CALGARY, ALBERTA–(Marketwired – May 31, 2016) Manitok Energy Inc. (the “Corporation” or “Manitok“) (TSX VENTURE:MEI) announces its financial and operating results for the first quarter of 2016 and provides an operational update.
The full text of Manitok’s first quarter results are contained in its unaudited condensed interim financial statements as at and for the three months ended March 31, 2016 and the related management’s discussion and analysis, copies of which are available electronically on Manitok’s profile on the System for Electronic Document Analysis and Retrieval (“SEDAR“) at www.sedar.com and also on Manitok’s website at www.manitokenergy.com.
First Quarter 2016 Results:
- Production averaged 4,407 boe/d (46% light oil and liquids) as compared to 4,504 boe/d (52% light oil and liquids) in the first quarter of 2015.
- Recorded funds from operations of $13.0 million, which included monetized crude oil derivative financial instruments for a portion of 2016 and all of 2017 for a cash receipt of $12.3 million, which was a 65% increase over funds from operations of $7.9 million in the first quarter of 2015. Manitok remains hedged on 1,500 bbls/d of crude oil to the end of 2016, which is anticipated to be about 90% to 95% of its net crude oil production after royalties.
- Operating netback was $9.79/boe before the realized gain of $12.3 million or $30.67/boe on the monetized crude oil derivative financial instruments, which together totals the $40.46/boe netback achieved in the quarter.
- As at March 31, 2016, Manitok reduced net bank debt by $8.7 million to $44.7 million from $53.4 million as at December 31, 2015.
- Capital expenditures before acquisition and divestitures were $1.6 million as compared to $4.7 million in the first quarter of 2015. Capital expenditures after acquisition and divestitures were $6.2 million as compared to $4.9 million in the first quarter of 2015.
- In February 2016, Manitok closed a non-cash asset exchange agreement with an effective date of November 1, 2015, in which Manitok divested of a 19.9% non-operated working interest in a gas plant, where it had no current throughput volumes or value in its latest reserve report, in exchange for a 17.5% average working interest in petroleum and natural gas production in its Stolberg Cardium F oil pool, along with an average 45% working interest in 10,560 acres of undeveloped land in its core Stolberg property. Manitok recorded a gain on the divestiture of the gas plant of $6.9 million for the three months ended March 31, 2016.
- In March 2016, Manitok closed the acquisition of a 14 Mmcf/d natural gas processing plant in Carseland including approximately 450 mcf/d (75 boe/d) of natural gas production, undeveloped land and an 11 kilometre sales gas line tied into the ATCO system, with an effective date of January 1, 2016. Total cash consideration for the acquisition was $4.5 million after estimated post-closing adjustments and was financed using the Corporation’s credit facility.
Operational and Financial Summary
| Three months ended March 31, | 2016 | 2015 | |||
| Operating | |||||
| Average daily production | |||||
| Light oil (bbls/d) | 1,812 | 2,269 | |||
| Natural gas (mcf/d) | 14,305 | 13,049 | |||
| NGLs (bbls/d) | 211 | 61 | |||
| Total (boe/d) | 4,407 | 4,504 | |||
| Average realized sales price | |||||
| Light oil ($/bbl) | 36.48 | 48.77 | |||
| Natural gas ($/mcf) | 2.03 | 2.89 | |||
| NGLs ($/bbl) | 21.58 | 52.85 | |||
| Total ($/boe) | 22.63 | 33.66 | |||
| Undeveloped land (end of period) | |||||
| Gross (acres) | 470,805 | 294,295 | |||
| Net (acres) | 434,121 | 272,729 | |||
| Netback and Cost ($ per boe) | |||||
| Petroleum and natural gas sales | 22.63 | 33.66 | |||
| Realized gain (loss) on financial instruments | 39.72 | 13.54 | |||
| Royalty income | – | – | |||
| Royalty expenses | (6.24 | ) | (8.47 | ) | |
| Operating expenses, net of recoveries | (14.12 | ) | (10.38 | ) | |
| Transportation and marketing expenses | (1.53 | ) | (2.87 | ) | |
| Operating netback(1) | 40.46 | 25.48 | |||
| General and administrative expenses, net of recoveries | (3.85 | ) | (4.34 | ) | |
| Interest and financing expenses | (4.14 | ) | (1.62 | ) | |
| Interest and other income | 0.02 | 0.02 | |||
| Funds from operations netback(1) | 32.49 | 19.54 | |||
| Financial | |||||
| Petroleum and natural gas revenue ($000) | 9,074 | 13,645 | |||
| Funds from operations ($000)(1) | 13,035 | 7,918 | |||
| Per share – basic and diluted ($)(1) | 0.08 | 0.12 | |||
| Net income (loss) ($000) | 3,602 | (3,401 | ) | ||
| Per share – basic and diluted ($)(2) | 0.02 | (0.05 | ) | ||
| Common shares outstanding | |||||
| End of period – basic | 161,079,746 | 65,279,607 | |||
| End of period – diluted | 177,452,639 | 71,719,880 | |||
| Weighted average for the period – basic | 156,066,181 | 65,279,607 | |||
| Weighted average for the period – diluted | 156,339,714 | 65,279,607 | |||
| Capital expenditures ($000) | 6,166 | 4,901 | |||
| Adjusted working capital deficit (surplus) ($000)(1) | 141 | (2,313 | ) | ||
| Drawn on credit facilities ($000) | 44,529 | 75,379 | |||
| Net bank debt(1) ($000) | 44,670 | 73,066 | |||
| Long-term financial obligations ($000) | 14,925 | 2,494 | |||
