VANCOUVER, Feb. 14, 2014 /CNW/ - New Zealand oil and gas producer TAG Oil Ltd. (TSX: TAO) and (OTCQX: TAOIF) is pleased to provide its financial and operating results for the three and nine months ended December 31, 2013. TAG currently has 64,402,052 common shares outstanding (68,085,386 fully diluted) and at December 31, 2013 the Company had cash of $68.5 million, working capital of $71.2 million and no debt.
"We continue to make significant progress on our strategy to deliver long-term shareholder value across all fronts within TAG, as well as achieving consistent profitability which has differentiated us from others in our international peer group." said Garth Johnson, TAG Oil Ltd. Chief Executive Officer. "With record production revenues, cash flow and profits and following completion of extensive infrastructure upgrades which are critical to facilitate anticipated growth, we have increased operational flexibility, which has resulted in committing to New Zealand's most active and diverse exploration campaigns in the country's history. We are confident TAG can continue to deliver value through organic production growth within an extensive drill-ready prospect portfolio consisting of low risk shallow Miocene development and step out wells, and leverage this cash flow into high-impact deep Eocene conventional wells and unconventional prospects in the East Coast."
TAG Oil Third Quarter Fiscal 2014 Highlights Ending December 31, 2013
- Sold 97,616 barrels (nine months: 306,729 barrels) of light oil and 194 mmcf (nine months: 1.23 bcf) of gas.
- Netbacks of approximately $78 per barrel of oil and $4.25 per mcf gas received for a combined netback of $64.63 per BOE compared to average North American netbacks ranging of approximately $34 per BOE.
- Revenue for the three months ended December 31, 2013 increased 19% to $12,939,442 and 35% to $43,522,224 over the nine month period when compared to the same periods last year.
- Net income for the three and nine-month periods ended December 31, 2013 increased 365% and 76%, respectively when compared with the same periods last year.
- Cash provided by operating activities for the nine months to December 31, 2013 increased by 40% to $21.26 million compared to $15.12 million for the same period last year.
- Active shallow drilling program (~2000 meters depth) continues to yield excellent success with five wells drilled within PEP 54877 (Cheal North East - E Site), two wells drilled on PEP 54879 (Cheal South - G Site).
- TAG's first deep well, Cardiff-3 (4,863 meters depth) intersects 45 meters (148 feet) of potential net pay in the K3E zone within the Kapuni Sands Formation.
- Reservoir characterization study on Ngapaeruru-1 well in East Coast Basin unconventional play provides encouraging new data.
- Capital expenditures in the first nine months of fiscal year 2014 were $47.8 million consitsting of drilling 6 shallow Miocene wells, one deep Eocene well and spending $6.92 million on new infrastructure.
|Three Months Ended||Nine Months Ended|
|2014||2013||% Change||2014||2013||% Change|
|Net income (loss)||$2,971,158||$638,521||365%||$8,903,569||$5,056,468||76%|
|Earnings per share (diluted)||$0.05||$0.01||400%||$0.15||$0.08||88%|
|Long term debt||$0||$0||-||$0||$0||-|
Oil and Natural Gas Operations, Production and Pricing
TAG continues to achieve record revenues including net income and cash flow. Operating netbacks of $78 per barrel of oil continue to be substantially higher than what is being achieved in North America, resulting in efficient payback of capital costs and long-term profitable operations.
