There were 759 press releases posted in the last 24 hours and 155,438 in the last 365 days.

Sundance Energy Australia Limited Reports First Quarter 2019 Financial and Operational Results

DENVER, May 16, 2019 (GLOBE NEWSWIRE) -- Sundance Energy Australia Limited (ASX: SEA) (NASDAQ: SNDE) (“Sundance” or the “Company”), a U.S. onshore oil and gas exploration and production company focused in the Eagle Ford in South Texas, reported its first quarter 2019 financial and operations results today.

/EIN News/ -- First Quarter 2019 Financial Results Highlights

  • First quarter net sales volumes were 1,107,222 boe or 12,302 boe per day, at the top end of the Company’s public guidance. This represents an increase of ~87% as compared to the same period for the prior year. First quarter sales volumes were ~63% oil, ~22% gas and ~15% NGLs.
  • Total revenue for the quarter increased ~99% to US $47.7 million as compared to the same prior year period.
  • Net Loss attributable to owners of the Company for the period was US $31.4 million, largely attributable to an unrealized loss on hedging of $37.1 million. Adjusted EBITDAX1 for the period was US $31.7 million, representing a ~62% Adjusted EBITDAX margin.
  • Average first quarter realized prices excluding the impact of hedging were US $56.47 per barrel of oil, US $2.58 per mmbtu of gas, and US $21.23 per barrel of NGL. This compares to an average WTI price of $54.82 for the quarter. Average first quarter price per boe was US$46.50.
  • Total cash operating costs for the quarter of US $17.90 per boe improved ~5% as compared to US $18.88 per boe for the same prior year period due to lower cash General and Administrative (“G&A”), Lease Operating Expense (“LOE”) and Workover expenses per boe. Cash operating costs for the quarter came in US $1.80 per boe, or ~9%, below guidance of US $19.70 per boe for the quarter.
  • As of 16 May 2019, the Company’s oil hedges covered a total of 5,371,000 barrels through 2023. Hedging covered approximately ~7,776 barrels of oil per day for the remainder of 2019 with a weighted average floor of US $61.09. These figures exclude hedges which have rolled off during the first four months of 2019.
  • First quarter development and production related expenditures totaled US $41.3 million primarily driven by the Company drilling faster than expected, incurring incremental capital costs of approximately $11 million which will reduce 2H 2019 capital expenditures.
  • Subsequent to the quarter’s end, on 16th May 2019 the Company announced a ~39% increase in its Senior Secured Borrowing Base Facility from US $122.5 million to US $170.0 million.

First Quarter 2019 Operational Highlights

  • Sundance brought 2.0 gross (2.0 net) wells onto production during the first quarter on its legacy acreage in Dimmit County. Immediately subsequent to the quarter’s end on April 1st, Sundance additionally brought online the 2.0 gross (2.0 net) well Bracken pad in McMullen County which was drilled during the quarter.
  • During the first quarter the Company additionally drilled the 4.0 gross (4.0 net) well Georgia Buck pad in Live Oak County. The Company exited the quarter with 8.0 gross (8.0 net) drilled uncompleted (“DUC”) wells in Live Oak, all of which it intends to complete during the second quarter. The 4.0 gross (4.0 net) well Roy Esse pad has begun flowing back as of the date of this report, while the Georgia Buck pad will be turned to sales early in the third quarter.
  • As of the date of this report, the Company was in the process of drilling the 4.0 gross (4.0 net) well HT Chapman pad in Live Oak County.
  • As of the date of this report, two additional compressors have been delivered to the CGP-41 gas processing plant. One of the compressors has been tied in, and the second is in the process of being tied in. Upon completion of this capacity expansion, the previously disclosed midstream constraints will be entirely removed at no material capital cost to Sundance. Sundance’s midstream partner is contractually obligated to fund certain infrastructure upgrades up to approximately US $10 million through the contractual term ending in 2022.

