Crescent Point Energy Corp. Announces Third Quarter 2011 Results

CALGARY, Alberta, November 10, 2011 -

Crescent Point Energy Corp. (”Crescent Point” or the “Company”) (TSX: CPG) is pleased to announce its operating and financial results for the third quarter ended September 30, 2011. The unaudited financial statements and notes, as well as management’s discussion and analysis, will be available on the System for Electronic Document Analysis and Retrieval (”SEDAR”) at www.sedar.com and on Crescent Point’s website at www.crescentpointenergy.com.

FINANCIAL AND OPERATING HIGHLIGHTS

                                  Three months ended       Nine months ended
                                        September 30            September 30
    (Cdn$000s except shares,
      per share and per boe
      amounts)               2011     2010  % Change   2011   2010  % Change
    Financial
    Funds flow from
    operations (1)         303,315   230,424     32   911,335   619,641   47
      Per share (1)(2)        1.09      0.91     20      3.32      2.70   23
    Net income (loss) (3)  204,624    (7,804) 2,722   287,331   101,826  182
      Per share (2)(3)        0.74     (0.03) 2,567      1.05      0.44  139
    Dividends paid or
    declared               195,021   175,753     11   571,493   472,832   21
      Per share (2)           0.69      0.69      -      2.07      2.07    -
    Payout ratio (%) (1)(4)     64        76    (12)       63        76  (13)
      Per share (%)(1)(2)(4)    63        76    (13)       62        77  (15)
    Net debt (1)(5)      1,072,615 1,340,196    (20)1,072,615 1,340,196  (20)
    Capital acquisitions
    (net) (6)              163,298 1,446,164    (89)  198,548 1,996,277  (90)
    Development capital
    expenditures           349,660   348,513      -   779,921   712,058   10
    Weighted average shares
    outstanding (mm)
      Basic                  275.3     250.0     10     271.6     225.2   21
      Diluted                277.9     254.0      9     274.2     229.1   20
    Operating
    Average daily production
      Crude oil and NGLs
      (bbls/d)              65,253    58,390     12    64,224    52,519   22
      Natural gas (mcf/d)   42,029    42,947     (2)   42,470    38,134   11
      Total (boe/d)         72,258    65,548     10    71,302    58,875   21
    Average selling prices (7)
      Crude oil and NGLs
      ($/bbl)                83.65     70.54     19     86.37     72.44   19
      Natural gas ($/mcf)     3.87      3.69      5      4.01      4.21   (5)
      Total ($/boe)          77.79     65.25     19     80.18     67.35   19
    Netback ($/boe)
      Oil and gas sales      77.79     65.25     19     80.18     67.35   19
      Royalties             (14.27)   (11.65)    22    (13.77)   (12.78)   8
      Operating expenses    (10.64)   (11.27)    (6)   (11.16)   (10.89)   2
      Transportation         (1.78)    (1.49)    19     (1.87)    (1.64)  14
      Netback prior to
      realized derivatives   51.10     40.84     25     53.38     42.04   27
      Realized gain (loss)
      on derivatives         (1.40)     1.25   (212)    (2.82)     0.66 (527)
    Netback (1)              49.70     42.09     18     50.56     42.70   18

    (1) Funds flow from operations, payout ratio, net debt and netback as
        presented do not have any standardized meaning prescribed by
        International Financial Reporting Standards ("IFRS") and, therefore,
        may not be comparable with the calculation of similar measures
        presented by other entities. Please refer to the Non-GAAP Financial

 Measures section of this press release.
    (2) The per share amounts (with the exception of per share dividends) are

 the per share - diluted amounts.
    (3) Net income for the three and nine month periods ended September 30,
        2011, includes unrealized derivative gains of $302.6 million and
        $265.1 million, respectively. Net income for the three and nine month
        periods ended September 30, 2010, includes unrealized derivative
        losses of $80.9 million and unrealized derivative gains of $8.2

million, respectively.
    (4) Payout ratio is calculated as dividends paid or declared (including
        the value of dividends issued pursuant to the Company's dividend

 reinvestment plan) divided by funds flow from operations.
    (5) Net debt includes long-term debt, working capital and long-term
        investments, but excludes derivative asset, derivative liability and
        unrealized foreign exchange on translation of US dollar senior

 guaranteed notes.
    (6) Capital acquisitions represent total consideration for the
        transactions, including long-term debt and working capital assumed,

 and exclude transaction costs.
    (7) The average selling prices reported are before realized derivatives

 and transportation charges.
<end_table>

HIGHLIGHTS

In third quarter 2011, Crescent Point continued to execute its integrated
business strategy of acquiring, exploiting and developing high-quality,
long-life light and medium oil and natural gas properties.