Q3 FY2014 Oil and Natural Gas Production, Pricing and Revenue (net to TAG basis)
|2014||2013||Nine months ended|
|Daily production volumes(1)|
|Natural gas (BOE/d)||458||891||785||874||831|
|Daily sales volumes(1)|
|Natural gas (BOE/d)||351||782||512||747||581|
|Natural Gas (Mmcf/d)||2,106||4,694||3,070||4,482||3,487|
|Natural gas ($/Mcf)||5.43||5.18||4.79||5.50||4.55|
|Total revenue - gross||$12,939,442||$15,884,584||$10,851,223||$43,522,224||$32,293,424|
|Less other revenue - gross||(881,134)||(861,603)||-||(2,863,656)||-|
|Oil and natural gas revenue - gross||12,058,308||15,022,981||$10,851,223||40,658,568||32,293,424|
|Oil and natural gas royalties(2)||(1,398,536)||(1,632,648)||(1,252,872)||(4,505,048)||(3,659,444)|
|Oil and natural gas Revenue - net||$10,659,772||$13,390,333||$9,598,351||$36,153,520||$28,633,980|
|(1)||Natural gas production converted at 6 Mcf:1BOE (for BOE figures, see BOE definition below)|
|(2)||Includes a 7.5% royalty related to the acquisition of a 69.5% interest in the Cheal field|
|(3)||Other revenue is electricity revenue related to OHL.|
Taranakai Shallow Miocene and Deep Eocene Operations Update
Over the past several years, TAG has focused its efforts on developing the shallow Miocene targets (~2000 meters depth), with excellent success, as shown by thirty-one successful wells drilled to date. Given this success, TAG has added a deep Eocene drilling component to its Taranaki Basin operations with a goal to capture reserves several times larger than what is being achieved in the shallow Miocene drilling program. In the current quarter, TAG successfully drilled, logged and cased its first deep Eocene well, Cardiff-3, which intersected 45 meters (148 feet) of potential pay in the successful Kapuni Formation. The Company anticipates production testing this well in the near future. An independent assessment was prepared by Sproule International Limited with an effective date of July 31, 2013, which has estimated the undiscovered resource potential on the Cardiff prospect on a P50 basis at 160 billion cubic feet gas and 5.59 million barrels of natural gas liquids(1). Sproule is a qualified reserves evaluator in accordance with NI 51-101 and the Canadian Oil and Gas Evaluations Handbook.
TAG Oil's shallow Miocene drilling program has continued concurrently with the deep Eocene drilling program; most recently eight oil wells have been drilled from the Company's Cheal-E and G sites, delineating a much larger oil saturated area than originally anticipated at the Cheal field. Utilizing TAG's 100% owned processing infrastructure, testing and first production has commenced on three of the five wells drilled from the Cheal E Site, with over 50,000 barrels of light oil produced to date from the new discovery site. The recent drilling success in the Cheal-E and G sites provides TAG with many years of low-risk development drilling opportunities and additional step out locations, such as the coming Southern Cross well that could further expand the scope and size of the Cheal pool.
East Coast Basin Update
TAG has now received the results of the Reservoir Characterization Study ("RCS") from independent experts in unconventional plays on the Ngapaeruru-1 well, the first ever East Coast Basin unconventional test well. The RCS study provides the first true unconventional data set ever acquired in the East Coast Basin and provides a number of encouraging attributes, and importantly confirmation that TAG's drilling mudlog interpretations from the Ngapaeruru-1 well demonstrate that oil is being generated in the Whangai source rocks.
Given the results of the study, TAG will now perforate and production test Ngapaeruru-1 in the coming months; with the goal being to prove the concept of moveable hydrocarbons from within the source rocks, a critical step to pursuing the economic viability of this unconventional play.
Details of the RCS report indicate a number of positives with respect to the Whangai source rocks as a viable unconventional oil target:
|a)||The Whangai Formation source rocks penetrated in Ngapaeruru-1 is 293 meters thick, it's highly naturally fractured, the fractures are open, and each fracture zone correlates well with elevated oil and gas mudlog shows.|
|b)||The hydrocarbon-filled porosity exceeds the minimum standard thresholds for unconventional reservoirs.|
|c)||Permeabilities within the Whangai section exceed standard unconventional reservoir thresholds|
|d)||The Whangai Formation has very low clay content, indicating fracture stimulation can be highly effective.|
|e)||Vitrinite reflectance analysis places the Whangai source rocks in the oil/condensate window, correlating well with the 50-degree API oil seeps in this basin.|
|f)||Ngapaeruru-1 intercepted a lateral equivalent of the true organic rich Whangai source rocks interpreted in the basin from oil seep fingerprinting, indicating that the Whangai source rocks have lateral variations as expected.|
|g)||A deeper basinal setting (which is planned for the next two wells in the program) will look to identify increased TOC contents of the reservoir, which at Ngapaeruru-1 is slightly less than 1% (with 2% being the standard threshold) indicating subsequent wells may be more optimally located to intercept the ideal source rock origin.|
The quality of the data set acquired at Ngapaeruru-1 is state-of-the-art, and, as expected, has provided the first ever specialized interpretation necessary to help unlock the major potential of this unconventional play.
TAG Oil Ltd.
TAG Oil Ltd. (http://www.tagoil.com/) is a Canadian-based production and exploration company with operations focused exclusively in New Zealand. With 100% ownership over all its core assets, including extensive oil and gas production infrastructure, TAG is enjoying significant organic value creation through exploration success and ongoing development and appraisal drilling of several light oil and gas discoveries. As New Zealand's leading explorer, TAG actively drills high-impact conventional and unconventional exploration prospects identified in the Taranaki Basin, East Coast Basin and Canterbury Basin that covers more than 2.7 million net acres of land, prospective for major discovery in New Zealand.
