St Stron rong Fou
- undatio
tions and Financial Discipl pline in a Vol
- latile Enviro
ronment
TSX: AAV AAV Inv nvestor Presentation Ap April 2020
St Stron rong Fou oundatio tions and Financial Discipl pline in - - PowerPoint PPT Presentation
St Stron rong Fou oundatio tions and Financial Discipl pline in a Vol olatile Enviro ronment Inv nvestor Presentation TSX: AAV AAV Ap April 2020 Adv Advantage at at a a Gla lance TSX 52-week tra rading range $0.9 .98 to $2.9
St Stron rong Fou
tions and Financial Discipl pline in a Vol
ronment
TSX: AAV AAV Inv nvestor Presentation Ap April 2020
2
Advan anta tage ho holds 134,4 ,400 ne net t acre res s (210 10 ne net t sec ections) ) in n the he cond ndensa sate/light oil-rich Mo Montn tney Glac acier/ r/Pipesto tone fairw rway ay
Notes: (1) Forward-looking information. Refer to Advantage news release dated January 8, 2020 and Advisory for material assumptions and risk factors.
TSX 52-week tra rading range $0.9 .98 to $2.9 .94 Shar ares s Outst Outstan anding (basi asic) 187 mi million Ma Mark rket Cap apitaliza zation $300 mi million Ent nterp rpris rise Valu alue $600 mi million 2020 Gui uidance (1) Cap apital – H1 H1 $100 mil million Cap apital – H2 H2 Significant flexibility Tota tal Production 45,000 to 47,500 boe/d Q1 Liquids Production ~3,6 ,600 bbls/d /d
Adv Advantage at at a a Gla lance
Advantage Montney Assets
Pipestone/ WembleyHigh gh Qual ality Light ght Oi Oil Pr Prolific Ga Gas Fo Foun undation Low-Cost st Own Owned Infras astruc ucture Disci scipline ned Fi Financ nancial al Mana nagement nt
De Deep inventory ry of high h retur urn n resource urce Found undatio ion n of free cash genera ratio ion Co Contro roll lled, , effic icie ient nt, , innovativ ive Se Self f fund nded growth
Esta tablish sh a stro trong liquids platf atform rm Sust ustain and nd rei einvest st in n hi highest IRR projects ts Complete key oil infra rastru ructure re projects Targ rget D/ D/AF AFF F rati tio ret eturn rning to 2x
3
20 2020 Str Strategy: Establis ish Liquid ids Platfo form, , Rein Reinfo force Gas Gas Foundations
Top Top-Tier Res Resources an and Cos Cost t Stru Structure For For A A Stro Strong Fou Foundati tion
Deli liver Sustai ainable Adju justed Funds Flow Gro Growth
Re Relentle tless ss Focu cus s on n As Asse set t Qua ualit ity and nd Cost st St Struct cture In In-Depth th Fund undamenta tals ls and nd Ri Risk k Ma Mana nagement nt Foun undatio tion n of Fina nancia cial l St Stabili ility ty Contin ntinuo uously sly Evolv lving ing, , Ad Adaptin ting and nd Competin ting
Tactical Elements
Foc
ial l Discipli line While ile Mar arkets ar are e Vola latile
4
Sha Shareholder-Focused Stra Strategy for
the New ew Ene nergy Mar arket
Cle lean Sustainable Energy High Quali ality Li Liquids Proli lific ic Ga Gas Foundatio ion Lo Low-cost Ow Owned Infras astructure Re Resili ilient In All ll Cycl cles Disciplin ined Financia ial Man anagement
5
Aggre regat ate Ind ndependent ESG Score res
Sources: ESG Scores are aggregation of Yale Environmental Performance Index, Social Progress Imperative and World Bank Governance Index; reserves from BP Statistical Review of World Energy 2019 based on government and published data; Canada Action. *Iraq scores unavailable“A Proud Clean Energy Producer – The World Needs More of Our Energy”
Ca Canada – Leading Jurisdiction for
Responsible le Energy Inve vestment
Cle lean Sustainable Energy High Quali ality Li Liquids Proli lific ic Ga Gas Foundatio ion Lo Low-cost Ow Owned Infras astructure Re Resili ilient In All ll Cycl cles Disciplin ined Financia ial Man anagement
