PDC Energy Announces 2017 First Quarter Operating and Financial Results Including Production Increase of 46% to 6.6 Million Barrels of Oil Equivalent

May 5, 2017 at 8:00 AM EDT

DENVER, May 05, 2017 (GLOBE NEWSWIRE) -- PDC Energy, Inc. ("PDC" or the "Company") (NASDAQ:PDCE) today reported its 2017 first quarter operating and financial results.

First Quarter 2017 Highlights

  • Production of 6.6 million barrels of oil equivalent ("MMBoe"), a 46 percent increase year-over-year; daily production of approximately 73,865 barrels of oil equivalent ("Boe").
  • Turned-in-line 43 gross operated wells consisting of 29 wells with lateral lengths in excess of one mile, including two 2-mile lateral wells in the Delaware Basin.
  • Lease operating expenses ("LOE") of $2.98 per Boe, an 11% decrease year-over-year.
  • Liquidity of approximately $945 million and a leverage ratio at 2.0 times, as defined by the Company's credit agreement.

CEO Commentary

President and Chief Executive Officer, Bart Brookman commented, "I am very pleased with our ability to deliver strong results in the first quarter.  Our Core Wattenberg position, highlighted by the increased type curves and enhanced internal rates-of-return disclosed at our recent Analyst Day, continues to be the primary growth driver for PDC.  In the Delaware Basin, we are very excited by the early results of the wells turned-in-line in the first quarter and are quickly gaining operational momentum as we integrate the new assets into the company.  Our results this quarter are a great first step in once again delivering impressive annual growth."

Operating Results

Oil and Gas Production, Sales and Operating Cost Data

The following table provides production and weighted-average sales price, by area, for the three months ended March 31, 2017 and 2016, excluding net settlements on derivatives:

  Three Months Ended
 March 31, 
  2017 2016 Percent 
Crude oil (MBbls)      
Wattenberg Field 2,141.6  1,818.2  17.8%
Delaware Basin 274.7    
Utica Shale 91.7  89.6  2.3%
Total 2,508.0  1,907.8  31.5%
Weighted-Average Sales Price $49.04  $28.29  73.3%
Natural gas (MMcf)      
Wattenberg Field 13,713.9  10,170.4  34.8%
Delaware Basin 1,246.0    
Utica Shale 624.2  507.6  23.0%
Total 15,584.1  10,678.0  45.9%
Weighted-Average Sales Price $2.37  $1.39  70.5%
NGLs (MBbls)          
Wattenberg Field 1,358.4  840.1  61.7%
Delaware Basin 130.5    
Utica Shale 53.6  42.1  27.3%
Total 1,542.5  882.2  74.8%
Weighted-Average Sales Price $19.29  $7.37  161.7%
Crude oil equivalent (MBoe)      
Wattenberg Field 5,785.7  4,353.4  32.9%
Delaware Basin  612.8    
Utica Shale 249.4  216.3  15.3%
Total 6,647.9  4,569.7  45.5%
Weighted-Average Sales Price $28.53  $16.49  73.0%

The following table provides the components of production costs for the three months ended March 31, 2017 and 2016 in terms of total dollars and on a per Boe basis:

 Three Months Ended
March 31,
 2017 2016
Lease operating expenses$19.8  $15.3 
Production taxes12.4  4.1 
Transportation, gathering and processing expenses5.9  4.0 
Total$38.1  $23.4 
Lease operating expenses per Boe $2.98  $3.35 
Production taxes per Boe 1.87   0.89 
Transportation, gathering and processing expenses per Boe 0.89   0.88 
Total per Boe$5.74  $5.12 

Financial Results

Net income for the first quarter of 2017 was $46.1 million, or $0.70 per diluted share, compared to net loss of $71.5 million, or $1.72 per diluted share, for the comparable period of 2016.  The year-over-year difference was primarily attributable to the $114.3 million increase in crude oil, natural gas and NGLs sales in 2017, as well as the impact of the change in the fair value of derivatives during the quarter.  Adjusted net loss, a non-GAAP measure defined below, was $4.1 million, or $0.06 per diluted share in the first quarter of 2017 compared to $37.0 million, or $0.89 per diluted share for the comparable period of 2016.

