|
Patterson-UTI Energy Reports Financial Results for the Three and Nine Months Ended September 30, 2019
HOUSTON, Oct. 24, 2019 /PRNewswire/ -- PATTERSON-UTI ENERGY, INC. (NASDAQ: PTEN) today reported financial results for the three and nine months ended September 30, 2019. The Company reported a net loss of $262 million, or $1.31 per share, for the third quarter of 2019, compared to a net loss of $75.0 million, or $0.34 per share, for the quarter ended September 30, 2018. Excluding charges discussed below, the majority of which were non-cash, the net loss for the third quarter of 2019 would have been $52.9 million, or $0.27 per share. Revenues for the third quarter of 2019 were $598 million, compared to $867 million for the third quarter of 2018.
Andy Hendricks, Patterson-UTI's Chief Executive Officer, stated, "We exceeded our expectation for cash flow generation during the third quarter. We reduced our capital expenditures and, excluding charges discussed below, Adjusted EBITDA for the third quarter exceeded capital expenditures by $74.9 million. During the third quarter, we also reduced debt by $150 million, repurchased $75 million of our shares, and paid dividends totaling $7.8 million."
For the nine months ended September 30, 2019, the Company reported a net loss of $340 million, or $1.65 per share, compared to a net loss of $120 million, or $0.55 per share, for the nine months ended September 30, 2018. Revenues for the nine months ended September 30, 2019, were $2.0 billion, compared to $2.5 billion for the same period in 2018.
Financial results for the three and nine months ended September 30, 2019, include pre-tax charges totaling $260 million ($209 million after-tax or $1.05 per share). These charges include asset impairment charges of $203 million primarily in our drilling and pressure pumping segments, $17.8 million of goodwill impairment charges at our Current Power and Great Plains Oilfield Rental businesses, $17.0 million primarily related to the write-off of inventory at MS Directional, $14.6 million related to inventory write-offs and severance at our Warrior Rig Technologies business, and $8.2 million related to the early repayment of debt. The financial results for the nine months ended September 30, 2019 also include charges in the second quarter, which included a $12.7 million charge to reduce the carrying value on our balance sheet of a deposit placed in 2017 on future sand purchases and $3.6 million of bad debt expense.
During the third quarter, the Company spent $75.0 million to repurchase 8.2 million shares, which brings the total repurchases through the first three quarters of 2019 to $225 million for 20.0 million shares under the Company's share repurchase program. At September 30, 2019, $175 million remained under the Company's share repurchase authorization.
Mr. Hendricks added, "As expected, operators slowed spending levels during the third quarter, which negatively impacted activity levels for both drilling and pressure pumping. However, our rig count in the third quarter of 142 rigs was in line with our expectation. We expect our rig count will stabilize near current levels and average 126 rigs for the fourth quarter, with some increase in the first quarter as operator budgets reset in 2020.
"Average rig revenue per operating day and average rig margin per day were $24,240 and $9,790, respectively, for the third quarter, both of which include the benefit of approximately $480 per operating day from $6.3 million of revenue from early contract terminations. Average rig direct operating cost per operating day increased during the third quarter to $14,440 from $14,030 in the second quarter due to lower fixed cost absorption, and increases in items such as workers' compensation and medical insurance. We expect these additional insurance costs will not repeat in the fourth quarter.
"During the third quarter, we incurred pre-tax, non-cash impairment charges in the contract drilling segment of $173 million related to the retirement of 36 legacy non-APEX® rigs and certain other drilling assets. Given current market conditions combined with strong customer demand for super-spec drilling rigs, we believe the 36 rigs that were retired had limited commercial opportunity. Our current, total rig fleet of 216 rigs includes 198 APEX® rigs of which we consider 150 to be super-spec rigs.
"As of September 30, 2019, we had term contracts for drilling rigs providing for approximately $645 million of future dayrate drilling revenue. Based on contracts currently in place, we expect an average of 73 rigs operating under term contracts during the fourth quarter, and an average of 55 rigs operating under term contracts during the 12 months ending September 30, 2020.
"In pressure pumping, lower activity levels and increased pricing pressure negatively impacted third quarter results. Pressure pumping revenues for the third quarter were $209 million compared to $251 million in the second quarter, and gross profit was $32.3 million in the third quarter compared to $44.9 million in the second quarter. We ended the third quarter with 14 active spreads, and we idled another spread early in the fourth quarter. As pressure pumping activity is expected to fall further in the fourth quarter, we will continue to evaluate the economics of working versus idling spreads on a spread-by-spread basis.
"During the third quarter, we incurred pre-tax, non-cash impairment charges in the pressure pumping segment of $20.5 million related to the retirement of approximately 300,000 horsepower. During the third quarter, we undertook a thorough process to evaluate the economic opportunity for our fleet and concluded that in the current market the cost to reactivate this retired equipment would be prohibitive. Any components from this retired equipment with remaining value will be used as parts to support our active equipment.
