November 6, 2018 - 9:01 PM EST
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Surge Energy Inc. Announces Third Quarter 2018 Results; Average Q3 Production Exceeds 2018 Exit Rate Guidance; Adjusted Funds Flow Per Share Up 80 Percent Over Q3/17

Canada NewsWire

CALGARY, Nov. 6, 2018 /CNW/ - Surge Energy Inc. ("Surge" or the "Company") (TSX: SGY) announces its operating and financial results for the quarter ended September 30, 2018.

FINANCIAL AND OPERATING HIGHLIGHTS



Three Months Ended September 30,


Nine Months Ended September 30, 

($000s except per share amounts)

2018

2017

% Change


2018

2017

% Change

Financial highlights








Oil sales

85,946

50,563

70 %


233,954

152,973

53 %

NGL sales

3,598

2,158

67 %


8,546

6,680

28 %

Natural gas sales

1,492

3,704

(60)%


3,920

11,995

(67)%

Total oil, natural gas, and NGL revenue

91,036

56,425

61 %


246,420

171,648

44 %

Cash flow from operating activities

37,197

24,589

51 %


95,137

65,042

46 %

Per share - basic ($)

0.16

0.11

45 %


0.41

0.29

41 %

Adjusted funds flow1

40,638

22,985

77 %


107,403

71,643

50 %

Per share - basic ($)1

0.18

0.10

80 %


0.46

0.32

44 %

Total exploration and development expenditures

28,701

26,652

8 %


86,954

75,757

15 %

Total acquisition and dispositions

6,279

36,650

(83)%


28,733

72,097

(60)%

Total capital expenditures

34,980

63,302

(45)%


115,687

147,854

(22)%

Net debt1, end of period

282,394

246,398

15 %


282,394

246,398

15 %









Operating highlights








Production:








Oil (bbls per day)

13,560

11,380

19 %


13,120

11,071

19 %

NGLs (bbls per day)

669

627

7 %


595

663

(10)%

Natural gas (mcf per day)

22,797

17,997

27 %


20,004

17,618

14 %

Total (boe per day) (6:1)

18,029

15,007

20 %


17,049

14,670

16 %

Average realized price (excluding hedges):








Oil ($ per bbl)

68.89

48.29

43 %


65.32

50.62

29 %

NGL ($ per bbl)

58.46

37.42

56 %


52.57

36.92

42 %

Natural gas ($ per mcf)

0.71

2.24

(68)%


0.72

2.49

(71)%









Netback ($ per boe)








Petroleum and natural gas revenue

54.89

40.87

34 %


52.94

42.86

24 %

Realized gain (loss) on financial contracts

(1.91)

0.12

nm2


(1.84)

(0.71)

159 %

Royalties

(8.32)

(5.27)

58 %


(7.68)

(5.49)

40 %

Net operating expenses1

(14.36)

(13.73)

5 %


(14.37)

(13.54)

6 %

Transportation expenses

(1.55)

(1.40)

11 %


(1.48)

(1.48)

—%

Operating netback3

28.75

20.59

40 %


27.57

21.64

27 %

G&A expense

(1.98)

(1.94)

2 %


(2.08)

(1.94)

7 %

Interest expense

(2.27)

(2.01)

13 %


(2.42)

(1.81)

34 %

Adjusted funds flow netback3

24.50

16.64

47 %


23.07

17.89

29 %









Common shares outstanding, end of period

233,618

232,920

0 %


233,618

232,920

0 %

Weighted average basic shares outstanding

231,988

228,309

2 %


231,932

226,623

2 %

Stock option dilution

4,234

nm


4,736

6,357

(25)%

Weighted average diluted shares outstanding

236,222

228,309

3 %


236,668

232,980

2 %

1 This is a non-GAAP financial measure which is defined in the Non-GAAP Financial Measures section of this document.

2 The Company views this change calculation as not meaningful, or "nm".

3 See the Additional Metrics section of this document for further information.

 

In accordance with industry practice, the Company uses adjusted funds flow to analyze the cash flow generated from its ongoing principal business activities. On this basis, both adjusted funds flow and cash flow from operating activities are provided for comparative purposes. Please see the Non-GAAP Financial Measures section of this release for further details.

