Frontera Announces Third Quarter 2017 Results

Continued Focus on Value over Volumes
Cash Generated by Operating Activities: $110 million, Cash Used in Investing Activities: $41 million

TORONTO, Nov. 13, 2017 /PRNewswire/ - Frontera Energy Corporation (TSX: FEC) ("Frontera" or the "Company") announced today the release of its interim condensed consolidated financial statements for the third quarter of 2017, together with its management discussion and analysis ("MD&A"). These documents will be posted on the Company's website at www.fronteraenergy.ca and SEDAR at www.sedar.com. The financial information contained herein is reported in United States dollars and is in accordance with International Financial Reporting Standards ("IFRS") as issued by the International Accounting Standards Board, unless otherwise noted.

THIRD QUARTER 2017 HIGHLIGHTS AND OPERATIONAL UPDATE

Operational:

    --  Q3 production, after royalties and internal consumption, of 71,068 boe/d
        was essentially flat with Q2 production of 72,370 boe/d. The slight
        decrease quarter over quarter was due to the impact of maintenance
        downtime related to the La Creciente natural gas field, and the impact
        of reduced spending on our Colombian assets thus far in 2017.
    --  Production growth continued in Peru, where light and medium oil
        production grew 39% in Q3 compared to Q2, however, Block 192 was subject
        to an indigenous blockade on September 18, 2017. Although the blockade
        has been lifted, production has not yet resumed, and the Company is
        currently evaluating the status of the assets within the block and is
        working with the local indigenous groups and the Peruvian government to
        ensure a safe and efficient re-start of production.
    --  Completed drilling of the Alligator 1x exploration well on the Guatiquia
        Block in the Llanos basin, the first exploration well for the Company in
        over two years. The well encountered three potential productive zones
        that will each be evaluated for testing in the fourth quarter of 2017.
    --  Initial results since implementing new best practices have yielded
        encouraging results with initial oil production rates at Quifa of ~235
        bbl/d (compared to historic results of ~150 bbl/d) and average water
        cuts of ~56% (compared to historic results of ~96%), on 9 wells drilled
        in September and October.
    --  The Company will be implementing a pressure maintenance project on the
        Copa field during the fourth quarter of 2017 with a further five fields
        to be placed under water flood in the next 12 months. These projects in
        addition to the start of wells with dual zone completions and
        multilateral drilling opportunities are all projects that have been
        implemented following the detailed reservoir review study undertaken
        earlier this year.
    --  The Company drilled 24 development wells and four workover wells in
        Colombia during Q3 with a further 35-45 development wells targeted in
        Q4. The Company currently has 10 drilling rigs running throughout its
        portfolio of assets in Colombia.
    --  Recent agreements to acquire Pacific Midstream Limited ("PML"), and sale
        of Petroelectrica de los Llanos ("PEL"), are the first two steps in a
        series of transactions targeted to improve transportation costs by ~$100
        million per year and reduce existing pipeline commitments.

Financial:

    --  Sales increased 3% to $307.1 million in Q3 compared with $299.5 million
        in Q2 due primarily to higher realized oil prices. Net loss of $141.1
        million was up 174% in Q3 compared to a loss of $51.5 million in Q2 due
        primarily to one off asset impairment charges.
    --  Operating EBITDA for Q3 was $105.9 million representing an increase of
        22% from the $86.9 million reported in Q2.
    --  The Company increased the midpoint of Operating EBITDA guidance by 13%
        to $300 to $350 million, while maintaining previous exit rate production
        and capital spending guidance of 70,000 to 75,000 boe/d and $250 to $300
        million respectively.
    --  Adjusted Funds Flow from Operations ("Adjusted FFO") was $47.9 million
        in Q3, up 4% from $46.2 million in Q2 as a result of higher oil prices
        and continued focus on cost control.
    --  Total capital expenditures increased to $48.6 million in Q3, compared to
        $37.8 million in Q2.
    --  Strong balance sheet with $599.9 million of total cash, cash equivalents
        and restricted cash. Cash and cash equivalents of $500.6 million, and
        only $250.0 million of total long-term debt.
    --  Operating Netback was $23.54/boe in Q3, an increase of 16%
        quarter-over-quarter compared to $20.31/boe in Q2, mainly due to strong
        realized pricing and lower total operating costs.
    --  Total operating costs (including production, royalties paid in cash,
        transportation, and diluent costs) averaged $24.32/boe in Q3, an
        improvement of 6% quarter over quarter compared to $25.97/boe in Q2. The
        largest driver of lower total operating costs was lower transportation
        costs, which improved 17% quarter over quarter to $11.77/boe in Q3 from
        $14.19/boe in Q2. The lower transportation costs were a result of two
        payments, the first from the reversal of the Bicentenario pipeline while
        the Caño Limón pipeline was offline, and the second due to cost
        recoveries from Puerto Bahia. Lower operational transportation costs
        were also a result of higher than expected downtime on the Caño Limón
        and Bicentenario pipeline systems in Q3, with 75 days off line compared
        to 48 days in Q2. When the Caño Limón and Bicentenario pipelines are
        off line lower cost transportation cost options were realized while take
        or pay fees are recognized as a separate line item outside of direct
        operating costs.
    --  G&A costs were essentially in line quarter over quarter at $4.06/boe in
        Q3 versus $3.96/boe in Q2.
    --  On November 2, 2017, Fitch upgraded the Company's Long Term Foreign and
        Local Currency Issuer Default Ratings, to B+ from B and the $250 million
        of senior secured notes to BB-/RR3 from B+/RR3, with a stable rating
        outlook.
    --  Strong hedging position with over 50% of production hedged with an
        average floor price over $51 per barrel Brent for the next 11 months.

