Legacy Oil + Gas Inc. Announces Third Quarter 2012 Results

CALGARY, Nov. 8, 2012 /CNW/ - Legacy Oil + Gas Inc. ("Legacy" or the 
"Company") (TSX:LEG) is pleased to announce it has filed on SEDAR its interim 
financial statements and related Management's Discussion and Analysis ("MD&A") 
for the three and nine months ended September 30, 2012. Selected financial 
and operational information is outlined below and should be read in 
conjunction with the interim financial statements and the related MD&A which 
are available for review at www.legacyoilandgas.com or www.sedar.com. 
FINANCIAL + OPERATIONAL HIGHLIGHTS OF LEGACY EXCLUDING LGX OIL + GAS INC.
("LGX")((1)) 


                                                                           
                   Three Months Ended              Nine Months Ended       
                         September 30                   September 30       

Unaudited (Cdn
$000's, except
per share                                    %                            %
amounts)              2012       2011  change       2012       2011  change

Financial                                                                  

Petroleum and
natural gas
sales, net of
royalties           90,325     72,617      24    266,118    206,233      29

Funds generated
by operations (
(2) )               55,692     44,160    26( )   163,681    128,542      27

  Per share
  basic               0.39       0.31      26       1.14       0.92      19

  Per share
  diluted ((3))       0.38       0.31      23       1.12       0.90      24

Net income
(loss)             (2,047)      7,905   (126)    (1,457)     11,936   (112)

  Per share
  basic             (0.01)       0.06   (117)     (0.01)       0.09   (111)

  Per share
  diluted (
  (3))              (0.01)       0.05   (120)     (0.01)       0.08   (113)

Capital
expenditures
(excluding
acquisitions)       75,328    101,783    (26)    243,752    217,029      12

Net acquisitions
(cash
consideration) (
(5))                   192     11,668    (98)      5,096    111,546    (95)

Net debt and
working capital
surplus
(deficit)( (2))  (464,637)  (317,190)      46  (464,637)  (317,190)      46

Operating                                                                  

Production                                                                 

  Crude oil
  (Bbls per
  day)              12,719      8,822      44     12,155      8,270      47

  Heavy oil
  (Bbls per
  day)                 170        229    (26)        181        292    (38)

  Natural gas
  (Mcf per day)     13,193     14,284     (8)     13,222     13,402     (1)

  Natural gas
  liquids (Bbls
  per day)           1,220      1,210       1      1,380      1,102      25

  Barrels of oil
  equivalent
  (Boe per day)
  ((4))             16,308     12,642      29     15,919     11,898      34

Average realized
price                                                                      

  Crude oil ($
  per Bbl)           83.59      89.40     (6)      85.55      91.66     (7)

  Heavy oil ($
  per Bbl)           62.53      67.02     (7)      69.44      69.24       -

  Natural gas ($
  per Mcf)            2.75       3.99    (31)       2.59       4.10    (37)

  Natural gas
  liquids ($ per
  Bbl)               49.38      65.38    (25)      53.84      66.62    (19)

  Barrels of oil
  equivalent ($
  per Boe) (
  (4))               71.77      74.37     (3)      72.93      76.20     (4)

Netback ($ per
Boe)( (1))                                                                 

  Petroleum and
  natural gas
  sales              71.77      74.37     (3)      72.93      76.20     (4)

  Royalties          11.56      11.93     (3)      11.92      12.71     (6)

  Operating
  expenses           13.91      16.08    (13)      14.54      15.14     (4)

  Transportation
  expenses            3.39       2.76      23       3.09       2.59      19

Operating
Netback ($ per
Boe)( (2))           42.91      43.60     (2)      43.38      45.76     (5)

Undeveloped land
holdings (gross
acres)             483,446    654,785    (26)    483,446    654,785    (26)
    (net
    acres)         377,416    499,224    (24)    377,416    499,224    (24)

Common Shares
(000's)                                                                    

Common shares
outstanding, end
of period          143,325    143,256       -    143,325    143,256       -

Weighted average
common shares
(basic)            143,325    143,256       -    143,325    140,105       2

Weighted average
common shares
(diluted) ((3))    145,149    144,211       1    145,584    143,151       2

(1)      Financial and operating highlights for Legacy Oil + Gas Inc.
         ("Legacy" or the "Company") excluding LGX Oil + Gas Inc.