MESSAGE TO THE SHAREHOLDERS

Based on continued successful development of Surge's Sparky, Valhalla, and Shaunavon core areas, the Company's Q3/18 production rate averaged 18,029 boepd. The Company's Q3/18 production exceeded Surge's previously released 2018 production exit rate guidance of 17,175 boepd by five percent, and exceeded analyst consensus production estimates of 16,880 boepd4 for Q3/18 by seven percent.

Over the last nine financial quarters Surge has now grown the Company's production per share by 41 percent. As a result of this consistent production per share growth, combined with higher oil prices, Surge's adjusted funds flow per share in Q3/18 increased by 80 percent as compared to Q3/17, and cash flow from operating activities per share increased by 45 percent as compared to Q3/17.    

Surge's continued quarterly operational outperformance has been accomplished to date within the Company's existing capital expenditure budget guidance of $107 million for 2018.

The Company's previously announced $320 million, accretive, light oil acquisition (the "Acquisition") of an Alberta based, private oil company named Mount Bastion Oil and Gas Corp. ("Mount Bastion" or "MBOG"), closed on October 25, 2018, and provided no operational or financial contribution to Surge's Q3/18 results below.

Q3/18 HIGHLIGHTS

  • Surge's Q3/18 quarterly average production of 18,029 boepd (79 percent oil and liquids) increased by more than 20 percent over Q3/17 production of 15,007 boepd (18 percent per share), and increased by six percent as compared to Q2/18 production of 17,072 boepd (five percent per share).
  • At Betty Lake, the Company drilled four wells to follow up Surge's discovery well drilled in Q4/17. All four of these wells were successful, and production from the pool is now greater than 600 boepd (83 percent oil).
  • Cash flow from operating activities in Q3/18 was $37.2 million ($0.16 per share), an increase of more than 50 percent as compared to Q3/17 at $24.6 million ($0.11 per share).
  • Adjusted funds flow in Q3/18 was $40.6 million ($0.18 per share), an increase of 77 percent as compared to Q3/17 at $23 million ($0.10 per share).
  • The Company's operating netback per boe increased by 40 percent, to $28.75 per boe in Q3/18, from $20.59 per boe in Q3/17.
  • Surge reported a dividend payout ratio5 of 14 percent for Q3/18;
  • The Company had an all-in payout ratio6 of 85 percent in Q3/18, while maintaining a net debt7 to adjusted funds flow ratio6 of 1.74 times.
  • On October 25, 2018 Surge announced:
    • The closing of the Company's accretive $320 million light oil Acquisition; and
    • The Company's revolving credit facility increased by 57 percent to $550 million, up from $350 million previously. The Company estimates $150 million in undrawn capacity at October 25, 2018.

______________________

4 Consensus average production of 16,880 boepd as per Thomson Reuters as at October 23rd, 2018.

5 This is a capital management measure which is defined in the Capital Management Measures section of this document.

 

NINE QUARTERS OF PER SHARE GROWTH

Surge has now delivered production per share growth of 41 percent over the last nine financial quarters, and has upwardly revised guidance five times over this period:

48% Production Growth Over The Last 9 Quarters (CNW Group/Surge Energy Inc.)

Surge's consistent production per share growth, combined with higher crude oil prices, is driving significant increases in the Company's adjusted funds flow and cash flow from operating activities per share. Surge's strong Q3/18 results were achieved with WCS differentials for the quarter averaging approximately 15 percent wider than Q2/18.

______________________

6 This is a capital management measure which is defined in the Capital Management Measures section of this document.

7 This is a non-GAAP financial measure which is defined in the Non-GAAP Financial Measures section of this document.

 

$320 MILLION ACCRETIVE LIGHT OIL ACQUISITION

Pursuant to the Company's press release dated October 25, 2018, Surge announced the Closing of the MBOG Acquisition.

The Acquisition includes 5,500 boepd (98 percent liquids) of operated, light oil production in the Greater Sawn Area and has a base annual production decline of 21 percent. The combination of Surge and MBOG results in a 22,500 boepd (85 percent oil-weighted), light and medium gravity, intermediate, growth and dividend paying company.

