News Releases

CALGARY, ALBERTA - Nov. 4, 2015 /CNW/ - Newalta Corporation ("Newalta") (TSX:NAL) today reported results for the three and nine months ended September 30, 2015, and, in response to fundamental changes in the oil and gas industry, also reported the recent completion of a third phase of cost rationalization and a reduction in Newalta's common share dividend effective with the payment in January, 2016.

FINANCIAL HIGHLIGHTS(1)

			Three months ended September 30,						Nine months ended September 30,
($000s except per share data)  (unaudited)			2015		2014		% Change(2)		2015		2014		% Change(2)
Continuing Operations(3)
Revenue			83,502		135,398		(38)		262,919		362,203		(27)
Divisional EBITDA(4)			30,017		59,779		(50)		83,244		146,752		(43)
	% of Revenue		36%		44%		(18)		32%		41%		(22)
Net (loss) earnings from Continuing Operations(5)			(12,690)		10,596		n/m		(49,330)		5,505		n/m
	- per share ($) basic		(0.23)		0.19		n/m		(0.88)		0.10		n/m
	- per share ($) diluted		(0.23)		0.19		n/m		(0.88)		0.10		n/m
Adjusted net (loss) earnings(5)			(189)		16,760		(101)		(9,364)		28,212		(133)
	- per share ($) basic adjusted(5)		-		0.30		(100)		(0.17)		0.51		(133)
Adjusted EBITDA(5)			20,067		43,284		(54)		48,439		98,738		(51)
	- per share(5)		0.36		0.77		(53)		0.86		1.77		(51)
Cash from Continuing Operations			36,810		10,843		n/m		29,979		52,960		(43)
	- per share ($)		0.65		0.19		n/m		0.53		0.95		(44)
Funds from operations(5)			16,556		41,115		(60)		22,616		75,822		(70)
	- per share ($)(5)		0.29		0.74		(61)		0.40		1.36		(71)
Maintenance capital expenditures(5)			3,879		6,381		(39)		10,343		15,824		(35)
Growth capital expenditures(5)			9,818		35,378		(72)		57,770		76,728		(25)
Dividends declared			7,030		6,990		1		21,084		20,097		5
	- per share ($)(5)		0.125		0.125		-		0.375		0.360		4
Dividends paid			7,030		5,567		26		19,780		15,006		32
Weighted average Shares outstanding			56,237		55,901		1		56,216		55,734		1
Shares outstanding, September 30,(6)			56,237		55,923		1		56,237		55,923		1
Combined Operations(3)
Revenue			83,502		228,431		(63)		305,027		629,325		(52)
Net (loss) earnings			(15,662)		16,570		(195)		(56,692)		14,890		n/m
	- per share ($) basic		(0.28)		0.30		(193)		(1.01)		0.27		n/m
	- per share ($) diluted		(0.28)		0.29		(197)		(1.01)		0.26		n/m
Cash from Operating Activities			32,758		27,649		18		4,486		64,507		(93)
	- per share ($) basic		0.58		0.49		18		0.08		1.16		(93)
(1) Newalta's unaudited Condensed Consolidated Financial Statements are attached. References to Generally Accepted Accounting Principles (GAAP) are synonymous with IFRS and references to unaudited Condensed Consolidated Financial Statements and notes are synonymous with Financial Statements. All financial figures are unaudited.
(2) n/m Indicates the percentage change is not meaningful.
(3) In Q1 2015, we completed the sale of our Industrial Division to Revolution. As a result, we have defined our Industrial Division as "Discontinued Operations", the remaining operations as "Continuing Operations" and the total Discontinued Operations and Continuing Operations as "Combined Operations". In accordance with the requirements of IFRS 5 Non-current Assets Held for Sale and Discontinued Operations, income and expenses and cash flow provided and used associated with the business to be sold have been classified as Discontinued Operations in our Financial Statements for the periods presented.
(4) As a result of the change in our financial statement presentation from functional to nature based, we have reclassified the sales expense directly attributable to the divisions from Corporate and Other to the respective division. Prior period comparative figures have been amended to conform to current period's presentation. Please refer to "Reporting Structure" for the restated the historical segmented information and key metrics.
(5)These financial measures do not have any standardized meaning prescribed by GAAP and are therefore unlikely to be comparable to similar measures presented by other issuers. Non-GAAP financial measures are identified and defined.
(6) Newalta has 56,236,548 Shares outstanding as at November 4, 2015.

MANAGEMENT COMMENTARY

"Third quarter revenue and Adjusted EBITDA were 38% and 54% lower than a year ago, in line with previous guidance, adjusted for the sub US$40 WTI oil prices in the quarter," said John Barkhouse, President and CEO. "While we offset some of this impact with significant cost reductions and the ongoing cash flows provided by our contract model, it's clear that new industry realities have set in. Accordingly, we triggered a third phase of our cost rationalization program which will drive an incremental $5 million in annualized savings. Lower overhead combined with growth initiatives will help to sustain our business but in this environment, additional action is warranted. Accordingly, the Board approved a 50% reduction to our quarterly dividend effective for the dividend payable to shareholders of record as of December 31, 2015. This reduction will preserve cash flow and align payouts with our previously stated strategic target of 15% to 20% of forward looking cash flows. These steps protect our balance sheet and ensure Newalta retains the strength to build on its environmental energy services industry leadership."

On the strength of our balance sheet, Senior Debt to EBITDA ratio and effective working capital management, we also increased financial flexibility for the next two years by securing a waiver of the Total Debt to EBITDA covenant under our credit facility.

"This spring, oil traded at a level of approximately US$50-60 WTI, which would have allowed us to show marked improvement in the second half of 2015. Instead, oil prices dropped approximately 30% to around US$40 and dipped even lower for several days. At these levels, some producers have shut-in wells, minimized maintenance activities, deferred capital spending and taken to managing their own waste to the extent possible.

"Newalta has proactively structured its business model to meet these challenges and our initiatives to strengthen our business provide the agility and balance sheet strength to weather this sustained downturn," said Mr. Barkhouse. "While we expect to continue to benefit from these actions, our revised guidance for the final quarter of 2015 is that Adjusted EBITDA will be lower than in the third quarter of this year. Despite the low oil price environment, we will target to be Free Cash Flow neutral commencing in 2016 and positive thereafter."

Newalta continues to focus on value creation for customers and shareholders using the strategies and approach of our Vision 2020 plan. This includes targeted investments and growth initiatives such as the extension of our contract at Syncrude's full-scale facility at Mildred Lake to March 2017. Vision 2020, launched in May 2015, directs Newalta to enhance the recovery of value from oil and gas waste streams for our customers at each stage of drilling, completions, production and reclamation using a business approach called Sustainability Simplified™ and to enhance performance for our shareholders with emphasis on improving corporate scale and operating footprint geographically, growing our onsite business and contracts and leveraging our core capabilities to add differentiated services.

THIRD QUARTER RESULTS

Continuing Operations reflect the ongoing pure play environmental energy services business of Newalta and exclude the Industrial Division which was sold in the first quarter. Newalta's Continuing Operations include two divisions - Heavy Oil and Oilfield - a structure adopted in Q1 2015 to more closely align operations with customer activities, facilitate a seamless service package to customers, optimize our resource allocations, and aid in the execution of our growth strategies.

