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Ikkuma Resources Corp. Announces Third Quarter 2017 Financial Results and Update on Foothills Acquisition

CALGARY, Nov. 23, 2017 /CNW/ - Ikkuma Resources Corp. ("Ikkuma" or the "Corporation") (TSXV: IKM) is pleased to report its financial and operating results for the three and nine months ended September 30, 2017.  Selected financial and operational information is set out below and should be read in conjunction with Ikkuma's interim condensed financial statements and the related management's discussion and analysis ("MD&A") for the three and nine months ended September 30, 2017.  Ikkuma's condensed interim financial statements and MD&A are available for review at www.sedar.com and on the Corporation's website at www.ikkumarescorp.com.

Ikkuma Resources Corp. (CNW Group/Ikkuma Resources Corp.)

The Corporation's operating netback in the third quarter of 2017 was eroded by natural gas prices and scheduled seasonal facilities maintenance that took place in the summer months.  Quarterly results, however, are expected to be transcended in the future following the previously announced transformational Foothills Acquisition, which is expected to more than triple the size of the Corporation's production base and to materially increase cash flow per share.  The purchase price for the Foothills Acquisition was funded mostly by the sale of existing underutilized facilities for $20 million, see "Infrastructure Disposition" below.

ACQUISITION UPDATE

As previously announced, Ikkuma closed in escrow the acquisition of certain assets (the "Assets") located in the Alberta Foothills and British Columbia Deep Basin (the "Foothills Acquisition") on November 14, 2017.  The original purchase price of $34.0 million was adjusted to $29.7 million after the exercise of rights of first refusals ("ROFRs").  Notwithstanding the exercise of the ROFRs, the Corporation retained the majority of the anticipated upside of the Foothills Acquisition while the 13% reduction in the adjusted purchase price results in only a 3% decrease in production (approximately 420 BOE/d net), leaving a more accretive asset.

Asset Summary (adjusted for exercise of ROFRs)

Purchase Price ("PP")

($mm)

$29.7

Production(1)

(BOE/d)

13,850

PDP Reserves(1,2)

(mboe)

35,096

PDP NPV10% (BT)(1,2)

($mm)

$168,206

2P Reserves(1,2)

(mboe)

41,664

2P NPV10% (BT) (1,2)

($mm)

$202,503

Total Land

(acres)

396,720

 

Acquisition Metrics (Unadjusted for $20mm infrastructure sale)

PP/BOE/d(1)

$2,144

PP/ Operating Netback(3)

1.9x

PP/PDP BOE(2)

$0.85

PP/ PDP NPV10% (BT)(2)

0.2x

PP/2P BOE(2)

$0.71

PP/acre

$74.86

(1) Reflects current production.  Approximately 4,400 BOE/d of production for the Assets was shut-in by the vendor of the Assets (the "Vendor") in September 2017.  These reserves were included in the PDP volumes at YE2016 (GLJ Report), but the recent production shut-in will require reassignment of PDP reserves at YE2017.

(2) The Foothills Acquisition assets are based on the Deloitte Report and the GLJ Reports for YE2016. Before tax net present value based on a 10% discount rate and the Deloitte Price Forecast in respect of the Central Alberta Foothills Assets and the GLJ forecast prices in respect of the BC and Other Alberta Assets.  Reserves have been subtracted from the Deloitte Report with respect to exercise of ROFRs.

(3) Operating Netback are non-IFRS measures.  See "Non-IFRS Measures".  Operating netback for the Assets is an annualized estimate for the year ending December 31, 2017, based on recent lease operating statements provided by the Vendor using an estimated AECO natural gas price of $2.50/Mcf and assumes a 4% royalty rate, $13.29/BOE operating expenses (including transportation), and $10 million of sulphur revenue per year.  Operating netback for the Assets does not include the potential 10-30% field operational cost savings, which are expected to commence upon closing of the Foothills Acquisition.