Barry Larson, Chief Executive Officer of the Company, commented:

"Earlier this year Frontera undertook a comprehensive reservoir optimization and technical review of its producing assets. During the third quarter, these studies have begun to exhibit successful results. Additional value creating operational practices including pressure maintenance projects, dual completions and multi-lateral field development will be implemented over the next twelve months.

Planning and preparation for the Company's major exploration well on the Llanos 25 block continues, as the Company is currently bidding to secure the rig that will be used to spud its Acorazado-1 prospect in the first quarter of 2018. The expected cost for the initial well is estimated between $35 million and $50 million.

Looking forward, additional potential positive catalysts to unlock shareholder value include contract renegotiations, continued non-core asset dispositions, exploration drilling success, and continued cost control. We are excited to continue to implement strategic initiatives and undertake material exploration drilling designed to drive long term growth and unlock latent value."

Production:


    Net Production Summary
    ----------------------

                                                       2017                 2016
                                                       ----                 ----

                                                Q3                     Q2        Q1        Q4        Q3

    Oil and Liquids (bbl/d)

    Colombia                                         58,836               61,535    62,180    60,150    64,946

    Peru                                              6,805                4,913     3,855     2,079     2,182
    ----                                              -----                -----     -----     -----     -----

    Total Oil and
     Liquids (bbl/
     d)                                              65,641               66,448    66,035    62,229    67,128
    --------------                                   ------               ------    ------    ------    ------

    Natural Gas (boe/d)(1)

    Colombia                                          5,427                5,922     6,489     7,203     7,968

    Total Natural
     Gas (boe/d)                                      5,427                5,922     6,489     7,203     7,968
    -------------                                     -----                -----     -----     -----     -----

    Total Equivalent
     Production
     (boe/d)                                         71,068               72,370    72,524    69,432    75,096
    ----------------                                 ------               ------    ------    ------    ------

    (1) Colombian standard natural gas conversion ratio of 5.7 Mcf/bbl.

    Additional production details are available in the MD&A.

Financial Results:


                                        2017        2016
                                        ----        ----

                                 Q3          Q2          Q3

    Total Sales ($ millions)           307.1       299.5             308.7

    Operating EBITDA ($
     millions)(1)                      105.9        86.9              89.8

    Operating EBITDA Margin
     (Operating EBITDA/
     Revenues)(1)                        34%        29%              29%

    Adjusted EBITDA ($
     millions)(1)                       44.2        87.4              37.7

    Adjusted EBITDA margin
     (Adjusted EBITDA/
     revenues)(1)                        14%        29%              12%

    Adjusted FFO ($ millions)(1)        47.9        46.2              43.0

    Net Loss ($ millions)(2)         (141.1)     (51.5)          (557.1)

    Per share - basic ($)(3)          (2.82)     (1.03)     (176,835.08)

    Total Production (boe/d)          71,068      72,370            75,096

    Sales Volumes (boe/d)             63,162      64,908            81,877

    Average Shares Outstanding -
     basic (thousands)              50,005.8    50,005.8               3.2
    ----------------------------    --------    --------               ---

    (1) These metrics are Non-IFRS
     financial measures. See
     Advisories - "Non-IFRS
     Financial Measures" - below
     and "Non-IFRS Measures" on
     page 17 of the MD&A.