Net cash from operating activities was $139.5 million in the first quarter of 2017, compared to $101.2 million in the first quarter of 2016.  The increase in 2017 cash flows was a result of increases to both production volumes and average commodity prices compared to the prior year.  Adjusted cash flows from operations, a non-GAAP financial measure defined below, were $113.7 million for the first quarter of 2017, compared to $91.0 million in the first quarter of 2016. 

Crude oil, natural gas and NGLs sales, excluding net settlements on derivatives, increased 152% to $189.7 million in the first quarter of 2017, compared to $75.4 million in the first quarter of 2016.  The sales price per Boe, excluding net settlements on derivatives, improved to $28.53 in the first quarter of 2017 compared to $16.49 in the first quarter of 2016.  Much of the increase was driven by improved crude oil prices, as well as improved NGL realizations in 2017.  Including commodity price risk management gain and other income, crude oil, natural gas and NGLs revenues increased 201% to $273.7 million in the first quarter of 2017 from $90.8 million in the first quarter of 2016.

Net commodity price risk management activities for the first quarter of 2017 resulted in a gain of $80.7 million compared to a gain of $11.1 million in the comparable period in 2016.  The first quarter 2017 gain was comprised of $80.2 million in net change in fair value of unsettled derivatives and $0.5 million of net settlement gains.  Net settlements in the first quarter of 2016 were $66.8 million with a decrease in fair value associated with commodity derivatives of $55.8 million.

Production costs for the first quarter of 2017, which include LOE, production taxes, and transportation, gathering and processing expenses, were $38.1 million, or $5.74 per Boe.  In the first quarter of 2016, production costs were $23.4 million, or $5.12 per Boe.  LOE in the first quarter of 2017 decreased 11% to $2.98 per Boe compared to $3.35 per Boe in the similar 2016 period due primarily to increased production volumes.  The decrease in LOE on a Boe basis was more than offset by an increase in production taxes as a result of the 152% increase in crude oil, natural gas and NGLs sales between the first quarters of 2017 and 2016. 

General and administrative expense ("G&A") was $26.3 million for the first quarter of 2017 compared to $22.8 million in the first quarter of 2016.  The increase in G&A in the first quarter of 2017 was primarily attributable to an increase in payroll and employee benefits as a result of an increase in headcount compared to the first quarter of 2016.  G&A per Boe decreased 20% to $3.96 in the first quarter of 2017, compared to $4.98 in the comparable period in 2016, driven by increased production volumes.

Depreciation, depletion and amortization expense ("DD&A") related to crude oil and natural gas properties was $107.8 million, or $16.22 per Boe in the first quarter of 2017, compared to $96.3 million, or $21.08 per Boe in the first quarter of 2016.  The decrease in weighted-average DD&A rate between periods was due to the increase in production more than offsetting the increase in total DD&A.  DD&A from all sources, including gas marketing, was $109.3 million in the first quarter of 2017 compared to $97.4 million in the comparable 2016 period.

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 $200.2 million during the first quarter of 2017 compared to $99.2 million for the same 2016 period. The increase in capital investment was primarily attributable to investments made in Delaware Basin drilling, completions and midstream infrastructure in the first quarter of 2017.

2017 Capital Investment Outlook and Financial Guidance

The Company anticipates 2017 production to be within the top-third of its previously disclosed guidance range of 30 to 33 MMBoe with 2017 capital investments expected to be in the top half of its $725 to $775 million range.  Additionally, the Company plans to pursue the 2017 divestiture of it Utica Shale asset in order to provide additional focus to its premier Core Wattenberg and Delaware Basin assets.

