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Western Energy Services Corp. Releases Third Quarter 2017 Financial and Operating Results

Oct. 25, 2017 , CALGARY /CNW/ - Western Energy Services Corp. ("Western" or the "Company") (WRG.TO) announces the release of its third quarter 2017 financial and operating results.  Additional information relating to the Company, including the Company's financial statements and management's discussion and analysis as at and for the three and nine months ended September 30, 2017 and 2016 will be available on SEDAR at www.sedar.com. Non-International Financial Reporting Standards ("Non-IFRS") measures and abbreviations for standard industry terms are included in this press release.  All amounts are denominated in Canadian dollars (CDN$) unless otherwise identified.

Third Quarter 2017 Operating Results:

  • Operating Revenue in the third quarter of 2017 benefited from improved crude oil prices and resulted in higher customer spending and a corresponding increase in demand for Western's services. Third quarter Operating Revenue increased by $20.4 million (or 67%) to $51.1 million in 2017 as compared to $30.7 million in 2016. In the contract drilling segment, Operating Revenue totalled $38.7 million in the third quarter of 2017 as compared to $20.2 million in the third quarter of 2016, an increase of $18.5 million (or 92%); while in the production services segment, Operating Revenue totalled $12.4 million for the three months ended September 30, 2017 as compared to $10.5 million in the third quarter of 2016, an increase of $1.9 million (or 19%). Higher utilization in the third quarter of 2017, and improved pricing in all divisions, positively impacted Operating Revenue in the contract drilling and production services segments as described below:

These factors, combined with improved commodity prices, resulted in higher demand for the Company's drilling rigs.  Operating Revenue per Billable Day in the third quarter of 2017 improved by 10% as compared to the same period in the prior year, as market conditions continued to improve;

  • Third quarter Adjusted EBITDA improved by $6.0 million to $6.9 million in 2017 as compared to $0.9 million in the third quarter of 2016. The year over year change in Adjusted EBITDA is due to higher activity and improved pricing across all divisions in 2017.
  • Administrative expenses, excluding depreciation and stock based compensation, decreased by 2% in the third quarter of 2017 as compared to the second quarter of 2017 due to lower employee costs. Third quarter 2017 administrative expenses increased by $0.6 million (or 12%) to $5.4 million , as compared to $4.8 million in the third quarter of 2016 mainly due to higher employee related costs, coupled with one time professional fees incurred in the period.
  • The Company incurred a net loss of $11.5 million in the third quarter of 2017 ( $0.16 per basic common share) as compared to a net loss of $17.0 million in the same period in 2016 ( $0.23 per basic common share). The change can be attributed to the following:

Offsetting the above mentioned items is a $1.9 million decrease in income tax recovery due to improved earnings before taxes.

  • Third quarter 2017 capital expenditures of $6.3 million included $4.0 million of expansion capital and $2.3 million of maintenance capital. In total, capital spending in the third quarter of 2017 increased by $5.6 million from the $0.7 million incurred in the third quarter of 2016. The Company incurred expansion capital mainly related to drilling rig upgrades in the third quarter of 2017, as well as necessary maintenance capital related to the higher activity in the period.
  • Subsequent to September 30, 2017 , on October 17, 2017 the Company closed the following financing transactions:

Western expects that the net proceeds of the Second Lien Facility, Private Placement and the Bought Deal, along with cash on hand and funds available under the Credit Facilities will be used to repay the Company's Senior Notes in the first quarter of 2018 when the Senior Notes will be redeemable at par.


Year to Date 2017 Operating Results:

