Delaware
|
1-12534
|
72-1133047
|
(State
or other jurisdiction
|
(Commission
File Number)
|
(I.R.S.
Employer
|
of
incorporation)
|
Identification
No.)
|
o
|
Written
communications pursuant to Rule 425 under the Securities Act (17 CFR
230.425)
|
o
|
Soliciting
material pursuant to Rule 14a-12 under the Exchange Act (17 CFR
240.14a-12)
|
o
|
Pre-commencement
communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR
240.14d-2(b))
|
o
|
Pre-commencement
communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR
240.13e-4(c))
|
Executive
Officer
|
Title
|
Number
of Shares of
Time-Vested
Restricted Stock
|
||||
Lee
K. Boothby
|
President
|
33,600
|
||||
Terry
W. Rathert
|
Senior
Vice President and Chief Financial Officer
|
33,600
|
||||
Mona
Leigh Bernhardt
|
Vice
President—Human Resources
|
14,400
|
||||
W.
Mark Blumenshine
|
Vice
President—Land
|
15,360
|
||||
Stephen
C. Campbell
|
Vice
President—Investor Relations
|
14,400
|
||||
George
T. Dunn
|
Vice
President—Mid-Continent
|
24,000
|
||||
John
H. Jasek
|
Vice
President—Gulf of Mexico
|
19,200
|
||||
James
J. Metcalf
|
Vice
President—Drilling
|
15,360
|
||||
Gary
D. Packer
|
Vice
President—Rocky Mountains
|
33,600
|
||||
William
D. Schneider
|
Vice
President—Onshore Gulf Coast & International
|
19,200
|
||||
Mark
J. Spicer
|
Vice
President—Information Technology
|
14,400
|
||||
James
T. Zernell
|
Vice
President—Production
|
19,200
|
||||
John
D. Marziotti
|
General
Counsel and Secretary
|
15,360
|
||||
Brian
L. Rickmers
|
Controller
& Assistant Secretary
|
14,400
|
||||
Susan
G. Riggs
|
Treasurer
|
11,520
|
·
|
Normally,
for an annual meeting Newfield must receive the notice not less than 75
days or more than 120 days before the first anniversary of the prior
year’s meeting.
|
·
|
However,
if the annual meeting is held on a date that is more than 15 days before
or 30 days after such anniversary date, Newfield must receive the notice
by the later of (1) 75 days before the annual meeting and (2) 10 days
after the day on which public announcement of the date of the meeting is
first made.
|
·
|
If
Newfield holds a special meeting, Newfield must receive the notice by the
later of (1) 75 days before the special meeting and (2) 10 days after the
day on which public announcement of the date of the meeting is first
made.
|
·
|
Normally,
for an annual meeting, the notice was required to be received by Newfield
not less than 45 days or more than 120 days in advance of the
date on which Newfield filed its definitive proxy materials for the prior
year’s annual meeting.
|
·
|
However,
if the annual meeting was held on a date more than 30 days before or
30 days after the anniversary of the previous year’s annual meeting, the
notice was required to be received by Newfield no later than the later of
(1) 60 days before the annual meeting or (2) 10 days following
the day on which public announcement of the date of the meeting was first
made.
|
(d)
|
Exhibits
|
|
3.2
|
Amended
and Restated Bylaws, effective as of February 5, 2009
|
|
10.15
|
Form
of Restricted Stock Agreement
|
|
10.20
|
Form
of Indemnification Agreement
|
|
99.1
|
Earnings
Press Release issued by Newfield on February 5, 2009
|
|
99.2
|
Succession
Press Release issued by Newfield on February 5, 2009
|
|
99.3
|
@
NFX Publication issued by Newfield on February 5,
2009
|
NEWFIELD
EXPLORATION COMPANY
|
||
Date:
February 6, 2009
|
By:
|
/s/
Brian L. Rickmers
|
Brian
L. Rickmers
|
||
Controller
|
Exhibit
No.
|
Description
|
|
3.2
|
Amended
and Restated Bylaws, effective as of February 5, 2009
|
|
10.15
|
Form
of Restricted Stock Agreement
|
|
10.20
|
Form
of Indemnification Agreement
|
|
99.1
|
Earnings
Press Release issued by Newfield on February 5, 2009
|
|
99.2
|
Succession
Press Release issued by Newfield on February 5, 2009
|
|
99.3
|
@
NFX Publication issued by Newfield on February 5,
2009
|
1
|
||
Section
1.01
|
Registered
Office . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . .
|
1
|
Section
1.02
|
Other
Offices. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . .
|
1
|
ARTICLE
II STOCKHOLDERS
|
1
|
|
Section
2.01
|
Place
of Meetings. . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . .
|
1
|
Section
2.02
|
Quorum;
Withdrawal During Meeting; Adjournment
. . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
|
1
|
Section
2.03
|
Annual
Meetings. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . .
|
2
|
Section
2.04
|
Special
Meetings. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . .
|
2
|
Section
2.05
|
Record
Dates. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . .
|
2
|
Section
2.06
|
Notice
of Meetings. . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . .
|
3
|
Section
2.07
|
List
of Stockholders. . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . .
|
4
|
Section
2.08
|
Proxies.
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . .
|
4
|
Section
2.09
|
Voting;
Elections; Inspectors. . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . .
|
5
|
Section
2.10
|
Conduct
of Meetings. . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . .
|
6
|
Section
2.11
|
Treasury
Stock. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . .
|
6
|
Section
2.12
|
Action
Without Meeting. . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . .
|
6
|
Section
2.13
|
Nominations
and Stockholder Business. . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
|
7
|
ARTICLE
III BOARD OF DIRECTORS
|
9
|
|
Section
3.01
|
Power;
Number; Term of Office. . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . .
|
9
|
Section
3.02
|
Quorum;
Required Vote for Director Action. . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
|
10
|
Section
3.03
|
Place
of Meetings; Order of Business. . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
|
10
|
Section
3.04
|
First
Meeting. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . .
|
10
|
Section
3.05
|
Regular
Meetings. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . .
|
10
|
Section
3.06
|
Special
Meetings. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . .
|
10
|
Section
3.07
|
Removal.