• Crescent Point grew third quarter 2011 production by 9 percent over second quarter 2011 and 10 percent over third quarter 2010. The Company produced an average of 72,258 boe/d, weighted 90 percent to light and medium crude oil. Current production exceeds 76,500 boe/d and the Company remains on track to achieve exit production guidance of 77,500 boe/d.
• During third quarter, Crescent Point spent a record $279.5 million on drilling and completions, drilling a record 164 (116.5 net) oil wells and 2 (2.0 net) service wells with a 100 percent success rate. Crescent Point also spent $70.2 million on land and facilities, for total capital expenditures of $349.7 million.
• Crescent Point’s funds flow from operations increased by 32 percent to $303.3 million ($1.09 per share - diluted) in third quarter 2011, compared to $230.4 million ($0.91 per share - diluted) in third quarter 2010.
• During the quarter, Crescent Point maintained consistent monthly dividends of $0.23 per share, totaling $0.69 per share for third quarter 2011. This is unchanged from $0.69 per share paid in third quarter 2010. On an annualized basis, the third quarter dividend equates to a yield of 6.6 percent, based on a volume weighted average quarterly share price of $41.55.
• On July 14, 2011, Crescent Point announced its land position in Alberta’s emerging Beaverhill Lake light oil resource play. Drilling results to date in the play have exceeded the Company’s expectations, with production hitting more than 2,000 boe/d by the end of third quarter from zero at the beginning of the year. There are currently six non-operated drilling rigs running on working interest lands and operators plan to add two more rigs for the remainder of the year. The Company has accumulated more than 380 (165 net) sections of land highly prospective for the Beaverhill Lake zone in the Swan Hills area, as well as approximately 19 percent of the issued and outstanding common shares of a leading Beaverhill Lake producer, Arcan Resources Ltd. (”Arcan”).
• Crescent Point grew production from the Shaunavon area to more than 9,900 boe/d by the end of third quarter, an increase of more than 2,600 boe/d. The increase was a result of the announced reallocation of a portion of planned capital spending to the Shaunavon area from the Viewfield Bakken play due to the prolonged spring break-up and unusual flooding conditions in southeast Saskatchewan, which demonstrates the depth of the Company’s drilling inventory and the flexibility of its operations. Production growth in the Shaunavon area continues to be strong, with current levels at more than 11,000 boe/d.
• On August 31, 2011, the Company announced the acquisition of approximately 750 boe/d of production and more than 78 net sections of land in North Dakota, U.S., through two strategic acquisitions. Crescent Point believes the land to be prospective for the lower-risk Bakken and Three Forks zones.
• Also on August 31, 2011, Crescent Point announced a $50 million increase to its 2011 capital expenditures budget, to $1.05 billion from $1.0 billion, as well as an increase in its 2011 exit production rate, to 77,500 boe/d from 76,500 boe/d. The Company also announced a $375 million bought deal financing with an over-allotment option for its underwriters. Including the over-allotment option, a total of 9,025,000 Crescent Point shares were issued pursuant to the financing at a price of $43.50, for total gross proceeds of $392.6 million.
• The Company’s balance sheet remains strong, with projected average net debt to 12-month cash flow of less than 1.0 times and approximately $1.1 billion unutilized on its bank lines as at September 30, 2011.
• Crescent Point continues to implement its disciplined hedging strategy to provide increased certainty over cash flow and dividends. As of November 8, 2011, the Company had hedged 55 percent, 56 percent, 43 percent and 23 percent of production, net of royalty interest, for the balance of 2011, 2012, 2013 and 2014, respectively. Average quarterly hedge prices range from Cdn$84 per boe to Cdn$97 per boe. The Company also initiated its first quarter 2015 hedge position, with nine percent of production hedged at approximately Cdn$93 per boe.

