Western Energy Services Corp. Releases Second Quarter 2016 Financial and Operating Results

CALGARY, ALBERTA--(Marketwired - July 26, 2016) - Western Energy Services Corp. ("Western" or the "Company") (TSX:WRG) announces the release of its second quarter 2016 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 six months ended June 30, 2016 and 2015 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.

Second Quarter 2016 Operating Results:

• Second quarter Operating Revenue decreased by $18.3 million (or 60%) to $12.4 million in 2016 as compared to $30.7 million in 2015. In the contract drilling segment, Operating Revenue totaled $7.4 million in the second quarter of 2016 as compared to $16.7 million in the second quarter of 2015; while in the production services segment, Operating Revenue totaled $5.0 million for the three months ended June 30, 2016 as compared to $14.0 million in the same period of the prior year. While West Texas Intermediate ("WTI") prices recovered somewhat in the second quarter of 2016, Operating Revenue was impacted by decreased commodity prices, as both crude oil and natural gas prices were still significantly lower year over year. Activity levels remained at 30 year lows with utilization experiencing no meaningful post spring breakup recovery until subsequent to the end of the second quarter of 2016. Operating Revenue in the contract drilling and production services segments were impacted by lower utilization and pricing as described below:
  • Drilling rig utilization - Operating Days (or "Drilling Rig Utilization") in Canada was 3% in the second quarter of 2016 compared to 10% in the second quarter of 2015, reflecting a 70% decrease. Second quarter 2016 Drilling Rig Utilization represented a discount of 400 basis points ("bps") to the Canadian Association of Oilwell Drilling Contractors ("CAODC") industry average of 7%, as compared to the 300 bps discount to the industry average realized in the second quarter of 2015. The CAODC industry average utilization for the three months ended June 30, 2016 was the lowest quarterly industry utilization on record. The Company's discount relative to the CAODC average is partially due to a number of Western's customers, who typically have substantial drilling programs, significantly cutting their capital spending in 2016. Additionally, lower activity and increased competition in the second quarter of 2016 resulted in downward pricing pressure on all drilling rig classes, which reduced Operating Revenue per Revenue Day in the contract drilling segment in Canada by 20%, as compared to the second quarter of 2015;
  • In the United States, the Company had one drilling rig working on a long term contract throughout the quarter, resulting in Drilling Rig Utilization of 18% in the second quarter of 2016, as compared to 31% in the same period of the prior year, while Operating Revenue per Revenue Day in the United States decreased by 12% in the second quarter of 2016 due to renegotiating the day rate and extending the term on the contract; and 
  • Well servicing utilization of 11% in the second quarter of 2016 compared to 26% in the same period of the prior year. Reduced activity, coupled with a 26% decrease in well servicing hourly rates, due to pricing pressure in all areas, resulted in an $8.6 million (or 69%) decrease in well servicing Operating Revenue in the period.
• Second quarter Adjusted EBITDA decreased by $6.3 million to a loss of $2.0 million in 2016 as compared to $4.3 million in the second quarter of 2015. The year over year change in Adjusted EBITDA is due to lower utilization and pricing in both the contract drilling and production services segments, offset partially by cost reduction measures, including an approximate one third reduction to salaried headcount year over year, wage reductions to all employees and other cost control measures.
• Administrative expenses, excluding depreciation and stock based compensation, in the second quarter of 2016 decreased by $1.4 million (or 23%) to $4.7 million as compared to $6.1 million in the second quarter of 2015. The decrease in administrative expenses is due to a reduced employee headcount, a 10% rollback to all salaried employee wages and directors' fees implemented in the first quarter of 2016, as well as additional cost control measures.
• As a result of the Company's review of estimated useful lives and methodology for depreciating its drilling and well service rig fleet and related equipment, effective April 1, 2016, Western changed the method for depreciating its drilling and well service rigs and related equipment from unit of production to straight line and changed certain estimates related to useful lives and salvage values. The change in depreciation methodology reflects the technological developments within the industry. The Company expects that straight line depreciation will better reflect the future economic benefit related to these assets, which are expected to depreciate over time instead of on a unit of production basis. Additionally, the change will result in idle or underutilized assets being depreciated more quickly in periods of low activity, better reflecting the cyclical nature of the oilfield service industry. These adjustments were applied prospectively and resulted in an increase of approximately $12.7 million of additional depreciation expense for the three months ended June 30, 2016, over what would have been expensed had the previous assumptions using the unit of production methodology continued to be used in the period. The estimated additional depreciation expense for the year ending December 31, 2016 from this change is approximately $24.7 million.

