PDC Energy Announces 2017 Full-Year and Fourth Quarter Operating and Financial Results Including Year-Over-Year Oil Production Increase of 48 Percent
February 26, 2018 - 4:45 PM EST
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PDC Energy Announces 2017 Full-Year and Fourth Quarter Operating and Financial Results Including Year-Over-Year Oil Production Increase of 48 Percent
DENVER, Feb. 26, 2018 (GLOBE NEWSWIRE) -- PDC Energy, Inc. ("PDC" or the "Company") (NASDAQ:PDCE) today reported its 2017 full-year and fourth quarter operating and financial results.
2017 Highlights
Year-over-year production increase of 44 percent to 31.8 million barrels of oil equivalent (MMBoe) or approximately 87,200 Boe per day with a December exit rate of approximately 97,000 Boe per day.
Oil production of 12.9 million barrels (MMBbls), representing 41 percent of total production.
Increase in proved reserves of 33 percent to 453 MMBoe, with all-sources reserve replacement of approximately 450 percent, driven primarily through an increase in Delaware Basin proved reserves to nearly 100 MMBoe.
Strategically created three consolidated development positions in the Wattenberg Field through the acquisition of approximately 7,400 net acres and closings of two significant acreage exchanges.
Full-year capital investments of approximately $790 million with a year-end leverage ratio, as defined by the Company’s revolving credit agreement, of 1.9 times.
Net cash from operating activities of approximately $590 million, a 21 percent increase compared to 2016 levels of approximately $485 million.
Year-end liquidity of $881 million, including $181 million of cash and cash equivalents as of December 31, 2017. Liquidity, pro forma for the January 2018 acquisition of Bayswater Exploration and Production, LLC (“Bayswater Acquisition”) closing, was approximately $700 million.
Successfully issued $600 million of 5.75% senior notes due 2026, the proceeds of which were used to redeem $500 million of 7.75% senior notes due 2022, partially fund the Bayswater Acquisition and for general corporate purposes.
CEO Commentary
President and Chief Executive Officer, Bart Brookman commented, “The fourth quarter was a great way for us to end another extremely successful year, while also serving as a spring board into 2018. Our Delaware Basin team continues to improve our operational execution and build positive momentum. This is highlighted by improvements in our drill times, our ability to deliver truly impressive well results and strong production growth for numerous quarters. In Wattenberg, our team anxiously awaits the upcoming midstream expansion and the opportunity to unbundle our production.”
“In 2018, we are once again focused on delivering tremendous returns to our shareholders with development in two of the most economic plays in the industry. Financially, the Company expects to operate in a cash flow positive environment in the second half of the year while simultaneously expecting to improve our leverage ratio to approximately 1.4 times by year-end.”
Operations Update
Production for 2017 was 31.8 MMBoe, or approximately 87,200 Boe per day, an increase of 44 percent from 2016. Oil production of 12.9 MMBbls in 2017 represents 41 percent of total production and was an increase of 48 percent compared to 2016 volumes. In the fourth quarter of 2017, production was approximately 8.7 MMBoe, an increase of 35 percent from the fourth quarter of 2016 and two percent from the third quarter of 2017. Oil production in the fourth quarter of 2017 was 3.7 MMBbls, representing 43 percent of total production and an increase of nearly 50 percent compared to the fourth quarter of 2016. The Company's capital investment in the development of oil and natural gas properties and other capital expenditures, before the change in accounts payable, was approximately $790 million and $170 million for the full-year and fourth quarter of 2017, respectively.
In Wattenberg, the Company spud and turned-in-line 153 and 130 wells in 2017, including 34 and 19 spuds and turn-in-lines in the fourth quarter of 2017. The Company is consistently drilling and completing wells while continuing to work closely with its primary third-party midstream gas processor in the basin.