OPERATIONS REVIEW

Third Quarter Operations Summary

During third quarter 2011, Crescent Point continued to implement management's
business strategy of creating sustainable, value-added growth in reserves,
production and cash flow through acquiring, exploiting and developing
high-quality, long-life light and medium oil and natural gas properties.

Crescent Point achieved average production of 72,258 boe/d in third quarter,
weighted 90 percent to light and medium crude oil. The Company remains on track
to achieve annual guidance of 72,500 boe/d and its upwardly revised 2011 exit
production rate of 77,500 boe/d. Current production exceeds 76,500 boe/d.

After a prolonged spring break-up due to unusual flooding in western Canada,
capital development activities resumed in early July. During third quarter, the
Company spent a record $279.5 million on drilling and completions, drilling 164
(116.5 net) oil wells and 2 (2.0 net) service wells with a 100 percent success
rate. Crescent Point also spent $70.2 million on land and facilities, for total
capital expenditures of $349.7 million during the quarter.

Drilling Results

The following tables summarize our drilling results for the three and nine
months ended September 30, 2011:

    Three months
    ended
    September 30,                                                          %
    2011            Gas  Oil  D&A  Service  Standing  Total   Net    Success
    Southeast
    Saskatchewan
    and Manitoba     -   55    -      2        -       57    43.0      100
    Southwest
    Saskatchewan     -   78    -      -        -       78    58.7      100
    South/Central
    Alberta          -   22    -      -        -       22    13.3      100
    Northeast BC
    and Peace River
    Arch, Alberta    -    2    -      -        -        2     1.4      100
    United States(1) -    7    -      -        -        7     2.1      100
    Total            -  164    -      2        -      166   118.5      100

    Nine months
    ended
    September 30,                                                         %
    2011            Gas  Oil  D&A  Service   Standing  Total   Net   Success
    Southeast
    Saskatchewan
    and Manitoba     -   159   -      2        -       161    127.1     100
    Southwest
    Saskatchewan     -   126   -      -        -       126     89.6     100
    South/Central
    Alberta          -    30   -      -        -        30     16.9     100
    Northeast BC
    and Peace River
    Arch, Alberta    -    4    -      -        -         4      2.7     100
    United States(1) -   16    -      -        -        16      3.4     100
    Total            -  335    -      2        -       337    239.7     100

    (1) The net well count is subject to final working interest determination.

Southeast Saskatchewan and Manitoba

In response to severe flooding in second quarter in southeast Saskatchewan,
Crescent Point reallocated a portion of planned 2011 capital spending from the
Viewfield Bakken play to the Shaunavon area in southwest Saskatchewan. The
Company reduced its 2011 drilling expectations in southeast Saskatchewan by
approximately 60 net wells, primarily in the Viewfield Bakken resource play.
Since then, weather conditions have significantly improved, allowing for
increased access and accelerated drilling. Production in the Viewfield Bakken
play grew by more than 4,400 boe/d by the end of third quarter. If conditions
remain favourable, Crescent Point may exceed its current 2011 capital
expenditures budget for the area. These drilling activities would position the
Company to exceed its current exit production guidance for 2011 and allow for an
early start to the 2012 capital program.

During third quarter 2011, Crescent Point participated in the drilling of 55
(41.0 net) oil wells and 2 (2.0 net) service wells in southeast Saskatchewan and
southwest Manitoba, achieving a 100 percent success rate. Of the oil wells
drilled, 37 (31.7 net) were horizontal wells in the Viewfield Bakken light oil
resource play, 2 (2.0 net) were Flat Lake horizontal wells, 10 (5.5 net) were
conventional horizontal wells in southeast Saskatchewan and 4 (1.0 net) were in
Manitoba.

Production performance from water injection patterns in the Viewfield Bakken
resource play continues to exceed the Company's expectations and has
demonstrated the applicability of water flood to the play. To date, the Company
has converted 18 wells to injection wells in the Bakken play. Crescent Point now
has more than 12 months of history on 11 injection wells across five different
areas of the play. Each one has demonstrated positive water flood response in
offsetting producer wells. Based on promising results from nearly three years of
production in the Company's first Bakken water flood pilot, Crescent Point
believes that water flood implementation could increase ultimate recovery
factors to greater than 30 percent from an expected 19 percent on primary
recovery. Preliminary meetings with partners to unitize a portion of the centre
of the play are underway. The Company will continue to develop the water flood
program and anticipates having more than 50 injection wells in the Viewfield
Bakken play by year end 2012.

