CALGARY, May 3, 2018 /CNW/ – Enerplus Corporation (“Enerplus” or the “Company”) (TSX & NYSE: ERF) is pleased to announce first quarter 2018 operating and financial results. The Company reported first quarter 2018 net income of $29.6 million or $0.12 per share.
HIGHLIGHTS
“Our plans are well on track to continue to drive competitive, profitable growth while generating robust returns on capital,” stated Ian C. Dundas, President and Chief Executive Officer. “With our continued margin expansion resulting from improved pricing realizations and reductions to our cost structure over the last year, we expect to generate meaningful free cash flow in 2018 under current strip prices. Additionally, we expect to deliver over 30% production growth from our high-returning North Dakota asset. Despite the improving crude oil price outlook, we remain committed to our disciplined approach to capital allocation focused on generating full-cycle returns and creating long-term value for our shareholders.”
FIRST QUARTER FINANCIAL AND OPERATIONAL SUMMARY
Production
Production in the first quarter of 2018 averaged 85,080 BOE per day, including 41,528 barrels per day of crude oil (90%) and natural gas liquids (10%). As forecast, liquids production was lower compared to the prior quarter primarily due to downtime related to completions activity on adjacent properties and on-stream activity in North Dakota weighted to the back half of the first quarter.
Natural gas production for the first quarter averaged 261 MMcf per day, a 4% increase from the prior quarter primarily due to higher Marcellus production supported by stronger natural gas pricing.
The Company remains well positioned relative to its 2018 production guidance with strong growth underway in the second quarter. Four wells from a high-working interest six-well pad in North Dakota began flowing back at strong initial rates in late April, with the two remaining wells expected on-stream in early May. Based on field estimates, current liquids production is averaging approximately 49,000 barrels per day. Enerplus is expecting second quarter liquids production to average 48,000 to 50,000 barrels per day.
Net Income, Adjusted Funds Flow and Netback
Enerplus generated net income of $29.6 million in the first quarter of 2018, an increase from $15.3 million in the previous quarter as a result of lower non-cash income tax expense in the first quarter.
Adjusted funds flow was $155.2 million during the first quarter, compared to $199.6 million in the previous quarter which included $50.1 million related to the U.S. Alternative Minimum Tax refund. Adjusted funds flow remained strong in the first quarter supported by higher benchmark oil and natural gas prices and a hedging gain related to the unwinding of a portion of the Company’s AECO – NYMEX basis contracts.
Enerplus’ netback, before commodity hedging, was $21.97 per BOE in the first quarter of 2018. This represents a 2% increase from the prior quarter and a 22% increase from the same period in 2017.
Pricing Realizations and Cost Structure
Enerplus’ realized Bakken crude oil price differential averaged US$3.27 per barrel below WTI in the first quarter, weaker than the previous quarter’s differential of US$1.61 per barrel largely driven by the 13% increase in average benchmark WTI oil prices quarter-over-quarter. As a result of the recent strength in WTI oil prices and with the current 2018 forward strip at approximately US$65 per barrel, Enerplus is increasing its estimated 2018 average Bakken crude oil price differential to US$3.50 per barrel below WTI, from US$2.50 per barrel below WTI previously.
Enerplus’ realized Marcellus natural gas price differential strengthened considerably to US$0.21 per Mcf below NYMEX in the first quarter, an improvement of US$0.60 per Mcf from the prior quarter. This pricing improvement was due to the continued build-out of regional pipeline takeaway capacity as well as the effect of a colder than normal winter, which resulted in price spikes in key consumption regions in the U.S. Enerplus expects its Marcellus differential to increase during the remainder of 2018 as a portion of its sales portfolio is linked to New York markets that are typically weaker during the summer months. Enerplus continues to project an average 2018 differential of US$0.40 per Mcf below NYMEX.
First quarter operating, transportation, and cash general and administrative (“G&A”) expenses were all largely in-line with the Company’s annual 2018 guidance. First quarter operating expenses averaged $7.02 per BOE, transportation costs averaged $3.52 per BOE, and cash G&A expenses averaged $1.72 per BOE. Enerplus’ 2018 guidance for these items remains unchanged.
Capital Expenditures and Balance Sheet Position
Exploration and development capital spending in the first quarter was $151.5 million associated with drilling 13.9 net wells and completing and bringing on production 8.9 net wells across the Company. Enerplus’ 2018 capital spending guidance of $535 million to $585 million is unchanged.
