UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549


FORM 8-K

CURRENT REPORT

Pursuant to Section 13 or 15(d) of
the Securities Exchange Act of 1934



Date of Report (date of earliest event reported): July 31, 2014



PIONEER ENERGY SERVICES CORP.
(Exact name of registrant as specified in its charter)


Texas
1-8182
74-2088619
(State or other jurisdiction
of incorporation)

(Commission File Number)
(IRS Employer
Identification No.)

        
1250 N.E. Loop 410, Suite 1000
San Antonio, Texas
78209
(Address of principal executive offices)
(ZIP Code)


Registrant’s telephone number, including area code: (855) 884-0575

_________________________________________

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:
q Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
q Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)
q Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act
(17 CFR 240.14d-2(b))
q Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act
(17 CFR 240.13e-4(c))
_________________________________________







Item 2.02 Results of Operations and Financial Condition

On July 31, 2014, we issued a press release announcing our results of operations for the quarter ended June 30, 2014. A copy of that press release is furnished as Exhibit 99.1 to this report and is incorporated by reference herein.

The information in this Item 2.02, including Exhibit 99.1, shall not be deemed to be “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and will not be incorporated by reference into any registration statement filed under the Securities Act of 1933, as amended, unless specifically identified therein as being incorporated by reference therein.






Item 9.01. Financial Statements and Exhibits

(d)    Exhibits

99.1     Press release issued by Pioneer Energy Services Corp. on July 31, 2014.








SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.


 
PIONEER ENERGY SERVICES CORP.
 
 
 
 
 
 
 
 
By:
 /s/ Lorne E. Phillips      
 
Lorne E. Phillips
 
Executive Vice President and Chief Financial Officer
 
 

    


Date: July 31, 2014




EXHIBIT INDEX

No.        Description

99.1
Press release issued by Pioneer Energy Services Corp. on July 31, 2014.



2014 10Q Q2 PR


Exhibit 99.1                                
Contacts:
Dan Petro, CFA, Director of Corporate Development and Investor Relations
Pioneer Energy Services Corp.
(210) 828-7689

Lisa Elliott / lelliott@dennardlascar.com
Anne Pearson / apearson@dennardlascar.com
Dennard ▪ Lascar Associates / (713) 529-6600
Pioneer Energy Services
Reports Second Quarter 2014 Results
SAN ANTONIO, Texas, July 31, 2014 - Pioneer Energy Services (NYSE: PES) today reported financial and operating results for the quarter ended June 30, 2014. Highlights include:
•
Production Services Segment revenue was $132.3 million in the second quarter, up 9% from the prior quarter.
•
Well servicing rigs achieved a 101% utilization rate and an average hourly rate of $648.
•
Drilling rig utilization is currently 90%, with 42 of our 56 working rigs, or 75%, under term contracts.
•
Planned growth for 2014 and 2015 has expanded to three new 1,500 horsepower AC drilling rigs, 25 well servicing rigs, 14 wireline units and four coiled tubing units.
•
Redeemed $200.5 million of our existing 9.875% Senior Notes with proceeds from our 6.125% Senior Notes, significantly lowering our interest expense.
Consolidated Financial Results
Revenues for the second quarter of 2014 were $259.8 million, up 9% from revenues of $239.0 million in the first quarter of 2014 (“the prior quarter”) and up 5% from revenues of $248.4 million in the second quarter of 2013 (“the year-earlier quarter”). Revenues in the second quarter were positively impacted by increased demand which resulted in higher utilization in our Production Services Segment and our Drilling Services Segment in the U.S.