The reserves data set forth above are based on an independent reserves evaluation of certain oil and gas assets in the Foothills area of Alberta (the "Central Alberta Foothills Assets"), effective December 31, 2016 (the "Deloitte Report") prepared by Deloitte LLP ("Deloitte") and  independent reserves assessments on the Assets other than the Central Alberta Foothills Assets (the "BC and Other Alberta Assets") effective December 31, 2016 (the "GLJ Reports") prepared by GLJ Petroleum Consultants Ltd. ("GLJ") for the Vendor.  The Deloitte Report is based on certain factual data supplied by the Vendor. Deloitte reviewed the land data provided by the Vendor as it related to any producing wells but accepted the working interest presented in the well lists as factual with no further review for the non-producing wells.  The GLJ Reports, as delivered by the Vendor, contain details regarding crude oil, natural gas liquids and natural gas reserves and the net present values before income tax of future net revenue using forecast prices and costs as set out in the GLJ Reports.  The GLJ Reports have been prepared in accordance with definitions, standards, and procedures contained in the Canadian Oil and Gas Evaluation Handbook and National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities ("NI-51-101").  The GLJ Reports are based on the GLJ Price Forecast, which is available on GLJ's website.  The Deloitte Report was also prepared in accordance with NI 51-101; however, Deloitte was instructed to evaluate proved and probable developed reserves only.  No effort was made by Deloitte to assess proved developed non-producing or undeveloped reserves.  As such, only proved and probable developed reserves are provided for the Central Alberta Foothills Assets.  The Deloitte Report is based on the Deloitte Price Forecast, which is available on Deloitte's website.  The information regarding the Assets set forth herein is in respect of all of the Assets. All of the reserves associated with the Assets are in Canada and, specifically, in Alberta and British Columbia.

INFRASTRUCTURE DISPOSITION

In October 2017, the Corporation closed its previously announced disposition of 51% of its trunk line and associated facilities (the "Infrastructure Disposition") located in the northern Alberta Foothills for cash consideration of $20.1 million, subject to customary adjustments.  The Infrastructure Disposition has an effective date of September 1, 2017.

THIRD QUARTER HIGHLIGHTS

  • Completed the non-brokered private placement of 15,091,221 flow-through shares at a price of $0.82 per/share for gross proceeds of $12.5 million (the "Offering").  The Offering consisted of common shares issued on a "flow-through" basis in respect of Canadian exploration expenses under the Income Tax Act (Canada) (the "Flow-Through Shares").  The gross proceeds from the Offering will be used by Ikkuma to incur eligible Canadian exploration expenses ("Qualifying Expenditures") prior to December 31, 2018.  Ikkuma will renounce the Qualifying Expenditures to subscribers of the Flow-Through Shares for the fiscal year ended December 31, 2017.
  • Production for the quarter averaged 5,707 BOE/d reflecting the impact of planned and unplanned pipeline and facility outages.  Production capacity is at approximately 6,500 to 7,100 BOE/d.
  • Funds used in operations totaled $1.1 million in the quarter due to the decrease in natural gas pricing, transaction costs of $0.7 million and one-time personnel costs of $0.2 million.  The Corporation is proactively managing pricing decisions to gain exposure to natural gas pricing outside of the volatile daily AECO market.







(Expressed in thousands of Canadian dollars except
per BOE and share amounts; unaudited)


Three months ended
September 30,


Nine months ended

September 30,



2017


2016


2017


2016

OPERATIONS









Average daily production









Natural gas (mcf/d)


33,208


34,487


35,220


38,009

Light oil (bbls/d)


52


-


53


-

NGL's (bbl/d)


120


118


121


91

Total equivalent (BOE/d)


5,707


5,866


6,043


6,426










Average prices and operating netback









Natural gas ($/mcf)

$

1.47

$

2.34

$

2.36

$

1.85

Light oil ($/bbl)


53.26


-


57.21


-

NGL ($/bbl)


