in 
a prior year is less than $150,000. 
(6)	Compensation to associates
Disclose any awards, earnings, payments, or payables to an associate of a 
named executive officer, or of a director, as a result of compensation awarded 
to, earned by, paid to, or payable to the named executive officer or the director, 
in any capacity with respect to the company.
(7)	Currencies
(a)	Companies must report amounts required by this form in Canadian 
dollars or in the same currency that the company uses for its financial 
statements. A company must use the same currency in all of the tables of 
this form. 
(b)	If compensation awarded to, earned by, paid to, or payable to a named 
executive officer or director was in a currency other than the currency 
reported in the prescribed tables of this form, state the currency in which 
compensation was awarded, earned, paid, or payable, disclose the 
currency exchange rate and describe the methodology used to translate 
the compensation into Canadian dollars or the currency that the 
company uses in its financial statements.
(8)	New reporting issuers
(a)	A company is not required to provide information for a completed 
financial year if the company was not a reporting issuer at any time 
during the most recently completed financial year, unless the company 
became a reporting issuer as a result of a restructuring transaction.
(b)	If the company was not a reporting issuer at any time during the most 
recently completed financial year and the company is completing this 
form because it is preparing a prospectus, discuss all significant 
elements of the compensation to be awarded to, earned by, paid to, or 
payable to named executive officers and directors of the company once 
it becomes a reporting issuer, to the extent this compensation has been 
determined.
(9)	Plain language
Information required to be disclosed under this form must be clear, concise, 
and presented in such a way that it provides a person, applying reasonable 
effort, an understanding of
(a)	how decisions about named executive officer and director compensation 
are made, and
(b)	how specific named executive officer and director compensation relates 
to the overall stewardship and governance of the company.  
Commentary
Refer to the plain language principles listed in section 1.5 of Companion 
Policy 51-102CP Continuous Disclosure Obligations for further guidance.
ITEM 2 - DIRECTOR AND NAMED EXECUTIVE OFFICER 
COMPENSATION
2.1	Director and named executive officer compensation, excluding 
compensation securities 
(1)	Using the following table, disclose all compensation referred to in subsection 
1.3(1) of this form for each of the two most recently completed financial years, 
other than compensation disclosed under section 2.3.
Commentary
For venture issuers, compensation includes payments, grants, awards, gifts 
and benefits including, but not limited to,
*	salaries,
*	consulting fees, 
*	management fees, 
*	retainer fees, 
*	bonuses, 
*	committee and meeting fees, 
*	special assignment fees, 
*	pensions and employer paid RRSP contributions, 
*	perquisites such as
o	car, car lease, car allowance or car loan, 
o	personal insurance, 
o	parking, 
o	accommodation, including use of vacation accommodation, 
o	financial assistance, 
o	club memberships
o	use of corporate motor vehicle or aircraft, 
o	reimbursement for tax on perquisites or other benefits, and 
o	investment-related advice and expenses.
Table of compensation excluding compensation securities
Name 
and 
position
Year
Salary, 
consulting 
fee, retainer 
or 
commission 
($)

Bonus 
($)
Committee 
or meeting 
fees ($)
Value of 
perquisites 
($)

Value of all 
other 
compensation 
($)
Total 
compensation 
($)
