• During the second quarter of 2016, the Company decommissioned one of its Cardium class drilling rigs, resulting in a loss on asset decommissioning of $5.2 million, and as a result at June 30, 2016 Horizon had a fleet of 51 drilling rigs.
• The Company incurred a net loss of $24.2 million in the second quarter of 2016 (a loss of $0.33 per basic common share) as compared to a net loss of $12.6 million in the same period in 2015 (a loss of $0.17 per basic common share). The decrease in net income in 2016 can be attributed to the following:
  • A $6.3 million decrease in Adjusted EBITDA due to lower utilization and pricing in both the contract drilling and production services segments;
  • An increase of $10.4 million in depreciation expense due to the Company changing from unit of production to straight line depreciation;
  • Losses on asset decommissioning of $5.2 million in the contract drilling segment; and
  • A $1.0 million increase in finance costs, due to lower capitalized interest as a result of the completion of the 2014 rig build program in the prior period.

Offsetting the above mentioned items was a $12.8 million decrease in income tax expense due to lower taxable income in the second quarter of 2016, along with the impact of the Alberta corporate tax rate increase in 2015, which increased income tax expense in the prior period by approximately $6.0 million.

• Second quarter 2016 capital expenditures of $0.4 million included $0.2 million of expansion capital and $0.2 million of maintenance capital. In total, capital spending in the second quarter of 2016 decreased by 94% from the $7.7 million incurred in the second quarter of 2015, as the Company is only incurring necessary maintenance capital during the current slowdown in oilfield service activity.
• On April 27, 2016, the Company amended the covenants and elected to reduce its syndicated revolving credit facility (the "Revolving Facility") from $175.0 million to $40.0 million and reduced its previously uncommitted operating demand revolving loan of $20.0 million to a committed operating line (the "Operating Facility") totaling $10.0 million. Western's decision to reduce its Revolving Facility and Operating Facility (the "Credit Facilities") is estimated to save the Company $1.5 million in standby fees annually.
• Subsequent to June 30, 2016, the Company added a lender to its syndicated Revolving Facility and increased the amount available by $10.0 million to $50.0 million, from $40.0 million previously. The increased Revolving Facility reinstates an interest coverage ratio when $30.0 million or more is drawn on the Company's Credit Facilities. The interest coverage ratio has been waived during the covenant relief period, which ends after December 31, 2017. Subsequent to the covenant relief period, the interest coverage ratio must exceed 1.0 and 1.25 in the first and second quarters of 2018 respectively, and 1.5 thereafter. Additionally, the Consolidated Senior Debt to Consolidated EBITDA ratio has been reduced during the covenant relief period to 3.0 to 1.0 under the increased Revolving Facility from 4.0 to 1.0 previously.