    (2) Net loss attributable to
     equity holders of the parent.

    (3) The basic and diluted
     weighted average numbers of
     common shares for the three
     months ended September 30, 2017
     and 2016 were 50,005,832 and
     3,150, respectively.

Strategic Initiatives:

    --  On October 13, 2017, the Company signed an agreement to acquire the
        outstanding 36.4% ownership of PML from the International Finance
        Corporation and from funds related to the International Finance
        Corporation (jointly, the "IFC Parties"). Following the acquisition, the
        Company will own 100% of PML which will enable the Company to pursue
        initiatives related to the reduction of, and unwinding of, various
        transportation commitments, including fixed rate take-or-pay
        arrangements. The acquisition consideration will be $225 million in
        cash, paid in instalments over a 36-month period, plus accrued interest
        over unpaid amounts. The completion of the transaction is subject to
        obtaining modifications to certain take-or-pay contracts entered into by
        Frontera, which are expected to reduce tariffs, and other customary
        conditions of closing. In addition, the consent of the Company's
        noteholders and secured lenders is required to complete the transaction.
    --  On October 25, 2017, the Company entered into an agreement to sell its
        interest in PEL to an affiliate of Electricas de Medellin - Ingenieria y
        S.A.S., for cash consideration of $56 million, of which $50 million will
        be used as the first payment to the IFC Parties in connection with the
        purchase of the IFC Parties' common shares of PML.
    --  The Company is currently undergoing an optimization of its
        organizational structure in an effort to streamline its operations and
        eliminate legal entity redundancies. In the third quarter, the Company
        initiated its first merger, of a series of mergers, and as of the date
        hereof, the Company is in a process of consolidating the four legal
        entities that hold its Colombian operational assets into one entity.
    --  During the third quarter 2017, Itau BBA S.A. released the outstanding
        standby letter of credit, related to the transfer of the Company's
        interest in three offshore blocks in Brazil to Queiroz Galvão
        Exploração e Produção S.A., reducing Frontera's credit exposure by
        $42.5 million.

Asset Sales:

During the third quarter of 2017, the Company continued to monetize non-core assets. Below is a summary of all the non-core asset sales of exploration and production blocks executed within the past 12 months; many are pending final government approvals:



    Assets Divested ($
     millions)                                     Cash Proceeds        Commitments(1)       SBLC / Collateral(2)
    ------------------                             -------------         -------------       --------------------

    Brazil Exploration
     Blocks                                                         5.5                 76.4                      42.5

    Colombia Exploration
     Blocks(3,4)                                                   11.2                 34.3                       5.4

    Colombia Production
     Blocks(5)                                                      2.1                 12.9                       0.8

    Peru Exploration
     Blocks(4)                                                     17.3                 22.7                       2.8

    Papua New Guinea(4)                                            57.0                    -                        -

    Petroelectrica de
     los Llanos(4)                                                 56.0                    -                        -
    -----------------                                              ----                  ---                      ---

    Total Divestments                                             149.1                146.3                      51.5
    -----------------                                             -----                -----                      ----

    (1) Includes Exploration, Abandonment and Environmental Costs

    (2) Standby Letter of Credit and Released Collateral

    (3) Includes Major lands, Putumayo Basin and San Jacinto 7 block

    (4) Agreements have been signed, subject to closing

    (5) Includes Casanare Este and Cerrito

Take-or-Pay Reduction Initiative:

    --  Frontera continues to create value through the execution of strategic
        initiatives, including the recently announced agreement to acquire the
        outstanding 36.4% ownership of PML for $225 million (bringing our
        ownership of PML to 100%), and the subsequent sale of PEL for proceeds
        of $56 million.
    --  These initiatives are part of a series of strategic transactions
        intended to reduce our transportation costs by eliminating certain
        take-or-pay commitments and is ultimately expected to decrease our
        annual transportation costs by over $100 million.

Updated 2017 Guidance and Fourth Quarter 2017 Outlook:

Due to operational improvements and higher realized oil prices, Frontera is raising its guidance for 2017 Operating EBITDA for the second time this year to $300 to $350 million - representing a 13% increase from the midpoint of previous guidance of $275 to $300 million, and a 24% increase from the midpoint of initial 2017 Operating EBITDA guidance of $250 to 275 million. Guidance for 2017 exit production and annual capital expenditures remains unchanged at 70,000 to 75,000 barrels of oil equivalent per day and $250 to $300 million, respectively. Revised guidance places Frontera's capital expenditures below Operating EBITDA for 2017. The Company's assumptions described above are dependent on a base case average Brent oil price assumption for 2017 of $53/bbl and benchmark combined price differential of between $5.50/bbl and $6.00/bbl.