(2)	In the table required under subsection (1), disclose compensation of each 
named executive officer first, followed by compensation of any director who is 
not a named executive officer.
(3)	If the individual is a named executive officer and a director, state both 
positions in the column entitled "Name and position". In a footnote to the table, 
identify how much compensation the NEO received for each position. 
(4)	In the column entitled "Value of perquisites", include perquisites provided to 
an NEO or director that are not generally available to all employees and that, in 
aggregate, are greater than
(a)	$15,000, if the NEO or director's total salary for the financial year is 
$150,000 or less, 
(b)	10% of the NEO or director's salary for the financial year, if the NEO or 
director's total salary for the financial year is greater than $150,000 but 
less than $500,000, or
(c)	$50,000, if the NEO or director's total salary for the financial year is 
$500,000 or greater. 
Value these items on the basis of the aggregate incremental cost to the 
company and its subsidiaries. Describe in a footnote the methodology used for 
computing the aggregate incremental cost to the company.
Provide a note to the table to disclose the nature of each perquisite provided 
that equals or exceeds 25% of the total value of perquisites provided to that 
named executive officer or director, and how the value of the perquisite was 
calculated, if it is not provided in cash.
Commentary
For the purposes of the column entitled "Value of perquisites", an item is 
generally a perquisite if it is not integrally and directly related to the 
performance of the director or named executive officer's duties. If something is 
necessary for a person to do his or her job, it is integrally and directly related 
to the job and is not a perquisite, even if it also provides some amount of 
personal benefit.
(5)	If non-cash compensation, other than compensation required to be disclosed in 
section 2.3, was provided or is payable, disclose the fair market value of the 
compensation at the time it was earned or, if it is not possible to calculate the 
fair market value, disclose that fact in a note to the table and the reasons why.
(6)	In the column entitled "Value of all other compensation", include all of the 
following:
(a)	any incremental payments, payables and benefits to a named executive 
officer or director that were triggered by, or resulted from, a scenario 
listed in subsection 2.5(2) that occurred before the end of the applicable 
financial year, 
(b)	all compensation relating to defined benefit or defined contribution plans 
including service costs and other compensatory items such as plan 
changes and earnings that are different from the estimated earnings for 
defined benefit plans and above market earnings for defined contribution 
plans. 
Commentary
The disclosure of defined benefit or defined contribution plans relates to all 
plans that provide for the payment of pension plan benefits. Use the same 
amounts indicated in column (e) of the defined benefit plan table required by 
section 2.7 for the applicable financial year and the amounts included in 
column (c) of the defined contribution plan table required by section 2.7 for the 
applicable financial year. 
(7)	Despite subsection (1), it is not necessary to disclose Canada Pension Plan, 
similar government plans and group life, health, hospitalization, medical 
reimbursement and relocation plans that do not discriminate in scope, terms or 
operation that are generally available to all salaried employees.
(8)	If a director or named executive officer has served in that capacity for only part 
of a year, indicate the number of months he or she has served; do not annualize 
the compensation. 
(9)	Provide notes to the table to disclose each of the following for the most 
recently completed financial year only:
(a)	compensation paid or payable by any person or company other than the 
company in respect of services provided to the company or its 
subsidiaries, including the identity of that other person or company;
(b)	compensation paid or payable indirectly to the director or named 
executive officer and, in such case, the amount of compensation, to 
whom it is paid or payable and the relationship between the director or 
named executive officer and such other person or company;
(c)	for the column entitled "Value of all other compensation", the nature of 
each form of other compensation paid or payable that equals or exceeds 
25% of the total value of other compensation paid or payable to that 
director or named executive officer, and how the value of such other 
compensation was calculated, if it is not paid or payable in cash. 
2.2	External management companies
(1)	If one or more individuals acting as named executive officers of the company 
are not employees of the company, disclose the names of those individuals.
(2)	If an external management company employs or retains one or more 
individuals acting as named executive officers or directors of the company and 
the company has entered into an understanding, arrangement or agreement with 
the external management company to provide executive management services 
to the company, directly or indirectly, disclose any compensation that
(a)	the company paid directly to an individual employed, or retained by the 
external management company, who is acting as a named executive 
officer or director of the company;
(b)	the external management company paid to the individual that is 
attributable to the services they provided to the company, directly or 
indirectly.
(3)	If an external management company provides the company's executive 
management services and also provides executive management services to 
another company, disclose the entire compensation the external management 
company paid to the individual acting as a named executive officer or director, 
or acting in a similar capacity, in connection with services the external 
management company provided to the company, or the parent or a subsidiary 
of the company. If the management company allocates the compensation paid 
to a named executive officer or director, disclose the basis or methodology 
used to allocate this compensation. 
Commentary
A named executive officer may be employed by an external management 
company and provide services to the company under an understanding, 
arrangement or agreement. In this case, references in this form to the chief 
executive officer or chief financial officer are references to the individuals who 
performed similar functions to that of the chief executive officer or chief 
financial officer. They are typically the same individuals who signed and filed 
annual and interim certificates to comply with National Instrument 52-109 
Certification of Disclosure in Issuers' Annual and Interim Filings. 
2.3	Stock options and other compensation securities 
(1)	Using the following table, disclose all compensation securities granted or 
issued to each director and named executive officer by the company or one of 
its subsidiaries in the most recently completed financial year for services 
provided or to be provided, directly or indirectly, to the company or any of its 
subsidiaries.
Compensation Securities

