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Copper Tip Energy Services
Hazloc Heaters
WEC - Western Engineered Containment
Copper Tip Energy
WEC - Western Engineered Containment
Hazloc Heaters

Gear Energy Ltd. Announces Fourth Quarter 2020 Operating Results and Year-End Reserves Summary

Gear Energy Ltd. Announces Fourth Quarter 2020 Operating Results and Year-End Reserves Summary

CALGARY, AB, Feb. 17, 2021 /CNW/ – Gear Energy Ltd. (“Gear” or the “Company”) (TSX: GXE) is pleased to provide the following fourth quarter operating update and reserves summary to shareholders. Gear’s Consolidated Financial Statements and related Management’s Discussion and Analysis (“MD&A”) for the period ended December 31, 2020 are available for review on Gear’s website at and on

Financial Summary


Gear Energy Q4 2020 (CNW Group/Gear Energy Ltd.)

Three months ended Twelve months ended
(Cdn$ thousands, except per share, share and per
boe amounts)
Dec 31,
Dec 31,
Sep 30,
Dec 31,
Dec 31,
Funds from operations (1) 8,253 13,738 10,848 33,429 61,842
Per boe 15.41 21.68 20.09 17.24 24.34
Per weighted average basic share 0.04 0.06 0.05 0.15 0.28
Cash flows from operating activities 8,016 11,401 8,864 30,217 49,876
Net income (loss) 39,349 (8,045) (1,157) (77,324) (5,680)
Per weighted average basic share 0.18 (0.04) (0.01) (0.36) (0.03)
Capital expenditures 386 12,603 715 12,441 36,989
Decommissioning liabilities settled (2) 726 889 87 1,505 2,932
Net acquisitions (dispositions) (3) 109 3 (976)
Net debt (1) 52,864 69,752 60,544 52,864 69,752
Weighted average shares, basic (thousands) 216,490 218,365 216,490 216,545 218,887
Shares outstanding, end of period (thousands) 216,490 217,610 216,490 216,490 217,610
Heavy oil (bbl/d) 3,236 4,034 3,321 2,985 4,053
Light and medium oil (bbl/d) 1,657 1,763 1,746 1,507 1,963
Natural gas liquids (bbl/d) 182 269 174 169 238
Natural gas (mcf/d) 4,477 4,935 3,761 3,825 4,252
Total (boe/d) 5,821 6,888 5,868 5,298 6,962
Average prices
Heavy oil ($/bbl) 36.16 49.17 40.27 32.64 53.87
Light and medium oil ($/bbl) 48.10 64.82 47.61 45.41 66.69
Natural gas liquids ($/bbl) 26.02 22.79 20.30 19.56 22.26
Natural gas ($/mcf) 2.69 2.36 2.25 2.24 1.63
Netback ($/boe)
Commodity and other sales 36.68 47.97 39.00 33.55 51.94
Royalties (4.38) (5.52) (3.48) (3.51) (5.71)
Transportation costs (1.96) (2.16) (2.71) (2.20) (2.20)
Operating costs (14.83) (15.77) (13.60) (14.80) (15.78)
Operating netback (1) 15.51 24.52 19.21 13.04 28.25
Realized risk management gain (loss) 4.67 0.58 5.35 8.85 (0.12)
General and administrative (2.41) (2.13) (2.28) (2.67) (2.17)
Interest (2.25) (1.30) (2.19) (2.00) (1.65)
Realized (loss) gain on foreign exchange (0.11) 0.01 0.02 0.03

($ based on intra-day trading)

High 0.31 0.48 0.25 0.50 0.88
Low 0.15 0.26 0.14 0.08 0.26
Close 0.29 0.46 0.16 0.29 0.46
Average daily volume (thousands) 320 529 275 510 418
(1) Funds from operations, net debt and operating netback are non-GAAP measures and are reconciled to the nearest GAAP measures under the heading “Non-GAAP Measures” in Gear’s MD&A.
(2) Decommissioning liabilities settled includes expenditures made by both Gear and the Federal Site Rehabilitation Program.
(3) Net acquisitions (dispositions) exclude non-cash items for decommissioning liability and deferred taxes and is net of post-closing adjustments.


