PR Newswire
CALGARY, May 8, 2018
CALGARY, May 8, 2018 /PRNewswire/ - (TSX:PMT) - Perpetual Energy Inc. ("Perpetual", the "Corporation" or the "Company") is pleased to release its first quarter 2018 financial and operating results. A complete copy of Perpetual's unaudited condensed interim consolidated financial statements and related Management Discussion and Analysis ("MD&A") for the three months ended March 31, 2018 can be obtained through the Company's website at www.perpetualenergyinc.com and SEDAR at www.sedar.com.
FIRST QUARTER 2018 HIGHLIGHTS
Production and Operations
Financial Highlights
2018 OUTLOOK
Perpetual has lowered its 2018 capital expenditure guidance from a range of $23 to 27 million provided in a press release dated February 7, 2018 ("Prior Guidance") to $21 to 25 million ($6 to 10 million for the remainder of 2018) and reduced its Mannville heavy oil drilling in the second half of 2018 to two wells (1.3 net) from the previous range of six to ten wells. At East Edson, one horizontal well drilled in the first quarter will be completed and tied-in during the fourth quarter of 2018 to align high initial production rates with higher expected winter natural gas prices. Additional development drilling is ready to activate if AECO forward prices normalize above $2.00/Mcf. Capital spending plans at Mannville include $1.5 to $2.0 million to capture anticipated banked oil from waterflood operations. Decommissioning expenditures are budgeted to be $1.0 to $1.5 million for the remainder of 2018. Capital spending during the remainder of 2018 will be funded through adjusted funds flow.
Production for 2018 is expected to be 10,500 boe/d to 11,000 boe/d, down from prior guidance of 11,500 boe/d due to lower natural gas production in the first quarter due to freeze offs and shut-ins and lower heavy oil production anticipated over the balance of the year due to reduced capital spending.
For the April through October period, Perpetual has fixed the price on 20,000 GJ/d at $1.74/GJ AECO with the remainder of its production sold at daily index prices at the Chicago, Dawn, Empress, Malin and Michcon markets through its 40,000 MMBtu/d market diversification contract. If AECO prices temporarily weaken, Perpetual's fixed price AECO position provides the ability to shut-in production and purchase gas to deliver against pre-sold commitments while preserving reserves and future deliverability capability.
Cash costs of $14.00 to $15.00/boe are anticipated compared to prior guidance of $13.00 to $14.00/boe, due to the impact of the forecast decrease in production on unit costs. Royalty costs are estimated to be moderately lower for the balance of 2018 than in the first quarter, consistent with lower AECO forward natural gas prices for the remainder of 2018. Other cash costs for the remainder of 2018 are anticipated to be comparable to first quarter expense levels.
Adjusted funds flow for 2018 is forecast to be in the $25 to $28 million range ($16 to $19 million for the remainder of 2018), down from previous guidance of $34 to $37 million due to lower heavy oil production and modestly lower natural gas prices.
Guidance assumptions are as follows:
Current Guidance |
Prior Guidance | |
Exploration and development expenditures |
$21 - 25 million |
$23 - 27 million |
2018 cash costs |
$14.00 - $15.00/boe |
$13.00 - 14.00/boe |
2018 average daily production |
10,500 - 11,000 boe/d |
11,500 boe/d |
2018 average production mix |
15% oil and NGL |
17% oil and NGL |
Commodity price assumptions are consistent with current market price levels as follows:
Current Guidance |
Prior Guidance | |
2018 average NYMEX natural gas price |
US$2.86/MMBtu |
US$2.98/MMBtu |
2018 average NYMEX to AECO basis differential |
(US$1.73)/MMBtu |
(US$1.77)/MMBtu |
2018 average West Texas Intermediate ("WTI") oil price |
US$65.55/bbl |
US$63.54/bbl |
2018 average Western Canadian Select ("WCS") differential |
(US$22.30)/bbl |
(US$23.83)/bbl |
2018 average exchange rate |
US$1.00 = $1.277 |
US$1.00 = $1.235 |
Year end 2018 net debt (net of the current market value of the Company's TOU share investment of approximately $40 million) is forecast at $105 - $110 million, consistent with prior guidance, based on the following assumptions:
On May 7, 2018, the revolving bank debt Borrowing Limit was decreased from $65 million to $60 million with the next Borrowing Limit redetermination scheduled on or prior to November 30, 2018. After giving effect to this Borrowing Limit reduction, Perpetual had available liquidity of $29.6 million. To improve liquidity, Perpetual plans to pursue additional asset sales in 2018 including the potential disposition of TOU shares.