"In directional drilling, revenues for the third quarter were $47.0 million compared to $50.2 million in the second quarter. We had a negative gross margin of $9.2 million in the third quarter, which included the impact of a $17.0 million pre-tax, non-cash charge primarily related to the write-off of inventory.
"In our Warrior Rig Technologies business, we implemented several cost cutting initiatives during the third quarter. These initiatives included the transition away from our engineering and manufacturing efforts in Calgary, which resulted in a $12.4 million pre-tax, non-cash charge related to the write-off of inventory and $2.2 million for severance.
Mr. Hendricks concluded, "Despite some primarily non-cash accounting charges during the third quarter, we generated strong cash flow. We reduced our third quarter capex to only $68.0 million from $96.9 million in the second quarter, and we now expect capital expenditures of approximately $350 million in 2019, down from our prior estimate of $400 million."
Mark S. Siegel, Chairman of Patterson-UTI, stated, "We remained disciplined with our capital allocation during the third quarter, and our strong financial position allowed us to focus on debt reduction and share repurchases. During the third quarter, we reduced debt by $150 million, repurchased $75 million of our common stock, and paid dividends totaling $7.8 million. Since the beginning of 2019, we have used our strong cash flow to repurchase 20.0 million shares or 9.4% of the shares outstanding at the beginning of the year, and our net debt to total capital ratio was only 21.6% at the end of the third quarter.
"Given our current public market equity valuation, our cash balance and expected future cash flow generation, we will likely allocate additional capital to both share repurchases and debt repayment," he concluded.
The Company declared a quarterly dividend on its common stock of $0.04 per share, payable on December 19, 2019, to holders of record as of December 5, 2019.
All references to "per share" in this press release are diluted earnings per common share as defined within Accounting Standards Codification Topic 260.
The Company's quarterly conference call to discuss the operating results for the quarter ended September 30, 2019, is scheduled for today, October 24, 2019, at 9:00 a.m. Central Time. The dial-in information for participants is (844) 704-2496 (Domestic) and (647) 253-8661 (International). The conference ID for both numbers is 9373879. The call is also being webcast and can be accessed through the Investor Relations section of the Company's website at https://investor.patenergy.com. A replay of the conference call will be on the Company's website for two weeks.
About Patterson-UTI
Patterson-UTI is a provider of oilfield services and products to oil and natural gas exploration and production companies in North America, including market leading positions in contract drilling, pressure pumping and directional drilling services. For more information, visit www.patenergy.com.
Cautionary Statement Regarding Forward-Looking Statements
This press release contains forward-looking statements which are protected as forward-looking statements under the Private Securities Litigation Reform Act of 1995 that are not limited to historical facts, but reflect Patterson-UTI's current beliefs, expectations or intentions regarding future events. Words such as "anticipate," "believe," "budgeted," "continue," "could," "estimate," "expect," "intend," "may," "plan," "predict," "potential," "project," "pursue," "should," "strategy," "target," or "will," and similar expressions are intended to identify such forward-looking statements. The statements in this press release that are not historical statements, including statements regarding Patterson-UTI's future expectations, beliefs, plans, objectives, financial conditions, assumptions or future events or performance that are not historical facts, are forward-looking statements within the meaning of the federal securities laws. These statements are subject to numerous risks and uncertainties, many of which are beyond Patterson-UTI's control, which could cause actual results to differ materially from the results expressed or implied by the statements. These risks and uncertainties include, but are not limited to: volatility in customer spending and in oil and natural gas prices, which could adversely affect demand for Patterson-UTI's services and their associated effect on rates, utilization, margins and planned capital expenditures; global economic conditions; excess availability of land drilling rigs and pressure pumping equipment, including as a result of low commodity prices, reactivation, improvement or construction; liabilities from operations; weather; decline in, and ability to realize, backlog; equipment specialization and new technologies; shortages, delays in delivery and interruptions of supply of equipment and materials; ability to hire and retain personnel; loss of, or reduction in business with, key customers; cybersecurity risk; difficulty with growth and in integrating acquisitions and new technology; governmental regulation; product liability; legal proceedings, including technology disputes, and actions by governmental or other regulatory agencies; political, economic and social instability risk; ability to effectively identify and enter new markets; dependence on our subsidiaries to meet our long-term debt obligations; variable rate indebtedness risk; ability to maintain credit rating and service debt; and anti-takeover measures in our charter documents; contingent tax liabilities; and ability to use net operating losses.