(2)      Management uses funds generated by operations, net debt and
         working capital surplus (deficit) and operating netback to
         analyze operating performance and leverage.   These terms, as
         presented, do not have a standardized meaning prescribed by
         International Financial Reporting Standards and therefore it
         may not be comparable with the calculation of similar measures
         for other entities.

(3)      In calculating the net income (loss) per share diluted, Legacy
         excludes the effect of outstanding stock options and share
         warrants outstanding and uses the weighted average common
         shares (basic) where the Company has a net loss for the
         period. In calculating, funds generated by operations per
         share diluted, the Company includes the effect of outstanding
         stock options and share warrants using the treasury stock
         method. 

(4)      Boe means barrel of oil equivalent.  All Boe conversions in
         this report are derived by converting natural gas to oil
         equivalent at a ratio of six thousand cubic feet of natural
         gas to one barrel of oil equivalent.  Boe may be misleading,
         particularly if used in isolation.  A Boe conversion rate of 1
         Boe: 6 Mcf is based on an energy equivalency conversion method
         primarily applicable at the burner tip and does not represent
         a value equivalency at the wellhead. 

(5)      For the three and nine months ended September 30, 2012, the
         Company issued no common shares as part consideration for
         acquisitions (no common shares for the three months ended
         September 30, 2011 and 6.2 million common shares valued at
         $102.7 million for the nine months ended September 30,
         2011).  
          

ACCOMPLISHMENTS
    --  Increased average production from 12,642 Boe per day in the
        third quarter of 2011 to 16,308 Boe per day (87 percent oil and
        NGL's) in the third quarter of 2012 (29 percent increase). 
        Third quarter average production represents an increase of 8
        percent compared to second quarter 2012 volumes.  On a
        year-to-date basis, average production for the nine months
        ended September 30, 2012 of 15,919 Boe per day represents an
        increase of 34 percent over the nine months ended September 30,
        2011. This growth demonstrates the strength of Legacy's organic
        capital program.
    --  Increased oil and NGL's weighting from 81 percent in the third
        quarter of 2011 to 87 percent in the third quarter of 2012.
    --  Current production of approximately 17,400 Boe per day, 87
        percent oil and NGL's (based on field estimates) represents an
        increase of 14 percent over second quarter 2012 average volumes
        and demonstrates Legacy's organic program is delivering strong
        results and is on-track to reach the Company's previously
        announced 2012 average production target and exit production
        target of 16,300 Boe per day and 17,900 Boe per day,
        respectively.
    --  Drilled 46 (36.2 net) wells with a 100 percent drilling success
        in the third quarter of 2012.
    --  Legacy's most recent horizontal well at Herriman #5 is an
        example of the progression of positive production results as
        the Turner Valley completion practices are further refined. The
        well has increased from 100 Boe per day to peak rates of 400
        Boe per day in its first weeks of production, while still
        producing at approximately 64 percent water cut and carrying a
        high fluid level.
    --  Continued success at the Company's operated pilot waterflood
        projects at Taylorton and Heward.
    --  At Alameda/Steelman, five of the wells drilled in the third
        quarter of 2012 have average 30 day initial production rates of
        440 Boe per day per well.
    --  Increased funds generated by operations from $44.2 million in
        the third quarter of 2011 to $55.7 million in the third quarter
        of 2012 (26 percent increase).   Increased funds flow from
        operations per share (basic) from $0.31 in the third quarter of
        2011 to $0.39 in the third quarter of 2012 (26 percent
        increase).
    --  On a year-to-date basis, funds generated by operations
        increased 27 percent year-over-year to $163.7 million.
    --  Operating costs were reduced to $13.91 per Boe in the third
        quarter of 2012 from $16.08 per Boe in the third quarter of
        2011 (13 percent reduction).  This reduction also represents a
        3 percent reduction since the second quarter of 2012.
    --  On November 1, 2012, the Company entered into a subscription
        agreement with CPPIB Credit Investments Inc., ("CII"), a
        wholly-owned subsidiary of the CPP Investment Board ("CPPIB")
        for an investment by CII in Legacy, subject to final
        documentation. The initial investment will be in the form of
        US$200 million of unsecured, five year term notes with a 7.5
        percent coupon, to be issued pursuant to a trust indenture with
        a Canadian trust company, with an additional US$100 million of
        notes available at a future date, subject to the approval of
        both CII and Legacy on terms to be confirmed at the time of
        issuance.
    --  In a recent scheduled review, Legacy's borrowing base was
        maintained at $525 million, while taking into consideration the
        effect of the recently announced Notes.