Enerplus remains in a strong financial position. Total debt net of cash at March 31, 2018 was $292 million. Total debt was comprised of $688.4 million of senior notes outstanding. The Company was undrawn on its $800 million bank credit facility, and had a cash balance of $396.4 million. At March 31, 2018, Enerplus’ net debt to adjusted funds flow ratio was 0.5 times.
AVERAGE DAILY PRODUCTION(1)
|
Three months ended March 31, 2018 |
||||
|
Crude Oil (Mbbl/d) |
Natural (Mbbl/d) |
Natural gas (MMcf/d) |
Total (Mboe/d) |
|
|
Williston Basin |
27.7 |
2.8 |
19.8 |
33.8 |
|
Marcellus |
0.0 |
0.0 |
208.4 |
34.7 |
|
Canadian Waterfloods |
9.4 |
0.1 |
5.0 |
10.3 |
|
Other(2) |
0.4 |
1.1 |
28.2 |
6.2 |
|
Total |
37.4 |
4.1 |
261.3 |
85.1 |
|
(1) |
Table may not add due to rounding. |
|
(2) |
Includes approximately 600 boe/d of production from Canadian natural gas properties sold in Q1 2018 |
SUMMARY OF WELLS BROUGHT ON-STREAM(1)
|
Three months ended March 31, 2018 |
|||||
|
Operated |
Non-Operated |
||||
|
Gross |
Net |
Gross |
Net |
||
|
Williston Basin |
8 |
5.2 |
0 |
0.0 |
|
|
Marcellus |
0 |
0.0 |
11 |
1.5 |
|
|
Canadian Waterfloods |
2 |
1.9 |
0 |
0.0 |
|
|
Other |
0 |
0.0 |
1 |
0.3 |
|
|
Total |
10 |
7.1 |
12 |
1.8 |
|
|
(1) Table may not add due to rounding. |
ASSET ACTIVITY
Williston Basin
Williston Basin production averaged 33,836 BOE per day (82% oil) during the first quarter of 2018, down 14% from the fourth quarter of 2017. This decrease was expected due to downtime related to offset completions and on-stream activity in North Dakota weighted to the back half of the first quarter. First quarter Williston Basin production was comprised of 30,372 BOE per day in North Dakota and 3,464 BOE per day in Montana.
Enerplus brought on-stream eight gross operated wells (65% average working interest) across its acreage at Fort Berthold during the first quarter. The average completed lateral length was 9,000 feet per well and average peak 30-day production rates per well were 1,360 BOE per day (77% oil, on a three-stream basis).
The Company drilled nine gross operated wells (96% average working interest) in the first quarter.
In late April, the Company completed and brought on production four of six planned wells from its Cats pad (91% average working interest). The wells are currently flowing back at strong rates which are tracking the high end of the Company’s expectations. The remaining two wells are expected to be on-stream in early May.
The Company continues to run two operated drilling rigs and one dedicated completions crew at its Fort Berthold operations.
Marcellus
Marcellus production averaged 208 MMcf per day during the first quarter, an increase from the previous quarter of 8% primarily due to stronger production driven by improved natural gas pricing.
Eleven gross non-operated wells (14% average working interest) were brought on-stream during the quarter. Nine wells had more than 30 days on production as of the date of this news release with an average completed lateral length of 6,340 feet per well and average peak 30-day production rates per well of 14 MMcf per day.
The Company participated in drilling 13 gross non-operated wells (20% average working interest) during the first quarter.
Canadian Waterfloods
Canadian waterflood production averaged 10,336 BOE per day (91% oil) during the first quarter, relatively flat to the previous quarter. Enerplus drilled and brought on-stream two wells in southeast Saskatchewan with average peak 30-day production rates per well of 235 barrels of oil per day, exceeding the Company’s expectations. At Ante Creek, the construction of two injection pipelines was completed along with two producer-to-injector well conversions. The increased water injection at Ante Creek has helped stabilize decline with oil production remaining relatively flat compared to the fourth quarter. Ante Creek oil volumes are expected to gradually increase during the second half of 2018.
DJ Basin
Enerplus’ first DJ Basin well (Maple 8-67-36-5C) has produced over 85,000 BOE (79% oil) in just over seven months on production. In April, the well averaged approximately 400 BOE per day (73% oil). The Company is continuing delineation activity to test the extent of commerciality across its acreage position with four gross (3.5 net) wells in 2018 testing both the Codell and Niobrara intervals.