Name 
and 
position
Type of 
compensation 
security 
Number of 
compensation 
securities, 
number of 
underlying 
securities, and 
percentage of 
class
Date of 
issue 
or 
grant
Issue, 
conversion 
or exercise 
price ($)
Closing 
price of 
security or 
underlying 
security 
on date of 
grant ($)
Closing 
price of 
security 
or 
underlyin
g security 
at year 
end ($)
Expiry 
date








































(2)	Position the tables prescribed in subsections (1) and (4) directly after the table 
prescribed in section 2.1.
(3)	Provide notes to the table to disclose each of the following:
(a)	the total amount of compensation securities, and underlying securities, 
held by each named executive officer or director on the last day of the 
most recently completed financial year end; 
(b)	any compensation security that has been re-priced, cancelled and 
replaced, had its term extended, or otherwise been materially modified, 
in the most recently completed financial year, including the original and 
modified terms, the effective date, the reason for the modification, and 
the name of the holder;
(c)	any vesting provisions of the compensation securities;
(d)	any restrictions or conditions for converting, exercising or exchanging 
the compensation securities.
(4)	Using the following table, disclose each exercise by a director or named 
executive officer of compensation securities during the most recently 
completed financial year.
Exercise of Compensation Securities by Directors and NEOs

Name 
and 
position
Type of 
compensation 
security 
Number of 
underlying 
securities 
exercised
Exercise 
price 
per 
security 
($)
Date of 
exercise
Closing 
price 
per 
security 
on date 
of 
exercise 
($)
Difference 
between 
exercise 
price and 
closing 
price on 
date of 
exercise 
($)
Total 
value  
on 
exercise 
date ($)








































