CALGARY, Nov. 7, 2014 /CNW/ - Enerplus Corporation ("Enerplus") (TSX: ERF) (NYSE: ERF) continued to deliver consistent, strong operational and financial performance during the third quarter of 2014.
|SELECTED FINANCIAL RESULTS|
|Three months ended September 30,||Nine months ended September 30,|
|Cash and Stock Dividends||55,438||54,405||165,587||162,199|
|Debt Outstanding - net of cash||1,091,110||964,577||1,091,110||964,577|
|Property and Land Acquisitions||3,986||15,792||17,186||71,451|
|Debt to Trailing 12-Month Funds Flow||1.3x||1.2x||1.3x||1.2x|
|Financial per Weighted Average Shares Outstanding|
|Net Income (Basic)||0.33||(0.02)||0.72||0.09|
|Weighted Average Number of Shares Outstanding (000's)||205,164||201,117||204,174||200,002|
|Selected Financial Results per BOE(1)(2)|
|Oil & Natural Gas Sales(3)||$||46.13||$||53.61||$||50.66||$||49.67|
|Royalties and Production Taxes||(10.36)||(11.91)||(11.31)||(10.46)|
|Commodity Derivative Instruments||(0.26)||(1.30)||(1.52)||0.42|
|General and Administrative||(1.97)||(2.48)||(2.08)||(2.63)|
|Interest, Foreign Exchange and Other Expenses||(1.18)||(1.78)||(1.48)||(1.78)|
|SELECTED OPERATING RESULTS|
|Three months ended September 30,||Nine months ended September 30,|
|Average Daily Production(2)|
|Crude oil (bbls/day)||40,332||38,883||39,328||38,426|
|Natural gas (Mcf/day)||359,007||275,164||356,288||279,212|
|% Natural Gas||58%||52%||58%||53%|
|Average Selling Price(2)(3)|
|Crude oil (per bbl)||$||86.49||$||96.30||$||90.91||$||86.05|
|NGLs (per bbl)||44.85||49.88||53.01||51.48|
|Natural gas (per Mcf)||3.22||2.96||4.04||3.26|
|Net Wells drilled||19||15||63||50|
|(1)||Non-cash amounts have been excluded.|
|(2)||Based on Company interest production volumes. See "Basis of Presentation" section in the following MD&A.|
|(3)||Net of oil and gas transportation costs, but before royalties and the effects of commodity derivative instruments.|
|Three months ended September 30,||Nine months ended September 30,|
|Average Benchmark Pricing||2014||2013||2014||2013|
|WTI crude oil (US$/bbl)||$97.17||$105.82||$99.61||$98.14|
|AECO- monthly index (CDN$/Mcf)||4.22||2.82||4.55||3.16|
|AECO- daily index (CDN$/Mcf)||4.02||2.43||4.81||3.05|
|NYMEX- last day (US$/Mcf)||4.06||3.58||4.55||3.67|
|USD/CDN exchange rate||1.09||1.04||1.09||1.02|
|Share Trading Summary||CDN* - ERF||U.S.** - ERF|
|For the three months ended September 30, 2014||(CDN$)||(US$)|
|*||TSX and other Canadian trading data combined.|
|**||NYSE and other U.S. trading data combined.|
|2014 Dividends per Share||CDN$||US$(1)|
|First Quarter Total||$0.27||$0.24|
|Second Quarter Total||$0.27||$0.24|
|Third Quarter Total||$0.27||$0.24|
|(1)||US$ dividends represent CDN$ dividends converted at the relevant foreign exchange rate on the payment date.|
|Production and Capital Spending||
Three months ended
September 30, 2014
Nine months ended
September 30, 2014
|Crude Oil & NGLs (BOE/day)||
|Total Crude Oil & NGLs (BOE/day)||44,201||$133||42,919||$383|
|Natural Gas (Mcf/day)|
|Total Natural Gas (Mcf/day)||359,006||$75||356,288||$247|
|Company Total (BOE/day)||104,035||$208||102,300||$630|
|Net Drilling Activity - for the three months ended September 30, 2014|
|Total Crude Oil||10.0||-||10.0||8.8||11.1||-|
|Total Natural Gas||9.3||-||9.3||8.3||6.2||-|
|*||Wells drilled during the quarter that are pending potential completion/tie-in or abandonment as at September 30, 2014.|
|**||Total wells brought on-stream during the quarter regardless of when they were drilled.|
Drilling activity continued at a brisk pace in Fort Berthold during the third quarter with 6.6 net wells drilled and 5.6 net wells brought on-stream. Production grew again to average 22,400 BOE per day, up almost 1,600 BOE per day from the second quarter. Year-to-date, we have continued to drill into both the Bakken and Three Forks zones with 10 operated wells and 2.4 net non-operated wells brought on-stream. Production performance has continued to improve as a result of our completion optimization activity. The 30 day initial production rates on our two mile horizontal wells brought on-stream in 2014 have averaged 1,725 barrels per day, 20% above our high expected ultimate recovery type curve. We are also seeing an improvement of over 10% in the 60 day production rates which have averaged approximately 1,400 barrels per day.