  • Operating Revenue for the nine month period ended September 30, 2017 benefited from improved commodity prices and higher customer spending which resulted in a corresponding increase in demand for Western's services. For the nine months ended September 30, 2017 , Operating Revenue increased by $84.4 million (or 112%) to $159.7 million as compared to $75.3 million for the nine months ended September 30, 2016 . In the contract drilling segment, Operating Revenue totalled $120.8 million for the nine months ended September 30, 2017 , an increase of $70.9 million (or 142%), as compared to $49.9 million in the same period of the prior year, and included $6.4 million in shortfall commitment revenue in 2017, as compared to $1.8 million in 2016; while in the production services segment, Operating Revenue totalled $39.1 million , an increase of $13.7 million (or 54%) as compared to $25.4 million in the same period of the prior year. Higher utilization for the nine months ended September 30, 2017 , as compared to the same period of the prior year, offset by lower pricing in the contract drilling segment, impacted Operating Revenue in the contract drilling and production services segments as described below:
  • Adjusted EBITDA for the nine months ended September 30, 2017 increased by $23.3 million to $25.6 million in 2017 as compared to $2.3 million for the nine months ended September 30, 2016 . The year over year increase in Adjusted EBITDA is due to higher activity across all divisions, a $4.6 million increase in shortfall commitment revenue in 2017, and the Company's ability to safely and efficiently reactivate equipment and crews without incurring significant costs, including rigs that had been idle for an extended period of time. These factors were aided by improved pricing in the production services segment, which was partially offset by lower pricing in the contract drilling segment.
  • Administrative expenses, excluding depreciation and stock based compensation, for the nine month period ended September 30, 2017 increased by $1.8 million (or 12%) to $16.8 million as compared to $15.0 million in the same period of the prior year. The increase in administrative expenses is mainly due to higher employee related costs, coupled with one time professional fees incurred in the period.
  • The Company incurred a net loss of $32.5 million for the nine months ended September 30, 2017 ( $0.44 per basic common share) as compared to a net loss of $47.5 million for the same period in 2016 ( $0.64 per basic common share). The decrease in net loss can be attributed to the following:

Offsetting the above mentioned items are the following:

  • Year to date capital expenditures of $12.2 million included $6.4 million of expansion capital and $5.8 million of maintenance capital. In total, capital spending for the nine months ended September 30, 2017 increased by $10.2 million from the $2.0 million incurred in the same period of 2016. The Company incurred expansion capital mainly related to drilling rig upgrades in the nine months ended September 30, 2017 , which have contributed to the increase in cash flow from operating activities year to date, as well as necessary maintenance capital related to the higher activity in the period.


Selected Financial Information

(stated in thousands, except share and per share amounts)


Three months ended Sept 30

Nine months ended Sept 30

Financial Highlights

2017

2016

Change

2017

2016

Change

Revenue

54,131

32,485

67%

171,660

79,312

116%

Operating Revenue(1)

51,111

30,665

67%

159,733

75,258

112%

Gross Margin(1)

12,299

5,685

116%

42,424

17,255

146%

Gross Margin as a percentage of Operating Revenue

24%

19%

26%

27%

23%

17%

Adjusted EBITDA(1)

6,882

896

668%

25,628

2,269

1,029%

Adjusted EBITDA as a percentage of Operating Revenue

13%

3%

333%

16%

3%

433%

Cash flow from operating activities

1,609

909

77%

25,441

17,958

42%

Capital expenditures

6,349

651

875%

12,220

1,995

513%

Net loss

(11,478)

(16,973)

(32%)

(32,471)

(47,464)

(32%)


-basic net loss per share

(0.16)

(0.23)

(30%)

(0.44)

(0.64)

(31%)


-diluted net loss per share

(0.16)

(0.23)

(30%)

(0.44)

(0.64)

(31%)

Weighted average number of shares








-basic

73,877,203

73,722,144

-

73,823,970

73,672,389

-


-diluted                                                      

73,877,203

73,722,144

-

73,823,970

73,672,389

-

Outstanding common shares as at period end

73,974,594

73,795,266

-

73,974,594

73,795,266

-

(1) See "Non-IFRS measures" included in this press release.
















Three months ended Sept 30

Nine months ended Sept 30

Operating Highlights(1)

2017

2016

Change

2017

2016

Change

Contract Drilling







Canadian Operations:







Contract drilling rig fleet:








-Average active rig count

20.2

11.4

77%

20.3

8.0

154%


-End of period

51

51

-

51

51

-

Operating Revenue per Billable Day

16,825

15,256

10%

17,109(3)

17,206(4)

(1%)

Operating Revenue per Operating Day

18,604

17,017

9%

18,862(3)

19,224(4)

(2%)

Operating Days

1,681

940

79%

5,027

1,959

157%

Drilling rig utilization - Billable Days

40%

22%

82%

40%

15%

167%

Drilling rig utilization - Operating Days

36%

20%

80%

36%

14%

157%

CAODC industry average utilization(2)

29%

17%

71%

29%

15%

93%








United States Operations:







Contract drilling rig fleet:








-Average active rig count

3.3

1.8

83%

2.8

1.3

115%


-End of period

5

5

-

5

5

-

Operating Revenue per Billable Day (US$)

19,801

18,967

4%

19,763

22,515

(12%)

Operating Revenue per Operating Day (US$)

21,832

22,246

(2%)

22,850

25,923

(12%)

Operating Days

272

145

88%

656

306

114%

Drilling rig utilization - Billable Days

65%

37%

76%

56%

26%

115%

Drilling rig utilization - Operating Days

59%

32%

84%

48%

22%

118%








Production Services







Well servicing rig fleet:








-Average active rig count

17.7

15.6

13%

17.3

11.4

52%


-End of period

66

66

-

66

66

-

Service rig Operating Revenue per Service Hour

629

603

4%

661

646

2%

Service Hours

16,328

14,335

14%

47,296

31,123

52%

Service rig utilization

27%

24%

13%

26%

17%

53%


(1)

See "Non-IFRS measures" included in this press release.