Operations Overview

Legacy participated in the drilling of 46 gross (36.2 net) wells targeting 
light oil with a 100 percent success rate. The Company spent $75.3 million 
on capital expenditures in the quarter: $61.3 million on drilling and 
completions and $14.0 million on equipping and facilities.

SPEARFISH PLAY

At Pierson, Manitoba, the Company continues to deliver excellent production 
results in the Spearfish compared to both the previous operator's drilling and 
the type curve used in the 2011 year-end independent engineering report. 
Legacy has achieved these rates while constraining production to maximize 
ultimate recovery. All recent wells carry significant fluid levels, with some 
wells having fluid just below surface. The Company estimates that initial 
productive capability of a number of these Pierson wells would range from 120 
to 280 Boe per day; well in excess of the currently constrained rates. The 
Company believes these achievements will lead to superior long term 
performance, higher per well reserve bookings plus additional locations booked.

Legacy has continued to improve capital efficiencies in the Spearfish play in 
Pierson. Through a combination of reduced day rates for both drilling and 
stimulation services and improved operations execution, wells drilled in 
Pierson over the first nine months of 2012 have drill, complete, equip and 
tie-in costs of less than $1.5 million. Wells drilled in the most recent 
quarter have all-in capital costs between $1.2 million to $1.3 million. The 
average number of drilling days has been reduced from 10 days in 2011 to 6 to 
7 days in the most recent quarter. This excellent performance has been on 
"long" horizontal wells which are typically drilled across an entire section. 
Operating costs continue to be reduced as additional wells are tied-in to the 
central oil battery. Current operating costs in Pierson are down 35 percent in 
the third quarter of 2012 from the third quarter of 2011.

At Bottineau County, North Dakota, no new operated wells were brought on 
production in the quarter, however, the Company anticipates having 6 (4.5 net) 
additional wells on production in the fourth quarter of 2012. The first four 
wells of this recent program have come on production at an average production 
rate of more than 150 Boe per day per well. Legacy has achieved these rates 
while constraining production to maximize ultimate recovery as all wells carry 
fluid levels.

Legacy has also continued to improve capital efficiencies in the Spearfish 
play in Bottineau County. Through a combination of reduced day rates for both 
drilling and stimulation services and improved operations execution, wells 
drilled in Bottineau County in the last half of 2012 have drill, complete, 
equip and tie-in costs of less than $1.6 million. Wells drilled in the most 
recent quarter have all-in capital costs between $1.4 million to $1.5 million 
on an all-in basis. Average number of drilling days has been reduced from 12 
days in 2011 to 7 to 8 days in the most recent quarter. Similar to Pierson, 
this excellent performance has been on "long" horizontal wells that are 
typically drilled across an entire section.

The total Spearfish play development drilling inventory of 440 net potential 
locations (88 percent unbooked) is based on eight wells per section. Based on 
other operators' results in the play, Legacy's location count could increase 
by 50 percent through downspacing. In addition, the Company is evaluating the 
waterflood potential in the play and anticipates recovery factors of up to 14 
percent, based on analogous pools.

BAKKEN PLAY

At Star Valley, Legacy has applied its leading fracture stimulation design 
developed in Heward to this area with good success. Legacy brought 11 (7.8 
net) wells on production since the start of the third quarter of 2012 and 
these wells have average 30 day initial rates of 200 Boe per day per well. As 
previously disclosed, the Company believes the Bakken play boundaries have 
expanded and has increased its drilling location inventory to more than 50 net 
wells in Star Valley.

At Taylorton, the Company has continued to observe improved waterflood 
response in the original pilot area. The 91/12-29 horizontal well has seen its 
oil production rate increase to nearly 50 Bbl per day, with a corresponding 
increase in fluid rate, fluid level and reduction in water cut. The pilot was 
expanded into section 28 in July 2012. Continuous improvement of drilling and 
completion practices has resulted in a reduction in capital costs in 
Taylorton, with drilling, completion, equip and tie-in costs for recent wells 
being 15 percent less than historical costs.