1


Net loss as reported for the second quarter, which includes the after tax impact of a loss on debt extinguishment of $9.3 million, was $0.3 million, or $0.01 per share. Adjusted net income(1) for the second quarter, which excludes the after tax impact of the loss on debt extinguishment, was $8.9 million, and Adjusted diluted EPS(2) was $0.14. This compares to the prior quarter's net loss as reported of $2.6 million, or $0.04 per share and Adjusted net income of $2.4 million, and Adjusted diluted EPS of $0.04.
Second quarter Adjusted EBITDA(3) was $69.7 million, up 10% from $63.3 million in the prior quarter and up 10% from $63.6 million in the year-earlier quarter.
Operating Results
Drilling Services Segment
Revenue for the Drilling Services Segment was $127.6 million in the second quarter, an 8% increase from the prior quarter and an 8% decrease from the year-earlier quarter. The increase in revenues for the second quarter as compared to the prior quarter was primarily due to increased utilization of certain lower horsepower vertical drilling rigs. The decrease from the year-earlier quarter is due to reduced revenue days due to the sale of eight drilling rigs in October 2013 and rigs on standby in Colombia as a result of customer delays in preparing well sites.
Currently, 56 rigs are earning revenues, of which 42 rigs, or 75%, are under term contracts. All eight of our drilling rigs in Colombia are currently under term contracts that extend through the end of 2014, seven of which are currently earning revenue with the remaining rig expected to be earning revenues again in the fourth quarter.
    Average drilling revenues per day in the second quarter were $26,058, up from $25,471 in the prior quarter and $24,968 in the year-earlier quarter. Dayrates remained firm during the second quarter with some modest increases on select contract renewals. The increase in average drilling revenues per day year over year was due to the full impact of our new-build rigs working in 2014 and certain rigs earning lower standby dayrates during 2013.
Drilling Services Segment margin(4) per day remained flat at $8,946 in the second quarter when compared to $8,987 in the prior quarter and was up 1% from $8,841 in the year-earlier quarter. The second

2


quarter Drilling Services Segment margin per day reflects the benefit from a scope-of-work agreement with our client in Colombia that resulted in additional billings of approximately $2.4 million, or $480 per revenue day, for work performed in prior quarters.
Production Services Segment
Revenue for the Production Services Segment was $132.3 million in the second quarter, up 9% from the prior quarter and up 20% from the year-earlier quarter. The increases in our Production Services Segment's revenues are primarily a result of the increased demand for our services, the contribution of unit additions and job mix. Well servicing pricing was $648 per hour in the second quarter, up slightly from $645 in the prior quarter and up from $606 in the year-earlier quarter. Well servicing rig utilization increased to 101% in the second quarter, up from 95% in the prior quarter and 92% in the year-earlier quarter due to increased demand and the impact of more 24-hour work. Coiled tubing unit utilization increased to 53% in the second quarter, from 50% in the prior quarter and 46% in the year-earlier quarter as demand continues to improve.
Production Services Segment margin(4) as a percentage of revenue was 38% in the second quarter, up from 36% in the prior quarter and 36% in the year-earlier quarter.
Comments from Our President and CEO    
“Our second quarter results exceeded our expectations as demand increased for all of our services, which led to higher utilization in most of the areas in which we operate," said Wm. Stacy Locke, President and CEO of Pioneer Energy Services Corp. "Well servicing rig utilization was exceptionally strong during the second quarter, resulting in the highest utilization ever achieved in company history. We also had some modest pricing improvements on certain term contract renewals in our Drilling Services Segment in the U.S. Additionally, there is increased interest for new-build drilling rigs as our clients continue to shift towards more horizontal drilling in the shale plays. Colombia had solid operating results for the second quarter partly due to the additional billing for the scope-of-work agreement, which is a non-recurring item. We experienced some downtime in Colombia due to delays by our client in preparing well sites, which will continue in the third quarter.

3


“While we intend to de-lever over time, we are seeing strong growth opportunities and have decided to expand our 2014 and 2015 capital expenditure program to meet customer demand. We have committed to add three new 1,500 horsepower AC drilling rigs that will begin working under term contracts in the Permian Basin and Eagle Ford Shale in the second and third quarters of 2015. In the Production Services Segment, we are adding a total of nine well servicing rigs, six wireline units and four coiled tubing units in 2014, followed by another 16 well service rigs and eight wireline units in 2015.
“We reduced debt $10 million in June and another $10 million in July and will continue to pay down debt when possible. The lower interest expense in the second quarter reflects our reduced debt outstanding as well as our success at replacing our higher interest notes with lower interest notes in the first and second quarters,” continued Locke.
Third Quarter Guidance
In the third quarter of 2014, drilling rig utilization is expected to average between approximately 86% and 89%, based on a fleet of 62 rigs. Drilling Services Segment margin is expected to be approximately $8,500 to $8,700 per day, which is flat with the second quarter when excluding the non-recurring benefit from the scope-of-work agreement in Colombia.
Production Services Segment revenue in the third quarter is expected to be up approximately 3% to 5% as compared to the second quarter. Production Services Segment margin as a percentage of revenues is expected to be up approximately 1% as compared to the second quarter.
Liquidity
Working capital at June 30, 2014 was $149.2 million, up from $118.5 million at December 31, 2013. Our cash and cash equivalents were $23.7 million, down from $27.4 million at year-end 2013.
The decrease in cash and cash equivalents during the six months ended June 30, 2014 is primarily due to $74.6 million used for purchases of property and equipment and $31.1 million of cash used in our financing activities, which were mostly offset by $95.5 million of cash provided by operating activities and $6.5 million of proceeds from the sale of assets.