Year to Date Operating Results

• Operating Revenue for the six month period ended June 30, 2016 decreased by $87.1 million (or 66%) to $44.6 million in 2016, as compared to $131.7 million in the same period of the prior year. In the contract drilling segment, Operating Revenue totaled $29.7 million for the six month period ended June 30, 2016 compared to $92.4 million in the same period of the prior year; while in the production services segment, Operating Revenue totaled $14.9 million compared to $39.6 million in the same period of the prior year. Operating Revenue in the contract drilling and production services segments for the six month period ended June 30, 2016 were impacted by lower utilization and pricing as described below:
  • Drilling Rig Utilization in Canada of 11% for the six month period ended June 30, 2016, compared to 30% for the six month period ended June 30, 2015, reflects a 63% decrease. Drilling Rig Utilization on a year to date basis in 2016 represented a discount of 300 bps to the CAODC industry average of 14%, as compared to the 600 bps premium to the CAODC industry average realized in the first six months of 2015. The change in the Company's utilization relative to the CAODC industry average, as mentioned for the second quarter of 2016, is partially due to a number of Western's customers who typically have substantial drilling programs, significantly cutting their capital spending in 2016. Additionally, changes in the industry rig mix, as competitors continue to decommission older and less competitive rigs in the Western Canadian Sedimentary Basin ("WCSB"), and add rigs that directly compete with Western's drilling rig fleet, impacts Western's relative utilization as compared to the CAODC industry average. Lower activity and increased competition in the first six months of 2016 resulted in downward pricing pressure on all drilling rig classes, which reduced Operating Revenue per Revenue Day in the contract drilling segment in Canada by 24%, as compared to the first six months of 2015;
  • In the United States, the Company had one drilling rig working on a long term contract throughout the period, resulting in Drilling Rig Utilization of 18% for the six months ended June 30, 2016, as compared to 39% in the same period of the prior year, while Operating Revenue per Revenue Day in the United States decreased by 11% in the first six months of 2016 due to renegotiating the day rate and extending the term on the contract; and 
  • Well servicing utilization of 14% for the six months ended June 30, 2016 compared to 34% in the same period of the prior year. Reduced activity as well as an 18% reduction in well servicing hourly rates, due to pricing pressure in all areas, resulted in a $22.1 million (or 66%) decrease in well servicing Operating Revenue in the period.
• Adjusted EBITDA for the six months ended June 30, 2016 decreased by $43.5 million to $1.4 million, as compared to $44.9 million for the six months ended June 30, 2015. The year over year decrease in Adjusted EBITDA is due to lower utilization and pricing in both the contract drilling and production services segments, offset by cost reduction measures, including an approximate one third reduction to salaried headcount, wage reductions to all employees and other cost control measures.
• Year to date administrative expenses, excluding depreciation and stock based compensation, for the six month period ended June 30, 2016 decreased by $3.2 million (or 24%) to $10.2 million as compared to $13.4 million in the same period of the prior year. The decrease in administrative expenses is due to a reduced employee headcount, a 10% rollback to all salaried employee wages and directors' fees implemented in the first quarter of 2016, coupled with additional cost control measures.
• The Company incurred a net loss of $30.5 million for the six months ended June 30, 2016 (a loss of $0.41 per basic common share) as compared to net income of $2.7 million for the same period in 2015 ($0.04 per basic common share). The reduction in net income in 2016 can be attributed to the following:
  • A $43.5 million decrease in Adjusted EBITDA due to lower utilization and pricing in both the contract drilling and production services segments;
  • An increase of $4.3 million in depreciation expense due to the Company changing from unit of production to straight line depreciation in the second quarter of 2016; and
  • A $1.8 million increase in finance costs, due to lower capitalized interest as a result of the completion of the 2014 rig build program in the prior period.

Offsetting the above mentioned items was a $21.7 million decrease in income tax expense due to lower taxable income for the six months ended June 30, 2016, along with the impact of the Alberta corporate tax rate increase in 2015, which increased income tax expense in the prior period by approximately $6.0 million.

• Year to date capital expenditures of $1.3 million included $0.6 million of expansion capital and $0.7 million of maintenance capital. In total, capital spending for the six months ended June 30, 2016 decreased by 95% from the $25.6 million incurred in the same period of 2015, as the Company minimized its capital expenditures to preserve cash balances during the current slowdown in oilfield service activity.

Selected Financial Information
(stated in thousands, except share and per share amounts)
		Three months ended June 30								Six months ended June 30
Financial Highlights		2016		2015		Change		2016		2015		Change
Revenue		12,890		32,037		(60	%)	46,827		137,887		(66	%)
Operating Revenue(1)		12,393		30,719		(60	%)	44,593		131,677		(66	%)
Gross Margin(1)		2,703		10,403		(74	%)	11,570		58,294		(80	%)
Gross Margin as a percentage of Operating Revenue		22	%	34	%	(35	%)	26	%	44	%	(41	%)
Adjusted EBITDA(1)		(1,990	)	4,255		(147	%)	1,374		44,892		(97	%)
Adjusted EBITDA as a percentage of Operating Revenue		(16	%)	14	%	(214	%)	3	%	34	%	(91	%)
Cash flow from operating activities		8,444		41,009		(79	%)	17,049		80,346		(79	%)
Capital expenditures		423		7,688		(94	%)	1,344		25,551		(95	%)
Net income (loss)		(24,172	)	(12,607	)	92	%	(30,491	)	2,687		(1,235	%)
	-basic net income (loss) per share	(0.33	)	(0.17	)	94	%	(0.41	)	0.04		(1,125	%)
	-diluted net income (loss) per share	(0.33	)	(0.17	)	94	%	(0.41	)	0.04		(1,125	%)
Weighted average number of shares
	-basic	73,648,192		74,579,889		(1	%)	73,647,241		74,633,065		(1	%)
	-diluted	73,648,192		74,579,889		(1	%)	73,647,241		74,652,435		(1	%)
Outstanding common shares as at period end		73,648,484		74,435,928		(1	%)	73,648,484		74,435,928		(1	%)
Dividends declared		-		5,591		(100	%)	-		11,184		(100	%)
(1) See "Non-IFRS measures" included in this press release.