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. .
|
10
|
Section
3.08
|
Vacancies;
Increases in the Number of Directors. . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . .
|
11
|
Section
3.09
|
Compensation.
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. .
|
11
|
Section
3.10
|
Action
Without a Meeting; Telephone Conference Meeting. . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . .
|
11
|
Section
3.11
|
Approval
or Ratification of Acts or Contracts by Stockholders. . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . .
|
11
|
ARTICLE
IV COMMITTEES
|
11
|
|
Section
4.01
|
Designation;
Powers. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . .
|
11
|
Section
4.02
|
Procedure;
Meetings; Quorum. . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
.
|
12
|
Section
4.03
|
Subcommittees.
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . .
|
12
|
ARTICLE
V OFFICERS
|
12
|
|
Section
5.01
|
Number,
Titles and Term of Office. . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. .
|
12
|
Section
5.02
|
Compensation.
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . .
|
12
|
Section
5.03
|
Removal.
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . .
|
12
|
Section
5.04
|
Vacancies.
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . .
|
13
|
Section
5.05
|
Powers
and Duties of the Chief Executive Officer. . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
|
13
|
Section
5.06
|
Chairman
of the Board. . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . .
|
13
|
Section
5.07
|
Powers
and Duties of the President. . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
.
|
13
|
Section
5.08
|
Vice
Presidents. . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . .
|
13
|
Section
5.09
|
Secretary.
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . .
|
13
|
Section
5.10
|
Assistant
Secretaries. . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . .
|
14
|
Section
5.11
|
Action
with Respect to Securities of Other Corporations. . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . .
|
14
|
ARTICLE
VI INDEMNIFICATION OF DIRECTORS, OFFICERS,
EMPLOYEES AND AGENTS
|
14
|
|
Section
6.01
|
Right
to Indemnification. . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . .
|
14
|
Section
6.02
|
Advance
Payment. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . .
|
15
|
Section
6.03
|
Appearance
as a Witness. . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . .
|
15
|
Section
6.04
|
Employees
and Agents. . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . .
|
15
|
Section
6.05
|
Right
of Claimant to Bring Suit. . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . .
|
15
|
Section
6.06
|
Nonexclusivity
of Rights. . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . .
|
16
|
Section
6.07
|
Insurance.
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . .
|
16
|
Section
6.08
|
Savings
Clause. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . .
|
16
|
Section
6.09
|
Definitions.
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . .
|
16
|
ARTICLE
VII CAPITAL STOCK
|
16
|
|
Section
7.01
|
Certificates
of Stock. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . .
|
16
|
Section
7.02
|
Transfer
of Shares. . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . .
|
17
|
Section
7.03
|
Ownership
of Shares. . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . .
|
17
|
Section
7.04
|
Regulations
Regarding Certificates. . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
.
|
17
|
Section
7.05
|
Lost,
Stolen, Destroyed or Mutilated Certificates. . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
|
17
|
ARTICLE
VIII MISCELLANEOUS PROVISIONS
|
18
|
|
Section
8.01
|
Fiscal
Year. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . .
|
18
|
Section
8.02
|
Corporate
Seal. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . .
|
18
|
Section
8.03
|
Facsimile
Signatures. . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . .
|
18
|
Section
8.04
|
Reliance
upon Books, Reports and Records. . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
|
18
|
ARTICLE
IX AMENDMENTS
|
18
|
Annual
Anniversary of Date of Grant
|
Percentage
of Restricted
Shares
Subject to Forfeiture Restrictions as
to
which Forfeiture Restrictions Lapse
|
Second
|
33
1/3%
|
Third
|
50%
|
Fourth
|
100%
|
NEWFIELD
EXPLORATION COMPANY
|
|
By:
|
|
_________
_________
_________
_________
_________
_________
|
|
Address:
363
N. Sam Houston Pkwy. E.
Suite
2020
Houston,
Texas 77060
Facsimile: (281)
405-4242
|
INDEMNITEE
|
|
By:
|
|
[Name]
|
|
Address:
Facsimile: (___)
____-_____
|
·
|
a
$1.8 billion ($1.2 billion after-tax), or $8.82 per share, reduction in
the carrying value of oil and gas properties due to significantly lower
commodity prices at year-end 2008. This non-cash adjustment
resulted from the application of full cost accounting
rules;
|
·
|
a
net unrealized gain on commodity derivatives of $623 million ($401 million
after-tax), or $3.07 per share;
|
·
|
a
goodwill impairment of $62 million or $0.48 per
share.
|
·
|
a
$1.8 billion ($1.2 billion after-tax), or $8.75 per share, reduction in
the carrying value of oil and gas properties due to significantly lower
commodity prices at year-end 2008. This non-cash adjustment resulted from
the application of full cost accounting
rules;
|
·
|
a
net unrealized gain on commodity derivatives of $665 million ($429 million
after-tax), or $3.25 per share;
|
·
|
a
goodwill impairment of $62 million or $0.47 per
share.
|
Ø
|
Proved Reserves
Increase 18% to 2.95 Tcfe at Year-End 2008
– Newfield added 758
Bcfe in 2008, stated before negative price related reserve revisions of 66
Bcfe. Reserve Life Index of approximately 13 years reflects continued
growth in longer-lived “resource plays.”
(See news release dated
January 29, 2009 for
details)
|
Ø
|
Approximately 75% of
Total Year-End Reserves Located in Resource Plays
– Mid-Continent
and Rocky Mountain divisions posted combined reserve growth of 21%.
