CALGARY, ALBERTA--(Marketwire - April 26, 2012) - Petro-Reef Resources Ltd. (TSX VENTURE:PER), ("Petro-Reef" or the "Company") is pleased to release its year end 2011 financial and operating results and its December 31, 2011 reserve report.
This press release should be read in conjunction with the Company's 2011 annual filings on Sedar.
For the twelve month period ended December 31, 2011, Petro-Reef generated cash flow from operations of $3,150,536 ($0.05 per basic share), a decrease of 29% compared to $4,447,326 ($0.11 per basic share) for the twelve month period ended December 31, 2010. Lower natural gas prices and production volumes were major factors in the cash flow decrease.
Daily production volumes decreased by 21.4% to 652 boe/d in the year ended December 31, 2011 as compared to 829 boe/d for the same period in 2010.
The decrease in volumes was mainly due to natural gas production declines and the shut-in of two new Detrital oils wells at Alexander (6-7-56-26W4 and 11-7-56-26W4) due to overproduction related to the gas/oil ratio. The two oil wells did not produce for the entire fourth quarter under the ERCB penalty which reduced daily volumes by 300 boe/day. Effective January 1, 2012 the production restrictions were lifted and average daily production volumes increased to over 900 boe/day.
Capital expenditures for 2011 totaled $7.7 million decreasing 3% from the $7.9 million expended in 2010. Total net debt at year end was $12.8 million.
Production and operating expenses increased 13.4% to $3,318,587 for the year ended December 31, 2011 compared to $2,925,862 for the same period ended December 31, 2010. The increase of $392,725 is related to increases in oil trucking and treating charges, fuel and power expenses and freehold surface lease rentals offset by decreases in gas processing charges and repairs and maintenance.
Production and operating expenses on a per unit of production basis increased 44.3% to $13.95 for the year ended December 31, 2011 compared to $9.67 for the same period in 2010.
For the year ended December 31, 2011 cash flow netbacks per boe decreased by 9.9% over the same period in 2010.
Financial
Effective September 30, 2011 the Corporation renewed its credit facilities with a Canadian Chartered Bank. Facility A is a revolving operating demand loan with a maximum limit of $14,000,000. Facility B is a non -revolving acquisition/development demand loan that provides an additional $6,000,000 of financing. Interest is at prime plus 1.0% per annum for Facility A and prime plus 1.5% per annum for Facility B. Petro-Reef has the ability to borrow by way of Bankers Acceptances.
The Company has the ability to draw on the development loan for the drilling of new wells subject to certain working capital ratio restrictions.
At December 31, 2011 the balance owing on Facility A was $12,511,275 (December 31, 2010 - $9,627,691). At December 31, 2011 the balance owing on Facility B was $nil (December 31, 2010 - $nil). Net debt was $12,832,932 at December 31, 2011 as compared to $10,560,062 at December 31, 2010.
Effective February 2, 2012 the Corporation renewed its operating facilities with a Canadian Chartered Bank. Facility A was reduced to a maximum limit of $13,000,000. There were no other changes to the facility.
In August, 2011 Petro-Reef Resources Ltd. closed a private placement financing of Flow -through Shares for gross proceeds of $2,391,200. Pursuant to the offering, Petro-Reef issued 5,978,000 common shares on a flow- through basis at a purchase price of 40 cents per common share.
Reserves
Petro-Reef's evaluation of gross proved plus probable reserves at December 31, 2011 indicated a net increase of 6% to 1,674,867 BOE from 1,579,900 BOE at December 31, 2010, after extensions, technical revisions, discoveries, acquisitions, economic factors, and production. After considering the production for the period January 1 to December 31, 2011 of 237,980 BOE, the 2011 reserve additions totalled 332,946 BOE which represents an increase of 21% over the 2010 year end reserves.
Using a 10% net present value ("NPV"), the value of proved plus probable reserves at forecast prices and costs (before income taxes) was $32,792,300 as compared with proved plus probable reserves of $34,741,400 as at December 31, 2010.
Petro-Reef's gross proved, probable plus possible reserves at December 31, 2011 totaled 2,521,567 BOE. Using a 10% NPV, the value of proved, probable plus possible reserves at forecast prices and costs (before income taxes) totaled $54,498,800. The possible reserves include four potential development locations targeting the Detrital zone offsetting the Company's recent 09-12-56-27W4 well.
Proved plus probable reserves were comprised of 47% natural gas and 53% crude oil and natural gas liquids (December 31, 2010 - 54% natural gas and 46% crude oil and natural gas liquids).
Of the total proved plus probable reserves reported (using forecast prices) Petro-Reef's reserves are 56% proved and 44% probable.
