WESTERN ENERGY SERVICES CORP. RELEASES FOURTH QUARTER AND YEAR END 2023 FINANCIAL AND OPERATING RESULTS, REDUCING DEBT BY $17 MILLION IN 2023
Fourth Quarter 2023 Operating Results:
- Fourth quarter revenue decreased by
$4.5 million or 7%, to$56.3 million in 2023, as compared to$60.8 million in the fourth quarter of 2022. Contract drilling revenue totalled$37.7 million in the fourth quarter of 2023, which was$5.5 million or 13%, lower than$43.2 million in the fourth quarter of 2022. Production services revenue was$18.6 million for the three months endedDecember 31, 2023 , an increase of$0.8 million or 5%, as compared to$17.8 million in the same period of the prior year. In the fourth quarter of 2023, revenue was negatively impacted by lower activity in contract drilling inCanada and the US due to lower commodity prices, compared to the fourth quarter of 2022 as described below:- In
Canada , Operating Days of 833 days in the fourth quarter of 2023 were 95 days (or 10%) lower compared to 928 days in the fourth quarter of 2022. This compares to a 9% decrease in CAOEC industry Operating Days in the fourth quarter of 2023, compared to the fourth quarter of 2022. Drilling rig utilization inCanada was 27% in the fourth quarter of 2023, compared to 28% in the same period of the prior year mainly due to customers reducing their capital budgets or deferring their programs into 2024, as a result of lower commodity prices in the fourth quarter.The Canadian Association of Energy Contractors ("CAOEC") industry average utilization of 36%1 for the fourth quarter of 2023 represented a decrease of four percentage points compared to the CAOEC industry average utilization of 40% in the fourth quarter of 2022. Revenue per Operating Day averaged$35,211 in the fourth quarter of 2023, an increase of 4% compared to the same period of the prior year, mainly due to higher pricing, which was offset partially by lower third party charges, such as fuel, as more customers are paying for fuel directly instead of passing fuel charges through Western; - In
the United States ("US"), drilling rig utilization averaged 36% in the fourth quarter of 2023, compared to 40% in the fourth quarter of 2022, with Operating Days decreasing from 293 days in the fourth quarter of 2022 to 229 days in the fourth quarter of 2023 due to lower industry activity. Average active industry rigs of 6222 in the fourth quarter of 2023 were 20% lower compared to the fourth quarter of 2022. Revenue per Operating Day for the fourth quarter of 2023 averagedUS$26,530 , a 10% decrease compared toUS$29,439 in the same period of the prior year, mainly due to changes in rig mix as activity was lower for the Company's higher specification rigs which have higher day rates; and - In
Canada , service rig utilization of 37% in the fourth quarter of 2023 was lower than 38% in the same period of the prior year as industry activity decreased. Revenue per Service Hour averaged$1,017 in the fourth quarter of 2023 and was 3% higher than the fourth quarter of 2022, due to improved pricing and inflationary pressures on operating costs, including higher wages that are passed through to the customer.
- In
- The Company incurred a net loss of
$2.2 million in the fourth quarter of 2023 ($0.06 net loss per basic common share) as compared to a net loss of$3.1 million in the same period in 2022 ($0.09 net loss per basic common share). The change can mainly be attributed to a$1.2 million increase in Adjusted EBITDA, a$0.3 million decrease in income tax expense, a$0.3 million decrease in stock based compensation expense, and a$0.3 million decrease in finance costs due to a lower total debt balance, which were partially offset by a$0.9 million increase in depreciation expense due to property and equipment additions and a$0.2 million increase in other items. Administrative expenses in the fourth quarter of 2023 were consistent with the fourth quarter of 2022. - Adjusted EBITDA of
$13.4 million in the fourth quarter of 2023 was$1.2 million , or 9%, higher compared to$12.2 million in the fourth quarter of 2022. Adjusted EBITDA in 2023 was higher due to higher industry activity and pricing in production services, higher pricing in the contract drilling segment in the fourth quarter of 2023, as well as lower repairs and maintenance costs, which were offset partially by lower contract drilling activity in the US andCanada , as well as inflationary cost increases. - Fourth quarter additions to property and equipment of
$3.4 million in 2023 compared to$7.7 million in the fourth quarter of 2022, consisting of$0.6 million of expansion capital related to rig upgrades and$2.8 million of maintenance capital. The decrease can mainly be attributable to the Company substantially completing its rig upgrade program in 2022. - On
December 22, 2023 , the Company made a$7.0 million voluntary prepayment on its second lien term loan facility withAlberta Investment Management Corporation (the "Second Lien Facility").