57,4 ,410 56,99 ,999 90,3 ,367 113,8 ,835 2016 2017 2018 2019
Glacie ier r CO CO2 Se Seque uestra ratio ion Proje ject
(tonnes CO2e accredited)
6
114,000 tonnes CO2e equates to approx
(1) Based on estimates per Environmental Protection Agency emissions per vehicle (2) Independent study prepared by Envirosoft Corp. effective Jan 1 2020; Scope 1 and 2 emissions, net of Glacier sequestration credits
Advan anta tage is an n Env nviro ronmental, Social and Go Govern rnance (ESG) ) lead eader
atura ral gas s is the he best st way to red educe global CO2 emi emissi sions s by disp splacing coal al
ery low, in part due to carbon capture and storage at Glacier
Env nvironmental Leadership an and Sust Sustainabil ilit ity
Cle lean Sustainable Energy High Quali ality Li Liquids Proli lific ic Ga Gas Foundatio ion Lo Low-cost Ow Owned Infras astructure Re Resili ilient In All ll Cycl cles Disciplin ined Financia ial Man anagement
0.00 .0079 0.00 .0093 0.00 .0049 0.00 .0045 2016 2017 2018 2019
Advant ntage Ne Net Ca Carbon n Intens nsity ity(2)
2)(tonnes CO2e per BOE)
7
Low Cos Cost t Stru Structure Def efines Th The Com Competi titi tive Adv Advantage
Cle lean Sustainable Energy High Quali ality Li Liquids Proli lific ic Ga Gas Foundatio ion Lo Low-cost Ow Owned Infras astructure Re Resili ilient In All ll Cycl cles Disciplin ined Financia ial Man anagement
$- $5 $10 $15 $20 $25 $30 $35 $40 A Advantage C D E F G H I J K L M N O P Q R S T U V W X Y $/boe
Finance & Other G&A Operating & Transport Royalties
Sou
: 2019 Actual Costs per Scot
, April 3, 2020
Ba Balan ance sheet dri drive ves s pa pace of deve development Liqui quids s gr growth limited only y by by markets Stat ate of the art rt em emiss ssion
s en engi gine neering ng Fr Free ee cash sh rede edeployed to highe hest st IRR pr projects Two
ew oil ba batteries, s, ex exist sting ng ga gas s pl plant ant Ba Balanc anced com
s, market ex expos
ure
Cle lean Sustainable Energy High Quali ality Li Liquids Proli lific ic Ga Gas Foundatio ion Lo Low-cost Ow Owned Infras astructure Re Resili ilient In All ll Cycl cles Disciplin ined Financia ial Man anagement
8
Val alhal alla Pipest stone/ Wem Wembley
6 miles
Gl Glac acier Progre ress ss
Bal Balanced Co Commoditi ities Pr Profile file, , Po Poised Fo For Fl Flexib ibili ility ty & & Eff Efficie ient t Gro Growt wth
9
Adva vantage Operated HZ Offset Operator HZ Glacier liquids zones Valhalla liquids appraisal targets New oil pool discovery Wembley primary target
Adv Advantage Mon
ultiz izone Oil, Oil, Liq iquids an and Gas as Th Throughout
Cle lean Sustainable Energy High Quali ality Li Liquids Proli lific ic Ga Gas Foundatio ion Lo Low-cost Ow Owned Infras astructure Re Resili ilient In All ll Cycl cles Disciplin ined Financia ial Man anagement
10 10
Pipe peline ne conn nnected to Gl Glac acier r pl plan ant; up p to 2,000 bbl bbl/d d pi pipe peline ne capac acity
bbl/d ba battery y po post stpone ned pen pending ng market rec ecov
Production n began began Febr Februa uary y 2020 at res estricted rates s
16-36: IP3 P30 (re rest stricted) ) 1,149 49 bbl bbl/d (oil + NG NGL) ) + 6 mmcf/d ga gas @ @ 9,850 kPa Pa
Progress ss com
ve wi with h Wem Wembley/ Pi Pipe pest stone ne, and highe her netb etbac acks
16-36 Montney D3 2019 Discovery
1-11 New Drill – Q1 Completion 5-22 Montney D3 (2018) 13-31 Montney D1 (2017) Kelt Oil Wells Up to 153,000 bbls CTD Tourmaline Oil Wells Up to 152,000 bbls CTDTie in to AAV Glacier Plant
8-17 New Drill – Q1 Completion 2-34 Montney D3 (2018)Dev evelopment Upd pdate Pos Post t Lig ight Oil Oil Disc iscovery at at Pro Progress