Based on proved plus probable reserves and 2011 average production volume, Petro-Reef's reserve life index was 5.1 years (38.7 years remaining life) on a proved plus probable basis at December 31, 2011 compared with 4.2 years (39.8 years remaining life) at the end of 2010. Petro-Reef's reserve life index (RLI) is an indication of the number of years it would take to deplete the Company's reserves.
| SUMMARY OF FINANCIAL AND OPERATIONAL RESULTS | |||||||||||||
| Three Months Ended December 31 | Year Ended December 31 | ||||||||||||
| $ | 2011 | 2010 | % Change | 2011 | 2010 | % Change | |||||||
| FINANCIAL | |||||||||||||
| Oil and gas revenue | 2,293,360 | 2,634,503 | -13 | 9,744,553 | 9,777,127 | - | |||||||
| Realized financial instrument gains (losses) | (48,075 | ) | 451,364 | -111 | 344,542 | 996,822 | -65 | ||||||
| Cash flow from operations | (34,841 | ) | 1,478,452 | -102 | 3,150,536 | 4,447,326 | -29 | ||||||
| Per share - basic | 0.00 | 0.04 | -100 | 0.05 | 0.11 | -55 | |||||||
| Net loss | (5,635,296 | ) | (1,351,334 | ) | 317 | (6,515,846 | ) | (2,335,998 | ) | 179 | |||
| Per share- basic | (0.09 | ) | (0.03 | ) | 200 | (0.11 | ) | (0.06 | ) | 83 | |||
| Total net debt | 12,832,932 | 10,560,062 | 22 | 12,832,932 | 10,560,062 | 22 | |||||||
| Shares outstanding - end of year | 62,239,477 | 55,943,157 | 11 | 62,239,477 | 55,943,157 | 11 | |||||||
| Capital expenditures | 423,000 | 1,698,201 | -75 | 7,691,000 | 7,920,000 | -3 | |||||||
| Wells drilled (net) | |||||||||||||
| Oil | 0.00 | 1.79 | - | 2.52 | 1.79 | 41 | |||||||
| Gas | 0.00 | 0.00 | - | 0.00 | 0.94 | - | |||||||
| Dry | 0.00 | 0.00 | - | 0.79 | 0.00 | - | |||||||
| Total net wells drilled | 0.00 | 1.79 | - | 3.31 | 2.73 | 21 | |||||||
| OPERATIONAL | |||||||||||||
| Daily production | |||||||||||||
| Oil & NGL (bbl) | 182 | 223 | -18 | 207 | 148 | 40 | |||||||
| Natural gas (mcf) | 2,559 | 3,796 | -33 | 2,670 | 4,086 | -35 | |||||||
| Oil equivalent (boe @ 6:1)^ | 608 | 856 | -29 | 652 | 829 | -21 | |||||||
| Commodity prices ($Cdn) | |||||||||||||
| Oil & NGL (bbl) | 88.59 | 66.96 | 32 | 79.61 | 69.92 | 14 | |||||||
| Natural gas (mcf) | 3.45 | 3.61 | -4 | 3.83 | 4.02 | -5 | |||||||
| Oil equivalent (boe @ 6:1) | 40.98 | 33.47 | 22 | 40.96 | 32.31 | 27 | |||||||
| Operating netback ($ per boe) | |||||||||||||
| Revenue | 40.98 | 33.47 | 22 | 40.96 | 32.31 | 27 | |||||||
| Royalty | (3.04 | ) | (3.64 | ) | -16 | (5.59 | ) | (4.06 | ) | 38 | |||
| Operating cost | (16.29 | ) | (9.59 | ) | 70 | (13.95 | ) | (9.67 | ) | 44 | |||
| Operating netback per boe | 21.65 | 20.24 | 7 | 21.42 | 18.58 | 15 | |||||||
| General and administrative | (18.16 | ) | (5.24 | ) | 247 | (7.57 | ) | (5.14 | ) | 47 | |||
| Finance charges and fees | (3.26 | ) | (1.95 | ) | 67 | (2.06 | ) | (2.03 | ) | 1 | |||
| Realized financial instrument gains (losses) | (0.85 | ) | 5.73 | -115 | 1.45 | 3.29 | -56 | ||||||
| Cash flow per Boe | (0.62 | ) | 18.78 | -103 | 13.24 | 14.70 | -10 | ||||||
| (1) | "Funds from operations", "funds from operations per share", "netbacks" and "netbacks per boe" are not defined by Generally Accepted Accounting Principles (''GAAP") in Canada and are regarded as non-GAAP measures. Funds from operations and funds from operations per share are calculated as cash provided by operating activities before changes in non-cash working capital and asset retirement expenditures. Funds from operations is used to analyze the Company's operating performance, the ability of the business to generate the cash flow necessary to fund future growth through capital investment and to repay debt. Funds from operations does not have a standardized measure prescribed by GAAP and therefore may not be comparable with the calculations of similar measures for other companies. The Company also presents funds from operation per share whereby per share amounts are calculated using the weighted average number of common shares outstanding consistent with the calculation of net income or loss per share. |
| (2) | The term barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet per barrel (6 mcf/bbl) of natural gas to barrels of oil equivalence is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. All boe conversions in the report are derived from converting gas to oil in the ratio mix of six thousand cubic feet of gas to one barrel of oil. |
Reserves Summary
The December 31, 2011 evaluation was prepared in accordance with National Instrument 51-101. The reserve report reflects current proved and probable reserves, and proved, probable and possible reserves. The December 31, 2011 report and the December 31, 2010 reports were prepared by McDaniel & Associates Consultants Ltd.