With a more active drilling program in the fourth quarter of 2017, Frontera expects oil production in Colombia to increase throughout the remainder of 2017. The Company plans to drill between 35 and 45 development wells, 2 to 4 exploration wells, and continue with an active workover and recompletion program in the fourth quarter of 2017.

From a financial perspective, the Company's strong balance sheet provides financial flexibility to unlock value for shareholders as we continue to focus on Operating EBITDA expansion. Some of the initiatives being considered include: contract renegotiations, non-core asset dispositions, continued cost control, and improved financial and covenant flexibility via debt refinancing or amendments. The Company's balance sheet remains extremely strong with $599.9 million of total cash, cash equivalents and restricted cash, offset by $250.0 million of long-term debt. Frontera also enjoys a strong oil hedge book with over 50% of our production hedged at an average floor of over $51 per barrel Brent for the next 11 months.

Third Quarter 2017 Conference Call Details:

A conference call for investors and analysts is scheduled for Tuesday, November 14, 2017 at 8:30 a.m. (Calgary time) and 10:30 a.m. (Toronto / Bogotá time). Participants will include Gabriel de Alba, Chairman of the Board of Directors, Barry Larson, Chief Executive Officer, Camilo McAllister, Chief Financial Officer and select members of the senior management team.

A presentation will be available on the Company's website prior to the call, which can be accessed at www.fronteraenergy.ca.

Analysts and investors are invited to participate using the following dial-in numbers:


    Participant Number (International/Local):     (647) 427-7450

    Participant Number (Toll free Colombia):      01-800-518-0661

    Participant Number (Toll free North America): (888) 231-8191

    Conference ID:                                                9489889

Webcast: www.fronteraenergy.ca

A replay of the conference call will be available until 11:59 p.m. (Toronto / Bogotá time), Tuesday, November 28, 2017 and can be accessed using the following dial-in numbers:


    Encore Toll Free Dial-
     in Number:                1-855-859-2056

    Local Dial-in-Number:      (416)-849-0833

    Encore ID:                                  9489889

About Frontera:

Frontera is a Canadian public company and a leading explorer and producer of crude oil and natural gas, with operations focused in Latin America. The Company has a diversified portfolio of assets with interests in more than 25 exploration and production blocks in Colombia and Peru. The Company's strategy is focused on sustainable growth in production and reserves and cash generation. Frontera is committed to conducting business safely, in a socially and environmentally responsible manner.

The Company's common shares trade on the Toronto Stock Exchange under the ticker symbol "FEC".

If you would like to receive News Releases via e-mail as soon as they are published, please subscribe here: http://fronteraenergy.mediaroom.com/subscribe

Advisories:

Cautionary Note Concerning Forward-Looking Statements

This news release contains forward-looking statements. All statements, other than statements of historical fact, that address activities, events or developments that the Company believes, expects or anticipates will or may occur in the future (including, without limitation, statements regarding estimates and/or assumptions in respect of production, revenue, cash flow and costs, reserve and resource estimates, potential resources and reserves and the Company's exploration and development plans and objectives) are forward-looking statements. These forward-looking statements reflect the current expectations or beliefs of the Company based on information currently available to the Company. Forward-looking statements are subject to a number of risks and uncertainties that may cause the actual results of the Company to differ materially from those discussed in the forward-looking statements, and even if such actual results are realized or substantially realized, there can be no assurance that they will have the expected consequences to, or effects on, the Company. Factors that could cause actual results or events to differ materially from current expectations include, among other things: uncertainty of estimates of capital and operating costs, production estimates and estimated economic return; uncertainties associated with estimating oil and natural gas reserves; failure to establish estimated resources or reserves; volatility in market prices for oil and natural gas; fluctuation in currency exchange rates; inflation; changes in equity markets; perceptions of the Company's prospects and the prospects of the oil and gas industry in Colombia and the other countries where the Company operates or has investments; uncertainties relating to the availability and costs of financing needed in the future; the uncertainties involved in interpreting drilling results and other geological data; and the other risks disclosed under the heading "Risk Factors" and elsewhere in the Company's annual information form dated March 14, 2017 filed on SEDAR at www.sedar.com. Any forward-looking statement speaks only as of the date on which it is made and, except as may be required by applicable securities laws, the Company disclaims any intent or obligation to update any forward-looking statement, whether as a result of new information, future events or results or otherwise. Although the Company believes that the assumptions inherent in the forward-looking statements are reasonable, forward-looking statements are not guarantees of future performance and accordingly undue reliance should not be put on such statements due to the inherent uncertainty therein.