Cle lean Sustainable Energy High Quali ality Li Liquids Proli lific ic Ga Gas Foundatio ion Lo Low-cost Ow Owned Infras astructure Re Resili ilient In All ll Cycl cles Disciplin ined Financia ial Man anagement
11 11
Wembley: y: pr predi dictable, top tier resul ults acros
s the fairway ay (150-300 300 bbl bbls/mmcf)
sults s include de restricted IP30 ra rates up p to 737 bbl bbls/d (oil + + NGL GL) )
dvant ntage Wem Wembley oil ba battery to be be commiss ssioned d Apr pril 2020; will reduc duce capac acity const
aints
rrent ntly 4 4 wel ells s shut ut in awai aiting ng capac acity
dvant ntage Val alhal halla pr prod
uction n cont ntinue nues to be be restricted du due to cont ntinue nued outperfor
nce of wells
Valhalla Pipe peston
Pi Pipe pesto tone/Wemble ley/V /Valhall lla Oil Oil an and Liq iquids Dev evelopment
Cle lean Sustainable Energy High Quali ality Li Liquids Proli lific ic Ga Gas Foundatio ion Lo Low-cost Ow Owned Infras astructure Re Resili ilient In All ll Cycl cles Disciplin ined Financia ial Man anagement
12 12
Mont
ney D4 4 Tier er 1 Half-cycle Econo
(March 18 Str trip ip; 2021 avg vg AEC ECO C$2.09/g /gJ & US$ S$31.64/b /bbl l WTI) I)
Type We Well Rate of Retur urn Payout ut 11.6 6 Bcf, , 32 32 bbl/mmcf 60% 60% 1.7 7 years rs
ly dev evelo lopme ment was s in Up Upper and Lowe wer Mo Montney; ultra-lo low co cost lean ean gas s with res esil ilie ient net etbac acks ks
ecent focus s on Mi Middle le Mo Montney (25-80 bbls/ ls/mmcf) f)
s rates s up to 400 00 bbls ls/d
s rates es up to 17 mm mmcf/d cf/d
Montney D3 (L3) Montney D2 (L4) Montney D4 (L2) (1) Management estimates. Rate of Return is assuming initial capital of $6.6 million per wellDCE+T and 1.5% escalation Q1 1 2019 19 10 Well Middle Montney Pad – Average Final Rate 422 bbls/d per Well (73 73 bbls/mmcf) Q4 2018 5 Well Middle Montney y Pad – Average Final Rate 428 bbls/d per Well (85 bbls/mmcf)
Liq iquids-Rich Mid iddle Mon
at Gla lacier Ste Stepping Up
Cle lean Sustainable Energy High Quali ality Li Liquids Proli lific ic Ga Gas Foundatio ion Lo Low-cost Ow Owned Infras astructure Re Resili ilient In All ll Cycl cles Disciplin ined Financia ial Man anagement
BC C AB
TCPL Groundbirch Lateral 6 milesmmcf/d + 6,800 bbl bbl/d capacity Gl Glac acier Plan ant; t; >120 mmc mmcf/d surp urplus capacity avai ailable
mmcf/d + 2,000 bbl bbl/d Valh alhal alla hu hub
mmcf/d + 5,000 bbl bbl/d Wem Wembley hu hub
mmcf/d + 5,000 bbl bbl/d Progre ress ss hu hub on n ho hold 100% Ow Owned Glac acier r Gas s Plan ant
13 13
Stra Strategic Infr nfrastructure Co Contr trol, l, Flex Flexible le Pi Pipe peline Acc Access
Cle lean Sustainable Energy High Quali ality Li Liquids Proli lific ic Ga Gas Foundatio ion Lo Low-cost Ow Owned Infras astructure Re Resili ilient In All ll Cycl cles Disciplin ined Financia ial Man anagement
14 14
27 MMcf/d of TC Prairies Mainline e to Nov 2032 54 MMcf/d of AEC ECO O to Dawn LTFP Capacity to Nov 2032 Up to 48 MMcf/d of net Empress capacity – varying term durations
Nat atural Gas as Tra Transport rtati tion Por Portfolio io
Cle lean Sustainable Energy High Quali ality Li Liquids Proli lific ic Ga Gas Foundatio ion Lo Low-cost Ow Owned Infras astructure Re Resili ilient In All ll Cycl cles Disciplin ined Financia ial Man anagement
15 15
Physical Flows
Q1 Q1-20 20 Q2 Q2-20 20 Q3 Q3-20 20 Q4 Q4-20 20 2021 2022-2027 AECO CO 63% 63% 50% 50% 47% 7% 26% 26% 15% 15% 26% - 50% 50% Empr mpress 0% 0% 0% 0% 0% 0% 7% 7% 13% 10% - 20% Emerson
C Prairies Mainline) 21% 22% 22% 23% 23% 30% 30% 34% 29% - 32% 32% U.S.