 

		Three months ended June 30						Six months ended June 30
Operating Highlights		2016		2015		Change		2016		2015		Change
Contract Drilling
Canadian Operations:
Contract drilling rig fleet:
	-Average	52		49		6	%	52		49		6	%
	-End of period	51		49		4	%	51		49		4	%
Operating Revenue per Revenue Day(1)		16,441(3)		20,589		(20	%)	19,001(3)		25,015		(24	%)
Operating Revenue per Operating Day(1)		17,369(3)		22,285		(22	%)	21,260(3)		27,570		(23	%)
Operating Days(1)		157		464		(66	%)	1,018		2,617		(61	%)
Drilling rig utilization - Revenue Days(1)		4	%	11	%	(64	%)	12	%	33	%	(64	%)
Drilling rig utilization - Operating Days(1)		3	%	10	%	(70	%)	11	%	30	%	(63	%)
CAODC industry average utilization(1)(2)		7	%	13	%	(46	%)	14	%	24	%	(42	%)
United States Operations:
Contract drilling rig fleet:
	-Average	5		5		-		5		5		-
	-End of period	5		5		-		5		5		-
Operating Revenue per Revenue Day (US$)(1)		24,568		27,766(4)		(12	%)	25,832		28,888(4)		(11	%)
Operating Revenue per Operating Day (US$)(1)		27,092		32,181(4)		(16	%)	29,240		33,118(4)		(12	%)
Operating Days(1)		83		142		(42	%)	161		356		(55	%)
Drilling rig utilization - Revenue Days(1)		20	%	36	%	(44	%)	20	%	45	%	(56	%)
Drilling rig utilization - Operating Days(1)		18	%	31	%	(42	%)	18	%	39	%	(54	%)
Production Services
Well servicing rig fleet:
	-Average	66		66		-		66		66		-
	-End of period	66		66		-		66		66		-
Service Rig Operating Revenue per Service Hour(1)		589		794		(26	%)	682		833		(18	%)
Service Hours(1)		6,402		15,596		(59	%)	16,788		40,308		(58	%)
Service rig utilization(1)		11	%	26	%	(58	%)	14	%	34	%	(59	%)
(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 $1.8 million for the three and six months ended June 30, 2016.
(4) Excludes shortfall commitment and standby revenue from take or pay contracts of US$0.7 million and US$4.5 million for the three and six months ended June 30, 2015 respectively.

Financial Position at (stated in thousands)	June 30, 2016	June 30, 2015	Dec 31, 2015
Working capital	60,278	79,618	70,679
Property and equipment	735,765	840,231	773,647
Total assets	814,757	1,025,776	876,608
Long term debt	264,145	264,234	264,155

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"). On December 28, 2015, Western wound up its partnership, Western Energy Services Partnership (the "Partnership") and rolled all of the Partnership's assets into IROC Drilling and Production Services Corp., which then changed its name to Western Production Services Corp. ("Western Production Services"). As a result, Western now provides well servicing operations in Canada through Western Production Services' division, Eagle Well Servicing ("Eagle") and oilfield rental equipment services in Canada through Western Production Services' division, Aero Rental Services ("Aero"). Financial and operating results for Horizon and Stoneham are included in Western's contract drilling segment, while Eagle and Aero's financial and operating results are included in Western's production services segment. 