In the Delaware Basin, the Company turned-in-line five wells in the fourth quarter of 2017 in its Eastern Area, including the three-well Grizzly pad, consisting of one extended-reach lateral Wolfcamp A well, one extended-reach lateral Wolfcamp B well and one standard-reach lateral Wolfcamp B well. Early performance has been extremely encouraging from all three wells, with an average 30-day initial peak production rate of approximately 255 Boe per day per thousand feet, including approximately 73% crude oil.
2018 Capital Investment Outlook, Financial Guidance and Transactions Update
In 2018, the Company anticipates capital investments between $850 million and $920 million to deliver total production of 38 to 42 MMBoe, or approximately 104,000 to 115,000 Boe per day. PDC’s guidance now includes an improvement in Delaware drill times, resulting in additional planned spuds and turn-in-lines in the basin, as well as the external January 2018 announcement relating to the in-service date of major gas takeaway infrastructure of its primary Wattenberg midstream service provider. Production for the first quarter of 2018 is expected to be relatively flat compared to the fourth quarter of 2017, with larger sequential growth anticipated in the second through fourth quarters, culminating in a December exit rate of approximately 130,000 Boe per day. The Company now anticipates its 2018 commodity mix to include 42 to 45 percent crude oil, 19 to 22 percent NGLs and 32 to 35 percent natural gas.
Additionally, the Company has updated its internal commodity price forecast in an effort to more accurately reflect the current pricing environment. Assuming annual NYMEX pricing averaging approximately $57.50 per barrel oil and $3.00 per MMBtu natural gas, the Company’s anticipates its 2018 capital investments will exceed its 2018 adjusted cash flows from operations by less than $90 million. The Company anticipates it will outspend adjusted cash flows from operations in the first half of the year, while operating in a cash flow positive environment in the second half. PDC currently expects to exit 2018 with a leverage ratio, as defined by its revolving credit facility, of 1.4 times.
In February 2018, the Company entered into a definitive purchase and sale agreement for the sale of its Utica Shale assets for total net proceeds of approximately $40 million. The transaction is expected to close late in the first quarter of 2018. Additionally, the Company received approximately $24 million in January 2018 in relation to an extension and modification of a Wattenberg pipeline commitment. When considering the total proceeds of approximately $64 million, or roughly two-thirds of its projected outspend, the Company anticipates exiting 2018 minimally drawn on its revolving credit facility.
The following table provides projected 2018 financial guidance:
Production taxes (% of Crude oil, natural gas & NGLs sales)
6%
8%
General and administrative expense ($/Boe)
$
3.40
$
3.70
Estimated Price Realizations (% of NYMEX) (excludes TGP)
Crude Oil
91%
95%
Natural Gas
55%
60%
NGLs
30%
35%
Estimated 2018 price realizations and TGP include adjustments made due to a new revenue recognition accounting standard adopted on January 1, 2018. This adjustment results in certain TGP being reclassified as a reduction in sales price, with no change to the net realized price. Had these changes been adopted at January 1, 2017, PDC estimates its 2017 average realization percentages, excluding TGP, would have been 94 percent, 70 percent and 36 percent for crude oil, natural gas and NGLs.
Oil and Gas Production, Sales and Operating Cost Data
Crude oil, natural gas and NGLs sales, excluding net settlements on derivatives, increased 84% to $913.1 million in 2017, compared to $497.4 million in 2016. The increase in sales was due to a 44% increase in total production and an increase in the sales price per Boe, excluding net settlements on derivatives, of 28% to $28.69 in 2017 from $22.43 in 2016. Including the impact of commodity price risk management, revenues increased 140% to $921.6 million in 2017 from $382.9 million in 2016.
In the fourth quarter of 2017, crude oil, natural gas and NGLs sales were $277.1 million, compared to $169.3 million in the fourth quarter of 2016. The average sales price, excluding net settlements on derivatives, improved to $32.00 per Boe for the fourth quarter of 2017, compared to $26.44 per Boe for the same 2016 period.