Continuing Operations

Q3 revenue and Adjusted EBITDA decreased 38% and 54%, respectively, to $83.5 million and $20.1 million compared to prior year. Performance in the third quarter of 2015 was significantly impacted by fundamental industry changes. Crude oil prices (WTI) hovered around $40 per bbl throughout August and September dipping below $40 for several days. This low price environment had significant impacts on the industry. Certain producers shut-in wells and minimized maintenance activities such as well work-overs and turn-arounds. To the extent possible, producers reduced volumes and the quality of waste available in the market. In addition, producers continued to review and defer projects and capital spending. These actions reduced production-driven volumes available for processing in the market, driving increased competition and competitive pricing actions. At our Canadian Oilfield Facilities, production-driven volumes decreased by over 40% while volumes at our Heavy Oil Facilities decreased 30%. In combination, these factors drove $17.4 million of the $23.2 million decline in Q3 Adjusted EBITDA compared to prior year. The balance was driven by both lower drilling activity and crude oil prices ($9.6 million and $5.3 million, respectively). These factors were partially offset by cost savings of approximately $9.1 million realized in the third quarter. Net loss from Continuing Operations for the quarter was $12.7 million compared to income of $10.6 million in the prior year. Lower EBITDA was partially offset by lower finance charges and stock-based compensation.

In response to the severe decline in activity levels and crude oil prices, we actioned the following steps to protect our profitability and balance sheet:

• We initiated the third phase of our cost rationalization program, which will drive an incremental $5 million in annualized savings. Actions over the three phases included the elimination of positions, office space consolidation and the suspension of the company-matching payments in our employee savings plans. In combination, we have realized $9.1 million and $19.4 million in savings in the quarter and year-to-date, respectively. We expect to realize approximately $30 million in cost savings in 2015 and in excess of $35 million on an annualized basis.
• We secured a waiver of our Total Debt to EBITDA covenant under our Credit Facility, in effect to June 2017. The waiver was granted based on the strength of our balance sheet, our effective working capital management and our strong Senior Debt to EBITDA ratio. The waiver provides us with increased financial flexibility in this low oil price and activity environment.
• We recommended and the Board approved a 50% reduction to our quarterly dividend effective for the dividend payable to shareholders of record as of December 31, 2015. This reduction will preserve cash flow and align our payouts with our previously stated strategic target of 15% to 20% of forward looking cash flows.

Our contract model has performed well during this downturn, continuing to provide steady, predictable cash flow. These contracts generally are not tied directly to commodity price changes or drilling activity and provide a solid foundation for our business, particularly in depressed markets. On a trailing-twelve month basis, contracts represented 29% of our revenue.

Year-to-date Adjusted EBITDA was $48.4 million, down 51% over prior year, reflecting the same factors as the quarter, with the decline in drilling activity having a greater impact. Year-to-date, Net loss from Continuing Operations was $49.3 million compared to $5.5 million net income in the prior year, reflecting the same factors as the quarter and higher restructuring and other related costs and impairment.

Q3 2015 and year-to-date G&A decreased 40% and 28% to $10.0 million and $34.8 million, respectively. The improvement reflects the cost rationalization initiatives commenced in Q1 2015. During the quarter, we incurred $2.7 million in restructuring and other related costs, comprised primarily of severance and related costs. Year-to-date restructuring and other related costs were $28.1 million, comprised almost equally of severance and related costs and non-cash onerous lease costs. Of the year-to-date employee termination and other costs, 70% were in corporate overhead with the balance in operations ($1.6 million, in Heavy Oil and $3.0 million in Oilfield).

Divisional Results

Heavy Oil revenue and Divisional EBITDA in the quarter decreased by 28% and 34%, respectively, to $40.3 million and $18.4 million compared to prior year. Contributions from both Heavy Oil Facilities and Onsite were weighed down by reduced activity in the heavy oil sector and lower crude oil prices. Year-to-date, revenue and Divisional EBITDA decreased by 21% and 34%, respectively, to $115.4 million and $44.5 million compared to prior year. The decrease was driven by lower contributions from Heavy Oil Facilities. Onsite contributions were relatively flat, supported by our mature fine tailings (MFT) contracts.

Year-to-date, Heavy Oil made progress with several growth initiatives:

• Completed construction of the second MFT plant at Shell Canada Limited's (Shell) Jackpine Mine and began MFT processing in the first quarter.
• Signed an extension on the original Syncrude MFT contract to operate in the second half of 2015.
• Signed an extension on the contract at Syncrude's full-scale facility at Mildred Lake in the third quarter.
• Completed construction and commissioning of the Fort McMurray full-service facility to serve the oil sands in Q2.
• Completed commissioning and began operations late in the third quarter at our new modular processing facility (MPF) near Silver Lake, Saskatchewan.

Oilfield revenue and Divisional EBITDA in the quarter decreased 45% and 64%, respectively, to $43.2 million and $11.6 million. Performance was driven by lower contributions from both Oilfield Facilities and Drilling Services due primarily to reduced production and drilling activity and lower crude oil prices. Year-to-date Oilfield revenue and Divisional EBITDA decreased 32% and 51%, respectively, to $147.5 million and $38.8 million compared to prior year. Results were impacted by the same factors as the quarter with drilling activity and crude oil prices having a more significant impact on year-to-date results.

Year-to-date, Oilfield made progress with several growth initiatives:

• Entered into a joint venture agreement with a midstream provider in Q2 for one commissioned MPF, which is anticipated to be expanded to include a full-service offering to customers.
• Completed commissioning of the Alexander, North Dakota MPF in the Bakken early in Q1.
• Completed construction and commissioning at two new MPFs at Fox Creek and Gold Creek, Alberta in Q1.
• Completed construction of our Gold Creek Landfill and commenced operations mid October 2015. The landfill is strategically located near our Gold Creek MPF to improve operational efficiencies and provide a seamless service for our customers.

Capital expenditures for the three and nine months ended September 30, 2015 were $13.7 million and $68.1 million. Throughout 2015, we have focused our capital deployment on strategic markets. In Heavy Oil, growth capital was allocated to our new Fort McMurray facility to serve the oil sands and the Silver Lake MPF to serve the conventional heavy oil market. In Oilfield, our resources have been focused on expanding our footprint in the Montenay/Duvernay and Deep Basin plays in Canada through our new locations at Fox Creek and Gold Creek, AB and in the U.S. at our MPF in Bakken.

At September 30, 2015, Total Debt was $333.4 million, reduced by $138.8 million from December 31, 2014. Senior Secured Debt to EBITDA at September 30, 2015 was 0.76.

Discontinued Operations

Q3 2015 Discontinued Operations net loss before loss on sale was $0.4 million compared to net earnings of $6.0 million in prior year. Q3 2015 results reflect customary purchase price adjustments. Year-to-date, net loss before loss on sale was $7.7 million compared to net earnings of $9.4 million in prior year. The decrease in performance was driven by the timing of the sale in February.