1 Source: CAOEC, monthly Contractor Summary. |
2023 Operating Results:
- During the year ended
December 31, 2023 , the Company reduced its total debt by$17.0 million (or 13%), primarily through a$7.0 million voluntary repayment on its Second Lien Facility, a$4.1 million voluntary repayment on itsHSBC Bank Canada six-year committed term non-revolving facility with the participation of Business Development Canada (the "HSBC Facility") and repayments of its Credit Facilities (as defined in this press release). - Western's drilling rig upgrade program, which was initiated in 2022, has been a success and has generated a substantial portion of revenue for the year ended
December 31, 2023 . The upgraded rigs have generated higher day rates which contributed to increased revenue for the year endedDecember 31, 2023 . - Revenue for the year ended
December 31, 2023 , increased by$33.2 million or 17%, to$233.5 million as compared to$200.3 million for the year endedDecember 31, 2022 . Contract drilling revenue totalled$164.6 million for the year endedDecember 31, 2023 , an increase of$35.1 million or 27%, compared to$129.5 million in the same period of the prior year. Production services revenue was$69.2 million for the year endedDecember 31, 2023 , a decrease of$2.1 million or 3%, as compared to$71.3 million in the same period of the prior year. In 2023, revenue was positively impacted by improved pricing in all divisions, rig upgrades, as well as higher activity in contract drilling, partially offset by lower activity in production services, compared to 2022 as described below:- In
Canada , Operating Days of 3,575 for the year endedDecember 31, 2023 , were 334 days (or 10%) higher, compared to 3,241 days for the year endedDecember 31, 2022 , resulting in drilling rig utilization of 29% for the year endedDecember 31, 2023 , compared to 24% for the year endedDecember 31, 2022 . This compares to a 2% decrease in CAOEC Operating Days for the year endedDecember 31, 2023 , compared to the year endedDecember 31, 2022 . The CAOEC industry average utilization of 36%3 for the year endedDecember 31, 2023 , represented an increase of one percentage point compared to the CAOEC industry average utilization of 35% for the year endedDecember 31, 2022 . Revenue per Operating Day averaged$33,328 for the year endedDecember 31, 2023 , an increase of 12% compared to the prior year, mainly due to rig upgrades, market driven increased pricing, and inflationary pressures on operating costs, including higher wages that are passed through to the customer; - In the US, drilling rig utilization averaged 38% for the year ended
December 31, 2023 , compared to 33% in the prior year, with Operating Days improving by 96 days from 976 days in 2022 to 1,072 days in 2023. Average active industry rigs of 6874 in 2023 were 5% lower than the average for the year endedDecember 31, 2022 as US industry activity weakened in 2023. Revenue per Operating Day for the year endedDecember 31, 2023 averagedUS$30,861 , a 19% increase compared toUS$25,927 for the year endedDecember 31, 2022 , mainly due to improved spot market pricing in theWilliston Basin ; and - In
Canada , service rig utilization of 34% for the year endedDecember 31, 2023 was lower than 41% in prior year as industry activity decreased, mainly due to the completion of the funding for the Federal site rehabilitation program, several customers waiting on the restoration of power in areas impacted by wildfires and lower commodity prices. Revenue per Service Hour averaged$1,027 for the year endedDecember 31, 2023 and was 9% higher than the prior year, due to improved pricing and inflationary pressures on operating costs, including higher wages that are passed through to the customer.