OPERATIONAL HIGHLIGHTS

Surge spent a total of $28.7 million of exploration and development capital in the third quarter of 2018 for the drilling of 12 gross (11.8 net) wells, along with waterflood injector conversions, associated infrastructure, land and seismic.  

In the Sparky core area, Surge drilled six gross (5.8 net) wells. At Betty Lake, the Company drilled four wells to follow up the discovery well drilled in Q4/17. All four of the Betty Lake drills were successful and production from the pool is now greater than 600 boepd (83 percent oil). The Company now estimates more than 50 net follow-up locations8 (five net booked) at Betty Lake. Surge also drilled two successful Sparky oil wells at Eyehill in the quarter, and converted two additional wells to water injection. 

At Valhalla, Surge successfully drilled and completed one gross (one net) Doig well. Over half of this well was positioned less than 200m from the nearest offset. The initial pressure for the well was 95 percent of the original pressure, which exceeded management's expectations, and further validates the Company's ongoing downspacing program.

Surge also successfully drilled five (five net) wells at its Shaunavon core area in Q3/18, targeting both the Upper and Lower Shaunavon formations. These five successful wells are producing a combined rate of more than 500 boepd.  The Company also continued its ongoing pumpjack conversion program. To date, 38 wells have been converted from progressive cavity pumps to pumpjacks, for a total combined production add of over 550 boepd net to Surge at a cost of less than $10,000 per flowing boepd.  

Despite the recent widening of Canadian oil differentials, approximately 33 percent of the Company's estimated fourth quarter oil production is either located downstream of recent apportionment points or trucked to sales points unaffected by apportionment. Notwithstanding this, Surge expects its average realized crude oil price in the fourth quarter to be lower compared to the third quarter, based on realized prices to date and current forward pricing.

2018 CAPITAL PROGRAM - ADDITIONAL CAPITAL ALLOCATED TO ACQUIRED ASSETS

Following the acquisition of the MBOG assets, the Company plans to drill two incremental light oil wells at Sawn, as well as undertake infrastructure modifications and 3D seismic acquisitions. Accordingly, budgeted capital expenditures for 2018 have now been increased from $107 million to $117 million. Surge anticipates the additional Sawn wells will come on production in early January 2019.

______________________

8 See Drilling Locations section of this document for further information

 

OUTLOOK – CONSISTENT QUARTERLY PER SHARE GROWTH

Management's stated goal is to be the best positioned, top performing, light/medium gravity crude oil growth and dividend paying public company in our peer group, in Canada.

Over the last nine financial quarters (i.e. prior to the MBOG Acquisition), Surge has continued to build and maintain the Company's track record, delivering: 

  1. consistent successful drilling and waterflood results;
  2. timely and accretive core area acquisitions; 
  3. increased production per share by more than 41 percent;
  4. increased cash flow from operating activities per share by over 125 percent; 
  5. increased adjusted funds flow per share by over 80 percent;
  6. increased Surge's dividend three times by a cumulative 33 percent, while maintaining a dividend payout ratio9 of under 20 percent.

During the extremely volatile period from the announcement of the Acquisition on September 5th, 2018 until today: 1) US$ WTI prices have fallen from a high of US $76.24 to as low as US $62.17 per barrel; 2) the Canadian oil industry has experienced an unprecedented widening of Edmonton to WTI light oil differentials, which have increased from US$10/bbl to as high as US$41/bbl; and 3) Canadian WCS crude oil differentials to WTI have widened dramatically, from US$24.50/bbl to as high as $46/bbl. On this basis, given Surge's disciplined approach to the dividend policy, the Company's Board of Directors and management will be analyzing whether to defer some portion or all of the previously anticipated dividend increase from $0.10 per share to $0.125 per share, based on market conditions. Surge's next dividend payment announcement is November 15, 2018.

The Company continues to focus on sustainability, balance sheet management, and cost controls to deliver returns to Surge shareholders. The Company continues to grow its production base and 11 year drilling inventory in its existing Sparky, Shaunavon, and Valhalla core areas - through low risk development drilling results, waterfloods, and strategic, high quality, large OOIP10, core area acquisitions. The Acquisition of the MBOG assets brings a fourth core area to further expand the Company's light oil development drilling and waterflood inventory.