(2)

Source:  The Canadian Association of Oilwell Drilling Contractors ("CAODC").  The CAODC industry average is based on Operating Days divided by total available days.

(3)

Excludes shortfall commitment revenue from take or pay contracts of $6.4 million for the nine months ended September 30, 2017.

(4)

Excludes shortfall commitment revenue from take or pay contracts of $1.8 million for the nine months ended September 30, 2016.

 






Financial Position at (stated in thousands)


September 30, 2017

December 31, 2016

September 30, 2016

Working capital


46,184

51,118

55,259

Property and equipment


663,542

708,567

720,554

Total assets


737,385

793,525

794,170

Long term debt


264,958

264,070

264,118

 

Western is an oilfield service company focused on three core business lines: contract drilling, well servicing and oilfield rental equipment services.  Western provides contract drilling services through its division, Horizon Drilling ("Horizon") in Canada , and its wholly owned subsidiary, Stoneham Drilling Corporation ("Stoneham") in the United States ("US").  Western provides well servicing and oilfield rental equipment services in Canada through its wholly owned subsidiary Western Production Services Corp. ("Western Production Services").  Western Production Services' division, Eagle Well Servicing ("Eagle") provides well servicing operations, while its division, Aero Rental Services ("Aero") provides oilfield rental equipment services.  Financial and operating results for Horizon and Stoneham are included in Western's contract drilling segment, while financial and operating results for Eagle and Aero are included in Western's production services segment.       

Western has a drilling rig fleet of 56 rigs specifically suited for drilling horizontal wells of increased complexity.  Western is currently the fifth largest drilling contractor in Canada , based on the CAODC registered rigs, with a fleet of 51 rigs operating through Horizon.  Of the Canadian fleet, 24 are classified as Cardium class rigs, 19 as Montney class rigs and eight as Duvernay class rigs.  As compared to the Cardium class rigs, the Montney class rigs have a larger hookload, while the Duvernay class rigs have the largest hookload allowing the rig to support more drill pipe downhole.  Additionally, Western has five Duvernay class triple drilling rigs deployed in the United States operating through Stoneham.  Western is also the sixth largest well servicing company in Canada with a fleet of 66 rigs operating through Eagle.  Western's oilfield rental equipment division, which operates through Aero, provides oilfield rental equipment for hydraulic fracturing services, well completions and production work, coil tubing and drilling services.

Crude oil and natural gas prices impact the cash flow of Western's customers, which in turn impacts the demand for Western's services.  West Texas Intermediate ("WTI") on average was relatively constant in the third quarter of 2017 as compared to the second quarter of 2017, however was 7% higher compared to the same period in the prior year.  For Western's Canadian customers, the impact of foreign exchange rates when translating WTI into the Canadian equivalent, resulted in only a 3% increase for the three months ended September 30, 2017 , as compared to the same period in the prior year.  Additionally, in the third quarter of 2017, Western Canadian Select ("WCS") on average declined by 1% as compared to the second quarter of 2017, however improved by 18% as compared to the same period of the prior year.  For the nine months ended September 30, 2017 , WTI was 19% higher than the same period of the prior year.  Similarly, WCS also improved for the nine months ended September 30, 2017 , increasing by 34% as compared to the nine months ended September 30 , 2016.   Canadian natural gas prices, such as AECO, declined quarter over quarter, decreasing on average by 41% from the second quarter of 2017 to the third quarter of 2017.  Further, AECO decreased in the third quarter of 2017 as compared to the same period of the prior year, decreasing by 31%, however for the nine month period ending September 30, 2017 AECO improved by 29% as compared to the same period in the prior year.  The following table summarizes average crude oil and natural gas prices, as well as average foreign exchange rates for the three and nine months ended September 30, 2017 and 2016.








