AUSTIN, Texas--(BUSINESS WIRE)--Jones Energy, Inc. (NYSE: JONE) (“Jones Energy ” or “the Company”) today announced financial and operating results for the quarter ended June 30, 2013, reporting net income attributable to common stockholders of $48.7 million and adjusted EBITDAX, a non-GAAP financial measure, of $52.7 million. (Please see supplemental financial information at the end of this news release for reconciliations of non-GAAP financial measures.)
2013 Second-Quarter Highlights
- Increased total production to 16,725 barrels of oil equivalent per day (“Boe/d”), up 5% from the first quarter of 2013 and 37% from the second quarter of 2012.
- Increased oil production to 4,540 barrels per day (“Bbl/d”), up 31% from the first quarter of 2013 and 147% from the second quarter of 2012.
- Increased adjusted EBITDAX to $52.7 million, up 12% from the first quarter of 2013 and 71% from the second quarter of 2012.
- Increased drilling pace from five rigs as of April 1, 2013 to six rigs as of June 30, 2013, all of which were drilling in the Cleveland; expect to add four additional rigs by year-end (two Cleveland and two Woodford).
- Achieved our fastest ever spud to total depth (“TD”) time and average rate of penetration for a Cleveland well of 14.6 days and 873 ft./day, respectively.
- Achieved a 40% production uplift by optimizing stimulation design and increasing stage count from 10 to 14 on recent Woodford completions with at least three months of production.
- Signed a new Joint Development Agreement (“JDA”) with Vanguard Natural Resources, covering a 360 section AMI in the Arkoma Woodford.
- Entered into an agreement with BP to drill up to 17 wells in the Arkoma Woodford.
- Subsequent to quarter end, on July 29, 2013, Jones successfully completed its initial public offering of 12.5 million primary shares of Class A common stock at a price to the public of $15.00 per share and received net proceeds of $177.0 million (net of underwriting discounts and commissions). Net proceeds were used to reduce indebtedness under the Company’s revolving credit facility.
Jonny Jones, Jones Energy’s Chairman and CEO commented, “The Company achieved new records in production, revenue and EBITDAX during the second quarter, driven by the focused execution of our business plan. We drilled 19 operated wells and completed 21 operated wells, and once again we achieved these results while not outspending our cash flow. We increased the percentage of oil in our total production from 15% in the second quarter 2012 to 27% in the second quarter 2013 by focusing on the liquids rich fairway of the Cleveland play. The operating team continues to focus on controlling and reducing our best-in-class drilling and completion costs, and during the quarter we achieved our fastest ever time to drill and complete a Cleveland well. These solid operating results and our industry-leading costs will help us continue to generate outstanding well level returns, and our recent successful IPO provides the Company with additional financial flexibility to grow. We have added one rig subsequent to the end of the quarter in the Woodford, and are on track to have ten rigs running by year-end with eight in the Cleveland and two in the Woodford.”
The Company drilled (spud) 19 Cleveland wells in the second quarter of 2013, 5 of which were completed as of June 30, 2013. The Company also completed 11 Cleveland wells in the second quarter that were carried over from prior periods. As of June 30, 2013, 6 wells were drilling and 8 wells were in various stages of completion. Please see the table below for more detail regarding the Cleveland drilling activity for the first half of 2013.
Daily net production in the Cleveland increased to 9,671 Boe/d, up 7% from the first quarter of 2013 and up 80% from the second quarter of 2012. Additionally, oil and natural gas liquids as a percentage of total production increased to 66% in the second quarter of 2013, up from 59% in the second quarter of 2012.
The average initial production rate for the first 30 days following completion, or IP30, of the 23 wells completed in the first half of 2013 was 505 Boe/d, which is at the upper end of management’s expectations. The average number of days to drill Cleveland wells has been reduced from 28.7 in 2012 to 26.6 in the first half of 2013. Drilling and completion costs were also in line with management’s expectations based on our $3.1 million AFE. The Company currently has 6 rigs running in the Cleveland, and expects 8 to be running by the end of the year. The Company expects to drill approximately 70 gross wells and complete approximately 60 gross wells in 2013.
The Company did not spud any Woodford wells in the second quarter; however, it brought online 5 previously drilled wells. The Company expects to drill an additional 9 gross wells in 2013, all of which will be undergoing batch completion operations in December. Of the 9 wells we expect to drill, 5 will be under our new JDA with Vanguard and 4 will be under our new agreement with BP.
