Bonavista Energy Corporation Announces 2015 Fourth Quarter and Year End Results, Reduced Capital Spending and Dividend for 2016

CALGARY, ALBERTA--(Marketwired - Feb. 25, 2016) - Bonavista Energy Corporation ("Bonavista") (TSX:BNP) is pleased to report to shareholders its financial and operating results for the fourth quarter and year ended December 31, 2015. Highlights include the reduction in fourth quarter operating costs by 21% to $5.85 per boe, decreased cash costs to $9.80 per boe and a 33% improvement in finding and development costs to $7.26 per boe, supporting Bonavista's emphasis on cost reductions and efficiency improvements. Bonavista's Audited Consolidated Financial Statements and Notes, as well as Bonavista's Management's Discussion and Analysis ("MD&A") for the years ended December 31, 2015 and 2014, are available on the System for Electronic Document Analysis and Retrieval ("SEDAR") at www.sedar.com and on Bonavista's website at www.bonavistaenergy.com.

Highlights
				Three months ended December 31,									Years ended December 31
				2015			2014			% Change			2015			2014			% Change
Financial
($ thousands, except per share)
Production revenues				137,260			244,612			(44	)%		599,999			1,106,852			(46	)%
Funds from operations(1)				95,792			135,845			(29	)%		385,351			561,105			(31	)%
	Per share(1) (2)			0.44			0.63			(30	)%		1.77			2.69			(34	)%
Dividends declared(3)				11,664			42,754			(73	)%		76,762			164,750			(53	)%
	Per share			0.06			0.21			(71	)%		0.37			0.84			(56	)%
Net income (loss)				(454,616	)		(60,978	)		(646	)%		(751,545	)		4,847			(15,605	)%
	Per share(4)			(2.09	)		(0.28	)		(646	)%		(3.45	)		0.02			(17,350	)%
Adjusted net loss(5)				(443,793	)		(199,730	)		(122	)%		(696,634	)		(136,643	)		(410	)%
	Per share(4)			(2.04	)		(0.93	)		(119	)%		(3.20	)		(0.65	)		(392	)%
Total assets													3,523,716			4,429,402			(20	)%
Long-term debt, net of working capital													1,265,820			1,032,029			23	%
Long-term debt, net of adjusted working capital(6)													1,310,663			1,155,422			13	%
Shareholders' equity													1,548,266			2,357,706			(34	)%
Capital expenditures:
	Exploration and development			56,084			162,155			(65	)%		313,905			639,560			(51	)%
	Dispositions, net of acquisitions			(5,540	)		(87,868	)		(94	)%		(30,552	)		(106,777	)		(71	)%
Weighted average outstanding equivalent shares: (thousands)(4)
	Basic			218,010			215,855			1	%		217,660			208,719			4	%
	Diluted			220,924			218,571			1	%		220,117			210,957			4	%
Operating
(boe conversion - 6:1 basis)
Production:
	Natural gas (mmcf/day)			325			359			(9	)%		337			314			7	%
	Natural gas liquids (bbls/day)			20,804			18,256			14	%		17,666			15,991			10	%
	Oil (bbls/day)(7)			4,934			7,688			(36	)%		5,445			8,873			(39	)%
		Total oil equivalent (boe/day)		79,862			85,810			(7	)%		79,288			77,211			3	%
Product prices:(8)
	Natural gas ($/mcf)			3.44			3.87			(11	)%		3.56			4.27			(17	)%
	Natural gas liquids ($/bbl)			19.39			37.56			(48	)%		23.17			49.78			(53	)%
	Oil ($/bbl)(7)			86.61			83.76			3	%		81.23			80.72			1	%
Operating expenses ($/boe)				5.85			7.38			(21	)%		6.60			8.25			(20	)%
General and administrative expenses ($/boe)				0.97			1.02			(5	)%		1.12			1.14			(2	)%
Cash costs ($/boe)(9)				9.80			10.99			(11	)%		10.70			12.20			(12	)%
Operating netback ($/boe)(10)				15.76			19.63			(20	)%		16.16			22.60			(28	)%