Newfield has significant inventory of development drilling locations.
Nearly two-thirds of 2009 capital budget allocated to these
regions.
|
Ø
|
Most Significant
Reserve Additions Came in Mid-Continent Division
– Newfield’s
Mid-Continent division reserves grew 26%. Division now comprises nearly
50% of total Company reserves. Reserves in the Mid-Continent region were
added for finding and development costs of $1.80 per Mcfe, excluding the
negative impact of price-related reserve revisions, and $2.02 per Mcfe
including these revisions. See
“Finding and Development
Costs”
found after the financial statements in this
release.
|
o
|
Woodford Shale Sets
Production Record in Fourth Quarter 2008
– In mid-December 2008,
gross operated production exceeded Newfield’s year-end goal of 250
MMcfe/d. Total Woodford production volumes in 2008 increased 65% over
2007. Benefit of efficiency gains expected to grow production an
additional 30% in 2009, despite running fewer operated rigs. A complete
Woodford Shale update can be found in today’s edition of the Company’s
@NFX publication on the website at
http://www.newfield.com
.
|
o
|
Success with Initial
Dual Lateral Woodford Completion
–
Newfield’s first dual
lateral completion in the Woodford had an initial gross production rate of
13 MMcfe/d and is currently producing 6 MMcfe/d after nearly three months
of production. Each lateral was approximately 4,250 feet in
length.
|
o
|
Stiles Ranch Field
Achieves Record Production
– Production from the Stiles Ranch
Field, located in the Texas Panhandle, recently reached a record gross
production rate of 130 MMcfe/d. Newfield has an approximate 80% interest
in the field.
|
Ø
|
Monument Butte Field
Benefits from Increased Activity Levels in 2008
–
|
o
|
2008
gross production grew 17% over 2007 levels, reaching 17,000 BOPD in late
2008.
|
o
|
The
Company has drilled 124 wells on 20-acre spacing in its Monument Butte
Field, located in the Uinta Basin of the Rocky Mountains. The Company
expects to drill more than 3,000 development wells to fully develop the
field. Newfield has drilled more than 900 wells in the field since
acquiring it in 2004.
|
o
|
During
2007 and 2008, Newfield added 45,000 net acres north and adjacent to
Monument Butte. The lands are owned by the Ute Tribe. Newfield has drilled
44 successful wells on this acreage out of 45 attempts to date. Results
have been consistent with drilling in the main field
area.
|
o
|
The
Company remains encouraged with our deep gas drilling beneath Monument
Butte. The Company drilled six successful wells in 2008 to test the
Wasatch, Mesa Verde, Blackhawk and Mancos Shale beneath the Monument Butte
Field. Half of these wells were covered under a deep gas exploration
agreement signed in late 2008 that allows for promoted exploratory
drilling and progressive earning in approximately 71,000 net acres in
which Newfield will retain a greater than 70% interest. The remaining
three wells were drilled in the eastern portion of the field (covers
10,000 acres) where Newfield is operator and retains an 86% interest.
Although results have been positive, the Company investments in this play
in 2009 have been substantially curtailed due to commodity prices and our
capital budget.
|
Ø
|
Continued Positive
Drilling Results from Williston Basin
– Since 2007, Newfield has
added more than 400,000 net acres in the Williston Basin. In 2008, the
Company focused on assessing this acreage position, building an inventory
of prospects and adding new acreage. Recent drilling has been focused in
North Dakota on the southern end of the Nesson Anticline. Complete
drilling results can be found in
@NFX.
|
Ø
|
Four Deepwater Gulf of
Mexico Discoveries in 2008/early 2009
– Developments underway
expected to generate significant production growth over the next three
years. Newfield is currently drilling the first of two
back-to-back deepwater wells.
|
Ø
|
Malaysian Production
Increases 145% in 2008
– All of Newfield’s shallow water fields on
PM 318 and PM 323 are now on-line. Although planned international activity
levels have been reduced in 2009 due to capital budget constraints,
production is expected to increase 10% over 2008
levels.
|
4Q08
Actual
|
||||||||||||
Domestic
|
Int’l
|
Total
|
||||||||||
Production/Liftings
Note 1
|
||||||||||||
Natural
gas – Bcf
|
43.9 | – | 43.9 | |||||||||
Oil
and condensate – MMBbl
|
1.6 | 1.5 | 3.1 | |||||||||
Total
Bcfe
|
53.4 | 8.9 | 62.3 | |||||||||
Average Realized
Prices
Note 2
|
||||||||||||
Natural
gas – $/Mcf
|
$ | 5.47 | $ | – | $ | 5.47 | ||||||
Oil
and condensate – $/Bbl
|
$ | 39.74 | $ | 44.46 | $ | 42.03 | ||||||
Mcf
equivalent – $/Mcfe
|
$ | 5.69 | $ | 7.41 | $ | 5.94 | ||||||
Operating
Expenses:
|
||||||||||||
Lease
operating
|
||||||||||||
Recurring
($MM)
|
$ | 50.3 | $ | 17.5 | $ | 67.8 | ||||||
per/Mcfe
|
$ | 0.94 | $ | 1.96 | $ | 1.09 | ||||||
Major
($MM)
|
$ | 13.7 | $ | – | $ | 13.7 | ||||||
per/Mcfe
|
$ | 0.26 | $ | – | $ | 0.22 | ||||||
Production and other taxes
($MM)
Note 3
|
$ | (4.2 | ) | $ | 7.4 | $ | 3.2 | |||||
per/Mcfe
|
$ | (0.08 | ) | $ | 0.83 | $ | 0.05 | |||||
General and administrative
(G&A), net ($MM)
|
$ | 34.6 | $ | 0.9 | $ | 35.5 | ||||||
per/Mcfe
|
$ | 0.65 | $ | 0.11 | $ | 0.57 | ||||||
Capitalized
internal costs ($MM)
|
$ | (16.3 | ) | |||||||||
per/Mcfe
|
$ | (0.26 | ) | |||||||||
Interest
expense ($MM)
|
$ | 28.7 | ||||||||||
per/Mcfe
|
$ | 0.46 | ||||||||||
Capitalized
interest ($MM)
|
$ | (16.2 | ) | |||||||||
per/Mcfe
|
$ | (0.26 | ) | |||||||||
Note
1: Reflects approximately 3 Bcfe of deferred domestic gas production
related to GOM storms.
