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Athabasca Oil Corporation Announces 2019 Second Quarter Results


Athabasca Oil Corporation (TSX: ATH) (“Athabasca” or the “Company”) is pleased to report continued strong financial performance with its second quarter results. With its resilient business model, the Company is well positioned to generate free cash flow in 2019 and beyond.

2019 Second Quarter Highlights

Consolidated Quarterly Results

  • Production of ~34,000 boe/d (85% liquids)
  • Operating income of ~$82 million (excluding hedging)
  • Adjusted funds flow of ~$48 million ($0.09/share)
  • Free cash flow of ~$21 million with positive contributions from both Light Oil and Thermal Oil

Light Oil – High Margin Liquids Rich Returns

  • Production of ~10,200 boe/d (51% liquids)
  • Operating income of ~$26 million with a top decile netback of ~$27.50/boe
  • Strong initial Two Creeks Duvernay results unlock significant inventory within a shallower window of the Kaybob play; IP60 of ~725 bbl/d per well 16-29 pad and IP30 of ~725 bbl/d 5-19 pad
  • Simonette Duvernay pad on-stream with initial rates >2,000 boe/d per well (~90% liquids)

Thermal Oil – Low Decline Production

  • Production of ~23,800 bbl/d including downtime for maintenance at both assets
  • Operating income of ~$56 million; record division netback of ~$27/bbl (~$31/bbl at Leismer)
  • Leismer L7 sustaining pad commenced circulation with first production expected in Q4 2019

Financial Resiliency

  • Liquidity of ~$425 million (cash & available credit facilities); net debt of ~$240 million

2019 Outlook

Uniquely Positioned for Current Market Fundamentals

  • Annual capital guidance of ~$135 million focused on sustaining production for 2020
  • Low annual sustaining capital advantage of ~$9.50/boe; balanced H2 2019 activity includes drilling a four well Montney pad at Placid, drilling 13 Duvernay wells, a steam debottleneck project and NCG co-injection expansion at Leismer
  • Annual adjusted funds flow forecast of $155 million (US$60 WTI & US$17.50 WCS differentials)

Athabasca is a liquids-weighted intermediate producer with exposure to Canada’s most active resource plays (Montney, Duvernay, Oil Sands). The Company’s high quality, long life assets provide investors with unique exposure to free cash flow which, combined with focus on strong margin opportunities, drives shareholder returns. The Company has flexibility to direct sustainable free cash flow to debt reduction, share buy backs or capital projects.

Financial and Operational Highlights

  3 months ended June 30
6 months ended June 30
($ Thousands, unless otherwise noted) 2019 2018 2019 2018
CONSOLIDATED
Petroleum and Natural Gas Production (boe/d) 33,958 37,658 36,568 39,107
Operating Income1,2 $ 67,122 $ 46,719 $ 125,724 $ 63,595
Operating Netback1,2 ($/boe) $ 22.19 $ 13.01 $ 19.29 $ 8.80
Capital Expenditures $ 33,717 $ 54,159 $ 86,681 $ 136,420
Capital Expenditures Net of Capital-Carry1 $ 26,888 $ 38,888 $ 58,644 $ 95,549
   
LIGHT OIL DIVISION    
Petroleum and Natural Gas Production (boe/d) 10,210 11,872 10,957 11,187
Liquids (%) 51% 48% 52% 49%
Operating Income1 $ 25,637 $ 30,936 $ 56,917 $ 55,228
Operating Netback1 ($/boe) $ 27.59 $ 28.64 $ 28.70 $ 27.27
Capital Expenditures $ 11,858 $ 25,557 $ 41,713 $ 92,187
Capital Expenditures Net of Capital-Carry1 $ 5,029 $ 10,286 $ 13,676 $ 51,316
   
THERMAL OIL DIVISION    
Bitumen Production (bbl/d) 23,748 25,786 25,611 27,920
Operating Income1 $ 56,522 $ 39,635 $ 101,650 $ 32,891
Operating Netback1 ($/bbl) $ 26.97 $ 15.79 $ 22.42 $ 6.33
Capital Expenditures $ 21,859 $ 28,595 $ 44,968 $ 44,226
   
CASH FLOW AND FUNDS FLOW    
Cash Flow from Operating Activities $ 61,488 $ 27,605 $ 42,916 $ 24,364
per share – basic $ 0.12 $ 0.05 $ 0.08 $ 0.05
Adjusted Funds Flow1 $ 47,757 $ 25,680 $ 89,376 $ 19,320
per share – basic $ 0.09 $ 0.05 $ 0.17 $ 0.04
   