Surge anticipates confirming 2019 guidance in early January, 2019. 

______________________

9 This is a capital management measure which is defined in the Capital Management Measures section of this document.

10 Original Oil in Place (OOIP) is the equivalent to Discovered Petroleum Initially In Place (DPIIP) for the purpose of this press release.

 

FORWARD LOOKING STATEMENTS:

This press release contains forward-looking statements. The use of any of the words "anticipate", "continue", "estimate", "expect", "may", "will", "project", "should", "believe" and similar expressions are intended to identify forward-looking statements. These statements involve known and unknown risks, uncertainties and other factors that may cause actual results or events to differ materially from those anticipated in such forward-looking statements.

More particularly, this press release contains statements concerning: the impact of the Acquisition on Surge and its results and development plans; Surge's dividend payout ratio and all-in payout ratio; anticipated 2018 exit rate production; management's expectations with respect to the development of the Sawn asset and the timing thereof; Surge's declared focus and primary goals; Surge's annual exploration and development capital expenditure program and budget; anticipated Q4 realized crude oil prices; commodity prices; availability of undrawn capacity with respect to Surge's credit facility; management's continued evaluation of the repurchase of Surge shares under the existing NCIB; management's plans to confirm 2019 and the timing thereof; Surge's dividend policy and the expectations of management with respect to an increase to Surge's dividend; and the timing of release of 2019 guidance.

Information respecting Surge's 2019 forecast operating netback and forecast cash flow from operating activities set forth in this press release may be considered to be future-oriented financial information or a financial outlook for the purposes of applicable Canadian securities laws. Financial outlook and future-oriented financial information and projected operational information contained in this press release are based on assumptions about future events based on management's assessment of the relevant information currently available that management considers to be reasonable in the circumstances. The future-oriented financial information and financial outlooks and projected operational information contained in this press release have been approved by management as of the date of this press release. Readers are cautioned that any such future-oriented financial information, financial outlooks and projected operational information contained herein should not be used for purposes other than those for which it is disclosed herein.

The forward-looking statements are based on certain key expectations and assumptions made by Surge, including expectations and assumptions concerning the ability of Surge to execute and realize on the anticipated benefits of the Acquisition; the performance of existing wells and success obtained in drilling new wells; anticipated expenses, cash flow and capital expenditures; the application of regulatory and royalty regimes; prevailing commodity prices and economic conditions; development and completion activities; the performance of new wells; the successful implementation of waterflood programs; the availability of and performance of facilities and pipelines; the geological characteristics of Surge's properties; the geological characteristics of the MBOG Assets; the successful application of drilling, completion and seismic technology; the determination of decommissioning liabilities; prevailing weather conditions; exchange rates; licensing requirements; the impact of completed facilities on operating costs; the ability of Surge to increase its dividend post-closing; the availability and costs of capital, labour and services; and the creditworthiness of industry partners.

Although Surge believes that the expectations and assumptions on which the forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because Surge can give no assurance that they will prove to be correct. Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to, risks associated with the oil and gas industry in general (e.g., operational risks in development, exploration and production; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to production, costs and expenses, and health, safety and environmental risks), commodity price and exchange rate fluctuations and constraint in the availability of services, adverse weather or break-up conditions, uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects or capital expenditures or failure to obtain the continued support of the lenders under Surge's bank line. Certain of these risks are set out in more detail in Surge's Annual Information Form dated March 14, 2018 and in Surge's MD&A for the period ended September 30, 2018, both of which have been filed on SEDAR and can be accessed at www.sedar.com.

The forward-looking statements contained in this press release are made as of the date hereof and Surge undertakes no obligation to update publicly or revise any forward-looking statements or information, whether as a result of new information, future events or otherwise, unless so required by applicable securities laws.