This news release contains future oriented financial information and financial outlook information (collectively, "FOFI") (including, without limitation, statements regarding expected capital expenditures, production levels, oil prices, and G&A), and are subject to the same assumptions, risk factors, limitations and qualifications as set forth in the above paragraph. The FOFI has been prepared by management to provide an outlook of the Company's activities and results, and such information may not be appropriate for other purposes. The Company and management believe that the FOFI has been prepared on a reasonable basis, reflecting management's best estimates and judgments, however, actual results of operations of the Company and the resulting financial results may vary from the amounts set forth herein. Any FOFI speaks only as of the date on which it is made and, except as may be required by applicable securities laws, the Company disclaims any intent or obligation to update any FOFI, whether as a result of new information, future events or results or otherwise.

In addition, reported production levels may not be reflective of sustainable production rates and future production rates may differ materially from the production rates reflected in this news release due to, among other factors, difficulties or interruptions encountered during the production of hydrocarbons.

Non-IFRS Financial Measures

This news release contains financial terms that are not considered in IFRS. These non-IFRS measures do not have any standardized meaning, and therefore are unlikely to be comparable to similar measures presented by other companies. These non-IFRS measures should not be considered in isolation or as a substitute for measures of performance prepared in accordance with IFRS. These financial measures are included because management uses this information to analyze operating performance and liquidity. They are different from those measures disclosed in prior periods, reflecting the Company's new strategic focus on operational efficiency and capital discipline.

Operating and Adjusted EBITDA

Management believes that EBITDA is a common measure used to assess profitability before the impact of different financing methods, income taxes, depreciation and impairment of capital assets and amortization of intangible assets.

    --  Operating EBITDA represents the operating results of the Company's
        primary business, excluding the effects of capital structure, other
        investments (infrastructure assets), non-cash items that depend on
        accounting policy choices, and one-time items that are not expected to
        recur.
    --  Adjusted EBITDA excludes items of a non-recurring nature (one-time
        items), or that could make the period-over-period comparison of results
        from operations less meaningful, but includes results from the Company's
        other investments (infrastructure assets).

A reconciliation of Operating and Adjusted EBITDA to net earnings is as follows:



                                                           Three Months Ended           Nine Months Ended
                                                              September 30                September 30
                                                              ------------                ------------

    (in thousands of US$)                                     2017           2016         2017             2016
    --------------------                                      ----           ----         ----             ----


    Net loss (1)                                        $(141,115)    $(557,068)  $(184,159)    $(1,576,671)


    Adjustments

                 Income tax expense                        12,134         20,381       25,703           38,953

                  Depletion, depreciation and
                  amortization                             87,802        113,802      287,184          490,285

                  Impairment and exploration
                  expenses                                 74,000        423,913       86,712        1,113,599

                 Finance costs                              7,207         22,943       18,690          124,748

                 Restructuring and severance costs          2,393         32,102       10,181           99,821

                 Equity tax                                     -             -      11,694           26,901

                 Other expense/(income)                     8,487          2,792          639         (41,628)

                 Foreign exchange unrealized gain         (6,705)      (21,176)     (9,993)        (20,422)
                 --------------------------------          ------        -------       ------          -------

    Adjusted EBITDA                                      44,203         37,689      246,651          255,586
    ---------------                                      ------         ------      -------          -------

                  (Gain) loss valuation of
                  unrealized hedge contracts               43,567         18,514      (9,012)         125,986

                  Share of gain in equity-accounted
                  investees                              (27,452)      (10,720)    (61,377)        (67,093)

                  Gain (loss) attributable to non-
                  controlling interest                     10,302        (2,304)      19,616           10,203

                 Share based compensation                     233              -         486          (8,503)

                  Foreign exchange realized loss
                  (gain)                                      194          3,635        4,646          (2,298)

                  Fees paid on suspended pipeline
                  capacity                                 34,838         43,032       84,175           86,481
                 --------------------------------          ------         ------       ------           ------

    Operating EBITDA                                   $105,885        $89,846     $285,185         $400,362
    ----------------                                   --------        -------     --------         --------

    (1) Net loss attributable to equity holders of the parent.