At Heward, the pilot waterflood project initiated in December 2011 continues 
to demonstrate waterflood response as the oil production rate in eight 
offsetting wells has increased since the commencement of the pilot. Individual 
well oil production rates are up 50 to 500 percent from prior to initiation of 
the waterflood. Plans are underway for expansion of the pilot waterflood 
project in the latter part of 2012

CONVENTIONAL MISSISSIPPIAN

Legacy has remained active drilling conventional Mississippian horizontal 
wells throughout its SE Saskatchewan properties. These wells typically cost 
approximately $1 million to drill, complete, equip and tie-in as they 
generally are not fracture stimulated and have excellent rates of return and 
quick payouts.

At Alameda/Steelman, Legacy's recent wells targeting the Frobisher and Midale 
have achieved tremendous production results. Five of the wells drilled in the 
third quarter of 2012 have average 30 day initial production rates of 440 Boe 
per day per well. The majority of these wells carry high fluid levels. The 
Company has identified a significant number of follow-up locations in both 
areas.

TURNER VALLEY

At Turner Valley, Legacy has continued to evolve drilling and completion 
practices to optimize both production rate and capital costs. Drilling to-date 
has targeted infill locations testing areas of varying water cut, reservoir 
pressure, proximity to water injection and three different stratigraphic 
horizons. As previously disclosed, horizontal wells in Turner Valley have 
typically come on production with a high water cut and as load fluid is 
recovered, the water cuts decrease and the oil rates increase. This phenomenon 
has been observed in the 22 previously drilled unfrac'd horizontal wells and 
in the wells drilled by Legacy. In turn, the Company expects the Turner Valley 
horizontal wells to produce at stable, low decline rates based on the 
production profile demonstrated by both the previously drilled and Legacy 
drilled wells.

The Hartell #6 well and Boyd #1 well continue to deliver excellent 
performance. Hartell #6 has produced nearly 50 MBoe in 11 months of production 
and Boyd #1 has produced nearly 40 MBoe in six months of production and has 
averaged 250 Boe per day for the last four months. Both wells did not reach 
peak rates until considerably after first production date. Production has 
continued to trend higher on the remainder of the Turner Valley wells as 
artificial lift optimization has taken place, production run times have 
improved and recovery of load fluid has resumed.

Legacy's most recent horizontal well at Herriman #5 is an example of the 
progression of positive production results as the Turner Valley completion 
practices are further refined. The well has increased from 100 Boe per day to 
peak rates of 400 Boe per day in its first weeks of production, while still 
producing at approximately 67 percent water cut and carrying a high fluid 
level. Offset producers have water cuts between 16 and 45 percent and it is 
anticipated Herriman #5 will continue to trend lower in water cut and higher 
in oil rate.

The Company has made great strides in reducing capital costs since the end of 
2011/early 2012. With an ongoing program, refinement of mud programs and bit 
selection, Legacy continues to improve its drilling performance in Turner 
Valley, leading to decreased capital costs. The recent dual lateral horizontal 
wells have cost approximately $6 million for drilling, completion, equip and 
tie-in, driving much improved capital efficiencies. Legacy believes there is 
potential for additional capital cost reductions on future wells.

EVENTS AFTER THE REPORTING PERIOD - TERM NOTE ISSUE AND MAINTENANCE OF BANK 
LINE

On November 1, 2012, Legacy announced that it has entered into a subscription 
agreement with CII, a wholly-owned subsidiary of the CPPIB for an investment 
by CII in Legacy, subject to final documentation. The initial investment 
will be in the form of US$200 million of unsecured, five year term notes with 
a 7.5% coupon (the "Notes"), to be issued pursuant to a trust indenture with a 
Canadian trust company, with an additional US$100 million of notes available 
at a future date, subject to the approval of both CII and Legacy on terms to 
be confirmed at the time of issuance.

In addition, the Company also announced that its syndicate of lenders, led by 
BMO Capital Markets as Administration Agent, and The Bank of Nova Scotia and 
National Bank of Canada as Co-Syndication Agents and including BMO Capital 
Markets, The Bank of Nova Scotia, Alberta Treasury Branches, National Bank of 
Canada, Canadian Imperial Bank of Commerce, The Toronto-Dominion Bank and JP 
Morgan Chase Bank NA as lenders, has maintained the borrowing base at C$525 
million after taking into account the issue of the Notes, subject to final 
documentation. The next annual borrowing base review is scheduled for on or 
before April 30, 2013.