Reserves Data

Boe means barrel of oil equivalent on the basis of 1 boe to 6,000 cubic feet of natural gas. Boe may be misleading, particularly if used in isolation. A boe conversion ratio of 1 boe for 6,000 cubic feet of natural gas is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Boe/d and boepd means barrel of oil equivalent per day. Original Oil in Place ("OOIP") is the equivalent to Discovered Petroleum Initially In Place ("DPIIP") for the purposes of this press release. DPIIP is defined as quantity of hydrocarbons that are estimated to be in place within a known accumulation. There is no certainty that it will be commercially viable to produce any portion of the resources. A recovery project cannot be defined for this volume of DPIIP at this time, and as such it cannot be further sub-categorized. Bbl means barrel of oil. NGLs means natural gas liquids.

Drilling Locations

This press release discloses drilling locations in two categories: (i) booked locations; and (ii) unbooked locations. Booked locations are proved locations and probable locations derived from an internal evaluation using standard practices as prescribed in the Canadian Oil and Gas Evaluations Handbook and account for drilling locations that have associated proved and/or probable reserves, as applicable. Booked locations referenced in this press release account for all of Surge's Asset Acquisitions and Divestiture activity up to and including the date of the subject acquisition, reflecting the bookings that existed (from the respective 3rd party auditor), as of January 1, 2018. Booked locations referenced for Mount Bastion corporate acquisition are based upon Sproule's reserve report titled "Evaluation of the P&NG Reserves of Mount Bastion Oil & Gas Corp. (as of December 31, 2017) for Surge Energy Inc. using Surge Energy Inc.'s Development Plan", dated August 31, 2018; this sensitivity run removed 73 gross (54.0 net) economic locations from Sproule's original 2017 year end reserves, leaving 67 gross (60.7 net) economic locations booked as of December 31, 2017. 

Unbooked locations are internal estimates based on prospective acreage and assumptions as to the number of wells that can be drilled per section based on industry practice and internal review. Unbooked locations do not have attributed reserves or resources. Unbooked locations have been identified by Surge's internal certified Engineers and Geologists (who are also Qualified Reserve Evaluators) as an estimation of our multi-year drilling activities based on evaluation of applicable geologic, seismic, engineering, production and reserves information. There is no certainty that the Company will drill all unbooked drilling locations and if drilled there is no certainty that such locations will result in additional oil and gas reserves, resources or production. The drilling locations on which the Company actually drills wells will ultimately depend upon the availability of capital, regulatory approvals, seasonal restrictions, oil and natural gas prices, costs, actual drilling results, additional reservoir information that is obtained and other factors. While certain of the unbooked drilling locations have been de-risked by drilling existing wells in relative close proximity to such unbooked drilling locations, the majority of other unbooked drilling locations are farther away from existing wells where management has less information about the characteristics of the reservoir and therefore there is more uncertainty whether wells will be drilled in such locations and if drilled there is more uncertainty that such wells will result in additional oil and gas reserves, resources or production.

Assuming the January 1, 2018 reference date outlined above, the >50 gross (>50 net) Sparky locations identified herein 4 gross (4 net) are Proved locations and 1 gross (1 net) are Probable locations. 

Non-GAAP Financial Measures

Certain secondary financial measures in this press release – namely, "adjusted funds flow", "adjusted funds flow per share", and "net debt" are not prescribed by GAAP. These non-GAAP financial measures are included because management uses the information to analyze business performance, cash flow generated from the business, leverage and liquidity, resulting from the Company's principal business activities and it may be useful to investors on the same basis. None of these measures are used to enhance the Company's reported financial performance or position. The non-GAAP measures do not have a standardized meaning prescribed by IFRS and therefore are unlikely to be comparable to similar measures presented by other issuers. They are common in the reports of other companies but may differ by definition and application. All non-GAAP financial measures used in this document are defined below:

Adjusted Funds Flow & Adjusted Funds Flow per Share

The Company adjusts cash flow from operating activities in calculating adjusted funds flow for changes in non-cash working capital, decommissioning expenditures, transaction and other costs, and cash settled stock-based compensation plans, particularly cash used to settle withholding obligations on stock-based compensation arrangements that are settled in shares. Management believes the timing of collection, payment or incurrence of these items involves a high degree of discretion and as such may not be useful for evaluating Surge's cash flows.