Highlights
Year ended December 31				2015			2014			% Change
Drilling:
	Gross			78			134			(42	)%
	Net			70.1			111.6			(37	)%
Land (net acres):
	Undeveloped			705,610			816,085			(14	)%
	Total			1,929,041			2,218,776			(13	)%
Reserves:(11)
Proved producing:
	Natural gas (bcf)(12)			614.9			662.0			(7	)%
	Oil and natural gas liquids (mbbls)(13)			59,592			59,129			1	%
	Total oil equivalent (mboe)			162,072			169,456			(4	)%
Total proved:
	Natural gas (bcf)(12)			1,026.0			1,094.4			(6	)%
	Oil and natural gas liquids (mbbls)(13)			91,230			93,329			(2	)%
	Total oil equivalent (mboe)			262,224			275,729			(5	)%
Proved plus probable:
	Natural gas (bcf)(12)			1,601.7			1,689.9			(5	)%
	Oil and natural gas liquids (mbbls)(13)			139,543			145,119			(4	)%
	Total oil equivalent (mboe)			406,494			426,768			(5	)%
		% Proved producing		40	%		40	%		-	%
		% Proved		65	%		65	%		-	%
		% Probable		35	%		35	%		-	%
Net present value of future cash flow before income taxes ($ millions, proved plus probable):
	0% discount rate			5,568			8,845			(37	)%
	5% discount rate			3,492			5,402			(35	)%
	10% discount rate			2,412			3,733			(35	)%
	15% discount rate			1,788			2,783			(36	)%
Reserve life index (years):(14)
	Total proved			9.7			9.4			3	%
	Proved plus probable			14.1			13.1			8	%
Reserves (boe per thousand shares - basic):
	Total proved			1,200			1,277			(6	)%
	Proved plus probable			1,860			1,977			(6	)%
Finding and development costs - proved plus probable ($/boe)(15)				7.26			10.86			(33	)%
Recycle ratio - proved plus probable(16)				2.2			2.1			5	%
Finding, development and acquisition costs - proved plus probable ($/boe)(15)				9.84			9.95			(1	)%
Recycle ratio - proved plus probable(16)				1.6			2.3			(30	)%

NOTES:
(1)	Management uses funds from operations to analyze operating performance, dividend coverage and leverage. Funds from operations as presented do not have any standardized meaning prescribed by IFRS and therefore it may not be comparable with the calculations of similar measures for other entities. Funds from operations as presented is not intended to represent operating cash flow or operating profits for the period nor should it be viewed as an alternative to cash flow from operating activities, net income or other measures of financial performance calculated in accordance with IFRS. All references to funds from operations throughout this report are based on cash flow from operating activities before changes in non-cash working capital, decommissioning expenditures and interest expense. Funds from operations per share is calculated based on the weighted average number of shares outstanding consistent with the calculation of net income per share.
(2)	Basic funds from operations per share calculations include exchangeable shares which are convertible into common shares on certain terms and conditions.
(3)	Dividends declared include both cash dividends and common shares issued pursuant to Bonavista's dividend reinvestment plan ("DRIP") and Bonavista's stock dividend program ("SDP"). There were no common shares issued under the DRIP and SDP for the three months ended December 31, 2015 and for the three months ended December 31, 2014. For the year ended December 31, 2015 there were no common shares issued under the DRIP and SDP, 1.7 million common shares were issued under the DRIP and SDP in the comparative year ended December 31, 2014.
(4)	Per share calculations include exchangeable shares which are convertible into common shares on certain terms and conditions.
(5)	Amounts have been adjusted to exclude unrealized gains and losses on financial instrument commodity contracts, net of tax
(6)	Amounts have been adjusted to exclude associated assets or liabilities from financial instrument commodity contracts and decommissioning liabilities.
(7)	Oil includes light, medium and heavy oil.
(8)	Product prices include realized gains and losses on financial instrument commodity contracts.
(9)	Cash costs equal the total of operating, transportation, general and administrative, and financing expenses.
(10)	Operating netback equals production revenues including realized gains and losses on financial instrument commodity contracts, less royalties, operating and transportation expenses, calculated on a boe basis.
(11)	Working interest reserves are gross reserves prior to deduction of royalties and without including any of Bonavista's royalty interests.
(12)	Includes Conventional Natural Gas, Shale Natural Gas and Coal Bed Methane.
(13)	Includes Natural Gas Liquids; and Light, Medium, Heavy and Tight Oil.
(14)	Calculated based on the amount for the relevant reserve category divided by the production forecast prepared by the independent reserve evaluator (GLJ).
(15)	Includes changes in future development costs.
(16)	Recycle ratio is calculated using operating netback per boe divided by either finding and development or finding, development and acquisition costs per boe.