Additional information concerning factors that could cause actual results to differ materially from those in the forward-looking statements is contained from time to time in Patterson-UTI's SEC filings. Patterson-UTI's filings may be obtained by contacting Patterson-UTI or the SEC or through Patterson-UTI's website at http://www.patenergy.com or through the SEC's Electronic Data Gathering and Analysis Retrieval System (EDGAR) at http://www.sec.gov. Patterson-UTI undertakes no obligation to publicly update or revise any forward-looking statement.
|
PATTERSON-UTI ENERGY, INC.
|
|
Condensed Consolidated Statements of Operations
|
|
(unaudited, in thousands, except per share data)
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
|
September 30,
|
|
September 30,
|
|
|
2019
|
|
2018
|
|
2019
|
|
2018
|
|
REVENUES
|
|
$
|
598,452
|
|
$
|
867,478
|
|
$
|
1,978,388
|
|
$
|
2,531,060
|
|
COSTS AND EXPENSES:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Direct operating costs
|
|
|
453,214
|
|
|
634,058
|
|
|
1,410,182
|
|
|
1,844,802
|
|
Depreciation, depletion, amortization and impairment
|
|
|
400,764
|
|
|
281,652
|
|
|
823,862
|
|
|
703,928
|
|
Impairment of goodwill
|
|
|
17,800
|
|
|
—
|
|
|
17,800
|
|
|
—
|
|
Selling, general and administrative
|
|
|
34,231
|
|
|
32,820
|
|
|
101,680
|
|
|
101,300
|
|
Provision for bad debts
|
|
|
—
|
|
|
—
|
|
|
3,594
|
|
|
—
|
|
Merger and integration expenses
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
2,738
|
|
Other operating expenses (income), net
|
|
|
(252)
|
|
|
(771)
|
|
|
83
|
|
|
(10,321)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
|
905,757
|
|
|
947,759
|
|
|
2,357,201
|
|
|
2,642,447
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
OPERATING LOSS
|
|
|
(307,305)
|
|
|
(80,281)
|
|
|
(378,813)
|
|
|
(111,387)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
OTHER INCOME (EXPENSE):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest income
|
|
|
1,693
|
|
|
817
|
|
|
4,481
|
|
|
4,600
|
|
Interest expense, net of amount capitalized
|
|
|
(20,739)
|
|
|
(12,376)
|
|
|
(47,021)
|
|
|
(38,668)
|
|
Other
|
|
|
119
|
|
|
281
|
|
|
328
|
|
|
666
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other expense
|
|
|
(18,927)
|
|
|
(11,278)
|
|
|
(42,212)
|
|
|
(33,402)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
LOSS BEFORE INCOME TAXES
|
|
|
(326,232)
|
|
|
(91,559)
|
|
|
(421,025)
|
|
|
(144,789)
|
|
INCOME TAX BENEFIT
|
|
|
(64,513)
|
|
|
(16,517)
|
|
|
(81,245)
|
|
|
(24,617)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NET LOSS
|
|
$
|
(261,719)
|
|
$
|
(75,042)
|
|
$
|
(339,780)
|
|
$
|
(120,172)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NET LOSS PER COMMON SHARE:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
$
|
(1.31)
|
|
$
|
(0.34)
|
|
$
|
(1.65)
|
|
$
|
(0.55)
|
|
Diluted
|
|
$
|
(1.31)
|
|
$
|
(0.34)
|
|
$
|
(1.65)
|
|
$
|
(0.55)
|
|
WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
199,343
|
|
|
218,059
|
|
|
206,191
|
|
|
219,635
|
|
Diluted
|
|
|
199,343
|
|
|
218,059
|
|
|
206,191
|
|
|
219,635
|
|
CASH DIVIDENDS PER COMMON SHARE
|
|
$
|
0.04
|
|
$
|
0.04
|
|
$
|
0.12
|
|
$
|
0.10
|
|
PATTERSON-UTI ENERGY, INC.