Three months ended Sept 30


Nine months ended Sept 30



2017

2016

Change


2017

2016

Change

Average crude oil and natural gas prices(1)(2)


















Crude Oil









West Texas Intermediate (US$/bbl)


48.16

44.88

7%


49.32

41.44

19%

Western Canadian Select (CDN$/bbl)


47.27

40.00

18%


49.62

37.09

34%










Natural Gas









30 day Spot AECO (CDN$/mcf)


1.65

2.38

(31%)


2.40

1.86

29%










Average foreign exchange rates(2)









US dollar to Canadian dollar


1.25

1.30

(4%)


1.31

1.32

(1%)


(1)

See "Abbreviations" included in this press release.

(2)

Source: Bloomberg

 

Improved commodity prices in 2017 has led to a corresponding increase in the demand for oilfield services in both Canada and the United States.  The CAODC reported that for drilling in Canada , the total number of Operating Days in the Western Canadian Sedimentary Basin ("WCSB") increased approximately 41% and 72% for the three and nine months ended September 30, 2017 respectively, as compared to the same periods in the prior year.  Similarly, as reported by Baker Hughes, a GE Company, the number of active drilling rigs in the United States increased approximately 97% and 77% for the three and nine months ended September 30, 2017 respectively, as compared to the same periods in the prior year.

Outlook

Currently, 22 of Western's drilling rigs are operating.  Five of Western's 56 drilling rigs (or 9%) are under long term take or pay contracts, with two expected to expire in 2018, two expected to expire in 2019 and one expected to expire in 2020.  These contracts each typically generate between 250 and 350 Billable Days per year.

Western's capital budget for 2017 remains unchanged and totals approximately $20 million comprised of $8 million in expansion capital and $12 million in maintenance capital.  The majority of the capital budget relates to expansion capital in the contract drilling segment related to drilling rig upgrades that offer compelling economics.  Western believes the revised 2017 capital budget provides a prudent use of cash resources and will allow it to maintain its premier drilling and well servicing rig fleets, while remaining responsive to customer requirements.  Western will continue to manage its operations in a disciplined manner and make any required adjustments to its capital program as customer demand changes.  Approximately $2 million from the revised 2017 capital budget is expected to be carried forward into 2018.

Since hitting 10 year lows in the first quarter of 2016, commodity prices, while remaining well below previous highs, have improved.  As such, North American drilling rig counts have begun to recover and the Company is expecting increased year over year activity levels throughout the remainder of 2017.  However, improved pricing for the Company's services has lagged the recovery in activity and is expected to occur gradually as rates are typically increased for rigs and drilling programs on an individual basis rather than universally.  Improving gross margin is a priority for the Company and, as has been demonstrated over the last two quarters, Western is working to implement higher rates with each rig that is awarded work.  Prices for Western's services below historical levels will continue to impact Adjusted EBITDA and cash flow from operating activities in the near term.  However, Western's variable cost structure and a prudent capital budget will aid in preserving balance sheet strength.  In addition to $39.6 million in cash and cash equivalents at September 30, 2017 , Western currently has $80.0 million of available credit under its undrawn amended Credit Facilities, which do not mature until December 17 , 2020.  Additionally, Western plans to repay the Senior Notes in the first quarter of 2018 with proceeds from the Second Lien Facility, Private Placement and the Bought Deal completed subsequent to September 30, 2017 , along with cash on hand and funds available under the Credit Facilities.  Completing these financing transactions will lower Western's total debt and leverage metrics, decrease Western's effective interest rates and extend the maturity on all of Western's long term debt.  Additionally, Western will save approximately $5.3 million annually in cash interest expense, due to the decreased total debt level and lower interest rate on the Second Lien Facility, as compared to the existing Senior Notes. 

Oilfield service activity in Canada will be impacted by the development of resource plays in Alberta and northeast British Columbia including those related to increased crude oil transportation capacity through pipeline development, increased environmental regulations including the implementation of a carbon tax in Alberta , and decreased foreign investment into Canada.  Currently, the largest challenges facing the oilfield service industry are continued customer spending constraints as a result of lower commodity prices and the increasing challenge of staffing field crews, particularly in the well servicing division.  Western's view is that its modern drilling and well servicing rig fleets, reputation, and disciplined cash management provide a competitive advantage which will enable the Company to manage through the current slowdown in oilfield service activity.

2017 Third Quarter Financial and Operating Results Conference Call and Webcast

Western has scheduled a conference call and webcast to begin promptly at 9:00 a.m. MDT (11:00 a.m. EDT) on Thursday, October 26, 2017 .

The conference call dial-in number is 1-888-231-8191.