Share Trading Statistics		Three months ended
		December 31, 2015		September 30, 2015		June 30, 2015		March 31, 2015
($ per share, except volume)
High		4.25		6.80		9.26		8.15
Low		1.60		2.93		6.35		5.62
Close		1.82		3.07		6.79		6.38
Average Daily Volume - Shares		1,210,201		1,047,494		1,050,652		763,522

MESSAGE TO SHAREHOLDERS

Our operational and financial results in 2015 mark another milestone in our goal to re-establish Bonavista as a top decile producer in western Canada. Our cost structure is mirroring that of a decade ago, and our commitment to do more with less has resulted in modest growth in our 2015 production with capital spending less than half of that spent in 2014. This capital program consumed approximately 75% of our funds from operations in 2015 and when added to our dividend commitment, created a sustainable business plan with a total payout ratio of 94%.

Significant improvements in operating and capital efficiencies were realized for the third straight year. Operating costs per boe improved to $6.60 in 2015, a 20% improvement over last year, in addition, fourth quarter operating costs were $5.85 per boe, 21% improvement from the same period in 2014. Our proved and probable finding and development costs declined by 33% to $7.26 per boe when compared to 2014, generating a recycle ratio of 2.2:1. Lastly, our cost to add production from our exploration and development ("E&D") program in 2015 was reduced by approximately ten percent over 2014 and currently, we are adding production between $12,000 and $14,000 per boe per day.

A year ago, with the WTI oil price dropping below US$50.00 per bbl, and propane losing its monetary value, we committed to a total payout ratio being less than forecasted funds from operations for 2015. We delivered on that promise and are committed to that same approach in 2016, given the continued weakness in commodity prices.

Over the past 12 months, both spot natural gas and oil prices have decreased a further 30% to 40%, meaningfully impacting the economics of our key plays. However, strength in the forward curve beyond 2016 enhances those economics with the timing of capital expenditures being key to higher returns. This commodity price environment is also placing further downward pressure on service costs through reductions in capital budgets, while creating acquisition opportunities that are competing favourably with our E&D program. To be successful in the current economic environment, we will remain flexible with our 2016 capital program spending between $145 million and $190 million. We will target the lower end of this range as our base E&D budget, but will be prepared to increase spending on E&D activities should commodity prices strengthen. This flexibility will allow us to reinforce our financial position and/or take advantage of acquisition opportunities that compete favourably with our key play economics. This budget is expected to result in production between 69,000 and 73,000 boe per day. In addition, effective April 1, 2016, our Board of Directors has approved a 67% reduction in the dividend to $0.01 per share per quarter. Using the base E&D budget of $145 million our total payout ratio for 2016 will be approximately 70%, with the remaining funds, approximately $70 million, being applied to our long-term debt.

Operational and financial accomplishments for 2015 include:

• Decreased fourth quarter operating costs by 21% to $5.85 per boe, and annual operating costs by 20% to $6.60 per boe;
  
  
• Reduced F&D costs by 33% to $7.26 per boe on a proved plus probable basis, including changes in future development costs ("FDC"), resulting in a recycle ratio of 2.2:1;
  
  
• Replaced 91% of production with proved developed producing reserve additions, while spending only 75% of our funds from operations, despite the loss of 10.3 mmboe resulting from the price-related acceleration of economics cutoffs;
  
  
• Executed a capital spending program, including acquisitions and divestitures ("A&D") of $283.4 million, a 47% reduction relative to 2014. Exploration and development ("E&D") activities totaled $313.9 million, drilling 78 (70.1 net) wells as compared to $639.6 million in E&D activities drilling 134 (111.6 net) wells in 2014. Dispositions, net of acquisitions were approximately $30.6 million in 2015;
  
  
• Generated funds from operations of $95.8 million ($0.44 per share) in the fourth quarter of 2015, a period where realized commodity prices decreased by 23% on a per boe basis and overall production revenues decreased by 44% respectively, when compared to the fourth quarter of 2014;
  
  
• Produced 79,862 boe per day in the fourth quarter and 79,288 boe per day in 2015 resulting in three percent growth relative to 2014, notwithstanding a 47% reduction in capital spending;
  
  
• Removed 14% of our inactive wells and 20% of our abandoned but unreclaimed wells year-over-year;
  
  
• Extended our existing bank credit facility of $600 million to a maturity date of September 10, 2019; and
  
  
• Enhanced our commodity hedges resulting in a current portfolio of:
  
  
  • Approximately 228,500 gjs per day of natural gas hedged at an average floor price of $3.16 per gj at AECO for 2016 and approximately 121,822 gjs per day at an average floor price of $3.09 per gj for 2017;
    
    
  • Approximately 2,700 bbls per day of oil hedged at an average floor price of CDN$78.95 per bbl WTI for 2016 and approximately 250 bbls per day at an average floor price of CDN$90.47 per bbl WTI for 2017; and
    
    
  • 1,875 bbls per day of propane hedged at 46% of US WTI pricing for 2016 and 1,000 bbls per day at 40% of US WTI pricing for the first quarter of 2017.
    