Note
2: Average realized prices include the effects of hedging contracts. If
the effects of these contracts were excluded, the average realized price
for total gas would have been $4.52 per Mcf and the total oil and
condensate average realized price would have been $45.17 per
barrel.
Note
3: Domestic production and other taxes includes refunds related to
production and severance tax exemptions on some of our onshore
wells.
|
1Q09
Estimates
|
||||||||||||
Domestic
|
Int’l
|
Total
|
||||||||||
Production/Liftings
Note
1
|
||||||||||||
Natural
gas – Bcf
|
42.1 – 46.6 | – | 42.1 – 46.6 | |||||||||
Oil
and condensate – MMBbl
|
1.4 – 1.6 | 1.4 – 1.5 | 2.8 – 3.1 | |||||||||
Total
Bcfe
|
50.7 – 56.0 | 8.3 – 9.1 | 59.0 – 65.1 | |||||||||
Average
Realized Prices
|
||||||||||||
Natural
gas – $/Mcf
|
Note
2
|
|||||||||||
Oil
and condensate – $/Bbl
|
Note
3
|
Note
4
|
||||||||||
Mcf
equivalent – $/Mcfe
|
||||||||||||
Operating
Expenses:
|
||||||||||||
Lease
operating
|
||||||||||||
Recurring
($MM)
|
$ | 52.4 - $57.9 | $ | 15.2 - $16.8 | $ | 67.6 - $74.7 | ||||||
per/Mcfe
|
$ | 1.03 - $1.04 | $ | 1.83 - $1.85 | $ | 1.14 - $1.16 | ||||||
Major
(workover, repairs, etc.) ($MM)
|
$ | 8.8 - $9.7 | – | $ | 8.8 - $9.7 | |||||||
per/Mcfe
|
$ | 0.17 - $0.18 | – | $ | 0.15 - $0.16 | |||||||
Production and other taxes
($MM)
Note
5
|
$ | 14.1 - $15.5 | $ | 5.1 - $5.7 | $ | 19.2 - $21.2 | ||||||
per/Mcfe
|
$ | 0.27 - $0.28 | $ | 0.61 - $0.63 | $ | 0.32 - $0.33 | ||||||
General and administrative
(G&A), net ($MM)
|
$ | 32.7 - $36.1 | $ | 1.5 - $1.7 | $ | 34.2 - $37.8 | ||||||
per/Mcfe
|
$ | 0.64 - $0.65 | $ | 0.18 - $0.19 | $ | 0.57 - $0.59 | ||||||
Capitalized
internal costs ($MM)
|
$ | (17.1 - $18.9 | ) | |||||||||
per/Mcfe
|
$ | (0.28 - $0.30 | ) | |||||||||
Interest
expense ($MM)
|
$ | 29.2 - $32.3 | ||||||||||
per/Mcfe
|
$ | 0.48 - $0.50 | ||||||||||
Capitalized
interest ($MM)
|
$ | (15.4 - $17.0 | ) | |||||||||
per/Mcfe
|
$ | (0.25 - $0.27 | ) | |||||||||
Tax
rate (%)
Note
6
|
36% - 38 | % | ||||||||||
Income
taxes (%)
|
||||||||||||
Current
|
14% - 16 | % | ||||||||||
Deferred
|
84% - 86 | % | ||||||||||
Note
1: Reflects approximately 1.75 Bcfe of deferred domestic gas production
related to GOM storms.
Note
2: Gas prices in the Mid-Continent, after basis differentials,
transportation and handling charges, typically average 70 – 80% of the
Henry Hub Index. Gas prices in the Gulf Coast, after basis differentials,
transportation and handling charges, are expected to average $0.40 – $0.60
per MMBtu less than the Henry Hub Index.
Note
3: Oil prices in the Gulf Coast typically average 90 – 95% of NYMEX WTI
price. Rockies oil prices average about $12 - $14 per barrel below WTI.
Oil production from the Mid-Continent typically averages 96 – 98% of
WTI.
Note
4: Oil in Malaysia typically sells at a slight discount to Tapis, or about
90% of WTI. Oil production from China typically sells at $10 - $15 per
barrel below WTI.
Note
5: Guidance for production taxes determined using $50/Bbl oil and $5/MMBtu
gas.
Note
6: Tax rate applied to earnings excluding unrealized gains or losses
on commodity derivatives.
