10-Q 1 pxd-20150930.htm 10-Q 10-Q
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549 
______________________________
FORM 10-Q 
______________________________
ý
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended September 30, 2015
or 
¨
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from  ________ to ________                     
Commission File Number: 1-13245
______________________________ 
PIONEER NATURAL RESOURCES COMPANY
(Exact name of Registrant as specified in its charter)
______________________________
Delaware
 
75-2702753
(State or other jurisdiction of
incorporation or organization)
 
(I.R.S. Employer
Identification No.)
 
 
5205 N. O'Connor Blvd., Suite 200, Irving, Texas
 
75039
(Address of principal executive offices)
 
(Zip Code)
(972) 444-9001
(Registrant's telephone number, including area code)
Not applicable
(Former name, former address and former fiscal year, if changed since last report) 
______________________________
Indicate by check mark whether the Registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.     Yes  ý    No  ¨
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    
Yes   ý    No   ¨
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See the definitions of "large accelerated filer," "accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Exchange Act. 
Large accelerated filer
 
ý
  
Accelerated filer
 
¨
 
 
 
 
Non-accelerated filer
 
o (Do not check if a smaller reporting company)
  
Smaller reporting company
 
¨
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
Yes   ¨    No  ý
Number of shares of Common Stock outstanding as of October 30, 2015                               149,377,919



PIONEER NATURAL RESOURCES COMPANY
TABLE OF CONTENTS 
 
 
Page
 
 
 
 
 
 
Item 1.
 
 
 
 
 
Consolidated Balance Sheets as of September 30, 2015 and December 31, 2014
 
 
 
 
Consolidated Statements of Operations for the three and nine months ended September 30, 2015 and 2014
 
 
 
 
Consolidated Statement of Equity for the nine months ended September 30, 2015
 
 
 
 
Consolidated Statements of Cash Flows for the nine months ended September 30, 2015 and 2014
 
 
 
 
 
 
 
Item 2.
 
 
 
Item 3.
 
 
 
Item 4.
 
 
 
 
Item 1.
 
 
 
Item 1A.
 
 
 
Item 2.
 
 
 
Item 4.
 
 
 
Item 6.
 
 
 
 

2


PIONEER NATURAL RESOURCES COMPANY
Cautionary Statement Concerning Forward-Looking Statements
The information in this Quarterly Report on Form 10-Q (this "Report") contains forward-looking statements that involve risks and uncertainties. When used in this document, the words "believes," "plans," "expects," "anticipates," "forecasts," "intends," "continue," "may," "will," "could," "should," "future," "potential," "estimate" or the negative of such terms and similar expressions as they relate to Pioneer Natural Resources Company ("Pioneer" or the "Company") are intended to identify forward-looking statements, which are generally not historical in nature. The forward-looking statements are based on the Company's current expectations, assumptions, estimates and projections about the Company and the industry in which the Company operates. Although the Company believes that the expectations and assumptions reflected in the forward-looking statements are reasonable as and when made, they involve risks and uncertainties that are difficult to predict and, in many cases, beyond the Company's control.
These risks and uncertainties include, among other things, volatility of commodity prices, product supply and demand, competition, the ability to obtain environmental and other permits and the timing thereof, other government regulation or action, the ability to obtain approvals from third parties and negotiate agreements with third parties on mutually acceptable terms, litigation, the costs and results of drilling and operations, availability of equipment, services, resources and personnel required to perform the Company's drilling and operating activities, access to and availability of transportation, processing, fractionation and refining facilities, Pioneer's ability to replace reserves, implement its business plans or complete its development activities as scheduled, access to and cost of capital, the financial strength of counterparties to Pioneer's credit facility and derivative contracts and the purchasers of Pioneer's oil, NGL and gas production, uncertainties about estimates of reserves and the ability to add proved reserves in the future, the assumptions underlying production forecasts, quality of technical data, environmental and weather risks, including the possible impacts of climate change, the risks associated with the ownership and operation of the Company's industrial sand mining and oilfield services businesses, and acts of war or terrorism. These and other risks are described in the Company's Annual Report on Form 10-K, this and other Quarterly Reports on Form 10-Q and other filings with the United States Securities and Exchange Commission. In addition, the Company may be subject to currently unforeseen risks that may have a materially adverse effect on it. Accordingly, no assurances can be given that the actual events and results will not be materially different than the anticipated results described in the forward-looking statements. See "Part I, Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations," "Part 1, Item 3. Quantitative and Qualitative Disclosures About Market Risk" and "Part II, Item 1A. Risk Factors" in this Report and "Part I, Item 1. Business — Competition, Markets and Regulations," "Part I, Item 1A. Risk Factors," "Part II, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" and "Part II, Item 7A. Quantitative and Qualitative Disclosures About Market Risk" in the Company's Annual Report on Form 10-K for the year ended December 31, 2014 for a description of various factors that could materially affect the ability of Pioneer to achieve the anticipated results described in the forward-looking statements. Readers are cautioned not to place undue reliance on forward-looking statements, which speak only as of the date hereof. The Company undertakes no duty to publicly update these statements except as required by law.

3


PIONEER NATURAL RESOURCES COMPANY
Definitions of Certain Terms and Conventions Used Herein
Within this Report, the following terms and conventions have specific meanings:
"Bbl" means a standard barrel containing 42 United States gallons.
"BOE" means a barrel of oil equivalent and is a standard convention used to express oil and gas volumes on a comparable oil equivalent basis. Gas equivalents are determined under the relative energy content method by using the ratio of six thousand cubic feet of gas to one Bbl of oil or natural gas liquid.
"BOEPD" means BOE per day.
"Btu" means British thermal unit, which is a measure of the amount of energy required to raise the temperature of one pound of water one degree Fahrenheit.
"Conway" means the daily average natural gas liquids components as priced in Oil Price Information Service ("OPIS") in the table "U.S. and Canada LP – Gas Weekly Averages" at Conway, Kansas.
"DD&A" means depletion, depreciation and amortization.
"GAAP" means accounting principles that are generally accepted in the United States of America.
"LIBOR" means London Interbank Offered Rate, which is a market rate of interest.
"Mcf" means one thousand cubic feet and is a measure of gas volume.
"MMBtu" means one million Btus.
"Mont Belvieu" means the daily average natural gas liquids components as priced in OPIS in the table "U.S. and Canada LP – Gas Weekly Averages" at Mont Belvieu, Texas.
"NGL" means natural gas liquid.
"NYMEX" means the New York Mercantile Exchange.
"Pioneer" or the "Company" means Pioneer Natural Resources Company and its subsidiaries.
"Proved reserves" mean the quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible – from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations – prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time.
(i) The area of the reservoir considered as proved includes: (A) The area identified by drilling and limited by fluid contacts, if any, and (B) Adjacent undrilled portions of the reservoir that can, with reasonable certainty, be judged to be continuous with it and to contain economically producible oil or gas on the basis of available geoscience and engineering data.
(ii) In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known hydrocarbons ("LKH") as seen in a well penetration unless geoscience, engineering, or performance data and reliable technology establishes a lower contact with reasonable certainty.
(iii) Where direct observation from well penetrations has defined a highest known oil ("HKO") elevation and the potential exists for an associated gas cap, proved oil reserves may be assigned in the structurally higher portions of the reservoir only if geoscience, engineering, or performance data and reliable technology establish the higher contact with reasonable certainty.
(iv) Reserves which can be produced economically through application of improved recovery techniques (including, but not limited to, fluid injection) are included in the proved classification when: (A) Successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir, or other evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which the project or program was based; and (B) The project has been approved for development by all necessary parties and entities, including governmental entities.
(v) Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined. The price shall be the average during the 12-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions.
"U.S." means United States.
With respect to information on the working interest in wells, drilling locations and acreage, "net" wells, drilling locations and acres are determined by multiplying "gross" wells, drilling locations and acres by the Company's working interest in such wells, drilling locations or acres. Unless otherwise specified, wells, drilling locations and acreage statistics quoted herein represent gross wells, drilling locations or acres.
Unless otherwise indicated, all currency amounts are expressed in U.S. dollars.