Total daily net production in the Woodford was 4,199 Boe/d, up 3% from the first quarter of 2013 and down 11% from the second quarter of 2012. This second quarter production decrease was due to the pause in drilling over the first half of the year which allowed us to evaluate results prior to signing the Vanguard JDA, and was in line with management expectations and full year 2013 guidance. The Company currently has one rig running in the Woodford, and expects to add an additional rig in the middle of September with both rigs running for the remainder of 2013.
The Company manages a non-operated position in the Hogshooter Granite Wash, which accounts for a relatively small piece of its overall capital program and allocation of resources. During the second quarter of 2013, 1 non-operated well was completed. While the Company’s working interest is generally small in these wells, the results have been strong and we expect to participate in approximately 10 gross wells by the end of the year.
|2013 YTD Operated Drilling Summary (Gross / Net Wells)|
|11 / 8||19 / 14||30 / 22|
|Woodford||3 / 1||- / -||3 / 1|
|Total Operated Wells Drilled||14 / 9||19 / 14||33 / 23|
|7 / 5||16 / 12||23 / 17|
|Woodford||- / -||5 / 1||5 / 1|
|Total Operated Wells Completed||7 / 5||21 / 13||28 / 18|
During the second quarter of 2013 the Company spent $46 million, of which $39 million was related to drilling and completing wells. The table below summarizes the Company’s capital investment by area for the first half of the year.
|2013 YTD Capital Expenditure Summary ($mm)|
|Other Areas and Non-Operated||-||1.2||1.2|
|Leasehold and Other||7.4||7.7||15.1|
|Total Capital Expenditures||$||43.6||$||46.4||$||90.0|
As of June 30, 2013, the Company had borrowings of $445 million outstanding under its revolving credit facility, which had a borrowing base of $500 million, and had $29.4 million of cash and cash equivalents. On July 29, 2013, we closed our initial public offering of 12,500,000 shares of our Class A common stock at a price to the public of $15.00 per share. We received net proceeds of approximately $177.0 million, of which $167.0 million was used to repay outstanding borrowings on the Company’s revolving credit facility and the remainder was used for IPO related expenses and working capital. As of August 29, 2013, the Company had $222.0 million in available borrowings under its revolving credit facility and $253.4 million of liquidity.
The Company had the following commodity derivative contracts outstanding as of August 29, 2013:
|Ending||FYE December 31,|
|Oil, Gas and NGL Swaps|
|Crude Oil (MBbl)||648||1,601||1,158||859||555||4,821|
|Natural Gas (MMcf)||6,350||11,610||9,073||7,220||5,850||40,103|
|Total Swaps (MBoe)||2,561||4,541||3,172||2,159||1,572||14,006|
|Weighted Average Prices|
|Crude Oil ($ / Bbl)||$||90.98||$||90.93||$||89.43||$||87.84||$||85.31||$||89.38|
|Natural Gas ($ / Mcf)||4.82||5.07||5.04||5.15||4.55||4.96|
The table below reflects the Company’s actual data for the first half of 2013, and the Company’s guidance for the second half of 2013 and the full year 2013.
|1H 2013||2H 2013E||2013E|
|Total Production (MMBoe) (1)||3.0||3.1 – 3.5||6.1 – 6.5|
|Average Daily Production (Boe/d) (1)||16,304||17,000 – 19,200||16,600 – 17,900|
|% Oil and Natural Gas Liquids (1)||53%||57% - 60%||54% - 57%|
|Operating Expenses ($/Boe)||$3.91||$3.75 - $4.75||$3.75 – $4.50|
|Production Taxes (% of revenue)||4.7%||
|G&A Expenses ($mm) (2)||$8.8||$9.2 - $12.2||$18.0 - $21.0|
|Capital Expenditures ($mm)||$90.0||$130.0 - $140.0||$220.0 - $230.0|
(1) Company is in ethane rejection in the Woodford. Projections assume
ethane rejection continues throughout 2013.
(2) Excluding non-cash compensation expense.