The following table provides forecasted 2017 financial guidance:

  Low High
Production (MMBoe)  30.0   33.0 
Capital Expenditures (millions) $725  $775 
Operating Expenses      
Lease operating expense ($/Boe) $2.65   $3.00 
Transportation, gathering & processing expense ($/Boe) $0.70  $0.90 
Production taxes (% of Crude Oil, Natural Gas & NGL Sales)  6%  8%
General & Administrative expense ($/Boe) $3.25  $3.60 
Depreciation, depletion and amortization ($/Boe) $15.00  $16.50 
Exploration, geologic and geophysical expense (millions) $5.0  $10.0 
Estimated Price Realizations (% of NYMEX, excluding TGP)    
Oil   92%  94 %
Gas  70%  72%
NGLs  27%  31%

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 when providing public guidance on possible future results.  Beginning in 2017, the Company has included non-cash stock-based compensation and exploration, geologic and geophysical expenses to its adjusted EBITDAX calculation.  All prior periods have been reconciled to match accordingly.  PDC believes that each of these measures is useful in providing transparency with respect to certain aspects of its operations.  Each of these measures is calculated by adjusting for the items set forth in the relevant table below from the most closely comparable U.S. GAAP measure. See Management's Discussion and Analysis of Financial Condition and Results of Operation - Reconciliation of Non-U.S. GAAP Financial Measures in PDC's Annual Report on Form 10-K for the year ended December 31, 2016, and other subsequent filings with the SEC, for additional disclosure concerning these non-U.S. GAAP measures.  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, cash flows from operations, investing or financing activities or other U.S. GAAP financial measures, 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 PDC uses 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 its investors more meaningfully evaluate and compare its future results of operations to its previously reported results of operations.  PDC strongly encourages users of financial information to review the Company's financial statements and publicly filed reports in their entirety and not to 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
March 31,
  2017 2016
Adjusted cash flows from operations:    
Net cash from operating activities $139.5  $101.2 
Changes in assets and liabilities (25.8) (10.2)
Adjusted cash flows from operations $113.7  $91.0 

Adjusted Net Income (Loss)
  Three Months Ended
March 31,
  2017 2016
Adjusted net income (loss):    
Net income (loss) $46.1  $(71.5)
Gain on commodity derivative instruments  (80.7) (11.1)
Net settlements on commodity derivative instruments instruments 0.5  66.8 
Tax effect of above adjustments 30.0  (21.2)
Adjusted net income (loss) $(4.1 ) $(37.0)
Weighted-average diluted shares outstanding 66.1  41.6 
Adjusted diluted net earnings per share $(0.06) $(0.89)

Adjusted EBITDAX
  Three Months Ended
March 31,
  2017  2016
Net income (loss) to adjusted EBITDAX:    
Net income (loss) $46.1  $(71.5)
Gain on commodity derivative instruments (80.7) (11.1)
Net settlements on commodity derivative instruments 0.5  66.8 
Non-cash stock-based compensation 4.5  4.7 
Interest expense, net 19.2  10.3 
Income tax expense (benefit) 26.3  (41.8)
Impairment of properties and equipment 2.2  1.0 
Exploration, geologic and geophysical expense 1.0   0.2 
Depreciation, depletion and amortization 109.3  97.4 
Accretion of asset retirement obligations 1.8  1.8 
Adjusted EBITDAX $130.2  $57.8 
Cash from operating activities to adjusted EBITDAX:    
Net cash from operating activities  $139.5  $101.2 
Interest expense, net 19.2  10.3 
Amortization of debt discount and issuance costs (3.2) (1.8)
Gain on sale of properties and equipment 0.2  0.1 
Exploration, geologic and geophysical expense 1.0  0.2 
Other (0.7) (42.0)
Changes in assets and liabilities (25.8) (10.2)
Adjusted EBITDAX $130.2  $57.8 