Western currently has a drilling rig fleet of 56 rigs specifically suited for drilling horizontal wells of increased complexity. Western is the sixth largest drilling contractor in Canada with a fleet of 51 rigs operating through Horizon. Of the Canadian fleet, 24 are classified as Cardium rigs, 19 as Montney rigs and eight as Duvernay rigs. As compared to the Cardium classified rigs, the Montney class rigs have a larger hookload, while the Duvernay class rigs have the largest hookload. Additionally, Western has five Duvernay class triple drilling rigs deployed in the United States operating through Stoneham. Western is also the fourth 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 frac 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. Overall performance of the Company for the three and six months ended June 30, 2016 was affected by the continued low crude oil and natural gas prices. While WTI on average increased by 36% in the second quarter of 2016, as compared to the first quarter of 2016 when prices were at their lowest levels in over a decade, WTI was still 21% and 25% lower for the three and six months ending June 30, 2016 respectively, as compared to the same periods 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 six months ended June 30, 2016 and 2015.

	Three months ended June 30				Six months ended June 30
	2016	2015	Change		2016	2015	Change
Average crude oil and natural gas prices(1)
Crude Oil
West Texas Intermediate (US$/bbl)	45.53	57.87	(21	%)	39.69	53.22	(25	%)
Western Canadian Select (CDN$/bbl)	42.31	56.76	(25	%)	34.49	49.96	(31	%)
Natural Gas
30 day Spot AECO (CDN$/mcf)	1.40	2.68	(48	%)	1.61	2.71	(41	%)
Average foreign exchange rates
US dollar to Canadian dollar	1.29	1.23	5	%	1.33	1.24	7	%
(1) See "Abbreviations" included in this press release.

The significant reduction in commodity prices has led to a corresponding decrease in the demand for oilfield services in both Canada and the United States. As a result, second quarter drilling rig counts in both Canada and the United States were at or near 30 year lows in 2016. The CAODC reported that for drilling in Canada, the total number of Operating Days in the WCSB decreased approximately 47% and 46% respectively, for the three and six months ended June 30, 2016, as compared to the three and six months ended June 30, 2015. Similarly, as reported by Baker Hughes Incorporated, the number of active drilling rigs in the United States decreased approximately 54% and 57% for the three and six months ended June 30, 2016 respectively, as compared to the same periods in the prior year.

Outlook

Currently, 16 of Western's drilling rigs are operating and five of Western's 56 drilling rigs (or 9%) are under long term take or pay contracts providing a base level of future revenue, with one of these contracts expected to expire in 2016, three expected to expire in 2017, and one expected to expire in 2018. These contracts each typically generate between 250 and 350 Revenue Days per year.

Western's capital budget for 2016 of $7 million remains unchanged, and is comprised of $2 million of expansion capital and $5 million of maintenance capital. Western believes the 2016 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. 

Commodity prices, while remaining well below previous highs, have improved significantly since hitting 10 year lows in the first quarter of 2016. As such, North American drilling rig counts appear to have bottomed out and the Company is expecting improved year over year activity levels in the second half of 2016. However, the Company expects pricing pressure will continue to be challenging as activity levels begin to recover. As at June 30, 2016, the Company had seven drilling rigs operating; since that time, activity has improved and at July 26, 2016, the Company has 16 drilling rigs operating, with a full complement of experienced crews. Lower than normal activity levels and pricing pressure will continue to impact Western's Adjusted EBITDA and cash flow from operating activities if low commodity prices persist. As discussed, the Company has taken a proactive approach to reducing administrative and fixed overhead costs including reducing fixed headcount since the beginning of 2015 by a third and implementing a 10% company wide wage rollback to salaried employees and directors' fees in the first quarter of 2016, as well as reducing various other office related costs. In addition, Western's variable cost structure, under which approximately 80% of operating and administrative costs are variable, the previously announced suspension of the Company's quarterly dividend and a prudent capital budget will aid in preserving balance sheet strength. In addition to $57 million in cash and cash equivalents at June 30, 2016, Western has $60 million undrawn on the Company's Credit Facilities, which do not mature until December 17, 2018 and no principal repayments due on the $265 million Senior Notes until they mature on January 30, 2019. 