dwest 16% 28% 28% 30% 30% 37% 38% 38% 10% - 22%
Mar arket He Hedging Act Activ iviti ties
0% 5% 10% 15% 20% 25% 30% 200 400 600 800 1000 1200 Q1-20 Q2-20 Q3-20 Q4-20
Current Crude Oil Hedging (bbls/d)
WTI ($US/bbl) % of Liquids Production Hedged $57.91 $56.53 $55.44 $55.44
Cle lean Sustainable Energy High Quali ality Li Liquids Proli lific ic Ga Gas Foundatio ion Lo Low-cost Ow Owned Infras astructure Re Resili ilient In All ll Cycl cles Disciplin ined Financia ial Man anagement
0% 10% 20% 30% 40% 50% 60% 70% 20 40 60 80 100 120 140 160 Q1-20 Q2-02 Q3-20 Q4-20 Q1-21Current Natural Gas Hedging
(MMcf/d) Henry Hub AECO Dawn Chicago % of Production Hedged $2.30 $2.30 $2.30 $2.30 $2.57 $2.26 $3.16 $1.49 $1.49 $1.49 $1.76 $1.76 $2.08 $2.51 $2.51 $2.5517
199 123 25 25
89 89 74 743 301 301
<25 bbls/mm mmcf 25-1
bbls/mmcf >100 bb bbls/mmcf
Deep Liquids-Ric ich Invento tory (1)(2)(3)
Bo Book
ed Undev evel elope ped Unboo
Upside de
18 18
le Montne ney is liquid uids-ric ich h throug ugho hout ut (25 25 to 28 280 0 bbls/mmcf) f)
– 400 mmcf/d raw gas capacity, 6,800 bbls/d liquids handling
Liquids-rich Middle Montney
TOT OTAL L future location inventory ~1,400 to 1,500
Glacie ier Pipestone ne/ We Wemble ley Va Valha hall lla Progre ress
Are Area Ove Overvie iew – Shift Shifting to to Mid iddle le Mon
iquids
(1) Management Estimates. Refer to Advisory. (2) Based on Sproule December 31, 2019 Reserves Report. (3) C3+ shallow cut recoveries.Forward-Lo Looking Information and Statements The information in this presentation contains certain forward-looking information and forward-looking statements (collectively, "forward-looking statements") within the meaning of applicable securities laws relating to the Corporation's plans and other aspects of its anticipated future operations, management focus, strategies, financial, operating and production results and business opportunities. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. The statements have been prepared by management to provide an outlook of the Corporation's activities and results and may not be appropriate for other
“expect”, “may”, “can”, “will”, “project”, “predict”, “potential”, “target”, “intend”, “could”, “might”, “should”, “believe”, “would” and similar expressions and include statements relating to, among other things, the Corporation's estimated net capital expenditures for 2020, including the expected allocation and timing of such expenditures and the anticipated effect of such expenditures on revenue; the development focus of the 2020 estimated capital expenditures and the anticipated timing thereof; the anticipated effect of net capital expenditures on liquids production, including the estimated amount of such production; expected focus and results to be derived from the 2020 capital budget, including, but not limited to, increasing annual liquids production and the anticipated amount thereof, diversifying the Corporation's revenue sources and developing additional operational and infrastructure capability and how this will be achieved; the expected amount by which revenues from liquids production will increase in 2020 and 2021 as a percentage of total revenue; the expected amount of average production in 2020, including the expected amount of gas production and liquids production; expectations that the owned Glacier gas plant has capacity to accommodate future growth and provide third party processing opportunities; the anticipated timing of wells being brought on production; drilling and development plans for 2020; anticipated disruptions to production while the oil battery at Pipestone/Wembley is being completed, the expected timing of such completion and the anticipated effect of such battery on performance and production; anticipated timing of production from certain wells at Pipestone/Wembley; the expected timing of completion of commissioning an oil battery at Progress and the tie-in of the Progress asset to Advantage's existing Glacier pipeline system; resource development potential of the Corporation's assets and the Corporation's future drilling inventory; the benefits derived from third party processing arrangements the Corporation entered into with two midstream firms; the Corporation's plans to continue to be a low-cost supplier of natural gas, condensate and light oil and to grow adjusted funds flow per share, increase free cash generation and strengthen netback margins; and other matters. Advantage’s actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them. With respect to the forward-looking statements contained in this presentation, Advantage has made a number of material assumptions regarding, but not limited to: current and future commodity prices; the Corporation's current and future hedging program; future exchange rates; future production and composition including natural gas and liquids; royalty regimes and future royalty rates; future operating costs; future transportation costs and availability of product transportation capacity; future general and administrative costs; the estimated well costs including frac stages and lateral lengths per well; the number of new wells required to achieve the objectives of the 2020 budget; that the Corporation will be able to complete its infrastructure projects on a timely basis; the timing for the construction to be completed on third party mid-stream facilities; timing and amount of net capital expenditures; and that the Corporation will have sufficient financial resources required to fund its capital and operating expenditures and requirements as needed.