In the Marcellus, drilling activity continued with 7.2 net wells drilled and 5.4 net wells brought on-stream. Basis differentials in the region continued to widen as a result of on-going production growth and the shortage of take-away capacity. Our Marcellus production received a discount of US$1.72 per Mcf to the NYMEX benchmark price during the quarter. As a result of the lower prices in the region, combined with pipeline maintenance, 3,000 - 4,000 BOE per day of production was intentionally curtailed during the quarter. Despite this curtailment, production from the Marcellus was essentially unchanged from the second quarter, averaging 187 MMcf per day. Plans are currently underway to slow our pace of activity, moving from a four-rig program to a two-rig program. As a result, we expect capital spending on our Marcellus assets in the fourth quarter to be meaningfully lower than in the third quarter.
As discussed earlier in the year, Enerplus has drilled and completed two horizontal Duvernay wells in the Willesden Green area of central Alberta. Our initial horizontal well at 1-7-45-5W5M was completed in the first quarter of 2014 with a 13 stage hybrid slickwater frac. The well was subsequently shut-in for installation of surface equipment and pipeline tie-in. In late June, we brought this well on production achieving a 30 day initial production rate of 535 BOE per day including 2.24 MMcf per day of sales gas with 162 barrels per day of total liquids, 53% condensate.
Our second horizontal well at 15-8-46-9W5M was completed in the second quarter of this year with a 14 stage hybrid slickwater frac. This well was also shut-in while surface equipment and pipelines were installed to a third party gas plant and oil battery in the area. We brought this well on-stream in early October and during the first 30 days of production, it has averaged an estimated 700 BOE per day including 1.75 MMcf per day of sales gas, with 410 barrels per day of liquids, roughly 85% condensate.
Both wells have met our expectations on liquids content based upon our geotechnical analysis. The cost of these wells was higher than we expected, particularly on the completions, which is similar to what others have experienced in this deep, over-pressured play. We see a number of opportunities to increase drilling and completion efficiencies going forward, particularly with multi-well pads. Further evaluation of these wells over the coming months is required in order to determine our next steps.
2014 GUIDANCE UPDATE
A summary of our revised 2014 guidance is outlined below.
|Average annual production||102,000 - 104,000 BOE/day (from 100,000 - 104,000 BOE/day)|
|Production mix (volume)||
44,000 bbls/day crude oil and natural gas liquids
58,000 - 60,000 BOE/day natural gas (from 56,000 - 60,000 BOE/day)
|Capital spending||$830 million (from $800 million)|
Average royalty rate
(% of gross sales, net of transportation)
|Operating costs||$10.25/BOE (from $10.10/BOE)|
|Cash G&A expenses||$2.30/BOE|
|Cash share-based compensation expenses||$0.45/BOE (from $0.60/BOE)|
|U.S. Cash taxes (% of U.S. funds flow)||2% (from 3% - 5%)|
Despite the current decline in crude oil prices, Enerplus is very well positioned. Based upon our revised production guidance, we expect to deliver above-average production growth of 13% per share in 2014. Our dividend payout is conservative and our balance sheet is very strong. Our debt-to-trailing 12 month funds flow ratio was 1.3 times at the end of the quarter and we have virtually all of our $1 billion revolving line of credit available. We also have a significant portion of our crude oil production hedged for the remainder of 2014 and into 2015 at prices well above the current market. We anticipate that these positions will provide strong funds flow protection through the fourth quarter and into 2015, lending support for our plans for the remainder of this year and next.
