EPL Announces Fourth Quarter and Year End Results for 2007
Energy Partners, Ltd. (EPL or the Company) (NYSE:EPL) today reported financial and operational results for the fourth quarter of 2007 and the full year, including year end 2007 proved reserves and reserve replacement.
Financial Results
For the fourth quarter of 2007, EPL reported a net loss to common stockholders of $73.4 million, or $2.31 per diluted share, compared to a net loss for the fourth quarter of 2006 of $52.5 million, or $1.35 per diluted share. The Company said the majority of the net loss for the fourth quarter of 2007 was attributable to $100.4 million of pre-tax, non-cash costs associated with property impairments. The vast majority of the impairments were associated with properties located in its Western offshore area. Five properties, located primarily in the Western area, experienced mechanical difficulties requiring significant capital to restore production, and accounted for over 60% of the impairments. The Company determined, with its decreased capital budget for 2008, this capital would be better deployed to projects with more potential. The remaining impairment costs were mainly due to six fields in the Western offshore area that depleted earlier than anticipated or experienced production underperformance and were partially impaired. Excluding the after-tax impact of $64.2 million of impairment costs, EPL’s adjusted fourth quarter net loss, a non-GAAP measure, would have been $9.2 million or $0.29 per diluted share (see reconciliation of adjusted net loss in the appendix). In addition, the net loss for the fourth quarter also included $9.0 million of after-tax non-cash unrealized losses on derivative instruments.
For the full year 2007, the net loss to common stockholders was $80.0 million, or $2.32 per diluted share, compared to a net loss in 2006 of $50.4 million, or $1.32 per diluted share. The benefit of record annual revenue was offset by $114.9 million of non-cash, pre-tax property impairment costs for the full year 2007, the majority of which were associated with the impairments recorded in the fourth quarter of 2007, and $9.4 million of pre-tax costs incurred in the first half of the year comprised of financial and legal advisory fees mainly related to the exploration of strategic alternatives. Excluding the after-tax impact of $79.6 million of impairment costs and the noted legal and financial advisory fees, EPL’s adjusted 2007 net loss, a non-GAAP measure, would have been $0.4 million or $0.01 per diluted share (see reconciliation of adjusted net loss in the appendix). In addition, the net loss for the year also included $8.8 million of after-tax non-cash unrealized losses on derivative instruments.
Revenue for the fourth quarter of 2007 was $114.1 million, up from the fourth quarter 2006 revenues of $111.6 million. Revenue for the year 2007 increased to $454.6 million from $449.6 million in 2006. Discretionary cash flow, which is cash flow from operations before changes in working capital and exploration expenditures, totaled $70.7 million in the fourth quarter of 2007, versus $65.0 million in the fourth quarter last year. For the full year, discretionary cash flow was $278.9 million compared to $279.1 million in 2006 (see reconciliation of discretionary cash flow in appendix). Cash flow from operations in the most recent quarter was $64.0 million, compared to $86.7 million in the fourth quarter of 2006. Cash flow from operations for 2007 totaled $293.9 million compared to $272.1 million in 2006.
In the fourth quarter of 2007, production averaged 20,806 barrels of oil equivalent (Boe) per day, compared to 27,080 Boe per day in the fourth quarter of 2006. Natural gas production in the fourth quarter of 2007 averaged 73.9 million cubic feet (Mmcf) per day and oil production averaged 8,489 barrels per day.
Production for the full year 2007 averaged 24,130 Boe per day, down from the 2006 average of 25,912 Boe per day primarily due to the sale of substantially all of the Company’s onshore south Louisiana properties in June of 2007. Natural gas production averaged 92.2 Mmcf per day in 2007, and oil production averaged 8,769 barrels per day.
Price realizations, all of which are stated before the impact of derivative instruments, averaged $84.44 per barrel for oil and $7.07 per thousand cubic feet (Mcf) of natural gas in the fourth quarter of 2007, compared to $53.64 per barrel and $6.64 per Mcf in the fourth quarter of 2006. For 2007, oil price realizations averaged $66.78 per barrel and natural gas averaged $7.15 per Mcf compared to $59.78 per barrel and $6.98 per Mcf in 2006.
As of December 31, 2007, the Company had cash on hand of $8.9 million and total debt of $484.5 million. The Company also had $170.0 million of remaining capacity available under its bank facility at year end 2007.