    
  • Using the midpoint of our production guidance for 2016, Bonavista has approximately 64% of volumes hedged and approximately 23,000 boe per day hedged for 2017.
    
    

2015 Acquisition and divestiture highlights:

• Completed 19 property transactions resulting in divestments, net of acquisitions, of approximately 2,200 boe per day of non-core high cost assets. The disposed assets had operating costs in excess of $15.00 per boe.

2015 FOURTH QUARTER AND ANNUAL CORE AREA HIGHLIGHTS

WEST CENTRAL CORE AREA

Our West Central core area draws its strength from a low capital cost structure, resilient economics and consistent results. In 2015, we continued to enhance our execution improving our cost structure in the Glauconite and achieved excellent results from our Morningside drilling program. With over 900,000 net acres and approximately 800 drilling locations in our key plays, our West Central core area represents both reliable, low risk drilling opportunities and promising new key plays. We have built an extensive network of infrastructure including 2,800 kilometers of pipelines and 38 facilities, the majority of which are operated by Bonavista, to support our continued development of this core area.

In 2015, our E&D spending in this core area was $175.5 million, drilling 56 (48.2 net) wells resulting in production of approximately 48,300 boe per day. This stable production rate was achieved while spending only 77% of our operating income for 2015, demonstrating the sustainability of our West Central development program.

Our Glauconite play has been the foundation of this sustainability, while the future potential of our Falher play continues to impress.

Glauconite Natural Gas

We drilled 46 (38.2 net) horizontal wells in 2015 including four (4.0 net) in the fourth quarter resulting in fourth quarter production of approximately 26,200 boe per day.

Our capital costs have improved throughout the year, with the cost to drill and complete a "typical" Glauconite well improving by 25% to $2.3 million when compared to 2014, while operating costs have decreased to below $4.50 per boe in our Hoadley area. Reduced costs and enhanced execution has resulted in annual production addition costs of approximately $12,300 per boe per day, a 10% improvement relative to 2014. The continued strength of the Glauconite play was also demonstrated by the 2015 proved plus probable finding and development costs coming in at a record low $3.74 per boe.

We continue to evolve our completion techniques from nitrogen foam to slick water fracs at Hoadley, resulting in improved well performance. Slick water, when combined with longer reach horizontal wells, has outperformed our conventional type curve by 200% after 12 months of production performance. This is accomplished at a cost equal to approximately 165% of our conventional Glauconite horizontal well.

In 2015, the commissioning of the deep cut processing facility at Rimbey resulted in a potential 30 bbl per mmcf increase in natural gas liquids from the Glauconite play (mostly ethane and propane). Unfortunately though, the challenging price environment for natural gas liquids has resulted in the curtailment of 20% to 60% of our ethane production. Furthermore, with negative propane pricing, we have chosen to redirect some Glauconite production to a Bonavista operated process facility. The benefits of natural gas with higher heat content and a lower operating cost structure at this facility will result in incremental operating income despite the lower recovery rates and production rates realized utilizing this process.

The Glauconite play continues to showcase consistent results with resilient economics that rank amongst the top liquids rich natural gas plays in North America. Our inventory of approximately 370 locations allows for over 13 years of development at our current pace. Our 2016 program entails drilling 16 to 30 (14.2 to 25.5 net) wells.

Spirit River Falher Natural Gas

We drilled eight (8.0 net) Falher wells in 2015 including one (1.0 net) in the fourth quarter.

Our 2015 Morningside Falher program has exceeded our expectations. We drilled six (6.0 net) wells at Morningside and successfully extended the boundaries of the play to the south of our main development area. Our six wells drilled in 2015 demonstrated average production rates of approximately 700 boe per day in their first three months.

Our Morningside Falher play continues to compete equally for capital with our Hoadley Glauconite and Ansell Wilrich plays. With current costs to drill and complete of $2.0 million, annual production addition costs remain less than $8,000 per boe with IRR's in excess of 25% at current commodity prices.