|
CONDENSED
CONSOLIDATED BALANCE SHEET
(Unaudited,
in millions)
|
December
31,
2008
|
December
31,
2007
|
||||||
ASSETS
|
||||||||
Current
assets:
|
||||||||
Cash and cash
equivalents
|
$ | 24 | $ | 250 | ||||
Short-term
investments
|
— | 120 | ||||||
Derivative assets
|
688 | 72 | ||||||
Other current
assets
|
519 | 485 | ||||||
Total current
assets
|
1,231 | 927 | ||||||
Oil
and gas properties, net (full cost method)
|
5,714 | 5,923 | ||||||
Derivative
assets
|
222 | 17 | ||||||
Other
assets
|
138 | 119 | ||||||
Total assets
|
$ | 7,305 | $ | 6,986 | ||||
LIABILITIES
AND STOCKHOLDERS’ EQUITY
|
||||||||
Current
liabilities
|
$ | 1,093 | $ | 929 | ||||
Other
liabilities
|
92 | 322 | ||||||
Long-term
debt
|
2,213 | 1,050 | ||||||
Deferred
taxes
|
650 | 1,104 | ||||||
Total long-term
liabilities
|
2,955 | 2,476 | ||||||
Commitments
and contingencies
|
— | — | ||||||
STOCKHOLDERS’
EQUITY
|
||||||||
Common
stock
|
1 | 1 | ||||||
Additional
paid-in capital
|
1,335 | 1,278 | ||||||
Treasury
stock
|
(32 | ) | (32 | ) | ||||
Accumulated
other comprehensive loss
|
(11 | ) | (3 | ) | ||||
Retained
earnings
|
1,964 | 2,337 | ||||||
Total stockholders’
equity
|
3,257 | 3,581 | ||||||
Total liabilities and
stockholders’ equity
|
$ | 7,305 | $ | 6,986 |
CONDENSED
CONSOLIDATED STATEMENT OF CASH FLOWS
(Unaudited,
in millions)
|
For
the
Twelve
Months Ended
December
31,
|
|||||||
2008
|
2007
|
|||||||
Cash
flows from operating activities:
|
||||||||
Net income (loss)
|
$ | (373 | ) | $ | 450 | |||
Adjustments
to reconcile net income (loss) to net cash provided by
operating
activities:
|
||||||||
Income
from discontinued operations, net of tax
|
— | (278 | ) | |||||
Depreciation,
depletion and amortization
|
697 | 682 | ||||||
Ceiling test and other
impairments
|
1,863 | — | ||||||
Stock-based
compensation
|
26 | 23 | ||||||
Commodity derivative (income)
expense
|
(408 | ) | 188 | |||||
Cash (payments) receipts on
derivative settlements
|
(750 | ) | 180 | |||||
Deferred tax provision
(benefit)
|
(198 | ) | 30 | |||||
857 | 1,275 | |||||||
Changes in operating assets and
liabilities
|
(3 | ) | (109 | ) | ||||
Net cash provided by continuing
activities
|
854 | 1,166 | ||||||
Net cash used in discontinued
activities
|
— | (12 | ) | |||||
Net cash provided by operating
activities
|
854 | 1,154 | ||||||
Cash
flows from investing activities:
|
||||||||
Additions to oil and gas
properties and other
|
(2,087 | ) | (1,943 | ) | ||||
Acquisition of oil and gas
properties
|
(223 | ) | (658 | ) | ||||
Proceeds from (purchase price
adjustment related to) sales of oil
and
gas properties
|
9 | 1,344 | ||||||
Proceeds from sale of UK
subsidiaries, net of cash on hand at sale date
|
— | 491 | ||||||
Purchases of
investments
|
(22 | ) | (271 | ) | ||||
Redemption of
investments
|
70 | 172 | ||||||
Net cash used in continuing
activities
|
(2,253 | ) | (865 | ) | ||||
Net cash used in discontinued
activities
|
— | (41 | ) | |||||
Net cash used in investing
activities
|
(2,253 | ) | (906 | ) | ||||
Cash
flows from financing activities:
|
||||||||
Net proceeds under credit
arrangements
|
561 | — | ||||||
Net proceeds from issuance of
senior subordinated notes
|
592 | — | ||||||
Repayment of senior
notes
|
— | (125 | ) | |||||
Payments to discontinued
operations
|
— | (38 | ) | |||||
Proceeds from issuances of common
stock
|
21 | 32 | ||||||
Stock-based compensation excess
tax benefit
|
— | 14 | ||||||
Purchases of treasury
stock
|
(1 | ) | — | |||||
Net cash provided by (used in)
continuing activities
|
1,173 | (117 | ) | |||||
Net cash provided by discontinued
activities
|
— | 38 | ||||||
Net cash provided by (used in)
financing activities
|
1,173 | (79 | ) | |||||
Effect
of exchange rate changes on cash and cash equivalents
|
— | 1 | ||||||
Increase
(decrease) in cash and cash equivalents
|
(226 | ) | 170 | |||||
Cash
and cash equivalents from continuing operations,
beginning
of period
|
250 | 52 | ||||||
Cash
and cash equivalents from discontinued operations,
beginning
of period
|
— | 28 | ||||||
Cash
and cash equivalents, end of period
|
$ | 24 | $ | 250 |
4Q08 |
2008
|
|||||||
(in
millions)
|
||||||||
Net
loss
|
$ | (789 | ) | $ | (373 | ) | ||
Ceiling test
writedowns
|
1,801 | 1,801 | ||||||
Goodwill
impairment
|
62 | 62 | ||||||
Net unrealized gain on
commodity derivatives
(1)
|
(623 | ) | (665 | ) | ||||
Income tax adjustment for
above items
|
(425 | ) | (410 | ) | ||||
Earnings
stated without the effect of the above items
|
$ | 26 | $ | 415 |
4Q08 |
2008
|
|||||||
(in
millions)
|
||||||||
Commodity
derivative income
|
$ | 655 | $ | 408 | ||||
Cash
payments (receipts) on derivative settlements
(1)
|
(33 | ) | 248 | |||||
Option
premiums associated with derivatives settled
during
the period
|
1 | 9 | ||||||
Net unrealized gain on commodity
derivatives
|
$ | 623 | $ | 665 |
4Q08 |
2008
|
|||||||
(in
millions)
|
||||||||
Net
cash provided by operating activities
|
$ | 232 | $ | 854 | ||||
Net change in operating assets
and liabilities
|
11 | 3 | ||||||
Net
cash provided by operating activities before changes
in
operating assets and liabilities
|
$ | 243 | $ | 857 |
·
|
2008
DRILLING ACTIVITY BY AREA
|
·
|
RECENT
HIGHLIGHTS
|
·
|
OPERATIONAL
SUMMARIES BY GEOGRAPHIC REGION
|
·
|
2009
GOALS
|
·
|
FIRST QUARTER 2009
GUIDANCE
|
·
|
UPDATED
TABLES
DETAILING COMPLETE HEDGE
POSITIONS
|
Mid-Continent
|
23 | 28 | 51 | 0 | ||||||||||||
Rocky
Mount.