Expansion of the Viewfield gas plant, to 30 mmcf/d from 21 mmcf/d, was
completed and brought on line during third quarter. In addition, more than 90
kilometres of pipeline were constructed.

Southwest Saskatchewan

In response to the unusual flooding experienced in southeast Saskatchewan
during second quarter, Crescent Point reallocated a portion of planned capital
spending from the Viewfield Bakken play to the Shaunavon area in southwest
Saskatchewan where surface conditions were more favourable. As a result,
production grew to more than 9,900 boe/d by the end of third quarter, an
increase of more than 2,600 boe/d. Production growth in the Shaunavon area
continues to be strong, with current levels at more than 11,000 boe/d.

During third quarter, the Company participated in the drilling of 78 (58.7
net) oil wells in southwest Saskatchewan, of which 34 (32.6 net) were Lower
Shaunavon wells and 8 (6.1 net) were Upper Shaunavon wells, achieving a 100
percent success rate. To the end of third quarter, the Company has drilled 89
(69.4 net) wells in the Shaunavon area. In total, Crescent Point has budgeted to
drill 114 (86 net) wells in the Shaunavon area during 2011, compared to original
plans to drill 44 net wells.

The Company is currently injecting water into six horizontal injection wells
in four pressure maintenance programs in the Lower Shaunavon zone. Crescent
Point is encouraged by results to date. Plans to convert up to 3 wells in the
Upper Shaunavon zone to water injection wells in 2012 are also underway.

Crescent Point continued to focus on adding infrastructure in the Shaunavon
area. The Company has commenced construction of a 6 mmcf/d gas plant, which is
designed to be expandable to12 mmcf/d. The plant is expected to be operational
by early 2012. During third quarter, more than 50 kilometres of pipeline were
constructed. Plans to design and construct an additional battery in 2012 to
accommodate increased production have commenced. Operating costs are expected to
be reduced with the infrastructure development.

The Company drilled 23 (14.0 net) horizontal oil wells, of a planned 26 wells
for the Viking area in 2011. The remaining 3 (1.5 net) wells were drilled in
early fourth quarter. As of the end of third quarter, 11 of the wells had been
fracture stimulated and are expected to be put on production during fourth
quarter 2011. Construction of a battery to accommodate increased production and
future development began in fourth quarter 2011.

At Battrum/Cantuar, the Company participated in the drilling of 13 (6.0 net)
oil wells, achieving a 100 percent success rate. Overall production remains
steady, with minimal capital required to maintain the area's production
rates.

Alberta

Due to the Company's positive results to date in the Swan Hills Beaverhill
Lake light oil resource play and the flooding in southeast Saskatchewan during
second quarter, Crescent Point reallocated a portion of its planned 2011 capital
spending from the Viewfield Bakken to the Swan Hills area.

During third quarter, 22 (13.3 net) oil wells were drilled, including 12 (4.5
net) wells in the Beaverhill Lake light oil resource play. As of the end of
third quarter, the Company has participated in a total of 19 (7.1 net)
successful wells in the Beaverhill Lake play and has plans to participate in up
to 44 (18.8 net) wells in 2011. There are currently six non-operated drilling
rigs running on working interest lands. Operators plan to add two more rigs for
the remainder of the year.

As of the end of third quarter, 16 (5.9 net) wells have been placed on stream
in the Swan Hills area, with 13 (4.9 net) of those wells on stream for more than
30 days. The average initial 30-day rate for those wells exceeds 750 boe/d.
Initial results from the wells have exceeded the Company's expectations, with
organic production growth from zero to over 2,000 boe/d by the end of third
quarter.

Crescent Point has access to more than one million net acres of undeveloped
land in southern Alberta and has been pursuing several exploration projects in
the area. During third quarter, the Company participated in the drilling of 10
(8.8 net) conventional oil wells, of which 6 (4.9 net) were horizontal oil wells
in various zones. During fourth quarter 2011, the Company plans to drill 2.0 net
wells to follow up on previously drilled unconventional exploration wells in the
Alberta Bakken play, for a total of 3.0 net wells in 2011.