Our 2016 Falher program includes drilling between seven to nine (6.5 to 8.5 net) wells.

DEEP BASIN CORE AREA

In 2015, we continued to expand our foot-print in this liquids-rich natural gas core area. We have established a net land position of approximately 295,000 acres and have increased our inventory through swap and acquisition transactions. We currently have over 300 horizontal drilling locations of which approximately 30% are extended reach. We built additional infrastructure in 2015 by installing a processing facility and a metering station, resulting in further operating cost reductions and incremental egress.

In 2015, we spent $114.8 million on E&D activities drilling 21 (20.9 net) wells. Production has averaged approximately 21,500 boe per day representing a 24% increase from the same period last year despite drilling 34% fewer wells.

Spirit River Wilrich Natural Gas

We drilled 18 (18.0 net) Wilrich wells in 2015 including four (4.0 net) in the fourth quarter, which were our first extended reach (approximately 1.5 mile lateral length) wells.

Improvements to our cost structure have made a significant impact to our economics at Ansell. The commissioning of our new processing facility and metering station in the second half of 2015 will result in operating costs below $3.00 per boe.

The average cost to drill and complete our fourth quarter Ansell wells was $4.9 million, representing an improvement of approximately 14% from the prior year period, despite two of these wells being extended reach horizontal wells. Our annual cost to add production at Ansell is currently $11,000 per boe per day, a 25% reduction from the same period in 2014.

During the second half of 2015, we continued expanding our Wilrich inventory at Ansell through a strategic land swap which added approximately 45 locations, the majority being extended reach wells.

Our 2016 program contemplates drilling between nine and 13 extended reach horizontal wells. We anticipate further economic enhancements driven by improved capital and operating efficiencies as we develop our extended reach program.

STRENGTHS OF BONAVISTA ENERGY CORPORATION

Throughout our nineteen year history, from an initial restructuring in 1997 to create a high growth junior exploration company, through the energy trust phase between July 2003 and December 2010, to a dividend paying corporation, Bonavista has remained committed to the same operating philosophies despite the endless commodity price volatility and uncertainty inherent in the energy sector. We have consistently maintained a high level of profitable investment activity on our asset base. This activity stems from the expertise of our people and their entrepreneurial approach to design profitable development projects with resilience to an unpredictable commodity price environment. Our experienced technical teams have a thorough understanding of our assets and the reservoirs within the Western Canadian Sedimentary Basin as they exercise the discipline and commitment required to deliver long-term value to our shareholders. The core operating and financial principles that guide our people have been with our organization from the beginning and remain solidly intact today.

As a result of our recent successful non-core disposition strategy, our production and development activity is now largely concentrated in two core areas in central Alberta. We create opportunity through undeveloped land purchases, asset swaps, acquisitions and farm-in opportunities in these areas. Specifically over the past five years, technology coupled with North American natural gas supply/demand fundamentals has led to numerous opportunities to reposition the asset portfolio and drastically improve the quality of our development projects. These activities have led to low cost reserve additions and a reliable production base. Today, the predictable production performance and optimized cost structure of our high quality asset base ensures operating netbacks that compete favorably in most operating environments. Furthermore, our assets are predominantly operated by us, providing control over the pace of operations and a direct influence over our operating and capital cost efficiencies.

Our team brings a successful track record of executing reliable development programs with consistency and precision. We continually strive for balance sheet flexibility and remain focused on prudent financial management. Our Board of Directors and management team possess extensive experience in the oil and natural gas business. They have successfully guided our organization through many different economic cycles utilizing a proven strategy underpinned with a set of consistent and reliable operating and financial principles. Directors, management and employees also own approximately 10% of the equity of Bonavista, aligning our interests with those of external shareholders.

OUTLOOK

Elevated world oil production and above average North American natural gas inventories will continue to weigh on our industry in 2016. These supply pressures and corresponding low commodity prices have resulted in a 73% drop in total operating U.S. oil and natural gas rigs to approximately 514 from a recent high of 1,931 in September 2014. Reduced drilling activity has impacted production, with North American oil production declining while world oil demand is forecasted to grow in 2016. All of these signals are constructive and support the beginning of a correction to the current imbalance between oil supply and demand.