(5)	For the tables prescribed in subsections (1) and (4), if the individual is a named 
executive officer and a director, state both positions in the columns entitled 
"Name and position".
Commentary
For the purposes of the column entitled "Total value on exercise date" 
multiply the number in the column entitled "Number of underlying securities 
exercised" by the number in the column entitled "Difference between exercise 
price and closing price on date of exercise". 
2.4 	Stock option plans and other incentive plans 
(1)	Describe the material terms of each stock option plan, stock option agreement 
made outside of a stock option plan, plan providing for the grant of stock 
appreciation rights, deferred share units or restricted stock units and any other 
incentive plan or portion of a plan under which awards are granted.
Commentary
Examples of material terms are vesting provisions, maximum term of options 
granted, whether or not a stock option plan is a rolling plan, the maximum 
number or percentage of options that can be granted, method of settlement. 
(2)	Indicate for each such plan or agreement whether it has previously been 
approved by shareholders and, if applicable, when it is next required to be 
approved.
(3)	Disclosure is not required of plans, such as shareholder rights plans, that 
involve issuance of securities to all securityholders.
2.5	Employment, consulting and management agreements
(1)	Disclose the material terms of each agreement or arrangement under which 
compensation was provided during the most recently completed financial year 
or is payable in respect of services provided to the company or any of its 
subsidiaries that were
(a)	performed by a director or named executive officer, or
(b)	performed by any other party but are services typically provided by a 
director or a named executive officer.
(2)	For each agreement or arrangement referred to in subsection (1), disclose each 
of the following:
(a)	the provisions, if any, with respect to change of control, severance, 
termination or constructive dismissal;
(b)	the estimated incremental payments that are triggered by, or result from, 
change of control, severance, termination or constructive dismissal;
(c)	any relationship between the other party to the agreement and a director 
or named executive officer of the company or any of its subsidiaries.
2.6	Oversight and description of director and named executive officer 
compensation
(1)	Disclose who determines director compensation and how and when it is 
determined.
(2)	Disclose who determines named executive officer compensation and how and 
when it is determined.
(3)	For each named executive officer, disclose each of the following:
(a)	a description of all significant elements of compensation awarded to, 
earned by, paid or payable to the named executive officer for the most 
recently completed financial year, including at a minimum each element 
of compensation that accounts for 10% or more of the named executive 
officer's total compensation;
(b)	whether total compensation or any significant element of total 
compensation is tied to one or more performance criteria or goals, 
including for example, milestones, agreements or transactions and, if so,
(i)	describe the performance criteria and goals, and
(ii)	indicate the weight or approximate weight assigned to each 
performance criterion or goal;
(c)	any significant events that have occurred during the most recently 
completed financial year that have significantly affected compensation 
including whether any performance criterion or goal was waived or 
changed and, if so, why;
(d)	how the company determines the amount to be paid for each significant 
element of compensation referred to in paragraph (a), including whether 
the process is based on objective, identifiable measures or a subjective 
decision;
(e)	whether a peer group is used to determine compensation and, if so, 
describe the peer group and why it is considered appropriate;
(f)	any significant changes to the company's compensation policies that 
were made during or after the most recently completed financial year 
that could or will have an effect on director or named executive officer 
compensation.
(4)	Despite subsection (3), if a reasonable person would consider that disclosure of 
a previously undisclosed specific performance criterion or goal would seriously 
prejudice the company's interests, the company is not required to disclose the 
criterion or goal provided that the company does each of the following:
(a)	discloses the percentage of the named executive officer's total 
compensation that relates to the undisclosed criterion or goal;
(b)	discloses the anticipated difficulty in achieving the performance 
criterion or goal;
(c)	states that it is relying on this exemption from the disclosure 
requirement;
(d)	explains why disclosing the performance criterion or goal would 
seriously prejudice its  interests.
(5)	For the purposes of subsection (4), a company's interests are considered not to 
be seriously prejudiced solely by disclosing a performance goal or criterion if 
that criterion or goal is based on broad corporate-level financial performance 
metrics such as earnings per share, revenue growth, or earnings before interest, 
taxes, depreciation and amortization (EBITDA).
2.7	Pension disclosure
If the company provides a pension to a director or named executive officer, provide 
for each such individual the additional disclosure required by Item 5 of Form 51-
102F6.
2.8	Companies reporting in the United States 
(1)	Except as provided in subsection (2), SEC issuers may satisfy the requirements 
of this form by providing the information that they disclose in the United States 
pursuant to item 402 "Executive compensation" of Regulation S-K under the 
1934 Act.
(2)	Subsection (1) does not apply to a company that, as a foreign private issuer, 
satisfies Item 402 of Regulation S-K by providing the information required by 
Items 6.B "Compensation" and 6.E.2 "Share Ownership" of Form 20-F under 
the 1934 Act..
19.	This Instrument comes into force on June 30, 2015.
Transportation
Hosting Expenses Exceeding $600.00 
For the period January 1, 2015 to March 31, 2015
Name: Transportation Regulations: Stakeholder Consultation Meetings 
Date(s): October 22, 23, 30 and 31, 2014
	November 4, 5, 6, 12, 13, 19, 21 and 24, 2014
Amount: $5,195.06 
Purpose: Cabinet granted approval to consult with stakeholders on issues and 
potential amendments to Alberta Transportation's regulations. 
Location: Calgary, Edmonton, Fort McMurray, Grande Prairie, Lethbridge and Red 
Deer, AB