4


PART I. FINANCIAL INFORMATION
Item 1.    Financial Statements
PIONEER NATURAL RESOURCES COMPANY
CONSOLIDATED BALANCE SHEETS
(in millions)
 
 
 
September 30,
2015
 
December 31,
2014
 
 
(Unaudited)
 
 
ASSETS
Current assets:
 
 
 
 
Cash and cash equivalents
 
$
581

 
$
1,025

Accounts receivable:
 
 
 
 
Trade, net
 
413

 
436

Due from affiliates
 

 
4

Income taxes receivable
 

 
23

Inventories
 
238

 
241

Prepaid expenses
 
19

 
15

Notes receivable
 
497

 

Derivatives
 
632

 
578

Other
 
23

 
37

Total current assets
 
2,403

 
2,359

Property, plant and equipment, at cost:
 
 
 
 
Oil and gas properties, using the successful efforts method of accounting:
 
 
 
 
Proved properties
 
16,799

 
15,662

Unproved properties
 
170

 
159

Accumulated depletion, depreciation and amortization
 
(6,407
)
 
(5,431
)
Total property, plant and equipment
 
10,562

 
10,390

Goodwill
 
272

 
272

Other property and equipment, net
 
1,480

 
1,391

Investment in unconsolidated affiliate
 

 
239

Derivatives
 
147

 
181

Other, net
 
101

 
94

 
 
$
14,965

 
$
14,926








The financial information included as of September 30, 2015 has been prepared by management
without audit by independent registered public accountants.
The accompanying notes are an integral part of these consolidated financial statements.


5



PIONEER NATURAL RESOURCES COMPANY
CONSOLIDATED BALANCE SHEETS (continued)
(in millions, except share data)
 
 
 
September 30,
2015
 
December 31,
2014
 
 
(Unaudited)
 
 
LIABILITIES AND EQUITY
Current liabilities:
 
 
 
 
Accounts payable:
 
 
 
 
Trade
 
$
791

 
$
1,197

Due to affiliates
 
58

 
123

Interest payable
 
36

 
40

Income taxes payable
 
27

 
1

Deferred income taxes
 
172

 
161

Derivatives
 
2

 
3

Other
 
61

 
55

Total current liabilities
 
1,147

 
1,580

Long-term debt
 
2,675

 
2,665

Derivatives
 
1

 
2

Deferred income taxes
 
1,925

 
1,803

Other liabilities
 
236

 
287

Equity:
 
 
 
 
Common stock, $.01 par value; 500,000,000 shares authorized; 152,774,139 and 152,158,428 shares issued as of September 30, 2015 and December 31, 2014, respectively
 
2

 
2

Additional paid-in capital
 
6,250

 
6,167

Treasury stock at cost: 3,396,200 and 3,253,781 shares as of September 30, 2015 and December 31, 2014, respectively
 
(199
)
 
(171
)
Retained earnings
 
2,921

 
2,583

Total equity attributable to common stockholders
 
8,974

 
8,581

Noncontrolling interests in consolidating subsidiaries
 
7

 
8

Total equity
 
8,981

 
8,589

Commitments and contingencies
 


 


 
 
$
14,965

 
$
14,926








The financial information included as of September 30, 2015 has been prepared by management
without audit by independent registered public accountants.
The accompanying notes are an integral part of these consolidated financial statements.

6


PIONEER NATURAL RESOURCES COMPANY
CONSOLIDATED STATEMENTS OF OPERATIONS
(in millions, except per share data)
(Unaudited) 
 
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
 
2015
 
2014
 
2015
 
2014
Revenues and other income:
 
 
 
 
 
 
 
 
Oil and gas
 
$
557

 
$
967

 
$
1,670

 
$
2,795

Sales of purchased oil and gas
 
326

 
202

 
665

 
554

Interest and other
 
(17
)
 
2

 

 
9

Derivative gains, net
 
573

 
341

 
617

 
19

Gain on disposition of assets, net
 
779

 
1

 
782

 
11

 
 
2,218

 
1,513

 
3,734

 
3,388

Costs and expenses:
 
 
 
 
 
 
 
 
Oil and gas production
 
189

 
168

 
532

 
493

Production and ad valorem taxes
 
36

 
58

 
112

 
169

Depletion, depreciation and amortization
 
364

 
274

 
1,003

 
734

Purchased oil and gas
 
339

 
194

 
684

 
535

Impairment of oil and gas properties
 
72

 

 
210

 

Exploration and abandonments
 
25

 
22

 
79

 
80

General and administrative
 
81

 
81

 
246

 
244

Accretion of discount on asset retirement obligations
 
3

 
3

 
9

 
9

Interest
 
46

 
46

 
138

 
138

Other
 
60

 
20

 
170

 
55

 
 
1,215

 
866

 
3,183

 
2,457

Income from continuing operations before income taxes
 
1,003

 
647

 
551

 
931

Income tax provision
 
(355
)
 
(236
)
 
(195
)
 
(319
)
Income from continuing operations
 
648

 
411

 
356

 
612

Loss from discontinued operations, net of tax
 
(2
)
 
(37
)
 
(6
)
 
(113
)
Net income attributable to common stockholders
 
$
646

 
$
374

 
$
350

 
$
499

 
 
 
 
 
 
 
 
 
Basic earnings per share attributable to common stockholders:
 
 
 
 
 
 
 
 
Income from continuing operations
 
$
4.29

 
$
2.84

 
$
2.36

 
$
4.24

Loss from discontinued operations
 
(0.01
)
 
(0.26
)
 
(0.04
)
 
(0.79
)
Net income
 
$
4.28

 
$
2.58

 
$
2.32

 
$
3.45

Diluted earnings per share attributable to common stockholders:
 
 
 
 
 
 
 
 
Income from continuing operations
 
$
4.28

 
$
2.84

 
$
2.36

 
$
4.23

Loss from discontinued operations
 
(0.01
)
 
(0.26
)
 
(0.04
)
 
(0.79
)
Net income
 
$
4.27

 
$
2.58

 
$
2.32

 
$
3.44

Weighted average shares outstanding:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Basic
 
149

 
143

 
149

 
143

Diluted
 
150

 
143

 
149

 
143

 
 
 
 
 
 
 
 
 
Dividends declared per share
 
$
0.04

 
$
0.04

 
$
0.08

 
$
0.08

 
 
 
 
 
 
 
 
 


The financial information included herein has been prepared by management
without audit by independent registered public accountants.
The accompanying notes are an integral part of these consolidated financial statements.

7


PIONEER NATURAL RESOURCES COMPANY
CONSOLIDATED STATEMENT OF EQUITY
(in millions, except share data and dividends per share)
(Unaudited)
 
 
 
 
 
Equity Attributable To Common Stockholders
 
 
 
 
 
 
Shares
Outstanding
 
Common
Stock
 
Additional
Paid-in
Capital
 
Treasury
Stock
 
Retained
Earnings
 
Noncontrolling
Interests
 
Total Equity
 
 
(in thousands)
 
 
 
 
 
 
 
 
 
 
 
 
Balance as of December 31, 2014
 
148,905

 
$
2

 
$
6,167

 
$
(171
)
 
$
2,583

 
$
8

 
$
8,589

Dividends declared ($0.08 per share)
 

 

 

 

 
(12
)
 

 
(12
)
Employee stock purchases
 
58

 

 
3

 
3

 

 

 
6

Purchases of treasury stock
 
(201
)
 

 

 
(31
)
 

 

 
(31
)
Tax benefits related to stock-based compensation
 

 

 
10

 

 

 

 
10

Compensation costs:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Vested compensation awards, net
 
616

 

 

 

 

 

 

Compensation costs included in net income
 

 

 
70

 

 

 

 
70

Cash distributions to noncontrolling interests
 

 

 

 

 

 
(1
)
 
(1
)
Net income
 

 

 

 

 
350

 

 
350

Balance as of September 30, 2015
 
149,378

 
$
2

 
$
6,250

 
$
(199
)
 
$
2,921

 
$
7

 
$
8,981








The financial information included herein has been prepared by management
without audit by independent registered public accountants.
The accompanying notes are an integral part of these consolidated financial statements.