Conference Call Details
Jones Energy will host a conference call for investors and analysts to discuss its results for the quarter on Wednesday, September 4th, 2013 at 10:00 a.m. ET (9:00 a.m. CT). Participants may join the conference call by dialing (866) 652-5200 (for U.S. and Canada) or (412) 317-6060 (International). If you are not able to participate in the conference call, an audio replay will be available through 9:00 a.m. ET, December 4, 2013, by dialing (877) 344-7529 for domestic U.S., or (412) 317-0088 for international participants, and entering conference code 10033052. A replay of the conference call may also be found on the Company's website, www.jonesenergy.com.
About Jones Energy
Jones Energy, Inc. is an independent oil and natural gas company engaged in the development and acquisition of oil and natural gas properties in the Anadarko and Arkoma basins of Texas and Oklahoma. Additional information about Jones Energy may be found on the Company’s website at: www.jonesenergy.com.
This press release contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements, other than statements of historical facts, included in this press release that address activities, events or developments that the Company expects, believes or anticipates will or may occur in the future are forward-looking statements. Without limiting the generality of the foregoing, forward-looking statements contained in this press release specifically include the expectations of plans, strategies, objectives and anticipated financial and operating results of the Company, including guidance regarding the timing and location of additional rigs, results of the Company's drilling program, 2013 capital budget, ability to fund substantially all of the Company’s 2013 capital expenditure budget with cash flow from operations, customers’ elections to reject ethane and include it as part of the natural gas stream for the remainder of 2013, projections regarding total production, average daily production, percentage liquids, operating expenses, production taxes as a percentage of revenue, G&A expenses and capital expenditure levels for the second half of 2013 and full year 2013. These statements are based on certain assumptions made by the Company based on management's experience and perception of historical trends, current conditions, anticipated future developments and other factors believed to be appropriate. Such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond the control of the Company, which may cause actual results to differ materially from those implied or expressed by the forward-looking statements. These include, but are not limited to, changes in oil and natural gas prices, weather and environmental conditions, the timing of planned capital expenditures, availability of acquisitions, uncertainties in estimating proved reserves and forecasting production results, operational factors affecting the commencement or maintenance of producing wells, the condition of the capital markets generally, as well as the Company's ability to access them, the proximity to and capacity of transportation facilities, and uncertainties regarding environmental regulations or litigation and other legal or regulatory developments affecting the Company's business and other important factors that could cause actual results to differ materially from those projected as described in the Company's reports filed with the SEC.
Any forward-looking statement speaks only as of the date on which such statement is made and the Company undertakes no obligation to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise, except as required by applicable law.
The historical financial information contained in this report relates to periods that ended prior to the completion of the initial public offering (“the Offering”) of 12,500,000 shares of Class A common stock of Jones Energy, Inc. (the “Company”) at a price of $15.00 per share. The Company’s Class A common stock began trading on the New York Stock Exchange (“NYSE”) under the symbol “JONE” on July 24, 2013, and the Offering closed on July 29, 2013. Consequently, the unaudited consolidated financial statements and related discussion of financial condition and results of operations contained in this report pertain to Jones Energy Holdings, LLC (“JEH LLC”), the predecessor entity to the Company. In connection with the completion of the Offering, the Company became a holding company whose sole material asset consists of units of ownership in JEH LLC. As the sole managing member of JEH LLC, the Company is responsible for all operational, management and administrative decisions relating to JEH LLC’s business and will consolidate the financial results of JEH LLC and its subsidiaries.
JEH LLC acts as a holding company of operating subsidiaries that own and operate assets that are used in the exploration, development, production and acquisition of oil and natural gas properties. Prior to the Offering, the equity capital of JEH LLC consisted of several classes of limited liability company units with differing entitlements to distributions. In connection with the Offering, the Jones family, Metalmark Capital, Wells Fargo Central Pacific Holdings, Inc., and certain members of management, or, collectively, the Existing Owners, converted their existing membership interests in JEH LLC into a single class of units (the “JEH LLC Units”), and the Second Amended and Restated Limited Liability Company Agreement of JEH LLC was amended and restated to, among other things, modify JEH LLC’s equity capital to consist solely of the JEH LLC Units and admit the Company as the sole managing member of JEH LLC.
Jones Energy, Inc.