|
|
|
Additional Financial and Operating Data
|
|
|
(unaudited, dollars in thousands)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
|
September 30,
|
|
|
September 30,
|
|
|
|
2019
|
|
|
2018
|
|
|
2019
|
|
|
2018
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Contract Drilling:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenues
|
|
$
|
317,035
|
|
|
$
|
365,280
|
|
|
$
|
1,037,565
|
|
|
$
|
1,043,005
|
|
|
Direct operating costs
|
|
$
|
188,934
|
|
|
$
|
226,373
|
|
|
$
|
609,928
|
|
|
$
|
656,630
|
|
|
Margin (1)
|
|
$
|
128,101
|
|
|
$
|
138,907
|
|
|
$
|
427,637
|
|
|
$
|
386,375
|
|
|
Selling, general and administrative
|
|
$
|
1,510
|
|
|
$
|
1,632
|
|
|
$
|
4,616
|
|
|
$
|
4,599
|
|
|
Depreciation, amortization and impairment
|
|
$
|
296,119
|
|
|
$
|
179,979
|
|
|
$
|
554,838
|
|
|
$
|
441,834
|
|
|
Operating loss
|
|
$
|
(169,528)
|
|
|
$
|
(42,704)
|
|
|
$
|
(131,817)
|
|
|
$
|
(60,058)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating days – United States
|
|
|
13,054
|
|
|
|
16,312
|
|
|
|
43,036
|
|
|
|
47,239
|
|
|
Operating days – Canada
|
|
|
27
|
|
|
|
82
|
|
|
|
217
|
|
|
|
371
|
|
|
Operating days – Total
|
|
|
13,081
|
|
|
|
16,394
|
|
|
|
43,253
|
|
|
|
47,610
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Average revenue per operating day – United States
|
|
$
|
24.25
|
|
|
$
|
22.30
|
|
|
$
|
24.02
|
|
|
$
|
21.94
|
|
|
Average direct operating costs per operating day – United States
|
|
$
|
14.40
|
|
|
$
|
13.78
|
|
|
$
|
14.07
|
|
|
$
|
13.76
|
|
|
Average margin per operating day – United States (1)
|
|
$
|
9.85
|
|
|
$
|
8.52
|
|
|
$
|
9.95
|
|
|
$
|
8.18
|
|
|
Average rigs operating – United States
|
|
|
142
|
|
|
|
177
|
|
|
|
158
|
|
|
|
173
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Average revenue per operating day – Canada
|
|
$
|
17.67
|
|
|
$
|
18.93
|
|
|
$
|
18.16
|
|
|
$
|
17.98
|
|
|
Average direct operating costs per operating day – Canada
|
|
$
|
35.07
|
|
|
$
|
18.87
|
|
|
$
|
20.65
|
|
|
$
|
17.86
|
|
|
Average margin per operating day – Canada (1)
|
|
$
|
(17.41)
|
|
|
$
|
0.06
|
|
|
$
|
(2.49)
|
|
|
$
|
0.12
|
|
|
Average rigs operating – Canada
|
|
|
0
|
|
|
|
1
|
|
|
|
1
|
|
|
|
1
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Average revenue per operating day – Total
|
|
$
|
24.24
|
|
|
$
|
22.28
|
|
|
$
|
23.99
|
|
|
$
|
21.91
|
|
|
Average direct operating costs per operating day – Total
|
|
$
|
14.44
|
|
|
$
|
13.81
|
|
|
$
|
14.10
|
|
|
$
|
13.79
|
|
|
Average margin per operating day – Total (1)
|
|
$
|
9.79
|
|
|
$
|
8.47
|
|
|
$
|
9.89
|
|
|
$
|
8.12
|
|
|
Average rigs operating – Total
|
|
|
142
|
|
|
|
178
|
|
|
|
158
|
|
|
|
174
|
|
|
Capital expenditures
|
|
$
|
34,752
|
|
|
$
|
103,295
|
|
|
$
|
158,141
|
|
|
$
|
299,637
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pressure Pumping:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenues
|
|
$
|
208,637
|
|
|
$
|
421,606
|
|
|
$
|
707,246
|
|
|
$
|
1,253,693
|
|
|
Direct operating costs
|
|
$
|
176,306
|
|
|
$
|
342,498
|
|
|
$
|
585,191
|
|
|
$
|
1,006,353
|
|
|
Margin (2)
|
|
$
|
32,331
|
|
|
$
|
79,108
|
|
|
$
|
122,055
|
|
|
$
|
247,340
|
|
|
Selling, general and administrative
|
|
$
|
3,154
|
|
|
$
|
3,609
|
|
|
$
|
9,734
|
|
|
$
|
11,431
|
|
|
Depreciation, amortization and impairment
|
|
$
|
72,139
|
|
|
$
|
76,986
|
|
|
$
|
188,459
|
|
|
$
|
191,370
|
|
|
Operating income (loss)
|
|
$
|
(42,962)
|
|
|
$
|
(1,487)
|
|
|
$
|
(76,138)
|
|
|
$
|
44,539
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fracturing jobs
|
|
|
126
|
|
|
|
210
|
|
|
|
412
|
|
|
|
631
|
|
|
Other jobs
|
|
|
173
|
|
|
|
287
|
|
|
|
629
|
|
|
|
831
|
|
|
Total jobs
|
|
|
299
|
|
|
|
497
|
|
|
|
1,041
|
|
|
|
1,462
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Average revenue per fracturing job
|
|
$
|
1,631.71
|
|
|
$
|
1,978.49
|
|
|
$
|
1,687.39
|
|
|
$
|
1,958.74
|
|
|
Average revenue per other job
|
|
$
|
17.58
|
|
|
$
|
21.34
|
|
|
$
|
19.14
|
|
|
$
|
21.34
|
|
|
Average revenue per total job
|
|
$
|
697.78
|
|
|
$
|
848.30
|
|
|
$
|
679.39
|
|
|
$
|
857.52
|
|
|
Average costs per total job
|
|
$
|
589.65
|
|
|
$
|
689.13
|
|
|
$
|
562.14
|
|
|
$
|
688.34
|
|
|
Average margin per total job (2)
|
|
$
|
108.13
|
|
|
$
|
159.17
|
|
|
$
|
117.25
|
|
|
$
|
169.18
|
|
|
Margin as a percentage of revenues (2)
|
|
|
15.5
|
%
|
|
|
18.8
|
%
|
|
|
17.3
|
%
|
|
|
19.7
|
%
|
|
Capital expenditures
|
|
$
|
19,826
|
|
|
$
|
44,860
|
|
|
$
|
90,028
|
|
|
$
|
125,978
|
|
|
PATTERSON-UTI ENERGY, INC.