Financial and Operating Highlights |
Three months ended March 31, | |||
($Cdn thousands except volume and per share amounts) |
2018 |
2017 |
Change | |
Financial |
||||
Oil and natural gas revenue |
23,340 |
18,158 |
29% | |
Net loss |
(6,465) |
(14,172) |
54% | |
Per share – basic and diluted(2) |
(0.11) |
(0.26) |
58% | |
Cash flow from (used in) operating activities |
11,198 |
(2,289) |
589% | |
Adjusted funds flow(1) |
9,101 |
5,110 |
78% | |
Per share(1)(2) |
0.15 |
0.09 |
67% | |
Total assets |
363,273 |
389,739 |
(7%) | |
Revolving bank debt |
46,912 |
– |
100% | |
Term Loan, at principal amount |
45,000 |
35,000 |
29% | |
TOU share margin loan, at principal amount |
15,990 |
35,039 |
(54%) | |
Senior Notes, at principal amount |
32,490 |
60,573 |
(46%) | |
TOU share investment |
(36,434) |
(49,440) |
(26%) | |
Adjusted working capital deficiency (surplus)(1) |
11,101 |
(16,714) |
(166%) | |
Net debt(1) |
115,059 |
64,458 |
79% | |
Net capital expenditures |
||||
Capital expenditures |
14,897 |
24,590 |
(39%) | |
Net payments on acquisitions and dispositions |
926 |
163 |
468% | |
Net capital expenditures |
15,823 |
24,753 |
(36%) | |
Common shares (thousands)(3) |
||||
End of period |
59,847 |
58,990 |
1% | |
Weighted average - basic and diluted |
59,345 |
54,468 |
9% | |
Operating |
||||
Daily average production |
||||
Natural gas (MMcf/d) |
65.9 |
40.7 |
62% | |
Oil (bbl/d) |
900 |
877 |
3% | |
NGL (bbl/d) |
848 |
479 |
77% | |
Total (boe/d) |
12,742 |
8,143 |
56% | |
Average prices |
||||
Realized natural gas price ($/Mcf) |
2.65 |
5.04 |
(47%) | |
Realized oil price ($/bbl) |
48.31 |
31.39 |
54% | |
Realized NGL price ($/bbl) |
57.61 |
49.70 |
16% | |
Wells drilled – gross (net) |
||||
Natural gas |
1 (1.0) |
6 (6.0) |
||
Oil |
3 (3.0) |
4 (3.3) |
||
Total |
4 (4.0) |
10 (9.3) |
(1) |
These are non-GAAP measures. Please refer to "Non-GAAP Measures" below. |
(2) |
Based on weighted average common shares outstanding for the period. |
(3) |
All common shares are presented net of shares held in trust. |
About Perpetual
Perpetual is an oil and natural gas exploration, production and marketing company headquartered in Calgary, Alberta. Perpetual operates a diversified asset portfolio, including liquids-rich natural gas assets in the deep basin of west central Alberta, heavy oil and shallow natural gas in eastern Alberta, with longer term opportunities through undeveloped oil sands leases in northern Alberta. Additional information on Perpetual can be accessed at www.sedar.com or from the Corporation's website at www.perpetualenergyinc.com.
