Canada NewsWire
CALGARY, Feb. 28, 2018
CALGARY, Feb. 28, 2018 /CNW/ - (TSXV: CWC) CWC Energy Services Corp. ("CWC" or the "Company") announces the release of its operational and financial results for the three months and year ended December 31, 2017. The Financial Statements and Management Discussion and Analysis ("MD&A") for the three months and year ended December 31, 2017 are filed on SEDAR at www.sedar.com.
Highlights for the Three Months Ended December 31, 2017
Highlights for the Year Ended December 31, 2017
For the Quarter Ended |
Previously |
Currently |
December 31, 2017 |
4.00 : 1 |
4.00:1 |
Thereafter |
3.50 : 1 |
4.00:1 |
In addition, on October 30, 2017, CWC and its syndicated lenders agreed to the Company's exercise of the accordion feature to expand its credit facilities from $65 million to $100 million to accommodate the acquisition of the C&J Canada assets.
(1) Please refer to the "Reconciliation of Non-IFRS Measures" section for further information. |
Financial and Operational Highlights
Three months ended December 31, |
Year ended December 31, | ||||||
$ thousands, except shares, per share amounts, margins and ratios |
2017 |
2016 |
% Change |
2017 |
2016 |
2015 | |
FINANCIAL RESULTS |
|||||||
Revenue |
|||||||
Contract Drilling |
10,914 |
5,299 |
106% |
35,222 |
15,903 |
27,758 | |
Production Services |
26,506 |
15,693 |
69% |
76,993 |
57,219 |
53,502 | |
37,420 |
20,992 |
78% |
112,215 |
73,122 |
81,260 | ||
Adjusted EBITDA (1) |
6,630 |
2,923 |
128% |
16,063 |
8,220 |
12,037 | |
Adjusted EBITDA margin (%) (1) |
18% |
14% |
14% |
11% |
15% | ||
Funds from operations |
5,081 |
2,923 |
74% |
14,514 |
8,220 |
12,037 | |
Net income (loss) and comprehensive income (loss) |
8,544 |
(1,717) |
n/m (2) |
4,861 |
(7,468) |
(29,106) | |
Net income (loss) and comprehensive income (loss) margin (%) |
23% |
(8%) |
31% |
4% |
(10%) |
(36%) | |
Dividends declared |
- |
- |
- |
- |
- |
3,579 | |
Per share information |
|||||||
Weighted average number of shares outstanding – basic |
418,913,266 |
390,655,440 |
399,008,915 |
349,836,144 |
285,524,891 | ||
Weighted average number of shares outstanding – diluted |
423,221,202 |
390,655,440 |
403,359,537 |
349,836,144 |
285,524,891 | ||
Adjusted EBITDA (2) per share – basic and diluted |
$0.02 |
$0.01 |
$0.04 |
$0.02 |
$0.04 | ||
Net income (loss) per share - basic and diluted |
$0.02 |
($0.00) |
$0.01 |
($0.02) |
($0.10) | ||
Dividends declared per share |
$0.00 |
$0.00 |
$0.00 |
$0.00 |
$0.0125 |
$ thousands, except ratios |
December 31, 2017 |
December 31, 2016 |
December 31, 2015 |
FINANCIAL POSITION AND LIQUIDITY |
|||
Working capital (excluding debt) (1) |
19,543 |
9,142 |
11,822 |
Working capital (excluding debt) ratio (1) |
2.6:1 |
2.2:1 |
3.1:1 |
Total assets |
264,354 |
210,750 |
222,428 |
Total long-term debt (including current portion) |
49,810 |
33,142 |
52,241 |
Shareholders' equity |
186,519 |
155,482 |
147,462 |
(1) |
Please refer to the "Reconciliation of Non-IFRS Measures" section for further information. |
(2) |
Not meaningful. |
Working capital (excluding debt) has increased 114% since December 31, 2016 due to increased accounts receivable from higher revenue in Q4 2017 offset by higher current liabilities. Long-term debt (including current portion) has increased by $16.7 million mainly due to the acquisition of C&J Canada's assets for $37.5 million less proceeds from the Rights Offering of $26.0 million and an increase in working capital of $10.4 million. Additionally, funds from operations were used for capital expenditures and to purchase shares under the NCIB. Shareholders' equity has increased since December 31, 2016 due to the net income of $4.5 million for the year ended December 31, 2017 and the closing of the $26.0 million Rights Offering offset by the purchase and cancellation of common shares under the NCIB program.