Our preliminary plans for 2015 target continued production growth of 5 - 10% per share with a modestly lower capital spending program than in 2014. We have a significant portfolio of economic development opportunities in both crude oil and natural gas that are expected to provide us with organic growth potential for many years. We expect to maintain our strong financial position. We will continue to apply discipline to our capital spending program, ensuring that our plans are affordable and that our business is sustainable.
CONFERENCE CALL DETAILS
A conference call hosted by Ian C. Dundas, President and CEO will be held at 9:00AM MT (11:00AM ET) today to discuss these results. Details of the conference call are as follows:
|Live Conference Call|
|Date:||Friday, November 7, 2014|
|Time:||9:00AM MT / 11:00AM ET|
|888-231-8191 (toll free)|
To ensure timely participation in the conference call, callers are encouraged to dial in 15 minutes prior to the start time to register for the event. A podcast of the conference call will be available on our website for downloading. A telephone replay will be available for 30 days following the conference call. The telephone replay can be accessed at the following numbers:
|1-855-859-2056 (toll free)|
Electronic copies of our Third Quarter 2014 MD&A and Financial Statements, along with other public information including investor presentations, are available on our website at www.enerplus.com. For further information, please contact Investor Relations at 1-800-319-6462 or email email@example.com.
Follow @EnerplusCorp on Twitter at https://twitter.com/EnerplusCorp.
Currency and Accounting Principles
All amounts in this news release are stated in Canadian dollars unless otherwise specified. All financial information in this news release has been prepared and presented in accordance with U.S. GAAP, except as noted below under "Non-GAAP Measures".
Barrels of Oil Equivalent
This news release also contains references to "BOE" (barrels of oil equivalent). Enerplus has adopted the standard of six thousand cubic feet of gas to one barrel of oil (6 Mcf: 1 bbl) when converting natural gas to BOEs. BOEs may be misleading, particularly if used in isolation. The foregoing conversion ratios are based on an energy equivalency conversion method primarily applicable at the burner tip and do not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of oil as compared to natural gas is significantly different from the energy equivalent of 6:1, utilizing a conversion on a 6:1 basis may be misleading.
Presentation of Production Information
Under U.S. GAAP, oil and gas sales are generally presented net of royalties and U.S. industry protocol is to present production volumes net of royalties. Under Canadian industry protocol, oil and gas sales and production volumes are presented on a gross basis before deduction of royalties. In order to continue to be comparable with our Canadian peer companies, the summary results contained within this news release presents our production and BOE measures on a before royalty company interest basis. All production volumes and revenues presented herein are reported on a company interest basis, before deduction of Crown and other royalties, plus Enerplus' royalty interest.
See "Non-GAAP Measures" below.
FORWARD-LOOKING INFORMATION AND STATEMENTS
This news release contains certain forward-looking information and forward-looking statements within the meaning of applicable securities laws ("forward-looking information"). The use of any of the words "expect", "anticipate", "continue", "estimate", "guidance", "objective", "ongoing", "may", "will", "project", "should", "believe", "plans", "intends", "budget", "strategy" and similar expressions are intended to identify forward-looking information. In particular, but without limiting the foregoing, this news release contains forward-looking information pertaining to the following: expected 2014 and 2015 average production volumes and the anticipated production mix; the proportion of our anticipated oil and gas production that is hedged; the results from our drilling program and the timing of related production; future oil and natural gas prices and differentials and our commodity risk management programs; expectations regarding our realized oil and natural gas prices; future royalty rates on our production and future production taxes; anticipated cash and non-cash G&A, share-based compensation and financing expenses; operating costs; capital spending levels in the remainder of 2014 and in 2015 and its impact on our production level; our future U.S. cash taxes; deferred income taxes, our tax pools and the time at which we may pay Canadian cash taxes and regular U.S. taxes; future debt and working capital levels and debt-to-funds-flow ratio and adjusted payout ratio, financial capacity, liquidity and capital resources to fund capital spending and working capital requirements; the amount and timing of future cash dividends that we may pay to our shareholders; and future dispositions, including expected proceeds therefrom and production volumes associated therewith.