Credit Facility Waiver

During Q3, we amended the Credit Facility to include a waiver of the Total Debt to EBITDA financial covenant and a reduction in the Interest Coverage Ratio covenant from 2.25x to 2.00x minimum, with each of these covenant amendments to take effect at the end of Q3 through to June 30, 2017. These amendments were granted based on the strength of our balance sheet and strong Senior Secured Debt to EBITDA ratio and provide us with increased financial flexibility in this period of uncertain market conditions.

Dividends

In determining the dividend to be paid to our shareholders, the Board of Directors considers a number of factors, including: the forecasts for operating and financial results, maintenance and growth capital requirements, as well as market activity and conditions. After review of all factors, the Board declared $7.0 million in dividends or $0.125 per share, paid October 15, 2015, to shareholders on record as at September 30, 2015.

The Board reviews dividends on a quarterly basis. In light of the current market environment and outlook, the Board approved a 50% reduction in the quarterly cash dividend to $0.0625 ($0.25 per share annualized) from the current rate of $0.50 annualized, effective for the dividend payable to shareholders of record as of December 31, 2015.

The following section contains forward-looking information as it outlines our Outlook for 2015. Our Outlook is based on several key assumptions including growth capital contributions, commodity prices and activity levels of the industries we serve. Changes to these assumptions could cause our actual results to differ materially.

OUTLOOK

Our performance in 2015 has been significantly impacted by the sharp drop in oil prices and activity levels in the oil and gas industry. The magnitude of this downturn is expected to continue to impact our results for the balance of 2015. During the third quarter, oil prices dropped below $40/bbl, outside of our previous guidance, and drove corresponding behavioral and market shifts. As a result, we have reduced our guidance for the final quarter of 2015, with the incremental decline reflecting reduced production volumes and pricing pressure partially offset by additional savings from our rationalization initiatives.

Adjusted EBITDA in the fourth quarter of 2015 is expected to be lower than the third quarter. Low crude oil prices and activity declines exacerbated by an anticipated early shut down for the holiday season are expected to continue to impact our results. Operations at our full-service facility in Fort McMurray and the Silver Lake modular processing facility (MPF) in Heavy Oil and at our Fox Creek and Gold Creek MPF and landfill in Oilfield will continue to ramp up. Contributions will be lower than previously expected as a result of the decreased activity experienced in the third quarter. In Heavy Oil, Onsite contributions will be seasonally lower and further impacted by the hibernation of our original Syncrude MFT contract. We expect to realize approximately $10 million of savings in the fourth quarter from our cost rationalization actions taken in the year.

The following table outlines the factors we expect to impact performance in the fourth quarter and full year.

Factor				Assumption		Expected impact on Adjusted EBITDA compared to prior year period(1)
		Q3 2015(1)		Q4 and Full year		Q4 2015		2015
West Texas Intermediate (US$/bbl)		$46.41		Q4 2015: $40 - $50 2015: $48 - $52
Canadian Light Sweet (CDN$/bbl)(2)		$54.71		Q4 2015: $50 - $60 2015: $55 - $60		$1M - $2M decrease		$10M - $11M decrease
Western Canadian Select (CDN$/bbl)(2)		$43.29		Q4 2015: $40 - $50 2015: $45 - $48		$1M - $2M decrease		$8M - $9M decrease
Drilling activity(2) decline year-over-year		~50%		50% - 55%		$8M - $9M decrease		$33M - $34M decrease
Step Change(3)		($17.4M)				$15M - $20M decrease		$44M - $49M decrease
Savings from cost rationalization		$9.1 M		In excess of $35 million annualized		$10M increase		$29M increase
(1) M refers to millions.
(2) Impact derived from annual sensitivities based on 2015 forecast performance and volumes outlined in the "Sensitivities" section. The actual impact from crude oil prices may vary with fluctuations in volumes.
(3) This factor is expected to have an impact on our performance through the year, and cannot be quantified on any linear sensitivity.

The expected impact of crude oil prices on Adjusted EBITDA is derived from the change in crude oil price and annual recovered crude oil volumes. At current activity levels, we expect to recover fewer barrels of crude oil in 2015 compared to 2014. This decrease reduces our sensitivity on an annual basis. For every $10 change in our Canadian benchmarks we expect a $6 million change in Adjusted EBITDA in 2015, compared to an $8 million change in 2014. The impact of the reduced volumes has increased the expected impact on performance from Step Change in 2015.

Crude oil prices

• Lower crude oil prices directly impact the value of the products we recover from waste. Year-to-date, crude oil prices have dropped more than 40% compared to 2014. We anticipate oil prices to remain low for the balance of 2015 and into 2016.

Drilling Activity

• Since December 2014, drilling activity in areas where we operate has declined approximately 50%. We anticipate drilling activity to remain depressed for the balance of 2015, with a staged recovery commencing in the second half of 2016.

Step Change (Production waste volumes, shifts in waste mix, customer pricing reductions, offset by returns from growth capital and operational efficiencies)

• In response to the significant market declines experienced in the third quarter, we have increased the expected impact of step change on our fourth quarter and 2015 results.
• In the fourth quarter, we expect heightened pricing pressure and lower production volumes, as experienced in Q3 2015, to continue.
• We are working with our customers to bundle opportunities, partner through contractual relationships, collaborating with our suppliers and reducing our operating cost structure to mitigate the impact of pricing pressure.
• In 2014, growth capital of $130 million was directed to our Heavy Oil and Oilfield Divisions. Year-to-date, the severe decline in crude oil prices and activity has reduced contributions from these investments. We expect this trend to continue for the balance of 2015 and into 2016.

Savings from Cost Rationalization

• We anticipate cost reduction and rationalization initiatives will drive in excess of $35 million in annualized ongoing savings and approximately $30 million in 2015.

Net Debt and Leverage

The waiver of our Total Debt to EBITDA covenant ratio under our Credit Facility provides us with additional flexibility to manage our balance sheet successfully during this downturn. Management of our debt leverage and optimal use of our cash and capital are of the highest priority. We will remain well within our remaining debt covenants throughout the balance of the year.

Restructuring and Other Related Costs

We expect to incur approximately $4 million in additional restructuring and other related costs in the fourth quarter of 2015.

Free Cash Flow Generation

We have proactively structured our business model for a "lower for longer" environment. Our rationalization initiatives, waiver on our Total Debt to EBITDA ratio, reduced dividend payout and continued focus on effective and timely capital execution give us agility and balance sheet strength to weather this sustained downturn. Our 2015 growth capital investments, including the Fort McMurray facility, the four new MPFs in Canada and the Bakken, are strategically located and provide torque to our business model as prices and activity recover. Going forward, we will continue to focus on value creation for our customers. Further, in 2016, despite the low oil price environment, we will target to be Free Cash Flow neutral, after all cash financing, tax, dividend and capital expenditures. Beyond 2016, we will target positive Free Cash Flow generation.

With crude oil prices below US$50 WTI and current activity levels, our previous guidance for 2016 based on oil between US$50 - $60 WTI for Adjusted EBITDA ranging from $120 to $140 million, is no longer valid. Given the current environment, we will provide guidance on 2016 results as we move through the next year and are better positioned to assess developments in commodity prices, drilling activity and customer spending.