8


PIONEER NATURAL RESOURCES COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOWS
(in millions)
(Unaudited)
 
 
Nine Months Ended
September 30,
 
 
2015
 
2014
Cash flows from operating activities:
 
 
 
 
Net income
 
$
350

 
$
499

Adjustments to reconcile net income to net cash provided by operating activities:
 
 
 
 
Depletion, depreciation and amortization
 
1,003

 
734

Impairment of oil and gas properties
 
210

 

Impairment of inventory and other property and equipment
 
21

 
7

Exploration expenses, including dry holes
 
22

 
11

Deferred income taxes
 
146

 
315

Gain on disposition of assets, net
 
(782
)
 
(11
)
Accretion of discount on asset retirement obligations
 
9

 
9

Discontinued operations
 
(4
)
 
247

Interest expense
 
14

 
13

Derivative related activity
 
(22
)
 
(39
)
Amortization of stock-based compensation
 
70

 
63

Other
 
13

 
42

Change in operating assets and liabilities:
 
 
 
 
Accounts receivable, net
 
26

 
(77
)
Income taxes receivable
 
23

 
(17
)
Inventories
 
(29
)
 
(27
)
Prepaid expenses
 
(3
)
 
(11
)
Other current assets
 
(6
)
 
(1
)
Accounts payable
 
(266
)
 
96

Interest payable
 
(4
)
 
(26
)
Income taxes payable
 
26

 
1

Other current liabilities
 
(28
)
 
(30
)
Net cash provided by operating activities
 
789

 
1,798

Cash flows from investing activities:
 
 
 
 
Proceeds from disposition of assets, net of cash sold
 
556

 
855

Additions to oil and gas properties
 
(1,573
)
 
(2,259
)
Additions to other assets and other property and equipment, net
 
(191
)
 
(224
)
Net cash used in investing activities
 
(1,208
)
 
(1,628
)
Cash flows from financing activities:
 
 
 
 
Borrowings under long-term debt
 

 
523

Principal payments on long-term debt
 

 
(523
)
Distributions to noncontrolling interests
 
(1
)
 
(1
)
Exercise of long-term incentive plan stock options and employee stock purchases
 
6

 
13

Purchases of treasury stock
 
(31
)
 
(33
)
Tax benefits related to stock-based compensation
 
10

 
14

Payments of financing fees
 
(3
)
 

Dividends paid
 
(6
)
 
(6
)
Net cash used in financing activities
 
(25
)
 
(13
)
Net increase (decrease) in cash and cash equivalents
 
(444
)
 
157

Cash and cash equivalents, beginning of period
 
1,025

 
393

Cash and cash equivalents, end of period
 
$
581

 
$
550

  


The financial information included herein has been prepared by management
without audit by independent registered public accountants.
  
The accompanying notes are an integral part of these consolidated financial statements.

9

PIONEER NATURAL RESOURCES COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
September 30, 2015
(Unaudited)


NOTE A. Organization and Nature of Operations
Pioneer Natural Resources Company ("Pioneer" or the "Company") is a Delaware corporation whose common stock is listed and traded on the New York Stock Exchange. The Company is a large independent oil and gas exploration and production company operating in the United States, with operations primarily in the Permian Basin in West Texas, the Eagle Ford Shale play in South Texas, the Raton field in southeastern Colorado and the West Panhandle field in the Texas Panhandle.
NOTE B. Basis of Presentation
Presentation. In the opinion of management, the consolidated financial statements of the Company as of September 30, 2015 and for the three and nine months ended September 30, 2015 and 2014 include all adjustments and accruals, consisting only of normal, recurring accrual adjustments, which are necessary for a fair presentation of the results for the interim periods. These interim results are not necessarily indicative of results for a full year.
Certain information and footnote disclosures normally included in financial statements prepared in accordance with generally accepted accounting principles in the United States ("GAAP") have been condensed in or omitted from this report pursuant to the rules and regulations of the United States Securities and Exchange Commission (the "SEC"). These consolidated financial statements should be read together with the consolidated financial statements and notes thereto included in the Company's Annual Report on Form 10-K for the year ended December 31, 2014.
Certain reclassifications have been made to the 2014 financial statement and footnote amounts in order to conform to the 2015 presentation.
Restructuring. On May 4, 2015, the Company announced plans to restructure its operations in Colorado, including closing its office in Denver, Colorado and eliminating its Trinidad-based pumping services operations. In connection therewith, during the three and nine months ended September 30, 2015, the Company recognized $9 million and $24 million, respectively, of restructuring charges in other expense in the accompanying consolidated statements of operations. The Company estimates that it will incur an additional $3 million of restructuring charges during the fourth quarter of 2015. The aggregate $27 million of estimated restructuring charges includes approximately $18 million in employee severance costs, $6 million in lease-related costs and $3 million in employee relocation and other costs.
Employee severance costs. The $18 million of employee severance costs is based on the number of employees impacted by the restructuring. Approximately $17 million is related to cash severance and $1 million is related to accelerated vesting of share-based grants, which are noncash charges.
Lease obligations and other. The $6 million of lease-related costs relates to certain Denver office space that will no longer be used as a part of the restructuring. Approximately $2 million represents the impairment of leasehold improvements and approximately $4 million represents the Company’s future obligations under the operating leases, net of anticipated sublease income.
As of September 30, 2015, the Company had $4 million of restructuring liabilities related to employee severance costs and future lease obligations recorded in other current and noncurrent liabilities in the accompanying consolidated balance sheets.
New accounting pronouncements. In July 2015, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2015-11, "Inventory (Topic 330): Simplifying the Measurement of Inventory." ASU 2015-11 requires an entity to measure inventory at the lower of cost or net realizable value rather than lower of cost or market as previously required by GAAP. ASU 2015-11 is effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. This update should be applied prospectively with early application permitted. The Company is currently evaluating the new guidance and has not determined the impact this standard may have on its financial statements.
In April 2015, the FASB issued ASU 2015-03, "Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs." ASU 2015-03 requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. Currently, debt issuance costs are recognized as deferred charges and recorded as assets. The guidance is effective for annual and interim periods beginning after December 15, 2015 with early adoption permitted and is to be implemented retrospectively. Adoption

10

PIONEER NATURAL RESOURCES COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
September 30, 2015
(Unaudited)

of the new guidance will only affect the presentation of the Company's consolidated balance sheets and will not have a material impact.
In May 2014, the FASB issued ASU 2014-09, "Revenue from Contracts with Customers (Topic 606)," which supersedes the revenue recognition requirements in Accounting Standards Codification ("ASC") Topic 605, "Revenue Recognition," and most industry-specific guidance. ASU 2014-09 is based on the principle that revenue is recognized to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU 2014-09 also requires additional disclosure about the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts. In August 2015, the FASB issued ASU 2015-14, which defers the effective date of ASU 2014-09 for one year to annual reports beginning after December 15, 2017. Early adoption is permitted as of the original effective date, December 15, 2016. Entities have the option of using either a full retrospective or modified approach to adopt the new standards. The Company is currently evaluating the new guidance and has not determined the impact this standard may have on its financial statements or decided upon the method of adoption.
NOTE C. Divestitures
Divestitures Recorded in Continuing Operations
For the three and nine months ended September 30, 2015, the Company recorded net gains on disposition of assets in continuing operations of $779 million and $782 million, respectively, as compared to $1 million and $11 million for the same respective periods in 2014. The net gains attributable to the disposition of assets included the following:

EFS Midstream. In November 2014, the Company announced that it was pursuing the divestment of its 50.1 percent equity interest in EFS Midstream LLC ("EFS Midstream"), which was accounted for under the equity method of accounting for investments in unconsolidated affiliates. In July 2015, the Company closed on the sale of its interest in EFS Midstream to an unaffiliated third party, with the Company receiving total consideration of $1.0 billion, of which $530 million was received at closing and the remaining approximately $500 million will be received in July 2016. The amount to be received in July 2016, less imputed interest, is included in notes receivable in the accompanying consolidated balance sheets and represents a noncash investing activity. Associated with the sale, the Company recorded a pretax gain of $778 million during the third quarter of 2015.

Vertical drilling rigs. In March 2014, the Company completed the sale of Sendero Drilling Company, LLC ("Sendero") to Sendero's minority interest owner for cash proceeds of $31 million, which resulted in a gain of $1 million. As part of the sales agreement, the Company committed to a lease agreement with Sendero for 12 vertical rigs through December 31, 2015, and eight vertical rigs in 2016. During the three and nine months ended September 30, 2015, the Company incurred $10 million and $30 million of idle drilling rig fees related to the leased Sendero rigs.