The following table provides production and weighted-average sales price, by area, for the three and twelve months ended December 31, 2017 and 2016, excluding net settlements on derivatives and TGP:
Three Months Ended December 31,
Twelve Months Ended December 31,
2017
2016
Percent
2017
2016
Percent
Crude oil (MBbls)
Wattenberg Field
3,039
2,301
32.1
%
10,922
8,230
32.7
%
Delaware Basin
624
80
*
1,699
79
*
Utica Shale
55
107
(48.6
)%
281
419
(32.9
)%
Total
3,718
2,488
49.4
%
12,902
8,728
47.8
%
Weighted-Average Sales Price
$
52.79
$
46.54
13.4
%
$
48.45
$
39.96
21.2
%
Natural gas (MMcf)
Wattenberg Field
15,412
13,921
10.7
%
60,106
48,889
22.9
%
Delaware Basin
3,358
373
*
9,410
373
*
Utica Shale
482
668
(27.8
)%
2,173
2,468
(12.0
)%
Total
19,252
14,962
28.7
%
71,689
51,730
38.6
%
Weighted-Average Sales Price
$
2.16
$
2.14
0.9
%
$
2.21
$
1.77
24.9
%
NGLs (MBbls)
Wattenberg Field
1,403
1,327
5.7
%
5,876
4,568
28.6
%
Delaware Basin
292
36
*
917
36
*
Utica Shale
37
60
(38.3
)%
188
222
(15.3
)%
Total
1,732
1,423
21.7
%
6,981
4,826
44.7
%
Weighted-Average Sales Price
$
22.68
$
15.11
50.1
%
$
18.59
$
11.80
57.5
%
Crude oil equivalent (MBoe)
Wattenberg Field
7,010
5,948
17.9
%
26,815
20,945
28.0
%
Delaware Basin
1,475
178
*
4,184
178
*
Utica Shale
173
279
(38.0
)%
831
1,053
(21.1
)%
Total
8,658
6,405
35.2
%
31,830
22,176
43.5
%
Weighted-Average Sales Price
$
32.00
$
26.44
21.0
%
$
28.69
$
22.43
27.9
%
Production costs for 2017, which include LOE, production taxes and TGP, were $183.5 million, or $5.77 per Boe, compared to $109.8 million, or $4.95 per Boe, for 2016. LOE per Boe was $2.82 for 2017 compared to $2.70 per Boe in 2016. The increase in LOE per Boe is primarily due to expected higher LOE costs related to Delaware Basin operations compared to other properties. In the fourth quarter of 2017, production costs were $53.3 million, or $6.15 per Boe, compared to $33.5 million or $5.24 per Boe in the comparable 2016 period.
The following table provides the components of production costs for the three and twelve months ended December 31, 2017 and 2016:
Three Months Ended December 31,
Twelve Months Ended December 31,
2017
2016
2017
2016
Lease operating expenses
$
24.5
$
16.9
$
89.6
$
60.0
Production taxes
17.8
11.7
60.7
31.4
Transportation, gathering and processing expenses
11.0
4.9
33.2
18.4
Total
$
53.3
$
33.5
$
183.5
$
109.8
Three Months Ended December 31,
Twelve Months Ended December 31,
2017
2016
2017
2016
Lease operating expenses per Boe
$
2.83
$
2.65
$
2.82
$
2.70
Production taxes per Boe
2.05
1.83
1.91
1.42
Transportation, gathering and processing expenses per Boe
1.27
0.76
1.04
0.83
Total per Boe
$
6.15
$
5.24
$
5.77
$
4.95
Financial Results and Liquidity
Net loss for 2017 was $127.5 million, or $1.94 per diluted share, compared to net loss of $245.9 million, or $5.01 per diluted share, for 2016. The year-over-year difference was primarily attributable to the increase in revenues between periods outweighing the increase in expenses despite inclusion of an impairment of properties and equipment of $285.9 million, as well as an income tax benefit of $114.4 million due to a decrease in deferred tax assets and liabilities related to tax reform legislation passed in 2017. Adjusted net loss, a non-GAAP financial measure defined below, was $114.4 million, or $1.74 per diluted share in 2017 compared to $37.0 million, or $0.75 per diluted share in 2016. Net income for the fourth quarter of 2017 was $77.6 million, or $1.17 per diluted share, and includes the aforementioned income tax benefit of $114.4 million. Net loss in the fourth quarter of 2016 was $55.6 million, or $0.94 per diluted share. Adjusted net income for the fourth quarter of 2017 was $130.9 million, or $1.98 per diluted share, compared to $10.6 million, or $0.18 per diluted share for the same 2016 period.