|
|
|
Additional Financial and Operating Data
|
|
|
(unaudited, dollars in thousands)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
|
September 30,
|
|
|
September 30,
|
|
|
|
2019
|
|
|
2018
|
|
|
2019
|
|
|
2018
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Directional Drilling:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenues
|
|
$
|
47,037
|
|
|
$
|
51,556
|
|
|
$
|
150,214
|
|
|
$
|
152,877
|
|
|
Direct operating costs
|
|
$
|
56,215
|
|
|
$
|
44,740
|
|
|
$
|
143,919
|
|
|
$
|
126,114
|
|
|
Margin (3)
|
|
$
|
(9,178)
|
|
|
$
|
6,816
|
|
|
$
|
6,295
|
|
|
$
|
26,763
|
|
|
Selling, general and administrative
|
|
$
|
2,805
|
|
|
$
|
3,548
|
|
|
$
|
7,998
|
|
|
$
|
13,310
|
|
|
Depreciation, amortization and impairment
|
|
$
|
20,518
|
|
|
$
|
12,263
|
|
|
$
|
41,755
|
|
|
$
|
35,039
|
|
|
Operating loss
|
|
$
|
(32,501)
|
|
|
$
|
(8,995)
|
|
|
$
|
(43,458)
|
|
|
$
|
(21,586)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Margin as a percentage of revenues (3)
|
|
|
(19.5)
|
%
|
|
|
13.2
|
%
|
|
|
4.2
|
%
|
|
|
17.5
|
%
|
|
Capital expenditures
|
|
$
|
5,559
|
|
|
$
|
6,855
|
|
|
$
|
11,121
|
|
|
$
|
29,718
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other Operations:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenues
|
|
$
|
25,743
|
|
|
$
|
29,036
|
|
|
$
|
83,363
|
|
|
$
|
81,485
|
|
|
Direct operating costs
|
|
$
|
31,759
|
|
|
$
|
20,447
|
|
|
$
|
71,144
|
|
|
$
|
55,705
|
|
|
Margin (4)
|
|
$
|
(6,016)
|
|
|
$
|
8,589
|
|
|
$
|
12,219
|
|
|
$
|
25,780
|
|
|
Selling, general and administrative
|
|
$
|
5,149
|
|
|
$
|
2,905
|
|
|
$
|
12,660
|
|
|
$
|
9,819
|
|
|
Depreciation, depletion, amortization and impairment
|
|
$
|
10,227
|
|
|
$
|
10,545
|
|
|
$
|
33,472
|
|
|
$
|
29,688
|
|
|
Impairment of goodwill
|
|
$
|
17,800
|
|
|
$
|
—
|
|
|
$
|
17,800
|
|
|
$
|
—
|
|
|
Operating loss
|
|
$
|
(39,192)
|
|
|
$
|
(4,861)
|
|
|
$
|
(51,713)
|
|
|
$
|
(13,727)
|
|
|
Capital expenditures
|
|
$
|
7,191
|
|
|
$
|
6,817
|
|
|
$
|
21,194
|
|
|
$
|
23,524
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Corporate:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Selling, general and administrative
|
|
$
|
21,613
|
|
|
$
|
21,126
|
|
|
$
|
66,672
|
|
|
$
|
62,141
|
|
|
Merger and integration expenses
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
2,738
|
|
|
Depreciation
|
|
$
|
1,761
|
|
|
$
|
1,879
|
|
|
$
|
5,338
|
|
|
$
|
5,997
|
|
|
Provision for bad debts
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
3,594
|
|
|
$
|
—
|
|
|
Other operating expenses (income), net
|
|
$
|
(252)
|
|
|
$
|
(771)
|
|
|
$
|
83
|
|
|
$
|
(10,321)
|
|
|
Capital expenditures
|
|
$
|
700
|
|
|
$
|
958
|
|
|
$
|
2,804
|
|
|
$
|
1,711
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total capital expenditures
|
|
$
|
68,028
|
|
|
$
|
162,785
|
|
|
$
|
283,288
|
|
|
$
|
480,568
|
|
|
|
|
(1)
|
For Contract Drilling, margin is defined as revenues less direct operating costs and excludes depreciation, amortization and impairment and selling, general and administrative expenses. Average margin per operating day is defined as margin divided by operating days.
