HOUSTON, Aug. 2, 2013 /CNW/ - Ultra Petroleum Corp. (NYSE: UPL) today reported second quarter 2013 operating and financial results. Highlights during the quarter include:
- Second quarter production volumes of 58.4 Bcfe
- Operating cash flow(1) of $135.1 million, or $0.87 per diluted share for the quarter
- Reported net income of $71.9 million, or $0.47 per diluted share – adjusted(3)
- Solid margins in second quarter 2013 (adjusted): 56 percent cash flow margin(5) and 30 percent net income margin(4)
(Logo: http://photos.prnewswire.com/prnh/20020226/DATU029LOGO)
Second Quarter Results
Ultra Petroleum produced 58.4 billion cubic feet equivalent (Bcfe) of natural gas and crude oil during the second quarter 2013. The company's production was comprised of 56.6 billion cubic feet (Bcf) of natural gas and 299.1 thousand barrels (Mbbls) of condensate.
Ultra's average realized natural gas price for the quarter was $3.80 per thousand cubic feet (Mcf), including the effect of commodity hedges. The realized condensate price in the second quarter was $88.90 per barrel (Bbl).
Ultra Petroleum reported operating cash flow(1) of $135.1 million, or $0.87 per diluted share in the second quarter. Adjusted net income(3) for the quarter was $71.9 million, or $0.47 per diluted share.
Year-to-Date Results
The company's natural gas and crude oil production for the first six months of 2013 was 117.8 Bcfe. Ultra's production was comprised of 114.4 Bcf of natural gas and 567.4 Mbbls of condensate.
Including the effects of commodity hedges, Ultra Petroleum's average realized natural gas price was $3.65 per Mcf. The realized condensate price for the first half of the year was $88.16 per Bbl.
Ultra reported operating cash flow(1) of $258.0 million, or $1.67 per diluted share for first six months of 2013. Adjusted net income(3) was $130.4 million, or $0.84 per diluted share for the same six month period in 2013.
"Our results for the first half of the year demonstrate sound execution of our 2013 objectives. Our focus now is optimizing future development of our asset portfolio in view of our returns-based development strategy and making key operational decisions that complement this approach," stated Michael D. Watford, Chairman, President and Chief Executive Officer.
Wyoming - Operational Highlights
During the second quarter, Ultra Petroleum and its partners drilled 39 gross (17 net) Wyoming Lance wells and placed on production 36 gross (17 net) wells. The second quarter average initial production (IP) rate for new wells brought online was 7.2 million cubic feet equivalent (MMcfe) per day. Net production from Wyoming averaged 456 MMcfe per day in the second quarter.
Ultra Petroleum and its partners drilled 65 gross (28 net) Wyoming Lance wells and placed on production 70 gross (37 net) wells for the first half of 2013. The average IP rate for the wells placed on production during the first and second quarter was 8.2 MMcfe per day. The company produced 82.4 Bcfe from Wyoming during the first six months of 2013.
Achieving a new milestone, Ultra averaged 9.6 days spud to total depth (TD) during the second quarter with sixty percent of all operated wells being drilled in less than 10 days. Total days per well, as measured by rig-release to rig-release, averaged 12.2 days in the second quarter.
Pennsylvania - Operational Highlights
During the second quarter, Ultra participated in drilling 6 gross (3 net) horizontal Marcellus wells and initiated production from 7 gross (3 net) wells. Ultra's Marcellus program demonstrated average IP rates of 6.4 MMcfe per day for the new wells placed online during the quarter. Second quarter Pennsylvania net production averaged 186 MMcfe per day.
For the first six months of 2013, Ultra and its partners drilled 13 gross (6 net) horizontal Marcellus wells and initiated production from 24 gross (12 net) wells. Ultra's Marcellus average IP rate during the first half of the year was 6.0 MMcfe per day for the new wells brought online. Cumulative Marcellus production from the first and second quarter was 35.3 Bcfe.
The company has 900 square miles of 3D seismic across two-thirds of its 260,000 net acres and is in the process of acquiring an additional 35 square miles over its operated acreage position. Ultra expects the additional 3D will further delineate Marcellus sweet spots and expand understanding of the Geneseo formation across its acreage holdings.
Commodity Hedges
Currently, Ultra has 43 percent of the company's remaining 2013 natural gas production hedged at a weighted-average price of $3.75 per Mcf. The total volume of the commodity hedges is 48.0 Bcf. The company opportunistically hedges a portion of its forecasted production to sustain cash flow and lessen the volatility associated with commodity prices.