A live webcast of the conference call will be accessible on Western's website at www.wesc.ca by selecting "Investors", then "Webcasts".  Shortly after the live webcast, an archived version will be available for approximately 14 days.

An archived recording of the conference call will also be available approximately two hours after the completion of the call until November 9, 2017 by dialing 1-855-859-2056, passcode 95867128.

Non-IFRS Measures

Western uses certain measures in this press release which do not have any standardized meaning as prescribed by International Financial Reporting Standards ("IFRS").  These measures, which are derived from information reported in the condensed consolidated financial statements, may not be comparable to similar measures presented by other reporting issuers.  These measures have been described and presented in this press release in order to provide shareholders and potential investors with additional information regarding the Company.  These Non-IFRS measures are identified and defined as follows:

Operating Revenue

Management believes that in addition to revenue, Operating Revenue is a useful supplemental measure as it provides an indication of the revenue generated by Western's principal operating activities, excluding flow through third party charges such as rig fuel, which at the customer's request may be paid for initially by Western, then recharged in its entirety to Western's customers.

Gross Margin

Management believes that in addition to net income, Gross Margin is a useful supplemental measure as it provides an indication of the results generated by Western's principal operating activities prior to considering administrative expenses, depreciation and amortization, stock based compensation, how those activities are financed, the impact of foreign exchange, how the results are taxed, how funds are invested, and how non-cash items and one-time gains and losses affect results.

The following table provides a reconciliation of revenue under IFRS, as disclosed in the condensed consolidated statements of operations and comprehensive income, to Operating Revenue and Gross Margin:








Three months ended Sept 30


Nine months ended Sept 30

(stated in thousands)

2017

2016


2017

2016

Operating Revenue







Drilling

38,711

20,210


120,754

49,922


Production services

12,411

10,460


39,094

25,354


Less: inter-company eliminations

(11)

(5)


(115)

(18)


51,111

30,665


159,733

75,258

Third party charges

3,020

1,820


11,927

4,054

Revenue

54,131

32,485


171,660

79,312

Less: operating expenses

(58,049)

(43,601)


(178,419)

(103,904)

Add:







Depreciation – operating

16,196

16,712


48,989

41,352


Stock based compensation – operating

21

89


194

495

Gross Margin

12,299

5,685


42,424

17,255

 

Adjusted EBITDA

Management believes that in addition to net income, 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 supplemental measure as it provides an indication of the results generated by the Company's principal operating segments similar to Gross Margin but also factors in the cash administrative expenses incurred in the period.

Operating Earnings

Management believes that in addition to net income, Operating Earnings is a useful supplemental measure as it provides an indication of the results generated by the Company's principal operating segments similar to Adjusted EBITDA but also factors in the depreciation expense incurred in the period.

The following table provides a reconciliation of net loss under IFRS, as disclosed in the condensed consolidated statements of operations and comprehensive income, to earnings before interest and finance costs, taxes, depreciation and amortization ("EBITDA"), Adjusted EBITDA and Operating Loss:






Three months ended Sept 30


Nine months ended Sept 30

(stated in thousands)

2017

2016


2017

2016

Net loss

(11,478)

(16,973)


(32,471)

(47,464)

Add:







Finance costs

5,521

5,708


16,352

17,044


Income tax recovery

(4,071)

(6,043)


(11,713)

(16,772)


Depreciation – operating

16,196

16,712


48,989

41,352


Depreciation – administrative

300

378


929

1,204

EBITDA

6,468

(218)


22,086

(4,636)

Add:







Stock based compensation – operating

21

89


194

495


Stock based compensation – administrative

158

759


1,292

2,651


Loss on asset decommissioning

-

-


-

5,225


Other items

235

266


2,056

(1,466)

Adjusted EBITDA

6,882

896


25,628

2,269

Subtract:







Depreciation – operating

(16,196)

(16,712)


(48,989)

(41,352)


Depreciation – administrative

(300)

(378)


(929)

(1,204)

Operating Loss

(9,614)

(16,194)


(24,290)

(40,287)

 

Net Debt

The following table provides a reconciliation of long term debt under IFRS, as disclosed in the condensed consolidated balance sheets to Net Debt:







(stated in thousands)




September 30, 2017

December 31, 2016

Long term debt




264,958

264,070

Current portion of long term debt




500

684

Less: cash and cash equivalents




(39,576)

(44,597)

Net Debt




225,882

220,157

 

Defined Terms:

Average active rig count (contract drilling): Calculated as drilling rig utilization – Billable Days 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.