The Toronto Stock Exchange has neither approved nor disapproved the information contained herein.
Forward-Looking Information
Certain information regarding Perpetual in this news release including management's assessment of future plans and operations may constitute forward-looking information or statements under applicable securities laws. The forward looking information includes, without limitation, anticipated amounts and allocation of capital spending; statements pertaining to adjusted funds flow levels, statements regarding estimated production and timing thereof; statements pertaining to type curves being exceeded, forecast average production; completions and development activities; infrastructure expansion and construction; estimated FDC required to convert proved plus probable non-producing and undeveloped reserves to proved producing reserves; prospective oil and natural gas liquids production capability; projected realized natural gas prices and adjusted funds flow; estimated decommissioning obligations; commodity prices and foreign exchange rates; and commodity price management. Various assumptions were used in drawing the conclusions or making the forecasts and projections contained in the forward-looking information contained in this news release, which assumptions are based on management's analysis of historical trends, experience, current conditions and expected future developments pertaining to Perpetual and the industry in which it operates as well as certain assumptions regarding the matters outlined above. Forward-looking information is based on current expectations, estimates and projections that involve a number of risks, which could cause actual results to vary and, in some instances, to differ materially from those anticipated by Perpetual and described in the forward-looking information contained in this news release. Undue reliance should not be placed on forward-looking information, which is not a guarantee of performance and is subject to a number of risks or uncertainties, including without limitation those described under "Risk Factors" in Perpetual's Annual Information Form and MD&A for the year ended December 31, 2017 and those included in other reports on file with Canadian securities regulatory authorities which may be accessed through the SEDAR website (www.sedar.com) and at Perpetual's website (www.perpetualenergyinc.com). Readers are cautioned that the foregoing list of risk factors is not exhaustive. Forward-looking information is based on the estimates and opinions of Perpetual's management at the time the information is released and Perpetual disclaims any intent or obligation to update publicly any such forward-looking information, whether as a result of new information, future events or otherwise, other than as expressly required by applicable securities law.
Non-GAAP Measures
This news release contains the terms "adjusted funds flow", "adjusted funds flow per share", "adjusted funds flow per boe", "available liquidity", "annualized adjusted funds flow", "cash costs", "net working capital deficiency (surplus)", "net debt and net bank debt", "operating netback" and "realized revenue" which do not have standardized meanings prescribed by GAAP. Management believes that in addition to net income (loss) and net cash flows from operating activities as defined by GAAP, these terms are useful supplemental measures to evaluate operating performance. Users are cautioned however that these measures should not be construed as an alternative to net income (loss) or net cash flows from operating activities determined in accordance with GAAP as an indication of Perpetual's performance and may not be comparable with the calculation of similar measurements by other entities.
For additional reader advisories in regards to non-GAAP financial measures, including Perpetual's method of calculation and reconciliation of these terms to their corresponding GAAP measures, see the section entitled "Non-GAAP Measures" within the Company's MD&A filed on SEDAR.
Management uses adjusted funds flow and adjusted funds flow per boe as key measures to assess the ability of the Company to generate the funds necessary to finance capital expenditures, expenditures on decommissioning obligations and meet its financial obligations. Adjusted funds flow is calculated based on cash flows from operating activities, excluding changes in non-cash working capital and expenditures on decommissioning obligations since Perpetual believes the timing of collection, payment or incurrence of these items involves a high degree of discretion. Expenditures on decommissioning obligations may vary from period to period depending on capital programs and the maturity of our operating areas. Expenditures on decommissioning obligations are managed through our capital budgeting process which considers available adjusted funds flow. The Company has also deducted the change in gas over bitumen royalty financing from adjusted funds flow in order to present these payments net of gas over bitumen royalty credits. These payments are indexed to gas over bitumen royalty credits and are recorded as a reduction to the Corporation's gas over bitumen royalty financing obligation in accordance with IFRS. Additionally, the Company has excluded payments of restructuring costs associated with the disposition of the Shallow Gas Properties, which management considers to not be related to cash flow from operating activities. Restructuring costs include employee downsizing costs and surplus office lease obligations. Commencing in the first quarter of 2018, the Company no longer excludes 'exploration and evaluation – geological and geophysical costs' (Q1 2018 and 2017 – nil) from the calculation of adjusted funds flow as these costs are no longer significant to the Company's business. The calculation of adjusted funds flow for comparative periods has been adjusted to give effect to this change. Adjusted funds flow per share is calculated using the same weighted average number of shares outstanding used in calculating earnings per share. Adjusted funds flow is not intended to represent net cash flows from (used in) operating activities calculated in accordance with IFRS. Adjusted funds flow per boe is calculated as adjusted funds flow divided by total production sold in a period.