Second Quarter and Full Year 2019 Guidance Highlights

  • Sundance’s 2019 plan remains unchanged. The Company intends to operate within cash flow while still providing attractive production and Adjusted EBITDAX growth. The Company’s 2019 plan was formulated assuming a conservative $50 oil price environment. Any incremental cash flow from more elevated commodity prices will be utilized to pay down debt or for additional investment activities as appropriate.
  • During the second quarter, the Company anticipates average sales volumes of 13,500 to 14,000 boe per day for 2019. Sales volumes guidance for full year 2019 remains unchanged.
  • The Company anticipates second quarter EBITDAX of US $35 to $40 million.
  • The Company still intends to bring 25 wells online during full year 2019, at a capital cost of US $135 to $155 million. During the second quarter, the Company intends to spud 8 total wells and place 6 wells onto production, with the 4 well Georgia Buck pad expected to begin producing early in the third quarter.

____________
1 Adjusted EBITDAX is a Non-IFRS measure, please see reconciliation to net income (loss) attributable to owners of Sundance at the end of this release. 

 

The table below provides an overview of the Company’s operational activity for year-to-date 20192:

Well Name County Spud
Date
Frac Start
Date
IP
Date
Lateral
Length
30-Day IP
(boe/d)
%
Oil
60-Day IP
(boe/d)
Roy Esse 15H Live Oak 1-Dec-18 7-Apr-19 4-May-19 4,718' - - -
Roy Esse 16H Live Oak 28-Nov-18 7-Apr-19 4-May-19 4,792' - - -
Roy Esse 17H Live Oak 26-Nov-18 7-Apr-19 4-May-19 4,657' - - -
Roy Esse 18H Live Oak 24-Nov-18 7-Apr-19 4-May-19 4,702' - - -
Bracken 22H McMullen 24-Jan-19 11-Mar-19 1-Apr-19 6,792' 1,053 76% -
Bracken 23H McMullen 22-Jan-19 11-Mar-19 1-Apr-19 6,630' 856 76% -
Georgia Buck 01H Live Oak 21-Feb-19 - - - - - -
Georgia Buck 02H Live Oak 23-Feb-19 - - - - - -
Georgia Buck 03H Live Oak 25-Feb-19 - - - - - -
Georgia Buck 10H Live Oak 26-Feb-19 - - - - - -
Chapman 11H Live Oak 16-Apr-19 - - - - - -
Chapman 12H Live Oak 14-Apr-19 - - - - - -
Chapman 13H Live Oak 12-Apr-19 - - - - - -
Chapman 14H Live Oak 10-Apr-19 - - - - - -

____________
2 Excludes the held for sale Red Ranch 18H & 19H wells in Dimmit County which were DUC wells at 12/31/18 and were brought online in February 2019.

 


The tables below set forth the Company’s hedge position as of 16th May 20193:

HEDGE POSITION OVERVIEW          
  Total Oil Derivative Contracts Gas Derivative Contracts          
  Weighted Average Weighted Average          
Year Units (Bbls) Floor
Ceiling
Units (Mcf) Floor
Ceiling
         
2019 1,905,000   61.09     67.74   2,088,000   2.86     3.13            
2020 2,046,000   56.92     60.49   1,536,000   2.65     2.70            
2021 732,000   50.37     59.34   1,200,000   2.66     2.66            
2022 528,000   45.68     60.83   1,080,000   2.69     2.69            
2023 160,000   40.00     63.10   240,000   2.64     2.64            
Total 5,371,000 $55.90   $63.02   6,144,000 $2.73   $2.83            
                               
CRUDE OIL HEDGE POSITION BY BASIS
  LLS Derivative Contracts Brent Derivative Contracts WTI Derivative Contracts
  Weighted Average Weighted Average Weighted Average
Year Units (Bbls) Floor
Ceiling
Units (Bbls) Floor
Ceiling
Units (Bbls) Floor Ceiling
2019 112,000 $52.51   $62.51   613,000 $60.59   $70.09   1,180,000 $62.17   $67.02  
2020 - -   -   - -   -   2,046,000 $56.92   $60.49  
2021 - -   -   - -   -   732,000 $50.37   $59.34  
2022 - -   -   - -   -   528,000 $45.68   $60.83  
2023 - -   -   - -   -   160,000 $40.00   $63.10  
Total 112,000 $52.51   $62.51   613,000 $60.59   $70.09   4,646,000 $55.36   $62.09  

____________
3 Excludes realized hedge volumes which rolled off during the first four months of 2019.

 