The fourth quarter of 2020 provided continued recovery from the setbacks experienced earlier in the year as the result of an oil price war and a Covid-induced global economic downturn. After coming into the year with strong oil prices and an ambitious $50 million capital budget, the Gear team was quick to respond to the commodity price downturn by deferring both production and capital spending while waiting out the uncertainty. With a solid commodity price recovery having recently occurred, the Company is now well positioned to resume its strategies and planned activities to capitalize on its depth of opportunities.

Gear halted its drilling program in early March 2020 after only 9 wells, and in April, Gear materially reduced costs and was well on the way to shutting in and storing oil to preserve value through the low oil price period. Through these defensive moves, Gear was able to not only preserve, but also improve the economic foundation of the company. By the end of 2020, the Company restarted the majority of its shut-in production, sold stored oil at significantly higher prices and reduced outstanding net debt by over 24 per cent from year end 2019. In addition, Gear completed the semi-annual borrowing base redetermination of its syndicated credit facilities with a maturity extension to May 2022 and negotiated the extension of the outstanding convertible debentures to 2023. The drilling activity that was completed during 2020 included a combination of low-risk infill drilling, core area step-out drilling and the exciting first-well discovery of a new medium oil play in Provost, Alberta . with multi-well potential.

Gear’s current $20 million capital budget for 2021 builds on the recent sector recovery and includes multiple follow up drilling and waterflooding activities to further advance upon prior year’s success. Underpinning these operational activities, oil prices have increased significantly, with WTI moving up from US$35.79 per barrel on October 30, 2020 to today’s price of over US$60 per barrel, a level not seen in well over a year. Heavy oil differentials also continue to narrow with the forward curve approaching a Western Canadian Select heavy oil differential of US$11 per barrel this summer. All of this has translated into a forecast of 2021 funds from operations (“FFO”) that is more than twice the current guided 2021 capital expenditures.

Whereas 2020 was dominantly a defensive year of survival for many junior oil weighted producers, 2021 is shaping up to be a year of opportunity, where Gear should again have the option of balancing excess FFO towards multiple strategic directions including continued debt reduction, accelerated capital investment and associated growth or other returns to shareholders. Although the price recovery is still relatively recent (and we will continue to monitor it diligently), the Gear team is very excited and poised for the opportunity to refocus efforts again towards creating value for its shareholders in 2021 and beyond.


  • Generated FFO for the fourth quarter of $8.3 million or $15.41 per boe. With minimal capital expenditures, Gear decreased net debt by an additional $7.7 million to $52.9 million. Annualized quarterly net debt to FFO ratio was 1.6 times.
  • Extended Gear’s syndicated credit facilities maturity date to May 2022 with a current borrowing base of $65 million. Presently, Gear is drawn $48 million and anticipates having ample liquidity to execute the 2021 capital program.
  • Successfully extended Gear’s $13.2 million convertible debentures with a three year maturity date extension to November 30, 2023, an increase in the coupon rate from 4.0 per cent to 7.0 per cent and a revision to the conversion price from $0.87 to $0.32 per Gear common share.