Oilfield service activity in Canada will be impacted by the development of resource plays in Alberta and northeast British Columbia including those related to liquefied natural gas projects, increased crude oil transportation capacity through rail and pipeline development and foreign investment into Canada. Currently, the largest challenge facing the oilfield service industry is customer spending constraints as a result of lower commodity prices. 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.

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, 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 June 30				Six months ended June 30
(stated in thousands)		2016		2015		2016		2015
Operating Revenue
	Drilling	7,388		16,746		29,712		92,353
	Production Services	5,008		14,004		14,894		39,577
	Less: inter-company eliminations	(3	)	(31	)	(13	)	(253	)
		12,393		30,719		44,593		131,677
Third party charges		497		1,318		2,234		6,210
Revenue		12,890		32,037		46,827		137,887
Less: operating expenses		(27,814	)	(28,710	)	(60,303	)	(100,185	)
Add:
	Depreciation - operating	17,329		6,884		24,640		20,249
	Stock based compensation - operating	298		192		406		343
Gross Margin		2,703		10,403		11,570		58,294

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 income 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 Earnings (Loss):

		Three months ended June 30				Six months ended June 30
(stated in thousands)		2016		2015		2016		2015
Net income (loss)		(24,172	)	(12,607	)	(30,491	)	2,687
Add:
	Finance costs	5,798		4,763		11,336		9,521
	Income tax (recovery) expense	(8,234	)	4,550		(10,729	)	10,972
	Depreciation - operating	17,329		6,884		24,640		20,249
	Depreciation - administrative	406		485		826		914
EBITDA		(8,873	)	4,075		(4,418	)	44,343
Add:
	Stock based compensation - operating	298		192		406		343
	Stock based compensation - administrative	962		807		1,893		1,619
	Loss on asset decommissioning	5,225		-		5,225		-
	Other items	398		(819	)	(1,732	)	(1,413	)
Adjusted EBITDA		(1,990	)	4,255		1,374		44,892
Subtract:
	Depreciation - operating	(17,329	)	(6,884	)	(24,640	)	(20,249	)
	Depreciation - administrative	(406	)	(485	)	(826	)	(914	)
Operating Earnings (Loss)		(19,725	)	(3,114	)	(24,092	)	23,729

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)	June 30, 2016		December 31, 2015
Long term debt	264,145		264,155
Current portion of long term debt	647		761
Less: cash and cash equivalents	(57,397	)	(58,445	)
Net Debt	207,395		206,471

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

Drilling rig utilization - Revenue Days: Calculated based on Revenue Days divided by total available days.

Operating Days: Defined as contract drilling days, calculated on a spud to rig release basis.

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

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, 366 days per year in 2016 (2015: 365 days).

Contract Drilling Rig Classifications

Cardium class rig: Defined as any contract drilling rig which has a total hookload of 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");
• Western Canadian Sedimentary Basin ("WCSB"); and
• Western Canadian Select ("WCS").

2016 Second Quarter Results Conference Call and Webcast

Western has scheduled a conference call and webcast to begin at 10:00 a.m. MDT (12:00 p.m. EDT) on Wednesday, July 27, 2016.

The conference call dial-in number is 1-866-223-7781.

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 one hour after the completion of the call until August 10, 2016 by dialing 1-800-408-3053 or 905-694-9451, passcode 5894344.

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", "contemplate", "pro forma", or other comparable terminology.

In particular, forward-looking information in this press release includes, but is not limited to, statements relating to future declaration of dividends; commodity pricing; the future demand for and utilization of 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 2016; the Company's liquidity needs including the ability of current capital resources to cover Western's financial obligations and the 2016 capital budget; 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 2016 if market conditions, including customer demand, continue to change; the expected benefits from cost control measures; the use and availability of the Company's Credit Facilities; the Company's ability to maintain certain covenants under its Credit Facility; expectations as to the increase in crude oil transportation capacity through rail and pipeline development; expectations as to the necessary approvals for liquefied natural gas projects being obtained; the expectation of continued foreign investment into the Canadian crude oil and natural gas industry; and the expectation that producer spending constraints will continue to be a large challenge facing the Company in 2016.

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; the development of liquefied natural gas projects, 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 improve for the remainder of 2016 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.