Net cash from operating activities was $588.6 million for 2017, compared to $486.3 million for 2016. Adjusted cash flows from operations, a non-GAAP financial measure defined below, were $582.1 million for 2017, compared to $466.8 million in 2016. Net cash from operating activities in the fourth quarter of 2017 was $177.2 million compared to $125.4 million in the fourth quarter of 2016. Adjusted cash flows from operations were $174.6 million for the fourth quarter of 2017, compared to $140.5 million in the same 2016 period. The increase in cash flows between comparable periods was a result of more production volumes coupled with a higher average oil prices as compared to the respective year and quarter.
PDC's available liquidity as of December 31, 2017 was approximately $881 million, compared to approximately $932 million as of December 31, 2016. In October 2017, the Company elected to increase its borrowing base on its revolving credit facility from $1.0 billion to $1.1 billion. The Company maintained its elected commitment level of $700 million.
Non-GAAP Financial Measures
PDC uses "adjusted cash flows from operations," "adjusted net income (loss)" and "adjusted EBITDAX," non-U.S. GAAP financial measures, for internal management reporting, when evaluating period-to-period changes and, in some cases, providing public guidance on possible future results. Beginning in 2017, PDC included non-cash stock-based compensation and exploration, geologic and geophysical expense in our reconciliation of adjusted EBITDAX calculation. In prior periods, PDC disclosed adjusted EBITDA, a non-U.S. GAAP financial measure that did not include these adjustments. The Company have elected to disclose Adjusted EBITDAX rather than Adjusted EBITDA in this report and other public disclosures because we believe it is more comparable to similar metrics presented by others in the industry. All prior periods have been conformed for comparability of this information. These measures are not measures of financial performance under U.S. GAAP and should be considered in addition to, not as a substitute for, net income (loss) or cash flows from operations, investing or financing activities, and should not be viewed as liquidity measures or indicators of cash flows reported in accordance with U.S. GAAP. The non-U.S. GAAP financial measures that we use may not be comparable to similarly titled measures reported by other companies. Also, in the future, PDC may disclose different non-U.S. GAAP financial measures in order to help investors more meaningfully evaluate and compare future results of operations to previously reported results of operations. PDC strongly encourages investors to review our financial statements and publicly filed reports in their entirety and not rely on any single financial measure.
The following three tables provide reconciliations of adjusted cash flows from operations, adjusted net income (loss) and adjusted EBITDAX to their most comparable U.S. GAAP measures (in millions, except per share data):
Adjusted Cash Flows from Operations
Three Months Ended December 31,
Twelve Months Ended December 31,
2017
2016
2017
2016
Adjusted cash flows from operations:
Net cash from operating activities
$
177.2
$
125.4
$
588.6
$
486.3
Changes in assets and liabilities
(2.6
)
15.1
(6.5
)
(19.5
)
Adjusted cash flows from operations
$
174.6
$
140.5
$
582.1
$
466.8
Adjusted Net Income (Loss)
Three Months Ended December 31,
Twelve Months Ended December 31,
2017
2016
2017
2016
Adjusted net income (loss):
Net income (loss)
$
77.6
$
(55.6
)
$
(127.5
)
$
(245.9
)
Loss on commodity derivative instruments
90.4
63.3
3.9
125.7
Net settlements on commodity derivative instruments