- In
- Administrative expenses increased by
$2.4 million or 17%, to$16.3 million for the year endedDecember 31, 2023 , as compared to$13.9 million in the prior year, due to higher employee related costs along with inflationary costs and higher professional fees. - The Company generated a net loss of
$6.9 million for the year endedDecember 31, 2023 ($0.20 net loss per basic common share) as compared to net income of$29.3 million in the prior year ($1.24 net income per basic common share). The change can mainly be attributed to the$49.4 million gain on debt forgiveness in 2022, a$7.8 million increase in Adjusted EBITDA, a$4.3 million decrease in income tax expense, a$3.0 million decrease in finance costs due to the lower total debt balance and a$0.9 million decrease in other items, offset partially by a$0.8 million increase in stock based compensation expense and a$2.1 million increase in depreciation expense due to property and equipment additions. - Adjusted EBITDA of
$47.7 million for the year endedDecember 31, 2023 was$7.8 million , or 20%, higher compared to$39.9 million in the prior year. Adjusted EBITDA was higher due to improved contract drilling activity inCanada and the US in the first half of 2023, higher pricing across all divisions, andUS$0.6 million of shortfall commitment revenue, which was offset partially by lower activity in the third and fourth quarters of 2023, one-time costs of$0.5 million related to reactivating certain drilling rigs, inflationary cost increases and$1.8 million lower government subsidies received in 2023 compared to 2022. - Year to date 2023 additions to property and equipment of
$22.6 million compared to$34.2 million in the prior year, consisting of$7.4 million of expansion capital and$15.2 million of maintenance capital. The decrease year over year can mainly be attributable to the Company substantially completing its rig upgrade program in 2022.
3 Source: CAOEC, monthly Contractor Summary. |
Selected Financial Information |
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(stated in thousands, except share and per share amounts) |
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Year ended |
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Financial Highlights |
2023 |
2022 |
Change |
2023 |
2022 |
Change |
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Revenue |
56,255 |
60,792 |
(7 %) |
233,451 |
200,344 |
17 % |
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Adjusted EBITDA(1) |
13,370 |
12,233 |
9 % |
47,739 |
39,921 |
20 % |
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Adjusted EBITDA as a percentage of revenue(1) |
24 % |
20 % |
20 % |
20 % |
20 % |
- |
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Cash flow from operating activities |
6,268 |
6,502 |
(4 %) |
51,353 |
28,541 |
80 % |
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Additions to property and equipment |
3,404 |
7,708 |
(56 %) |
22,622 |
34,228 |
(34 %) |
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Net income (loss) |
(2,194) |
(3,095) |
(29 %) |
(6,885) |
29,320 |
(123 %) |
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– basic and diluted net income (loss) per share |
(0.06) |
(0.09) |
(33 %) |
(0.20) |
1.24 |
(116 %) |
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Weighted average number of shares |
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– basic |
33,843,009 |
33,841,318 |
- |
33,841,864 |
23,581,155 |
44 % |
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– diluted |
33,843,009 |
33,841,318 |
- |
33,841,864 |
23,581,735 |
44 % |
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Outstanding common shares as at period end |
33,843,009 |
33,841,318 |
- |
33,843,009 |
33,841,318 |
- |
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(1) See "Non-IFRS Measures and Ratios" included in this press release. |
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Year ended |
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Operating Highlights (2) |
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2023 |
2022 Change |
2023 |
2022 |
Change |
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Contract Drilling |
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Canadian Operations: |
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Contract drilling rig fleet: |
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– Average active rig count |
9.1 |
10.1 |
(10 %) |
9.8 |
8.9 |
10 % |
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Operating Days |
833 |
928 |
(10 %) |
3,575 |
3,241 |
10 % |
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Revenue per Operating Day(3) |
35,211 |
33,923 |
4 % |
33,328 |
29,698 |
12 % |
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Drilling rig utilization |
27 % |
28 % |
(4 %) |
29 % |
24 % |
21 % |
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CAOEC industry average utilization – Operating Days(4) |
36 % |
40 % |
(10 %) |
36 % |
35 % |
3 % |
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Average meters drilled per well |
6,320 |
7,412 |
(15 %) |
6,757 |
6,406 |
5 % |
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Average Operating Days per well |
11.2 |
14.8 |
(24 %) |
12.3 |
12.8 |
(4 %) |
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United States Operations: |
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Contract drilling rig fleet: |