We are well positioned to succeed through this environment. We are focused on improving our financial flexibility and will continue to rationalize non-core assets and concentrate our capital spending in two core areas. Our key plays in these core areas rank among the best economic performers in western Canada. We remain protected from further commodity price volatility with approximately 83% of our budgeted natural gas revenues and 64% of budgeted total production hedged for 2016 on a boe basis. In addition, our cost structure continues to improve, creating the opportunity to improve capital efficiencies throughout 2016. Lastly, we do not forecast a covenant breach on our long-term debt in 2016.

We intend to be flexible with our 2016 capital budget in light of uncertain commodity prices. This uncertainty will create opportunities with capital allocation and reinvestment timing and as such, we plan capital spending of between $145 and $190 million. This will generate production between 69,000 and 73,000 boe per day, focused on those projects generating at least a 20% IRR in the current commodity price environment. With our revised dividend commitment for 2016, we are targeting a total payout ratio of approximately 70% utilizing our base E&D budget guidance of $145 million, and intend to apply the remaining funds from operations, of approximately $70 million, to improve our balance sheet.

As always, we thank our employees for their tireless dedication and commitment to our vision and our shareholders for their support through these uncertain times. We are confident of our strategies and are backed by a resilient asset base that continues to provide value in this challenging environment.

BONAVISTA ENERGY CORPORATION
Supplemental Financial Information
Consolidated Statements of Financial Position
As at December 31			2015			2014
($ thousands) (unaudited)
Assets
Current assets
	Accounts receivable		70,278			102,840
	Prepaid expenses		8,333			9,525
	Marketable securities		102			814
	Other assets		14,104			19,358
	Financial instrument commodity contracts		66,213			140,271
	Financial instrument contracts		2,013			-
			161,043			272,808
Financial instrument commodity contracts			19,390			17,680
Financial instrument contracts			68,754			16,025
Property, plant and equipment			3,064,335			3,933,396
Exploration and evaluation assets			210,194			189,493
Total assets			3,523,716			4,429,402
Liabilities and Shareholders' Equity
Current liabilities
	Accounts payable and accrued liabilities		137,722			234,025
	Current portion of long-term debt		34,600			50,000
	Decommissioning liabilities		18,559			15,185
	Dividends payable		2,140			14,263
	Financial instrument commodity contracts		2,811			1,693
			195,832			315,166
Financial instrument commodity contracts			2,289			2,385
Long-term debt			1,231,031			989,671
Other long-term liabilities			10,742			12,412
Decommissioning liabilities			470,342			482,797
Deferred income taxes			65,214			269,265
			1,975,450			2,071,696
Shareholders' equity
	Shareholders' capital		2,716,011			2,514,006
	Exchangeable shares		94,550			272,900
	Contributed surplus		52,825			57,613
	Deficit		(1,315,120	)		(486,813	)
			1,548,266			2,357,706
Commitments
Total liabilities and shareholders' equity			3,523,716			4,429,402

BONAVISTA ENERGY CORPORATION
Supplemental Financial Information
Consolidated Statements of Income (Loss) and Comprehensive Income (Loss)
			Three months ended December 31							Years ended December 31
			2015			2014			2015			2014
($ thousands, except per share amounts) (unaudited)
Revenues
	Production		137,260			244,612			599,999			1,106,852
	Royalties		(11,389	)		(27,328	)		(54,201	)		(136,095	)
			125,871			217,284			545,798			970,757
	Realized gains (losses) on financial instrument commodity contracts		41,924			5,490			149,153			(65,232	)
	Unrealized gains (losses) on financial instrument commodity contracts		(14,231	)		185,148			(73,370	)		188,803
			153,564			407,922			621,581			1,094,328
Expenses
	Operating		43,000			58,239			190,889			232,474
	Transportation		9,023			9,556			36,500			36,013
	General and administrative		7,120			8,074			32,495			32,012
	Share-based compensation		4,057			2,608			17,157			20,449
	Gain on disposition of property, plant and equipment		586			(46,318	)		(19,946	)		(61,780	)
	Loss (gain) on disposition of exploration and evaluation assets		8,316			(1,614	)		(14,534	)		5,903
	Depletion, depreciation, amortization and impairment		649,232			404,949			1,168,016			670,510
			721,334			435,494			1,410,577			935,581
Income from operating activities			(567,770	)		(27,572	)		(788,996	)		158,747
	Finance costs		27,378			13,315			221,342			127,579
	Finance income		14,721			26,158			(54,742	)		(8,002	)
	Net finance costs		42,099			39,473			166,600			119,577
Income (loss) before taxes			(609,869	)		(67,045	)		(955,596	)		39,170
	Deferred income tax (recovery)		(155,253	)		(6,067	)		(204,051	)		34,323
Net income (loss) and comprehensive income (loss)			(454,616	)		(60,978	)		(751,545	)		4,847
Net income (loss) and comprehensive income (loss) per share
	Basic		(2.09	)		(0.28	)		(3.45	)		0.02
	Diluted		(2.09	)		(0.28	)		(3.45	)		0.02