Richard A. Bachmann, EPL’s Chairman and CEO, commented, “Our fourth quarter and full year results were clearly overshadowed by the impairments of properties in our Western offshore area. These impairments were the result of mechanical and performance issues. The performance in our Western offshore area is unacceptable, and we have taken decisive steps to correct this issue. These steps include reducing our capital spending in this area going forward, an area that we no longer consider one of our core focus areas for capital investment. It is important to note that these impairments occurred in areas outside of our core focus areas in the Central and Eastern offshore areas where we have experienced tremendous success, particularly in our South Timbalier area. Our 2008 spending plans will be focused primarily on our core areas in South Timbalier and our East Bay field where we have enjoyed a good return on our capital deployed, and initiating production from our deepwater Raton discovery.”
Operational Results
EPL drilled 17 exploratory wells in 2007 on the Gulf of Mexico (GOM) Shelf (Shelf) and onshore in South Louisiana. Of the 13 wells offshore, five were successful, and of the four wells onshore, one was successful. A table of EPL’s 2007 exploratory wells is available in the appendix.
In addition to exploratory drilling, EPL drilled four successful development wells and completed 24 successful workovers and recompletions in 2007. Overall, EPL was 100% successful in its low risk drillwell program.
At year end 2007, undeveloped gross leasehold acreage stood at 341,019 acres and combined gross undeveloped and developed acreage totaled 593,101 acres.
Reserve Replacement and Costs
EPL’s proved reserves at year end 2007 stood at 28.1 million barrels of oil and 103.1 billion cubic feet of natural gas, or 45.3 million Boe. EPL’s proved reserves at year-end 2007 were 62% oil and 38% natural gas, and 84% were classified as proved developed. EPL added 2.5 million Boe from its exploration and development program, and acquired an additional 0.7 million Boe mainly from the purchase of an additional interest in the Company’s Mississippi Canyon blocks 248 (the Raton discovery), 204, and 292 leases in the deepwater GOM. The Company recorded 5.3 million Boe in negative revisions to its proved reserves in 2007, comprised of 4.1 million Boe of negative revisions for fields mainly in the Western offshore area that were impaired during 2007. EPL produced 8.8 million Boe during 2007. The Company sold 2.1 million Boe in the sale of substantially all of its onshore South Louisiana asset base in June of 2007. The Company’s total expenditures for finding and development in 2007 were $307.7 million, or $317.3 million including acquisition expenditures (see reconciliation in the appendix).
The present value of the future net cash flows before income taxes of the Company’s estimated proved oil and natural gas reserves at the end of 2007 using a discount rate of 10% was approximately $1.5 billion, a $0.3 billion increase over the value reported last year. The 2007 value was determined based on period-end prices of $94.76 per barrel of oil and $6.98 per Mcf for natural gas.
All of the Company’s proved reserve figures are based upon third party engineering estimates prepared by Netherland, Sewell & Associates, Inc. and Ryder Scott Company, L.P.
Bachmann continued, “Our lack of exploratory drilling success in 2007 was clearly the reason for our low reserve replacement from the drill bit. Our negative revisions, mainly related to the impairment of properties outside our renewed core focus areas, led to all-in reserve adds that were less than our annual production. We are undertaking a comprehensive risk assessment study, which has been commissioned with an outside firm, to look at our past performance, and more importantly, to take a critical look at our current exploratory inventory and how to best execute on it. Nonetheless, our current proved reserve base experienced an increase of almost $300 million in present value compared to the prior year-end value. Our reserve base now has a higher concentration of oil reserves than we have had in the past five years.”
2008 Operational Update
The Company currently has two moderate risk, moderate potential exploratory wells located on the Shelf underway, including the South Timbalier (ST) 46 #5 (A-3) well and the ST 23 CC-14st well located in Bay Marchand. Both of these wells are located in EPL’s core Central offshore area.
EPL’s total budget for its current 2008 exploration and development program is approved up to $200 million. In addition to the two Shelf exploratory wells currently drilling in its Central offshore area, the Company plans to commence a pilot program late in the first quarter within its East Bay field to enhance oil production through the drilling of two infill horizontal wells. Additionally, the Company has three projects scheduled to commence production early to mid second quarter, including EPL’s first deepwater GOM well, Raton, in Mississippi Canyon 248. The Company does not budget for acquisitions.
MMS 205 Lease Sale Awards
The Company announced today that it has been awarded four additional leases since the beginning of 2008 from the October 2007 MMS lease sale. In total, the Company has been awarded seven of the eight leases on which it was high bidder from last year’s lease sale at a total cost of $18.8 million, including six Shelf leases and one deepwater GOM lease.
