August 7, 2019 - 4:30 PM EDT
Print Email Article Font Down Font Up Charts

PDC Energy Announces 2019 Second Quarter Results, Decreases Full-Year Capital Investment Guidance and Increases Full-Year Production Range

DENVER, Aug. 07, 2019 (GLOBE NEWSWIRE) -- PDC Energy, Inc. ("PDC" or the "Company") (NASDAQ: PDCE) today reported its 2019 second quarter operating and financial results while announcing improvements to its 2019 capital efficiency by reducing its full-year capital investment guidance and increasing its full-year production guidance.   

Company Highlights:

  • Lowered full-year capital investment guidance to a range of $810 to $840 million from $810 to $870 million, which includes reducing the Wattenberg rig count from three to two in September.
  • Reduced corporate headcount in June by approximately 15 percent to more closely align with the updated operational plan, contributing to second half projected 2019 G&A expense between $2.60 and $2.80 per Boe.
  • Increased full-year production to a range of 48 to 50 MMBoe, reflecting the benefit of increased operational efficiencies in both basins driving increased production in the first half of the year.
  • Returned $125 million to shareholders through July with the repurchase of approximately 3.7 million shares via the previously announced $200 million stock repurchase program.  
  • Received approximately $264 million of cash in the second quarter from closing of all three Delaware midstream sales. An additional unconditional payment of $82 million is due June 2020.
  • Received nearly $35 million through the sale of approximately 6,500 net Delaware acres that were scheduled to expire in 2019. 

Second Quarter Highlights:

  • Oil production of 4.9 MMBbls, or approximately 53,800 Bbls per day, a 24 percent increase from the second quarter of 2018 and a seven percent increase from the first quarter of 2019.
  • Total production of 12.4 MMBoe, or approximately 136,500 Boe per day, a 32 percent increase from the second quarter of 2018 and a ten percent increase from the first quarter of 2019.
  • LOE of $2.76 per Boe, a 20 percent improvement from the second quarter of 2018 and a 12 percent decrease from the first quarter of 2019.
  • Further improved Delaware basin drill times, from spud to rig release, to an average of 23 days, a 33 percent, or 11 day improvement, from the second quarter of 2018.

CEO Commentary

President and Chief Executive Officer, Bart Brookman commented, “Throughout the second quarter, our operating teams continued to deliver improved drilling and completion efficiencies while building on the momentum created earlier in the year.  The combination of lowering our full-year capital investment guidance while increasing our full-year production guidance enables PDC to generate in excess of $150 million of free cash flow in the second half of 2019.  Additionally, the adjustments to our business plan clearly demonstrate our ability to execute on a strategy centered on delivering sustainable free cash flow in a volatile commodity price environment. Over the past several months, we have met extensively with our long-term shareholders and are confident our cost control measures, slowed Wattenberg development pace and return of capital all align with our long-term value proposition.”

Operations Update

Production for the second quarter of 2019 was 12.4 million barrels of oil equivalent (“MMBoe”), or approximately 136,500 Boe per day, an increase of 32 percent from the second quarter of 2018 and ten percent from the first quarter of 2019.  Oil production of 4.9 million barrels (“MMBbls”) in the second quarter represents an increase of approximately 24 percent compared to the second quarter of 2018 and seven percent from the first quarter of 2019.  Both total production and oil production growth, on a year-over-year and sequential basis, are largely attributable to increased operational efficiencies and the corresponding acceleration of planned turn-in-lines (“TILs”) in both the Wattenberg and Delaware Basins.  As a result, the Company has increased its full-year production range by one MMBoe at the mid-point to 48 to 50 MMBoe. 

In Wattenberg, the Company spud 43 wells and TIL’d 27 wells with average working interests of 92 percent.  The Company’s completion crew has averaged approximately 17 stages per day in the first half of 2019, more than ten percent above initial 2019 expectations.  The Company’s Wattenberg activity year-to-date has largely focused on the western side of its Kersey acreage block, which has a slightly gassier production mix than average Kersey wells.  Additionally, the Company now expects prolonged elevated Wattenberg line pressures in the second half of 2019 as a result of the slightly delayed processing capacity expansion from its primary third-party midstream provider. The cumulative impact is expected to result in a Wattenberg and total Company full-year oil mix of approximately 40 percent.