NET INCOME (LOSS) AND COMPREHENSIVE INCOME (LOSS)    
Net Income (Loss) and Comprehensive Income (Loss) $ 57,091 $ (19,267 ) $ 263,887 $ (112,597 )
per share – basic $ 0.11 $ (0.04 ) $ 0.51 $ (0.22 )
per share – diluted $ 0.11 $ (0.04 ) $ 0.50 $ (0.22 )
   
COMMON SHARES OUTSTANDING    
Weighted Average Shares Outstanding – basic 522,459,443 514,679,681 519,253,275 512,448,170
Weighted Average Shares Outstanding – diluted 527,661,455 514,679,681 525,417,016 512,448,170
   
As at ($ Thousands)     June 30
 2019
Dec. 31
 2018
LIQUIDITY AND BALANCE SHEET
Cash and Cash Equivalents $ 292,851 $ 73,898
Available Credit Facilities3 $ 131,264 $ 126,491
Capital-Carry Receivable (current & LT portion – undiscounted) $ 53,638 $ 81,675
Face Value of Long-term Debt4 $ 589,095 $ 614,070

 

1) Refer to the “Advisories and Other Guidance” section in the MD&A for additional information on Non-GAAP Financial Measures.
2) Includes realized commodity risk management loss of $15.0 million and $32.8 million for the three and six months ended June 30, 2019, respectively (June 30, 2018 – $23.9 million and $24.5 million).
3) Includes available credit under Athabasca’s Credit Facility and Unsecured Letter of Credit Facility.
4) The face value of the 2022 Notes is US$450 million. The 2022 Notes were translated into Canadian dollars at the June 30, 2019 exchange rate of US$1.00 = C$1.3091.

Business Environment

In December, the Alberta Government announced mandatory industry production curtailments starting in January 2019 to alleviate the high differential situation until additional egress is added. Following the announcement, the Western Canadian Select (“WCS”) heavy oil pricing outlook has significantly improved. WCS prices have averaged C$61.18 in H1 2019, a ~140% increase from C$25.36 in Q4 2018. Athabasca remains supportive of these actions and views them as a necessary step to normalize pricing and provide a bridge to permanent market access initiatives.

Industry crude by rail remains an important factor in managing differentials and Alberta inventories. Rail capacity continues to increase and base line utilization is expected to build through 2019 as long term contracts are operationalized.

The global heavy oil market continues to tighten with supply declines in Venezuela and Mexico, OPEC cuts and growing petrochemical demand. These changing dynamics are supporting heavy oil pricing benchmarks with US refineries in the PADD II and III regions requiring a heavier feedstock. The majority of onshore North American liquids production growth is light or condensate spec and slated for export to the international market. Athabasca is well positioned for this changing global supply dynamic with its Thermal Oil weighted production and long life reserve base.

Operations Update

Light Oil

Q2 2019 production averaged 10,210 boe/d (51% liquids). The division generated operating income of $25.6 million and maintained a top decile netback of $27.59/boe. Capital expenditures for the quarter were $5.0 million (net of capital carry).

The liquids rich Montney at Greater Placid (70% operated working interest) is positioned for flexible and efficient development. Robust project economics are supported by strong initial liquids yields (200 – 300 bbl/mmcf), low lifting costs and a ~200 well high graded inventory. Drilling will recommence this fall on a four well pad at 2-5-61-23W5 (“2-5”). The Company retains flexibility for completion timing and tie-in of two pads (11 wells).

The Greater Kaybob Duvernay program (30% non-operated working interest) remains robust and the partnership is executing a jointly approved 2019 budget of C$256 million gross (~C$20 million net of capital carry). Activity is focused on delineation at Two Creeks, Kaybob East and Kaybob West. Athabasca remains encouraged by continued strong production results across the volatile oil window.

At Two Creeks, two multi-well pads were recently brought on-stream with strong initial rates and high quality liquids (~41⁰API). 16-29-64-16-W5 (two well pad) had an IP30 of ~750 bbl/d and an IP60 of ~725 bbl/d per well. 5-19-64-16W5 (two well pad) had an IP30 of ~725 bbl/d per well. The Company sees significant long term potential at Two Creeks with exposure to approximately 45,000 acres in a shallower window of the play (~2,700m vertical depth) which is expected to drive lower well costs. The partnership recently completed a strategic land swap with an industry major, capturing 31 sections of consolidated acreage between Kaybob East and Two Creeks in exchange for nine non-core sections.

At Kaybob West, a significant northern step-out 16-25-65-20W5 had a facility restricted IP30 of ~800 bbl/d with an IP120 of ~700 bbl/d.