|
81 | 3 | 84 | 1 | ||||||||||||
Onshore
GC
|
17 | 3 | 20 | 5 | ||||||||||||
Gulf
of Mexico
|
1 | 1 | 2 | 0 | ||||||||||||
International
|
4 | 4 | 8 | 0 | ||||||||||||
Total:
|
126 | 39 | 165 | 6 |
Mid-Continent
|
120 | 107 | 227 | 3 | ||||||||||||
Rocky
Mount.
|
271 | 16 | 287 | 4 | ||||||||||||
Onshore
GC
|
55 | 9 | 64 | 16 | ||||||||||||
Gulf
of Mexico
|
3 | 3 | 6 | 1 | ||||||||||||
International
|
10 | 13 | 23 | 1 | ||||||||||||
Total:
|
459 | 148 | 607 | 25 |
-
|
2008
production of 236 Bcfe, an increase of 24% over 2007 proforma volumes of
190 Bcfe (adjusted for asset sales and
acquisitions).
|
-
|
Year-end 2008 proved reserves
of 2.95 Tcfe,
an 18% increase over proved reserves at year-end
2007. We replaced nearly 300% of 2008 production with new reserves.
Substantially all of the reserve additions were from organic drilling
programs and 62% at year-end were proved developed. Net negative reserve
revisions, due primarily to lower commodity prices at year-end 2008,
totaled 66 Bcfe.
|
-
|
2008 Capital Spending/Finding
Costs.
Newfield invested approximately $2.3 billion in 2008. Total
F&D costs in 2008 were $2.96 per Mcfe, excluding the negative impact
of price-related reserve revisions, and $3.31 per Mcfe including the
revisions.
|
-
|
Approximately 75% of total
Company year–end ’08 reserves in resource plays in our two largest
divisions
:
the
Mid-Continent and Rocky Mountains
. Reserves in these divisions
increased 21%. Nearly two-thirds of the 2009 capital budget is allocated
to these areas. Combined F&D costs in the Mid-Continent and Rocky
Mountains averaged $1.91 per Mcfe in 2008, excluding the negative impact
of price related reserve revisions and $2.23 per Mcfe including the
revisions.
|
-
|
Five
deepwater Gulf of Mexico developments provide visible, future production
growth.
|
-
|
Williston
Basin success continues with a growing inventory of oil locations in the
Bakken and Sanish/Three Forks.
|
-
|
2009-10 hedge position has a
mark-to-market value of nearly $1 billion.
Approximately 70% of
expected 2009 gas production is hedged with an average minimum price of
nearly $8 per Mcf. Substantially all of our 2009 domestic oil production
is hedged with half of this amount fixed at about $129 per barrel and the
remainder with a floor price of $107 per
barrel.
|
-
|
Drilling
improvements – We’re drilling our wells faster. We have identified “speed
zones” in the Woodford section that allow our penetration rates in the
lateral to dramatically improve. We are continually refining bit designs
and using new technology for bits to drill faster and run longer which has
been another significant factor for driving cost out of our
program.
|
-
|
Pad
drilling – Before the majority of our acreage was held by production, we
were unable to fully implement pad drilling. Costs have significantly
improved with pad drilling. More than 80% of our 2009 wells will be from
common pads.
|
-
|
Completion
advances – We have refined our completions with the biggest cost savings
coming through reducing our pumped frac fluid
volumes.
|
-
|
Increased
lateral lengths – In 2006, our average well had a 2500’ lateral and our
plans for 2009 include 5000’ laterals. Please see above chart. Although
our longer lateral wells cost more, the F&D cost per MCF is
significantly lower.
|
Well Name
|
Initial Rate
|
Target Zone
|
Olson
1-30H
|
329
BOEPD
|
Bakken
|
Larsen
1-16H
|
710
BOEPD
|
Bakken
|
Rolfsrud
1-32H
|
590
BOEPD
|
Bakken
|
Wisness
1-21H
|
538
BOEPD
|
Bakken
|
Jorgensen
1-10H
|
911
BOEPD
|
Bakken
|
Jorgensen
1-4H
|
622
BOEPD
|
Bakken
|
Jorgensen
1-15H
|
1,010
BOEPD
|
Sanish/Three
Forks
|
Lost
Bridge 16-9H
|
1,023
BOEPD
|
Sanish/Three
Forks
|
1Q09
Estimates
|
||||||||||||
Domestic
|
Int’l
|
Total
|
||||||||||
Production/Liftings
Note
1
|
||||||||||||
Natural
gas – Bcf
|