Asset Divestiture Update
The Company today announced it has entered into a definitive agreement to sell two non-operated properties located in its Western offshore area for $16.2 million in cash. The announced sale represents less than 1% of its proved reserves as of December 31, 2007 and a recent average production rate net to the Company of less than 2% of fourth quarter average production. The transaction is expected to close in late March or early April and is subject to customary closing conditions and adjustments from the effective date.
Bachmann concluded, “We believe the best near-term plan for the Company is to focus on exploitation and exploration in our core areas in the South Timbalier area and our East Bay field, and we have positioned our technical staff accordingly. Based on that narrowed focus, we are in the process of right sizing our Company to match a proved asset base that is concentrated in these areas. This right sizing is intended to reduce our cash costs. We are targeting a 20% reduction in our costs, mainly through reductions in general and administrative (G&A) costs and lease operating expenses (LOE). This process is underway and the major reductions in our G&A are expected to be implemented in the first half of this year, with LOE reductions to occur throughout the year.
“The Company will continue to look at property sales as a part of our strategy to pay down debt, with likely sales candidates to come from outside of our core focus areas, and transactions likely to be similar to the one we announced today in the Western offshore area.
“As I discussed earlier, we are undergoing an exhaustive look at our risking of drilling opportunities. We have retained Rose & Associates, a leading consulting firm on risk assessment, to lead this effort with our technical staff. While our risk assessment exercise will focus on our past performance, it will more importantly assess our portfolio of prospects that span the Shelf and deepwater GOM. The outcome of that study will focus the future direction of our capital spending in these areas.
“We are focused on growth through exploring and acquiring additional acreage and reserves within our core Central and Eastern offshore areas, with a clear preference to opportunities that fall within these core focus areas and lead to expansion of our reserve base. We are also considering other basins for investment opportunities that could lengthen our reserve life and provide a more predictable production base to support our Shelf and deepwater GOM pursuits. The actions we have detailed today provide us with a clear path to move forward that is intended to lead to future growth.”
EPL has scheduled a conference call to review fourth quarter and year end 2007 results this morning , February 28, 2008, at 8:30 A.M. central time. To participate in the EPL conference call, callers in the United States and Canada can dial (877) 612-5303 and international callers can dial (706) 634-0487. The Conference I.D. for callers is 33382119.
The call will be available for replay beginning two hours after the call is completed through midnight of March 4, 2008. For callers in the United States and Canada, the toll-free number for the replay is (800) 642-1687. For international callers the number is (706) 645-9291. The Conference I.D. for all callers to access the replay is 33382119.
The conference call will be webcast live as well as for on-demand listening at the Company’s web site, www.eplweb.com. Listeners may access the call through the “Conference Calls” link in the Investor Relations section of the site. The call will also be available through the CCBN Investor Network.
Founded in 1998, EPL is an independent oil and natural gas exploration and production company based in New Orleans, Louisiana. The Company’s operations are focused along the U.S. Gulf Coast, both onshore in south Louisiana and offshore in the Gulf of Mexico.
Forward-Looking Statements
This press release may contain forward-looking information and statements regarding EPL. Any statements included in this press release that address activities, events or developments that EPL expects, believes or anticipates will or may occur in the future are forward-looking statements. These include statements regarding:
reserve and production estimates;
oil and natural gas prices;
the impact of derivative positions;
production expense estimates;
cash flow estimates;
future financial performance;
planned capital expenditures; and
other matters that are discussed in EPL’s filings with the Securities and Exchange Commission.
These statements are based on current expectations and projections about future events and involve known and unknown risks, uncertainties, and other factors that may cause actual results and performance to be materially different from any future results or performance expressed or implied by these forward-looking statements. Please refer to EPL’s filings with the SEC, including Form 10-K for the year ended December 31, 2006, Form 10-Q for the quarter ended September 30, 2007, and Form 10-K for the year ended December 31, 2007 to be filed for a discussion of these risks.
Additional Information and Where to Find It. Security holders may obtain information regarding the Company from EPL’s website at www.eplweb.com, from the Securities and Exchange Commission’s website at www.sec.gov, or by directing a request to: Energy Partners, Ltd. 201 St. Charles Avenue, Suite 3400, New Orleans, Louisiana 70170, Attn: Secretary, (504) 569-1875.