The forward-looking information contained in this news release reflects several material factors, expectations and assumptions including, without limitation: that we will conduct our operations and achieve results of operations as anticipated; that our development plans will achieve the expected results; the general continuance of current or, where applicable, assumed industry conditions; the continuation of assumed tax, royalty and regulatory regimes; the accuracy of the estimates of our reserve and resource volumes; commodity price and cost assumptions; the continued availability of adequate debt and/or equity financing and funds flow to fund our capital, operating and working capital requirements, and dividend payments as needed; the continued availability and sufficiency of our funds flow and availability under our bank credit facility to fund our working capital deficiency; the availability of third party services; and the extent of our liabilities. We believe the material factors, expectations and assumptions reflected in the forward-looking information are reasonable but no assurance can be given that these factors, expectations and assumptions will prove to be correct.
The forward-looking information included in this news release is not a guarantee of future performance and should not be unduly relied upon. Such information involves 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 including, without limitation: changes in commodity prices; changes in realized prices of Enerplus' products; changes in the demand for or supply of our products; unanticipated operating results, results from our capital spending activities or production declines; changes in tax or environmental laws, royalty rates or other regulatory matters; changes in our capital plans or by third party operators of our properties; increased debt levels or debt service requirements; inaccurate estimation of our oil and gas reserve and resource volumes; limited, unfavourable or a lack of access to capital markets; increased costs; a lack of adequate insurance coverage; the impact of competitors; reliance on industry partners and third party service providers; a failure to complete planned asset dispositions on the terms anticipated or at all; and certain other risks detailed from time to time in our public disclosure documents (including, without limitation, those risks and contingencies described under "Risk Factors and Risk Management" in our MD&A for the year ended December 31, 2013 and in our other public filings).
The forward-looking information contained in this news release speaks only as of the date of this news rlease, and we do not assume any obligation to publicly update or revise such forward-looking information to reflect new events or circumstances, except as may be required pursuant to applicable laws.
In this news release, we use the terms "funds flow" and "debt-to-funds flow ratio" as measures to analyze operating performance, leverage and liquidity. "Funds flow" is calculated as net cash generated from operating activities but before changes in non-cash operating working capital and asset retirement obligation expenditures. "Debt-to-funds flow ratio" is used to analyze leverage and liquidity and is calculated as total debt net of cash, divided by a trailing 12 months of funds flow.
Enerplus believes that, in addition to net earnings and other measures prescribed by U.S. GAAP, the terms "funds flow", and "debt-to-funds flow ratio" are useful supplemental measures as they provide an indication of the results generated by Enerplus' principal business activities. However, these measures are not measures recognized by U.S. GAAP and do not have a standardized meaning prescribed by U.S. GAAP. Therefore, these measures, as defined by Enerplus, may not be comparable to similar measures presented by other issuers. See disclosure under "Non-GAAP Measures" in our Third Quarter MD&A for reconciliation of these measures to the most directly comparable measures circulated in accordance with U.S. GAAP.
SOURCE Enerplus Corporation
Video with caption: "Video: Q3 Q&A with President and CEO, Ian C. Dundas". Video available at: http://stream1.newswire.ca/cgi-bin/playback.cgi?file=20141107_C9461_VIDEO_EN_43192.mp4&posterurl=http://photos.newswire.ca/images/20141107_C9461_PHOTO_EN_43192.jpg&clientName=Enerplus%20Corporation&caption=Video%3A%20Q3%20Q%26A%20with%20President%20and%20CEO%2C%20Ian%20C%2E%20Dundas&title=ENERPLUS%20CORPORATION%20%2D%20Enerplus%20Continues%20Operational%20Momentum%20in%20Third%20Quarter%202014%20%26%20Increases%20Annual%20Production%20Guidance&headline=Enerplus%20Continues%20Operational%20Momentum%20in%20Third%20Quarter%202014%20%26%20Increases%20Annual%20Production%20Guidance
For further information:
Ian C. Dundas
President & Chief Executive Officer