Available Liquidity: Available Liquidity is defined as Perpetual's Credit Facility Borrowing Limit, plus TOU share investment, less borrowings and letters of credit issued under the Credit Facility and TOU share margin loan. Management uses available liquidity to assess the ability of the Company to finance capital expenditures, expenditures on decommissioning obligations and meet financial obligations.
Cash costs: Management believes that cash costs assist management and investors in assessing Perpetual's efficiency and overall cost structure. Cash costs are comprised of royalties, production and operating, transportation, general and administrative and cash interest expense and net income. Cash costs per boe is calculated by dividing cash costs by total production sold in a period.
Net debt and net bank debt: Net bank debt is measured as current and long-term bank indebtedness including net working capital deficiency (surplus). Net debt includes the carrying value of net bank debt, the principal amount of the Term Loan, the principal amount of the TOU share margin loan and the principal amount of Senior Notes reduced for the mark-to-market value of the TOU share investment. Net bank debt and net debt are used by management to analyze borrowing capacity.
Net working capital deficiency (surplus): Net working capital deficiency (surplus) includes total current assets and current liabilities excluding short-term derivative assets and liabilities related to the Corporation's risk management activities, current portion of gas over bitumen royalty financing, TOU share investment, TOU share margin loan and current portion of provisions.
Operating netback: Perpetual considers operating netback an important performance measure as it demonstrates its profitability relative to current commodity prices. Operating netback is calculated by deducting royalties, operating costs, and transportation from realized revenue. Operating netback is also calculated on a per boe basis using production sold for the period. Operating netback on a per boe basis can vary significantly for each of the Company's operating areas.
Realized revenue: Realized revenue is the sum of realized natural gas revenue, realized oil revenue and realized NGL revenue which includes realized gains (losses) on financial natural gas, crude oil and foreign exchange contracts but excludes any realized gains (losses) resulting from contracts related to the disposition of the Shallow Gas Properties. Realized revenue, excluding foreign exchange contracts is used by management to calculate the Corporation's net realized commodity prices, taking into account monthly settlements on financial crude oil and natural gas forward sales, collars and basis differentials. These contracts are put in place to protect Perpetual's adjusted funds flow from potential volatility in commodity prices, and as such, any related realized gains or losses are considered part of the Corporation's realized price.
BOE Equivalents
Perpetual's aggregate proved and probable reserves are reported in barrels of oil equivalent (boe). Boe may be misleading, particularly if used in isolation. In accordance with NI 51-101 a boe conversion ratio for natural gas of 6 Mcf: 1 boe has been used, which is based on an energy equivalency conversion method primarily applicable at the burner tip and does not necessarily represent a value equivalency at the wellhead. As the value ratio between natural gas and crude oil based on the current prices of natural gas and crude oil is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
The following abbreviations used in this news release have the meanings set forth below:
bbls |
barrels |
boe |
barrels of oil equivalent |
Mcf |
thousand cubic feet |
MMcf |
million cubic feet |
MMBtu |
million British Thermal Units |
GJ |
gigajoules |
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SOURCE Perpetual Energy Inc.