Appendix
2007 Exploratory Wells
Offshore Block or Parish
Well Number or Prospect Name
EPL Working Interest
Risk
Result
Region
Terrebonne Parish
Barracuda
33%
Mod
Dryhole
Onshore
West Cameron 252
#1
75%
Mod
Success
Shelf
South Marsh Island 79
#2
100%
Mod
Dryhole
Shelf
South Pass 38
Apollo
75%
Mod
Dryhole
Shelf
Terrebonne Parish
LL&E #18-1
33%
Mod
Dryhole
Onshore
South Timbalier 26
ST26:Louisville
100%
Mod
Success
Shelf
West Cameron 312
WC312
100%
Mod
Dryhole
Shelf
Terrebonne Parish
Longhorn
40%
Mod
Dryhole
Onshore
South Timbalier 26
Chimney Rock
100%
Mod
Dryhole
Shelf
Eugene Island 312
#D-2
40%
Mod
Success
Shelf
Eugene Island 312
#D-3
40%
Mod
Success
Shelf
South Marsh Island 247
#1
100%
Mod
Dryhole
Shelf
South Timbalier 41
Caprock
60%
Low
Success
Shelf
Terrebonne Parish
Tigerbait
40%
Low
Success
Onshore
Eugene Island 21
#1
100%
High
Dryhole
Shelf
South Timbalier 214
#2
50%
High
Dryhole
Shelf
West Cameron 141
#1
100%
High
Dryhole
Shelf
ENERGY PARTNERS, LTD.
CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands, except per share data)
Three Months Ended
Year Ended
December 31,
December 31,
2007
2006
2007
2006
(Unaudited)
(Unaudited)
Revenues:
Oil and natural gas
$114,027
$111,592
$454,340
$449,186
Other
55
42
309
364
114,082
111,634
454,649
449,550
Costs and expenses:
Lease operating
16,692
14,092
69,919
58,808
Transportation expense
571
490
2,441
2,028
Exploration expenditures, dry hole costs and impairments
131,254
81,934
213,122
136,425
Depreciation, depletion and amortization
36,392
58,996
170,083
198,162
Accretion expense
1,128
1,322
4,458
4,572
General and administrative
13,357
26,919
61,724
120,113
Taxes, other than on earnings
2,452
2,684
9,900
13,632
Gain on insurance recoveries
–
–
(8,084
)
–
(Gain) loss on sale of assets
(505
)
–
(6,605
)
969
Other
401
1,478
2,788
3,053
Total costs and expenses
201,742
187,915
519,746
537,762
Business interruption recovery
–
1,293
9,084
32,869
Loss from operations
(87,660
)
(74,988
)
(56,013
)
(55,343
)
Other income (expense):
Interest income
799
348
1,585
1,428
Interest expense
(12,926
)
(7,380
)
(46,213
)
(24,570
)
Gain (loss) on derivative instruments
(14,805
)
–
(13,083
)
–
Loss on early extinguishment of debt
–
–
(10,838
)
–
(26,932
)
(7,032
)
(68,549
)
(23,142
)
Loss before income taxes
(114,592
)
(82,020
)
(124,562
)
(78,485
)
Income taxes
41,174
29,474
44,607
28,085
Net loss
(73,418
)
(52,546
)
(79,955
)
(50,400
)
Basic loss per share
$(2.31
)
$(1.35
)
$(2.32
)
$(1.32
)
Diluted loss per share
$(2.31
)
$(1.35
)
$(2.32
)
$(1.32
)
Weighted average common shares used in computing loss per share:
Basic
31,729
38,947
34,501
38,313
Incremental common shares
–
–
–
–
Diluted
31,729
38,947
34,501
38,313
Net loss available to common stockholders, as reported:
$(73,418
)
$(52,546
)
$(79,955
)
$(50,400
)
Add back:
Impact of property impairments on the periods presented
100,358
77,939
114,913
84,680
Impact of merger and acquisition costs on the periods presented
–
11,873
9,388
66,520
Deduct:
Impact of income taxes on impairments and merger and acquisition costs at a rate of 36%
(36,129
)
(32,332
)
(44,748
)
(54,432
)
Adjusted Non-GAAP net income (loss)
$(9,189
)
$4,934
$(402
)
$46,368
The table above reconciles net loss as reported to an adjusted non-GAAP amount and is provided as supplemental information, and should not be relied upon as alternative measures to GAAP. The Company’s management utilizes both the GAAP and the non-GAAP results, calculated above, to evaluate the Company’s performance and believes that comparative analysis of results can be enhanced by excluding the impact of the certain items. Management believes in certain cases, the Company’s GAAP results are not indicative of the Company’s operating performance for the applicable period, nor should they be considered in developing trend analysis for future periods. Specifically, the Company believes that it is useful to provide investors with information regarding the impact of mergers and acquisitions costs as well as property impairments on the periods presented because these items are not typical and are not expected to be reoccurring at these levels.