Operational Overview
Contract Drilling
CWC Ironhand Drilling, the Company's Contract Drilling segment, has a fleet of nine telescopic double drilling rigs with depth ratings from 3,200 to 5,000 metres, eight of nine rigs have top drives and two have pad rig walking systems. All of the drilling rigs are well suited for the most active depths for horizontal drilling in the WCSB, including the Montney, Cardium, Duvernay and other deep basin horizons. In 2017, the Company completed the upgrades to Drilling Rig #4 to a high specification rig capable of racking over 6,500 metres of drill pipe. The upgrade is part of the Company's strategic initiatives to increase the capabilities of its existing fleet to meet the growing demands of E&P customers for deeper depths at a cost effective price.
Three months ended | |||||||||
OPERATING HIGHLIGHTS |
Dec. 31, |
Sep. 30, |
Jun. 30, |
Mar. 31, |
Dec. 31, |
Sep. 30, |
Jun. 30, |
Mar. 31, | |
Drilling Rigs |
|||||||||
Active drilling rigs, end of period |
9 |
9 |
9 |
9 |
9 |
9 |
8 |
8 | |
Inactive drilling rigs, end of period |
- |
- |
- |
- |
- |
- |
1 |
1 | |
Total drilling rigs, end of period |
9 |
9 |
9 |
9 |
9 |
9 |
9 |
9 | |
Revenue per operating day (1) |
$23,572 |
$19,424 |
$19,575 |
$20,942 |
$20,623 |
$16,835 |
$21,754 |
$21,565 | |
Drilling rig operating days |
463 |
522 |
155 |
532 |
257 |
301 |
65 |
191 | |
Drilling rig utilization % (2) |
56% |
63% |
19% |
66% |
31% |
37% |
9% |
26% | |
CAODC industry average utilization % |
28% |
29% |
17% |
40% |
24% |
17% |
7% |
20% | |
Wells drilled |
30 |
29 |
17 |
41 |
21 |
21 |
5 |
14 | |
Average days per well |
15.0 |
18.0 |
9.1 |
13.0 |
12.2 |
14.3 |
13.0 |
13.6 | |
Meters drilled (thousands) |
128.1 |
112.2 |
45.6 |
151.8 |
82.0 |
70.0 |
19.5 |
56.0 | |
Meters drilled per day |
277 |
215 |
294 |
285 |
319 |
232 |
300 |
293 | |
Average meters per well |
4,270 |
3,869 |
2,684 |
3,702 |
3,906 |
3,332 |
3,903 |
4,000 |
(1) |
Revenue per operating day is calculated based on operating days (i.e. spud to rig release basis). New or inactive drilling rigs are added based on the first day of field service. |
(2) |
Drilling rig utilization is calculated based on operating days (i.e. spud to rig release basis) in accordance with the methodology prescribed by the CAODC. |
Contract Drilling revenue of $10.9 million for Q4 2017 (Q4 2016: $5.3 million) was achieved with a utilization rate of 56% (Q4 2016: 31%), compared to the CAODC industry average of 28%. CWC achieved 463 drilling rig operating days in Q4 2017, an 80% increase from Q4 2016, reflecting increased year-over-year industry activity, focused marketing efforts on E&P companies with ongoing drilling programs and the high quality and efficiency of our drilling rigs and field employees, coupled with Q4 2016 having experienced unusually warm and wet weather conditions, which negatively affected ground conditions and the movement of heavy equipment resulting in lower activity levels. Q4 2017 revenue was 106% higher compared to Q4 2016 as increased activity was combined with a 14% increase in revenue per operating day.