Changes in non-cash working capital are a result of the timing of cash flows related to accounts receivable and accounts payable, which management believes reduces comparability between periods. Management views decommissioning expenditures predominately as a discretionary allocation of capital, with flexibility to determine the size and timing of decommissioning programs to achieve greater capital efficiencies and as such, costs may vary between periods. Transaction and other costs represent expenditures associated with acquisitions, which management believes do not reflect the ongoing cash flows of the business, and as such reduces comparability. Subsequent to the third quarter of 2018, all of the Company's stock-based compensation plans are equity classified as the Company has the intention of settling all awards with shares. Cash settled stock-based compensation currently represents the statutory tax withholdings required on stock-based compensation awards and is a discretionary allocation of capital. The Company has the option to either require the holder to sell shares earned in the stock-based compensation plan to satisfy tax withholdings, or the Company can issue less shares to the individual and remit a cash payment to satisfy tax withholding requirements. Each of these expenditures, due to their nature, are not considered principal business activities and vary between periods, which management believes reduces comparability.

Adjusted funds flow per share is calculated using the same weighted average basic and diluted shares used in calculating income per share.

The following table reconciles cash flow from operating activities to adjusted funds flow and adjusted funds flow per share:





($000s)

Q3/18


Q3/17

Cash flow from operating activities

$

37,197


$

24,589

Change in non-cash working capital


(2,269)



(2,954)

Decommissioning expenditures


1,329



686

Transaction and other costs


1,016



138

Cash settled stock-based compensation


3,365



526

Adjusted funds flow

$

40,638


$

22,985

Per share – basic

$

0.18


$

0.10

 

Net Debt

There is no comparable measure in accordance with IFRS for net debt. Net debt is calculated as bank debt plus the liability component of the convertible debentures plus or minus working capital, however, excluding the fair value of financial contracts and other long term liabilities. This metric is used by management to analyze the level of debt in the Company including the impact of working capital, which varies with timing of settlement of these balances.





($000s)

As at Sept 30,
2018


As at Sept 30,
2017

Bank debt

$ (250,684)


$ (247,774)

Accounts receivable

35,940


31,104

Prepaid expenses and deposits

7,111


4,068

Convertible debentures

(37,646)


-

Accounts payable and accrued liabilities

(35,168)


(31,952)

Dividends payable

(1,947)


(1,844)

Total

$ (282,394)


$ (246,398)

 

Net Operating Expenses

Net operating expenses are determined by deducting processing and other revenue primarily generated by processing third party volumes at processing facilities where the Company has an ownership interest. It is common in the industry to earn third party processing revenue on facilities where the entity has a working interest in the infrastructure asset. Under IFRS this source of funds is required to be reported as revenue. However, the Company's principal business is not that of a midstream entity whose activities are dedicated to earning processing and other infrastructure payments. Where the Company has excess capacity at one of its facilities, it will look to process third party volumes as a means to reduce the cost of operating/owning the facility. As such, third party processing revenue is netted against operating costs in the MD&A.

Additional information relating to non-GAAP measures can be found in the Company's most recent management's discussion and analysis MD&A, which may be accessed through the SEDAR website (www.sedar.com).

Capital Management Measures

Certain capital management measures in this press release – namely, "dividend payout ratio", "all-in payout ratio", "free adjusted funds flow", and "net debt to adjusted funds flow" are disclosed for the purpose of providing investors with additional insight as to how the Company evaluates the management of its capital. Management uses each of the capital management measures included in this document to analyze the Company's capital management objectives and to assist in capital allocation decisions. Management believes capital management measures may be useful to investors on the same basis. None of these measures are used to enhance the Company's reported financial performance or position.

The capital management measures do not have a standardized meaning prescribed by IFRS or a corresponding IFRS measure and therefore are unlikely to be comparable to similar measures presented by other issuers. They are common in the reports of other companies but may differ by definition and application. The amounts used in the calculation of the measures are derived from the financial statements that are prepared in accordance with IFRS. In some instances, the capital management measure incorporates a non-GAAP measure, such as adjusted funds flow and net debt, which are defined in the non-GAAP section of this document.