|
|
|
|
(2)
|
For Pressure Pumping, margin is defined as revenues less direct operating costs and excludes depreciation, amortization and impairment and selling, general and administrative expenses. Average margin per total job is defined as margin divided by total jobs. Margin as a percentage of revenues is defined as margin divided by revenues.
|
|
|
|
(3)
|
For Directional Drilling, margin is defined as revenues less direct operating costs and excludes depreciation, amortization and impairment and selling, general and administrative expenses. Margin as a percentage of revenues is defined as margin divided by revenues.
|
|
|
|
(4)
|
For Other Operations, margin is defined as revenues less direct operating costs and excludes depreciation, depletion, amortization and impairment, impairment of goodwill, and selling, general and administrative expenses.
|
|
|
|
|
|
|
|
September 30,
|
|
December 31,
|
|
Selected Balance Sheet Data (unaudited, in thousands):
|
|
2019
|
|
2018
|
|
Cash and cash equivalents
|
|
$
|
|
164,829
|
|
$
|
|
245,029
|
|
Current assets
|
|
$
|
|
677,560
|
|
$
|
|
950,197
|
|
Current liabilities
|
|
$
|
|
438,858
|
|
$
|
|
526,316
|
|
Working capital
|
|
$
|
|
238,702
|
|
$
|
|
423,881
|
|
Long-term debt
|
|
$
|
|
969,909
|
|
$
|
|
1,119,205
|
|
PATTERSON-UTI ENERGY, INC.
|
|
Non-U.S. GAAP Financial Measures
|
|
(unaudited, dollars in thousands)
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
|
September 30,
|
|
|
September 30,
|
|
|
|
2019
|
|
|
2018
|
|
|
2019
|
|
|
2018
|
|
|
Adjusted Earnings Before Interest, Taxes, Depreciation and Amortization (Adjusted EBITDA)(1):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net loss
|
|
$
|
(261,719)
|
|
|
$
|
(75,042)
|
|
|
$
|
(339,780)
|
|
|
$
|
(120,172)
|
|
|
Income tax benefit
|
|
|
(64,513)
|
|
|
|
(16,517)
|
|
|
|
(81,245)
|
|
|
|
(24,617)
|
|
|
Net interest expense
|
|
|
19,046
|
|
|
|
11,559
|
|
|
|
42,540
|
|
|
|
34,068
|
|
|
Depreciation, depletion, amortization and impairment
|
|
|
400,764
|
|
|
|
281,652
|
|
|
|
823,862
|
|
|
|
703,928
|
|
|
Impairment of goodwill
|
|
|
17,800
|
|
|
|
—
|
|
|
|
17,800
|
|
|
|
—
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjusted EBITDA
|
|
$
|
111,378
|
|
|
$
|
201,652
|
|
|
$
|
463,177
|
|
|
$
|
593,207
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenues
|
|
$
|
598,452
|
|
|
$
|
867,478
|
|
|
$
|
1,978,388
|
|
|
$
|
2,531,060
|
|
|
Adjusted EBITDA margin
|
|
|
18.6
|
%
|
|
|
23.2
|
%
|
|
|
23.4
|
%
|
|
|
23.4
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjusted EBITDA by operating segment:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Contract drilling
|
|
$
|
126,591
|
|
|
$
|
137,275
|
|
|
$
|
423,021
|
|
|
$
|
381,776
|
|
|
Pressure pumping
|
|
|
29,177
|
|
|
|
75,499
|
|
|
|
112,321
|
|
|
|
235,909
|
|
|
Directional drilling
|
|
|
(11,983)
|
|
|
|
3,268
|
|
|
|
(1,703)
|
|
|
|
13,453
|
|
|
Other operations
|
|
|
(11,165)
|
|
|
|
5,684
|
|
|
|
(441)
|
|
|
|
15,961
|
|
|
Corporate
|
|
|
(21,242)
|
|
|
|
(20,074)
|
|
|
|
(70,021)
|
|
|
|
(53,892)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Consolidated Adjusted EBITDA
|
|
$
|
111,378
|
|
|
$
|
201,652
|
|
|
$
|
463,177
|
|
|
$
|
593,207
|
|
|
|
|
(1)
|
Adjusted earnings before interest, taxes, depreciation and amortization ("Adjusted EBITDA") is not defined by accounting principles generally accepted in the United States of America ("U.S. GAAP"). We define Adjusted EBITDA as net income (loss) plus net interest expense, income tax benefit and depreciation, depletion, amortization and impairment expense (including impairment of goodwill). We present Adjusted EBITDA because we believe it provides to both management and investors additional information with respect to the performance of our fundamental business activities and a comparison of the results of our operations from period to period and against our peers without regard to our financing methods or capital structure. We exclude the items listed above from net income (loss) in arriving at Adjusted EBITDA because these amounts can vary substantially from company to company within our industry depending upon accounting methods and book values of assets, capital structures and the method by which the assets were acquired. Adjusted EBITDA should not be construed as an alternative to the U.S. GAAP measure of net income (loss). Our computations of Adjusted EBITDA may not be the same as similarly titled measures of other companies.