In the Delaware Basin, the Company spud ten wells and TIL’d eight wells with average working interests of approximately 92 percent.  Second quarter production of 31,500 Boe per day was approximately 43 percent oil and represented 26 percent growth in total production and oil production compared to the first quarter of 2019.  The Company’s average second quarter drill times, in terms of spud to rig release, averaged 23 days, a 33 percent improvement from the second quarter of 2018 and 15 percent improvement from the first quarter of 2019.  In June, the Company decreased its rig count from three to two, and in July, the Company released its completion crew.  The Company expects to operate two drilling rigs for the remainder of 2019 and to resume completions in 2020.

Capital investments for the quarter were approximately $277 million and included $10 million of Delaware Basin midstream related capital.  The Company anticipates a decrease to its projected cash flows from operations as compared to its previously released guidance for the full-year due to higher than expected natural gas and NGL differentials realized in the second quarter and projected in the second half of the year, as well as a slight decrease to projected oil volumes.  The Company now projects full-year natural gas and NGL realizations, excluding transportation, gathering and processing expenses (“TGP”), to be approximately 40 to 45 percent and 20 to 25 percent of NYMEX pricing, respectively.  This compares to prior estimates of 50 to 55 percent for natural gas and 30 to 35 percent for NGLs.

In order to generate free cash flow in 2019, the Company plans to decrease its Wattenberg rig count from three to two in September while maintaining its original completion activity of approximately 110 to 125 TILs. Due to operating efficiencies accelerating the timing of completions and TILs, the Company expects limited completion activity in the fourth quarter. As a result of these operating plan adjustments, as well as additional capital allocation decisions, the Company has lowered its full-year expected capital investments by $15 million at the mid-point to a range of $810 million to $840 million, excluding corporate capital.   This plan is expected to deliver between $160 million and $190 million of free cash flow in the second half of 2019 with a production profile of flat to modest second half growth on a daily basis.

Stock Repurchase Program

Year-to-date, the Company has returned $125 million of capital to shareholders through the repurchase of approximately 3.7 million shares of common stock outstanding via its previously announced $200 million stock repurchase program (the “Program”).  The remaining repurchases under the Program are currently expected to be conducted in open markets, at the Company’s discretion and in compliance with safe harbor provisions. The Program has a target completion date of December 31, 2020 and can be modified or discontinued by the Board of Directors at any time.  The Company projects to generate a sufficient level of free cash flow in the second half of 2019 and full-year 2020 to fund the Program while maintaining the ability to pursue additional future return of capital programs, depending on market conditions.

Oil and Gas Production, Sales and Operating Cost Data

Crude oil, natural gas and NGLs sales, excluding net settlements on derivatives, increased four percent to $339.0 million in the second quarter of 2019, compared to $325.9 million in the second quarter of 2018.  The increase in sales was due to a 32 percent increase in total production offsetting a decrease in the sales price per Boe, excluding net settlements on derivatives, of 22 percent to $27.28 in the second quarter of 2019 from $34.74 in the comparable 2018 period.  The decrease in sales price per Boe was driven by 42 percent and 27 percent decreases in the weighted-average NGL and natural gas sales prices, respectively, in the second quarter of 2019 compared to the second quarter of 2018. Including the impact of net settlements on derivatives and the change in fair value of unsettled derivatives, combined revenues increased 84 percent to $390.7 million from $212.5 million between periods.

The following table provides production and weighted-average sales price, by area, for the three and six months ended June 30, 2019 and 2018, excluding net settlements on derivatives and TGP:

  Three Months Ended June 30, Six Months Ended June 30,
  2019 2018 Percent
Change
 2019 2018 Percent
Change
             
Crude oil (MBbls)            
Wattenberg Field 3,681  2,943  25.1% 7,253  5,823  24.6%
Delaware Basin 1,218  1,005  21.2% 2,172  1,876  15.8%
Utica Shale      *   46   *
Total 4,899  3,948  24.1% 9,425  7,745  21.7%
             