4


On May 1, 2014, we redeemed $200.5 million of our 2010 and 2011 Senior Notes. We recognized a loss on debt extinguishment of approximately $14.6 million for the redemption premium, net unamortized discount and unamortized debt issuance costs. In total, we have redeemed $300 million of the 9.875% Senior Notes with the proceeds from the issuance of the 6.125% Senior Notes in March 2014, which will significantly lower our interest expense.
We currently have $60 million outstanding and $14.0 million in committed letters of credit under our $250 million Revolving Credit Facility.
Capital Expenditures
Cash capital expenditures in the second quarter were $42.9 million, including capitalized interest. We estimate that our total cash capital expenditures in 2014 will be approximately $185 million to $200 million. The total 2014 capital expenditure budget includes partial payments for three 1,500 horsepower AC drilling rigs, nine well servicing rigs, six wireline units, four coiled tubing units, upgrades to certain drilling rigs and routine capital expenditures. In addition, the 2014 capital expenditure budget includes down payments for certain equipment that will be delivered in 2015, but requires long lead-time orders.
Conference Call
Pioneer Energy Services' management team will hold a conference call today at 10:00 a.m. Eastern Time (9:00 a.m. Central Time), to discuss these results. To participate in the call, dial (719) 325-2429 ten minutes early and ask for the Pioneer Energy Services conference call. A replay will be available after the call and will be accessible until August 7. To access the replay, dial (719) 457-0820 and enter the pass code 2737502#.
The conference call will also be webcast on the Internet and accessible from Pioneer Energy Services' Web site at www.pioneeres.com. To listen to the live call, visit Pioneer Energy Services' Web site at least 10 minutes early to register and download any necessary audio software. A replay will be available shortly after the call. For more information, please contact Donna Washburn at Dennard ▪ Lascar Associates, LLC at (713) 529-6600 or e-mail dwashburn@dennardlascar.com.

5



About Pioneer
Pioneer Energy Services provides contract land drilling services to independent and major oil and gas operators in Texas, the Mid-Continent, Rocky Mountain and Appalachian regions and internationally in Colombia through its Drilling Services Segment. Pioneer also provides well, wireline, coiled tubing and fishing and rental services to producers in the U.S. Gulf Coast, offshore Gulf of Mexico, Mid-Continent and Rocky Mountain regions through its Production Services Segment.
Cautionary Statement Regarding Forward-Looking Statements,
Non-GAAP Financial Measures and Reconciliations
Statements we make in this news release that express a belief, expectation or intention, as well as those that are not historical fact, are forward-looking statements that are subject to risks, uncertainties and assumptions. Our actual results, performance or achievements, or industry results, could differ materially from those we express in the following discussion as a result of a variety of factors, including general economic and business conditions and industry trends, levels and volatility of oil and gas prices, decisions about exploration and development projects to be made by oil and gas exploration and production companies, economic cycles and their impact on capital markets and liquidity, the continued demand for drilling services or production services in the geographic areas where we operate, the highly competitive nature of our business, our future financial performance, including availability, terms and deployment of capital, future compliance with covenants under our senior secured revolving credit facility and our senior notes, the supply of marketable drilling rigs, well servicing rigs, coiled tubing and wireline units within the industry, changes in technology and improvements in our competitors' equipment, the continued availability of drilling rig, well servicing rig, coiled tubing and wireline unit components, the continued availability of qualified personnel, the success or failure of our acquisition strategy, including our ability to finance acquisitions, manage growth and effectively integrate acquisitions, and changes in, or our failure or inability to comply with, governmental regulations, including those relating to the environment. We have discussed many of these factors in more detail in our Annual Report on Form 10-K for the year ended December 31, 2013. These factors are not necessarily all the important factors that could affect us. Unpredictable or unknown factors we have not discussed in this news release, in our Annual Report on Form 10-K for the year ended December 31, 2013, or in our Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2014 could also have material adverse effects on actual results of matters that are the subject of our forward-looking statements. All forward-looking statements speak only as of the date on which they are made and we undertake no obligation to publicly update or revise any forward-looking statements whether as a result of new information, future events or otherwise. We advise our shareholders that they should (1) be aware that important factors not referred to above could affect the accuracy of our forward-looking statements and (2) use caution and common sense when considering our forward-looking statements.
 