Quarterly Conference Call

Management will hold a conference call on November 5, 2015 at 11:00 a.m. (ET) to discuss Newalta's performance for the quarter ended September 30, 2015. To participate in the teleconference, please call 416-340-8010 or toll free 866-226-1798. To access the simultaneous webcast, please visit www.newalta.com. For those unable to listen to the live call, a taped broadcast will be available at www.newalta.com and, until midnight on Friday, November 13, 2015, by dialing 800-408-3053 and using pass code 4737155.

About Newalta

Newalta is a leading provider of innovative engineered environmental solutions that enable customers to reduce disposal, enhance recycling and recover valuable resources from oil and gas exploration and production waste streams. We simplify the critical challenges of sustainable environmental practices through the use of advanced processing capabilities deployed through a differentiated business model. We serve customers onsite directly at their operations and through a network of locations throughout North America. Our proven processes and excellent record of safety make us the first-choice provider of sustainability-enhancing services for oil and gas customers. With a highly skilled team of people, a two-decade track record of innovation and a commitment to commercializing new solutions, Newalta is positioned for sustained future growth and improvement. We are Sustainability Simplified™. Newalta trades on the TSX as NAL. For more information, visitwww.newalta.com.

The press release contains certain statements that constitute forward-looking information. Please refer to the section below "Forward-Looking Information", for further discussion of assumptions and risks relating to this forward looking information.

The unaudited interim Condensed Consolidated Financial Statements and MD&A, which contain additional notes and disclosures, are available on SEDAR at www.sedar.com or our website at www.newalta.com under Investor Relations/Financial Reports.

SELECTED FINANCIAL INFORMATION

			Three months ended September 30,						Nine months ended September 30,
($000s except per share data)  (unaudited)			2015		2014		% Change		2015		2014		% Change
Heavy Oil
Revenue			40,328		56,256		(28)		115,427		146,598		(21)
Divisional EBITDA(1)			18,434		27,836		(34)		44,479		67,329		(34)
- % of revenue			46%		49%		(6)		39%		44%		(15)
Revenue by Business Unit
	Facilities		26%		35%		(26)		25%		37%		(32)
	Onsite		74%		65%		14		75%		63%		19
Assets Employed(2)									278,465		237,148		17
Oilfield
Revenue			43,174		79,142		(45)		147,492		215,605		(32)
Divisional EBITDA(1)			11,583		31,943		(64)		38,765		79,423		(51)
- % of revenue			27%		40%		(33)		26%		37%		(30)
Revenue by Business Unit
	Facilities		73%		69%		6		72%		73%		(1)
	Drilling Services		27%		31%		(13)		28%		27%		4
Assets Employed(2)									538,422		490,838		10
Capital Expenditures
Maintenance capital expenditures			3,879		6,381		(39)		10,343		15,824		(35)
	Heavy Oil		2,165		1,594		36		6,315		5,598		13
	Oilfield		1,268		3,685		(66)		1,875		7,069		(73)
Growth capital expenditures			9,818		35,378		(72)		57,770		76,728		(25)
	Heavy Oil		4,377		18,560		(76)		22,854		32,732		(30)
	Oilfield		4,092		14,168		(71)		29,452		35,720		(18)
(1) Divisional EBITDA does not have any standardized meaning prescribed by GAAP.
(2) Assets employed is provided to assist management and investors in determining the effectiveness of the use of the assets at a divisional level. Assets employed is the sum of capital assets, intangible assets and goodwill allocated to each division. Assets employed as defined does not include capital assets held by corporate. Corporate assets include information technology, leasehold improvements, and technical development.

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited - Expressed in thousands of Canadian Dollars)

			September 30, 2015		December 31, 2014
Assets
Current assets
	Cash		2,998		4,129
	Accounts and other receivables		71,073		104,945
	Inventories		5,225		7,681
	Prepaid expenses and other assets		5,628		9,150
	Assets held for sale		-		365,262
			84,924		491,167
Non-current assets
	Property, plant and equipment		835,387		804,522
	Other long-term assets		4,775		8,953
	Goodwill		60,443		60,443
TOTAL ASSETS			985,529		1,365,085
Liabilities
Current liabilities
	Accounts payable and accrued liabilities		94,414		170,541
	Dividends payable		7,030		7,003
	Liabilities held for sale		-		97,131
			101,444		274,675
Non-current liabilities
	Senior secured debt		40,091		183,104
	Senior unsecured debentures		271,390		270,837
	Other liabilities		672		1,973
	Deferred tax liability		23,254		43,180
	Provisions		84,186		68,410
TOTAL LIABILITIES			521,037		842,179
Shareholders' Equity
Shareholders' capital			426,061		422,991
Contributed surplus			11,760		10,916
Retained (deficit) earnings			(1,715)		76,061
Accumulated other comprehensive income			28,386		12,938
TOTAL SHAREHOLDERS' EQUITY			464,492		522,906
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY			985,529		1,365,085

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited - Expressed in thousands of Canadian Dollars)

(Except per share data)

			For the three months ended September 30,				For the nine months ended September 30,
			2015		2014		2015		2014
Revenue			83,502		135,398		262,919		362,203
	Operating expenses		53,485		75,619		179,675		215,451
	General and administrative		9,950		16,495		34,805		48,014
	Depreciation and amortization		16,020		14,901		45,803		37,157
	Stock-based compensation (recovery) expense		(2,406)		2,850		(3,376)		10,540
	Restructuring and other related costs		2,683		-		28,146		526
	Impairment		9,049		-		14,794		-
	Finance charges		6,498		6,943		20,891		26,651
	Embedded derivative loss		3,175		3,314		402		11,641
Total expenses			98,454		120,122		321,140		349,980
(Loss) earnings before income taxes			(14,952)		15,276		(58,221)		12,223
Deferred income tax (recovery) expense			(2,262)		4,680		(8,891)		6,718
Net (loss) earnings from continuing operations			(12,690)		10,596		(49,330)		5,505
Net (loss) earnings from discontinued operations			(2,972)		5,974		(7,362)		9,385
Net (loss) earnings			(15,662)		16,570		(56,692)		14,890
Other comprehensive income:
Items that may be reclassified subsequently to consolidated statement of operations
	Exchange difference on translating foreign operations		8,194		5,532		15,448		5,552
Other comprehensive income			8,194		5,532		15,448		5,552
Total comprehensive (loss) income			(7,468)		22,102		(41,244)		20,442
(Loss) earnings per share:
	Basic from continuing operations		(0.23)		0.19		(0.88)		0.10
	Basic from discontinued operations		(0.05)		0.11		(0.13)		0.17
Basic (loss) earnings per share			(0.28)		0.30		(1.01)		0.27
	Diluted from continuing operations		(0.23)		0.19		(0.88)		0.10
	Diluted from discontinued operations		(0.05)		0.10		(0.13)		0.16
Diluted (loss) earnings per share			(0.28)		0.29		(1.01)		0.26

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY

(Unaudited - Expressed in thousands of Canadian Dollars)