United States

On August 31, 2011, the Company announced the acquisition of approximately
750 boe/d of production and more than 78 net sections of land in North Dakota,
U.S., through two strategic acquisitions. Crescent Point has now accumulated
more than 165 net sections of land in the state.

During third quarter, the Company participated in the drilling of 7 (2.1 net)
oil wells, of which 2 (1.3 net) were operated, achieving a 100 percent success
rate. The two operated wells are expected to be completed by early 2012, as part
of Crescent Point's two-year service agreement with a leading U.S. fracture
stimulation company. The Company expects to participate in drilling up to 10 net
wells in 2011, including 4 gross operated wells.

OUTLOOK

Crescent Point continues to execute its business plan of creating sustainable
value-added growth in reserves, production and cash flow through management's
integrated strategy of acquiring, exploiting and developing high-quality,
long-life light and medium oil and natural gas properties in United States and
Canada.

Crescent Point delivered strong operational and financial results and
executed a record development program in third quarter 2011. Crescent Point
remains on track to achieve annual guidance of 72,500 boe/d and its 2011 exit
production rate of 77,500 boe/d. Current production exceeds 76,500 boe/d.

The Company successfully executed a reallocation of a portion of its planned
capital spending from the Viewfield Bakken play to the Shaunavon and Beaverhill
Lake areas, resulting in strong production growth in both areas and
demonstrating the depth of its drilling inventory opportunities and flexibility
of its operations. Improved conditions in southeast Saskatchewan have also
allowed for increased drilling activities. Assuming weather conditions continue
to be favourable in southeast Saskatchewan, Crescent Point may exceed its 2011
capital budget expectations due to increased drilling in the Viewfield Bakken
play and strong growth in the Shaunavon area. The majority of the increased
drilling would be completed in fourth quarter, which would position the Company
to exceed its 2011 exit production forecast, and would provide an early start to
the Company's 2012 capital program. Water tables in southeast Saskatchewan
remain high despite the dry weather, so the Company is again planning for a
prolonged, three-month spring break-up in 2012. Crescent Point expects to
release its 2012 budget plans in early December, along with an update on its
2011 capital expenditures and production expectations.

The Company expects 2011 annual funds flow from operations to be $1.21
billion ($4.36 per share - diluted), based on US$94.00/bbl WTI, Cdn$3.70/mcf
AECO and a US$/Cdn$1.01 exchange rate.

Crescent Point has more than 6,500 net low-risk drilling locations in
inventory in four large resource plays, representing more than 450,000 boe/d of
risked potential production additions. This depth of drilling inventory
positions the Company well for long-term sustainable growth in production,
reserves and net asset value, and also provides support for dividends over the
long term.

The Company's balance sheet remains strong, with projected average net debt
to 12-month cash flow of less than 1.0 times and approximately $1.1 billion
unutilized on its bank lines as at September 30, 2011.

Crescent Point continues to implement its balanced 3½-year price risk
management program, using a combination of swaps, collars and purchased put
options with investment-grade counterparties. As of November 8, 2011, the
Company had hedged 55 percent, 56 percent, 43 percent and 23 percent of
production, net of royalty interest, for the balance of 2011, 2012, 2013 and
2014, respectively. Average quarterly hedge prices range from Cdn$84 per boe to
Cdn$97 per boe. The Company also initiated its first quarter 2015 hedge
position, with nine percent of production hedged at approximately Cdn$93 per
boe.

Crescent Point's management believes that with the Company's high-quality
reserve base and development drilling inventory, excellent balance sheet and
solid risk management program, the Company is well-positioned to continue
generating strong operating and financial results.

2011 Guidance

Crescent Point's 2011 guidance is as follows:

    Production
      Oil and NGL (bbls/d)                       65,375
      Natural gas (mcf/d)                        42,750
    Total (boe/d)                                72,500
    Exit (boe/d)                                 77,500
    Funds flow from operations ($000)         1,210,000
    Funds flow per share - diluted ($)             4.36
    Cash dividends per share ($)                   2.76
    Capital expenditures ($000) (1)           1,050,000
    Wells drilled, net                              312
    Pricing
      Crude oil - WTI (US$/bbl)                   94.00
      Crude oil - WTI (Cdn$/bbl)                  93.07
      Natural gas - Corporate (Cdn$/mcf)           3.70
      Exchange rate (US$/Cdn$)                     1.01

(1) The projection of capital expenditures excludes acquisitions, which are
separately considered and evaluated.