At Simonette, a three well pad 8-3-64-24W5 was recently tied into third party infrastructure. The first two wells had an average IP14 of ~2,050 boe/d (91% liquids) per well and the third well is expected to be placed on production during Q3 2019.

By the end of this year Athabasca believes the majority of the Duvernay acreage (six areas across ~210,000 gross acres) will be de-risked from a resource appraisal perspective and the partnership will be in a position to high-grade development opportunities thereafter. Athabasca remains protected into 2020 with a current capital carry balance of $53.6 million ($238 million gross expenditures).

Thermal Oil

Q2 2019 production averaged 23,748 bbl/d. Production was impacted by facility maintenance activities and recovery from curtailed production in Q4 2018 and Q1 2019 as a response to the unprecedented WCS differential environment (~1,000 bbl/d impact to annual average). As such, the Company anticipates Thermal Oil production to trend on the lower end of its annual guidance.

The division generated operating income of $56.5 million with a record operating netback of $26.97/bbl ($31.07/bbl at Leismer and $18.04/bbl at Hangingstone). The Company’s realized bitumen price averaged $55.58/bbl, supported by a US$10.67 WCS differential during the quarter and lower seasonal blending requirements. Capital expenditures for the quarter were $21.9 million.

At Leismer, Athabasca rig released the L7 sustaining pad earlier in the year. L7 is the first sustaining pad drilled since acquiring the asset in early 2017 and includes five well pairs with ~1,250m laterals (50% longer than prior wells). The Company commenced well pair circulation in June with first production expected in Q4 2019. The upcoming winter program will include completion of a steam debottleneck project, expansion of non-condensable gas co-injection across the field and long lead initiatives aimed at maintaining base production.

Risk Management and Balance Sheet

Athabasca has protected a base level of capital activity through its risk management program while maintaining cash flow upside to the current pricing environment. For H2 2019, the Company has hedged 14,000 bbl/d of apportionment protected volumes with a WCS floor price of ~C$52.50 and an additional 2,000 bbl/d of WCS differentials at ~US$20. The Company has also secured 8,000 bbl/d of direct refinery sales for 2020. The hedging program targets up to 50% of near term corporate production and Athabasca will layer on additional protection to support its 2020 capital plans through the fall.

The Company has access to 130,000 bbl of storage at Edmonton to manage and optimize product sales. Athabasca has secured long term egress to multiple end markets with 25,000 bbl/d of capacity on TC Energy Keystone XL and 20,000 bbl/d of capacity on the Trans Mountain Expansion Project.

Athabasca maintains a strong financial position with liquidity of $424 million (cash and available credit facilities) and a Duvernay capital carry balance of $53.6 million. The Company’s term debt is in place until 2022 with no maintenance covenant and the $120 million undrawn reserve based credit facility was recently reaffirmed by the banking syndicate.

Outlook and Drive to Free Cash Flow

Athabasca’s 2019 capital guidance of ~$135 million is focused on sustaining production for 2020. The Company maintains a low annual sustaining capital advantage of ~$9.50/boe. Balanced H2 2019 activity includes drilling a four well Montney pad at Placid, drilling 13 Duvernay wells, a steam debottleneck project and NCG co-injection expansion at Leismer. Annual adjusted funds flow is forecast at $155 million (US$60 WTI & US$17.50 WCS differential for the balance of 2019). The Company has flexibility to direct sustainable free cash flow to debt reduction, share buy backs or capital projects.

2019 Guidance Full Year
CORPORATE (net)
Production (boe/d) 37,500 – 40,000
Capital Expenditures ($MM) $135
LIGHT OIL (net)
Production (boe/d) 10,000 – 11,000
Capital Expenditures ($MM) $35
THERMAL OIL (net)
Production (bbl/d) 27,500 – 29,000
Capital Expenditures ($MM) $100
ADJUSTED FUNDS FLOW SENSITIVITY1 ($MM)
US$60 WTI / US$17.50 WCS diff $155
US$65 WTI / US$17.50 WCS diff $175
1) Funds flow sensitivity includes H1 2019 actuals, current hedging and flat pricing assumptions for the remainder of 2019 (US$10 MSW differential, US$5 C5 differential, C$1.50 AECO, 0.75 C$/US$ FX).

About Athabasca Oil Corporation

Athabasca Oil Corporation is a Canadian energy company with a focused strategy on the development of thermal and light oil assets. Situated in Alberta’s Western Canadian Sedimentary Basin, the Company has amassed a significant land base of extensive, high quality resources. Athabasca’s common shares trade on the TSX under the symbol “ATH”. For more information, visit www.atha.com.

For more information, please contact:
Matthew Taylor
Vice President, Capital Markets and Communications
1-403-817-9104
mtaylor@atha.com



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