Results of Operations
($ in thousands)
The following table summarizes our revenues and expenses for the periods indicated.
|Three Months Ended June 30,||Six Months Ended June 30,|
|Total oil and gas||64,300||31,105||33,195||119,559||73,622||45,937|
|Total operating revenues||64,526||31,354||33,172||120,006||74,150||45,856|
|Costs and expenses:|
|Depletion, depreciation and amortization||26,922||18,249||8,673||52,023||37,022||15,001|
|Impairment of oil and gas properties||-||43||(43||)||-||61||(61||)|
|Accretion of discount||166||134||32||263||281||(18||)|
|General and administrative||7,325||4,000||3,325||11,637||7,675||3,962|
|Total costs and expenses||44,275||29,502||14,773||81,708||59,310||22,398|
|Other income (expenses):|
|Net gain on commodity derivatives||36,555||30,822||5,733||25,172||38,559||(13,387||)|
|Gain (loss) on sales of assets||(45||)||(72||)||27||25||1,356||(1,331||)|
|Total other income (expense)||28,656||25,198||3,458||9,364||27,763||(18,399||)|
|Income before income tax||48,907||27,050||21,858||47,662||42,603||5,059|
|Income tax provision||252||112||140||251||223||28|
|Jones Energy, Inc.|
($ in thousands)
|June 30,||December 31,|
|Accounts receivable, net|
|Oil and gas sales||41,124||29,684|
|Joint interest owners||29,263||21,876|
|Other current assets||5,156||1,088|
|Commodity derivative assets||18,053||17,648|
|Total current assets||124,810||98,612|
|Oil and gas properties, net, at cost|
|under the successful efforts method||1,046,131||1,007,344|
|Other property, plant and equipment, net||2,764||3,398|
|Commodity derivative assets||34,540||25,199|
|Liabilities and Members' Equity|
|Trade accounts payable||$||60,248||$||38,036|
|Oil and gas sales payable||56,569||45,860|
|Deferred tax liabilities||68||61|
|Asset retirement obligations||174||174|
|Commodity derivative liabilities||2,383||4,035|
|Total current liabilities||124,564||92,039|
|Commodity derivative liabilities||88||7,657|
|Asset retirement obligations||10,023||9,332|
|Deferred tax liabilities||2,086||1,876|
|Class A preferred units; 14,250,000 authorized and issued||222,376||205,970|
|Class B preferred units; 1,500,000 authorized and issued||23,408||21,681|
|Class C preferred units; 8,500,000 authorized and issued||132,644||122,860|
|Common units; 4,500,000 authorized and issued||70,224||65,043|
|Management units; 3,194,444 authorized and issued||19,014||14,228|
|Total members' equity||467,666||429,782|
|Total liabilities and members' equity||$||1,224,427||$||1,150,686|
|Jones Energy, Inc.|
Statement of Cash Flow Data
($ in thousands)
|Six Months Ended June 30,|
|Cash flows from operating activities|
|Adjustments to reconcile net income to net cash|
|provided by operating activities|
|Depletion, depreciation, and amortization||52,023||37,022|
|Impairment of oil and gas properties||-||61|
|Accretion of discount||263||281|
|Amortization of debt issuance costs||1,327||1,765|
|Stock compensation expense||473||283|
|Other compensation expense||2,465||-|
|Gain on commodity derivatives||(25,172||)||(38,559||)|
|Gain on sales of assets||(25||)||(1,356||)|
|Deferred income tax provision||217||223|
|Other - net||310||141|
|Changes in assets and liabilities|
|Accounts payable and accrued liabilities||7,859||(27,339||)|
|Net cash provided by operations||76,810||41,012|
|Cash flows from investing activities|
|Additions to oil and gas properties||(63,545||)||(62,034||)|
|Proceeds from sales of assets||423||9,151|
|Acquisition of other property, plant and equipment||(290||)||(323||)|
|Current period settlements of matured derivative contracts||7,267||11,907|
|Net cash used in investing||(56,145||)||(41,299||)|
|Cash flows from financing activities|
|Proceeds from issuance of long-term debt||-||44,243|
|Repayment under long-term debt||(5,000||)||(34,243||)|
|Payment of debt issuance costs||(25||)||-|
|Distributions to members||(10,000||)||-|
|Net cash (used in) provided by financing||(15,025||)||10,000|
|Net increase in cash||5,640||9,713|
|Beginning of period||23,726||6,136|
|End of period||$||29,366||$||15,849|
|Supplemental disclosure of cash flow information|
|Cash paid for interest||$||13,818||$||10,419|
|Noncash oil and gas property additions||26,312||(3,546||)|
|Current additions to ARO||263||166|
|Deferred offering costs||3,479||-|
|Noncash distributions to members||10,000||-|
Jones Energy, Inc.