Contract Drilling revenue of $35.2 million for the year ended December 31, 2017 (2016: $15.9 million) was realized as a result of a 105% increase in drilling rig operating days to 1,672 days (2016: 814 days). CWC's utilization rate in 2017 of 51% continues to significantly exceed the CAODC industry average of 29% and has increased from 26% for the year ended December 31, 2016 when CWC marketed only 8 of 9 drilling rigs for the first half of the year. Increased activity was complemented by average revenue per operating day of $21,066 in 2017, 8% higher than in 2016. Improved financial performance for 2017 reflect higher industry activity due to higher average crude oil prices, despite experiencing a modest pull back in Q2 and Q3 2017, and to CWC's modern, relevant, well maintained and cost effective drilling rigs, as well as a solid reputation for safe and efficient operations, exceptional management and experienced drilling rig crews.
Production Services
With a fleet of 149 service rigs, CWC is the largest well servicing company in Canada as measured by operating hours. CWC's service rig fleet consists of 77 single, 58 double, and 14 slant rigs providing services which include completions, maintenance, workovers and abandonments with depth ratings from 1,500 to 5,000 metres. CWC has chosen to park 38 of its service rigs and focus its sales and operational efforts on the remaining 111 active service rigs.
CWC's fleet of ten coil tubing units consists of six Class I, three Class II and one Class III coil tubing units having depth ratings from 1,500 to 4,000 metres. In light of competitive challenges for CWC's one inactive Class III coil tubing unit, subsequent to the year ended December 31, 2017, the Company has sold this Class III coil tubing unit for cash proceeds of $0.5 million and has chosen to focus its sales and operational efforts on its nine Class I and II coil tubing units which are better suited at servicing SAGD wells, which are shallower in depth and more appropriate for these coil tubing operations.
CWC's fleet of 13 swabbing rigs were acquired as part of the C&J Canada acquisition and operate under the trade name of CWC Swabtech. The Company has chosen to park four of its swabbing rigs and focus its sales and operational efforts on the remaining nine active swabbing rigs.
Three months ended | |||||||||
OPERATING HIGHLIGHTS |
Dec. 31, 2017 |
Sep. 30, 2017 |
Jun. 30, 2017 |
Mar. 31, 2017 |
Dec. 31, 2016 |
Sep. 30, 2016 |
Jun. 30, 2016 |
Mar. 31, 2016 | |
Service Rigs |
|||||||||
Active service rigs, end of period |
111 |
66 |
66 |
66 |
67 |
66 |
65 |
65 | |
Inactive service rigs, end of period |
38 |
8 |
8 |
8 |
7 |
8 |
9 |
9 | |
Total service rigs, end of period |
149 |
74 |
74 |
74 |
74 |
74 |
74 |
74 | |
Operating hours |
40,879 |
28,320 |
20,047 |
32,997 |
27,091 |
22,927 |
21,724 |
23,466 | |
Revenue per hour |
$606 |
$559 |
$551 |
$584 |
$536 |
$543 |
$548 |
$580 | |
Service rig utilization % (1) |
46% |
47% |
33% |
56% |
45% |
38% |
37% |
40% | |
Coil Tubing Units |
|||||||||
Active coil tubing units, end of period |
9 |
9 |
9 |
9 |
8 |
8 |
8 |
8 | |
Inactive coil tubing units, end of period |
1 |
1 |
1 |
1 |
2 |
1 |
1 |
1 | |
Total coil tubing units, end of period |
10 |
10 |
10 |
10 |
10 |
9 |
9 |
9 | |
Operating hours |
1,978 |
1,783 |
1,557 |
4,243 |
2,349 |
2,160 |
1,147 |
3,034 | |
Revenue per hour |
$728 |
$688 |
$657 |
$491 |
$507 |
$458 |
$508 |
$662 | |
Coil tubing unit utilization % (2) |
24% |
22% |
19% |
52% |
32% |
29% |
16% |
42% | |
Swabbing Rigs |
|||||||||
Active swabbing rigs, end of period |
9 |
- |
- |
- |
- |
- |
- |
- | |
Inactive swabbing rigs, end of period |
4 |
- |
- |
- |
- |
- |
- |
- | |
Total swabbing rigs, end of period |
13 |
- |
- |
- |
- |
- |
- |
- | |
Operating hours |
1,063 |
- |
- |
- |
- |
- |
- |
- | |
Revenue per hour |
$286 |
- |
- |
- |
- |
- |
- |
- | |
Swabbing rig utilization % (1) |
19% |
- |
- |
- |
- |
- |
- |
- | |
(1) Service rig & swabbing rig utilizations are calculated based on 10 hours a day, 365 days a year. New service rigs & swabbing rigs are added based on the first day of field service. Service rigs and swabbing rigs requiring their 24,000 hour recertification, refurbishment or have been otherwise removed from service for greater than 90 days are excluded from the utilization calculation until their first day back in field service. | |
(2) Coil tubing unit utilization is calculated based on 10 hours a day, 365 days a year. New coil tubing units are added based on the first day of field service. |
Production Services revenue was $26.5 million in Q4 2017, up $10.8 million (69%) compared to $15.7 million in Q4 2016 primarily as a result of adding an additional 44 active service rigs and nine active swabbing rigs from the C&J Canada acquisition; an increase of 66% in CWC's active service rigs fleet from 67 to 111 rigs for the last 57 days of 2017.