(8.9
)
40.2
13.3
208.1
Tax effect of above adjustments
(28.2
)
(37.3
)
(4.1
)
(124.9
)
Adjusted net income (loss)
$
130.9
$
10.6
$
(114.4
)
$
(37.0
)
Weighted-average diluted shares outstanding
66.1
58.9
65.8
49.1
Adjusted diluted earnings per share
$
1.98
$
0.18
$
(1.74
)
$
(0.75
)
Adjusted EBITDAX
Three Months Ended December 31,
Twelve Months Ended December 31,
2017
2016
2017
2016
Net income (loss) to adjusted EBITDAX:
Net income (loss)
$
77.6
$
(55.6
)
$
(127.5
)
$
(245.9
)
Loss on commodity derivative instruments
90.4
63.3
3.9
125.7
Net settlements on commodity derivative instruments
(8.9
)
40.2
13.3
208.1
Non-cash stock-based compensation
4.8
4.3
19.4
19.5
Interest expense, net
19.6
20.1
76.4
61.0
Income tax benefit
(140.4
)
(35.0
)
(211.9
)
(147.2
)
Impairment of properties and equipment
3.4
3.9
285.9
10.0
Impairment of goodwill
—
—
75.1
—
Exploration, geologic, and geophysical expense
3.4
4.0
47.3
4.7
Depreciation, depletion, and amortization
108.5
99.5
469.1
416.9
Accretion of asset retirement obligations
1.4
1.7
6.4
7.0
Loss on extinguishment of debt
24.7
—
24.7
—
Adjusted EBITDAX
$
184.5
$
146.4
$
682.1
$
459.8
Cash from operating activities to adjusted EBITDAX:
Net cash from operating activities
$
177.2
$
125.4
$
588.6
$
486.3
Interest expense, net
19.6
20.1
76.4
61.0
Amortization of debt discount and issuance costs
(3.3
)
(3.2
)
(12.9
)
(16.2
)
Gain on sale of properties and equipment
—
—
0.7
—
Exploration, geologic, and geophysical expense
3.4
4.0
47.3
4.7
Exploratory dry hole expense
(0.1
)
—
(41.3
)
—
Other
(9.7
)
(15.0
)
29.8
(56.5
)
Changes in assets and liabilities
(2.6
)
15.1
(6.5
)
(19.5
)
Adjusted EBITDAX
$
184.5
$
146.4
$
682.1
$
459.8
PDC ENERGY, INC. Consolidated Statements of Operations (unaudited, in thousands, except per share data)
Three Months Ended December 31,
Twelve Months Ended December 31,
2017
2016
2017
2016
Revenues
Crude oil, natural gas, and NGLs sales
$
277,057
$
169,340
$
913,084
$
497,353
Commodity price risk management gain (loss), net
(90,394
)
(63,333
)
(3,936
)
(125,681
)
Other income
2,853
2,090
12,468
11,243
Total revenues
189,516
108,097
921,616
382,915
Costs, expenses and other
Lease operating expenses
24,471
16,944
89,641
59,950
Production taxes
17,760
11,728
60,717
31,410
Transportation, gathering, and processing expenses
11,036
4,861
33,220
18,415
Exploration, geologic, and geophysical expense
3,439
3,981
47,334
4,669
Impairment of properties and equipment
3,388
3,869
285,887
9,973
Impairment of goodwill
—
—
75,121
—
General and administrative expense
35,225
33,602
120,370
112,470
Depreciation, depletion and amortization
108,517
99,545
469,084
416,874
Provision for uncollectible notes receivable
—
—
(40,203
)
44,038
Accretion of asset retirement obligations
1,400
1,680
6,306
7,080
Gain on sale of properties and equipment
(12
)
—
(766
)
(43
)
Other expenses
2,792
2,398
13,157
10,193
Total costs, expenses and other
208,016
178,608
1,159,868
715,029
Loss from operations
(18,500
)
(70,511
)
(238,252
)
(332,114
)
Loss on extinguishment of debt
(24,747
)
—
(24,747
)
—
Interest expense
(20,335
)
(19,213
)
(78,694
)
(61,972
)
Interest income
774
(912
)
2,261
963
Loss before income taxes
(62,808
)
(90,636
)
(339,432
)
(393,123
)
Income tax benefit
140,445
34,997
211,928
147,195
Net income (loss)
$
77,637
$
(55,639
)
$
(127,504
)
$
(245,928
)
Earnings per share:
Basic
$
1.18
$
(0.94
)
$
(1.94
)
$
(5.01
)
Diluted
$
1.17
$
(0.94
)
$
(1.94
)
$
(5.01
)
Weighted-average common shares outstanding:
Basic
65,875
58,914
65,837
49,052
Diluted
66,085
58,914
65,837
49,052
PDC ENERGY, INC. Consolidated Balance Sheets (unaudited, in thousands)
December 31, 2017
December 31, 2016
Assets
Current assets:
Cash and cash equivalents
$
180,675
$
244,100
Accounts receivable, net
197,598
143,392
Fair value of derivatives
14,338
8,791
Prepaid expenses and other current assets
8,613
3,542
Total current assets
401,224
399,825
Properties and equipment, net
3,933,467
4,002,994
Assets held-for-sale, net
40,084
5,272
Fair value of derivatives
—
2,386
Goodwill
—
62,041
Other assets
45,116
13,324
Total Assets
$
4,419,891
$
4,485,842
Liabilities and Stockholders' Equity
Liabilities
Current liabilities:
Accounts payable
$
150,067
$
66,322
Production tax liability
37,654
24,767
Fair value of derivatives
79,302
53,595
Funds held for distribution
95,811
71,339
Accrued interest payable
11,815
15,930
Other accrued expenses
42,987
38,625
Total current liabilities
417,636
270,578
Long-term debt
1,151,932
1,043,954
Deferred income taxes
191,992
400,867
Asset retirement obligations
71,006
82,612
Fair value of derivatives
22,343
27,595
Other liabilities
57,333
37,482
Total liabilities
1,912,242
1,863,088
Commitments and contingent liabilities
Stockholders' equity
Common shares - par value $0.01 per share, 150,000,000 authorized, 65,955,080 and 65,704,568 issued as of December 31, 2017 and December 31, 2016, respectively
659
657
Additional paid-in capital
2,503,294
2,489,557
Retained earnings
6,704
134,208
Treasury shares - at cost, 55,927 and 28,763 as of December 31, 2017 and December 31, 2016, respectively
(3,008
)
(1,668
)
Total stockholders' equity
2,507,649
2,622,754
Total Liabilities and Stockholders' Equity
$
4,419,891
$
4,485,842
PDC ENERGY, INC. Consolidated Statements of Cash Flows (unaudited, in thousands)
Three Months Ended December 31,
Twelve Months Ended December 31,
2017
2016
2017
2016
Cash flows from operating activities:
Net income (loss)
$
77,637
$
(55,639
)
$
(127,504
)
$
(245,928
)
Adjustments to net income (loss) to reconcile to net cash from operating activities:
Net change in fair value of unsettled commodity derivatives
81,567
103,593
17,260
333,770
Depreciation, depletion and amortization
108,517
99,545
469,084
416,874
Provision for uncollectible notes receivable
—
—
(40,203
)
44,038
Impairment of properties and equipment
3,388
3,869
285,887
9,973
Impairment of goodwill
—
—
75,121
—
Exploratory dry hole costs
110
—
41,297
—
Loss on extinguishment of debt
24,747
—
24,747
—
Accretion of asset retirement obligations
1,400
1,680
6,306
7,080
Non-cash stock-based compensation
4,766
4,297
19,353
19,502
Gain on sale of properties and equipment
(12
)
—
(766
)
(43
)
Amortization of debt discount and issuance costs
3,279
3,216
12,907
16,167
Deferred income taxes
(132,156
)
(23,113
)
(203,685
)
(137,249
)
Other
1,279
3,129
2,265
2,603
Changes in assets and liabilities
2,639
(15,145
)
6,494
19,476
Net cash from operating activities
177,161
125,432
588,563
486,263
Cash flows from investing activities:
Capital expenditures for development of crude oil and natural gas properties
(208,358
)
(84,671
)
(737,208
)
(436,884
)
Capital expenditures for other properties and equipment
(1,354
)
(1,955
)
(5,094
)
(3,464
)
Acquisition of crude oil and natural gas properties, including settlement adjustments and deposit for pending acquisition
(1,146
)
(973,723
)
(15,628
)
(1,073,723
)
Proceeds from sale of properties and equipment
6,669
—
9,991
4,945
Sale of promissory note
—
—
40,203
—
Restricted cash
—
—
(9,250
)
—
Sale of short-term investments
—
—
49,890
—
Purchases of short-term investments
—
—
(49,890
)
—
Net cash from investing activities
(204,189
)
(1,060,349
)
(716,986
)
(1,509,126
)
Cash flows from financing activities:
Proceeds from issuance of equity, net of issuance costs
—
—
—
855,074
Proceeds from issuance of senior notes
592,366
—
592,366
392,172