Permian Basin. During February 2014, the Company completed the sale of proved and unproved properties in Gaines and Dawson counties in the Spraberry field in West Texas for cash proceeds of $72 million, which resulted in a gain of $2 million.
Divestitures Recorded as Discontinued Operations
During 2014, the Company completed the sales of its (i) net assets in the Hugoton field in southwest Kansas for cash proceeds of $328 million, (ii) net assets in the Barnett Shale field in North Texas for cash proceeds of $150 million and (iii) capital stock in its Alaskan subsidiary ("Pioneer Alaska") for cash proceeds of $267 million. The Company has included its Hugoton, Barnett Shale and Pioneer Alaska results of operations in loss from discontinued operations, net of tax, in the accompanying consolidated statements of operations.

11

PIONEER NATURAL RESOURCES COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
September 30, 2015
(Unaudited)

The following table represents the components of the Company's discontinued operations for the three and nine months ended September 30, 2015 and 2014:
 
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
 
2015
 
2014
 
2015
 
2014
 
 
(in millions)
 
 
 
 
 
 
 
 
 
Revenues and other income (a)
 
$

 
$
50

 
$
1

 
$
234

Costs and expenses (b)
 
(2
)
 
(108
)
 
(10
)
 
(408
)
Loss from discontinued operations before income taxes
 
(2
)
 
(58
)
 
(9
)
 
(174
)
Current tax provision
 

 

 

 
(1
)
Deferred tax benefit
 

 
21

 
3

 
62

Loss from discontinued operations, net of tax
 
$
(2
)
 
$
(37
)
 
$
(6
)
 
$
(113
)
 ____________________
(a)
Primarily reflects oil and gas revenues and cash received associated with Alaskan Petroleum Production Tax credits on qualifying capital expenditures.
(b)
Costs and expenses during 2015 were primarily related to an arbitration award associated with plugging and abandonment obligations for two Gulf of Mexico wells from which Pioneer withdrew in 2009. Costs and expenses in 2014 were primarily comprised of oil and gas production costs and impairment charges. See Note D for information about impairment charges on the Barnett Shale assets and Pioneer Alaska.
NOTE D. Fair Value Measurements
Fair value is defined as the price that would be received to sell an asset or the price paid to transfer a liability in an orderly transaction between market participants at the measurement date. Fair value measurements are based upon inputs that market participants use in pricing an asset or liability, which are characterized according to a hierarchy that prioritizes those inputs based on the degree to which they are observable. Observable inputs represent market data obtained from independent sources, whereas unobservable inputs reflect a company's own market assumptions, which are used if observable inputs are not reasonably available without undue cost and effort. The three input levels of the fair value hierarchy are as follows:
Level 1 – quoted prices for identical assets or liabilities in active markets.
Level 2 – quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability (e.g., interest rates) and inputs derived principally from or corroborated by observable market data by correlation or other means.
Level 3 – unobservable inputs for the asset or liability.

12

PIONEER NATURAL RESOURCES COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
September 30, 2015
(Unaudited)

Assets and liabilities measured at fair value on a recurring basis. The fair value input hierarchy level to which an asset or liability measurement in its entirety falls is determined based on the lowest level input that is significant to the measurement in its entirety.
 
The following table presents the Company's assets and liabilities that are measured at fair value on a recurring basis as of September 30, 2015 for each of the fair value hierarchy levels: 
 
 
Fair Value Measurement at September 30, 2015 Using
 
 
 
 
Quoted Prices
in Active
Markets for
Identical
Assets
(Level 1)
 
Significant
Other
Observable
Inputs
(Level 2)
 
Significant
Unobservable
Inputs
(Level 3)
 
Fair Value at September 30, 2015
 
 
(in millions)
Assets:
 
 
 
 
 
 
 
 
Commodity derivatives
 
$

 
$
779

 
$

 
$
779

Deferred compensation plan assets
 
69

 

 

 
69

Total assets
 
69

 
779

 

 
848

Liabilities:
 
 
 
 
 
 
 
 
Commodity derivatives
 

 
1

 

 
1

Interest rate derivatives
 

 
2

 

 
2

Total liabilities
 

 
3

 

 
3

Total recurring fair value measurements
 
$
69

 
$
776

 
$

 
$
845

Commodity derivatives. The Company's commodity derivatives represent oil, natural gas liquids ("NGL") and gas swap contracts and collar contracts with short puts. The asset and liability measurements for the Company's commodity derivative contracts represent Level 2 inputs in the hierarchy. The Company utilizes discounted cash flow and option-pricing models for valuing its commodity derivatives.
The asset and liability values attributable to the Company's commodity derivatives were determined based on inputs that include (i) the contracted notional volumes, (ii) independent active market price quotes, (iii) the applicable estimated credit-adjusted risk-free rate yield curve and (iv) the implied rate of volatility inherent in the collar contracts with short puts, which is based on active and independent market-quoted volatility factors.
Deferred compensation plan assets. The Company's deferred compensation plan assets represent investments in equity and mutual fund securities that are actively traded on major exchanges. These investments are measured based on observable prices on major exchanges. As of September 30, 2015, the significant inputs to these asset values represented Level 1 independent active exchange market price inputs.
Interest rate derivatives. The Company's interest rate derivative liabilities represent Treasury rate swap contracts and interest rate swap contracts. The Company utilizes discounted cash flow models for valuing its interest rate derivatives. The net derivative values attributable to the Company's interest rate derivative contracts are based on (i) the contracted notional amounts, (ii) forward active market-quoted London Interbank Offered Rate ("LIBOR") or United States Treasury yield curves and (iii) the applicable credit-adjusted risk-free rate yield curve. The Company's interest rate derivative fair value measurements represent Level 2 inputs in the hierarchy.
Assets and liabilities measured at fair value on a nonrecurring basis. Certain assets and liabilities are measured at fair value on a nonrecurring basis. These assets and liabilities are not measured at fair value on an ongoing basis, but are subject to fair value adjustments in certain circumstances. These assets and liabilities can include inventory, proved and unproved oil and gas properties and other long-lived assets that are written down to fair value when they are impaired or held for sale. During the three and nine months ended September 30, 2015, the Company recorded charges in other expense in the Company's accompanying consolidated statements of operations of $12 million and $20 million, respectively, to reduce the carrying value of inventory to fair value.

13

PIONEER NATURAL RESOURCES COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
September 30, 2015
(Unaudited)

Proved oil and gas properties. During 2015, reductions in management's longer-term commodity price outlooks ("Management's Price Outlooks") provided indications of possible impairment of the Company's oil and gas properties in the West Panhandle field and in the South Texas - Other field (Edwards dry gas). As a result of management's assessments, during March 2015 and September 2015, the Company recognized pretax noncash impairment charges to reduce the carrying values of the West Panhandle field and the South Texas - Other field, respectively, to their estimated fair values.
The Company calculated the fair values of the West Panhandle field and the South Texas - Other field using a discounted future cash flow model. Significant Level 3 assumptions associated with the calculations included Management's Price Outlooks and management's outlooks for (i) production costs, (ii) capital expenditures, (iii) production and (iv) estimated proved reserves and risk-adjusted probable reserves. Management's Price Outlooks are developed based on third-party futures price outlooks as of the measurement date. The expected future net cash flows were discounted using an annual rate of 10 percent to determine estimated fair value.
The following table presents the fair value and fair value adjustments (in millions) for the Company's March 2015 and September 2015 proved property impairments, as well as the average oil price per barrel ("Bbl") and gas price per British thermal unit ("MMBtu") utilized in respective Management's Price Outlooks:
 
 
 
 
 
 
 
 
Management's Price Outlooks
 
 
 
 
Fair Value
 
Fair Value Adjustment
 
Oil
 
Gas
West Panhandle
 
March 2015
 
$
61

 
$
(138
)
 
$
65.02

 
$
3.83

South Texas - Other
 
September 2015
 
$
88

 
$
(72
)
 
$
57.41

 
$
3.46

Assets associated with divestitures. Long-lived assets that are classified as held for sale are recorded at the lower of the asset's net carrying amount or estimated fair value less costs to sell. The Hugoton field assets, the Barnett Shale field assets and Pioneer Alaska were classified as held for sale and carried as such until their divestitures in September 2014, September 2014 and April 2014, respectively. Associated therewith, the Company recognized impairment charges during 2014 to reduce the carrying values of the Hugoton field assets, the Barnett Shale field assets and Pioneer Alaska to their sales prices, less costs to sell.
The following table presents the fair value adjustments made by the Company during 2014 related to assets associated with divestitures:
 
 
 