Legacy will use the net proceeds of the Notes to reduce borrowings under its 
syndicated credit facility. The Company has no intent to increase overall 
leverage, but has pursued the investment by CII for the purposes of increasing 
liquidity, improving financial flexibility and diversifying its sources of 
capital. The introduction of the Notes improves the long term sustainability 
of Legacy's business model. Although no specific agreements have been 
reached, CPPIB and the Company may consider equity investments at some time in 
the future, subject to terms negotiated at that time. Closing of the 
investment is anticipated to occur on or about November 15, 2012. Closing is 
subject to the satisfaction of all of the conditions to closing set out in the 
subscription agreement and to the finalization and execution of all required 
documentation.

OUTLOOK - SUSTAINABILITY + GROWTH

Legacy's business plan has remained unchanged since our inception in July 
2009. Our focus on high quality, high netback, light oil assets comprised of 
large in-place oil resources with low recovery factors and a multi-dimensional 
opportunity inventory, supported by a predictable production and cash flow 
base and strong balance sheet, has been maintained.

Throughout 2012, the Company has remained focused on improving well results, 
improving capital efficiencies and reducing operating costs. Attainment of 
these goals has been demonstrated by another strong quarterly operational and 
financial performance. In the third quarter of 2012, Legacy has grown 
production per share 29 percent and cash flow per share 26 percent from the 
same period last year. The Company has not completed an equity financing or 
major acquisition for 21 months and has generated these results through the 
strength of our organic capital program.

Through continuous improvement of drilling and completion operations and 
proactively working with our service providers, we have seen capital cost 
reductions of up to 15 percent in some areas. Operating costs are at a level 
not seen since late 2010. We are aggressively pursuing additional potential 
cost savings and efficiencies.

Legacy has more than 1,200 net development locations for light oil that 
represent ten years of drilling inventory and number more than our oil 
weighted, mid-cap peers combined. These development locations are in 
well-established and understood large, light oil in-place reservoirs. Our 
inventory does not include the more than 340 net Bakken infill locations, the 
potential 240 net Spearfish infill locations and the potential 260 net 
locations at Maxhamish.

Legacy has dramatically strengthened our balance sheet and liquidity through 
the recently announced a term debt deal and maintenance of our bank line. 
The Company has continued to improve its ability to weather commodity price 
volatility and capital markets turbulence without limiting our significant 
upside potential. Furthermore, as a result of the strategic transaction with 
LGX, Legacy retains a significant share and technical control in a potential 
high impact light oil resource play without any capital obligation.

From the beginning, the Company has been a leader in promoting a sustainable, 
light oil weighted business model. Legacy has proactively managed its 
corporate decline by acquiring strategic assets with both lower base declines 
and secondary recovery potential. Legacy has pioneered industry leading 
completion and production practices that enhance the sustainability of the 
company and the capability to deliver solid per share growth. Our 
disciplined approach, impressive light oil resource capture and significant 
development/waterflood inventory, provides optionality to pursue the best 
strategy to maximize returns for shareholders; whether it is growth, dividend 
or a combination of growth plus dividend. This flexibility differentiates 
Legacy from its peers.

Our team at Legacy has always applied a consistent technical approach and 
resolute perseverance to deliver positive results on our capital 
initiatives. The benefits of our strategy, diligence and successful 
execution will continue to show positive results in the remainder of 2012 and 
beyond.

CONFERENCE CALL DETAILS

Management will be holding a conference call for investors, financial 
analysts, media and any interested persons on Friday November 9, 2012 at 9:00 
a.m. (MDT) (11:00 a.m. EDT) to discuss the quarterly results.

The investor conference call details are as follows:

Participant Dial-In Number(s):
    --  Operator Assisted Toll-Free Dial-In Number:  (888) 231-8191
    --  Local Dial-In Number:  (403) 451-9838
    --  Conference ID:  41483553

Note:In order to join this conference call, you will be required to provide 
the Conference ID Number listed above.

Legacy is a uniquely positioned, well‐capitalized, technically driven, 
intermediate oil and natural gas company with a proven management team 
committed to aggressive, cost‐effective growth of light oil reserves and 
production in large hydrocarbon in‐place assets and resource plays. Legacy's 
common shares trade on the Toronto Stock Exchange under the symbol LEG.