Selected Financial and Operating Statistics
The following table sets forth summary data regarding production volumes, average prices and average production costs associated with our sale of oil and natural gas for the periods indicated.
|Three Months Ended June 30,||Six Months Ended June 30,|
|Net production volumes:|
|Natural gas (MMcf)||4,138||3,268||870||8,404||6,812||1,592|
|Average net (Boe/d)||16,725||12,209||4,516||16,304||12,934||3,370|
|Average sales price, unhedged:|
|Oil (per Bbl), unhedged||$||88.80||$||90.12||$||(1.32||)||$||88.62||$||94.48||$||(5.87||)|
|Natural gas (per Mcf), unhedged||3.60||1.53||2.07||3.29||1.82||1.47|
|NGLs (per Bbl), unhedged||30.37||
|Combined (per Boe), unhedged||42.25||28.00||14.25||40.51||31.45||9.07|
|Average sales price, hedged:|
|Oil (per Bbl), hedged||$||86.75||$||88.33||$||(1.58||)||$||86.54||$||89.39||$||(2.85||)|
|Natural gas (per Mcf), hedged||4.11||3.77||0.34||4.06||3.81||0.25|
|NGLs (per Bbl), hedged||33.26||35.65||(2.39||)||35.05||36.47||(1.41||)|
|Combined (per Boe), hedged||43.86||37.16||6.70||42.62||38.04||4.58|
|Average costs (per BOE):|
|Depletion, depreciation and amortization||17.69||16.43||1.26||17.63||15.81||1.81|
|General and administrative||4.81||3.60||1.21||3.94||3.28||0.66|
Jones Energy, Inc.
Non-GAAP Financial Measures and Reconciliations
($ in thousands)
Adjusted EBITDAX is a supplemental non-GAAP financial measure that is used by management and external users of our consolidated financial statements, such as industry analysts, investors, lenders and rating agencies.
We define Adjusted EBITDAX as earnings before interest expense, income taxes, depreciation, depletion and amortization, exploration expense, unrealized gains and losses from derivatives, and other items. Adjusted EBITDAX is not a measure of net income as determined by United States generally accepted accounting principles, or GAAP. Management believes Adjusted EBITDAX is useful because it allows them to more effectively evaluate our operating performance and compare the results of our operations from period to period and against our peers without regard to our financing methods or capital structure. We exclude the items listed above from net income in arriving at Adjusted EBITDAX because these amounts can vary substantially from company to company within our industry depending upon accounting methods and book values of assets, capital structures and the method by which the assets were acquired. Adjusted EBITDAX has limitations as an analytical tool and should not be considered as an alternative to, or more meaningful than, net income as determined in accordance with GAAP or as an indicator of our liquidity. Certain items excluded from Adjusted EBITDAX are significant components in understanding and assessing a company’s financial performance, such as a company’s cost of capital and tax structure, as well as the historical costs of depreciable assets. Our presentation of Adjusted EBITDAX should not be construed as an inference that our results will be unaffected by unusual or non-recurring items. Our computations of Adjusted EBITDAX may not be comparable to other similarly titled measures of other companies.
The following table sets forth a reconciliation of net income (loss) as determined in accordance with GAAP to Adjusted EBITDAX for the periods indicated:
|Three Months Ended June 30,||Six Months Ended June 30,|
|(in thousands of dollars)||2013||2012||2013||2012|
|Reconciliation of Adjusted EBITDAX|
|to net income|
|Interest expense (excluding amortization of|
|deferred financing costs)||7,190||4,669||14,506||10,387|
|Amortization of deferred financing costs||664||883||1,327||1,765|
|Depreciation and depletion||26,922||18,249||52,023||37,022|
|Impairment of oil and natural gas properties||-||43||-||61|
|Other non-cash charges||145||201||310||141|
|Stock compensation expense||352||142||473||283|
|Other compensation expense||2,465||-||2,465||-|
|Net gain on derivative contracts||(36,555||)||(30,822||)||(25,172||)||(38,559||)|
|Current period settlements of matured|
|Loss (gain) on sales of assets||45||72||(25||)||(1,356||)|