Fair Value Adjustment
 
Sales Value Less Costs to Sell
 
Three Months Ended
September 30, 2014
 
Nine Months Ended
September 30, 2014
 
(in millions)
Hugoton field
$
328

 
$
(34
)
 
$
(34
)
Barnett Shale field
$
149

 
$
(46
)
 
$
(174
)
Pioneer Alaska
$
253

 
$

 
$
(97
)
See Note C for additional information regarding the Company's divestitures of the Hugoton field assets, the Barnett Shale field assets and Pioneer Alaska.
Financial instruments not carried at fair value. Carrying values and fair values of financial instruments that are not carried at fair value in the accompanying consolidated balance sheets as of September 30, 2015 and December 31, 2014 are as follows: 

 
 
September 30, 2015
 
December 31, 2014
 
 
Carrying
Value
 
Fair
Value
 
Carrying
Value
 
Fair
Value
 
 
(in millions)
Long-term debt
 
$
2,675

 
$
2,867

 
$
2,665

 
$
2,938


14

PIONEER NATURAL RESOURCES COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
September 30, 2015
(Unaudited)

Long-term debt includes the Company's credit facility and the Company's senior notes. The fair value of debt is determined utilizing inputs that are Level 2 measurements in the fair value hierarchy.
Credit facility. The fair value of the Company's credit facility is calculated using a discounted cash flow model based on (i) forecasted contractual interest and fee payments, (ii) forward active market-quoted United States Treasury Bill rates and (iii) the applicable credit-adjustments.
Senior notes. The Company's senior notes represent debt securities that are traded on major exchanges but are not actively traded. The fair values of the Company's senior notes are based on their periodic values as quoted on the major exchanges.
The Company has other financial instruments consisting primarily of cash equivalents, accounts receivables, prepaid expenses, notes receivable, payables and other current assets and liabilities that approximate fair value due to the nature of the instrument and their relatively short maturities. Non-financial assets and liabilities initially measured at fair value include assets acquired and liabilities assumed in a business combination, goodwill and asset retirement obligations.
NOTE E. Derivative Financial Instruments
The Company utilizes commodity swap contracts, collar contracts and collar contracts with short puts to (i) reduce the effect of price volatility on the commodities the Company produces and sells or consumes, (ii) support the Company's annual capital budgeting and expenditure plans and (iii) reduce commodity price risk associated with certain capital projects. The Company also, from time to time, utilizes interest rate contracts to reduce the effect of interest rate volatility on the Company's indebtedness.
Oil production derivative activities. All material physical sales contracts governing the Company's oil production are tied directly to, or are highly correlated with, New York Mercantile Exchange ("NYMEX") West Texas Intermediate ("WTI") oil prices. The Company uses derivative contracts to manage oil price volatility and basis swap contracts to reduce basis risk between NYMEX prices and the actual index prices at which the oil is sold.

15

PIONEER NATURAL RESOURCES COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
September 30, 2015
(Unaudited)

The following table sets forth the volumes per day associated with the Company's outstanding oil derivative contracts as of September 30, 2015 and the weighted average oil prices for those contracts: 
 
 
Three Months Ending December 31,
 
Year Ending December 31,
 
 
2015
 
2016
 
2017
Swap contracts:
 
 
 
 
 
 
Volume (Bbl)
 
82,000

 
4,475

 

Price per Bbl
 
$
71.18

 
$
59.00

 
$

Collar contracts with short puts (a):
 
 
 
 
 
 
Volume (Bbl)
 
15,000

 
101,806

 
34,000

Price per Bbl:
 
 
 
 
 
 
Ceiling
 
$
97.69

 
$
75.93

 
$
70.42

Floor
 
$
82.97

 
$
65.30

 
$
57.65

Short put
 
$
69.67

 
$
46.08

 
$
47.65

Rollfactor swap contracts (b):
 
 
 
 
 
 
Volume (Bbl)
 
37,000

 

 

NYMEX roll price
 
$
0.06

 
$

 
$

 ____________________
(a)
Counterparties have the option to extend for an additional year 5,000 Bbls per day of 2015 collar contracts with short puts with a ceiling price of $100.08 per Bbl, a floor price of $90.00 per Bbl and a short put price of $80.00 per Bbl. The option to extend is exercisable on December 31, 2015. These contracts give the counterparties the option to extend the contracts under the same terms for an additional year if the option to extend is exercised by the counterparties on December 31, 2015.
(b)
Represents swaps that fix the difference between (i) each day's price per Bbl of WTI for the first nearby month less (ii) the price per Bbl of WTI for the second nearby NYMEX month, multiplied by .6667; plus (iii) each day's price per Bbl of WTI for the first nearby month less (iv) the price per Bbl of WTI for the third nearby NYMEX month, multiplied by .3333.
NGL production derivative activities. All material physical sales contracts governing the Company's NGL production are tied directly or indirectly to either Mont Belvieu or Conway NGL component product prices.
The following table sets forth the volumes per day associated with the Company's outstanding NGL derivative contracts as of September 30, 2015 and the weighted average NGL prices for those contracts: 
 
 
Three Months Ending December 31,
 
Year Ending December 31,
 
 
2015
 
2016
Ethane swap contracts:
 
 
 
 
Volume (Bbl)
 
6,000

 
5,000

Price per Bbl
 
$
7.80

 
$
11.61

Propane swap contracts:
 
 
 
 
Volume (Bbl)
 
11,000

 
7,500

Price per Bbl
 
$
21.62

 
$
21.57

Gas production derivative activities. All material physical sales contracts governing the Company's gas production are tied directly or indirectly to NYMEX Henry Hub ("HH") gas prices or regional index prices where the gas is sold. The Company uses derivative contracts to manage gas price volatility and basis swap contracts to reduce basis risk between HH prices and the actual index prices at which the gas is sold.

16

PIONEER NATURAL RESOURCES COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
September 30, 2015
(Unaudited)

The following table sets forth the volumes per day associated with the Company's outstanding gas derivative contracts as of September 30, 2015 and the weighted average gas prices for those contracts: 
 
 
Three Months Ending December 31,
 
Year Ending December 31,
 
 
2015
 
2016
 
2017
Swap contracts:
 
 
 
 
 
 
Volume (MMBtu)
 
20,000

 
70,000

 

Price per MMBtu
 
$
4.31

 
$
4.06

 
$

Collar contracts with short puts:
 
 
 
 
 
 
Volume (MMBtu)
 
285,000

 
180,000

 

Price per MMBtu:
 
 
 
 
 
 
Ceiling
 
$
5.07

 
$
4.01

 
$

Floor
 
$
4.00

 
$
3.24

 
$

Short put
 
$
3.00

 
$
2.78

 
$

Basis swap contracts:
 
 
 
 
 
 
Gulf Coast index swap volume (a)
 
20,000

 
10,000

 

Price differential ($/MMBtu)
 
$

 
$

 
$

Mid-Continent index swap volume (a)
 
95,000

 
15,000

 
45,000

Price differential ($/MMBtu)
 
$
(0.24
)
 
$
(0.32
)
 
$
(0.32
)
Permian Basin index swap volume (a)
 
10,000

 

 

Price differential ($/MMBtu)
 
$
(0.13
)
 
$

 
$

Permian Basin index swap volume (b)
 
30,000

 

 

Price differential ($/MMBtu)
 
$
0.19

 
$

 
$

____________________
(a)
Represent swaps that fix the basis differentials between the index prices at which the Company sells its Gulf Coast, Mid-Continent and Permian Basin gas, respectively, and the HH index price used in gas swap and collar contracts.
(b)
Represent swaps that fix the basis differentials between Permian Basin index prices and southern California index prices for Permian Basin gas forecasted for sale in southern California.
Marketing and basis differential derivative activities. Periodically, the Company enters into buy and sell marketing arrangements to fulfill firm pipeline transportation commitments. Associated with these marketing arrangements, the Company may enter into index swaps to mitigate price risk. As of September 30, 2015, the Company had marketing oil index swap contracts for 10,000 Bbl per day for the remainder of 2015 with a price differential of $2.99 per Bbl between WTI and Louisiana Light Sweet oil.
Interest rate derivative activities. As of September 30, 2015, the Company was party to interest rate derivative contracts whereby the Company will receive (i) the 10-year Treasury rate in exchange for paying average fixed rates of 2.15 percent on a notional amount of $100 million on December 15, 2015 and 2.24 percent on a notional amount of $100 million on March 15, 2016 and (ii) the three-month LIBOR rate for the 10-year period from March 2016 through March 2026 in exchange for paying a fixed interest rate of 2.18 percent on a notional amount of $50 million on March 15, 2016. Subsequent to September 30, 2015, the Company entered into additional interest rate derivative contracts whereby the Company will receive the three-month LIBOR rate for the 10-year period from March 2016 through March 2026 in exchange for paying a fixed interest rate of 2.12 percent on a notional amount of $50 million on March 15, 2016.
Tabular disclosure of derivative financial instruments. All of the Company's derivatives are accounted for as non-hedge derivatives and therefore all changes in the fair values of its derivative contracts are recognized as gains or losses in the earnings of the periods in which they occur. The Company classifies the fair value amounts of derivative assets and liabilities as net current or noncurrent derivative assets or net current or noncurrent derivative liabilities, whichever the case may be, by commodity and counterparty. The Company enters into derivatives under master netting arrangements, which, in an event of default, allows the Company to offset payables to and receivables from the defaulting counterparty.