  • Generated $33.4 million of FFO or $17.24 per boe through a highly volatile commodity price year where WTI hit a historical low of negativeUS$37 per barrel in April 2020. FFO was supported by a continued focus on maximizing revenue for every barrel produced, maintaining a low cost structure and delivering record high realized gains on risk management contracts of $17.2 million.
  • Posted year-end net debt of $52.9 million with a net debt to FFO ratio of 1.6 times for the year. This represents a substantial $16.9 million or 24 per cent reduction from year end 2019.
  • Delivered production of 5,298 boe per day for 2020, hitting the upper end of the annual guidance range of 5,200 – 5,300 boe per day. Also achieved the lower end of the operating and transportation cost guidance of $17.00 – $18.00 with actual full year operating and transportation cost of $17.00 per boe. This was achieved through prudent operating practices and better than expected run-time on Gear’s wells.
  • Drilled nine gross (nine net) wells including seven heavy oil wells consisting of four single lateral wells in Paradise Hill, two multi-lateral wells in Lindbergh, and one single leg lined well in Frenchman’s Butte, all in the Lloydminster area of Alberta; and two medium oil wells consisting of one multi-stage fractured well in Killam and one multi-lateral well in Provost, all in the east central area of Alberta. The Provost well was a discovery well in a new area on an eight section block of land. Gear anticipates significant future development potential with this discovery under both primary and secondary recovery schemes. Multiple new wells are planned to be drilled in Provost in 2021.


  • Through the first six weeks of 2021, Gear has successfully drilled eight heavy oil wells in Paradise Hill, with the first four of those wells being completed and already starting to show initial oil production. Gear anticipates drilling two more wells in Paradise Hill prior to shutting down for spring break up.
  • Gear’s budgeted capital program details were released on December 16, 2020 using an estimated WTI oil price of US$45 per barrel and a WCS differential estimate of US$14 per barrel. Those prices were expected to yield funds from operations in excess of capital and further reduce debt to contribute to Gear’s already strong balance sheet. With the spot market WTI oil price now trending approximately $15 per barrel higher and WCS differentials tightening by over $2 per barrel, the newly forecasted funds from operations are well over double the current $20 million capital forecast. Details of current 2021 estimated results using existing guidance and various WTI price scenarios are as follows:
2021 Strip pricing as
of Feb 16, 2021
Forecasted FFO
($ million)
46 34 42 48 53
Forecasted Net
Debt ($million)
26 38 30 24 19
Forecasted Net
Debt to FFO
0.6 1.1 0.7 0.5 0.4
WTI sensitivities are run from February to December 2021 and assume a WCS diff of US$12, an MSW and LSB diff of US$4, an FX of $0.79US/Cdn, and AECO of C$2.80/GJ.
  • Current forward strip pricing supports an estimated $46 million of FFO in 2021, yielding a forecasted $26 million of free FFO in excess of the current $20 million capital budget. This provides Gear with the ability to reduce outstanding debt through 2021. With continued market stability and the completion of the Spring credit facilities renewal, Gear will consider a return to growth through investment in its deep inventory of drilling across the three core areas, as well as the acceleration of decline-reducing waterflood opportunities in Killam and Wildmere.
  • Through 2021, Gear plans to invest a total of $5.9 million towards abandonment and reclamation activities through a combination of $1.1 million of Gear funding and an additional $4.8 million of Government funding under the Site Rehabilitation Programs.
  • Gear currently has hedged approximately 2,550 boe/d for 2021 under various structures of 3-way collars, enhanced swaps and swaps. The risk management program has been cultivated to provide both downside price protection along with participation to a WTI price recovery. The current hedge contracts protect approximately 53 per cent of forecasted production after royalties with details as follows:
Q1 2021 Q2 2021 Q3 2021 Q4 2021
WTI Oil 3-way collar WTI Oil 3-way collar WTI Oil 3-way collar WTI Oil 3-way collar
Price ($/bbl) U$35x42x50 C$45x55x70.50 C$45x55x74 C$45x55x74
Volume (bbl/d) 1,300 1,100 800 800
WTI Oil Enhanced
WTI Oil Enhanced
WTI Oil 3-way collar WTI Oil 3-way collar
Price ($/bbl) U$46.50 w/ U$35 sold
C$65.85 w/ $C50 sold
C$45x55x71 C$45x55x71
Volume (bbl/d) 800 1,200 800 800
WTI Oil 3-way collar WTI Oil 3-way collar WTI Oil 3-way collar
Price ($/bbl) C$45x55x83 C$45x55x83 C$45x55x83
Volume (bbl/d) 300 400 400
Price ($/GJ) 2.75 2.75 2.75 2.75
Volume (GJ/d) 2,400 2,400 2,400 2,400
Total (boe/d) 2,479 2,979 2,379 2,379