42.1 – 46.6 | – | 42.1 – 46.6 | |||||||||
Oil
and condensate – MMBbl
|
1.4 – 1.6 | 1.4 – 1.5 | 2.8 – 3.1 | |||||||||
Total
Bcfe
|
50.7 – 56.0 | 8.3 – 9.1 | 59.0 – 65.1 | |||||||||
Average
Realized Prices
|
||||||||||||
Natural
gas – $/Mcf
|
Note
2
|
|||||||||||
Oil
and condensate – $/Bbl
|
Note
3
|
Note
4
|
||||||||||
Mcf
equivalent – $/Mcfe
|
||||||||||||
Operating
Expenses:
|
||||||||||||
Lease
operating
|
||||||||||||
Recurring
($MM)
|
$ | 52.4 - $57.9 | $ | 15.2 - $16.8 | $ | 67.6 - $74.7 | ||||||
per/Mcfe
|
$ | 1.03 - $1.04 | $ | 1.83 - $1.85 | $ | 1.14 - $1.16 | ||||||
Major
(workover, repairs, etc.) ($MM)
|
$ | 8.8 - $9.7 | – | $ | 8.8 - $9.7 | |||||||
per/Mcfe
|
$ | 0.17 - $0.18 | – | $ | 0.15 - $0.16 | |||||||
Production and other taxes
($MM)
Note
5
|
$ | 14.1 - $15.5 | $ | 5.1 - $5.7 | $ | 19.2 - $21.2 | ||||||
per/Mcfe
|
$ | 0.27 - $0.28 | $ | 0.61 - $0.63 | $ | 0.32 - $0.33 | ||||||
General and administrative
(G&A), net ($MM)
|
$ | 32.7 - $36.1 | $ | 1.5 - $1.7 | $ | 34.2 - $37.8 | ||||||
per/Mcfe
|
$ | 0.64 - $0.65 | $ | 0.18 - $0.19 | $ | 0.57 - $0.59 | ||||||
Capitalized
internal costs ($MM)
|
$ | (17.1 - $18.9 | ) | |||||||||
per/Mcfe
|
$ | (0.28 - $0.30 | ) | |||||||||
Interest
expense ($MM)
|
$ | 29.2 - $32.3 | ||||||||||
per/Mcfe
|
$ | 0.48 - $0.50 | ||||||||||
Capitalized
interest ($MM)
|
$ | (15.4 - $17.0 | ) | |||||||||
per/Mcfe
|
$ | (0.25 - $0.27 | ) | |||||||||
Tax
rate (%)
Note
6
|
36% - 38 | % | ||||||||||
Income
taxes (%)
|
||||||||||||
Current
|
14% - 16 | % | ||||||||||
Deferred
|
84% - 86 | % | ||||||||||
Note
1: Reflects approximately 1.75 Bcfe of deferred domestic gas production
related to GOM storms.
Note
2: Gas prices in the Mid-Continent, after basis differentials,
transportation and handling charges, typically average 70 – 80% of the
Henry Hub Index. Gas prices in the Gulf Coast, after basis differentials,
transportation and handling charges, are expected to average $0.40 – $0.60
per MMBtu less than the Henry Hub Index.
Note
3: Oil prices in the Gulf Coast typically average 90 – 95% of NYMEX WTI
price. Rockies oil prices average about $12 - $14 per barrel below WTI.
Oil production from the Mid-Continent typically averages 96 – 98% of
WTI.
Note
4: Oil in Malaysia typically sells at a slight discount to Tapis, or about
90% of WTI. Oil production from China typically sells at $10 - $15 per
barrel below WTI.
Note
5: Guidance for production taxes determined using $50/Bbl oil and $5/MMBtu
gas.
Note
6: Tax rate applied to earnings excluding unrealized gains or losses
on commodity derivatives.
|
(in
millions)
1Q09
|
2Q09
|
3Q09
|
4Q09
|
TOTAL
BUDGET
|
$460-$480
|
$405-$420
|
$310-$325
|
$210-$225
|
$1,450
|
Weighted
Average
|
Range
|
|||||||||||||||||||
Volume
|
Fixed
|
Floors
|
Collars
|
Floor
|
Ceiling
|
|||||||||||||||
21,950
MMMBtus
|
$ | 7.81 | — | — | — | — | ||||||||||||||
13,485
MMMBtus
|
— | — | $ | 8.00 — $11.83 | $ | 8.00 | $ | 8.97 — $14.37 |
Weighted
Average
|
Range
|
|||||||||||||||||||
Volume
|
Fixed
|
Floors
|
Collars
|
Floor
|
Ceiling
|
|||||||||||||||
22,150
MMMBtus
|
$ | 7.81 | — | — | — | — | ||||||||||||||
13,620
MMMBtus
|
— | — | $ | 8.00 — $11.83 | $ | 8.00 | $ | 8.97 — $14.37 |
Weighted
Average
|
Range
|
|||||||||||||||||||
Volume
|
Fixed
|
Floors
|
Collars
|
Floor
|
Ceiling
|
|||||||||||||||
26,120
MMMBtus
|
$ | 7.34 | — | — | — | — | ||||||||||||||
8,435
MMMBtus
|
— | — | $ | 8.23 — $11.20 | $ | 8.00 — $8.50 | $ | 8.97 — $14.37 |
Weighted
Average
|
Range
|
|||||||||||||||||||
Volume
|
Fixed
|
Floors
|
Collars
|
Floor
|
Ceiling
|
|||||||||||||||
15,600
MMMBtus
|
$ | 7.41 | — | — | — | — | ||||||||||||||
5,700
MMMBtus
|
— | — | $ | 8.50 — $10.44 | $ | 8.50 | $ | 10.00 — $11.00 |
Weighted
Average
|
Range
|
|||||||||||||||||||
Volume
|
Fixed
|
Floors
|
Collars
|
Floor
|
Ceiling
|
|||||||||||||||
11,190
MMMBtus