17

PIONEER NATURAL RESOURCES COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
September 30, 2015
(Unaudited)

The aggregate fair value of the Company's derivative instruments reported in the accompanying consolidated balance sheets by type and counterparty, including the classification between current and noncurrent assets and liabilities, consists of the following:
 
Fair Value of Derivative Instruments as of September 30, 2015
Type
 
Consolidated Balance Sheet
Location
 
Fair
Value
 
Gross Amounts Offset in the Consolidated Balance Sheet
 
Net Fair Value Presented in the Consolidated Balance Sheet
 
 
 
 
(in millions)
Derivatives not designated as hedging instruments
 
 
 
 
 
 
Asset Derivatives:
 
 
 
 
 
 
Commodity price derivatives
 
Derivatives - current
 
$
634

 
$
(2
)
 
$
632

Commodity price derivatives
 
Derivatives - noncurrent
 
$
148

 
$
(1
)
 
147

 
 
 
 
 
 
 
 
$
779

Liability Derivatives:
 

 
 
 
 
Commodity price derivatives
 
Derivatives - current
 
$
2

 
$
(2
)
 
$

Interest rate derivatives
 
Derivatives - current
 
$
2

 
$

 
2

Commodity price derivatives
 
Derivatives - noncurrent
 
$
2

 
$
(1
)
 
1

 
 
 
 
 
 
 
 
$
3


Fair Value of Derivative Instruments as of December 31, 2014
Type
 
Consolidated Balance Sheet
Location
 
Fair
Value
 
Gross Amounts Offset in the Consolidated Balance Sheet
 
Net Fair Value Presented in the Consolidated Balance Sheet
 
 
 
 
(in millions)
Derivatives not designated as hedging instruments
 
 
 
 
 
 
Asset Derivatives:
 
 
 
 
 
 
Commodity price derivatives
 
Derivatives - current
 
$
579

 
$
(1
)
 
$
578

Commodity price derivatives
 
Derivatives - noncurrent
 
$
182

 
$
(1
)
 
181

 
 
 
 
 
 
 
 
$
759

Liability Derivatives:
 
 
 
 
 
 
Commodity price derivatives
 
Derivatives - current
 
$
1

 
$
(1
)
 
$

Interest rate derivatives
 
Derivatives - current
 
$
3

 
$

 
3

Commodity price derivatives
 
Derivatives - noncurrent
 
$
3

 
$
(1
)
 
2

 
 
 
 
 
 
 
 
$
5


The Company uses credit and other financial criteria to evaluate the credit standing of, and to select, counterparties to its derivative instruments. Although the Company does not obtain collateral or otherwise secure the fair value of its derivative instruments, associated credit risk is mitigated by the Company's credit risk policies and procedures.


18

PIONEER NATURAL RESOURCES COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
September 30, 2015
(Unaudited)

The following table details the location of gains and losses recognized on the Company's derivative contracts in the accompanying consolidated statements of operations:
 
 
 
 
 
 
 
 
 
Derivatives Not Designated as Hedging
 
Location of Gain / (Loss) Recognized in
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
Instruments
 
Earnings on Derivatives
 
2015
 
2014
 
2015
 
2014
 
 
 
 
(in millions)
Commodity price derivatives
 
Derivative gains, net
 
$
575

 
$
341

 
$
614

 
$
1

Interest rate derivatives
 
Derivative gains, net
 
(2
)
 

 
3

 
18

Total
 
$
573

 
$
341

 
$
617

 
$
19

NOTE F. Exploratory Costs
The Company capitalizes exploratory well and project costs until a determination is made that the well or project has either found proved reserves, is impaired or is sold. The Company's capitalized exploratory well and project costs are presented in proved properties in the accompanying consolidated balance sheets. If the exploratory well or project is determined to be impaired, the impaired costs are charged to exploration and abandonments expense.
The following table reflects the Company's capitalized exploratory well and project activity during the three and nine months ended September 30, 2015:
 
Three Months Ended September 30, 2015
 
Nine Months Ended September 30, 2015
 
(in millions)
Beginning capitalized exploratory costs
$
270

 
$
305

Additions to exploratory costs pending the determination of proved reserves
321

 
782

Reclassification due to determination of proved reserves
(319
)
 
(800
)
Exploratory well costs charged to exploration expense

 
(15
)
Ending capitalized exploratory costs
$
272

 
$
272

As of September 30, 2015 and December 31, 2014, the Company had no exploratory projects for which exploratory costs have been capitalized for a period greater than one year from the date drilling was completed.
NOTE G. Long-term Debt
Credit facility. The Company's long-term debt consists of senior notes, a revolving corporate credit facility and the effects of net deferred fair value hedge losses and issuance discounts. During August 2015, the Company entered into the Second Amendment to its Second Amended and Restated 5-Year Revolving Credit Agreement ("Credit Facility") with a syndicate of financial institutions to primarily extend the maturity of the credit facility from December 2017 to August 2020 while maintaining aggregate loan commitments of $1.5 billion. The Company accounted for the entry into the Credit Facility as a modification of the prior agreement and capitalized the debt issuance costs along with those unamortized issuance costs that remained from the issuance of the prior agreement. As of September 30, 2015, the Company had no outstanding borrowings under the Credit Facility and was in compliance with its debt covenants.
Senior notes. The Company's 5.875% senior notes (the "5.875% Senior Notes"), with outstanding debt principal balances of $455 million, are due to mature in July 2016. As the Company has the ability to fund any required cash payments upon the maturity of the 5.875% Senior Notes with its borrowing capacity under the Credit Facility, to the extent that they are not refinanced prior to their maturity, such notes are classified as long-term debt in the accompanying consolidated balance sheets.
NOTE H. Incentive Plans
Stock-based compensation
For the three and nine months ended September 30, 2015, the Company recorded $26 million and $87 million, respectively, of stock-based compensation expense for all plans, as compared to $27 million and $89 million for the same respective periods

19

PIONEER NATURAL RESOURCES COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
September 30, 2015
(Unaudited)

of 2014. As of September 30, 2015, there was $131 million of unrecognized compensation expense related to unvested share-based compensation plan awards, including $21 million attributable to stock-based awards that are expected to be settled on their vesting date in cash, rather than in equity shares ("Liability Awards"). The unrecognized compensation expense will be recognized over the remaining vesting periods of the awards, which is a period of less than three years on a weighted average basis. As of September 30, 2015 and December 31, 2014, accounts payable – due to affiliates includes $11 million and $23 million, respectively, of liabilities attributable to Liability Awards.
The following table summarizes the activity that occurred during the nine months ended September 30, 2015, for each type of share-based incentive award issued by Pioneer: 
 
 
Restricted
Stock Equity
Awards
 
Restricted
Stock Liability
Awards
 
Performance
Units
 
Stock
Options
Outstanding as of December 31, 2014
 
1,233,539

 
328,087

 
154,733

 
199,058

Awards granted
 
439,742

 
158,726

 
82,431

 

Awards vested
 
(525,494
)
 
(185,302
)
 

 

Awards forfeited
 
(36,679
)
 
(28,851
)
 

 

Outstanding as of September 30, 2015
 
1,111,108

 
272,660

 
237,164

 
199,058

NOTE I. Asset Retirement Obligations
The Company's asset retirement obligations primarily relate to the future plugging and abandonment of wells and facilities. The following table summarizes the Company's asset retirement obligation activity during the three and nine months ended September 30, 2015 and 2014: 
 