This news release contains non-GAAP financial measures as defined by SEC Regulation G. A reconciliation of each such measure to its most directly comparable U.S. Generally Accepted Accounting Principles (GAAP) financial measure, together with an explanation of why management believes that these non-GAAP financial measures provide useful information to investors, is provided in the following tables.
_________________________________
 

(1)
Adjusted net income (loss) represents net income (loss) as reported less the loss on debt extinguishment and the related tax benefit. We believe that adjusted net income (loss) is a useful measure for evaluating our core operating performance, although it is not a measure of financial performance under GAAP. Adjusted net income (loss) may not be comparable to other similarly titled measures reported by other companies.

(2)
Adjusted (diluted) EPS represents adjusted net income (loss) divided by the weighted-average number of shares outstanding during the period, including the effect of dilutive securities as applicable. We believe that

6


adjusted (diluted) EPS is a useful measure for evaluating our core operating performance, although it is not a measure of financial performance under GAAP. A reconciliation of (diluted) EPS as reported to adjusted (diluted) EPS is included in the tables to this news release. Adjusted (diluted) EPS may not be comparable to other similarly titled measures reported by other companies. A reconciliation of net income (loss) as reported to adjusted net income (loss) is included in the tables to this news release.

(3)
Adjusted EBITDA is a financial measure that is not in accordance with GAAP and should not be considered (a) in isolation of, or as a substitute for, net income (loss), (b) as an indication of cash flows from operating activities or (c) as a measure of liquidity. In addition, Adjusted EBITDA does not represent funds available for discretionary use. We define Adjusted EBITDA as income (loss) before interest income (expense), taxes, depreciation, amortization, loss on extinguishment of debt and any impairments. We use this measure, together with our GAAP financial metrics, to assess our financial performance and evaluate our overall progress towards meeting our long-term financial objectives. We believe that this non-GAAP financial measure is useful to investors and analysts in allowing for greater transparency of our operating performance and makes it easier to compare our results with those of other companies within our industry. Adjusted EBITDA, as we calculate it, may not be comparable to Adjusted EBITDA measures reported by other companies. A reconciliation of Adjusted EBITDA to net loss as reported is included in the tables to this news release.

(4)
Drilling Services Segment margin represents contract drilling revenues less contract drilling operating costs. Production Services Segment margin represents production services revenue less production services operating costs. We believe that Drilling Services Segment margin and Production Services Segment margin are useful measures for evaluating financial performance, although they are not measures of financial performance under GAAP. However, Drilling Services Segment margin and Production Services Segment margin are common measures of operating performance used by investors, financial analysts, rating agencies and Pioneer’s management. Drilling Services Segment margin and Production Services Segment margin as presented may not be comparable to other similarly titled measures reported by other companies. A reconciliation of Drilling Services Segment margin and Production Services Segment margin to net loss as reported is included in the tables to this news release.

(5)
Drilling Services Segment margin per revenue day represents the Drilling Services Segment's average revenue per revenue day less average operating costs per revenue day.

 
- Financial Statements and Operating Information Follow -




7


PIONEER ENERGY SERVICES CORP. AND SUBSIDIARIES
Condensed Consolidated Statements of Operations
(in thousands, except per share data)
(unaudited)

 
Three months ended
 
Six months ended
 
June 30,
 
March 31,
 
June 30,
 
2014
 
2013
 
2014
 
2014
 
2013
 
 
 
 
 
 
 
 
 
 
Revenues:
 
 
 
 
 
 
 
 
 
Drilling services
$
127,553

 
$
138,250

 
$
117,957

 
$
245,510

 
$
271,324

Production services
132,259

 
110,104

 
121,077

 
253,336

 
206,700

Total revenues
259,812

 
248,354

 
239,034

 
498,846

 
478,024

 
 
 
 
 
 
 
 
 
 
Costs and expenses:
 
 
 
 
 
 
 
 
 