During 2020, Gear responded to the unprecedented commodity price weakness and volatility by curtailing its planned $50 million budget in early March.  Gear generated $33.4 million of funds from operations in 2020 and reinvested only $13.4 million, or 40 per cent, consisting of $12.4 million of development capital and $1.0 million directed towards abandonment and reclamation activities (not including any government funding provided during the year).  The limited capital investment resulted in a 24 per cent reduction in outstanding net debt at the expense of a decrease in annual production and reserves year-over-year.

Compounding the reduction in reserves as a result of declines, was a significant reduction in the evaluator average price forecast that negatively impacted net present values and reserves amounts due to economic limit cut-offs. New Canadian Oil and Gas Evaluation Handbook (“COGE Handbook”) recommendations state that evaluator’s price forecasts should now be within 20 per cent of the strip price forecast at year end. In this case, the average evaluator forecast for the WTI oil price was 2.4 per cent lower than the strip price for 2021, 7.3 per cent higher for 2022 and16 per cent higher for 2023. Although this evaluator forecast could have been considered reasonable at the time, the forecast for WTI is disjointed from prevailing market realities and is now over US$10 per barrel lower than the current forward strip for 2021 and does not achieve current spot price levels of approximately US$60 per barrel until the year 2029.

Consistent with 2019, and as per guidance in the COGE Handbook, the independent reserves report includes the full corporate abandonment and reclamation costs (‘ARO’), including all of the ARO associated with both active and inactive wells regardless of whether such wells had any attributed reserves.

For details on the annual operating results please see the Management’s Discussion and Analysis (“MD&A”) dated February 17, 2021, which is available on SEDAR at


Year-end 2020 reserves were evaluated by independent reserves evaluator Sproule Associates Ltd. (“Sproule”) in accordance with the definitions, standards and procedures contained in the COGE Handbook and National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities (“NI 51-101”). A reserves committee, comprised of independent board members, reviews the qualifications and appointment of the independent reserves evaluator and reviews the procedures for providing information to the evaluators. The reserves evaluation was based on an average of price forecasts prepared by Sproule, GLJ Petroleum Consultants Ltd. and McDaniel & Associates Consulting Ltd. effective at January 1, 2021. Reserves included herein are stated on a company gross basis (working interest before deduction of royalties without inclusion of any royalty interests) unless noted otherwise. Additional reserves information required under NI 51-101 will be included in Gear’s Annual Information Form to be filed on SEDAR on or before March 31, 2021.

The following tables outline Gear’s reserves as at December 31, 2020. No provision for interest, risk management contracts, debt service charges and general and administrative expenses have been made and it should not be assumed that the net present values of the reserves estimated by Sproule represents the fair market value of the reserves.

Reserves Summary at Dec 31, 2020 Using Sproule Costs and Jan 1, 2021 Evaluator Average Forecast Prices

Company Gross Light &


 Heavy Oil


















Proved Developed Producing5 3,406 2,483 302 6,085 7,205 86
Proved Non-Producing & Undeveloped 2,310 2,950 142 2,342 5,793 93
Total Proved 5,716 5,433 444 8,427 12,998 89
Probable Developed Producing 1,397 937 110 2,204 2811 87
Probable Non-Producing & Undeveloped 3,258 3,744 142 3,270 7,689 93
Total Probable 4,655 4,681 252 5,474 10,500 91
Total Proved plus Probable 10,371 10,114 696 13,901 23,498 90

Net Present Value of Future Revenues Including Full ARO Before Income Taxes Under Forecast Prices and Costs