19 19
Adv Advisory
Management has included the summary of assumptions and risks related to forward-looking information in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage’s actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive. The Corporation and management believe that the statements have been prepared on a reasonable basis, reflecting management's best estimates and judgments. However, because this information is highly subjective and subject to numerous risks including the risks discussed above, it should not be relied on as necessarily indicative of future results. These forward- looking statements are made as of the date of this presentation and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage’s control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; impact of significant declines in market prices for oil and natural gas; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions; Advantage's success at acquisition, exploitation and development of reserves; failure to achieve production targets on timelines anticipated or at all; unexpected drilling results; risk and assumptions used in estimating the 2020 budget, including commodity prices, timing of expenditures and the focus of such expenditures, change from current expectations; risk that the Corporation does not achieve the anticipated increases to production and revenues expected from the 2020 capital budget; changes in commodity prices, currency exchange rates, net capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; individual well productivity; lack of available capacity on pipelines; delays in anticipated timing of drilling and completion of wells; delays in completion of infrastructure; lack of available capacity on pipelines; individual well productivity; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; our ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many
www.advantageog.com.
20 20
Adv Advisory
Oil and Gas Gas Information Barrels of oil equivalent ("boe") and thousand cubic feet of natural gas equivalent ("mcfe") may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value. This presentation discloses drilling inventory in the Glacier, Valhalla, Progress and Pipestone/Wembley areas in three categories: (i) proved locations; (ii) probable locations; and (iii) unbooked locations. Proved locations and probable locations are derived from Sproule Associates Limited reserves evaluation effective December 31, 2019 and account for drilling locations that have associated proved and/or probable reserves, as applicable. Unbooked locations are internal estimates based on our prospective acreage and an assumption as to the number of wells that can be drilled per section based on industry practice and internal review. Unbooked locations do not have attributed reserves or resources. Of the 1,400 to 1,500 total drilling locations identified herein, 309 are proved locations, 38 are probable locations and 1,053 to 1,153 are unbooked locations. Unbooked locations have been identified by management as an estimation of our multi-year drilling activities based on evaluation of applicable geologic, seismic, engineering, production and reserves information. There is no certainty that the Corporation will drill all unbooked drilling locations and if drilled there is no certainty that such locations will result in additional oil and gas reserves, resources or
prices, costs, actual drilling results, additional reservoir information that is obtained and other factors. While certain of the unbooked drilling locations have been de-risked by drilling existing wells in relative close proximity to such unbooked drilling locations, other unbooked drilling locations are farther away from existing wells where management has less information about the characteristics of the reservoir and therefore there is more uncertainty whether wells will be drilled in such locations and if drilled there is more uncertainty that such wells will result in additional oil and gas reserves, resources or production. References in this presentation to production test rates, initial production rates, IP30 rates, flow rates, yields and other short-term production rates are useful in confirming the presence
performance or of ultimate recovery. Additionally, such rates may also include recovered "load oil" fluids used in well completion stimulation. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production of Advantage. Advantage cautions that the test results should be considered to be preliminary. Advantage has presented certain type curves and well economics for its Montney areas. The type curves presented are based on Advantage's historical production. Such type curves and well economics are useful in understanding management's assumptions of well performance in making investment decisions in relation to development drilling in the Montney area and for determining the success of the performance of development wells; however, such type curves and well economics are not necessarily determinative of the production rates and performance of existing and future wells and such type curves do not reflect the type curves used by our independent qualified reserves evaluator in estimating our reserves volumes. The type curves differ as a result of varying horizontal well length, stage count and stage spacing. The type curves represent the average type curves expected. In this presentation, estimated ultimate recovery represents the estimated ultimate recovery associated with the type curves presented; however, there is no certainty that Advantage will ultimately recover such volumes from the wells it drills.