Weighted-average price $55.96  $63.99  (12.5)% $53.61  $61.85  (13.3)%
             
 Natural gas (MMcf)            
Wattenberg Field 23,233  15,836  46.7% 44,193  31,360  40.9%
Delaware Basin 5,759  4,851  18.7% 10,450  8,500  22.9%
Utica Shale      *   414   *
Total 28,992  20,687  40.1% 54,643  40,274  35.7%
             
Weighted-average price $1.07  $1.46  (26.7)% $1.53  $1.71  (10.5)%
             
NGLs (MBbls)            
Wattenberg Field 2,007  1,544  30.0% 3,908  2,973  31.4%
Delaware Basin 686  443  54.9% 1,200  826  45.3%
Utica Shale      *   34   *
Total 2,693  1,987  35.5% 5,108  3,833  33.3%
             
Weighted-average price $12.53  $21.76  (42.4)% $13.96  $21.78  (35.9)%
             
Crude oil equivalent (MBoe)            
Wattenberg Field 9,561  7,126  34.2% 18,526  14,023  32.1%
Delaware Basin 2,864  2,256  27.0% 5,114  4,118  24.2%
Utica Shale      *   149   *
Total 12,425  9,382  32.4% 23,640  18,290  29.3%
             
Weighted-average price $27.28  $34.74  (21.5)% $27.92  $34.51  (19.1)%

Production costs for the second quarter of 2019, which include lease operating expenses (“LOE”), production taxes and TGP, were $69.1 million, or $5.57 per Boe, compared to $63.9 million, or $6.81 per Boe, for the comparable 2018 period.  The 18 percent decrease in production costs per Boe between periods is largely attributable to a 20 percent decrease in LOE per Boe. Wattenberg LOE per Boe in the second quarter of 2019 was $2.46 compared to $3.29 in the second quarter of 2018.  Delaware Basin LOE decreased between periods to $3.76 from $3.92 per Boe.  The decreases were primarily attributable to the 32 percent company-wide production growth in the second quarter of 2019 compared to the second quarter of 2018.

The following table provides the components of production costs for the three and six months ended June 30, 2019 and 2018:

 Three Months Ended June 30, Six Months Ended June 30,
 2019 2018 2019 2018
        
Lease operating expenses$34.3  $32.3  $69.5  $61.9 
Production taxes22.6  22.6  44.8  42.8 
Transportation, gathering and processing expenses12.2  9.0  23.6  16.3 
Total$69.1  $63.9  $137.9  $121.0 


 Three Months Ended June 30, Six Months Ended June 30,
 2019 2018 2019 2018
        
Lease operating expenses per Boe$2.76  $3.44  $2.94  $3.38 
Production taxes per Boe1.82  2.41  1.90  2.34 
Transportation, gathering and processing expenses per Boe0.99  0.96  1.00  0.89 
Total per Boe$5.57  $6.81  $5.84  $6.61 

Financial Results

Net income for the second quarter of 2019 was $68.5 million, or $1.04 per diluted share, compared to net loss of $160.3 million, or $2.43 per diluted share, for the comparable 2018 period.  The year-over-year difference was primarily attributable to a $160.3 million difference in fair value of unsettled derivatives, a $130.6 million decrease in impairments of property and equipment and a $33.6 million difference in gain on sale of properties and equipment.  Adjusted net income for the second quarter, a non-GAAP financial measure defined below, was $22.5 million, or $0.34 per diluted share in 2019 compared to an adjusted net loss of $84.5 million, or $1.28 per diluted share in 2018. 

Net cash from operating activities was $260.4 million in the second quarter of 2019, compared to $175.7 million in the comparable 2018 period.  The increase between periods is primarily a result of an accounting treatment related to the divestiture of the Company’s Delaware Basin midstream assets in the second quarter of 2019.  Adjusted cash flows from operations, a non-GAAP financial measure defined below, were $207.0 million in the second quarter of 2019, compared to $199.3 million in the comparable 2018 period. 

G&A was $42.8 million, or $3.45 per Boe, for the second quarter of 2019 compared to $37.2 million, or $3.97 per Boe in the comparable 2018 period.  In June 2019, the Company reduced its current corporate headcount by approximately 15 percent while also reducing its future hiring plans.  These changes were made to more closely align with the updated operating plan.  The expenses for cash and non-cash severance, as well as shareholder activism expenses and the settlement of the Company’s final partnership agreements, net a one-time insurance credit, totaled approximately $4.3 million, or $0.35 per Boe.  Excluding these expenses would result in a normalized G&A per Boe of approximately $3.10 for the second quarter of 2019, a 15 percent decrease compared to the comparable 2018 period.  In the second half of 2019, the Company estimates G&A per Boe of $2.60 to $2.80, assuming the mid-point of its updated production guidance range.