2018 GUIDANCE
Enerplus’ 2018 guidance is summarized below. The Company has included second quarter 2018 liquids production guidance and revised its estimated 2018 Bakken crude oil price differential to US$3.50 per barrel below WTI from US$2.50 per barrel below WTI previously. All other guidance targets are unchanged.
|
Guidance |
|
|
Capital spending |
$535 – $585 million |
|
Q2 2018 crude oil and natural gas liquids production |
48,000 to 50,000 bbls/day |
|
Average annual production |
86,000 to 91,000 BOE/day |
|
Average annual crude oil and natural gas liquids production |
46,000 to 50,000 bbls/day |
|
Average royalty and production tax rate |
25% |
|
Operating expense |
$7.00/BOE |
|
Transportation expense |
$3.60/BOE |
|
Cash G&A expense |
$1.65/BOE |
|
2018 Full-Year Differential/Basis Outlook (1) |
|
|
U.S. Bakken crude oil differential (compared to WTI crude oil): |
US$(3.50)/bbl (from US$(2.50)/bbl) |
|
Marcellus natural gas sales price differential (compared to NYMEX natural gas): |
US$(0.40)/Mcf |
|
(1) Excluding transportation costs. |
RISK MANAGEMENT
Enerplus continues to manage price risk through commodity hedging. Using swaps and collar structures, Enerplus has an average of 21,500 barrels per day of crude oil protected for the remainder of 2018 (approximately 67% of forecast crude oil production at the midpoint of guidance, net of royalties), 21,300 barrels per day protected in 2019, and 6,000 barrels per day of crude oil protected in 2020.
For natural gas, Enerplus has 37,800 Mcf per day protected for the remainder of 2018 (approximately 21% of forecast natural gas production at the midpoint of guidance, net of royalties) using collar structures.
Commodity Hedging Detail (As at May 2, 2018)
|
WTI Crude Oil |
Nymex Natural Gas |
||||||||
|
Apr 1, – Apr 30, |
May 1 – |
Jul 1 – |
Oct 1 – |
Jan 1, – |
Apr 1, – |
Jan 1, – |
Apr 1, – Oct 31, 2018 |
Nov 1, – Dec 31, 2018 |
|
|
Swaps |
|||||||||
|
Sold Swaps |
$55.38 |
$57.20 |
$53.73 |
$53.73 |
$53.73 |
– |
– |
– |
– |
|
Volume (bbls/d or Mcf/d) |
5,000 |
6,000 |
3,000 |
3,000 |
3,000 |
– |
– |
– |
– |
|
Three-Way Collars |
|||||||||
|
Sold Puts |
$42.92 |
$42.92 |
$42.71 |
$42.74 |
$44.05 |
$44.26 |
$46.67 |
– |
– |
|
Volume (bbls/d or Mcf/d) |
15,000 |
15,000 |
18,000 |
20,000 |
16,000 |
22,000 |
6,000 |
– |
– |
|
Purchased Puts |
$52.90 |
$52.90 |
$52.53 |
$52.48 |
$53.69 |
$54.17 |
$56.00 |
$2.75 |
$2.75 |
|
Volume (bbls/d or Mcf/d) |
15,000 |
15,000 |
18,000 |
20,000 |
16,000 |
22,000 |
6,000 |
40,000 |
30,000 |
|
Sold Calls |
$61.73 |
$61.73 |
$61.22 |
$61.10 |
$63.44 |
$64.83 |
$70.33 |
$3.38 |
$3.47 |
|
Volume (bbls/d or Mcf/d) |
15,000 |
15,000 |
18,000 |
20,000 |
16,000 |
22,000 |
6,000 |
40,000 |
30,000 |
|
(1) Based on weighted average price (before premiums) |
BOARD OF DIRECTOR RETIREMENT
As previously announced, Mr. David Barr will be retiring from the Board at the Annual Meeting being held later today. Mr. Barr has been a valued member of the Board of Directors since his appointment in 2011. Enerplus would like to acknowledge and thank him for his contribution and dedicated service.