ON BEHALF OF THE BOARD OF DIRECTORS

(signed)

Scott Saxberg
President and Chief Executive Officer
November 10,
2011

Non-GAAP Financial Measures

Throughout this press release, the Company uses
the terms "funds flow from operations", "funds flow from operations per share -
diluted", "net debt", "netback", "payout ratio" and "payout ratio per share -
diluted." These terms do not have any standardized meaning as prescribed by IFRS
and, therefore, may not be comparable with the calculation of similar measures
presented by other issuers.

Funds flow from operations is calculated based on
cash flow from operating activities before changes in non-cash working capital,
transaction costs and decommissioning expenditures. Funds flow from operations
per share - diluted is calculated based on cash flow from operating activities
before changes in non-cash working capital, transaction costs and
decommissioning expenditures. Management utilizes funds flow from operations as
a key measure to assess the ability of the Company to finance dividends,
operating activities, capital expenditures and debt repayments. Funds flow from
operations as presented is not intended to represent cash flow from operating
activities, net earnings or other measures of financial performance calculated
in accordance with IFRS.

The following table reconciles the cash flow from
operating activities to funds flow from operations:

              Three months ended September 30  Nine months ended September 30
    ($000s)         2011      2010  % Change      2011     2010   % Change
    Cash flow from
      operating
      activities  309,622    204,583      51    936,695   580,990     61
    Changes in
      non-cash
      working
      capital      (7,679)    24,480    (131)   (30,248)   29,075   (204)
    Transaction
    costs             721        951     (24)     2,488     8,062    (69)
    Decommissioning
    expenditures      651        410      59      2,400     1,514     59
    Funds flow from
    operations    303,315    230,424      32    911,335   619,641     47

Net debt is calculated as current liabilities plus
long-term debt less current assets and long-term investments, but excludes
derivative asset, derivative liability and unrealized foreign exchange on
translation of US dollar senior guaranteed notes. Management utilizes net debt
as a key measure to assess the liquidity of the Company.

The following table reconciles long-term debt to
net debt:

                                     As at September 30
    ($000s)                        2011    2010    % Change
    Long-term debt              996,881    1,214,705    -18
    Current liabilities         482,999      357,110     35
    Current assets             -310,701     -171,755     81
    Long-term investments      -122,967      -46,161    166

    Excludes:
      Derivative asset           51,139      14,110     262
      Derivative liability       -7,230     -25,079     -71
      Unrealized foreign
       exchange on
       translation of US
       dollar senior
       guaranteed notes         -17,506      -2,734     540
    Net debt                  1,072,615   1,340,196     -20

Netback is calculated on a per boe basis as oil
and gas sales, less royalties, operating and transportation expenses and
realized derivative gains and losses. Netback is used by management to measure
operating results on a per boe basis to better analyze performance against prior
periods on a comparable basis.

Payout ratio and payout ratio per share - diluted
are calculated on a percentage basis as dividends paid or declared (including
the value of dividends issued pursuant to the Company's dividend reinvestment
plan) divided by funds flow from operations. Payout ratio is used by management
to monitor the dividend policy and the amount of funds flow from operations
retained by the Company for capital reinvestment.

Forward-Looking Statements

Certain statements contained in this press release constitute forward-looking
statements. All forward-looking statements are based on Crescent Point's beliefs
and assumptions based on information available at the time the assumption was
made. The use of any of the words "could", "should", "can", "anticipate",
"expect", "believe", "will", "may", "projected", "sustain", "continues",
"strategy", "potential", "projects", "grow", "take advantage", "estimate",
"well-positioned" and similar expressions are intended to identify
forward-looking statements. By their nature, such forward-looking statements
involve known and unknown risks, uncertainties and other factors that may cause
actual results or events to differ materially from those anticipated in such
forward-looking statements. Crescent Point believes that the expectations
reflected in those forward-looking statements are reasonable but no assurance
can be given that these expectations will prove to be correct and such
forward-looking statements included in this report should not be unduly relied
upon. These statements speak only as of the date of this press release or, if
applicable, as of the date specified in those documents specifically referenced
herein.