2019 Capital Investment Outlook and Financial Guidance

The following table summarizes the Company’s updated 2019 financial guidance:

 Low High
Production (MMBoe)48.0  50.0 
Capital Investment in Crude Oil and Natural Gas Properties (millions)$810  $840 
    
Operating Expenses
Lease operating expense ($/Boe)$2.85  $3.00 
Transportation, gathering and processing expenses ($/Boe)$0.90  $1.00 
Production taxes (% of Crude oil, natural gas & NGL sales)6% 7%
General and administrative expense ($/Boe)$3.00  $3.20 
Estimated Price Realizations (% of NYMEX) (excludes TGP)
Crude oil90% 95%
Natural gas40% 45%
NGLs20% 25%

The Company projects to generate free cash flow in the third quarter as it expects a material reduction in capital investments compared to the second quarter, driven primarily through reduced Delaware Basin completion activity.  Additionally, the Company projects its third quarter production volumes to reflect modest growth in each basin compared to the second quarter.

In 2020, the Company projects to generate between $100 million and $200 million of free cash flow after updating its assumptions to reflect an anticipated increase in natural gas and NGL price differentials, lower corporate cost structure and reduced Wattenberg rig count and projected oil volumes.  

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. 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 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 June 30, Six Months Ended June 30,
  2019 2018 2019 2018
Adjusted cash flows from operations:        
Net cash from operating activities $260.4  $175.7  $442.2  $380.9 
Changes in assets and liabilities (53.4) 23.6  (42.7) (6.6)
Adjusted cash flows from operations $207.0  $199.3  $399.5  $374.3 


Adjusted Net Income (Loss)
  Three Months Ended June 30, Six Months Ended June 30,
  2019 2018 2019 2018
Adjusted net income (loss):        
Net income (loss) $68.5  $(160.3) $(51.6) $(173.4)
(Gain) loss on commodity derivative instruments (47.3) 116.1  142.7  163.4 
Net settlements on commodity derivative instruments (13.2) (16.4) (21.6) (42.4)
Tax effect of above adjustments 14.5  (23.9) (29.0) (29.0)
Adjusted net income (loss) $22.5  $(84.5) $40.5  $(81.4)
Weighted-average diluted shares outstanding 65.9  66.1  66.0  66.0 
Adjusted diluted earnings per share $0.34  $(1.28) $0.61  $(1.23)


Adjusted EBITDAX
  Three Months Ended June 30, Six Months Ended June 30,
  2019 2018 2019 2018
Net income (loss) to adjusted EBITDAX:        
Net income (loss) $68.5  $(160.3) $(51.6) $(173.4)
(Gain) loss on commodity derivative instruments (47.3) 116.1  142.7  163.4 
Net settlements on commodity derivative instruments (13.2) (16.4) (21.6) (42.4)
Non-cash stock-based compensation 7.6  5.5  12.3  10.8 
Interest expense, net 18.9  17.3  35.9  34.7 
Income tax expense (benefit) 22.6  (45.3) (14.8) (49.9)
Impairment of properties and equipment 29.0  159.5  36.9  192.7 
Exploration, geologic and geophysical expense 0.6  0.9  3.3  3.5 
Depreciation, depletion and amortization 168.5  135.6  319.9  262.4 
Accretion of asset retirement obligations 1.6  1.4  3.1  2.6 
Adjusted EBITDAX $256.8  $214.3  $466.1  $404.4 
         
Cash from operating activities to adjusted EBITDAX:        
Net cash from operating activities $260.4  $175.7  $442.2  $380.9 
Interest expense, net 18.9  17.3  35.9  34.7 
Amortization of debt discount and issuance costs (3.4) (3.1) (6.7) (6.4)
Gain (loss) on sale of properties and equipment 33.9  0.4  34.3  (1.1)
Exploration, geologic and geophysical expense 0.6  0.9  3.3  3.5 
Other (0.2) (0.5) (0.2) (0.6)
Changes in assets and liabilities (53.4) 23.6  (42.7) (6.6)
Adjusted EBITDAX $256.8  $214.3  $466.1  $404.4 


PDC ENERGY, INC.