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– Average active rig count |
2.5 |
3.2 |
(22 %) |
2.9 |
2.7 |
7 % |
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Operating Days |
229 |
293 |
(22 %) |
1,072 |
976 |
10 % |
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Revenue per Operating Day (US$)(3) |
26,530 |
29,439 |
(10 %) |
30,861 |
25,927 |
19 % |
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Drilling rig utilization |
36 % |
40 % |
(10 %) |
38 % |
33 % |
15 % |
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Average meters drilled per well |
5,195 |
3,001 |
73 % |
3,759 |
3,450 |
9 % |
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Average Operating Days per well |
17.0 |
13.7 |
24 % |
13.7 |
11.7 |
17 % |
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Production Services |
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Well servicing rig fleet: |
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– Average active rig count |
24.1 |
23.7 |
2 % |
22.2 |
25.8 |
(14 %) |
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Service Hours |
15,712 |
15,443 |
2 % |
57,792 |
67,077 |
(14 %) |
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Revenue per Service Hour(3) |
1,017 |
991 |
3 % |
1,027 |
943 |
9 % |
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Service rig utilization |
37 % |
38 % |
(3 %) |
34 % |
41 % |
(17 %) |
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(2) |
See "Defined Terms" included in this press release. |
(3) |
See "Non-IFRS Measures and Ratios" included in this press release. |
(4) |
Source: The CAOEC monthly Contractor Summary. The CAOEC industry average is based on Operating Days divided by total available drilling days. |
Financial Position at (stated in thousands) |
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Working capital(1) |
20,125 |
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21,923 |
2,224 |
Total assets |
442,933 |
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475,708 |
456,003 |
Long term debt – non current portion |
111,174 |
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126,527 |
226,884 |
(1) See "Non-IFRS Measures and Ratios" included in this press release. |
Business Overview
Western is an energy services company that provides contract drilling services in
Contract Drilling
Western markets a fleet of 41 drilling rigs specifically suited for drilling complex horizontal wells across
Western's marketed and owned contract drilling rig fleets are comprised of the following:
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As at |
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2023 |
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2022 |
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Rig class(1) |
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US |
Total |
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Canada |
US |
Total |
Cardium |
11 |
- |
11 |
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11 |
1 |
12 |
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18 |
1 |
19 |
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18 |
1 |
19 |
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5 |
6 |
11 |
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7 |
6 |
13 |
Total marketed drilling rigs(2) |
34 |
7 |
41 |
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36 |
8 |
44 |
Total owned drilling rigs |
48 |
7 |
55 |
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48 |
8 |
56 |
(1) |
See "Contract Drilling Rig Classifications" included in this press release. |
(2) |
Source: CAOEC Contractor Summary as at |
Production Services
Production services provides well servicing and oilfield equipment rentals in
Western's well servicing rig fleet is comprised of the following:
Owned well servicing rigs |
As at |
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Mast type |
2023 |
2022 |
Single |
30 |
30 |
Double |
27 |
27 |
Slant |
8 |
8 |
Total owned well servicing rigs |
65 |
65 |
Business Environment
Crude oil and natural gas prices impact the cash flow of Western's customers, which in turn impacts the demand for Western's services. The following table summarizes average crude oil and natural gas prices, as well as average foreign exchange rates, for the three months ended
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2023 |
2022 |
Change |
2023 |
2022 |
Change |
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Average crude oil and natural gas prices(1)(2) |
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Crude Oil |
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West Texas Intermediate (US$/bbl) |
78.32 |
82.64 |
(5 %) |
77.63 |
94.23 |
(18 %) |
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Western Canadian Select (CDN$/bbl) |
76.86 |
77.39 |
(1 %) |
79.53 |
98.51 |
(19 %) |
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Natural Gas |
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30 day Spot AECO (CDN$/mcf) |
2.39 |
5.43 |
(56 %) |
2.74 |
5.63 |
(51 %) |
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Average foreign exchange rates(2) |
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US dollar to Canadian dollar |
1.36 |
1.36 |
- |
1.35 |
1.30 |
4 % |
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(1) See "Abbreviations" included in this press release.