Company Gross Undiscounted Discounted Discounted Discounted Discounted
($ thousands) @ 5% @ 10% @ 15% @ 20%
Proved Developed Producing 15,014 66,883 73,787 71,463 67,414
Proved Non-Producing & Undeveloped 72,993 50,602 35,528 25,158 17,802
Total Proved 88,007 117,485 109,315 96,621 85,216
Probable Developed Producing 60,632 55,057 41,548 32,591 26,745
Probable Non-Producing &
135,894 95,536 69,402 51,810 39,478
Total Probable 196,526 150,593 110,950 84,401 66,223
Total Proved plus Probable 284,533 268,079 220,265 181,022 151,439

Net Future Development Costs (“FDC”) Under Forecast Prices and Costs

($ thousands) Proved Probable Total
2021 13,545 4,954 18,499
2022 26,498 39,125 65,623
2023 29,915 31,297 61,212
2024 27,858 18,817 46,675
2025 12,405 7,254 19,659
Subsequent Years 0 8,186 8,186
Undiscounted Total 110,221 109,633 219,854
Discounted at 10% 87,553 86,256 173,809


2020 2019
Reserves (mboes), Capital ($ thousands) Proved Proved plus
Proved Proved plus
Development Reserves Additions (1,186) (1,732) 1,659 981
Net Acquisition Reserves Additions (127) (346) 1 40
Total Reserves Additions (1,313) (2,078) 1,660 1,021
Development capital 11,775 11,775 36,948 36,984
Development change in FDC (41,825) (41,082) (2,385) (4,880)
Total development capital including FDC (30,050) (29,307) 34,563 32,068
Net acquisition capital 3 3 (937) (937)
Net acquisition change in FDC 0 0 0 0
Total net acquisition capital including FDC 3 3 (937) (937)
Total capital 11,778 11,778 36,012 36,012
Total change in FDC (41,825) (41,082) (2,385) (4,880)
Total capital including FDC (30,047) (29,304) 33,627 31,131

Estimated Future Finding and Development Costs

Proved Proved plus
Future Development Costs ($ thousands) 110,221 219,854
Undeveloped and Non-producing Reserves (Mboe) 5,793 13,482
Future Finding and Development Costs ($/boe) 19.03 16.31

Reserves Life Index (“RLI”)

(years) 2020 2019 2018
Proved Developed Producing 4.3 4.2 3.9
Total Proved 6.9 6.6 5.4
Total Proved plus Probable 10.7 9.4 7.7


Reserves Reconciliation

Company Gross

Heavy Oil
Light &


Proved Producing
Opening Balance, January 1, 2020 3,348 3,913 6,827 464 8,861
Technical Revisions 336 92 1,001 (81) 513
Drilling Extensions 125 94 59 229
Infill Drilling
Improved Recovery 43 41 51
Acquisitions 12 16 1 16
Dispositions (14) (14) (2) (19)
Economic Factors (233) (183) (451) (18) (508)
Production (1,093) (551) (1,394) (62) (1,938)
Closing Balance, December 31, 2020 2,483 3,406 6,085 302 7,205
Total Proved
Opening Balance, January 1, 2020 6,906 6,882 10,540 705 16,249
Technical Revisions 47 516 378 (142) 485
Drilling Extensions 328 183 216 2 549
Infill Drilling 16 19 2 21
Improved Recovery 43 41 1 51
Acquisitions 12 16 1 16
Dispositions (109) (25) (26) (4) (143)
Economic Factors (646) (1,360) (1,363) (59) (2,292)
Production (1,093) (551) (1,394) (62) (1,938)
Closing Balance, December 31, 2020 5,433 5,716 8,427 444 12,998
Proved plus Probable
Opening Balance, January 1, 2020 12,705 11,242 15,201 1,033 27,515
Technical Revisions (631) 149 620 (232) (611)
Drilling Extensions 497 307 212 1 841
Infill Drilling 0
Improved Recovery 72 62 1 83
Acquisitions 16 22 2 22
Dispositions (321)- (35) (36) (5) (368)
Economic Factors (1,043) (829) (786) (42) (2,046)
Production (1,093) (551) (1,394) (62) (1,938)
Closing Balance, December 31, 2020 10,114 10,371 13,901 696 23,498


Sproule has adopted changes to the COGE Handbook that are expected to come into effect in April 2021.  This updated pricing guidance recommends that forecasting not deviate more than 20% from the current strip pricing for the first two years of the forecast.  Discretion can be incorporated for the third year based upon the judgement of the issuer.  Pricing beyond the third year should be adjusted by forecasted inflation in the given year.