The following unaudited tables present certain production, per unit metrics and Adjusted EBITDAX that compare results of the corresponding quarterly reporting periods:

  Three Months Ended March 31,
   
Unaudited   2019       2018     % Change
Net Sales Volumes              
Oil (Bbls)     722,396         365,241     98 %
Natural gas (Mcf)     1,272,546         884,423     44 %
NGL (Bbls)     172,736         79,513     117 %
Total sales (Boe)     1,107,222         592,158     87 %
           
Average Daily Volumes          
Average daily sales   12,302         6,580     87 %
           
Product Price Received          
Total price received (per Boe) $ 43.12     $ 40.59     6 %
Total realized price (per Boe)(1)(2)(3) $ 46.50     $ 37.92     23 %
Total price received - Oil (per Bbl) $ 56.47     $ 55.15     2 %
Total price realized - Oil (per Bbl)(1) $ 61.15     $ 50.80     20 %
Total price received - Natural gas (per Mcf) $ 2.58     $ 2.46     5 %
Total price realized - Natural gas (per Mcf)(2) $ 2.73     $ 2.47     11 %
Total price received - NGL (per Bbl) $ 21.23     $ 21.60     (2 %)
Total price realized - NGL (per Bbl)(3) $ 22.23     $ 21.60     3 %
           
           
(1) Includes realized gains on oil derivatives of $3.4 million and realized losses of $1.6 million for the three months ended March 31, 2019 and 2018, respectively. 
 
(2) Includes realized gains on natural gas derivatives of $0.2 million and realized losses of $6.7 thousand for the three months ended March 31, 2019 and 2018, respectively.
 
(3) Includes realized gains on NGL derivatives of $172.8 thousand for the three months ended March 31, 2019 and nil for the three months ended March 31, 2018. 
           


           
UNIT COST ANALYSIS Three Months Ended March 31,    
Unaudited   2019       2018     % Change
Revenue/Boe (Inclusive of Hedging) $ 46.50     $ 37.92     23 %
Lease operating expense/Boe   (7.84 )     (9.20 )   (15 %)
Workover expense/Boe   (1.31 )     (2.05 )   (36 %)
Gathering, processing and transportation /Boe   (2.55 )     0.00     100 %
Production taxes/Boe   (2.83 )     (3.13 )   (10 %)
Cash G&A/Boe(1)   (3.37 )     (4.50 )   (25 %)
Net EBITDAX Margin per Boe $ 28.60     $ 19.04     50 %
           
Adjusted EBITDAX(2) $ 31,705     $ 11,279     181 %
Adjusted EBITDAX Margin (3)   61.6 %     50.2 %   23 %
           
(1) Cash G&A represents general and administrative expenses (non transaction-related) incurred less equity-settled share based compensation expense, which totaled $0.1 million and $0.4 million for the three months ended March 31, 2019 and 2018, respectively.
           
(2) See reconciliation of loss attributable to owners of the Company to Adjusted EBITDAX included at end of release.
           
(3) Adjusted EBITDAX Margin represents Adjusted EBITDAX as a percentage of revenue, inclusive of commodity derivative settlements, during the period.
           

 

 

 

Condensed Consolidated Financial Statements
The Company’s condensed consolidated financial statements are included below.

CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS
       
  Three Months Ended March 31,
Unaudited (US$000s)   2019       2018  
Revenue $   47,740     $   24,036  
Lease operating, workover and production tax expenses     (13,257 )       (8,515 )
Gathering, processing and transportation expenses     (2,825 )       -   
General and administrative expenses (non-transaction related)     (3,868 )       (3,031 )
Transaction-related expense     (527 )       (1,026 )
Depreciation and amortisation expense     (20,338 )       (12,187 )
Impairment expense     (3,479 )       (2,957 )
Finance costs, net of amounts capitalized     (8,243 )       (3,982 )
Loss on commodity hedging, net (1)     (33,343 )       (6,684 )
Loss on interest rate derivative financial instruments, net     (1,620 )       -   
Other items income, net     19         1,066  
       
Loss before income tax      (39,741 )       (13,280 )
       
Income tax benefit (expense)     8,320         (2,303 )
       
Loss attributable to owners of the Company $    (31,421 )   $    (15,583 )
       
       
(1) Included an unrealised loss on commodity hedging of $37.1 and $5.1 million for the three months ended March 31, 2019 and 2018, respectively.
 