Financial Strength
Approximately 83 percent of Ultra Petroleum's second quarter outstanding debt of $1.9 billion was comprised of long-term, fixed-rate debt with an average remaining term of 6.8 years and a 5.6 percent weighted average coupon rate. Ultra's debt to trailing 12-months EBITDA(2) was 2.6 times at the end of the second quarter with over $800.0 million in unused senior debt capacity. Ultra relies on total debt to EBITDA(2) as a measure of leverage because it appropriately removes the effect of certain non-cash items, such as impairment charges.
Third Quarter 2013 Production Guidance
Ultra's third quarter production is expected to range between 56.0 – 58.5 Bcfe. Ultra is maintaining its annual production target of 233 Bcfe and tightening its guidance range to 230 – 236 Bcfe. Based on the mid-point of the company's annual production guidance, approximately 70 percent of total company production will come from the Rockies, while 30 percent will come from the Appalachian region. The company is reaffirming its previous capital investment program guidance of $415.0 million for 2013.
|
2013 Estimated Total Production (Bcfe)
|
|
1st Quarter (A)
|
2nd Quarter (A)
|
3rd Quarter (E)
|
Full-Year (E)
|
|
59.3
|
58.4
|
56.0 – 58.5
|
230 - 236
|
Third Quarter 2013 Price Realizations and Differentials Guidance
In the third quarter 2013, the company's realized natural gas price is expected to average 7 to 9 percent below the NYMEX price due to regional differentials, before consideration of any hedging activity. Realized pricing for condensate is expected to be about $7.00 less than the average NYMEX crude oil price.
Third Quarter 2013 Expense Guidance
The following table presents the company's expected expenses per Mcfe in the third quarter 2013 assuming a $3.50 per MMbtu Henry Hub natural gas price and a $100.00 per Bbl NYMEX crude oil price:
|
Costs Per Mcfe
|
|
Q3 2013
|
|
Lease operating expenses
|
|
$ 0.37 – 0.40
|
|
Production taxes
|
|
$ 0.30 – 0.32
|
|
Gathering fees
|
|
$ 0.23 – 0.25
|
|
Total lease operating costs
|
|
$ 0.90 – 0.97
|
|
|
|
|
Transportation charges
|
|
$ 0.35 – 0.37
|
|
Depletion and depreciation
|
|
$ 1.03 – 1.06
|
|
General and administrative – total
|
|
$ 0.10 – 0.12
|
|
Interest and debt expense
|
|
$ 0.43 – 0.45
|
|
Total operating costs per Mcfe
|
|
$ 2.81 – 2.97
|
2013 Annual Income Tax Guidance
Due to the ceiling test write-downs the company incurred during 2012, Ultra currently projects a two percent book tax rate for 2013. This equates to forecasted annual cash taxes of $5.0 million for the year with approximately $2.2 million for the remainder of 2013.
Conference Call Webcast Scheduled for August 2, 2013
Ultra Petroleum's second quarter 2013 results conference call will be available via live audio webcast at 11:00 a.m. Eastern Daylight Time (10:00 a.m. Central Daylight Time) Friday, August 2, 2013. To listen to this webcast, log on to www.ultrapetroleum.com and follow the link to the webcast. The webcast replay and podcast will be archived on Ultra Petroleum's website through November 1, 2013.
Financial tables to follow.
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Ultra Petroleum Corp.