All capital management measures used in this document are defined below:

All-in Payout Ratio

All-in payout ratio is calculated using the sum of total exploration and development capital plus dividends paid divided by adjusted funds flow. This capital management measure is used by management to analyze allocated capital in comparison to the cash being generated by the principal business activities. This measure is provided to allow readers to quantify the amount of adjusted funds flow that is being used to either: i) pay dividends; and ii) deployed into the Company's development and exploration program. A ratio of less than 100% indicates that a portion of the adjusted funds flow is being retained by the Company and can be used to fund items such as asset abandonment, repayment of debt, fund acquisitions or the costs related thereto, withholding tax obligations on stock based compensation or other items.


($000s)

Q3/18


Q3/17

Dividends paid

$

5,788


$

5,386

Total exploration and development expenditures

$

28,701


$

26,652

All-in payout

$

34,489


$

32,038

Adjusted funds flow

$

40,638


$

22,985

All-in payout ratio (dividends paid and total exploration and
development expenditures as a % of adjusted funds flow)


85%



139%

 

Dividend Payout Ratio 

Dividend payout ratio is calculated as the dividends paid for the respective period divided by adjusted funds flow. This capital management measure is used by management to analyze the level of dividends currently being paid on the stock in comparison to the cash being generated by the principal business activities.


($000s)

Q3/18


Q3/17

Dividends paid

$

5,788


$

5,386

Adjusted funds flow

$

40,638


$

22,985

Dividend payout ratio (dividends paid as a % of adjusted funds flow)


14%



23%

 

Net Debt to Adjusted Funds Flow Ratio

Net debt to adjusted funds flow ratio is calculated as net debt divided by adjusted funds flow for the period. This capital management measure provides an indication of leverage and the number of years it would take to repay the net debt based on the level of adjusted funds flow.

Additional information relating to non-GAAP and capital management measures can be found in the Company's most recent management's discussion and analysis MD&A, which may be accessed through the SEDAR website (www.sedar.com).

Additional Metrics

This press release contains additional metrics commonly used in the oil and natural gas industry. These terms have been calculated by Management and do not have a standardized meaning. Management uses these oil and gas metrics to further analyze the performance of the Company over time and to compare the results of the Company with others in the industry. Additional metrics used in this press release are as follows:

Operating Netback & Adjusted Funds Flow Netback

Operating netback & adjusted funds flow netback are calculated on a per unit basis as follows:


($000s)

Q3/18


Q3/17


YTD 2018


YTD 2017

Petroleum and natural gas revenue*

$

91,036


$

56,425


$

246,420


$

171,648

Processing and other income*


537



961



2,242



2,000

Royalties*


(13,803)



(7,276)



(35,725)



(21,993)

Realized gain (loss) on financial contracts*


(3,166)



169



(8,577)



(2,850)

Operating expenses*


(24,360)



(19,911)



(69,123)



(56,221)

Transportation expenses*


(2,574)



(1,939)



(6,907)



(5,930)

Operating netback

$

47,670


$

28,429


$

128,330


$

86,654

G&A expense*


(3,276)



(2,673)



(9,677)



(7,762)

Interest expense*


(3,756)



(2,771)



(11,250)



(7,249)

Adjusted funds flow netback

$

40,638


$

22,985


$

107,403


$

71,643

Barrels of oil equivalent (boe)


1,658,668



1,380,644



4,654,377



4,004,910

Operating netback ($ per boe)

$

28.75


$

20.59


$

27.57


$

21.64

Adjusted funds flow netback ($ per boe)

$

24.50


$

16.64


$

23.07


$

17.89

* Taken directly from the financial statements.

 

Neither the TSX nor its Regulation Services Provider (as that term is defined in the policies of the TSX) accepts responsibility for the adequacy or accuracy of this release.

SOURCE Surge Energy Inc.

View original content to download multimedia: http://www.newswire.ca/en/releases/archive/November2018/06/c6561.html

Paul Colborne, President & CEO, Surge Energy Inc., Phone: (403) 930-1507, Fax: (403) 930-1011, Email: [email protected]; Jared Ducs, Vice President Finance, Surge Energy Inc., Phone: (403) 930-1046, Fax: (403) 930-1011, Email: [email protected] CNW Group 2018


Source: Canada Newswire (November 6, 2018 - 9:01 PM EST)

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