Condensed Consolidated Statements of Operations
(unaudited, in thousands, except per share data)

 Three Months Ended June 30, Six Months Ended June 30,
 2019 2018 2019 2018
        
Revenues       
Crude oil, natural gas and NGLs sales$338,956  $325,933  $660,055  $631,158 
Commodity price risk management gain (loss), net47,349  (116,126) (142,725) (163,366)
Other income4,353  2,724  7,828  5,339 
Total revenues390,658  212,531  525,158  473,131 
Costs, expenses and other       
Lease operating expenses34,328  32,260  69,549  61,896 
Production taxes22,642  22,604  44,810  42,773 
Transportation, gathering and processing expenses12,208  8,964  23,632  16,277 
Exploration, geologic and geophysical expense640  875  3,283  3,521 
Impairment of properties and equipment28,979  159,554  36,854  192,742 
General and administrative expense42,808  37,247  82,406  72,943 
Depreciation, depletion and amortization168,523  135,624  319,945  262,412 
Accretion of asset retirement obligations1,563  1,285  3,147  2,573 
(Gain) loss on sale of properties and equipment(33,904) (351) (34,273) 1,081 
Other expenses2,836  2,708  6,390  5,476 
Total costs, expenses and other280,623  400,770  555,743  661,694 
Income (loss) from operations110,035  (188,239) (30,585) (188,563)
Interest expense(18,905) (17,410) (35,883) (34,939)
Interest income5  69  15  217 
Income (loss) before income taxes91,135  (205,580) (66,453) (223,285)
Income tax (expense) benefit(22,587) 45,323  14,825  49,889 
Net income (loss)$68,548  $(160,257) $(51,628) $(173,396)
        
Earnings per share:       
Basic$1.04  $(2.43) $(0.78) $(2.63)
Diluted$1.04  $(2.43) $(0.78) $(2.63)
        
Weighted-average common shares outstanding:       
Basic65,815  66,066  65,998  66,012 
Diluted65,926  66,066  65,998  66,012 


PDC ENERGY, INC.

Condensed Consolidated Balance Sheets
(unaudited, in thousands, except share and per share data)

  June 30, 2019 December 31, 2018
Assets    
Current assets:    
Cash and cash equivalents $1,474  $1,398 
Accounts receivable, net 277,321  181,434 
Fair value of derivatives 41,425  84,492 
Prepaid expenses and other current assets 5,607  7,136 
Total current assets 325,827  274,460 
Properties and equipment, net 4,196,335  4,002,862 
Assets held-for-sale, net   140,705 
Fair value of derivatives 31,655  93,722 
Other assets 41,087  32,396 
Total Assets $4,594,904  $4,544,145 
     
Liabilities and Stockholders' Equity    
Liabilities    
Current liabilities:    
Accounts payable $219,158  $181,864 
Production tax liability 69,951  60,719 
Fair value of derivatives 19,775  3,364 
Funds held for distribution 88,879  105,784 
Accrued interest payable 14,273  14,150 
Other accrued expenses 86,523  75,133 
Total current liabilities 498,559  441,014 
Long-term debt 1,197,744  1,194,876 
Deferred income taxes 183,120  198,096 
Asset retirement obligations 78,909  85,312 
Liabilities held-for-sale   4,111 
Fair value of derivatives 927  1,364 
Other liabilities 257,239  92,664 
Total liabilities 2,216,498  2,017,437 
     
Stockholders' equity    
Common shares - par value $0.01 per share, 150,000,000 authorized, 63,520,462 and 66,148,609 issued as of June 30, 2019 and December 31, 2018, respectively
 635  661 
Additional paid-in capital 2,433,974  2,519,423 
Retained earnings (deficit) (42,901) 8,727 
Treasury shares - at cost, 364,780 and 45,220
 as of June 30, 2019 and December 31, 2018, respectively
 (13,302) (2,103)
Total stockholders' equity 2,378,406  2,526,708 
Total Liabilities and Stockholders' Equity $4,594,904  $4,544,145 
     