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
|
September 30,
|
|
September 30,
|
|
|
2019
|
|
2019
|
|
Adjusted EBITDA
|
|
$
|
111,378
|
|
$
|
463,177
|
|
|
|
|
|
|
|
|
Reverse certain items:
|
|
|
|
|
|
|
|
Write-down of capacity reservation contract
|
|
|
—
|
|
|
12,673
|
|
Provision for bad debts
|
|
|
—
|
|
|
3,594
|
|
Directional drilling charges
|
|
|
16,977
|
|
|
16,977
|
|
Oilfield technology and manufacturing charges
|
|
|
14,581
|
|
|
14,581
|
|
|
|
|
|
|
|
|
Adjusted EBITDA, excluding certain charges (2)
|
|
$
|
142,936
|
|
$
|
511,002
|
|
|
|
(2)
|
We present Adjusted EBITDA, excluding certain charges, in order to convey to investors our performance on a basis that, by excluding certain items, is more comparable to our Adjusted EBITDA performance information reported in previous periods. Adjusted EBITDA, excluding certain non-cash charges, should not be construed as an alternative to the U.S. GAAP measure of net income (loss).
|
|
PATTERSON-UTI ENERGY, INC.
|
|
Pro Forma Net Loss Per Share
|
|
(unaudited, dollars in thousands)
|
|
|
Three Months Ended September 30, 2019
|
|
As Reported
|
|
|
Pro Forma
|
|
Total
|
|
|
Per Share
|
|
|
Total
|
|
|
Per Share (1)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net loss as reported
|
$
|
(261,719)
|
|
|
$
|
(1.31)
|
|
|
$
|
(261,719)
|
|
|
$
|
(1.31)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reverse certain items:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Impairment of property and equipment (2)
|
|
|
|
|
|
|
|
|
|
202,720
|
|
|
|
|
|
Income tax benefit
|
|
|
|
|
|
|
|
|
|
(40,139)
|
|
|
|
|
|
After tax amount
|
|
|
|
|
|
|
|
|
|
162,581
|
|
|
$
|
0.82
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Impairment of goodwill
|
|
|
|
|
|
|
|
|
|
17,800
|
|
|
|
|
|
Income tax benefit
|
|
|
|
|
|
|
|
|
|
(3,524)
|
|
|
|
|
|
After tax amount
|
|
|
|
|
|
|
|
|
|
14,276
|
|
|
$
|
0.07
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Directional drilling charges (3)
|
|
|
|
|
|
|
|
|
|
16,977
|
|
|
|
|
|
Income tax benefit
|
|
|
|
|
|
|
|
|
|
(3,361)
|
|
|
|
|
|
After tax amount
|
|
|
|
|
|
|
|
|
|
13,616
|
|
|
$
|
0.07
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oilfield technology and manufacturing charges (4)
|
|
|
|
|
|
|
|
|
|
14,581
|
|
|
|
|
|
Income tax benefit
|
|
|
|
|
|
|
|
|
|
(2,887)
|
|
|
|
|
|
After tax amount
|
|
|
|
|
|
|
|
|
|
11,694
|
|
|
$
|
0.06
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Early repayment of debt charge (5)
|
|
|
|
|
|
|
|
|
|
8,247
|
|
|
|
|
|
Income tax benefit
|
|
|
|
|
|
|
|
|
|
(1,633)
|
|
|
|
|
|
After tax amount
|
|
|
|
|
|
|
|
|
|
6,614
|
|
|
$
|
0.03
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total, after tax
|
|
|
|
|
|
|
|
|
|
208,781
|
|
|
$
|
1.05
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net loss attributed to common shareholders
|
$
|
(261,719)
|
|
|
$
|
(1.31)
|
|
|
$
|
(52,938)
|
|
|
$
|
(0.27)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock
|
|
199,343
|
|
|
|
|
|
|
|
199,343
|
|
|
|
|
|
Add dilutive effect of potential common shares
|
|
—
|
|
|
|
|
|
|
|
—
|
|
|
|
|
|
Weighted average number of diluted common shares outstanding
|
|
199,343
|
|
|
|
|
|
|
|
199,343
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Effective income tax rate
|
|
19.8
|
%
|
|
|
|
|
|
|
19.8
|
%
|
|
|
|
|
|
(1)
|
We present pro forma net loss per share in order to convey to investors our performance on a basis that, by excluding certain items, is more comparable to our earnings per share information reported in previous periods. Pro Forma Net Loss per Share should not be construed as an alternative to U.S. GAAP earnings per share.