The evaluator average crude oil and natural gas benchmark reference pricing, inflation, and exchange rates was utilized again this year by Sproule. Gear’s main product components under Sproule’s evaluator average forecast are down 26 to 28 per cent from the previous year’s price forecast.  The Sproule evaluator average forecast at December 31, 2020 is as follows:

Year Inflation




WTI Cushing

(40 API)



(40 API)



(21 API)




2021 0.00 0.77 47.17 55.76 44.63 2.78
2022 1.33 0.77 50.17 59.89 48.18 2.70
2023 2.00 0.76 53.17 63.48 52.10 2.61
2024 2.00 0.76 54.97 65.76 54.10 2.65
2025 2.00 0.76 56.07 67.13 55.19 2.70
2026 2.00 0.76 57.19 68.53 56.29 2.76
2027 2.00 0.76 58.34 69.95 57.42 2.81
2028 2.00 0.76 59.50 71.40 58.57 2.87
2029 2.00 0.76 60.69 72.88 59.74 2.92
2030 2.00 0.76 61.91 74.34 60.93 2.98
2031+ 2.00 0.76 +2.0%/yr +2.0%/yr +2.0%/yr +2.0%/yr

Forward-looking Information and Statements
This press release contains certain forward-looking information and statements within the meaning of applicable securities laws. The use of any of the words “expect”, “anticipate”, “continue”, “estimate”, “objective”, “ongoing”, “may”, “will”, “project”, “should”, “believe”, “plans”, “intends”, “strategy” and similar expressions are intended to identify forward-looking information or statements. In particular, but without limiting the foregoing, this press release contains forward-looking information and statements pertaining to the following: details of Gear’s expected capital program in 2021; Western Canadian Select heavy oil differential of US$11 per barrel for the summer of 2021; forecasted 2021 FFO of that is over double the current guided 2021 $20 million capital plan; the expectation that Gear should have the option of balancing excess FFO towards multiple strategic directions including continued debt reduction, accelerated capital investment and associated growth in 2021; the expectation that the anticipation of significant future development potential in Provost on both primary and secondary recovery schemes; Gear’s anticipation of drilling two more wells in Paradise Hill prior to shutting down for spring break up; the expectation of FFO in excess of capital and further reduction of debt in 2021; the expectation that the newly forecasted funds from operations are well over double the current $20 million capital forecast; the expected 2021 FFO, forecasted net debt and forecasted net debt to FFO based on various commodity pricing scenarios; the expectation that with continued market stability and the completion of the Spring credit facilities renewal, Gear will consider a return to growth through investment in its deep inventory of drilling across the three core areas, as well as the acceleration of decline-reducing waterflood opportunities in Killam and Wildmere; the amount of abandonment and reclamation expenditures expected in 2021 including the amount of Government funding to be received for such expenditures; the expectation that current hedges will protect approximately 53 per cent of forecasted production after royalties in 2021; reserves and associated future net revenue; expected future abandonment and reclamation costs; and the expectation of filing Gear’s Annual Information Form on SEDAR on or before March 31, 2021.