Drilling services
83,762

 
89,294

 
76,338

 
160,100

 
178,280

Production services
82,505

 
70,450

 
77,752

 
160,257

 
131,069

Depreciation and amortization
45,791

 
47,348

 
45,526

 
91,317

 
93,633

General and administrative
25,276

 
23,605

 
24,483

 
49,759

 
46,659

Bad debt expense (recovery)
561

 
137

 
(124
)
 
437

 
418

Impairment charges
—

 
44,788

 
—

 
—

 
44,788

Total costs and expenses
237,895

 
275,622

 
223,975

 
461,870

 
494,847

Income (loss) from operations
21,917

 
(27,268
)
 
15,059

 
36,976

 
(16,823
)
 
 
 
 
 
 
 
 
 
 
Other (expense) income:
 
 
 
 
 
 
 
 
 
Interest expense
(10,728
)
 
(12,331
)
 
(12,388
)
 
(23,116
)
 
(23,793
)
Loss on extinguishment of debt
(14,595
)
 
—

 
(7,887
)
 
(22,482
)
 
—

Other
2,017

 
(1,249
)
 
2,674

 
4,691

 
(2,070
)
Total other expense
(23,306
)
 
(13,580
)
 
(17,601
)
 
(40,907
)
 
(25,863
)
 
 
 
 
 
 
 
 
 
 
Loss before income taxes
(1,389
)
 
(40,848
)
 
(2,542
)
 
(3,931
)
 
(42,686
)
Income tax (expense) benefit
1,070

 
14,953

 
(37
)
 
1,033

 
15,499

Net loss
$
(319
)
 
$
(25,895
)
 
$
(2,579
)
 
$
(2,898
)
 
$
(27,187
)
 
 
 
 
 
 
 
 
 
 
Loss per common share:
 
 
 
 
 
 
 
 
 
Basic
$
(0.01
)
 
$
(0.42
)
 
$
(0.04
)
 
$
(0.05
)
 
$
(0.44
)
Diluted
$
(0.01
)
 
$
(0.42
)
 
$
(0.04
)
 
$
(0.05
)
 
$
(0.44
)
 
 
 
 
 
 
 
 
 
 
Weighted-average number of shares outstanding:
 
 
 
 
 
 
 
 
 
Basic
62,877

 
62,177

 
62,542

 
62,710

 
62,073

Diluted
62,877

 
62,177

 
62,542

 
62,710

 
62,073







8




PIONEER ENERGY SERVICES CORP. AND SUBSIDIARIES
Condensed Consolidated Balance Sheets
(in thousands)



 
June 30,
2014
 
December 31,
2013
 
(unaudited)
 
(audited)
ASSETS
 
 
 
Current assets:
 
 
 
Cash and cash equivalents
$
23,711

 
$
27,385

Receivables, net of allowance for doubtful accounts
200,537

 
176,360

Deferred income taxes
32,365

 
13,092

Inventory
13,466

 
13,232

Prepaid expenses and other current assets
9,390

 
9,311

Total current assets
279,469

 
239,380

 
 
 
 
Net property and equipment
923,440

 
937,657

Intangible assets, net of accumulated amortization
28,276

 
32,269

Noncurrent deferred income taxes
4,010

 
1,156

Other long-term assets
16,236

 
19,161

Total assets
$
1,251,431

 
$
1,229,623

 
 
 
 
LIABILITIES AND SHAREHOLDERS' EQUITY
 
 
 
Current liabilities:
 
 
 
Accounts payable
$
54,735

 
$
43,718

Current portion of long-term debt
429

 
2,847

Deferred revenues
3,306

 
699

Accrued expenses
71,783

 
73,569

Total current liabilities
130,253

 
120,833

 
 
 
 
Long-term debt, less current portion
493,630

 
499,666

Noncurrent deferred income taxes
102,988

 
84,636

Other long-term liabilities
4,771

 
6,055

Total liabilities
731,642

 
711,190

Total shareholders’ equity
519,789

 
518,433

Total liabilities and shareholders’ equity
$
1,251,431

 
$
1,229,623









9



PIONEER ENERGY SERVICES CORP. AND SUBSIDIARIES
Condensed Consolidated Statements of Cash Flows
(in thousands)
(unaudited)

 
Six months ended
 
June 30,
 
2014
 
2013
 
 
 
 
Cash flows from operating activities:
 
 
 
Net loss
$
(2,898
)
 
$
(27,187
)
Adjustments to reconcile net loss to net cash provided by operating activities:
 
 
 