 

 
CONDENSED CONSOLIDATED BALANCE SHEETS
       
(US$'000s) March 31, 2019(2)   December 31, 2018
  (Unaudited)   (Audited)
Cash $ 3,923     $ 1,581  
Trade and other receivables     16,527         23,633  
Derivative assets - current     481         24,315  
Other current assets     3,929         3,546  
Assets held for sale(1)     29,189         24,284  
Total current assets     54,049         77,359  
       
Oil and gas properties     728,005         712,870  
Derivative assets - non current     1,941         8,003  
Other assets     3,753         3,847  
Total assets $ 787,748     $ 802,079  
       
Current liabilities $ 56,144     $ 70,919  
Derivative liabilities - current     3,919         436  
Liabilities held for sale(1)     1,140         1,125  
Total current liabilities     61,203         72,480  
       
Credit facilities, net of financing fees $ 331,288     $ 300,440  
Derivative liabilities - non current     8,020         2,578  
Other non current liabilities     25,174         33,207  
Total liabilities $ 425,685     $ 408,705  
       
Net assets $ 362,063     $ 393,374  
Equity $ 362,063     $ 393,374  
       
(1) The Company's Dimmit County Eagle Ford assets (and related liabilities) were classified as held for sale as of March 31, 2019 and December 31, 2018. 
 
(2) The Company is in the process of finalizing its implementation of IFRS 16 - Leases, which was effective as of January 1, 2019.  The 2019 unaudited condensed financial statements presented in this release do not reflect the impact of IFRS 16.  The Company anticipates that it will recognize approximately $11 to $13 million of right to use assets and a corresponding lease liability on its balance sheet as of March 31, 2019. The first full interim financial statements issued by the Company in 2019 will reflect the implementation of this standard. 
       

 

       
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS
       
  Three Months Ended March 31,
Unaudited (US$000s)   2019       2018  
Operating      
Receipts from sales $   50,183     $   25,896  
Payments for operating and administrative expenses     (23,286 )       (9,026 )
Receipts (payments) for commodity derivative settlements, net     7,527         (1,613 )
Other, net     -          (2,324 )
Net cash provided by operating activities  $ 34,424     $ 12,933  
       
Investing      
Payments for development expenditures     (54,558 )       (7,058 )
Payments for exploration expenditures     (230 )       (1,359 )
Payment for Eagle Ford acquisition, net     -          (48,000 )
Other     (17 )       (62 )
Net cash used in investing activities ($ 54,805 )   ($ 56,479 )
       
Financing      
Proceeds from the issuance of shares     -          47,585  
Proceeds from foreign currency derivatives     -          991  
Interest paid, net of capitalized portion     (7,308 )       (3,648 )
Proceeds from borrowings     30,000         -   
Repayments of borrowings (including production prepayment)     -          (6,415 )
Other     36         -   
Net cash used in financing activities $ 22,728     $ 38,513  
       
Total Net Cash Provided (Used) $ 2,347     ($ 5,033 )
       
Cash beginning of period $ 1,581     $ 5,761  
FX effect      (5 )       338  
Cash at end of period $ 3,923     $ 1,066  
       


Conference Call
The Company will host a conference call for investors on Thursday 16th May, 2019 at 4 p.m. MDT (Friday, 17th May, 2019 at 9 a.m. AEDT).

Interested investors can listen to the call via webcast at https://edge.media-server.com/m6/p/4tsj3ygb. The webcast will also be available for replay on the Company’s website.

Additional Information
We define “Adjusted EBITDAX”, a non-IFRS measure, as earnings before interest expense, income taxes, depreciation, depletion and amortization, property impairments, gain/(loss) on sale of non-current assets, exploration expense, share based compensation and income, gains and losses on commodity hedging, net of settlements of commodity hedging and items that the Company believes affect the comparability of operating results such as items whose timing and/or amount cannot be reasonably estimated or items that are non-recurring. Management uses Adjusted EBITDAX to facilitate comparisons of its performance between periods and to the performance of its peers.  This non-IFRS financial measure should not be considered as a substitute for, nor superior to, measures of financial performance prepared in accordance with IFRS. 