(2)
Source: Sproule |
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5 Source: CAOEC Drilling Contractor Summary as at |
West Texas Intermediate on average decreased by 5% and 18% respectively, for the three months and year ended
In both the US and
Outlook
In 2023, crude oil prices were impacted in the short term by the fear of a North American recession, concerns surrounding demand from a weak global economy, continued uncertainty concerning the ongoing war in
As previously announced, Western's board of directors has approved a capital budget for 2024 of
As at
Energy service activity in
7 Source: Baker Hughes Company, 2023 Rig Count monthly press releases. |
Non-IFRS Measures and Ratios
Western uses certain financial measures in this press release which do not have any standardized meaning as prescribed by International Financial Reporting Standards ("IFRS"). These measures and ratios, which are derived from information reported in the consolidated financial statements, may not be comparable to similar measures presented by other reporting issuers. These measures and ratios have been described and presented in this press release to provide shareholders and potential investors with additional information regarding the Company. The non-IFRS measures and ratios used in this press release are identified and defined as follows:
Adjusted EBITDA and Adjusted EBITDA as a Percentage of Revenue
Adjusted earnings before interest and finance costs, taxes, depreciation and amortization, other non-cash items and one-time gains and losses ("Adjusted EBITDA") is a useful non-GAAP financial measure as it is used by management and other stakeholders, including current and potential investors, to analyze the Company's principal business activities prior to consideration of how Western's activities are financed and the impact of foreign exchange, income taxes and depreciation. Adjusted EBITDA provides an indication of the results generated by the Company's principal operating segments, which assists management in monitoring current and forecasting future operations, as certain non-core items such as interest and finance costs, taxes, depreciation and amortization, and other non-cash items and one-time gains and losses are removed. The closest IFRS measure would be net income (loss) for consolidated results.
Adjusted EBITDA as a percentage of revenue is a non-IFRS financial ratio which is calculated by dividing Adjusted EBITDA by revenue for the relevant period. Adjusted EBITDA as a percentage of revenue is a useful financial measure as it is used by management and other stakeholders, including current and potential investors, to analyze the profitability of the Company's principal operating segments.
The following table provides a reconciliation of net income (loss), as disclosed in the consolidated statements of operations and comprehensive income, to Adjusted EBITDA:
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(stated in thousands) |
2023 |
2022 |
2023 |
2022 |
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Net income (loss) |
(2,194) |
(3,095) |
(6,885) |
29,320 |
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Income tax expense (recovery) |
(452) |
(177) |
(1,383) |
2,858 |
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Income (loss) before income taxes |
(2,646) |
(3,272) |
(8,268) |
32,178 |
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Add (deduct): |
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Gain on debt forgiveness |
- |
- |
- |
(49,357) |
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Depreciation |
11,333 |
10,444 |
42,164 |
40,096 |
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Stock based compensation |
549 |
850 |
2,761 |
1,985 |
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Finance costs |
2,687 |
2,988 |
11,397 |
14,416 |
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Other items |
1,447 |
1,223 |
(315) |
603 |
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Adjusted EBITDA |
13,370 |
12,233 |
47,739 |
39,921 |
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Revenue per Operating Day
This non-IFRS measure is calculated as drilling revenue for both
Revenue per Service Hour
This non-IFRS measure is calculated as well servicing revenue divided by Service Hours. This calculation represents the average hourly rate charged to Western's customers.
Working Capital
This non-IFRS measure is calculated as current assets less current liabilities as disclosed in the Company's consolidated financial statements.
Defined Terms
Average active rig count (contract drilling): Calculated as drilling rig utilization multiplied by the average number of drilling rigs in the Company's fleet for the period.
Average active rig count (production services): Calculated as service rig utilization multiplied by the average number of service rigs in the Company's fleet for the period.