		Shareholders' capital		Contributed surplus		Retained (deficit) earnings		Accumulated other comprehensive income		Total
Balance, December 31, 2013		409,894		15,251		245,834		4,183		675,162
Changes in equity for the nine months ended September 30, 2014
Expense related to vesting of options		-		1,968		-		-		1,968
Exercise of options		6,880		(6,409)		-		-		471
Issuance of shares		4,187		-		-		-		4,187
Dividends declared		-		-		(20,097)		-		(20,097)
Other comprehensive income		-		-		-		5,552		5,552
Net earnings for the period		-		-		14,890		-		14,890
Balance, September 30, 2014		420,961		10,810		240,627		9,735		682,133
Changes in equity for the three months ended December 31, 2014
Expense related to vesting of options		-		675		-		-		675
Exercise of options		569		(569)		-		-		-
Issuance of shares		1,461		-		-		-		1,461
Dividends declared		-		-		(7,003)		-		(7,003)
Other comprehensive income		-		-		-		3,203		3,203
Net loss for the period		-		-		(157,563)		-		(157,563)
Balance, December 31, 2014		422,991		10,916		76,061		12,938		522,906
Changes in equity for the nine months ended September 30, 2015
Expense related to vesting of options		-		2,277		-		-		2,277
Exercise of options		1,791		(1,433)		-		-		358
Issuance of shares		1,279		-		-		-		1,279
Dividends declared		-		-		(21,084)		-		(21,084)
Other comprehensive income		-		-		-		15,448		15,448
Net loss for the period		-		-		(56,692)		-		(56,692)
Balance, September 30, 2015		426,061		11,760		(1,715)		28,386		464,492

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited - Expressed in thousands of Canadian Dollars)

			For the three months ended September 30,				For the nine months  ended September 30,
			2015		2014		2015		2014
Cash provided by (used for):
Operating Activities
Net (loss) income from continuing operations			(12,690)		10,596		(49,330)		5,505
Adjustments for:
	Depreciation and amortization		16,020		14,901		45,803		37,157
	Impairment		9,049		-		14,794		-
	Onerous lease		(150)		-		12,731		-
	Onerous lease paid		(1,029)		-		(2,108)		-
	Income tax provision		(2,262)		4,680		(8,891)		6,718
	Income tax paid		(11)		(5)		(161)		(12)
	Non-cash stock-based compensation (recovery) expense		(2,407)		2,193		(4,446)		6,230
	Finance charges		6,498		6,943		20,891		26,651
	Embedded derivative loss		3,175		3,314		402		11,641
	Finance charges paid		(471)		(1,893)		(10,001)		(18,740)
	Other		834		386		2,932		672
Funds from Operations			16,556		41,115		22,616		75,822
Change in non-cash working capital			20,505		(29,341)		8,414		(20,649)
Decommissioning costs incurred			(251)		(931)		(1,051)		(2,213)
Cash from continuing operations			36,810		10,843		29,979		52,960
Cash (used in) from discontinued operations			(4,052)		16,806		(25,493)		11,547
Cash from Operating Activities			32,758		27,649		4,486		64,507
Investing Activities
	Additions to property, plant and equipment		(20,144)		(30,371)		(123,097)		(117,520)
	(Adjustment) proceeds on sale of discontinued operations		(15,701)		-		279,646		-
	Proceeds on sale of property, plant and equipment		293		1		718		562
	Other		907		(95)		7,148		(1,135)
Cash (used in) from continuing operations			(34,645)		(30,465)		164,415		(118,093)
Cash used in discontinued operations			-		(4,979)		(4,041)		(14,242)
Cash (used in) from Investing Activities			(34,645)		(35,444)		160,374		(132,335)
Financing Activities
	Issuance of shares		-		237		358		469
	Issuance of series 3 senior unsecured debentures		-		-		-		147,069
	Redemption of series 1 senior unsecured debentures		-		-		-		(125,000)
	Increase (decrease) in senior secured debt		15,143		13,613		(143,013)		66,626
	Decrease in bank indebtedness		(1,711)		-		-		(1,321)
	Dividends paid		(7,030)		(5,567)		(19,780)		(15,006)
Cash from (used in) continuing operations			6,402		8,283		(162,435)		72,837
Cash from (used in) Financing Activities			6,402		8,283		(162,435)		72,837
Effect of foreign exchange on cash			(1,517)		(650)		(3,556)		(495)
Change in cash			2,998		(162)		(1,131)		4,514
Cash, beginning of period			-		4,676		4,129		-
Cash, end of period			2,998		4,514		2,998		4,514

FORWARD-LOOKING STATEMENTS

Certain statements contained in this document constitute "forward-looking information" as defined under applicable securities laws. When used in this document, the words "may", "would", "could", "will", "intend", "plan", "anticipate", "believe", "estimate", "expect", "potential", "strategy", "target", and similar expressions, as they relate to Newalta Corporation and the subsidiaries of Newalta Corporation, or their management, are intended to identify forward-looking information. In particular, forward-looking information included or incorporated by reference in this document includes statements with respect to:

• future operating and financial results;
• business prospects and strategy including related timelines;
• capital expenditure programs and other expenditures;
• realization of anticipated benefits from the sale of the Industrial Division, including the ability to reinvest net proceeds of disposition in a timely and efficient manner;
• realization of anticipated benefits of growth capital investments, acquisitions, divestitures and our innovation and process development initiatives;
• realization of anticipated benefits from the implementation of cost rationalization initiatives including the anticipated value and sustainability of the cash savings from such initiatives;
• anticipated industry activity levels;
• anticipated commodity prices;
• expected demand for our services;
• expected expansion opportunities for our business;
• the amount of dividends declared or payable in the future;
• our projected cost structure; and
• expectations and implications of changes in legislation.

Expected future financial and operating performance and related assumptions are set out under "Outlook".

Such information reflects our current views with respect to future events and is subject to certain risks, uncertainties and assumptions, including, without limitation:

• strength of the oil and gas industry, including drilling activity;
• general market conditions;
• fluctuations in commodity prices for oil and the price we receive for our recovered oil;
• fluctuations in interest rates and exchange rates;
• our ability to secure future capital to support and develop our business, including the issuance of additional common shares;
• the highly regulated nature of the environmental services and waste management business in which we operate;
• dependence on our senior management team and other operations management personnel with waste industry experience;
• the competitive environment of our industry in Canada and the U.S.;
• success of our growth, acquisition and innovation and process development strategies, including integration of businesses and processes into our operations, and potential liabilities from acquisitions;
• potential operational and safety risks and hazards, obtaining insurance for such risks and hazards on reasonable financial terms, and potential failure of meeting customer safety standards;
• the seasonal nature of our operations;
• risk of pending and future legal proceedings;
• risk to our reputation;
• our ability to attract, retain, and integrate skilled employees;
• open access for new industry entrants and the general unprotected nature of technology used in the waste industry;
• possible volatility of the price of, and the market for, our shares, and potential dilution for shareholders in the event of a sale of additional shares;
• financial covenants in our debt agreements that may restrict our ability to engage in transactions or to obtain additional financing;
• costs associated with operating our landfills; and
• such other risks or factors described from time to time in reports we file with securities regulatory authorities.