Consolidated Statements of Operations
(unaudited, in thousands, except per share data)
  Three Months Ended
March 31,
  2017 2016
Crude oil, natural gas, and NGLs sales $189,692  $75,367 
Commodity price risk management gain, net of settlements 80,704   11,056 
Other income 3,311  4,408 
Total revenues 273,707  90,831 
Costs, expenses and other    
Lease operating expenses 19,789  15,330 
Production taxes 12,399  4,071  
Transportation, gathering and processing expenses 5,902  4,041 
General and administrative expense 26,315   22,779 
Exploration, geologic, and geophysical expense 954  210 
Depreciation, depletion and amortization 109,316  97,388 
Impairment of properties and equipment 2,193  1,001 
Accretion of asset retirement obligations 1,768  1,812 
Gain on sale of properties and equipment (160) (84)
Provision for uncollectible notes receivable   44,738 
Other expenses 3,528  2,578 
Total cost, expenses and other 182,004  193,864 
Income (loss) from operations 91,703  (103,033)
Interest expense (19,467) (11,894)
Interest income 240  1,558 
Income (loss) before income taxes 72,476  (113,369)
Income tax benefit (expense) (26,330)  41,839 
Net income (loss) $46,146  $(71,530)
Earnings per share:    
Basic $0.70  $(1.72)
Diluted $0.70  $(1.72)
Weighted-average common shares outstanding:    
Basic 65,749  41,608 
Diluted 66,117  41,608 


Consolidated Balance Sheets
(unaudited, in thousands)
  March 31, 2017 December 31, 2016
Current assets:    
Cash and cash equivalents $207,624  $244,100 
Short-term investments 49,890  - 
Accounts receivable, net 122,484  143,392 
Fair value of derivatives 27,047  8,791 
Prepaid expenses and other current assets 4,726  3,542  
Total current assets 411,771  399,825 
Properties and equipment, net 4,098,463  4,008,266 
Fair value of derivatives 13,921  2,386 
Goodwill 56,058  62,041 
Other assets 12,917  13,324 
Total Assets $ 4,593,130  $4,485,842 
Liabilities and Stockholders' Equity    
Current liabilities:    
Accounts payable $144,440  $66,322 
Production tax liability 25,065   24,767 
Fair value of derivatives 26,495  53,595 
Funds held for distribution 76,067  71,339 
Accrued interest payable 18,977  15,930 
Other accrued expenses 26,938  38,625 
Total current liabilities 317,982  270,578 
Long-term debt  1,046,461  1,043,954 
Deferred income taxes 427,205  400,867 
Asset retirement obligations 78,162  82,612 
Fair value of derivatives 4,302  27,595 
Other liabilities 47,841  37,482 
Total liabilities 1,921,953  1,863,088 
Commitments and contingent liabilities    
Stockholders' equity    
Common shares - par value $0.01 per share, 150,000,000 authorized, 65,797,748 and 65,704,568 issued as of March 31, 2017 and December 31, 2016, respectively 658  657 
Additional paid-in capital 2,492,276  2,489,557 
Retained earnings 180,354  134,208 
Treasury shares - at cost, 34,443 and 28,763 as of March 31, 2017 and December 31, 2016, respectively (2,111) (1,668)
Total stockholders' equity 2,671,177  2,622,754 
Total Liabilities and Stockholders' Equity $4,593,130  $4,485,842 


Consolidated Statements of Cash Flows
(unaudited, in thousands)
  Three Months Ended
March 31,
  2017  2016
Cash flows from operating activities:    
Net income (loss)$46,146  (71,530)
Adjustments to net income (loss) to reconcile to net cash from operating activities:    
Net change in fair value of unsettled commodity derivatives (80,153) 55,770 
Depreciation, depletion and amortization 109,316  97.388 
Impairment of properties and equipment 2,193  1,001 
Accretion of asset retirement obligation 1,768  1,812 
Non-cash stock-based compensation 4,454  4,682 
Gain on sale of properties and equipment (160) (84)
Amortization of debt discount and issuance costs 3,184  1,754 
Deferred income taxes 26,280  (43,372)
Provision for uncollectible notes receivable -  44,738 
Other 722  (1,202)
Changes in assets and liabilities 25,750  10,193 
Net cash from operating activities 139,500  101,150 
Cash flows from investing activities:    
Capital expenditures for development of crude oil and natural gas properties (129,826) (122,309)
Capital expenditures for other properties and equipment (821) (450)
Acquisition of crude oil and natural gas properties, including settlement adjustments 6,181  - 
Proceeds from sale of properties and equipment, net 737  90 
Purchases of short-term investments (49,890) - 
Net cash from investing activities (173,619) (122,669)
Cash flows from financing activities:     
Proceeds from sale of equity, net of issuance costs (8) 296,578 
Proceeds from senior notes, net of issuance costs -  85,000 
Repayment of revolving credit facility -  (122,000)
Other (2,349) (364)
Net cash from financing activities (2,357) 259,214 
Net change in cash and cash equivalents (36,476) 237,695 
Cash and cash equivalents, beginning of year 244,100  850 
Cash and cash equivalents, end of year$207,624  238,545 