Average meters drilled per well: Defined as total meters drilled divided by the number of wells completed in the period.
Average Operating Days per well: Defined as total Operating Days divided by the number of wells completed in the period.
Drilling rig utilization: Calculated based on Operating Days divided by total available days.
Operating Days: Defined as contract drilling days, calculated on a spud to rig release basis.
Service Hours: Defined as well servicing hours completed.
Service rig utilization: Calculated as total Service Hours divided by 217 hours per month per rig multiplied by the average rig count for the period as defined by the CAOEC industry standard.
Contract Drilling Rig Classifications
Cardium class rig: Defined as any contract drilling rig which has a total hookload less than or equal to 399,999 lbs (or 177,999 daN).
Abbreviations
- Barrel ("bbl");
-
Canadian Association of Energy Contractors ("CAOEC"); - DecaNewton ("daN");
- International Financial Reporting Standards ("IFRS");
- Pounds ("lbs");
- Thousand cubic feet ("mcf"); and
-
Western Canadian Sedimentary Basin ("WCSB").
Forward-Looking Statements and Information
This press release contains certain forward-looking statements and forward-looking information (collectively, "forward-looking information") within the meaning of applicable Canadian securities laws, as well as other information based on Western's current expectations, estimates, projections and assumptions based on information available as of the date hereof. All information and statements contained herein that are not clearly historical in nature constitute forward-looking information, and words and phrases such as "may", "will", "should", "could", "expect", "intend", "anticipate", "believe", "estimate", "plan", "predict", "potential", "continue", or the negative of these terms or other comparable terminology are generally intended to identify forward-looking information. Such information represents the Company's internal projections, estimates or beliefs concerning, among other things, an outlook on the estimated amounts and timing of additions to property and equipment, anticipated future debt levels and revenues or other expectations, beliefs, plans, objectives, assumptions, intentions or statements about future events or performance. This forward-looking information involves 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 information.
In particular, forward-looking information in this press release includes, but is not limited to, statements relating to: the business of Western; industry, market and economic conditions and any anticipated effects on Western; commodity pricing; the future demand for the Company's services and equipment; the effect of inflation and commodity prices on energy service activity; expectations with respect to customer spending; the success of Western's drilling rig upgrade program; the potential impact of the current conflicts in
The material assumptions that could cause results or events to differ from current expectations reflected in the forward-looking information in this press release include, but are not limited to: demand levels and pricing for oilfield services; demand for crude oil and natural gas and the price and volatility of crude oil and natural gas; pressures on commodity pricing; the impact of inflation; the continued business relationships between the Company and its significant customers; crude oil transport, pipeline and LNG export facility approval and development; that all required regulatory and environmental approvals can be obtained on the necessary terms and in a timely manner, as required by the Company; liquidity and the Company's ability to finance its operations; the effectiveness of the Company's cost structure and capital budget; the effects of seasonal and weather conditions on operations and facilities; the competitive environment to which the various business segments are, or may be, exposed in all aspects of their business and the Company's competitive position therein; the ability of the Company's various business segments to access equipment (including spare parts and new technologies); global economic conditions and the accuracy of the Company's market outlook expectations for 2024 and in the future; the impact, direct and indirect, of epidemics, pandemics, other public health crisis and geopolitical events, including the conflicts in
Although Western believes that the expectations and assumptions on which such forward-looking information is based on are reasonable, undue reliance should not be placed on the forward-looking information as Western cannot give any assurance that such will prove to be correct. By its nature, forward-looking information is subject to 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, volatility in market prices for crude oil and natural gas and the effect of this volatility on the demand for oilfield services generally; reduced exploration and development activities by customers and the effect of such reduced activities on Western's services and products; political, industry, market, economic, and environmental conditions in
The forward-looking statements and information contained in this news release are made as of the date hereof and Western does not undertake any obligation to update publicly or revise any forward-looking statements and information, whether as a result of new information, future events or otherwise, unless so required by applicable securities laws. Any forward-looking statements contained herein are expressly qualified by this cautionary statement.
SOURCE