Depreciation and amortization
91,317

 
93,633

Allowance for doubtful accounts
396

 
408

Gain on dispositions of property and equipment
(1,731
)
 
(1,721
)
Stock-based compensation expense
3,827

 
3,064

Amortization of debt issuance costs, discount and premium
1,504

 
1,534

Loss on extinguishment of debt
22,482

 
—

Impairment charges
—

 
44,788

Deferred income taxes
(3,762
)
 
(16,717
)
Change in other long-term assets
4,448

 
(2,113
)
Change in other long-term liabilities
(1,284
)
 
(1,340
)
Changes in current assets and liabilities
(18,812
)
 
(23,672
)
Net cash provided by operating activities
95,487

 
70,677

 
 
 
 
Cash flows from investing activities:
 
 
 
Purchases of property and equipment
(74,567
)
 
(112,179
)
Proceeds from sale of property and equipment
6,538

 
6,059

Net cash used in investing activities
(68,029
)
 
(106,120
)
 
 
 
 
Cash flows from financing activities:
 
 
 
Debt repayments
(330,013
)
 
(10,862
)
Proceeds from issuance of debt
320,000

 
40,000

Debt issuance costs
(6,187
)
 
(13
)
Tender premium costs
(15,381
)
 
—

Proceeds from exercise of options
1,581

 
789

Purchase of treasury stock
(1,132
)
 
(628
)
Net cash provided by (used in) financing activities
(31,132
)
 
29,286

 
 
 
 
Net decrease in cash and cash equivalents
(3,674
)
 
(6,157
)
Beginning cash and cash equivalents
27,385

 
23,733

Ending cash and cash equivalents
$
23,711

 
$
17,576


10



PIONEER ENERGY SERVICES CORP. AND SUBSIDIARIES
Operating Statistics
(in thousands, except average number of drilling rigs, utilization rate, revenue days and per day information)
(unaudited)

 
Three months ended
 
Six months ended
 
June 30,
 
March 31,
 
June 30,
 
2014
 
2013
 
2014
 
2014
 
2013
 
 
 
 
 
 
 
 
 
 
Drilling Services Segment:
 
 
 
 
 
 
 
 
 
Revenues
$
127,553

 
$
138,250

 
$
117,957

 
$
245,510

 
$
271,324

Operating costs
83,762

 
89,294

 
76,338

 
160,100

 
178,280

Drilling Services Segment margin (1)
$
43,791

 
$
48,956

 
$
41,619

 
$
85,410

 
$
93,044

 
 
 
 
 
 
 
 
 
 
Average number of drilling rigs
62.0

 
70.3

 
62.0

 
62.0

 
70.4

Utilization rate
87
%
 
87
%
 
83
%
 
85
%
 
85
%
Revenue days
4,895

 
5,537

 
4,631

 
9,526

 
10,876

 
 
 
 
 
 
 
 
 
 
Average revenues per day
$
26,058

 
$
24,968

 
$
25,471

 
$
25,773

 
$
24,947

Average operating costs per day
17,112

 
16,127

 
16,484

 
16,807

 
16,392

Drilling Services Segment margin per day (2)
$
8,946

 
$
8,841

 
$
8,987

 
$
8,966

 
$
8,555

 
 
 
 
 
 
 
 
 
 
Production Services Segment:
 
 
 
 
 
 
 
 
 
Revenues
$
132,259

 
$
110,104

 
$
121,077

 
$
253,336

 
$
206,700

Operating costs
82,505

 
70,450

 
77,752

 
160,257

 
131,069

Production Services Segment margin (1)
$
49,754

 
$
39,654

 
$
43,325

 
$
93,079

 
$
75,631

 
 
 
 
 
 
 
 
 
 
Combined:
 
 
 
 
 
 
 
 
 
Revenues
$
259,812

 
$
248,354

 
$
239,034

 
$
498,846

 
$
478,024

Operating Costs
166,267

 
159,744

 
154,090

 
320,357

 
309,349

Combined margin
$
93,545

 
$
88,610

 
$
84,944

 
$
178,489

 
$
168,675

 
 
 
 
 
 
 
 
 
 
Adjusted EBITDA (3)
$
69,725

 
$
63,619

 
$
63,259

 
$
132,984

 
$
119,528

 
 
 
 
 
 
 
 
 
 


(1)Drilling Services Segment margin represents contract drilling revenues less contract drilling operating costs. Production Services Segment margin represents production services revenue less production services operating costs. We believe that Drilling Services Segment margin and Production Services Segment margin are useful measures for evaluating financial performance, although they are not measures of financial performance under U.S. Generally Accepted Accounting Principles (GAAP). However, Drilling Services Segment margin and Production Services Segment margin are common measures of operating performance used by investors, financial analysts, rating agencies and Pioneer’s management. Drilling Services Segment margin and Production Services Segment margin as presented may not be comparable to other similarly titled measures reported by other companies. A reconciliation of combined Drilling Services Segment margin and Production Services Segment margin to net income (loss) as reported is included in the table on the following page.