|
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|
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|
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Consolidated Statements of Income (unaudited)
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All amounts expressed in US$000's,
|
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|
|
|
|
|
|
|
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Except per unit data
|
|
|
|
|
|
|
|
|
|
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For the Six Months Ended
|
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For the Quarter Ended
|
|
|
June 30,
|
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June 30,
|
|
|
2013
|
|
2012
|
|
2013
|
|
2012
|
|
Volumes
|
|
|
|
|
|
|
|
|
|
Natural gas (Mcf)
|
|
114,351,403
|
|
129,707,356
|
|
56,624,054
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|
63,068,313
|
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Oil liquids (Bbls)
|
|
567,381
|
|
691,554
|
|
299,125
|
|
332,512
|
|
Mcfe - Total
|
|
117,755,689
|
|
133,856,680
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|
58,418,804
|
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65,063,385
|
|
|
|
|
|
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Revenues
|
|
|
|
|
|
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|
|
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Natural gas sales
|
$
|
436,985
|
$
|
331,876
|
$
|
234,785
|
$
|
140,836
|
|
Oil sales
|
|
50,018
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|
64,537
|
|
26,591
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|
29,434
|
|
Total operating revenues
|
|
487,003
|
|
396,413
|
|
261,376
|
|
170,270
|
|
|
|
|
|
|
|
|
|
|
Expenses
|
|
|
|
|
|
|
|
|
|
Lease operating expenses
|
|
36,331
|
|
29,241
|
|
17,514
|
|
12,239
|
|
LGS operating lease expense
|
|
10,000
|
|
-
|
|
5,000
|
|
-
|
|
Production taxes
|
|
36,561
|
|
31,587
|
|
20,006
|
|
13,367
|
|
Gathering fees
|
|
25,718
|
|
36,318
|
|
13,834
|
|
16,766
|
|
Total lease operating costs
|
|
108,610
|
|
97,146
|
|
56,354
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|
42,372
|
|
|
|
|
|
|
|
|
|
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Transportation charges
|
|
40,958
|
|
42,422
|
|
20,649
|
|
21,366
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Depletion and depreciation
|
|
121,591
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|
227,469
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|
60,123
|
|
114,767
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Ceiling test and other impairments
|
|
-
|
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1,869,136
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-
|
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1,869,136
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General and administrative
|
|
5,775
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|
7,786
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|
2,823
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|
5,234
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|
Stock compensation
|
|
6,062
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|
4,781
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|
3,053
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|
2,325
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|
Total operating expenses
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|
282,996
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|
2,248,740
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|
143,002
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2,055,200
|
|
|
|
|
|
|
|
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Other income (expense), net
|
|
13
|
|
14
|
|
5
|
|
7
|
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Contract cancellation fees
|
|
-
|
|
(9,512)
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|
-
|
|
(4,666)
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Interest and debt expense, net
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|
(51,002)
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|
(37,046)
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|
(25,238)
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|
(18,748)
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Deferred gain on sale of liquids gathering system
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|
5,276
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|
-
|
|
2,636
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|
-
|
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Realized gain on commodity derivatives
|
|
(19,764)
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|
176,805
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|
(19,764)
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|
114,268
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Unrealized (loss) gain on commodity derivatives
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|
(2,860)
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|
(89,809)
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|
41,855
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|
(147,555)
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Income before income taxes
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|
135,670
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(1,811,875)
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|
117,868
|
|
(1,941,624)
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Income tax provision - current
|
|
2,859
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|
3,023
|
|
1,491
|
|
1,607
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Income tax provision - deferred
|
|
-
|
|
(712,175)
|
|
-
|
|
(756,249)
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|
|
|
|
|
|
|
|
|
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Net income
|
$
|
132,811
|
$
|
(1,102,723)
|
$
|
116,377
|
$
|