Billable Days:  Defined as Operating Days plus rig mobilization days.

Drilling rig utilization Operating Days (or "Drilling Rig Utilization"):  Calculated based on Operating Days divided by total available days.

Drilling rig utilization Billable Days:  Calculated based on Billable 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 based on Service Hours divided by available hours, being 10 hours per day, per well servicing rig, 365 days per year in 2017 (2016:366 days).

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). 

Montney class rig: Defined as any contract drilling rig which has a total hookload between 400,000 lbs (or 178,000 daN) and 499,999 lbs (or 221,999 daN).

Duvernay class rig: Defined as any contract drilling rig which has a total hookload equal to or greater than 500,000 lbs (or 222,000 daN).

Abbreviations:

  • Barrel ("bbl");
  • Basis point ("bps"): A 1% change equals 100 basis points and a 0.01% change is equal to one basis point;
  • Canadian Association of Oilwell Drilling Contractors ("CAODC");
  • DecaNewton ("daN");
  • International Financial Reporting Standards ("IFRS");
  • Pounds ("lbs");
  • Thousand cubic feet ("mcf");
  • West Texas Intermediate ("WTI"); and
  • Western Canadian Sedimentary Basin ("WCSB").


Forward-Looking Statements and Information

This press release contains certain statements or disclosures relating to Western that are based on the expectations of Western as well as assumptions made by and information currently available to Western which may constitute forward-looking information under applicable securities laws.  All such statements and disclosures, other than those of historical fact, which address activities, events, outcomes, results or developments that Western anticipates or expects may, or will occur in the future (in whole or part) should be considered forward-looking information.  In some cases forward-looking information can be identified by terms such as "forecast", "future", "may", "will", "expect", "anticipate", "believe", "potential", "enable", "plan", "continue", or other comparable terminology.

In particular, forward-looking information in this press release includes, but is not limited to, statements relating to commodity pricing; the future demand for and utilization of the Company's services and equipment; the pricing for the Company's services and equipment; the terms of existing and future drilling contracts in Canada and the US and the revenue resulting therefrom (including the number of Operating Days typically generated from the Company's contracts); the Company's expansion and maintenance capital plans for 2017; the Company's liquidity needs including the ability of current capital resources to cover Western's financial obligations and the 2017 capital budget; the expected use of proceeds of the Second Lien Facility, Private Placement and the Bought Deal; the Company's expected sources of funding to support such capital plans and the Company's ability to adjust capital spending for the remainder of 2017 if market conditions, including customer demand changes; the expected benefits from cost control measures; the use and availability of the Company's Credit Facilities; pricing for Western's services and impact on Adjusted EBITDA; the Company's ability to maintain certain covenants under its Credit Facilities; the future declaration of dividends; expectations as to the increase in crude oil transportation capacity through pipeline development; the potential impact of changes to environmental laws and regulations and the implementation of a carbon tax in Alberta ; the expectation of continued foreign investment into the Canadian crude oil and natural gas industry; expectations relating to producer spending, and the Company's ability to find and maintain enough field crew members and the Company's change to its depreciation assumptions.

The material assumptions in making the forward-looking statements in this press release include, but are not limited to, assumptions relating to, demand levels and pricing for oilfield services; fluctuations in the price and demand for crude oil and natural gas; the continued low levels of and pressures on commodity pricing; the continued business relationship between the Company and its significant customers; general economic and financial market conditions; crude oil transport and pipeline approval and development; the Company's ability to finance its operations; 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; the ability of the Company's various business segments to access equipment (including spare parts and new technologies); changes in laws or regulations; currency exchange fluctuations; the ability of the Company to attract and retain skilled labour and qualified management; the ability to retain and attract significant customers; and other unforeseen conditions which could impact the use of services supplied by Western including Western's ability to respond to such conditions.

Although Western believes that the expectations and assumptions on which such forward-looking statements and information are based on are reasonable, undue reliance should not be placed on the forward-looking statements and information as Western cannot give any assurance that they will prove to be correct.  Since forward-looking statements and information 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 risk that the demand for oilfield services will not continue to improve for the remainder of 2017 and that commodity prices will remain low, and other general industry, economic, market and business conditions.  Readers are cautioned that the foregoing list of risks, uncertainties and assumptions are not exhaustive.  Additional information on these and other risk factors that could affect Western's operations and financial results are included in Western's annual information form which may be accessed through the SEDAR website at www.sedar.com.  The forward-looking statements and information contained in this press 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.

SOURCE Western Energy Services Corp.


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