Treasury Board and Finance
Insurance Notice
(Insurance Act)
Effective May 7, 2015, Darwin National Assurance Company changed their name to 
Allied World Specialty Insurance Company.
David Sorensen 
Deputy Superintendent of Insurance.
______________
Effective December 31, 2014 Molecule Exchange Reciprocal withdrew from 
Alberta, pursuant to section 31 of the Insurance Act.
David Sorensen 
Deputy Superintendent of Insurance.
ADVERTISEMENTS
Public Sale of Land
(Municipal Government Act)
City of Brooks
Notice is hereby given that, under the provisions of the Municipal Government Act, 
the City of Brooks will offer for sale, by public auction, in the City of Brooks Council 
Chambers, Brooks, Alberta, on Wednesday, September 2, 2015, at 2 p.m., the 
following lands:
Lot
Block/Unit
Plan
Linc
Address
31
H
1584LK
0015717077
15 St. Mary's Cres
18-19
11
3230AM
0016830770
127 3 St E.
34-36
7
4012X
0019624030
212 Centre St
14
8
7411020
0011544055
56 Dr. Anderson Park
12
11
0212372
0029399078
66 Upland Rd
Each parcel will be offered for sale, subject to a reserve bid and to the reservations 
and conditions contained in the existing certificate of title.
These lands are being offered for sale on an "as is, where is" basis, and the City of 
Brooks makes no representation and gives no warranty whatsoever as to the adequacy 
of services, soil conditions, land use districting, building and development conditions, 
absence or presence of environmental contamination, or the develop ability of the 
subject property for any intended use by the Purchaser.
The City of Brooks may, after the public auction, become the owner of any parcel of 
land not sold at the public auction.
Terms: Cash, certified cheque, interact or bank draft with minimum 10% down 
payment, non-refundable, payable the day of the sale. Balance due within 10 days 
from date of auction.
Redemption may be effected by payment of all arrears of taxes and costs at any time 
prior to the sale.
Dated at Brooks, Alberta, May 19, 2015.
Alan Martens, Chief Administrative Officer.
______________
Town of Bassano
Notice is hereby given that under the provisions of the Municipal Government Act, 
the Town of Bassano will offer for sale, by public auction, in the Town of Bassano 
Administration Office, 502 2nd Avenue Bassano, Alberta, on Wednesday, August 5, 
2015, at 10:00 a.m., the following lands:
Roll Number
Plan
Block
Lot
Linc Number
312000
3872T
7
19
0019674282
This parcel will be offered for sale subject to a reserve bid and to the reservations and 
conditions contained in the existing Certificate of Title.
The Town of Bassano may, after the public auction, become the owner of any parcel 
of land not sold at the public auction.
The lands are being offered for sale on an "as is, where is" basis, and the Town of 
Bassano makes no representation and gives no warranty whatsoever as to the 
adequacy of services, soil conditions, land use distracting, building and development 
conditions, absence of presence of environmental contamination, vacant possession, 
or the developability of the lands for any intended use by the successful bidder. No 
bid will be accepted where the bidder attempts to attach conditions precedent to the 
sale of any parcel of land. No terms or conditions of sale will be considered other than 
those specified by the Town of Bassano . No further information is available at the 
auction regarding the lands to be sold.
Terms: Cash or Certified Cheque. Deposit: 10% (Non Refundable) of bid at the time 
of sale, August 5, 2015. Balance: 90% of bid within 30 days of receipt by the Town of 
Bassano. Goods and Services Taxes (GST) applicable per Federal statues.
Redemption may be effected by payment of all arrears of taxes and costs at any time 
prior to the sale.
Dated at Bassano, Alberta, June 5, 2015.
______________
Town of Sedgewick
Notice is hereby given that, under the provisions of the Municipal Government Act, 
the Town of Sedgewick will offer for sale, by public auction, at the Sedgewick Town 
Office (4818 - 47 St.), Sedgewick, Alberta, on Thursday, August 6, 2015, at 11:00 
a.m., the following lands:
LINC Number
Legal Description
Title Number
0020710190
Plan 1251KS, Block 10, Lots 2A
072120981
All properties are subject to the Tax Sale if the total outstanding property taxes 
remain outstanding prior to the Tax Sale.
Each parcel will be offered for sale, subject to a reserve bid and to the reservations 
and conditions contained in the existing certificate of title.
The land is being offered for sale on an "as is, where is" basis, and the Town of 
Sedgewick makes no representation and gives no warranty whatsoever as to the 
adequacy of services, soil conditions, land use districting, building and development 
conditions, absence or presence of environmental contamination, or the developability 
of the subject land for any intended use by the Purchaser.  No bid will be accepted 
where the bidder attempts to attach conditions precedent to the sale of any parcel.  No 
terms and conditions of sale will be considered other than those specified by the 
Town of Sedgewick.  No further information is available at the auction regarding the 
lands to be sold.
The Town of Sedgewick may, after the public auction, become the owner of any 
parcel of land not sold at the public auction.
Terms: Payment in full by certified cheque, bank draft or money order is required on 
the date of sale.  All sales are subject to current taxes.
GST may apply on properties sold at the public auction.
Redemption may be effected by payment of all arrears of taxes and costs at any time 
prior to the date of the sale .  Properties may be deleted from this list as the tax arrears 
and costs are paid.