Q1 2018 CONFERENCE CALL DETAILS
A conference call hosted by Ian C. Dundas, President and CEO will be held at 7:30 AM MT (9:30 AM ET) today to discuss these results. Details of the conference call are as follows:
|
Date: |
Thursday, May 3, 2018 |
|
Time: |
7:30 AM MT (9:30 AM ET) |
|
Dial-In: |
647-427-7450 |
|
1-888-231-8191 (toll free) |
|
|
Audiocast: |
https://event.on24.com/wcc/r/1651698/8A98B2F74E8F567D4C28F7EFF7E44424 |
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 telephone replay will be available for 30 days following the conference call and can be accessed at the following numbers:
|
Dial-In: |
416-849-0833 |
|
1-855-859-2056 (toll free) |
|
|
Passcode: |
8267908 |
SELECTED FINANCIAL AND OPERATING RESULTS
|
Three months ended |
|||||
|
2018 |
2017 |
||||
|
Financial (000’s) |
|||||
|
Net Income/(Loss) |
$ |
29,637 |
$ |
76,293 |
|
|
Adjusted Funds Flow(4) |
155,162 |
119,920 |
|||
|
Dividends to Shareholders – Declared |
7,320 |
7,242 |
|||
|
Debt Outstanding – net of Cash and Restricted Cash |
291,978 |
350,401 |
|||
|
Capital Spending |
151,472 |
120,351 |
|||
|
Property and Land Acquisitions |
12,272 |
2,536 |
|||
|
Property Divestments |
6,970 |
(899) |
|||
|
Net Debt to Adjusted Funds Flow Ratio(4) |
0.5x |
0.9x |
|||
|
Financial per Weighted Average Shares Outstanding |
|||||
|
Net Income – Basic |
$ |
0.12 |
$ |
0.32 |
|
|
Net Income – Diluted |
0.12 |
0.31 |
|||
|
Weighted Average Number of Shares Outstanding (000’s) |
243,874 |
241,285 |
|||
|
Selected Financial Results per BOE(1)(2) |
|||||
|
Oil & Natural Gas Sales(3) |
$ |
42.91 |
$ |
36.33 |
|
|
Royalties and Production Taxes |
(10.41) |
(7.89) |
|||
|
Commodity Derivative Instruments |
1.33 |
0.86 |
|||
|
Cash Operating Expenses |
(7.02) |
(6.57) |
|||
|
Transportation Costs |
(3.52) |
(3.88) |
|||
|
General and Administrative Expenses |
(1.72) |
(1.87) |
|||
|
Cash Share-Based Compensation |
(0.25) |
(0.02) |
|||
|
Interest, Foreign Exchange and Other Expenses |
(1.05) |
(1.26) |
|||
|
Current Income Tax Recovery/(Expense) |
(0.01) |
(0.01) |
|||
|
Adjusted Funds Flow(4) |
$ |
20.26 |
$ |
15.69 |
|
|
Three months ended |
|||||
|
2018 |
2017 |
||||
|
Average Daily Production(2) |
|||||
|
Crude Oil (bbls/day) |
37,443 |
33,178 |
|||
|
Natural Gas Liquids (bbls/day) |
4,085 |
3,158 |
|||
|
Natural Gas (Mcf/day) |
261,310 |
291,607 |
|||
|
Total (BOE/day) |
85,080 |
84,937 |
|||
|
% Crude Oil and Natural Gas Liquids |
49% |
43% |
|||
|
Average Selling Price (2)(3) |
|||||
|
Crude Oil (per bbl) |
$ |
69.67 |
$ |
57.53 |
|
|
Natural Gas Liquids (per bbl) |
28.13 |
37.76 |
|||
|
Natural Gas (per Mcf) |
3.50 |
3.63 |
|||
|
Net Wells Drilled |
14 |
15 |
|||
|
(1) |
Non-cash amounts have been excluded. |
|
(2) |
Based on Company interest production volumes. See “Presentation of Production Information” below. |
|
(3) |
Before transportation costs, royalties, and commodity derivative instruments. |
|
(4) |
These non-GAAP measures may not be directly comparable to similar measures presented by other entities. See “Non-GAAP Measures” section in this news release. |
All financial information contained within this news release has been prepared in accordance with U.S. GAAP, except as noted under “Non-GAAP Measures”. This news release includes forward-looking statements and information within the meaning of applicable securities laws. Readers are advised to review the “Forward-Looking Information and Statements” at the conclusion of this news release. A full copy of Enerplus’ First Quarter 2018 Financial Statements and MD&A are available on the Company’s website at www.enerplus.com, under its SEDAR profile at www.sedar.com and on the EDGAR website at www.sec.gov.