PDC ENERGY, INC.
Condensed Consolidated Statements of Cash Flows
(unaudited, in thousands)

   Three Months Ended June 30, Six Months Ended June 30,
  2019 2018 2019 2018 
Cash flows from operating activities:         
Net income (loss) $68,548  $(160,257) $(51,628) $(173,396) 
Adjustments to net income (loss) to reconcile to net cash from operating activities:         
Net change in fair value of unsettled commodity derivatives (60,542) 99,718  121,080  120,920  
Depreciation, depletion and amortization 168,523  135,624  319,945  262,412  
Impairment of properties and equipment 28,979  159,554  36,854  192,742  
Accretion of asset retirement obligations 1,563  1,285  3,147  2,573  
Non-cash stock-based compensation 7,575  5,518  12,258  10,779  
(Gain) loss on sale of properties and equipment (33,904) (351) (34,273) 1,081  
Amortization of debt discount and issuance costs 3,382  3,126  6,731  6,372  
Deferred income taxes 22,512  (45,372) (14,975) (50,181) 
Other 374  459  395  974  
Changes in assets and liabilities 53,373  (23,596) 42,702  6,581  
     Net cash from operating activities 260,383  175,708  442,236  380,857  
Cash flows from investing activities:         
Capital expenditures for development of crude oil and natural gas properties (275,851) (235,718) (542,791) (432,635) 
Capital expenditures for other properties and equipment (5,627) (1,384) (10,453) (2,450) 
Acquisition of crude oil and natural gas properties (4,146) (227) (4,146) (181,052) 
Proceeds from sale of properties and equipment 1,052  1,762  1,154  1,782  
Proceeds from divestitures 199,430    199,430  39,023  
Restricted cash 8,001    8,001  1,249  
     Net cash from investing activities (77,141) (235,567) (348,805) (574,083) 
Cash flows from financing activities:         
Proceeds from revolving credit facility 458,000  198,000  890,000  233,000  
Repayment of revolving credit facility (552,000) (176,000) (892,500) (211,000) 
Payment of debt issuance costs (36) (4,060) (36) (4,060) 
Purchase of treasury shares (94,113)   (94,113)   
Purchase of treasury shares for employee stock-based compensation tax withholding obligations (2,257) (2,239) (3,717) (4,494) 
Other (475) (340) (990) (719) 
     Net cash from financing activities (190,881) 15,361  (101,356) 12,727  
Net change in cash, cash equivalents and restricted cash (7,639) (44,498) (7,925) (180,499) 
Cash, cash equivalents and restricted cash, beginning of period 9,113  53,924  9,399  189,925  
Cash, cash equivalents and restricted cash, end of period $1,474  $9,426  $1,474  $9,426  

2019 Second 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, Chief Operating Officer, for a conference call on Thursday, August 8, 2019, to discuss its 2019 second quarter results. The related slide presentation will be available on PDC's website at www.pdce.com.

Conference Call and Webcast:
Date/Time: Thursday, August 8, 2019, 11:00 a.m. ET
Webcast available at: www.pdce.com
Domestic (toll free): 877-312-5520
International: 253-237-1142
Conference ID: 3583153

Replay Numbers:
Domestic (toll free): 855-859-2056
International: 404-537-3406
Conference ID: 3583153

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 attend the following conferences: EnerCom’s The Oil and Gas Conference in Denver on Tuesday, August 13; Barclay’s Energy Conference in New York on Wednesday, September 4; and the Johnson Rice Energy Conference in New Orleans on Tuesday, September 24. Presentation materials will be posted to the Company’s website, www.pdce.com, prior to the start of the conference.