Village of Alix
Notice is hereby given that under the provisions of the Municipal Government Act, 
Village of Alix will offer for sale, by public auction, in the Council Chambers, 4849 
50 Street, Village of Alix, Alberta, on Tuesday, August 4, 2015, at 10:00 a.m., the 
following lands:
Roll No
Lot
Block
Plan
C of T
27900
2
E
486KS
072 200 175
40300
23
25
7621249
112 184 306
The purchaser of the property will be responsible for any property taxes for the 
current year.
Each parcel will be offered for sale subject to a reserve bid and to the reservations and 
conditions contained in the existing Certificate of Title.
Redemption of a parcel of land offered for sale may be effected by certified payment 
of all arrears of taxes, penalties and costs at any time prior to the auction.
The lands are being offered for sale on an "as is, where is" basis, and the Municipality 
makes no representation and gives no warranty whatsoever as to the adequacy of 
services, soil conditions, land use districting, building and development conditions, 
absence or presence of environmental contamination, vacant possession, or the 
developability of the lands for any intended use by the successful bidder.
No terms and conditions of sale will be considered other than those specified by the 
municipality.
The auctioneer, the councillors, the chief administrative officer the designated officers 
and employees of the municipality must not bid for or buy, or act as an agent in 
buying any parcel of land offered for sale, unless directed by the municipality to bid 
for or buy a parcel of land on behalf of the municipality.
Once the property is declared sold to another individual at public auction the previous 
owner has no further right to pay the tax arrears.
The risk of the property lies with the purchaser immediately following the auction.
The purchaser is responsible for obtaining vacant possession.
If no offer is received on a property or if the reserve bid is not met, the property 
cannot be sold at the public auction.
The municipality may, after the public auction, become the owner of any parcel of 
land not sold at the public auction.
Terms: The successful bidder must, at the time of the sale, make a non-refundable ten 
percent (10%) deposit in cash, certified cheque or bank draft payable to the 
municipality, with the remaining balance of the purchasing price due within thirty 
(30) days of the sale. GST will apply to all applicable lands sold at the auction.
Bonnie Cretzman, Chief Administrative Officer.
______________
Village of Barons
Notice is hereby given that under the provisions of the Municipal Government Act, 
the Village of Barons will offer for sale, by public auction, at the Village Office, 210 
Main Street, Barons, Alberta, on Tuesday, August 5, 2015, at 10:00 a.m., the 
following lands:
Lot(s)
Block
Plan
Certificate of Title
18 - W1/2 20
1
2605X
941 302 418
13-14
3
2605X
941 304 760
15-16
3
2605X
941 304 760+1
17-18
3
2605X
941 304 775
19
3
2605X
981 211 841
20-21
3
2605X
981 211 925