CWC's service rig utilization of 46% in Q4 2017 was slightly higher than the 45% in Q4 2016, while the 40,879 operating hours was 51% higher than the 27,091 operating hours in Q4 2016.
CWC's coil tubing utilization of 24% in Q4 2017 (Q4 2016: 32%) from 1,978 operating hours was 16% lower than the 2,349 operating hours in Q4 2016. Operating hours were negatively impacted by the continuation of low natural gas prices which started in Q3 2017 causing delays in allocation and commitment of capital by our E&P customers. These capital allocation delays were further caused by a change of ownership in land and well positions among some of CWC's key customers. The decreased activity level in Q4 2017 was more than offset by an increase in coil tubing's average revenue per hour of $728; a 44% increase from $507 per hour in Q4 2016 as the Company was successful in increasing pricing for its Class I and II coil tubing units.
For the year ended December 31, 2017, Production Services revenue of $77.0 million was 35% higher than the $57.2 million achieved in 2016 as a result of a 28% increase in service rig operating hours from 95,223 in 2016 to a Company record setting 122,242 operating hours in 2017 driven by the addition of 44 service rigs for the last 57 days of 2017 as a result of the C&J Canada acquisition, as well as an increase in pricing of 6% in 2017 compared to 2016. Service rig utilization increased to 46% in 2017 compared to 40% in 2016. In addition, coil tubing operating hours increased 10% to 9,561 operating hours in 2017 (2016: 8,690 operating hours) as a result of one additional active coil tubing unit being added to the fleet in 2017 compared to 2016. The 10% increase in coil tubing activity combined with the 10% increase to the average coil tubing revenue per hour in 2017 compared to 2016 also helped contribute to the increased Production Services revenue in 2017 compared to 2016. However, the coil tubing utilization of 29% in 2017 (2016: 30%) was impacted by low natural gas prices, which started in Q3 2017, causing delays in allocation and commitment of capital by our E&P customers. These capital allocation delays were further caused by a change of ownership in land and well positions among some of CWC's key customers.
Capital Expenditures
Three months ended December 31, |
Year ended December 31, | |||
$ thousands |
2017 |
2016 |
2017 |
2016 |
Contract Drilling |
1,176 |
1,303 |
3,964 |
1,662 |
Production Services |
37,730 |
451 |
40,559 |
996 |
Corporate |
- |
- |
9 |
- |
Total capital expenditures |
38,906 |
1,754 |
44,532 |
2,658 |
Growth capital |
37,605 |
207 |
39,340 |
207 |
Maintenance and infrastructure capital |
1,301 |
1,547 |
5,192 |
2,451 |
Total capital expenditure |
38,906 |
1,754 |
44,532 |
2,658 |
Capital expenditures in 2017 of $44.5 million are $41.9 million higher than the $2.7 million in 2016 and primarily consist of the acquisition of C&J Canada's service and swabbing rig assets, recertification costs, leasehold improvements, new drill pipe, coil tubing equipment and vehicles.