| Reserves Gross and Net (Forecast Prices and Costs) - December 31, 2011 | ||||||||||||
| Light / Medium Oil | Natural Gas | BOE | ||||||||||
| Gross | Net | Gross | Net | Gross | Net | |||||||
| (Mbbl | ) | (Mbbl | ) | (MMcf | ) | (MMcf | ) | (MBOE | ) | (MBOE | ) | |
| Reserves Category | ||||||||||||
| Proved | ||||||||||||
| Developed Producing | 331.3 | 278.1 | 2,642.9 | 2,293.6 | 771.8 | 660.4 | ||||||
| Developed Non-Producing | 23.4 | 21.2 | 207.7 | 185.1 | 58.0 | 52.1 | ||||||
| Undeveloped | 74.1 | 65.2 | 156.4 | 139.6 | 100.2 | 88.5 | ||||||
| Total Proved | 428.8 | 364.5 | 3,007.0 | 2,618.3 | 930.0 | 800.9 | ||||||
| Probable | 460.0 | 376.9 | 1,709.4 | 1,495.9 | 744.9 | 626.2 | ||||||
| Total Proved & Probable | 888.8 | 741.4 | 4,716.4 | 4,114.2 | 1,674.9 | 1,427.1 | ||||||
| Possible | 587.6 | 499.3 | 1,554.6 | 1,359.0 | 846.7 | 725.8 | ||||||
| Total Proved, Probable & Possible | 1,476.4 | 1,240.7 | 6,271.0 | 5,473.2 | 2,521.6 | 2,152.9 | ||||||
| N1 51-101 Summary of Net Present Values of Future Net Revenue as of December 31, 2011 Forecast Prices and Costs |
| 0% DCF | 5% DCF | 10% DCF | 15% DCF | |||||
| Reserves Category | (M$ | ) | (M$ | ) | (M$ | ) | (M$ | ) |
| Proved Developed Producing | 17,898 | 16,7556 | 15,769 | 14,910 | ||||
| Developed Non-Producing | 1,330 | 854 | 584 | 425 | ||||
| Undeveloped | 2,717 | 2,419 | 2,166 | 1,949 | ||||
| Total Proved | 21,944 | 20,030 | 18,519 | 17,284 | ||||
| Probable | 25,032 | 18,236 | 14,273 | 11,728 | ||||
| Total Proved Plus Probable | 46,980 | 38,266 | 32,792 | 29,011 | ||||
Using a ten percent (10%) NPV, the estimated value of proved plus probable reserves at forecast prices and costs (before Income Taxes) decreased by 6% to $32,792,300 as compared with last year's estimated value of $34,741,400. The estimated values disclosed do not represent fair market value.