Forward-Looking Information - This press release contains forward-looking 
statements. More particularly, it contains forward-looking statements 
concerning: (i) Legacy being on track to meet its 2012 average and exit 
production targets, (ii) the initial productive capacity of wells at Pierson, 
(iii) the effect of constraining initial production of wells at Pierson on 
long-term well performance, future reserves bookings and additional drilling 
locations, (iv) the anticipated bringing onto production of additional wells 
at Bottineau County in the fourth quarter of 2012, (v) the potential number of 
drilling locations associated with Legacy's Spearfish properties, (vi) the 
potential recovery rates achievable through waterflood of Legacy's Spearfish 
properties, (vii) the potential number of drilling locations at Star Valley, 
(viii) Legacy's plans to expand its waterflood project at Heward, (ix) 
expected production characteristics of horizontal wells drilled at Turner 
Valley, * the potential for future cost reductions for wells drilled at 
Turner Valley, (xi) the anticipated closing date of the unsecured Note 
investment by CII, and (xii) Legacy's total number of drilling locations.

The forward-looking statements contained in this press release are based on 
certain key expectations and assumptions made by Legacy, including 
expectations and assumptions concerning the success of future drilling, 
development and completion activities, the performance of existing wells, the 
performance of new wells, the viability of waterflood projects, the 
availability and performance of facilities and pipelines, the geological 
characteristics of Legacy's properties, the successful application of 
drilling, completion and seismic technology, prevailing weather conditions, 
commodity prices, royalty regimes and exchange rates, the application of 
regulatory and licensing requirements and the availability of capital, labour 
and services. In addition, the forward-looking statements respecting the 
closing of the unsecured Note investment by CII are based on expectations and 
assumptions concerning the satisfaction of all of the conditions to closing 
set out in the subscription agreement with CII and the due finalization and 
execution of all required documentation.

Although Legacy believes that the expectations and assumptions on which the 
forward-looking statements are based are reasonable, undue reliance should not 
be placed on the forward-looking statements because Legacy can give no 
assurance that they will prove to be correct. Since forward-looking 
statements address future events and conditions, by their very nature they 
involve inherent risks and uncertainties. Actual results could differ 
materially from those currently anticipated due to a number of factors and 
risks. These include, but are not limited to, risks associated with the oil 
and gas industry in general (e.g., operational risks in development, 
exploration and production; the uncertainty of reserve estimates; the 
uncertainty of estimates and projections relating to production, costs and 
expenses, and health, safety and environmental risks), constraint in the 
availability of services, commodity price and exchange rate fluctuations, 
adverse weather conditions and uncertainties resulting from potential delays 
or changes in plans with respect to exploration or development projects, 
waterflood projects or capital expenditures. These and other risks are set 
out in more detail in Legacy's Annual Information Form for the year ended 
December 31, 2011 dated March 20, 2012. In addition, the unsecured Note 
investment by CII may not close at the anticipated time or at all due to a 
number of factors and risks. These include, but are not limited to, the 
failure to satisfy all of the conditions to closing set out in the 
subscription agreement or the failure of the parties to agree to acceptable 
final documentation.

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

Meaning of Boe: When used in this press release, Boe means a barrel of oil 
equivalent on the basis of 1 Boe to 6 thousand cubic feet of natural gas. 
Boe/d means a barrel of oil equivalent per day. Boe's may be misleading, 
particularly if used in isolation. A Boe conversion ratio of 1 Boe for 6 
thousand cubic feet of natural gas is based on an energy equivalency 
conversion method primarily applicable at the burner tip and does not 
represent a value equivalency at the wellhead.





Trent J. Yanko, P.Eng. President + CEO

Legacy Oil + Gas Inc. 4400,525-8th Avenue SW Calgary, AB T2P 1G1

Telephone: 403.441.2300 Fax: 403.441.2017

Matt Janisch, P.Eng. Vice-President, Finance + CFO

Legacy Oil + Gas Inc. 4400,525-8th Avenue SW Calgary, AB T2P 2V7

Telephone: 403.441.2300 Fax: 403.441.2017

SOURCE: Legacy Oil + Gas Inc.

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CO: Legacy Oil + Gas Inc.
ST: Alberta
NI: OIL ERN CONF 

-0- Nov/09/2012 01:33 GMT


 
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