BONAVISTA ENERGY CORPORATION
Supplemental Financial Information
Consolidated Statements of Changes in Equity
For the years ended December 31	Shareholders' Capital		Exchangeable Shares		Contributed Surplus		Deficit		Total Shareholders' Equity
($ thousands) (unaudited)
Balance as at December 31, 2013	2,228,210		307,468		61,247		(326,910	)	2,270,015
Net income and comprehensive income	-		-		-		4,847		4,847
Issuance of equity	200,860		-		-		-		200,860
Issue costs, net of future tax benefit	(6,280	)	-		-		-		(6,280	)
Issued for cash on exercise of stock options and common share incentive rights	4,154		-		-		-		4,154
Exercise of stock options and common share incentive rights	4,550		-		(4,550	)	-		-
Conversion of incentive and restricted share awards	21,721		-		(21,721	)	-		-
Tax effect on conversion of incentive awards	148		-		-		-		148
Share-based compensation expense	-		-		20,449		-		20,449
Share-based compensation capitalized	-		-		2,188		-		2,188
Issued pursuant to the dividend reinvestment and stock dividend plans	26,075		-		-		-		26,075
Exchangeable shares exchanged for common shares	34,568		(34,568	)	-		-		-
Dividends declared	-		-		-		(164,750	)	(164,750	)
Balance as at December 31, 2014	2,514,006		272,900		57,613		(486,813	)	2,357,706
Net loss and comprehensive loss	-		-		-		(751,545	)	(751,545	)
Conversion of incentive and restricted share awards	23,655		-		(23,655	)	-		-
Share-based compensation expense	-		-		17,157		-		17,157
Share-based compensation capitalized	-		-		1,710		-		1,710
Exchangeable shares exchanged for common shares	178,350		(178,350	)	-		-		-
Dividends declared	-		-		-		(76,762	)	(76,762	)
Balance as at December 31, 2015	2,716,011		94,550		52,825		(1,315,120	)	1,548,266

BONAVISTA ENERGY CORPORATION
Supplemental Financial Information
Consolidated Statements of Cash Flows
			Three months ended December 31						Years ended December 31
			2015			2014			2015			2014
($ thousands) (unaudited)
Cash provided by (used for):
Operating Activities
Net income (loss) and comprehensive income (loss)			(454,616	)		(60,978	)		(751,545	)		4,847
Adjustments for:
	Depletion, depreciation, amortization and impairment		649,232			404,949			1,168,016			670,510
	Share-based compensation		4,057			2,608			17,157			20,449
	Unrealized losses (gains) on financial instrument commodity contracts		14,231			(185,148	)		73,370			(188,803	)
	Loss (gain) on disposition of property, plant and equipment		586			(46,318	)		(19,946	)		(61,780	)
	Loss (gain) on disposition of exploration and evaluation assets		8,316			(1,614	)		(14,534	)		5,903
	Net finance costs		42,099			39,473			166,600			119,577
	Deferred income tax (recovery)		(155,253	)		(6,067	)		(204,051	)		34,323
Decommissioning expenditures			(3,281	)		(9,944	)		(18,925	)		(32,026	)
Changes in non-cash working capital items			21,364			2,388			(9,852	)		20,824
			126,735			139,349			406,290			593,824
Financing Activities
	Issuance of equity, net of issue costs		-			-			-			192,476
	Proceeds on exercise of stock options and common share incentive rights		-			15			-			4,154
	Dividends paid		(16,930	)		(42,711	)		(88,885	)		(137,499	)
	Interest paid		(23,240	)		(19,737	)		(48,946	)		(43,550	)
	Proceeds from long-term debt		-			454			94,935			-
	Repayment of long-term debt		(15,799	)		-			(28,357	)		(75,827	)
			(55,969	)		(61,979	)		(71,253	)		(60,246	)
Investing Activities
	Business acquisition		-			-			-			(141,062	)
	Exploration and development		(56,084	)		(162,155	)		(313,905	)		(639,560	)
	Property acquisitions		(1,572	)		(11,580	)		(69,576	)		(45,546	)
	Property dispositions		7,112			99,448			100,128			289,385
	Office equipment		(74	)		(449	)		(1,203	)		(3,018	)
	Changes in non-cash working capital items		(20,148	)		(2,634	)		(50,481	)		6,223
			(70,766	)		(77,370	)		(335,037	)		(533,578	)
Change in cash and cash equivalents			-			-			-			-
Cash and cash equivalents, beginning of year			-			-			-			-
Cash and cash equivalents, end of year			-			-			-			-