A 2018 capital expenditure budget of $12.7 million was approved by the Board of Directors on December 13, 2017, $7.2 million of which is growth capital to improve certain drilling and coil tubing equipment while the remaining $5.5 million is maintenance and infrastructure capital related to recertifications, additions and upgrades to field equipment for the drilling rigs, service rigs, swabbing rigs and coil tubing divisions as well as information technology infrastructure.
Outlook
The continued optimism that has been building up throughout 2017 over improving crude oil prices as OPEC reaffirmed their decision to curtail production at their November 30, 2017 meeting. As a result crude oil, as represented by WTI, closed above US$60/bbl for the year ended December 31, 2017; the first time it has achieve this price since May 2015. WTI averaged US$55.28/bbl in Q4 2017, an increase of 15% over the Q3 2017 average price of US$48.18/bbl and a 13% increase from the Q4 2016 average price of US$49.04/bbl. Natural gas prices improved in Q4 2017 with AECO averaging $1.67/GJ; an increase of 23% over the Q3 2017 average price of $1.36/GJ, but still significantly lower by 43% from the Q4 2016 average price of $2.95/GJ. With the backdrop of an improving crude oil price and a depressed natural gas price, the Petroleum Services Association of Canada ("PSAC") on January 31, 2018 updated its 2018 forecast of number of wells drilled to 7,600 wells; a decrease of 300 wells or 4% compared to their original 2018 forecast on October 31, 2017, but consistent with the 7,550 wells drilled in 2017.
CWC is experiencing strong utilization in its drilling rig and service rig business units well above the CAODC industry averages. During Q1 2018, the Company had all nine drilling rigs working (100%) and expects this utilization to continue until Q2 2018 spring breakup. Similar to CWC's drilling rigs, the Company's service rigs continue to see strong industry demand leading all other Canadian service rig companies with the highest operating hours as determined by the CAODC. CWC was successful in increasing service rig pricing by 8% in Q4 2017 compared to Q3 2017 and intends to continue implementing pricing increases with our E&P customers to cover the additional costs of the Government of Alberta's Bill 17, which requires employers to pay statutory holiday pay to its hourly field employees regardless of whether the employee works on a statutory holiday. CWC believes the improving crude oil price will allow for the Company to increase the price for its services throughout 2018. However, aggressive pricing from certain competitors will limit how much CWC will be able to garner from our E&P customers. As such, CWC will continue to sustainably position itself as a low cost contractor for its E&P customers providing the highest quality service from the highest quality people at reasonable prices. CWC has achieved 18 continuous quarters of positive Adjusted EBITDA since Q2 2013 initially demonstrating management's ability to reduce costs thereby offsetting lower revenue from reduced pricing and activity since the beginning of this industry downturn three years ago and now beginning to demonstrate management's ability to increase pricing and activity as the industry recovers.
While CWC continues to maintain focus on its operational and financial performance, it also recognizes the need to pursue opportunities that create long-term shareholder value. On May 4, 2017, CWC announced a process to review strategic alternatives with a view to maximizing shareholder value by capitalizing on CWC's strong financial and operational performance, market share and attractive fleet of modern assets. This strategic alternatives review process resulted in CWC's acquisition of C&J Canada's service and swabbing rig assets to become the largest service rig company in Canada by operating hours, according to the CAODC, with 111 active service rigs and approximately 16% of the Canadian service rig market share. CWC will continue to pursue further opportunities to consolidate the North American drilling and well servicing industry. CWC cautions that there are no guarantees that other strategic opportunities will result in a transaction, or if a transaction is undertaken, as to its terms or timing.
About CWC Energy Services Corp.
CWC Energy Services Corp. is a premier contract drilling and well servicing company operating in the WCSB with a complementary suite of oilfield services including drilling rigs, service rigs and coil tubing units. The Company's corporate office is located in Calgary, Alberta, with operational locations in Nisku, Grande Prairie, Slave Lake, Drayton Valley, Lloydminster, Provost and Brooks, Alberta. The Company's shares trade on the TSX Venture Exchange under the symbol "CWC".