Proceeds from issuance of convertible senior notes
—
—
—
193,935
Proceeds from revolving credit facility
—
—
—
85,000
Repayment of revolving credit facility
—
—
—
(122,000
)
Redemption of senior notes
(519,375
)
—
(519,375
)
—
Redemption of convertible notes
—
—
—
(115,000
)
Payment of debt issuance costs
(50
)
(15,502
)
(50
)
(15,556
)
Purchase of treasury shares
(1,348
)
(1,829
)
(6,672
)
(6,935
)
Other
(319
)
(1,344
)
(1,271
)
(577
)
Net cash from financing activities
71,274
(18,675
)
64,998
1,266,113
Net change in cash and cash equivalents
44,246
(953,592
)
(63,425
)
243,250
Cash and cash equivalents, beginning of period
136,429
1,197,692
244,100
850
Cash and cash equivalents, end of period
$
180,675
$
244,100
$
180,675
$
244,100
2017 Year-End and Fourth Quarter Teleconference and Webcast
The Company invites you to join Bart Brookman, President and Chief Executive Officer; Scott Meyers, Chief Financial Officer; Lance Lauck, Executive Vice President Corporate Development and Strategy; and Scott Reasoner, Senior Vice President Chief Operating Officer, for a conference call on Tuesday, February 27, 2018, to discuss its 2017 year-end and fourth quarter results. The related slide presentation will be available on PDC's website at www.pdce.com.
Conference Call and Webcast: Date/Time: Tuesday, February 27, 2018, 11:00 a.m. ET Webcast available at: www.pdce.com Domestic (toll free): 877-312-5520 International: 253-237-1142 Conference ID: 1897819
The replay of the call will be available for six months on PDC's website at www.pdce.com.
Upcoming Investor Presentations
PDC is scheduled to present at the following conferences: Scotia Howard Weil Energy Conference in New Orleans on Wednesday, March 28, 2018 and IPAA New York on Monday, April 9, 2018. Webcast information will be posted to the Company’s website, www.pdce.com, prior to the start of each conference, along with any presentation materials.
About PDC Energy, Inc.
PDC Energy, Inc. is a domestic independent exploration and production company that acquires, produces, develops, and explores for crude oil, natural gas and NGLs with operations in the Wattenberg Field in Colorado, in the Delaware Basin in West Texas. Its operations are focused on the liquid-rich horizontal Niobrara and Codell plays in the Wattenberg Field, the liquid-rich Wolfcamp zones in the Delaware Basin.
NOTE REGARDING FORWARD-LOOKING STATEMENTS
This press release contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 ("Securities Act") and Section 21E of the Securities Exchange Act of 1934 ("Exchange Act") regarding PDC’s business, financial condition, results of operations, and prospects. All statements other than statements of historical facts included in this press release are "forward-looking statements" within the meaning of the safe harbor provisions of the United States ("U.S.") Private Securities Litigation Reform Act of 1995. Words such as expect, anticipate, intend, plan, believe, seek, estimate and similar expressions or variations of such words are intended to identify forward-looking statements herein. Forward-looking statements include, among other things, statements regarding future: reserves, production, costs, cash flows and earnings; drilling locations and zones and growth opportunities; capital expenditures and projects, including expected lateral lengths of wells, drill times and number of rigs employed; rates of return; operational enhancements and efficiencies; management of lease expiration issues; financial ratios; our anticipated sale of our Utica assets; certain accounting and tax change impacts; midstream capacity and related curtailments; and the closing of pending, and the nature of future, transactions.