(1,186,982)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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Ceiling test and other impairments
|
$
|
-
|
$
|
1,869,136
|
$
|
-
|
$
|
1,869,136
|
|
Deferred taxes
|
-
|
|
(712,415)
|
|
-
|
|
(756,489)
|
|
Contract cancellation fees
|
|
-
|
|
9,512
|
|
-
|
|
4,666
|
|
Deferred gain on sale of liquids gathering system
|
|
(5,276)
|
|
-
|
|
(2,636)
|
|
-
|
|
Unrealized loss (gain) on commodity derivatives
|
|
2,860
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|
89,809
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|
(41,855)
|
|
147,555
|
|
Adjusted net income (3)
|
$
|
130,395
|
$
|
153,319
|
$
|
71,886
|
$
|
77,886
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|
|
|
|
|
|
|
|
|
|
Operating cash flow (1)
|
$
|
258,048
|
$
|
376,297
|
$
|
135,064
|
$
|
190,550
|
|
(see non-GAAP reconciliation)
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|
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|
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|
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|
|
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Weighted average shares (000's)
|
|
|
|
|
|
|
|
|
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Basic
|
|
152,947
|
|
152,761
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|
152,948
|
|
152,921
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|
Fully diluted
|
|
154,397
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|
152,761
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|
154,513
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152,921
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Earnings per share
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|
|
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Net income - basic
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|
$0.87
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($7.22)
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|
$0.76
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|
($7.76)
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Net income - fully diluted
|
|
$0.86
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|
($7.22)
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|
$0.75
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|
($7.76)
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|
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|
|
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Adjusted earnings per share(3)
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|
|
|
|
|
|
|
|
Adjusted net income - basic
|
|
$0.85
|
|
$1.00
|
|
$0.47
|
|
$0.51
|
|
Adjusted net income - fully diluted
|
|
$0.84
|
|
$1.00
|
|
$0.47
|
|
$0.51
|
|
|
|
|
|
|
|
|
|
|
Cash flow per share(1)
|
|
|
|
|
|
|
|
|
|
Cash flow per share - basic
|
|
$1.69
|
|
$2.46
|
|
$0.88
|
|
$1.25
|
|
Cash flow per share - fully diluted
|
|
$1.67
|
|
$2.46
|
|
$0.87
|
|
$1.25
|
|
|
|
|
|
|
|
|
|
|
Realized Prices
|
|
|
|
|
|
|
|
|
|
Natural gas (Mcf), including realized gain (loss)
|
|
|
|
|
|
|
|
|
|
on commodity derivatives
|
|
$3.65
|
|
$3.92
|
|
$3.80
|
|
$4.04
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|
Natural gas (Mcf), excluding realized gain (loss)
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|
|
|
|
|
|
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|
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on commodity derivatives
|
|
$3.82
|
|
$2.56
|
|
$4.15
|
|
$2.23
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|
Oil liquids (Bbls)
|
|
$88.16
|
|
$93.32
|
|
$88.90
|
|
$88.52
|
|
|
|
|
|
|
|
|
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Costs Per Mcfe
|
|
|
|
|
|
|
|
|
|
Lease operating expenses
|
|
$0.39
|
|
$0.22
|
|
$0.39
|
|
$0.19
|
|
Production taxes
|
|
$0.31
|
|
$0.24
|
|
$0.34
|
|
$0.21
|
|
Gathering fees
|
|
$0.22
|
|
$0.27
|
|
$0.24
|
|
$0.26
|
|
Transportation charges
|
|
$0.35
|
|
$0.32
|
|
$0.35
|
|
$0.33
|
|
Depletion and depreciation
|
|
$1.03
|
|
$1.70
|
|
$1.03
|
|
$1.76
|
|
General and administrative - total
|
|
$0.10
|
|
$0.09
|
|
$0.10
|
|
$0.12
|
|
Interest and debt expense
|
|
$0.43
|
|
$0.28
|
|
$0.43
|
|
$0.29
|
|
|
$2.83
|
|
$3.12
|
|
$2.88
|
|
$3.16
|
|
|
|
|
|
|
|
|
|
|
Note: Amounts on a per Mcfe basis may not total due to rounding.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjusted Margins
|
|
|
|
|
|
|
|
|
|
Adjusted Net Income(4)
|
|
28%
|
|
27%
|
|
30%
|
|
27%
|
|
Adjusted Operating Cash Flow Margin(5)
|
|
55%
|
|
66%
|
|
56%
|
|
67%
|
|
|
|
|
|
|
|
|
|
|
Ultra Petroleum Corp.
|
|
|
|
|
|
Supplemental Balance Sheet Data
|
|
|
|
|
|
All amounts expressed in US$000's
|
|
|
|
|
|
|
As of
|
|
|
|
|
|
|
June 30,
|
|
December 31,
|
|
|
|
|
|
|
2013
|
|
2012
|
|
|
|
|
|
|
(Unaudited)
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
$
|
6,557
|
$
|
12,921
|
|
|
|
|
|
Long-term debt
|
|
|
|
|
|
|
|
|
|
Bank indebtedness
|
|
320,000
|
|
277,000
|
|
|
|
|
|
Senior notes
|
|
1,560,000
|
|
1,560,000
|
|
|
|
|
|
$
|
1,880,000
|
$
|
1,837,000
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reconciliation of Operating Cash Flow and Net Cash Provided by Operating Activities (unaudited)
|
|
All amounts expressed in US$000's
|
|
|
|
|
|
The following table reconciles net cash provided by operating activities with operating cash flow as derived from the company's financial information.
|
|
|
|
|
|
|
|
|
|
|
|
For the Six Months Ended
|
|
For the Quarter Ended
|
|
|
June 30,
|
|
June 30,
|
|
|
2013
|
|
2012
|
|
2013
|
|
2012
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by operating activities
|
$
|
209,134
|
$
|
327,649
|
$
|
141,274
|
$
|
138,346
|
|
Net changes in operating assets and liabilities
|
|
|
|
|
|
|
|
|
|
and other non-cash items*
|
|
48,914
|
|
48,648
|
|
(6,210)
|
|
52,204
|
|
Net cash provided by operating activities before
|
|
|
|
|
|
|
|
|
|
changes in operating assets and liabilities
|
$
|
258,048
|
$
|
376,297
|
$
|
135,064
|
$
|
190,550
|
|
|
|
|
|
|
|
|
|
|
Ultra Petroleum Corp.