Forward-Looking Information
This MD&A contains certain forward-looking information and statements within the meaning of applicable Canadian securities legislation. Certain statements contained in this MD&A, including most of those contained in the section titled "Outlook" and including statements which may contain such words as "anticipate", "could", "continue", "should", "seek", "may", "intend", "likely", "plan", "estimate", "believe", "expect", "will", "objective", "ongoing", "project", "view" and similar expressions are intended to identify forward-looking information or statements. In particular, this MD&A contains forward-looking statements involving the anticipated benefits to be derived from the C&J Canada transaction including SG&A expense synergies with respect thereto and statements with respect to the Transaction being accretive on various metrics, management's assessment of future plans and operations, planned levels of capital expenditures, expectations as to activity levels, expectations on the sustainability of future cash flow and earnings and the ability to pay dividends, expectations with respect to crude oil and natural gas prices, activity levels in various areas, expectations regarding the level and type of drilling and production and related drilling and well services activity in the WCSB, expectations regarding entering into long-term drilling contracts and expanding its customer base, and expectations regarding the business, operations, revenue and debt levels of the Company in addition to general economic conditions. Although the Company believes that the expectations and assumptions on which such forward-looking information and statements are based are reasonable, undue reliance should not be placed on the forward-looking information and statements because the Company can give no assurances that they will prove to be correct. Since forward-looking information and 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, the risks associated with the drilling and oilfield services sector (ie. demand, pricing and terms for oilfield drilling and services; current and expected oil and gas prices; exploration and development costs and delays; reserves discovery and decline rates; pipeline and transportation capacity; weather, health, safety and environmental risks), integration of acquisitions, competition, and uncertainties resulting from potential delays or changes in plans with respect to acquisitions, development projects or capital expenditures and changes in legislation, including but not limited to tax laws, royalties and environmental regulations, stock market volatility and the inability to access sufficient capital from external and internal sources and the inability to pay dividends. Accordingly, readers should not place undue reliance on the forward-looking statements. Readers are cautioned that the foregoing list of factors is not exhaustive. Additional information on these and other factors that could affect the Company's financial results are included in reports on file with applicable securities regulatory authorities and may be accessed through SEDAR at www.sedar.com. The forward-looking information and statements contained in this MD&A are made as of the date hereof and the Company undertakes no obligation to update publicly or revise any forward-looking information or statements, whether as a result of new information, future events or otherwise, unless so required by applicable securities laws. Any forward-looking statements made previously may be inaccurate now.
Reconciliation of Non-IFRS Measures
Three months ended |
Year ended | |||||
December 31, |
December 31, | |||||
$ thousands except share and per share amounts |
2017 |
2016 |
2017 |
2016 |
2015 | |
NON-IFRS MEASURES |
||||||
Adjusted EBITDA: |
||||||
Net income (loss) and comprehensive income (loss) |
8,544 |
(1,717) |
4,861 |
(7,468) |
(29,106) | |
Add: |
||||||
Depreciation |
4,811 |
3,733 |
17,103 |
14,248 |
15,469 | |
Finance costs |
606 |
502 |
2,054 |
2,515 |
2,203 | |
Transaction costs |
1,549 |
- |
1,549 |
- |
- | |
Deferred income tax expense (recovery) |
(142) |
(420) |
(1,285) |
(2,414) |
(1,966) | |
Stock based compensation |
278 |
594 |
869 |
945 |
1,008 | |
Gain on acquisition |
(9,128) |
- |
(9,128) |
- |
- | |
Impairment of goodwill and assets held for sale |
- |
- |
- |
- |
24,214 | |
Loss on sale of equipment |
112 |
231 |
40 |
394 |
215 | |
Adjusted EBITDA (1) |
6,630 |
2,923 |
16,063 |
8,220 |
12,037 | |
Adjusted EBITDA per share – basic and diluted(1) |
$0.02 |
$0.01 |
$0.04 |
$0.02 |
$0.04 | |