The forward-looking information and statements contained in this press release reflect several material factors and expectations and assumptions of Gear including, without limitation: that Gear will continue to conduct its operations in a manner consistent with past operations; the general continuance of current industry conditions; the continuance of existing (and in certain circumstances, the implementation of proposed) tax, royalty and regulatory regimes; the accuracy of the estimates of Gear’s reserves and resource volumes; certain commodity price and other cost assumptions; the continued availability of adequate debt and equity financing and funds from operations to fund its planned expenditures; and certain other guidance and assumptions as set out in the section entitled 2020 Guidance in the MD&A.. Gear believes the material factors, expectations and assumptions reflected in the forward-looking information and statements are reasonable but no assurance can be given that these factors, expectations and assumptions will prove to be correct.

To the extent that any forward-looking information contained herein may be considered a financial outlook, such information has been included to provide readers with an understanding of management’s assumptions used for budgeting and developing future plans and readers are cautioned that the information may not be appropriate for other purposes. The forward-looking information and statements included in this press release are not guarantees of future performance and should not be unduly relied upon. Such information and 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 information or statements including, without limitation: the continuing impact of the COVID-19 pandemic; changes in commodity prices; changes in the demand for or supply of Gear’s products; unanticipated operating results or production declines; changes in tax or environmental laws, royalty rates or other regulatory matters; changes in development plans of Gear or by third party operators of Gear’s properties, increased debt levels or debt service requirements; any action taken by Gear’s lenders to reduce borrowing capacity or require repayment under its credit facilities; any inability for Gear to repay any of its indebtedness when due; inaccurate estimation of Gear’s oil and gas reserve and resource volumes; limited, unfavorable or a lack of access to capital markets; increased costs; a lack of adequate insurance coverage; the impact of competitors; and certain other risks detailed from time to time in Gear’s public documents including in Gear’s most current annual information form which is available on SEDAR at

The forward-looking information and statements contained in this press release speak only as of the date of this press release, and Gear does not assume any obligation to publicly update or revise them to reflect new events or circumstances, except as may be required pursuant to applicable laws.

Oil and Gas Metrics
This press release contains a number of oil and gas metrics, including future finding and development costs, reserves life index and operating netback, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies. Such metrics have been included herein to provide readers with additional measures to evaluate the Company’s performance; however, such measures are not reliable indicators of the future performance of the Company and future performance may not compare to the performance in previous periods. Future finding and development costs are used as a measure of capital efficiency. The calculation for future finding and development costs is calculated by dividing future development costs for proved plus probable reserves by the undeveloped and non-producing reserves as included in the year end reserves report. Reserves life index is calculated by dividing the reserves in each category by the corresponding Sproule forecast annual production. Operating netbacks are presented before taking into account the effects of hedging and are calculated based on the amount of revenues received on a per unit of production basis after royalties and operating costs.

NON-GAAP Measures
This press release contains the terms funds from operations, net debt and operating netback, which do not have standardized meanings under Canadian generally accepted accounting principles (“GAAP”) and therefore may not be comparable with the calculation of similar measures by other companies. Management believes that these key performance indicators and benchmarks are key measures of financial performance for Gear and provide investors with information that is commonly used by other oil and gas companies. Funds from operations is calculated as cash flow from operating activities before changes in noncash operating working capital and decommissioning liabilities settled. Net debt is calculated as debt less current working capital items, excluding risk management contracts. Operating netbacks are presented both before and after taking into account the effects of hedging and are calculated based on the amount of revenues received on a per unit of production basis after royalties and operating costs. Additional information relating to certain of these non-GAAP measures, including the reconciliation between funds from operations and cash flow from operating activities, can be found in the MD&A.

Barrels of Oil Equivalent
Disclosure provided herein in respect of BOEs may be misleading, particularly if used in isolation. A BOE conversion ratio of six Mcf to one Bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and do not represent a value equivalency at the wellhead. Additionally, given that the value ratio based on the current price of crude oil, as compared to natural gas, is significantly different from the energy equivalency of 6:1; utilizing a conversion ratio of 6:1 may be misleading as an indication of value.

SOURCE Gear Energy Ltd.

For further information: Ingram Gillmore, President & CEO, 403-538-8463; David Hwang, Vice President Finance & CFO, 403-538-8437; Email:, Website:

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