Forecast Prices Used in Estimates
McDaniel employed the following pricing, exchange rate and inflation rate assumptions in estimating Petro-Reef reserve data as of December 31, 2011:
| Year | WTI Crude Oil ($US/bbl |
) | Edmonton Par Price 40° API ($Cdn/bbl |
) | Cromer Medium 29.3° API ($Cdn/bbl |
) | Natural Gas AECO Gas Prices ($Cdn/MMBtu |
) | Edmonton Condensate ($Cdn/bbl |
) | Edmonton Butane ($Cdn/bbl |
) | Inflation Rate (%/Yr |
) | Exchange Rate ($US/$Cdn |
) | |
| Historical | |||||||||||||||||
| 2005 | 56.56 | 68.72 | 57.47 | 8.58 | 69.63 | 52.58 | 2.1 | 0.83 | |||||||||
| 2006 | 66.23 | 72.80 | 61.25 | 7.16 | 75.06 | 60.10 | 2.2 | 0.88 | |||||||||
| 2007 | 72.30 | 76.35 | 65.40 | 6.65 | 77.36 | 63.75 | 2.0 | 0.94 | |||||||||
| 2008 | 99.60 | 102.20 | 93.20 | 8.15 | 104.75 | 75.25 | 2.4 | 0.94 | |||||||||
| 2009 | 61.80 | 65.90 | 62.80 | 4.20 | 68.15 | 49.25 | 2.0 | 0.88 | |||||||||
| 2010 | 79.50 | 77.50 | 73.80 | 4.15 | 84.25 | 66.05 | 2.0 | 0.97 | |||||||||
| 2011 | 94.80 | 95.20 | 88.35 | 3.70 | 104.20 | 75.50 | 2.0 | 1.01 | |||||||||
| Forecast | |||||||||||||||||
| 2012 | 97.50 | 99.00 | 91.00 | 3.50 | 106.00 | 76.20 | 2.0 | 0.98 | |||||||||
| 2013 | 97.50 | 99.00 | 91.00 | 4.20 | 104.10 | 79.80 | 2.0 | 0.98 | |||||||||
| 2014 | 100.00 | 101.50 | 93.30 | 4.70 | 104.60 | 81.80 | 2.0 | 0.98 | |||||||||
| 2015 | 100.80 | 102.30 | 94.10 | 5.10 | 105.50 | 82.40 | 2.0 | 0.98 | |||||||||
| 2016 | 101.70 | 103.20 | 94.90 | 5.55 | 106.40 | 83.20 | 2.0 | 0.98 | |||||||||
| Thereafter | 2.0% Escalation Rates | ||||||||||||||||
| Reconciliation of Changes in Reserves |
| Light, Medium Oil and NGL | Natural Gas | BOE | |||||||||||||||||
| Gross | Gross | Gross | |||||||||||||||||
| Proved | Proved | Proved | |||||||||||||||||
| Gross | Gross | Plus | Gross | Gross | Plus | Gross | Gross | Plus | |||||||||||
| Proved | Probable | Probable | Proved | Probable | Probable | Proved | Probable | Probable | |||||||||||
| Factors | (Mbbl | ) | (Mbbl | ) | (Mbbl | ) | (MMcf | ) | (MMcf | ) | (MMcf | ) | (BOE | ) | (BOE | ) | (BOE | ) | |
| December | |||||||||||||||||||
| 31, 2010 | 372.8 | 330.1 | 702.9 | 3,467.2 | 1,794.6 | 5,261.8 | 950.7 | 629.2 | 1,579.9 | ||||||||||
| Extensions | 107.9 | 271.9 | 379.8 | 163.8 | 609.5 | 773.3 | 135.2 | 373.5 | 508.7 | ||||||||||
| Technical | |||||||||||||||||||
| Revisions | 26.2 | (139.0 | ) | (112.8 | ) | 450.6 | (662.0 | ) | (211.4 | ) | 101.2 | (249.2 | ) | (148.0 | ) | ||||
| Economic | |||||||||||||||||||
| Factors | (2.6 | ) | (3.0 | ) | (5.6 | ) | (108.0 | ) | (32.4 | ) | (140.4 | ) | (20.6 | ) | (8.4 | ) | (29.0 | ) | |
| Production | (75.5 | ) | - | (75.5 | ) | (966.6 | ) | (0.3 | ) | (966.9 | ) | (236.6 | ) | (0.1 | ) | (236.7 | ) | ||
| December | |||||||||||||||||||
| 31, 2011 | 428.8 | 460.0 | 888.8 | 3,007.0 | 1,790.4 | 4,716.4 | 929.9 | 745.0 | 1,674.9 | ||||||||||
Forward-Looking Statements: All statements, other than statements of historical fact, set forth in this news release, including without limitation, assumptions and statements regarding reservoirs, resources and reserves, future production rates, exploration and development results, financial results, and future plans, operations and objectives of the Corporation are forward-looking statements that involve substantial known and unknown risks and uncertainties. Some of these risks and uncertainties are beyond management's control, including but not limited to, the impact of general economic conditions, industry conditions, fluctuation of commodity prices, fluctuation of foreign exchange rates, environmental risks, industry competition, availability of qualified personnel and management, availability of materials, equipment and third party services, stock market volatility, timely and cost effective access to sufficient capital from internal and external sources. The reader is cautioned that assumptions used in the preparation of such information, although considered reasonable by the Corporation at the time of preparation, may prove to be incorrect. There can be no assurance that such statements will prove to be accurate and actual results and future events could differ materially from those anticipated in such statements.
Reference is made to barrels of oil equivalent (BOE). Barrels of oil equivalent may be misleading, particularly if used in isolation. In accordance with National Instrument 51-101, a BOE conversion ratio for natural gas of 6 Mcf: 1 bbl has been used, which is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead.
The TSX Venture Exchange does not accept responsibility for the adequacy or accuracy of this news release.
Contact Information:
Hugh M. Thomson
Vice-President Finance and CFO
(403) 523-2505
(403) 264-1348 (FAX)
Petro-Reef Resources Ltd.
970, 10655 Southport Road S.W.
Calgary, Alberta T2W 4Y1
info@petro-reef.ca
www.petro-reef.ca