|
|
Hedging Summary
|
|
August 2, 2013
|
|
|
|
|
|
|
The company has the following hedge positions in place to mitigate its commodity price exposure:
|
|
|
|
|
|
|
NYMEX
|
|
Q3 2013
|
Q4 2013
|
Balance
2013
|
|
Volume (Bcf)
|
|
35.9
|
12.1
|
48.0
|
|
MMbtu ($)
|
|
$3.54
|
$3.54
|
$3.54
|
|
Mcf ($)
|
|
$3.75
|
$3.75
|
$3.75
|
The company reports its financial results in accordance with accounting principles generally accepted in the United States of America ("GAAP"). However, management believes certain non-GAAP performance measures may provide users of this financial information with additional meaningful comparisons between current results and the results of the company's peers and of prior periods.
(1) Operating Cash Flow is defined as Net cash provided by operating activities before changes in operating assets and liabilities and other non-cash items. Management believes that the non-GAAP measure of operating cash flow is useful as an indicator of an oil and gas exploration and production company's ability to internally fund exploration and development activities and to service or incur additional debt. The company has also included this information because changes in operating assets and liabilities relate to the timing of cash receipts and disbursements which the company may not control and may not relate to the period in which the operating activities occurred. Operating cash flow should not be considered in isolation or as a substitute for net cash provided by operating activities prepared in accordance with GAAP.
(2) EBITDA is defined as earnings before interest, taxes, DD&A and other non-cash charges.
Management presents the following measures because (i) they are consistent with the manner in which the company's performance is measured relative to the performance of its peers, (ii) these measures are more comparable to earnings estimates provided by securities analysts, and (iii) charges or amounts excluded cannot be reasonably estimated and guidance provided by the company excludes information regarding these types of items. These adjusted amounts are not a measure of financial performance under GAAP.
(3) Adjusted Net Income is defined as Net income (loss) adjusted to exclude certain charges or amounts in order to excluded the volatility associated with the effects of non-recurring charges, non-cash mark-to-market losses on commodity derivatives, non-cash ceiling test impairments and other similar items.
(4) Adjusted Net Income Margin is defined as Adjusted Net Income divided by the sum of Oil and natural gas sales plus Realized gain (loss) on commodity derivatives.
(5) Adjusted Operating Cash Flow Margin is defined as Operating Cash Flow divided by the sum of Oil and natural gas sales plus Realized gain (loss) on commodity derivatives.
*Other non-cash items include reduction in tax benefit from stock based compensation and other.
About Ultra Petroleum
Ultra Petroleum Corp. is an independent exploration and production company focused on developing its long-life natural gas reserves in the Green River Basin of Wyoming – the Pinedale and Jonah Fields and is in the early exploration and development stages in the Appalachian Basin of Pennsylvania. Ultra is listed on the New York Stock Exchange and trades under the ticker symbol "UPL". The company had 152,972,162 shares outstanding on June 30, 2013.
This release can be found at http://www.ultrapetroleum.com
This news release includes "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The opinions, forecasts, projections or other statements, other than statements of historical fact, are forward-looking statements. Although the company believes that the expectations reflected in such forward-looking statements are reasonable, the company can give no assurance that such expectations will prove to have been correct. Certain risks and uncertainties inherent in the company's businesses are set forth in its filings with the SEC, particularly in the section entitled "Risk Factors" included in its Annual Report on Form 10-K for the most recent fiscal year and from time to time in other filings made by the company with the SEC. These risks and uncertainties include, but are not limited to, increased competition, the timing and extent of changes in prices for oil and gas, particularly in Wyoming and Pennsylvania, the timing and extent of the company's success in discovering, developing, producing and estimating reserves, the effects of weather and government regulation, availability of oil field personnel, services, drilling rigs and other equipment, as well as other factors listed in the reports filed by the company with the SEC. Full details regarding the selected financial information provided above will be available in the company's report on Form 10-Q for the quarter ended June 30, 2013.
SOURCE: Ultra Petroleum Corp.
Kelly L. Whitley, Director, Investor Relations, 281-582-6602, kwhitley@ultrapetroleum.com, or Julie E. Danvers, Manager, Investor Relations, 281-582-6604, jdanvers@ultrapetroleum.com