ENERGY PARTNERS, LTD.
CONSOLIDATED STATEMENTS OF NET CASH PROVIDED BY
OPERATING ACTIVITIES
(In thousands)
Three Months Ended
Year Ended
December 31,
December 31,
2007
2006
2007
2006
(Unaudited)
(Unaudited)
Cash flows from operating activities:
Net loss
$(73,418
)
$(52,546
)
$(79,955
)
$(50,400
)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion, amortization and accretion
37,520
60,318
174,541
202,734
(Gain) loss on disposal of assets and other
(491
)
550
(5,083
)
4,047
Non-cash compensation
1,785
3,070
8,521
11,038
Non-cash loss on early extinguishment of debt
–
–
3,398
–
Deferred income taxes
(41,174
)
(29,124
)
(44,607
)
(27,452
)
Exploration expenditures
129,241
80,341
202,015
122,449
Amortization of deferred financing costs
426
429
1,380
1,133
Unrealized (gain) loss on derivative contracts
14,141
–
13,726
–
Gain on insurance recoveries
–
–
(8,084
)
–
Other
636
392
1,927
1,587
Changes in operating assets and liabilities:
Trade accounts receivable
17,583
(1,582
)
23,542
2,390
Other receivables
1,863
35,111
58,269
(8,966
)
Prepaid expenses
785
(1,770
)
1,930
(391
)
Other assets
(909
)
(419
)
(2,529
)
283
Accounts payable and accrued expenses
(22,021
)
(8,977
)
(51,449
)
13,599
Other liabilities
(1,987
)
897
(3,653
)
23
Net cash provided by operating activities
$63,980
$86,690
$293,889
$272,074
Reconciliation of discretionary cash flow:
Net cash provided by operating activities
63,980
86,690
293,889
272,074
Changes in working capital
4,686
(23,260
)
(26,110
)
(6,938
)
Non-cash exploration expenditures
(129,241
)
(80,341
)
(202,015
)
(122,449
)
Total exploration expenditures
131,254
81,934
213,122
136,425
Discretionary cash flow
$70,679
$65,023
$278,886
$279,112
The table above reconciles discretionary cash flow to net cash provided by operating activities. Discretionary cash flow is defined as cash flow from operations before changes in working capital and exploration expenditures. Discretionary cash flow is widely accepted as a financial indicator of an oil and natural gas company’s ability to generate cash which is used to internally fund exploration and development activities, pay dividends and service debt. Discretionary cash flow is presented based on management’s belief that this non-GAAP financial measure is useful information to investors because it is widely used by professional research analysts in the valuation, comparison, rating and investment recommendations of companies within the oil and natural gas exploration and production industry. Many investors use the published research of these analysts in making their investment decisions. Discretionary cash flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income. Investors should be cautioned that discretionary cash flow as reported by us may not be comparable in all instances to discretionary cash flow as reported by other companies.
ENERGY PARTNERS, LTD.
SELECTED PRODUCTION, PRICING AND OPERATIONAL STATISTICS
(Unaudited)
Three Months Ended
Year Ended
December 31,
December 31,
2007
2006
2007
2006
PRODUCTION AND PRICING
Net Production (per day):
Oil (Bbls)
8,489
9,465
8,769
8,238
Natural gas (Mcf)
73,904
105,687
92,167
106,042
Total (Boe)
20,806
27,080
24,130
25,912
Average Sales Prices, excluding derivatives:
Oil (per Bbl)
$84.44
$53.64
$66.78
$59.78
Natural gas (per Mcf)
7.07
6.64
7.15
6.98
Average (per Boe)
59.57
44.68
51.59
47.57
Impact of derivatives(1):
Oil (per Bbl)
$(16.32
)
$-
$(5.11
)
$-
Natural gas (per Mcf)
(0.28
)
0.03
0.09
(0.02
)
Oil and Natural Gas Revenues (in thousands):
Oil
$65,949
$46,705
$213,751
$179,752
Natural gas
48,078
64,887
240,589
269,434
Total
114,027
111,592
454,340
449,186
OPERATIONAL STATISTICS
Average Costs (per Boe):
Lease operating expense
$8.72
$5.66
$7.94
$6.22
Depreciation, depletion and amortization
19.01
23.68
19.31
20.95
Accretion expense
0.59
0.53
0.51
0.48
Taxes, other than on earnings
1.28
1.08
1.12
1.44
General and administrative
6.98
10.80
7.01
12.70
(1) The 2007 derivative amounts are included in Other income (expense) in the statement of operations and represents the current fair value of future settlements.