Adjusted EBITDA margin (Adjusted EBITDA/Revenue) (1) |
18% |
14% |
14% |
11% |
15% | |
Weighted average number of shares outstanding – basic |
418,913,266 |
390,655,440 |
399,008,915 |
349,836,144 |
285,524,891 | |
Weighted average number of shares outstanding - diluted |
423,221,202 |
390,655,440 |
403,359,537 |
349,836,144 |
285,524,891 | |
Funds from operations: |
||||||
Cash flows from operating activities |
(2,116) |
2,300 |
4,260 |
8,788 |
25,427 | |
Add (deduct): Change in non-cash working capital |
7,197 |
623 |
10,254 |
(568) |
(13,390) | |
Funds from operations |
5,081 |
2,923 |
14,514 |
8,220 |
12,037 | |
Gross margin: |
||||||
Revenue |
37,420 |
20,992 |
112,215 |
73,122 |
81,260 | |
Less: Direct operating expenses |
26,620 |
15,248 |
82,361 |
53,209 |
55,124 | |
Gross margin (2) |
10,800 |
5,744 |
29,854 |
19,913 |
26,136 | |
Gross margin percentage (2) |
29% |
27% |
27% |
27% |
32% |
$ thousands |
December 31, 2017 |
December 31, 2016 |
December 31, 2015 | |
Working capital (excluding debt): |
||||
Current assets |
31,745 |
16,501 |
17,333 | |
Less: Current liabilities |
(12,378) |
(7,535) |
(5,716) | |
Add: Current portion of long-term debt |
176 |
176 |
205 | |
Working capital (excluding debt) (3) |
19,543 |
9,142 |
11,822 | |
Working capital (excluding debt) ratio (3) |
2.6:1 |
2.2:1 |
3.1:1 | |
Net debt: |
||||
Long-term debt |
49,634 |
32,966 |
52,036 | |
Less: Current assets |
(31,745) |
(16,501) |
(17,333) | |
Add: Current liabilities |
12,378 |
7,535 |
5,716 | |
Net debt (4) |
30,267 |
24,000 |
40,419 |
(1) |
Adjusted EBITDA (Earnings before interest and finance costs, income tax expense, depreciation, amortization, gain or loss on disposal of asset, goodwill impairment, transaction costs and stock based compensation) is not a recognized measure under IFRS. Management believes that in addition to net earnings, Adjusted EBITDA is a useful supplemental measure as it provides an indication of the Company's ability to generate cash flow in order to fund working capital, service debt, pay current income taxes, pay dividends, repurchase common shares under the Normal Course Issuer Bid, and fund capital programs. Investors should be cautioned, however, that Adjusted EBITDA should not be construed as an alternative to net income (loss) and comprehensive income (loss) determined in accordance with IFRS as an indicator of the Company's performance. CWC's method of calculating Adjusted EBITDA may differ from other entities and accordingly, Adjusted EBITDA may not be comparable to measures used by other entities. Adjusted EBITDA margin is calculated as Adjusted EBITDA divided by revenue and provides a measure of the percentage of Adjusted EBITDA per dollar of revenue. Adjusted EBITDA per share is calculated by dividing Adjusted EBITDA by the weighted average number of shares outstanding as used for calculation of earnings per share. |
(2) |
Gross margin is calculated from the statement of comprehensive income as revenue less direct operating costs and is used to assist management and investors in assessing the Company's financial results from operations excluding fixed overhead costs. Gross margin percentage is calculated as gross margin divided by revenue. The Company believes the relationship between revenue and costs expressed by the gross margin percentage is a useful measure when compared over different financial periods as it demonstrates the trending relationship between revenue, costs and margins. Gross margin and gross margin percentage are non-IFRS measures and do not have any standardized meaning prescribed by IFRS and may not be comparable to similar measures provided by other companies. |
(3) |
Working capital (excluding debt) is calculated based on current assets less current liabilities excluding the current portion of long-term debt. Working capital (excluding debt) is used to assist management and investors in assessing the Company's liquidity. Working capital (excluding debt) does not have any meaning prescribed under IFRS and may not be comparable to similar measures provided by other companies. Working capital (excluding debt) ratio is calculated as current assets divided by the difference of current liabilities less the current portion of long-term debt. |
(4) |
Net debt is not a recognized measure under IFRS and does not have any standardized meaning prescribed by IFRS and may not be comparable to similar measures provided by other companies. Management believes net debt is a useful indicator of a company's debt position. |
SOURCE CWC Energy Services Corp.
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