FORWARD LOOKING INFORMATION

Forward-Looking Statements - Certain information set forth in this document, including management's assessment of Bonavista's future plans and operations, contains forward-looking statements including: (i) forecasted capital expenditures and plans; (ii) exploration, drilling and development plans; (iii) prospects and drilling inventory and locations; (iv) anticipated production rates; (v) anticipated operating and service costs; (vi) our financial strength; (vii) incremental development opportunities; (viii) total shareholder return; (ix) asset acquisition and disposition plans; (x) growth prospects; (xi) sources of funding, which are provided to allow investors to better understand our business. By their nature, forward-looking statements are subject to numerous risks and uncertainties; some of which are beyond Bonavista's control, including the impact of general economic conditions, industry conditions, volatility of commodity prices, currency fluctuations, imprecision of reserve estimates, environmental risks, changes in environmental, tax and royalty legislation, competition from other industry participants, the lack of availability of qualified personnel or management, stock market volatility and ability to access sufficient capital from internal and external sources. Readers are cautioned that the assumptions used in the preparation of such information, although considered reasonable at the time of preparation, may prove to be imprecise and, as such, undue reliance should not be placed on forward-looking statements. Bonavista's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements or if any of them do so, what benefits that Bonavista will derive there from. Bonavista disclaims any intention or obligation to update or revise any forward-looking statements, whether as a result of new information, future events or otherwise, except as required by law.

Non-IFRS Measurements - Within management's discussion and analysis, references are made to terms commonly used in the oil and natural gas industry. Operating netbacks as presented does not have any standardized meaning prescribed by IFRS and therefore it may not be comparable with the calculation of similar measures for other entities. Operating netbacks equal production revenues and realized gains and losses on financial instrument commodity contracts, less royalties, operating and transportation expenses calculated on a boe basis. Total boe is calculated by multiplying the daily production by the number of days in the period. Management uses this term to analyze operating performance and leverage.

Additional IFRS Measurements - Within management's discussion and analysis, references are made to terms commonly used in the oil and natural gas industry. Additional IFRS measurements which are non-IFRS measurements that are referenced in the annual financial statements, do not have a standardized meaning prescribed by IFRS and therefore may not be comparable with the calculation of similar measures for other entities. Management uses "funds from operations" and the "ratio of net debt to funds from operations" to analyze operating performance and leverage. Funds from operations as presented is not intended to represent operating cash flow or operating profits for the period nor should it be viewed as an alternative to cash flow from operating activities, net income or other measures of financial performance calculated in accordance with IFRS. All references to funds from operations throughout this report are based on cash flow from operating activities before changes in non-cash working capital, decommissioning expenditures and interest expense. Basic funds from operations per share is calculated based on the weighted average number of common shares outstanding in accordance with International Financial Reporting Standards. Net debt is equal to bank debt and senior unsecured notes, net of adjusted working capital. Adjusted working capital excludes the current assets and liabilities from financial instrument commodity contracts. The annualized current quarter funds from operations is calculated as the current quarter funds from operations annualized for the year.

Conversion of Natural Gas to Barrels of Equivalent (BOE)

To provide a single unit of production for analytical purposes, natural gas production and reserves volumes are converted mathematically to equivalent barrels of oil (boe). We use the industry-accepted standard conversion of six thousand cubic feet of natural gas to one barrel of oil (6 Mcf = 1 bbl). The 6:1 boe ratio is based on an energy equivalency conversion method primarily applicable at the burner tip. It does not represent a value equivalency at the wellhead and is not based on either energy content or current prices. While the boe ratio is useful for comparative measures and observing trends, it does not accurately reflect individual product values and might be misleading, particularly if used in isolation. As well, given that the value ratio, based on the current price of crude oil to natural gas, is significantly different from the 6:1 energy equivalency ratio, using a 6:1 conversion ratio may be misleading as an indication of value.