By its nature, forward-looking information involves numerous assumptions, known and unknown risks and uncertainties, both general and specific, that contribute to the possibility that the predictions, forecasts, projections and other forward-looking information will not occur. Many other factors could also cause actual results, performance or achievements to be materially different from any future results, performance or achievements that may be expressed or implied by such forward-looking information and readers are cautioned that the foregoing list of factors is not exhaustive. Should one or more of these risks or uncertainties materialize, or should assumptions underlying the forward-looking information prove incorrect, actual results may vary materially from those described herein as intended, planned, anticipated, believed, estimated or expected. Furthermore, the forward-looking information contained in this document is made as of the date of this document and, in each case, is expressly qualified by this cautionary statement. Unless otherwise required by law, we do not intend, or assume any obligation, to update any such forward-looking information.

RECONCILIATION OF NON-GAAP MEASURES

This Press Release contains references to certain financial measures, including some that do not have any standardized meaning prescribed by International Financial Reporting Standards (IFRS or GAAP) and may not be comparable to similar measures presented by other corporations or entities. These financial measures are identified and defined below.

"EBITDA", "EBITDA per share", "Adjusted EBITDA", and "Adjusted EBITDA per share" are measures of our operating profitability. EBITDA provides an indication of the results generated by our principal business activities prior to how these activities are financed, assets are amortized or impaired, or how the results are taxed in various jurisdictions. In addition, Adjusted EBITDA provides an indication of the results generated by our principal business activities prior to recognizing stock-based compensation and restructuring and other related costs. Adjusted EBITDA provides improved continuity with respect to the comparison of our operating results over a period of time. Stock-based compensation, a component of employee remuneration, can vary significantly with changes in the price of our common shares (Shares), while restructuring and other related costs are outside of our normal course of business. Restructuring and other related costs are charges primarily attributable to cost rationalization initiatives. EBITDA and Adjusted EBITDA are derived from the condensed consolidated statements of operations and comprehensive income. EBITDA per share and Adjusted EBITDA per share are derived by dividing EBITDA and Adjusted EBITDA by the basic weighted average number of Shares.

EBITDA and Adjusted EBITDA from Continuing Operations are calculated as follows:

			Three months ended September 30,				Nine months ended September 30,
($000s except per share data)			2015		2014		2015		2014
Net (loss) earnings from Continuing Operations			(12,690)		10,596		(49,330)		5,505
Add back:
	Deferred income tax (recovery) expense		(2,262)		4,680		(8,891)		6,718
	Embedded derivative loss		3,175		3,314		402		11,641
	Finance charges		6,498		6,943		20,891		26,651
	Impairment		9,049		-		14,794		-
	Depreciation and amortization(1)		16,020		14,901		45,803		37,157
EBITDA			19,790		40,434		23,669		87,672
Add back:
	Stock-based compensation (recovery) expense(2)		(2,406)		2,850		(3,376)		10,540
	Restructuring and other related costs		2,683		-		28,146		526
Adjusted EBITDA			20,067		43,284		48,439		98,738
Weighted average number of Shares			56,237		55,901		56,216		55,734
EBITDA per share			0.35		0.72		0.42		1.57
Adjusted EBITDA per share			0.36		0.77		0.86		1.77
(1) Includes non-cash gains or losses on asset disposal and other non-cash charges.
(2) Stock-based compensation includes ($2,407) and ($4,446) for Q3 2015 and 2015 year-to-date, respectively, and $2,193 and $6,230 for Q3 2014 and 2014 year-to-date, respectively of non-cash stock-based compensation (recovery) expense.

"Divisional EBITDA" provides an indication of the results generated by the division's principal business activities prior to how activities are financed, the assets are amortized or impaired and before allocation of General and Administrative costs (G&A), restructuring and other related costs or stock-based compensation. Divisional EBITDA is derived from Net (loss) earnings before income tax from Continuing Operations as follows:

			Three months ended September 30,				Nine months ended September 30,
($000s except per share data)			2015		2014		2015		2014
Net (loss) earnings before Income tax from Continuing Operations			(14,952)		15,276		(58,221)		12,223
Add back:
	Embedded derivative loss		3,175		3,314		402		11,641
	Finance charges		6,498		6,943		20,891		26,651
	Restructuring and other related costs		2,683		-		28,146		526
	Impairment		9,049		-		14,794		-
	Stock-based compensation (recovery) expense		(2,406)		2,850		(3,376)		10,540
	Depreciation and amortization		16,020		14,901		45,803		37,157
	G&A(1)		9,950		16,495		34,805		48,014
Divisional EBITDA			30,017		59,779		83,244		146,752
	Heavy Oil		18,434		27,836		44,479		67,329
	Oilfield		11,583		31,943		38,765		79,423
Deduct:
	G&A(1)		9,950		16,495		34,805		48,014
Adjusted EBITDA			20,067		43,284		48,439		98,738
	Stock-based compensation (recovery) expense		(2,406)		2,850		(3,376)		10,540
	Restructuring and other related costs		2,683		-		28,146		526
EBITDA			19,790		40,434		23,669		87,672
(1) As a result of the change in our financial statement presentation from functional to nature based, we have reclassified the sales expense directly attributable to the divisions from Corporate and Other to the respective division. Prior period comparative figures have been amended to conform to current period's presentation. Please refer to "Reporting Structure" for the restated historical segmented information and key metrics.

"Adjusted net earnings" and "Adjusted net earnings per share" are measures of our profitability from Continuing Operations. Adjusted net earnings from Continuing Operations (Adjusted net earnings) provides an indication of the results generated by our principal business activities prior to recognizing stock-based compensation recovery or expense, the gain or loss on embedded derivatives, impairment and restructuring and other related charges. Stock-based compensation, a component of employee remuneration, can vary significantly with changes in the price of our Shares. The loss on the embedded derivative is a result of the change in the trading price of the debentures and the volatility of the applicable bond market. Impairment and restructuring and other related costs are related to initiatives outside of our normal course of business. As such, Adjusted net earnings provides improved continuity with respect to the comparison of our results over a period of time. Adjusted net earnings per share is derived by dividing Adjusted net earnings by the basic weighted average number of Shares.

			Three months ended September 30,				Nine months ended September 30,
($000s except per share data)			2015		2014		2015		2014
Net (loss) earnings from Continuing Operations			(12,690)		10,596		(49,330)		5,505
Add back:
	Embedded derivative loss		3,175		3,314		402		11,641
	Restructuring and other related costs		2,683		-		28,146		526
	Impairment		9,049		-		14,794		-
	Stock-based compensation (recovery) expense		(2,406)		2,850		(3,376)		10,540
Adjusted net (loss) earnings			(189)		16,760		(9,364)		28,212
Weighted average number of Shares			56,237		55,901		56,216		55,734
Adjusted net (loss) earnings per share			-		0.30		(0.17)		0.51

"Tangible book value per share" is used to assist management and investors in evaluating the book value compared to the market value.

($000s except per share data)			September 30, 2015		December 31, 2014
Total Assets			985,529		1,365,085
Less:
	Goodwill		60,443		60,443
	Other long-term assets		4,775		8,953
	Assets held for sale		-		365,262
Total Tangible Assets			920,311		930,427
Weighted average number of Shares			56,237		55,802
Tangible book value per share			16.36		16.67

"Return on Capital Employed" (ROCE) is used to assist management and investors in measuring the returns realized at the consolidated level from capital employed. ROCE is derived from Net earnings plus tax-adjusted interest divided by the average of the beginning and ending balances of our total assets less current liabilities for the period (Net Assets).