|
$ | 6.78 | — | — | — | — |
Weighted
Average
|
Range
|
|||||||||||||||||||
Volume
|
Fixed
|
Floors
|
Collars
|
Floor
|
Ceiling
|
|||||||||||||||
11,280
MMMBtus
|
$ | 6.78 | — | — | — | — |
Weighted
Average
|
Range
|
|||||||||||||||||||
Volume
|
Fixed
|
Floors
|
Collars
|
Floor
|
Ceiling
|
|||||||||||||||
3,790
MMMBtus
|
$ | 6.78 | — | — | — | — |
$ | 4.00 | $ | 5.00 | $ | 6.00 | $ | 7.00 | $ | 8.00 | |||||||||||
2009
|
||||||||||||||||||||
1st
Quarter
|
$ | 109 | $ | 85 | $ | 61 | $ | 37 | $ | 6 | ||||||||||
2nd
Quarter
|
$ | 137 | $ | 102 | $ | 66 | $ | 31 | $ | (5 | ) | |||||||||
3rd
Quarter
|
$ | 138 | $ | 102 | $ | 67 | $ | 31 | $ | (5 | ) | |||||||||
4th
Quarter
|
$ | 123 | $ | 88 | $ | 54 | $ | 19 | $ | (15 | ) | |||||||||
Total
2009
|
$ | 507 | $ | 377 | $ | 248 | $ | 118 | $ | (19 | ) | |||||||||
2010
|
||||||||||||||||||||
1st
Quarter
|
$ | 79 | $ | 57 | $ | 36 | $ | 15 | $ | (6 | ) | |||||||||
2nd
Quarter
|
$ | 31 | $ | 20 | $ | 9 | $ | (2 | ) | $ | (13 | ) | ||||||||
3rd
Quarter
|
$ | 31 | $ | 20 | $ | 9 | $ | (3 | ) | $ | (14 | ) | ||||||||
4th
Quarter
|
$ | 11 | $ | 7 | $ | 3 | $ | (1 | ) | $ | (5 | ) | ||||||||
Total
2010
|
$ | 152 | $ | 104 | $ | 57 | $ | 9 | $ | (38 | ) |
Weighted
Average
|
Range
|
|||||||||||||||||||
Volume
|
Fixed
|
Floors
|
Collars
|
Floor
|
Ceiling
|
|||||||||||||||
810,000
Bbls
|
$ | 128.93 | — | — | — | — | ||||||||||||||
810,000
Bbls
|
— | $ | 107.11 | — | $ | 104.50 — $109.75 | — |
Weighted
Average
|
Range
|
|||||||||||||||||||
Volume
|
Fixed
|
Floors
|
Collars
|
Floor
|
Ceiling
|
|||||||||||||||
819,000
Bbls
|
$ | 128.93 | — | — | — | — | ||||||||||||||
819,000
Bbls
|
— | $ | 107.11 | — | $ | 104.50 — $109.75 | — |
Weighted
Average
|
Range
|
|||||||||||||||||||
Volume
|
Fixed
|
Floors
|
Collars
|
Floor
|
Ceiling
|
|||||||||||||||
828,000
Bbls
|
$ | 128.93 | — | — | — | — | ||||||||||||||
828,000
Bbls
|
— | $ | 107.11 | — | $ | 104.50 — $109.75 | — |
Weighted
Average
|
Range
|
|||||||||||||||||||
Volume
|
Fixed
|
Floors
|
Collars
|
Floor
|
Ceiling
|
|||||||||||||||
828,000
Bbls
|
$ | 128.93 | — | — | — | — | ||||||||||||||
828,000
Bbls
|
— | $ | 107.11 | — | $ | 104.50 — $109.75 | — |
Weighted
Average
|
Range
|
|||||||||||||||||||
Volume
|
Fixed
|
Floors
|
Collars
|
Floor
|
Ceiling
|
|||||||||||||||
90,000
Bbls
|
$ | 93.40 | — | — | — | — | ||||||||||||||
810,000
Bbls
|
— | — | $ | 127.97— $170.00 | $ | 125.50 — $130.50 | $ | 170.00 |
Weighted
Average
|
Range
|
|||||||||||||||||||
Volume
|
Fixed
|
Floors
|
Collars
|
Floor
|
Ceiling
|
|||||||||||||||
90,000
Bbls
|
$ | 93.40 | — | — | — | — | ||||||||||||||
819,000
Bbls
|
— | — | $ | 127.97— $170.00 | $ | 125.50 — $130.50 | $ | 170.00 |
Weighted
Average
|
Range
|
|||||||||||||||||||
Volume
|
Fixed
|
Floors
|
Collars
|
Floor
|
Ceiling
|
|||||||||||||||
90,000
Bbls
|
$ | 93.40 | — | — | — | — | ||||||||||||||
828,000
Bbls
|
— | — | $ | 127.97— $170.00 | $ | 125.50 — $130.50 | $ | 170.00 |
Weighted
Average
|
Range
|
|||||||||||||||||||
Volume
|
Fixed
|
Floors
|
Collars
|
Floor
|
Ceiling
|
|||||||||||||||
90,000
Bbls
|
$ | 93.40 | — | — | — | — | ||||||||||||||
828,000
Bbls
|
— | — | $ | 127.97— $170.00 | $ | 125.50 — $130.50 | $ | 170.00 |
Oil
Prices
|
|||||||
$40.00
|
$50.00
|
$60.00
|
$70.00
|
$80.00
|
|||
2009
|
|||||||
1st
Quarter
|
$ 120
|
$ 104
|
$ 88
|
$ 72
|
$
55
|
||
2nd
Quarter
|
$ 122
|
$ 105
|
$ 89
|
$ 72
|
$
56
|
||
3rd
Quarter
|
$ 123
|
$ 107
|
$ 90
|
$ 73
|
$
57
|
||
4th
Quarter
|
$ 145
|
$ 134
|
$ 122
|
$ 112
|
$ 101
|
||
Total
2009
|
$ 510
|
$ 450
|
$ 389
|
$ 329
|
$ 269
|
||
2010
|
|||||||
1st
Quarter
|
$ 69
|
$ 59
|
$ 50
|
$ 42
|
$
33
|
||
2nd
Quarter
|
$ 69
|
$ 60
|
$ 51
|
$ 42
|
$
33
|
||
3rd
Quarter
|
$ 70
|
$ 61
|
$ 52
|
$ 42
|
$
33
|
||
4th
Quarter
|
$ 70
|
$ 61
|
$ 52
|
$ 42
|
$ 33
|
||
Total
2010
|
$ 278
|
$ 241
|
$ 205
|
$ 168
|
$ 132
|