(2)Drilling Services Segment margin per revenue day represents the Drilling Services Segment's average revenue per revenue day less average operating costs per revenue day.

(3)Adjusted EBITDA is a financial measure that is not in accordance with GAAP and should not be considered (a) in isolation of, or as a substitute for, net income (loss), (b) as an indication of cash flows from operating activities or (c) as a measure of liquidity. In addition, Adjusted EBITDA does not represent funds available for discretionary use. We define Adjusted EBITDA as income (loss) before interest income (expense), taxes, depreciation, amortization, loss on extinguishment of debt and any impairments. We use this measure, together with our GAAP financial metrics, to assess our financial performance and evaluate our overall progress towards meeting our long-term financial objectives. We believe that this non-GAAP financial measure is useful to investors and analysts in allowing for greater transparency of our operating performance and makes it easier to compare our results with those of other companies within our industry. Adjusted EBITDA, as we calculate it, may not be comparable to Adjusted EBITDA measures reported by other companies. A reconciliation of Adjusted EBITDA to net income (loss) as reported is included in the table on the following page.



11


PIONEER ENERGY SERVICES CORP. AND SUBSIDIARIES
Reconciliation of Combined Drilling Services and Production Services
Margin and Adjusted EBITDA to Net Income (Loss)
(in thousands)
(unaudited)

 
Three months ended
 
Six months ended
 
June 30,
 
March 31,
 
June 30,
 
2014
 
2013
 
2014
 
2014
 
2013
 
 
 
 
 
 
 
 
 
 
Combined margin
$
93,545

 
$
88,610

 
$
84,944

 
$
178,489

 
$
168,675

 
 
 
 
 
 
 
 
 
 
General and administrative
(25,276
)
 
(23,605
)
 
(24,483
)
 
(49,759
)
 
(46,659
)
Bad debt (recovery) expense
(561
)
 
(137
)
 
124

 
(437
)
 
(418
)
Other income (expense)
2,017

 
(1,249
)
 
2,674

 
4,691

 
(2,070
)
Adjusted EBITDA (3)
69,725

 
63,619

 
63,259

 
132,984

 
119,528

 
 
 
 
 
 
 
 
 
 
Depreciation and amortization
(45,791
)
 
(47,348
)
 
(45,526
)
 
(91,317
)
 
(93,633
)
Impairment charges
—

 
(44,788
)
 
—

 
—

 
(44,788
)
Interest expense
(10,728
)
 
(12,331
)
 
(12,388
)
 
(23,116
)
 
(23,793
)
Loss on extinguishment of debt
(14,595
)
 
—

 
(7,887
)
 
(22,482
)
 
—

Income tax (expense) benefit
1,070

 
14,953

 
(37
)
 
1,033

 
15,499

Net loss
$
(319
)
 
$
(25,895
)
 
$
(2,579
)
 
$
(2,898
)
 
$
(27,187
)



12


PIONEER ENERGY SERVICES CORP. AND SUBSIDIARIES
Reconciliation of Net Loss as Reported to Adjusted Net Loss Excluding the Impact of Loss on Extinguishment of Debt and Diluted EPS as Reported to Adjusted Diluted EPS Excluding the Impact of Loss on Extinguishment of Debt
(in thousands, except per share data)
(unaudited)
 
Three months ended
 
June 30,
 
March 31,
 
2014
 
2014
 
 
 
 
Net loss as reported
$
(319
)
 
$
(2,579
)
Loss on extinguishment of debt
14,595

 
7,887

Tax benefit from loss on extinguishment of debt
(5,342
)
 
(2,887
)
Adjusted net income (loss) (4)
8,934

 
2,421

 
 
 
 
Basic weighted average number of shares outstanding, as reported
62,877

 
62,542

Effect of dilutive securities
2,465

 
1,775

Diluted weighted average number of shares outstanding, adjusted for loss on extinguishment of debt impact
65,342

 
64,317

 
 
 
 
Adjusted diluted EPS (5)
$
0.14

 
$
0.04

 
 
 
 
Diluted EPS as reported (6)
$
(0.01
)
 
$
(0.04
)

(4)Adjusted net income (loss) represents net income (loss) as reported less the loss on debt extinguishment and the related tax benefit. We believe that adjusted net income (loss) is a useful measure for evaluating our core operating performance, although it is not a measure of financial performance under GAAP. Adjusted net income (loss) may not be comparable to other similarly titled measures reported by other companies.