TAG Oil has adopted the standard of six thousand cubic feet of gas to equal one barrel of oil when converting natural gas to "BOEs". BOEs may be misleading, particularly if used in isolation. A BOE conversion ratio of 6Mcf: 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.
(1) Cardiff Resource Estimates Footnote:
Best Estimate is considered to be the best estimate of the in-place volumes that will actually be present. It is equally likely that the actual in-place volumes will be greater or less than the best estimate. If probabilistic methods are used, there should be at least a 50 percent probability (P50) that the in-place volumes will equal or exceed the best estimate.
Undiscovered Petroleum Initially-In-Place (equivalent to undiscovered resources) is that quantity of petroleum that is estimated, on a given date, to be contained in accumulations yet to be discovered. The recoverable portion of undiscovered petroleum initially in place is referred to as "prospective resources," the remainder as "unrecoverable."
Prospective resources are those quantities of petroleum estimated, as of a given date, to be potentially recoverable from undiscovered accumulations by application of future development projects. Prospective resources have both an associated chance of discovery and a chance of development. There is no certainty that any portion of the resources will be discovered. If discovered, there is no certainty that it will be commercially viable to produce any portion of the resources.
Exploration for hydrocarbons is a speculative venture necessarily involving substantial risk. TAG's future success in exploiting and increasing its current reserve base will depend on its ability to develop its current properties and on its ability to discover and acquire properties or prospects that are capable of commercial production. However, there is no assurance that TAG's future exploration and development efforts will result in the discovery or development of additional commercial accumulations of oil and natural gas. In addition, even if further hydrocarbons are discovered, the costs of extracting and delivering the hydrocarbons to market and variations in the market price may render uneconomic any discovered deposit. Geological conditions are variable and unpredictable. Even if production is commenced from a well, the quantity of hydrocarbons produced inevitably will decline over time, and production may be adversely affected or may have to be terminated altogether if TAG encounters unforeseen geological conditions. TAG is subject to uncertainties related to the proximity of any reserves that it may discover to pipelines and processing facilities. It expects that its operational costs will increase proportionally to the remoteness of, and any restrictions on access to, the properties on which any such reserves may be found. Adverse climatic conditions at such properties may also hinder TAG's ability to carry on exploration or production activities continuously throughout any given year.
The significant positive factors that are relevant to the resource estimate are:
- Proven production in close proximity;
- Proven commercial quality reservoirs in close proximity; and
- Oil and gas shows while drilling wells nearby.
The significant negative factors that are relevant to the resource estimate are:
- Tectonically complex geology could compromise seal potential; and
- Seismic attribute mapping in the two, deep, liquids-rich gas plays can be indicative but not certain in identifying proven resource.
Cautionary Note Regarding Forward-Looking Statements:
Statements contained in this news release that are not historical facts are forward-looking statements that involve various risks and uncertainty affecting the business of TAG. Such statements can be generally, but not always, identified by words such as "expects", "plans", "anticipates", "intends", "estimates", "forecasts", "schedules", "prepares", "potential" and similar expressions, or that events or conditions "will", "would", "may", "could" or "should" occur. All estimates and statements that describe the Company's objectives, goals, production rates, test rates, optimization, infrastructure capacity timing of operations and or future plans with respect to the drilling and testing in the Taranaki and East Coast Basins are forward-looking statements under applicable securities laws and necessarily involve risks and uncertainties including, without limitation: risks associated with oil and gas exploration, development, exploitation and production, geological risks, marketing and transportation, availability of adequate funding, volatility of commodity prices, environmental risks, competition from other producers, and changes in the regulatory and taxation environment. Actual results may vary materially from the information provided in this release, and there is no representation by TAG Oil that the actual results realized in the future would be the same in whole or in part as those presented herein.
Other factors that could cause actual results to differ from those contained in the forward-looking statements are also set forth in filings that TAG and its independent evaluator have made, including TAG's most recently filed reports in Canada under NI 51-101, which can be found under TAG's SEDAR profile at www.sedar.com.
TAG undertakes no obligation, except as otherwise required by law, to update these forward-looking statements in the event that management's beliefs, estimates or opinions, or other factors change.
SOURCE: TAG Oil Ltd.
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