| Net debt(1) ($000) | 59,595 | 75,560 | |||
| (1) | Funds from operations, funds from operations per share, funds from operations netback, operating netback, adjusted working capital deficit (surplus), net bank debt and net debt do not have standardized meanings prescribed by generally accepted accounting principles and therefore should not be considered in isolation. These reported amounts and their underlying calculations are not necessarily comparable or calculated in an identical manner to a similarly titled measure of other companies where similar terminology is used. Where these measures are used they should be given careful consideration by the reader. Refer to the Non-GAAP Measures section of this press release. |
| (2) | The basic and diluted weighted average shares outstanding are the same for periods in which the Corporation records a net loss and when all the outstanding stock options and warrants are anti-dilutive. |
Financial Update Subsequent to the First Quarter of 2016
In May 2016, Manitok closed the first tranche of its private placement equity financing for the issuance of 8,435,945 common shares in the capital of Manitok (“Manitok Shares“) at a price of $0.18 per Manitok Share and 7,994,980 Manitok Shares issued on a “flow-through” basis in respect of Canadian exploration expense under the Income Tax Act (Canada) (the “Manitok CEE Flow-through Shares“) at a price of $0.21 per Manitok CEE Flow-through Share for aggregate gross proceeds of $3.2 million. The net cash proceeds from the Manitok Shares were used to reduce the Corporation’s bank indebtedness and the net cash proceeds from the Manitok CEE Flow-through Shares will be used to incur eligible Canadian exploration expenses.
As at May 31, 2016, Manitok anticipates its net bank debt will be approximately $43.5 million. The Corporation’s credit facility is currently $48.8 million and the next customary review date has been set for June 2016. Details of the credit facility are in the 2016 first quarter report, a copy of which is available under Manitok’s SEDAR profile at www.sedar.com and also on Manitok’s website at www.manitokenergy.com.
Manitok’s anticipated 2016 oil production, net of royalties, is approximately 90% to 95% hedged with a swap of 500 bbls/d of crude oil at $80.15 CAD WTI and collar transactions for 1,000 bbls/d of crude oil from an average price of $68.68 to $86.18 CAD WTI net of the deferred premium.
Manitok anticipates it will begin its 2016 drilling program in the second half of the year, with a minimum of approximately $11.0 million of drilling and completion spending funded by its funds from operations, credit facility and proceeds from the recently announced equity financing, which along with the drilling activity pursuant to a farm-out agreement, is anticipated to satisfy Manitok’s drilling commitments for 2016. The Corporation’s capital plan will be flexible and if warranted, Manitok will be able to increase the drilling and completions spending should commodity prices improve over the course of 2016.
Operational Update
Manitok’s production during the first two weeks of May 2016 has averaged approximately 3,637 boe/d (46% oil) based on field estimates. This production incorporates downtime in southeast Alberta, mainly due to the recently acquired Carseland gas plant modifications over 10 days, which represented approximately 630 boe/d (37% oil). The modifications were completed on budget and the plant is operational. Also impacting production in the first two weeks of May, is an additional 170 boe/d (67% oil) of production that was shut-in at Stolberg in advance of a scheduled third party gas plant turnaround which began May 15, 2016 and 92 boe/d (100% gas) that has been temporarily shut-in on Manitok’s non-core properties due to low natural gas prices. It is anticipated that there will be no long term negative effects associated with the wells being shut-in. These shut-in wells will immediately be placed back on production, once natural gas prices improve to levels that generate positive cash flow.
Additionally, a third party gas plant turnaround in Stolberg began May 15, 2016 and Manitok anticipates its completion by early June 2016. Based on field estimates, production associated with the downtime is approximately 2,050 boe/d (39% oil) which includes the 170 boe/d mentioned in the paragraph above. Once the turnaround is complete, all of its Cardium oil production of approximately 1,325 boe/d (61% oil) will be placed back on production. Approximately 725 boe/d (100% gas) will remain temporarily shut-in due to low natural gas prices and it is anticipated that there will be no long term negative effects associated with the natural gas wells being shut-in. These shut-in wells will immediately be placed back on production, once natural gas prices improve to levels that generate positive cash flow.
About Manitok
Manitok is a public oil and gas exploration and development company focusing on conventional oil and gas reservoirs in southeast Alberta and the Canadian foothills. The Corporation will utilize its experience to develop the untapped conventional oil and liquids-rich natural gas pools in both the southeast Alberta and foothills areas of the Western Canadian Sedimentary Basin.
