CALGARY, ALBERTA--(Marketwire - Aug. 1, 2012) - Donnybrook Energy Inc. ("Donnybrook" or the "Company") (TSX VENTURE:DEI) provides an operations update on its Bigstone Montney formation, liquids rich natural gas resource play.
Donnybrook's Bigstone Hz 14-29-60-22 W5M Montney discovery well, which tested 4.3 mmcf/d and 295 barrels of NGL's (1,011 barrels of oil equivalent per day) from a 1,254m lateral, commenced production in mid June 2012 and during the first 42 days of operation the 14-29 well produced at an average rate of 1.61 mmcf/d (523 mcf/d net) and 72.8 bbls/d (23.7 bbls/d net) of condensate for a combined oil equivalent total of 341 boe/d (111 boe/d net). Further NGLs will be extracted during processing at the shallow cut plant and are estimated to be 30-35 bbls/mmcf of raw gas. Donnybrook has a 25% W.I. plus 10% GORR on 75% BPO/50% APO in the 14-29 well.
Donnybrook's Bigstone Hz 15-32-60-22 W5M well (DEI 50%) commenced production on July 16 and for the first 7 producing days has been producing natural gas, free condensate and NGLs which will be extracted during processing. The 15-32 well had technical problems during the completion and only 6 stages of the planned 23 stage frac were completed successfully. The well is currently producing and the initial production rates are encouraging. The well has averaged 1.75 mmcf/d (875 mcf/d net) with 153 bbls/d (76.5 bbls/d net) of condensate for a total of 445 boe (222 boe/d net). The current fluid production includes both load fluids and free condensate, as 100% of the load fluids have not been fully recovered to date.
The Donnybrook Bigstone Hz 13-33-60-22 W5M well (DEI 25%) was drilled to a total measured depth of 5,336m and completed with a 23 stage frac. After initial flow back and clean up, the well is currently waiting on dry weather for the installation of production tubing, final flow testing and commencement of construction and installation of surface facilities. The well will be tied into the Donnybrook operated Bigstone pipeline system as soon as access conditions permit. All operations at 13-33 have encountered delays due to heavy rain which has made access to the lease site difficult. As soon as surface conditions dry out operations at 13-33 will commence. Flow rates on the well will be released upon the completion of final testing.
Industry activity in the Bigstone area continues to prove up the potential of Donnybrook's land holdings on the western side of its land block. The most recent well to be announced was an extended reach Hz that terminated 195m south of Donnybrook's 50% W.I. lands in Twp 60-23 W5M. The operator has reported the well tested an average 16 mmcf/d and approximately 800 bbls of condensate per day at the end of the test.
This compares very well to an initial extended reach Hz well by the same operator which for a mile of Hz length offsets Donnybrook's 50% W.I. lands in 60-22 W5M and is only 200m west of Donnybrook's lands. The initial well tested 12.5 mmcf/d and 770 bbls/d of condensate.
These wells continue to demonstrate the excellent reservoir potential of the Montney Formation underlying the western side of Donnybrook's 50% W.I. lands in the Bigstone area. Donnybrook has a 50% interest in 4 sections (1,024 ha/612 ha net) in the western portion of its Bigstone prospect that have not been drilled to date.
Based on the results to date, four new Hz Montney drilling locations at Bigstone have been surveyed. The timing of the drilling of the additional wells will be finalized in Q4 2012.
At Bigstone, Donnybrook has 8 gross sections (2,048 ha) 3.75 net sections (960 ha) of P&NG rights located approximately 35 kilometres (22 miles) east of the eastern edge of the Company Simonette acreage block.
Donnybrook has 3 (1.25 net) Montney wells on production at Simonette producing at a combined rate of approximately 250 boe/d of natural gas, condensate and NGLs net to Donnybrook. The Resthaven 11-27 well (DEI 70%) has been production tested in-line intermittently at rates of 1 mmcf/d and 60 bbls/d of condensate. The line pressure in the gathering system that the 11-27 well is tied into is running at high line pressures which is affecting the 11-27 well's ability to flow consistently into the gathering system.
Donnybrook holds interests in 46 gross (22.9 net) sections of petroleum and natural gas rights in the Bigstone-Simonette-Resthaven liquid rich natural gas resource play in the Deep Basin area of west central Alberta.
Further information relating to Donnybrook is also available on its website at www.donnybrookenergy.ca.
ON BEHALF OF THE BOARD OF DONNYBROOK ENERGY INC.
Malcolm F. W. Todd, Chief Executive Officer
This press release contains forward-looking statements or information ("forward-looking statements") within the meaning of applicable securities laws including statements regarding the estimated raw gas of NGLs extracted during processing at the 14-29 well, the timing and completion of the 13-33 well and the timing for drilling of additional extended reach horizontal wells at Bigstone. The use of any of the words "will", "expects", "believe", "plans", "potential" and similar expressions are intended to identify forward-looking statements.
The forward-looking statements in this press release are based on certain key expectations and assumptions made by Donnybrook, including the quality of the Montney reservoir, continued performance from existing wells, future drilling programs and performance from new wells, the growth of infrastructure, well density per section, recovery factors and that development necessarily involves known and unknown risks and uncertainties. Although Donnybrook believes that the expectations and assumptions on which such forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because Donnybrook can give no assurance that they will prove to be correct. There is no certainty that Donnybrook will achieve commercially viable production from its undeveloped lands and prospects.
Since forward-looking statements address future events and conditions, by their very nature, they involve inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to the risks associated with the oil and gas industry in general such as: operational risks in development, exploration and production; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to reserve, production, costs and expenses; health, safety and environmental risks; commodity price and exchange rate fluctuations; marketing and transportation of petroleum and natural gas and loss of markets; environmental risks; competition; incorrect assessment of the value of acquisitions; failure to realize the anticipated benefits of acquisitions; ability to access sufficient capital from internal and external sources; stock market volatility; and changes in legislation, including but not limited to tax laws, royalty rates and environmental regulations. Readers are cautioned that the foregoing list of factors is not exhaustive. Additional information on these and other factors that could affect the operations or financial results of Donnybrook are included in Donnybrook's Annual Information Form, management's discussion and analysis and other documents filed with applicable securities regulatory authorities and may be accessed through the SEDAR website (www.sedar.com). The forward-looking statements contained in this press release are made as of the date hereof and Donnybrook undertakes no obligation to update publicly or revise any forward-looking statements, whether as a result of new information, future events or otherwise, unless so required by applicable securities laws. The forward-looking statements contained in this press release are expressly qualified by this cautionary statement.
Where amounts are expressed on a barrel of oil equivalent ("BOE") basis, natural gas volumes have been converted to oil equivalence at six thousand cubic feet per barrel. The term BOE may be misleading, particularly if used in isolation. A BOE conversion ratio of six thousand cubic feet per barrel is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. References to oil in this discussion include crude oil and natural gas liquids ("NGLs"). NGLs include condensate, propane, butane and ethane. References to gas in this discussion include natural gas.
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