"Cash Basis Return on Capital" (ROC - Cash) is also used to assist management and investors in measuring the returns realized at the consolidated level from capital employed. ROC - Cash is derived from Adjusted EBITDA less cash stock-based compensation, cash taxes and maintenance capital divided by Net Assets.

"Net Debt" is defined as sum of amount drawn on the Credit Facility, Letters of Credit and Senior Unsecured Debentures less Cash on hand.

"Funds from operations" is used to assist management and investors in analyzing cash flow and leverage from Continuing Operations. Funds from operations as presented is not intended to represent operating funds from operations or operating profits for the period, nor should it be viewed as an alternative to cash flow from operating activities, net earnings or other measures of financial performance calculated in accordance with IFRS. Funds from operations is derived from the condensed consolidated statements of cash flows and is calculated as follows:

			Three months ended September 30,				Nine months ended September 30,
($000s except per share data)			2015		2014		2015		2014
Cash from Continuing Operations			36,810		10,843		29,979		52,960
Add back (deduct):
	Change in non-cash working capital		(20,505)		29,341		(8,414)		20,649
	Decommissioning costs incurred		251		931		1,051		2,213
Funds from Operations			16,556		41,115		22,616		75,822
Weighted average number of Shares			56,237		55,901		56,216		55,734
Funds from operations per share			0.29		0.74		0.40		1.36

"Free Cash Flow" is defined as Funds from Operations less dividends paid, capital expenditures and decommissioning costs incurred.

References to EBITDA, EBITDA per share, Adjusted EBITDA, Adjusted EBITDA per share, Divisional EBITDA, Adjusted net earnings, Adjusted net earnings per share, ROC - Cash, Net Debt, Funds from operations, Funds from operations per share and Free Cash Flow throughout this document have the meanings set out above.

REPORTING STRUCTURE

In Q1 2015, we reorganized our reporting structure into two divisions - Heavy Oil and Oilfield. The new structure more closely aligns operations with customer activities, facilitates a seamless service package to customers, optimizes our resource allocations, and aids in the execution of our refreshed growth strategy.

The revised structure consists of:

Heavy Oil

• Facilities business unit
• Onsite business unit

Oilfield

• Facilities business unit (includes facilities in both Canada and the U.S.)
• Drilling Services business unit (includes drill site services in both Canada and the U.S.)
   

HEAVY OIL RESTATED INFORMATION BY QUARTER

				2014				2013				2012
($ millions)	Q4	Q3	Q2	Q1	Q4	Q3	Q2	Q1	Q4	Q3	Q2	Q1
Revenue	56.7	56.2	50.4	40.0	48.3	53.5	41.7	24.4	36.5	45.6	25.4	22.9
Operating expenses	33.3	28.4	27.2	23.7	26.4	25.2	21.4	13.8	19.0	24.9	12.8	11.5
Divisional EBITDA	23.4	27.8	23.2	16.3	21.9	28.3	20.3	10.6	17.5	20.7	12.6	11.4
Divisional EBITDA % of revenue	41%	49%	46%	41%	45%	53%	49%	43%	48%	45%	50%	50%
Depreciation and amortization	5.6	5.5	4.2	2.7	4.5	5.1	3.2	1.4	3.4	2.3	1.4	1.2
Operating profit	17.8	22.3	19.0	13.6	17.4	23.2	17.1	9.2	14.1	18.4	11.2	10.2
Operating profit % of revenue	31%	40%	38%	34%	36%	43%	41%	38%	39%	40%	44%	45%
Maintenance capital	2.6	1.6	3.0	1.0	7.4	1.5	0.6	0.2	2.0	2.1	2.1	0.3
Growth capital	29.8	18.6	8.4	5.8	18.0	12.4	13.4	3.8	12.3	2.9	26.7	17.0
Assets employed	261	237	223	217	210	189	178	168	165	158	155	129
Business Unit Revenue Contribution %
Facilities	28%	35%	35%	43%	32%	31%	33%	51%	35%	30%	51%	57%
Onsite	72%	65%	65%	57%	68%	69%	67%	49%	65%	70%	49%	43%
Metrics
Contracts % of Onsite revenue	80%	77%	74%	77%	75%	86%	71%	67%	74%	71%	61%	65%

HEAVY OIL RESTATED INFORMATION BY YEAR

				2014				2013				2012
($ millions)	Q4 YTD	Q3 YTD	Q2 YTD	Q1	Q4 YTD	Q3 YTD	Q2 YTD	Q1	Q4 YTD	Q3 YTD	Q2 YTD	Q1
Revenue	203.3	146.6	90.4	40.0	167.9	119.6	66.1	24.4	130.4	93.9	48.3	22.9
Operating expenses	112.6	79.3	50.9	23.7	86.8	60.4	35.2	13.8	68.2	49.2	24.3	11.5
Divisional EBITDA	90.7	67.3	39.5	16.3	81.1	59.2	30.9	10.6	62.2	44.7	24.0	11.4
Divisional EBITDA % of revenue	45%	46%	44%	41%	48%	49%	47%	43%	48%	48%	50%	50%
Depreciation and amortization	18.0	12.4	6.9	2.7	14.2	9.7	4.6	1.4	8.3	4.9	2.6	1.2
Operating profit	72.7	54.9	32.6	13.6	66.9	49.5	26.3	9.2	53.9	39.8	21.4	10.2
Operating profit % of revenue	36%	37%	36%	34%	40%	41%	40%	38%	41%	42%	44%	45%
Maintenance capital	8.2	5.6	4.0	1.0	9.6	2.3	0.7	0.2	6.5	4.5	2.5	0.3
Growth capital	62.6	32.8	14.2	5.8	47.6	29.6	17.2	3.8	58.9	46.6	43.7	17.0
Business Unit Revenue Contribution %
Facilities	35%	37%	38%	43%	35%	36%	40%	51%	40%	42%	54%	57%
Onsite	65%	63%	62%	57%	65%	64%	60%	49%	60%	58%	46%	43%
Metrics
Contracts % of Onsite revenue	77%	76%	75%	77%	77%	77%	69%	67%	69%	68%	63%	65%