ENERGY PARTNERS, LTD.
CONSOLIDATED BALANCE SHEETS
(In thousands, except share data)
December 31,
December 31,
2007
2006
(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents
$8,864
$3,214
Trade accounts receivable
52,139
74,132
Other receivables
–
58,269
Deferred tax asset
3,865
1,387
Prepaid expenses
1,640
3,570
Total current assets
66,508
140,572
Property and equipment, at cost under the successful efforts method of accounting for oil and natural gas properties
1,547,003
1,527,304
Less accumulated depreciation, depletion and amortization
(824,397
)
(680,845
)
Net property and equipment
722,606
846,459
Other assets
15,556
13,029
Deferred financing costs — net of accumulated amortization
10,186
3,785
$814,856
$1,003,845
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable
$14,369
$47,154
Accrued expenses
104,555
133,198
Fair value of commodity derivative instruments
9,124
1,552
Total current liabilities
128,048
181,904
Long-term debt
484,501
317,000
Deferred income taxes
20,880
62,451
Asset retirement obligation
73,350
68,767
Fair value of commodity derivative instruments
4,602
–
Other
1,505
1,453
712,886
631,575
Stockholders’ equity:
Preferred stock, $1 par value. Authorized 1,700,000 shares; no shares issued and outstanding
–
–
Common stock, par value $0.01 per share. Authorized 100,000,000 shares; issued and outstanding: 2007 — 43,980,644 shares; 2006 — 42,501,726 shares
441
425
Additional paid-in capital
374,874
365,313
Accumulated other comprehensive loss
–
(994
)
Retained earnings (accumulated deficit)
(14,989
)
64,966
Treasury stock, at cost. 2007 — 12,239,986 shares; 2006 — 3,479,814 shares
(258,356
)
(57,440
)
Total stockholders’ equity
101,970
372,270
Commitments and contingencies
$814,856
$1,003,845
ENERGY PARTNERS, LTD.
SUPPLEMENTAL OIL & GAS DISCLOSURE
(Unaudited)
Crude Oil
Natural Gas
Equivalents
(Mbbl)
(Mmcf)
(Mboe)
Proved developed and undeveloped reserves:
December 31, 2004
28,770
149,835
53,743
Purchases of reserves in place
3,949
52,690
12,731
Extensions, discoveries and other additions
1,086
24,490
5,168
Revisions
587
(27,789
)
(4,045
)
Production
(2,914
)
(32,277
)
(8,294
)
December 31, 2005
31,478
166,949
59,303
Sales of reserves in place
(129
)
(750
)
(254
)
Extensions, discoveries and other additions
1,057
44,336
8,446
Revisions
515
(1,704
)
231
Production
(3,007
)
(38,708
)
(9,458
)
December 31, 2006
29,914
170,123
58,268
Sales of reserves in place
(363
)
(10,214
)
(2,066
)
Purchases of reserves in place
46
3,628
651
Extensions, discoveries and other additions
469
12,361
2,529
Revisions
1,258
(39,139
)
(5,265
)
Production
(3,201
)
(33,641
)
(8,808
)
December 31, 2007
28,123
103,118
45,309
Proved developed reserves:
December 31, 2005
25,646
103,627
42,917
December 31, 2006
24,811
117,392
44,376
December 31, 2007
23,636
85,926
37,957
Costs incurred for oil and natural gas property acquisition, exploration and development activities for the three-years ended December 31 are as follows (in Thousands):
2007
2006
2005
Acquisitions:
Proved
2,167
420
142,025
Unproved
7,346
15,896
56,955
Exploration
191,621
224,147
171,859
Development
116,122
158,837
107,910
Total finding and development costs
307,743
382,984
279,769
Total finding, development and acquisition costs
317,256
399,300
478,749
Asset retirement liabilities incurred
4,409
5,947
7,151
Asset retirement revisions
1,238
2,562
(247
)
Total cost incurred
$322,903
$407,809
$485,653