(5)Adjusted (diluted) EPS represents adjusted net income (loss) divided by the weighted-average number of shares outstanding during the period, including the effect of dilutive securities as applicable. We believe that adjusted (diluted) EPS is a useful measure for evaluating our core operating performance, although it is not a measure of financial performance under GAAP. A reconciliation of (diluted) EPS as reported to adjusted (diluted) EPS is included in the tables to this news release. Adjusted (diluted) EPS may not be comparable to other similarly titled measures reported by other companies. A reconciliation of net income (loss) as reported to adjusted net income (loss) is included in the table above.

(6)The effect of dilutive securities is not reflected in diluted earnings per share (EPS) as reported because the effect of their inclusion would be antidilutive, or would decrease the reported loss per share. Therefore, basic EPS as reported is the same as diluted EPS as reported.

13




PIONEER ENERGY SERVICES CORP. AND SUBSIDIARIES
Capital Expenditures
(in thousands)
(unaudited)


 
Three months ended
 
Six months ended
 
June 30,
 
March 31,
 
June 30,
 
2014
 
2013
 
2014
 
2014
 
2013
 
 
 
 
 
 
 
 
Drilling Services Segment:
 
 
 
 
 
 
 
 
 
Routine and tubulars
$
11,774

 
$
12,927

 
$
8,769

 
$
20,543

 
$
19,789

Discretionary
6,076

 
8,345

 
9,872

 
15,948

 
22,063

Fleet additions
3,575

 
7,492

 
153

 
3,728

 
40,954

 
21,425

 
28,764

 
18,794

 
40,219

 
82,806

Production Services Segment:
 
 
 
 
 
 
 
 
 
Routine
9,306

 
6,267

 
5,389

 
14,695

 
11,976

Discretionary
3,148

 
4,996

 
5,854

 
9,002

 
13,562

Fleet additions
9,014

 
839

 
1,637

 
10,651

 
3,835

 
21,468

 
12,102

 
12,880

 
34,348

 
29,373

Net cash used for purchases of property and equipment
42,893

 
40,866

 
31,674

 
74,567

 
112,179

  Net effect of accruals
(1,897
)
 
(8,206
)
 
5,243

 
3,346

 
(37,469
)
Total capital expenditures
$
40,996

 
$
32,660

 
$
36,917

 
$
77,913

 
$
74,710
































14


PIONEER ENERGY SERVICES CORP. AND SUBSIDIARIES
Drilling Rig, Well Servicing Rig, Wireline and Coiled Tubing Unit
Current Information


Drilling Services Segment:
Rig Type
 
 
 
Mechanical
 
Electric
 
Total Rigs
 
 
 
 
 
 
Drilling rig horsepower ratings:
 
 
 
 
 
    550 to 700 HP
1

 
—

 
1

    750 to 950 HP
4

 
2

 
6

    1000 HP
12

 
9

 
21

    1200 to 2000 HP
6

 
28

 
34

        Total
23

 
39

 
62

 
 
 
 
 
 
Drilling rig depth ratings:
 
 
 
 
 
    Less than 10,000 feet
3

 
2

 
5

    10,000 to 13,900 feet
10

 
6

 
16

    14,000 to 25,000 feet
10

 
31

 
41

        Total
23

 
39

 
62

 
 
 
 
 
 
Production Services Segment:
 
 
 
 
 
 
 
 
 
 
 
Well servicing rig horsepower ratings:
 
 
 
 
 
    550 HP
 
 
 
 
102

    600 HP
 
 
 
 
10

        Total
 
 
 
 
112

 
 
 
 
 
 
Wireline units
 
 
 
 
121

 
 
 
 
 
 
Coiled tubing units
 
 
 
 
15

 
 
 
 
 
 



15