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
 
2015
 
2014
 
2015
 
2014
 
 
(in millions)
Beginning asset retirement obligations
 
$
187

 
$
193

 
$
189

 
$
194

New wells placed on production
 
1

 
1

 
2

 
3

Changes in estimates
 

 
2

 

 
3

Dispositions
 

 
(5
)
 

 
(7
)
Liabilities settled
 
(9
)
 
(6
)
 
(18
)
 
(14
)
Accretion of discount
 
3

 
3

 
9

 
9

Ending asset retirement obligations
 
$
182

 
$
188

 
$
182

 
$
188

The Company records the current and noncurrent portions of asset retirement obligations in other current liabilities and other liabilities, respectively, in the accompanying consolidated balance sheets. As of September 30, 2015, the current portion of the Company's asset retirement obligations was $31 million, as compared to $28 million at December 31, 2014.
NOTE J. Commitments and Contingencies
The Company is a party to proceedings and claims incidental to its business. While many of these matters involve inherent uncertainty, the Company believes that the amount of the liability, if any, ultimately incurred with respect to such proceedings and claims will not have a material adverse effect on the Company's consolidated financial position as a whole or on its liquidity, capital resources or future annual results of operations. The Company records reserves for contingencies when information available indicates that a loss is probable and the amount of the loss can be reasonably estimated.
Obligations following divestitures. In connection with its divestiture transactions, the Company may retain certain liabilities and provide the purchaser certain indemnifications, subject to defined limitations, which may apply to identified pre-closing matters, including matters of litigation, environmental contingencies, royalty obligations and income taxes. The Company does

20

PIONEER NATURAL RESOURCES COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
September 30, 2015
(Unaudited)



not believe these obligations are probable of having a material impact on its liquidity, financial position or future results of operations.
NOTE K. Interest and Other Income
The following table provides the components of the Company's interest and other income for the three and nine months ended September 30, 2015 and 2014:
 
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
 
2015
 
2014
 
2015
 
2014
 
 
(in millions)
Equity interest in income of EFS Midstream (a)
 
$

 
$
3

 
$
5

 
$
10

Deferred compensation plan income
 

 

 
4

 
3

Interest income
 
2

 

 
2

 

Loss from vertical integration services (b)
 
(20
)
 
(2
)
 
(16
)
 
(9
)
Other income
 
1

 
1

 
5

 
5

Total interest and other income
 
$
(17
)
 
$
2

 
$

 
$
9

 ____________________
(a)
The Company accounted for its investment in EFS Midstream LLC ("EFS Midstream") prior to its sale in July 2015 using the equity method. EFS Midstream provided gathering, treating and transportation services for the Company. See Note C for additional information on the Company's sale of EFS Midstream.
(b)
Loss from vertical integration services primarily represents net margins that result from Company-provided fracture stimulation and service operations, which are ancillary to and supportive of the Company's oil and gas joint operating activities, and do not represent intercompany transactions. For the three and nine months ended September 30, 2015, these vertical integration net margins included $66 million and $264 million, respectively, of revenues and $86 million and $280 million, respectively, of costs and expenses. For the same periods in 2014, these vertical integration net margins included $125 million and $321 million, respectively, of revenues and $127 million and $330 million, respectively, of costs and expenses.
 NOTE L. Other Expense
The following table provides the components of the Company's other expense for the three and nine months ended September 30, 2015 and 2014:
 
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
 
2015
 
2014
 
2015
 
2014
 
 
(in millions)
Idle drilling and well service equipment charges (a)
 
$
22

 
$
2

 
$
73

 
$
2

Transportation commitment charge (b)
 
11

 
11

 
38

 
34

Restructuring charges (c)
 
9

 

 
24

 

Impairment of inventory and other property and equipment (d)
 
13

 
3

 
21

 
7

Other
 
5

 
4

 
14

 
12

Total other expense
 
$
60

 
$
20

 
$
170

 
$
55

 ____________________
(a)
Primarily represents expenses attributable to idle drilling rig fees, which are not chargeable to joint operations.
(b)
Primarily represents firm transportation payments on excess pipeline capacity commitments.
(c)
Represents one-time restructuring costs associated with the Company's restructuring of its operations in Colorado, including closing its office in Denver, Colorado and eliminating its Trinidad-based pumping services operations. See Note B for additional information on the restructuring charges.
(d)
Primarily represents charges to reduce excess material and supplies inventories to their market values. See Note D for additional information on the fair value of materials and supplies inventory.

21

PIONEER NATURAL RESOURCES COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
September 30, 2015
(Unaudited)

NOTE M. Income Taxes
The Company's income tax benefit (provision) attributable to income from continuing operations consisted of the following for the three and nine months ended September 30, 2015 and 2014:
 
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
 
2015
 
2014
 
2015
 
2014
 
 
(in millions)
Current tax benefit (provision)
 
$
(48
)
 
$
14

 
$
(49
)
 
$
(4
)
Deferred tax provision
 
(307
)
 
(250
)
 
(146
)
 
(315
)
Income tax provision
 
$
(355
)
 
$
(236
)
 
$
(195
)
 
$
(319
)
For both the three and nine months ended September 30, 2015, the Company's effective tax rate, excluding income attributable to noncontrolling interests, was 35 percent, as compared to effective rates of 36 percent and 34 percent for the same respective periods in 2014. During 2014, the Company's effective tax rates differed from the U.S. statutory rate of 35 percent primarily due to state income tax apportionments, nondeductible expenses and, for the nine months ended September 30, 2014, the recognition of a $21 million tax benefit resulting from the resolution during the first quarter of 2014 of a tax uncertainty related to net operating loss carryovers and alternative minimum tax credits obtained from the 2012 sand mine acquisition. The Company has no unrecognized tax benefits as of September 30, 2015.
The Company files income tax returns in the U.S. federal and various state and foreign jurisdictions. The Internal Revenue Service has closed examinations of the 2013 and prior tax years and, with few exceptions, the Company believes that it is no longer subject to examinations by state and foreign tax authorities for years before 2009. As of September 30, 2015, no adjustments had been proposed in any jurisdiction that would have a significant effect on the Company's liquidity, future results of operations or financial position.
NOTE N. Net Income Per Share
The following table reconciles the Company's income from continuing operations to basic and diluted net income attributable to common stockholders for the three and nine months ended September 30, 2015 and 2014:
 
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
 
2015
 
2014
 
2015
 
2014
 
 
(in millions)
Income from continuing operations
 
$
648

 
$
411

 
$
356

 
$
612

Participating basic earnings
 
(6
)
 
(4
)
 
(3
)
 
(5
)
Basic and diluted income from continuing operations
 
$
642

 
$
407

 
353

 
607

Basic and diluted loss from discontinued operations
 
$
(2
)
 
$
(37
)
 
$
(6
)
 
$
(113
)
Basic and diluted net income attributable to common stockholders
 
$
640

 
$
370

 
$
347

 
$
494

Basic weighted average common shares outstanding were 149 million for both the three and nine months ended September 30, 2015 and diluted weighted average common shares outstanding were 150 million and 149 million for the three and nine months ended September 30, 2015, respectively. Basic and diluted weighted average common shares outstanding were 143 million for the three and nine months ended September 30, 2014.