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 and the Delaware Basin in West Texas. Its operations are focused on the liquid-rich horizontal Niobrara and Codell plays in the Wattenberg Field and 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"), Section 21E of the Securities Exchange Act of 1934 ("Exchange Act") and the United States ("U.S.") Private Securities Litigation Reform Act of 1995 regarding our business, financial condition, results of operations and prospects. All statements other than statements of historical fact included in and incorporated by reference into this press release are "forward-looking statements." Words such as expect, anticipate, intend, plan, believe, seek, estimate, schedule 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: production, costs and cash flows; drilling locations, zones and growth opportunities; commodity prices and differentials; capital expenditures and projects, including the number of rigs employed, and that cash flows from operations will exceed expected capital investments in crude oil and natural gas properties for 2019 and 2020; our stock repurchase program, which may be modified or discontinued at any time; potential additional payments from the sale of our midstream assets; financial ratios and compliance with covenants in our revolving credit facility and other debt instruments; impacts of certain accounting and tax changes; timing and adequacy of infrastructure projects of our midstream providers and the related impact on our midstream capacity and related curtailments; fractionation capacity; impacts of Colorado political matters and expected timing of rulemakings; ability to meet our volume commitments to midstream providers; ongoing compliance with our consent decree and expected timing of certain litigation; and reclassification of the Denver Metro/North Front Range NAA ozone classification to serious.

The above statements are not the exclusive means of identifying forward-looking statements herein. Although forward-looking statements contained in this report reflect our good faith judgment, such statements can only be based on facts and factors currently known to us. 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, we may use the term “projection” or similar terms or expressions, or indicate that we have “modeled” certain future scenarios. We typically use these terms to indicate our current thoughts on possible outcomes relating to our business or our 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 global production volumes and demand, including economic conditions that might impact demand and prices for the products we produce;
  • volatility of commodity prices for crude oil, natural gas and natural gas liquids ("NGLs") and the risk of an extended period of depressed prices;
  • impact to our operations, personnel retention, strategy, stock price and expenses caused by the actions of activist shareholders;
  • volatility and widening of differentials;
  • reductions in the borrowing base under our revolving credit facility;
  • impact of governmental policies and/or regulations, including changes in environmental and other laws, the interpretation and enforcement of those laws and regulations, liabilities arising thereunder and the costs to comply with those laws and regulations;
  • declines in the value of our crude oil, natural gas and NGLs properties resulting in impairments;
  • changes in estimates of proved reserves;
  • inaccuracy of reserve estimates and expected production rates;
  • potential for production decline rates from our 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 our production and the impact of these facilities and regional capacity on the prices we receive for our production;
  • timing and receipt of necessary regulatory permits;
  • risks incidental to the drilling and operation of crude oil and natural gas wells;
  • difficulties in integrating our operations as a result of any significant acquisitions or acreage exchanges;
  • increases or changes in costs and expenses;
  • availability of supplies, materials, contractors and services that may delay the drilling or completion of our wells;
  • potential losses of acreage due to lease expirations or otherwise;
  • increases or changes in costs and expenses;
  • future cash flows, liquidity and financial condition;
  • competition within the oil and gas industry;
  • availability and cost of capital;
  • our success in marketing crude oil, natural gas and NGLs;
  • effect of crude oil and natural gas derivative activities;
  • impact of environmental events, governmental and other third-party responses to such events and our ability to insure adequately against such events;
  • cost of pending or future litigation;
  • effect that acquisitions we may pursue have on our capital requirements;
  • our ability to retain or attract senior management and key technical employees; and
  • success of strategic plans, expectations and objectives for our future operations.

Further, we urge you to carefully review and consider the cautionary statements and disclosures, specifically those under the heading "Risk Factors," made in our Annual Report on Form 10-K for the year ended December 31, 2018 filed with the U.S. Securities and Exchange Commission ("SEC") on February 28, 2019 (the "2018 Form 10-K"), our Quarterly Report on Form 10-Q for the quarter ended March 31, 2019 filed with the SEC on May 2, 2019 (the "2019 Q1 Form 10-Q") and our other filings with the SEC for further information on risks and uncertainties that could affect our business, financial condition, results of operations and prospects, which are incorporated by this reference as though fully set forth herein. We caution you not to place undue reliance on the forward-looking statements, which speak only as of the date of this report. We undertake 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 cautionary statement.

Contacts:

Michael Edwards
Senior Director Investor Relations
303-860-5820
[email protected]

Kyle Sourk
Manager Investor Relations
303-318-6150
[email protected]

 

Primary Logo


Source: GlobeNewswire (August 7, 2019 - 4:30 PM EDT)

News by QuoteMedia
www.quotemedia.com
Tags:

Legal Notice