In particular, this press release contains forward-looking statements
pertaining to the following: the performance characteristics of Crescent Point's
oil and natural gas properties; oil and natural gas production levels; capital
expenditure programs; drilling programs; well conversion and water injection
programs; the quantity of Crescent Point's oil and natural gas reserves and
anticipated future cash flows from such reserves; the quantity of drilling
locations in inventory; projections of commodity prices and costs; supply and
demand for oil and natural gas; expectations regarding the ability to raise
capital and to continually add to reserves through acquisitions and development;
expected debt levels and credit facilities; expected pipeline capacity
additions; facility construction plans; and treatment under governmental
regulatory regimes.

By their nature, such forward-looking statements are subject to a number of
risks, uncertainties and assumptions, which could cause actual results or other
expectations to differ materially from those anticipated, including those
material risks discussed in our annual information form under "Risk Factors" and
our Management's Discussion and Analysis for the year ended December 31, 2010,
under the headings "Risk Factors" and "Forward-Looking Information." The
material assumptions are disclosed in the Management's Discussion and Analysis
for the year ended December 31, 2010, under the headings "Dividends", "Capital
Expenditures", "Asset Retirement Obligation", "Liquidity and Capital Resources",
"Critical Accounting Estimates", "New Accounting Pronouncements" and "Outlook",
and in Management's Discussion and Analysis for the period ended September 30,
2011, under the headings "Dividends", "Capital Expenditures", "Decommissioning
Liability", "Liquidity and Capital Resources", "Critical Accounting Estimates"
and "Outlook". The actual results could differ materially from those anticipated
in these forward-looking statements as a result of the material risks set forth
under the noted headings, which include, but are not limited to: financial risk
of marketing reserves at an acceptable price given market conditions; volatility
in market prices for oil and natural gas; delays in business operations,
pipeline restrictions, blowouts; the risk of carrying out operations with
minimal environmental impact; industry conditions including changes in laws and
regulations including the adoption of new environmental laws and regulations and
changes in how they are interpreted and enforced; uncertainties associated with
estimating oil and natural gas reserves and Discovered Petroleum Initially in
Place; economic risk of finding and producing reserves at a reasonable cost;
uncertainties associated with partner plans and approvals; operational matters
related to non-operated properties; increased competition for, among other
things, capital, acquisitions of reserves and undeveloped lands; competition for
and availability of qualified personnel or management; incorrect assessments of
the value of acquisitions and exploration and development programs; unexpected
geological, technical, drilling, construction and processing problems;
availability of insurance; fluctuations in foreign exchange and interest rates;
stock market volatility; failure to realize the anticipated benefits of
acquisitions; general economic, market and business conditions; uncertainties
associated with regulatory approvals; uncertainty of government policy changes;
uncertainties associated with credit facilities and counterparty credit risk;
and changes in income tax laws, tax laws, crown royalty rates and incentive
programs relating to the oil and gas industry.

A barrel of oil equivalent ("boe") is based on a conversion rate of six
thousand cubic feet of natural gas to one barrel of oil.

Additional information on these and other factors that could affect Crescent
Point's operations or financial results are included in Crescent Point's reports
on file with Canadian securities regulatory authorities. Readers are cautioned
not to place undue reliance on this forward-looking information, which is given
as of the date it is expressed herein or otherwise and Crescent Point undertakes
no obligation to update publicly or revise any forward-looking information,
whether as a result of new information, future events or otherwise, unless
required to do so pursuant to applicable law.

Crescent Point is a conventional oil and gas producer with assets
strategically focused in properties comprised of high-quality, long-life,
operated light and medium oil and natural gas reserves in United States and
Canada.  

For further information:

ON CRESCENT POINT ENERGY CORP. PLEASE CONTACT:

Greg Tisdale, Chief Financial Officer, or Trent Stangl, Vice President
Marketing and Investor Relations.

Telephone: +1(403)693-0020
Toll-free (US & Canada):
888-693-0020
Fax: +1(403)693-0070
Website: www.crescentpointenergy.com
ir@crescentpointenergy.com 

Crescent Point shares are traded on the Toronto
Stock Exchange under the symbol CPG.

Crescent Point Energy Corp.
Suite 2800, 111-5th
Avenue S.W.
Calgary, Alberta T2P
3Y6

.