The above statements are not the exclusive means of identifying forward-looking statements herein. Although forward-looking statements contained in this report reflect PDC’s good faith judgment, such statements can only be based on facts and factors currently known. Forward-looking statements are always subject to risks and uncertainties, and become subject to greater levels of risk and uncertainty as they address matters further into the future. Throughout this press release or accompanying materials, PDC may use the terms “projection” or similar terms or expressions, or indicate that it has “modeled” certain future scenarios. PDC typically use these terms to indicate current thoughts on possible outcomes relating to our business or the industry in periods beyond the current fiscal year. Because such statements relate to events or conditions further in the future, they are subject to increased levels of uncertainty.
Important factors that could cause actual results to differ materially from the forward-looking statements include, but are not limited to:
changes in worldwide production volumes and demand, including economic conditions that might impact demand and prices for products produced;
volatility of commodity prices for crude oil, natural gas, and natural gas liquids ("NGLs") and the risk of an extended period of depressed prices;
reductions in the borrowing base under the revolving credit facility;
impact of governmental policies and/or regulations, including changes in environmental and other laws,
the interpretation and enforcement related to those laws and regulations, liabilities arising thereunder, and the costs to comply with those laws and regulations;
declines in the value of crude oil, natural gas, and NGLs properties resulting in further impairments;
changes in estimates of proved reserves;
inaccuracy of estimated reserves and production rates;
production decline rates from wells being greater than expected;
timing and extent of our success in discovering, acquiring, developing, and producing reserves;
availability of sufficient pipeline, gathering and other transportation facilities and related infrastructure to process and transport production and the impact of these facilities and regional capacity on the prices received for production;
timing and receipt of necessary regulatory permits;
risks incidental to the drilling and operation of crude oil and natural gas wells;
losses from PDC’s gas marketing business exceeding expectations;
difficulties in integrating operations as a result of any significant acquisitions and acreage exchanges;
increases or changes in expenses;
availability of supplies, materials, contractors, and services that may delay the drilling or completion of wells;
potential losses of acreage or zones due to partial or complete lease expirations or otherwise;
increases or adverse changes in construction costs and procurement costs associated with future build out of midstream related assets;
future cash flows, liquidity, and financial condition;
possibility that the sale of the Utica Shale properties will not close as expected;
competition within the oil and gas industry;
availability and cost of capital;
success in marketing crude oil, natural gas, and NGLs;
effect of crude oil and natural gas derivatives activities;
impact of environmental events, governmental and other third-party responses to such events, and PDC’s ability to insure adequately against such events;
cost of pending or future litigation;
effect that acquisitions PDC may pursue have on its capital requirements;
ability to retain or attract senior management and key technical employees; and
success of strategic plans, expectations and objectives for future operations.
Further, PDC urges you to carefully review and consider the cautionary statements and disclosures, specifically those under Item 1A, Risk Factors, made in this press release and our other filings with the U.S. Securities and Exchange Commission ("SEC") for further information on risks and uncertainties that could affect PDC’s business, financial condition, results of operations and cash flows. The Company cautions you not to place undue reliance on forward-looking statements, which speak only as of the date of this press release. PDC undertakes no obligation to update any forward-looking statements in order to reflect any event or circumstance occurring after the date of this report or currently unknown facts or conditions or the occurrence of unanticipated events. All forward-looking statements are qualified in their entirety by this cautionarystatement.
Contacts: Michael Edwards Senior Director Investor Relations 303-860-5820 michael.edwards@pdce.com