21 21
Adv Advisory
In presenting such type curves, inputs and economics information and in this presentation generally, Advantage has used a number of oil and gas metrics which do not have standardized meanings and therefore may be calculated differently from the metrics presented by other oil and gas companies. Such metrics include DCE+T, "EUR", "NPV10", "payout", "rate of return" (or "ROR"), "half cycle ROR", and “operating netback". EUR represents the estimated ultimate recovery of resources associated with the type curves presented. NPV10 represents the anticipated net present value of the future net revenue discounted at a rate of 10% associated with the type curves presented. Payout means the anticipated years of production from a well required to fully pay for the DCE+T of such well. ROR means the rate of return of a well or the discount rate required to arrive at a NPV equal to zero. Half cycle ROR means the rate of return of a well or the discount rate required to arrive at a NPV equal to zero when taking into account "half cycle" costs, which include drilling, completion, equip and tie-in capital expenditures. Production estimates contained herein are expressed as anticipated average production over the calendar year. In determining anticipated production for the years ended 2019 to 2021 Advantage considered historical drilling, completion and production results for prior years and took into account the estimated impact on production of the Corporation’s 2019 to 2021 expected drilling and completion activities. Non-GAAP Measures The Corporation discloses several financial and performance measures that do not have any standardized meaning prescribed under International Financial Reporting Standards ("IFRS"
funds flow”. Such financial and performance measures should not be considered as alternatives to, or more meaningful than measures determined in accordance with GAAP including “net income”, “comprehensive income”, “cash provided by operating activities”, or “cash used in investing activities”. Management believes that these measures provide an indication of the results generated by the Corporation’s principal business activities and provide useful supplemental information for analysis of the Corporation’s operating performance and liquidity. Advantage’s method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. “Net capital expenditures” include total capital expenditures related to property, plant and equipment and exploration and evaluation assets incurred during the period. Management considers this measure reflective of actual capital activity for the period as it excludes changes in working capital related to other periods. The Corporation considers “adjusted funds flow” to be a useful measure of Advantage’s ability to generate cash from the production of natural gas and liquids, which may be used to settle outstanding debt and obligations, and to support future capital expenditures plans. Changes in non-cash working capital are excluded from adjusted funds flow as they may vary significantly between periods and are not considered to be indicative of the Corporation’s operating performance as they are a function of the timeliness of collecting receivables or paying payables. Expenditures on decommissioning liabilities are excluded from the calculation as the amount and timing of these expenditures are unrelated to current production, highly variable and discretionary. “Net debt” is the total of bank indebtedness and working capital deficit. “Net debt to adjusted funds flow” is a ratio calculated as net debt divided by adjusted funds flow for the previous four
www.sedar.com and www.advantageog.com, for additional information about certain financial measures, including reconciliations to the nearest GAAP measures, as applicable.
22 22
Adv Advisory
23 23
Abbreviations The following abbreviations used in this presentation have the meanings set forth below. bbl barrel bbl/d barrel per day bbls/d barrels per day bbls/mmcf barrels per million cubic feet boe barrels of oil equivalent of natural gas, on the basis of one barrel of oil or natural gas liquids for six thousand cubic feet of natural gas boe/d barrels of oil equivalent per day GJ Gigajoule mcf thousand cubic feet Mcfe thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or natural gas liquids mmcf/d million cubic feet per day mmcfe/d million cubic feet equivalent per day NGL natural gas liquids DCE+T drill, complete, equip and tie-in C3+ propane plus C5+ pentanes plus
Adv Advisory
Inv nvestor r Rel elations
1.866.393.0393 ir@advantageog.com www.advantageog.com Listed on TSX: AAV
Advan anta tage Oi Oil & Gas s Ltd.
Suite 2200, 440 – 2nd Avenue SW Calgary, Alberta T2P 5E9 Main: 403.718.8000 Facsimile: 403.718.8332
Andy Mah, ah, P.Eng ng. Director, Chief Execut utive Of Officer Mike ke Belenki kie, P.Eng ng. Pr Presi esident nt & Chief Oper Operat ating ng Of Officer Craig Blackwood, CPA, A, CA Chief Fi Finan ancial al Off Officer
Advantage 100% W.I. Glacier Gas Plant
Adv Advantage Con Contact t Info nformation