Pt. of Sec.
Sec.
Twp.
Rge.
M.
Certificate of Title
SW
15
12
23
4
75G39
The parcel is being offered for sale on an "as is, where is" basis and the Village of 
Barons makes no representation and gives no warranty whatsoever as to the adequacy 
of services, soil conditions, land use districting, building and development conditions, 
absence or presence of environmental contamination, vacant possession or the 
developability of the subject land for any intended use by the Purchaser.
No bid will be accepted where the bidder attempts to attach conditions precedent to 
the sale of any parcel. No terms or conditions of sale will be considered other than 
those specified by the Village of Barons.  No further information is available at the 
auction regarding the parcels to be sold.
Each parcel will be offered for sale subject to a reserve bid and to the reservations and 
conditions contained in the existing Certificate of Title.
The Village of Barons may, after the public auction, become the owner of any parcel 
of land not sold at the public auction.
Terms: Cash or Certified Cheque
Redemption may be effected by payment of all arrears of taxes and costs at any time 
prior to the sale.
Dated at Barons, Alberta, May 15, 2015.
Laurie Beck, Administrator.
______________
Village of Donalda
Notice is hereby given that under the provisions of the Municipal Government Act, 
Village of Donalda will offer for sale, by public auction, in the Village Office, 5001 
Main St., Donalda, Alberta, on Sunday, July 26, 2015, at 12:00 p.m., the following 
lands:
Lot
Block
Plan
Linc
C of T
8
8
78222154
0013 595 858
062 429 182
The land will be offered for sale subject to a reserve bid and to the reservations and 
conditions contained in the existing Certificate of Title.
No bid will be accepted where the bidder attempts to attach conditions precedent to 
the sale of any parcel. No terms or conditions will be considered other than those 
specified by the Village of Donalda
The Village of Donalda may, after the public auction, become the owner of any parcel 
of land not sold at the public auction.
Terms: Cash or certified cheque and GST will apply to the land sold at the public 
auction. A 25% deposit is payable upon acceptance of the bid at public auction. The 
full balance of the accepted bid is due within 30 days.
Redemption may be effected by payment of all arrears of taxes and costs at any time 
prior to the sale.
Dated at the Village of Donalda, Alberta, May 28, 2015.
Anna Volk, CAO.
______________
Village of Innisfree
Notice is hereby given that under the provisions of the Municipal Government Act, 
the Village of Innisfree will offer for sale, by public auction, in the Village Office, 
5116 - 50 Ave., Innisfree, Alberta, on Wednesday, September 2, 2015, at 10:00 a.m., 
the following lands:
Lot
Block
Plan
Linc Number
10 & 11
9
4175R
0014926604
This parcel is being offered for sale, subject to a reserve bid and to the reservations 
and conditions contained in the existing certificate of title.
This parcel is being offered for sale on an "as is, where is" basis, and the Village of 
Innisfree makes no representation and gives no warranty whatsoever as to the 
adequacy of services, soil conditions, land use districting, building and development 
conditions, absence or presence of environmental contamination, or the developability 
of the parcel for any intended use by the purchaser.
G.S.T. will apply to all applicable land sold at the Auction.
No bid will be accepted where the Bidder attempts to attach conditions to the sale of 
the land.  The minimum bid cannot be lower than the market value estimate 
predetermined by the Assessor.  No Terms or Conditions of Sale will be considered 
other than those specified by the Village of Innisfree.  The successful Bidder shall be 
required to execute a Sale Agreement in a form and substance acceptable to the 
Village of Innisfree.
No further information will be available at the Public Auction regarding the land to be 
offered for sale.
Terms: Cash or certified cheque, a 10% deposit with the balance due within 30 days 
of the public auction.
The Village of Innisfree may, after the public auction, become the owner of any 
parcel of land not sold at the public auction.
Redemption may be effected by payment of all arrears of taxes and costs at any time 
prior to the sale.
______________
Village of Veteran
Notice is hereby given that under the provisions of the Municipal Government Act, 
the Village of Veteran will offer for sale, by public auction, in the Village Office, at 
110 Waterloo Street, Veteran, Alberta, on Wednesday, August 5, 2015, at 10:00 a.m., 
the following lands:
Plan
Block
Lot
Linc#
Title #
6224HW
10
5
0016  362 551
052 194 940 +1
585AJ
1
11-13
0017 510 620
002 318 155
Each parcel will be offered for sale subject to a reserve bid and to the reservations and 
conditions contained in the existing Certificate of Title.
The Village of Veteran may, after the public auction, become owner of any parcel of 
land not sold at the public auction.
Terms: 5% down and balance in 30 days; Cash or Certified Cheque
Redemption may be effected by payment of all arrears of taxes and costs at any time 
prior to the sale.
Dated at Veteran, Alberta, June 15, 2015.
Debbie Johnstone, C.A.O. 
Village of Veteran






NOTICE TO ADVERTISERS
The Alberta Gazette is issued twice monthly, on the 15th and last day.
Notices and advertisements must be received ten full working days before the 
date of the issue in which the notices are to appear. Submissions received after 
that date will appear in the next regular issue.
Notices and advertisements should be typed or written legibly and on a sheet separate 
from the covering letter. An electronic submission by email or disk is preferred. 
Email submissions may be sent to the Editor of The Alberta Gazette at 
albertagazette@gov.ab.ca. The number of insertions required should be specified and 
the names of all signing officers typed or printed. Please include name and complete 
contact information of the individual submitting the notice or advertisement.
Proof of Publication: Statutory Declaration is available upon request.
A copy of the page containing the notice or advertisement will be emailed to each 
advertiser without charge.
The dates for publication of Tax Sale Notices in The Alberta Gazette are as follows:
 
Issue of
Earliest date on which 
sale may be held
June 30
August 10


July 15
August 25
July 31
September 10


August 15
September 25
August 31
October 11


September 15
October 26
September 30
November 10


October 15
November 25
October 31
December 11


November 14
December 25
November 30
January 10


December 15
January 25
The charges to be paid for the publication of notices, advertisements and documents 
in The Alberta Gazette are:
Notices, advertisements and documents that are 5 or fewer pages	$20.00
Notices, advertisements and documents that are more than 5 pages	$30.00
Please add 5% GST to the above prices (registration number R124072513).


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