OILFIELD RESTATED INFORMATION BY QUARTER

				2014				2013				2012
($ millions)	Q4	Q3	Q2	Q1	Q4	Q3	Q2	Q1	Q4	Q3	Q2	Q1
Revenue	76.4	79.1	66.0	70.5	61.7	63.6	53.9	65.1	60.5	63.2	52.2	63.7
Operating expenses	51.0	47.1	43.0	46.0	41.7	39.4	35.4	39.2	39.8	39.3	36.6	37.1
Divisional EBITDA	25.4	32.0	23.0	24.5	20.0	24.2	18.5	25.9	20.7	23.9	15.6	26.6
Divisional EBITDA % of revenue	33%	40%	35%	35%	32%	38%	34%	40%	34%	38%	30%	42%
Depreciation and amortization	8.0	5.7	4.6	4.4	4.4	3.9	4.0	4.1	4.0	4.1	3.6	4.1
Operating profit	17.4	26.3	18.4	20.1	15.6	20.3	14.5	21.8	16.7	19.8	12.0	22.5
Operating profit % of revenue	23%	33%	28%	29%	25%	32%	27%	33%	28%	31%	23%	35%
Maintenance capital	6.0	3.7	2.1	1.3	2.8	2.8	1.9	1.5	1.8	3.2	2.3	1.4
Growth capital(1)	31.5	14.2	8.8	12.7	30.5	12.6	8.9	7.2	15.6	8.8	4.5	5.7
Assets employed	513	491	475	472	451	427	421	413	407	391	385	380
Business Unit Revenue Contribution %
Facilities	67%	69%	73%	76%	73%	75%	74%	71%	70%	68%	67%	67%
Canada % of Facilities revenue	86%	89%	85%	88%	92%	93%	90%	91%	89%	91%	93%	95%
U.S. % of Facilities revenue	14%	11%	15%	12%	8%	7%	10%	9%	11%	9%	7%	5%
Drilling Services	33%	31%	27%	24%	27%	25%	26%	29%	30%	32%	33%	33%
Canada % of revenue(2)	29%	30%	24%	43%	35%	30%	26%	35%	38%	41%	36%	47%
U.S. % of revenue(2)	71%	70%	76%	57%	65%	70%	74%	65%	62%	59%	64%	53%
Metrics
U.S. Recovered Crude Oil ('000 bbl)	8.1	4.4	8.6	7.5	-	-	-	-	-	-	-	-
U.S. Netback (CDN$/bbl)	58.38	78.88	83.80	81.32	-	-	-	-	-	-	-	-
U.S. Recovered Crude Oil sales	0.5	0.3	0.7	0.6	-	-	-	-	-	-	-	-

OILFIELD RESTATED INFORMATION BY YEAR

				2014				2013				2012
($ millions)	Q4 YTD	Q3 YTD	Q2 YTD	Q1	Q4 YTD	Q3 YTD	Q2 YTD	Q1	Q4 YTD	Q3 YTD	Q2 YTD	Q1
Revenue	292.0	215.6	136.5	70.5	244.3	182.6	119.0	65.1	239.6	179.1	115.9	63.7
Operating expenses	187.1	136.1	89.0	46.0	155.7	114.0	74.6	39.2	152.8	113.0	73.7	37.1
Divisional EBITDA	104.9	79.5	47.5	24.5	88.6	68.6	44.4	25.9	86.8	66.1	42.2	26.6
Divisional EBITDA % of revenue	36%	37%	35%	35%	36%	38%	37%	40%	36%	37%	36%	42%
Depreciation and amortization	22.7	14.7	9.0	4.4	16.4	12.0	8.1	4.1	15.8	11.8	7.7	4.1
Operating profit	82.2	64.8	38.5	20.1	72.2	56.6	36.3	21.8	71.0	54.3	34.5	22.5
Operating profit % of revenue	28%	30%	28%	29%	30%	31%	31%	33%	30%	30%	30%	35%
Maintenance capital	13.1	7.1	3.4	1.3	9.0	6.2	3.4	1.5	8.7	6.8	3.7	1.4
Growth capital(1)	67.2	35.7	21.5	12.7	59.2	28.7	16.1	7.2	34.5	19.0	10.2	5.7
Business Unit Revenue Contribution %
Facilities	71%	73%	75%	76%	73%	73%	72%	71%	68%	67%	67%	67%
Canada % of Facilities revenue	87%	87%	87%	88%	91%	91%	91%	91%	92%	93%	94%	95%
U.S. % of Facilities revenue	13%	13%	13%	12%	9%	9%	9%	9%	8%	7%	6%	5%
Drilling Services	29%	27%	25%	24%	27%	27%	28%	29%	32%	33%	33%	33%
Canada % of revenue(2)	31%	32%	33%	43%	32%	31%	31%	35%	39%	41%	42%	47%
U.S. % of revenue(2)	69%	68%	67%	57%	68%	69%	69%	65%	61%	59%	58%	53%
Metrics
U.S. Recovered Crude Oil ('000 bbl)	28.6	20.5	16.1	7.5	-	-	-	-	-	-	-	-
U.S. Netback (CDN$/bbl)	75.60	81.33	82.56	81.32	-	-	-	-	-	-	-	-
U.S. Recovered Crude Oil sales	2.1	1.6	1.3	0.6	-	-	-	-	-	-	-	-
(1) Growth capital has been restated from the information reported in our Q1 2015 MD&A.
(2) Drilling Services revenue split by country has been restated from the information reported in our Q1 2015 MD&A to include Environmental Services.

G&A RESTATED INFORMATION

				2014				2013				2012
($ millions)	Q4	Q3	Q2	Q1	Q4	Q3	Q2	Q1	Q4	Q3	Q2	Q1
G&A - by quarter	18.6	16.6	15.8	15.7	20.8	17.0	15.7	16.1	15.1	13.8	14.5	13.1
G&A - YTD	66.7	48.1	31.5	15.7	69.6	48.8	31.8	16.1	56.4	41.4	27.6	13.1

SENSITIVITIES

Results from Continuing Operations are sensitive to changes in commodity prices for crude oil. The direct impact of these commodity prices is reflected in the revenue received from the sale of products such as crude oil. Approximately 20% of our revenue is sensitive to the direct impact of commodity prices. Our results are also impacted by drilling activity. Drilling sensitivities are impacted by the area in which drilling occurs, compared to areas where we operate and the drilling techniques employed. Where possible, we actively manage these impacts by strategically geographically balancing mobile assets to meet demand and shifts in activity levels where necessary.

In Q2, we revised our sensitivities for crude oil prices to better reflect the lower recovered crude oil volumes recovered at our facilities. Year-to-date, volumes have declined approximately 40%. As a result, the assumptions and relationships used to derive the previously disclosed sensitivities have been revised. The following table provides our estimates of fluctuations in key inputs and prices, and the direct impact on revenue and Adjusted EBITDA from product sales:

			2014		Change in benchmark		Impact on Annual Revenue ($)(1)		Impact on Annual Adjusted EBITDA($)(1)
Canadian Light Sweet ($/bbl)			94		10		3 to 3.5 million		3 to 3.5 million
WCS ($/bbl)			81		10		2 to 2.5 million		2 to 2.5 million
Drilling activity(2)(3)					5% change		5 to 8 million		2 to 3 million
	Metres drilled (million metres)		25		1		1.5 million		0.8 million
	Active rigs in WCSB		370		100 rigs		4 million		1 million
(1) Based on 2015 forecast performance and volumes. The actual impact from crude oil prices may vary with fluctuations in recovered crude oil volumes.
(2) Impact from changes in drilling activity assumes a change in the key drilling metrics including metres drilled, and active rigs in the WCSB and in the U.S.
(3) U.S. results are impacted by changes in drilling activity in the respective plays we serve, as indicated by active rigs, and to a greater extent changes in our market share and operations. A sensitivity for active rigs in the U.S. has not been provided because of the overriding impact of shifts in market share on our results.

Stock-based compensation expense is sensitive to changes in our share price. At September 30, 2015, a $1 change in our share price between $9 per share and $15 per share has approximately a $0.5 to 1.0 million direct impact on annual stock-based compensation reflected in G&A from Continuing Operations. Stock-based compensation is also impacted by dividend rate changes and the effects of vesting.