Below is a reconciliation from the net income (loss) attributable to owners of the Company to Adjusted EBITDAX:

IFRS Income (Loss) Attributable to Owners of Sundance Reconciliation to Adjusted EBITDAX
   Three Months Ended March 31, 
Unaudited (US$000s)   2019       2018  
Loss attributable to owners of the Company ($31,421 )   ($15,583 )
Income tax expense (benefit)     (8,320 )       2,303  
Finance costs, net of amounts capitalized     8,243         3,982  
Loss on derivative financial instruments, net     33,343         6,684  
Settlement of commodity derivatives financial instruments     3,751         (1,583 )
Loss on interest rate derivative financial instruments, net     1,620         -   
Depreciation and amortization     20,338         12,187  
Impairment expense     3,479         2,957  
Noncash share-based compensation     135         369  
Transaction-related costs included in general and administrative expenses and other     537         1,036  
Gain on foreign currency derivatives     -          (1,073 )
Adjusted EBITDAX $31,705     $11,279  

The Company reports under International Financial Reporting Standards (IFRS).  All amounts are reported in US dollars unless otherwise noted. 

The Company’s full Unaudited Activities Report as filed with the Australian Securities Exchange (ASX) and Securities and Exchange Commission on Form 6-K for the Quarter Ended March 31, 2019 can be found at www.sundanceenergy.net

The Company’s 2018 Annual Report as filed with the ASX and Form 20-F as filed with the SEC can be found at www.sundanceenergy.net.

About Sundance Energy Australia Limited

Sundance Energy Australia Limited (“Sundance” or the “Company”) is an Australian-based, independent energy exploration company, with a wholly owned US subsidiary, Sundance Energy Inc., located in Denver, Colorado, USA. The Company is focused on the acquisition and development of large, repeatable oil and natural gas resource plays in North America. Current activities are focused in the Eagle Ford.  A comprehensive overview of the Company can be found on Sundance’s website at www.sundanceenergy.net

Summary Information

The following disclaimer applies to this document and any information contained in it. The information in this release is of general background and does not purport to be complete. It should be read in conjunction with Sundance’s periodic and continuous disclosure announcements lodged with ASX Limited that are available at www.asx.com.au and Sundance’s filings with the Securities and Exchange Commission available at www.sec.gov

Forward Looking Statements

This release may contain forward-looking statements. These statements relate to the Company’s expectations, beliefs, intentions or strategies regarding the future. These statements can be identified by the use of words like “anticipate”, “believe”, “intend”, “estimate”, “expect”, “may”, “plan”, “project”, “will”, “should”, “seek” and similar words or expressions containing same.

These forward-looking statements reflect the Company’s views and assumptions with respect to future events as of the date of this release and are subject to a variety of unpredictable risks, uncertainties, and other unknowns. Actual and future results and trends could differ materially from those set forth in such statements due to various factors, many of which are beyond our ability to control or predict. These include, but are not limited to, risks or uncertainties associated with the discovery and development of oil and natural gas reserves, cash flows and liquidity, business and financial strategy, budget, projections and operating results, oil and natural gas prices, amount, nature and timing of capital expenditures, including future development costs, availability and terms of capital and general economic and business conditions. Given these uncertainties, no one should place undue reliance on any forward looking statements attributable to Sundance, or any of its affiliates or persons acting on its behalf.  Although every effort has been made to ensure this release sets forth a fair and accurate view, we do not undertake any obligation to update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

For more information, please contact:

United States:
John Roberts
VP Finance & Investor Relations
Tel: +1 (720) 638-2400
Eric McCrady
CEO and Managing Director
Tel: +1 (303) 543-5703
   
Australia:
Mike Hannell
Chairman
Tel: + 61 8 8274 2128 or
+ 61 418 834 957
 

 


EIN Presswire does not exercise editorial control over third-party content provided, uploaded, published, or distributed by users of EIN Presswire. We are a distributor, not a publisher, of 3rd party content. Such content may contain the views, opinions, statements, offers, and other material of the respective users, suppliers, participants, or authors.