|
|
|
|
(2)
|
Impairment of property and equipment for the three months ended September 30, 2019 was included in "Depreciation, depletion, amortization and impairment" in the Condensed Consolidated Statements of Operations.
|
|
|
|
(3)
|
Directional drilling charges for the three months ended September 30, 2019 were included in "Direct operating costs" in the Condensed Consolidated Statements of Operations.
|
|
|
|
(4)
|
$12.4 million of inventory write-offs and $2.2 million of severance expense for the three months ended September 30, 2019 as a result of transitioning away from our engineering and manufacturing efforts in Calgary were included in "Direct operating costs" and "Selling, general and administrative" in the Condensed Consolidated Statements of Operations, respectively.
|
|
|
|
(5)
|
Early repayment of debt charge for the three months ended September 30, 2019 was included in "Interest expense, net of amount capitalized" in the Condensed Consolidated Statements of Operations.
|
|
PATTERSON-UTI ENERGY, INC.
|
|
Contract Drilling Per Day Successive Quarters
|
|
(unaudited, dollars in thousands)
|
|
|
|
2019
|
|
2019
|
|
|
|
|
|
Third
|
|
Second
|
|
|
|
|
|
Quarter
|
|
Quarter
|
|
Change
|
|
Contract drilling revenues
|
|
$
|
317,035
|
|
$
|
348,138
|
|
$
|
(31,103)
|
|
Operating days - Total
|
|
|
13,081
|
|
|
14,385
|
|
|
(1,304)
|
|
Average rigs operating - Total
|
|
|
142
|
|
|
158
|
|
|
(16)
|
|
Average revenue per operating day - Total
|
|
$
|
24.24
|
|
$
|
24.20
|
|
$
|
0.04
|
|
Early termination revenue
|
|
$
|
6,291
|
|
$
|
4,035
|
|
$
|
2,256
|
|
Average early termination revenue per operating day - Total
|
|
$
|
0.48
|
|
$
|
0.28
|
|
$
|
0.20
|
|
Direct operating costs - Total
|
|
$
|
188,934
|
|
$
|
201,792
|
|
$
|
(12,858)
|
|
Average direct operating costs per operating day - Total
|
|
$
|
14.44
|
|
$
|
14.03
|
|
$
|
0.41
|
|
Average margin per operating day - Total
|
|
$
|
9.79
|
|
$
|
10.17
|
|
$
|
(0.38)
|
|
PATTERSON-UTI ENERGY, INC.
|
|
Pressure Pumping Margin
|
|
(unaudited, dollars in thousands)
|
|
|
|
2019
|
|
2019
|
|
|
|
|
|
Third
|
|
Second
|
|
|
|
|
|
Quarter
|
|
Quarter
|
|
Change
|
|
|
|
|
|
|
|
|
|
|
|
Pressure pumping revenues
|
|
$
|
208,637
|
|
$
|
251,008
|
|
$
|
(42,371)
|
|
Direct operating costs
|
|
|
176,306
|
|
|
206,137
|
|
|
(29,831)
|
|
Margin
|
|
$
|
32,331
|
|
$
|
44,871
|
|
$
|
(12,540)
|
|
PATTERSON-UTI ENERGY, INC.
|
|
Directional Drilling Margin
|
|
(unaudited, in thousands)
|
|
|
|
2019
|
|
2019
|
|
|
|
|
|
Third
|
|
Second
|
|
|
|
|
|
Quarter
|
|
Quarter
|
|
Change
|
|
|
|
|
|
|
|
|
|
|
|
Directional drilling revenues
|
|
$
|
47,037
|
|
$
|
50,218
|
|
$
|
(3,181)
|
|
Direct operating costs
|
|
|
56,215
|
|
|
42,102
|
|
|
14,113
|
|
Margin
|
|
$
|
(9,178)
|
|
$
|
8,116
|
|
$
|
(17,294)
|
 View original content:http://www.prnewswire.com/news-releases/patterson-uti-energy-reports-financial-results-for-the-three-and-nine-months-ended-september-30-2019-300944452.html
SOURCE PATTERSON-UTI ENERGY, INC.
Source: PR Newswire
(October 24, 2019 - 6:00 AM EDT)
News by QuoteMedia
www.quotemedia.com |