22

PIONEER NATURAL RESOURCES COMPANY

Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations
Financial and Operating Performance
The Company's financial and operating performance for the third quarter of 2015 included the following highlights:
Net income attributable to common stockholders for the third quarter of 2015 was $646 million ($4.27 per diluted share), as compared to net income of $374 million ($2.58 per diluted share) for the third quarter of 2014. The increase in net income attributable to common stockholders is comprised of a $237 million increase in income from continuing operations attributable to common stockholders and a $35 million decrease in loss from discontinued operations, net of tax.
The primary components of the increase in income from continuing operations include:
the recognition of a $778 million gain on disposition of assets as a result of the sale of EFS Midstream in July 2015; and
a $232 million increase in net derivative gains, primarily as a result of declines in forward commodity prices and the Company's portfolio of derivatives; partially offset by
a $410 million decrease in oil and gas revenues as a result of a 49 percent decrease in the average commodity prices per BOE, partially offset by a 13 percent increase in sales volumes;
a $90 million increase in DD&A expense, primarily attributable to the 13 percent increase in sales volumes and reductions in proved reserves as a result of the decline in commodity prices;
a $72 million noncash impairment charge related to the Company's South Texas - Other field in the third quarter of 2015;
a $40 million increase in other expense, primarily related to idle drilling rig charges, inventory valuation allowances and restructuring charges associated with the closing of the Company's Denver, Colorado office;
a $21 million decrease in net margins attributable to purchases and sales of oil and gas used to fulfill transportation commitments;
a $19 million decrease in interest and other income, primarily attributable to decreased fracture stimulation service margins, reflecting a reduction in market rates for such services as a result of lower commodity prices; and
a $119 million increase in the Company's income tax provision as a result of the Company's increase in income from continuing operations before taxes.
The loss from discontinued operations, net of tax, during the three months ended September 30, 2014 was attributable to the results of operations (prior to their sale) associated with the Company's sales of its Hugoton field assets and Barnett Shale field assets in September 2014.
During the third quarter of 2015, average daily sales volumes from continuing operations increased by 13 percent to 210,711 BOEPD, as compared to 186,077 BOEPD during the third quarter of 2014. The increase in third quarter 2015 average daily sales volumes, as compared to the third quarter of 2014, is primarily due to the Company's successful Spraberry/Wolfcamp horizontal drilling program.
Average oil, NGL and gas prices decreased during the third quarter of 2015 to $42.46 per Bbl, $12.39 per Bbl and $2.53 per Mcf, respectively, as compared to $90.82 per Bbl, $28.44 per Bbl and $3.79 per Mcf, respectively, in the third quarter of 2014.
Net cash provided by operating activities decreased to $358 million for the three months ended September 30, 2015, as compared to $616 million for the three months ended September 30, 2014. The $258 million decrease in net cash provided by operating activities is primarily due to the decrease in oil, NGL and gas prices, partially offset by an increase in net cash flows from derivative settlements and an increase in oil and gas sales volumes.
As of September 30, 2015, the Company's net debt to book capitalization increased to 19 percent, as compared to 16 percent at December 31, 2014, due to the use of cash and cash equivalents to fund the Company's drilling program.
Recent Developments
Commodity prices. North American and worldwide oil, NGL and gas prices remain under pressure given the current oversupply of such commodities. In general, this imbalance between supply and demand reflects the significant supply growth achieved in the United States as a result of shale drilling and the OPEC oil production increases as part of an effort to retain market share combined with only modest demand growth in the United States and decreasing demand in other parts of the world, particularly

23

PIONEER NATURAL RESOURCES COMPANY

in Europe and China. Although there has been a dramatic decrease in drilling activity in the industry, oil and NGL storage levels in the United States remain at historically high levels. Until supply and demand balance and the overhang in storage levels begins to decline, prices are expected to remain under pressure. In addition, the expected lifting of economic sanctions on Iran has caused the market to anticipate increased supplies of oil from Iran in early 2016, further weakening the outlook for oil prices. The reduced demand for drilling rigs, fracture-stimulation services and oilfield supplies, for which prices had reached very high levels during a period of high utilization in 2014, has led to a decline of these costs. However, their declines have significantly lagged behind the declines in oil, NGL and gas prices. As a result of these circumstances, the Company experienced significant operating margin deterioration during the first nine months of 2015. The duration and magnitude of the commodity price declines and the timing and amount of cost reductions cannot be accurately predicted.
 Low price environment initiatives. In the midst of the lower commodity price environment, the Company has implemented initiatives to improve drilling and completion efficiencies and reduce capital spending, operating costs and general and administrative expenses to minimize spending in excess of estimated cash flows for 2015 and to maintain significant financial flexibility. As a result of these initiatives, the Company has realized significant service cost reductions and efficiency gains that have resulted in (i) an estimated 25 percent decrease in drilling and completion costs compared to 2014 and (ii) an 18 percent reduction in third quarter lease operating expenses per BOE compared to 2014. Drilling and completion costs are expected to be reduced by more than 30 percent by early 2016 compared to 2014 levels as additional cost reductions and efficiency gains are achieved.
Drilling Rig Additions. With the completion of the EFS Midstream sale, along with the benefits of the Company's cost savings and efficiency initiatives, the Company began adding horizontal rigs in the northern Spraberry/Wolfcamp area in July 2015. To-date, the Company has added eight horizontal rigs since July 1, 2015. The Company does not expect to add any additional drilling rigs during the remainder of 2015 based on the Company's outlook for commodity prices and continuing efficiency improvements, which are significantly reducing the number of days required to place wells on production. This additional drilling activity, combined with the efficiency improvements, is expected to increase the Company’s 2015 capital budget by approximately $350 million to a total of $2.2 billion. Due to the timing associated with multi-well pad drilling, the addition of the rigs is expected to have minimal impact on 2015 production.

 Fourth Quarter 2015 Outlook
Based on current estimates, the Company expects the following operating and financial results from continuing operations for the quarter ending December 31, 2015:
Production is forecasted to average 206,000 to 211,000 BOEPD.
Production costs (including production and ad valorem taxes and transportation costs) are expected to average $11.00 to $13.00 per BOE based on current NYMEX strip commodity prices. DD&A expense is expected to average $18.50 to $20.50 per BOE, reflecting an anticipated further decline in proved reserves as a result of lower commodity prices reducing the economic lives of the Company's producing wells.
Total exploration and abandonment expense is expected to be $25 million to $35 million. General and administrative expense is expected to be $80 million to $85 million. Interest expense is expected to be $45 million to $50 million, and other expense is expected to be $40 million to $50 million, excluding anticipated nonrecurring restructuring charges during the quarter of approximately $3 million. Accretion of discount on asset retirement obligations is expected to be $3 million to $5 million.
The Company's effective income tax rate is expected to range from 35 percent to 40 percent assuming current capital spending plans and no significant mark-to-market changes in the Company's derivative position. Current income taxes are expected to range from $10 million to $20 million and are primarily attributable to (i) estimated federal alternative minimum taxes associated with the sale of the Company's interest in EFS Midstream during July 2015 and (ii) state taxes.

24

PIONEER NATURAL RESOURCES COMPANY

Operations and Drilling Highlights
The following table summarizes the Company's average daily oil, NGL, gas and total production by asset area during the nine months ended September 30, 2015:
 
 
Oil (Bbls)
 
NGLs (Bbls)
 
Gas (Mcf)
 
Total (BOE)
Permian Basin
 
79,988

 
22,836

 
111,847

 
121,464

South Texas - Eagle Ford Shale
 
18,063

 
11,531

 
94,422

 
45,331

Raton Basin
 

 

 
113,325

 
18,887

West Panhandle
 
2,924

 
3,360

 
14,304

 
8,669

South Texas - Other
 
1,803

 
175

 
24,666

 
6,089

Other
 
2

 
1

 
30

 
8

   Total
 
102,780

 
37,903

 
358,594

 
200,448

The Company's total liquids production from continuing operations increased to 70 percent of total production, on a BOE basis, for the nine months ended September 30, 2015, as compared to 68 percent for the same period last year.
 The following table summarizes by geographic area the Company's finding and development costs incurred during the nine months ended September 30, 2015: 
 
 
Acquisition Costs
 
Exploration
 
Development
 
 
 
 
Proved
 
Unproved
 
Costs
 
Costs
 
Total
 
 
(in millions)
Permian Basin
 
$
9

 
$
24

 
$
627

 
$
468

 
$
1,128

South Texas - Eagle Ford Shale
 

 

 
191

 
133

 
324

Raton Basin
 

 

 
2

 
2

 
4

West Panhandle
 

 

 
1

 
8

 
9

South Texas - Other
 

 

 
1

 

 
1

Other
 

 

 
10

 

 
10

   Total
 
9

 
$
24

 
$
832

 
$
611

 
$
1,476

The following table summarizes the Company's development and exploration/extension drilling activities for the nine months ended September 30, 2015: 
 
 
Development Drilling
 
 
Beginning Wells
in Progress
 
Wells
Spud
 
Successful
Wells
 
Ending Wells
in Progress
Permian Basin
 
41

 
48

 
72

 
17

South Texas - Eagle Ford Shale
 
13

 
25

 
29

 
9

   Total
 
54

 
73

 
101

 
26

 
 
 
Exploration/Extension Drilling
 
 
Beginning Wells
in Progress
 
Wells
Spud
 
Successful
Wells
 
Unsuccessful
Wells
 
Ending Wells
in Progress