                            2017       2016
                            ----       ----

    (in thousands of
     US$ )           Q3           Q2        Q1           Q4          Q3         Q2           Q1
    ---------------- ---         ---        ---         ---         ---         ---          ---


    Financial and
     Operational
     results:

    Operating EBITDA     105,885     86,857      92,442      44,275      89,846      120,452     190,064


    Adjusted EBITDA       44,203     87,389     115,058     (1,967)     37,689      126,083      91,814

Netbacks

Management believes that Netback is a useful measure to assess the net profit after all the costs associated with bringing one barrel of oil to the market. It is also commonly used by the oil and gas industry to analyze financial and operating performances expressed as profit per barrel.

    --  Operating Netback represents realized price per barrel plus realized
        gain or loss on financial derivatives, less production costs, royalties
        paid in cash, transportation cost and diluent cost, and shows how
        efficient the Company is at extracting and selling its product.
    --  Adjusted Netback represents Operating Netback plus the results from
        corporate investments such as our pipeline investments that are in
        addition to oil and gas production and the take-or-pay tariffs paid on
        disrupted pipelines.
    --  Adjusted Funds Flow from Operations Netback, represents Adjusted Netback
        less corporate cash expenses (general and administrative expenses and
        cash finance costs), and other cash items (mainly includes dividends
        from associates, Frontera's share of gains or losses from
        equity-accounted investee-pipelines, current income tax, equity tax
        paid, realized foreign exchange, inventory fluctuations, overlift and
        underlift and uses of asset retirement obligations).

Adjusted Funds Flow from Operations

Management believes Adjusted FFO is a useful measure to assess operating performance and liquidity. Changes to non-cash working capital can include differences in timing of cash flows related to accounts receivable and accounts payable, which management believes reduces comparability among periods. This non- IFRS measure excludes assets retirement obligation settlements, one-time expenses for the Company not related to ongoing operations such as restructuring and severance costs, and expense/revenue from past assets.



                              Three Months Ended     Nine Months Ended
                                 September 30          September 30
                                 ------------          ------------

    (in thousands of US$)        2017         2016      2017         2016
    --------------------         ----         ----      ----         ----

    Net cash provided (used)
     by operating activities  110,306     (12,414)  189,287     (56,450)


    Changes in non-cash
     working capital         (65,733)      22,846  (27,873)     128,037

    Deferred revenue net
     proceeds                       -           -        -      75,000

    Restructuring and
     severance costs            2,393       32,102    10,181       99,821

    Settlement of assets
     retirement obligations     1,565          502     1,847        2,308

    Loss (gain) from past
     assets                     (642)           -    (642)           -
    ---------------------        ----          ---     ----          ---

    Adjusted FFO               47,889       43,036   172,800      248,716
    ------------               ------       ------   -------      -------

Please see the Company's most recent Management's Discussion and Analysis, which is available at www.sedar.com for additional information about these financial measures.

Boe Conversion

The term "boe" is used in this news release. Boe may be misleading, particularly if used in isolation. A boe conversion ratio of 5.7 Mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead.

Definitions


                               bbl                      Barrel of oil.
                               ---                      --------------

                             bbl/d              Barrel of oil per day.
                             -----              ----------------------

                               boe     Barrel of oil equivalent. Boe's
                                       may be misleading, particularly
                                             if used in isolation. The
                                           Colombian standard is a boe
                                         conversion ratio of 5.7 Mcf:1
                                         bbl and is based on an energy
                                         equivalency conversion method
                                           primarily applicable at the
                                               burner tip and does not
                                         represent a value equivalency
                                                      at the wellhead.
                               ---    --------------------------------

                             boe/d        Barrel of oil equivalent per
                                                                  day.
                             -----       -----------------------------

                              Mbbl                   Thousand barrels.
                              ----                   -----------------

                              Mboe             Thousand barrels of oil
                                                           equivalent.
                              ----            ------------------------

                             MMbbl                    Million barrels.
                             -----                    ----------------

                             MMboe              Million barrels of oil
                                                           equivalent.
                             -----             -----------------------

                               Mcf                Thousand cubic feet.
                               ---                --------------------

                    Net Production            Company working interest
                                         production after deduction of
                                                            royalties.
                    --------------      ------------------------------

                       Total Field      100% of total field production
                                         before accounting for working
                                                  interest and royalty
                                                           deductions.
                        Production
                        ----------

                             Gross            Company working interest
                                        production before deduction of
                                                            royalties.
                        Production
                        ----------

SOURCE Frontera Energy Corporation