2017 First Quarter Teleconference and Webcast

The Company invites you to join Bart Brookman, President and Chief Executive Officer; David Honeyfield, Senior Vice President Chief Financial Officer; Lance Lauck, Executive Vice President Corporate Development and Strategy; and Scott Reasoner, Chief Operating Officer, for a conference call on Friday, May 5, 2017, to discuss its 2017 first quarter results. The related slide presentation will be available on PDC's website at www.pdce.com

Conference Call and Webcast:
Date/Time: Friday, May 5, 2017, 11:00 a.m. ET
Webcast available at: www.pdce.com 
Domestic (toll free): 877-312-5520
International: 253-237-1142
Conference ID: 1282967

Replay Numbers:
Domestic (toll free): 855-859-2056
International: 404-537-3406
Conference ID: 1282967

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: Credit Suisse Shale Symposium in Boston on Tuesday, May 16, 2017, and UBS Global Oil & Gas Conference in Austin on Tuesday, May 23, 2017.  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 produces, develops, and explores for crude oil, natural gas, and NGLs, with primary operations in the Wattenberg Field in Colorado and, beginning in December 2016, the Delaware Basin in Reeves and Culberson Counties, Texas. The Company also has operations in the Utica Shale in Southeastern Ohio, although management expects to divest these properties during 2017. PDC's operations in the Wattenberg Field are focused in the horizontal Niobrara and Codell plays and in the Delaware Basin operations are currently focused in the Wolfcamp zones.


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 report are "forward-looking statements".  Words such as expects, anticipates, intends, plans, believes, seeks, estimates, and similar expressions or variations of such words are intended to identify forward-looking statements herein.  Forward-looking statements may include, among other things, statements regarding future: reserves, production, costs, cash flows, and earnings; drilling locations and growth opportunities; capital investments 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; and midstream capacity and related curtailments.

The above statements are not the exclusive means of identifying forward-looking statements herein.  Although forward-looking statements contained in this press release 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 terms "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 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 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;
  • 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 further 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;
  • losses from our gas marketing business exceeding our expectations;
  • difficulties in integrating our operations as a result of any significant acquisitions, including our recent acquisitions in the Delaware Basin;
  • increases or changes in operating costs, severance and ad valorem taxes, and increases or changes in drilling, completion, and facilities costs;
  • 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;
  • 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 derivatives 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 investments;
  • 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, PDC urges you to carefully review and consider the cautionary statements and disclosures, specifically those under the heading "Risk Factors," made in this Quarterly Report on Form 10-Q, our Annual Report on Form 10-K for the year ended December 31, 2016 (the "2016 Form 10-K"), filed with the U.S. Securities and Exchange Commission ("SEC") on February 28, 2017, and other filings with the SEC for further information on risks and uncertainties that could affect the Company's business, financial condition, results of operations, and prospects, which are incorporated by this reference as though fully set forth herein.

PDC cautions you not to place undue reliance on the forward-looking statements, which speak only as of the date of this report. The Company 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 cautionary statement.


Michael Edwards

Senior Director Investor Relations



Kyle Sourk

Manager Investor Relations



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Source: PDC Energy

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