30.05


21.81


33.40


23.01

Revenue ($/BOE)


9.75


14.21


15.02


11.44

Realized gain on commodity contracts ($/BOE)


4.43


3.39


1.58


5.29

Royalties ($/BOE)


(0.38)


0.41


(0.33)


(0.04)

Operating expenses ($/BOE)


(9.42)


(9.01)


(8.60)


(8.46)

Transportation costs ($/BOE)


(1.67)


(1.72)


(1.91)


(1.78)

Operating netback (1) ($/BOE)

$

2.71

$

7.28

$

5.76

$

6.45










FINANCIAL









Oil and natural gas sales

$

5,120

$

7,670

$

24,777

$

20,142

Funds flow from operations (1,2)

$

(1,143)

$

2,563

$

3,749

$

7,154


Per share – basic and diluted                     

$

(0.01)

$

0.03

$

0.04

$

0.08

Loss

$

(3,394)

$

(1,952)

$

(1,828)

$

(8,966)


Per share – basic and diluted

$

(0.03)

$

(0.02)

$

(0.02)

$

(0.10)

Capital expenditures

$

10,050

$

4,111

$

21,207

$

7,920

Property acquisitions

$

-

$

27

$

-

$

2,761

Debt (3)

$

33,406

$

26,132

$

33,406

$

26,132

Shares outstanding (000)


109,335


94,244


109,335


94,244

Weighted average shares outstanding










Basic and diluted (000)


97,959


87,407


95,496


87,407

(1)

Funds flow from operations and operating netback are non-IFRS measures. See "Non- IFRS Measures".

(2)

Funds flow from operations include transaction costs related to the Foothills Acquisition and non-recurring G&A expenses for personnel changes.

(3)

Debt is defined as the outstanding principal amounts of Ikkuma's term loan and its bank loan, plus outstanding letters of credit, less unrestricted cash.

 

OPERATIONS UPDATE

Two horizontal wells were completed in Q3 2017.  Each well intersected high-quality light oil pools, with one exploration well expanding the fairway farther west than previously delineated.  The wells were also used to collect reservoir data from the "Badheart formation", a sandstone reservoir that has proven to be oil bearing.  Initial Cardium reservoir pressure in one of the wells appears to have lessened following fracture stimulation, suggesting that stimulated reservoir rock is now in pressure communication with a low pressure conduit, thought to be a fault, impeding efforts to recover frac fluid.  In the Corporation's experience, this is an unusual complexity for foothills reservoirs, but fairly common in the deep basin.  The Corporation is currently collecting pressure information to aid in the future production of these wells and is working on an alternative completion design for these wells, found in only 15% of the Corporation's land base. In contrast, the first well drilled (8-31-63-11W6) into the mildly structured part of the Narraway Pool, and known as the "deep basin" play type, has been on production for more than a year.  Production decline of this well has been significantly lower than expected (about 40%), typical of unstimulated wells with significant matrix contribution.  The intersection of the deep basin play type, in mildly structured parts of Narraway subsurface, is generally known to occur in over 70% of the Corporation's land base.  Over these lands, the Corporation expects that oil production can be improved significantly with a stimulation redesign, similar to many deep basin plays.  The last play type, "folded Cardium", is expected to be tested in 2018.

ABOUT IKKUMA

Ikkuma Resources Corp. is a diversified junior public oil and gas company listed on the TSXV under the symbol "IKM", with holdings in both conventional and unconventional projects in Western Canada.  The technical team has worked together for over a decade in the Foothills Region of Western Canada, through two successful, publicly traded companies.  The unique skills and repeat success at exploiting a complex, potentially prolific play type are fundamental ingredients for a successful growth-oriented company in Western Canada.  Corporate information can be found at: www.ikkumarescorp.com.

Forward-Looking Statements and Information and Cautionary Statements

This press release contains forward‑looking statements and forward‑looking information within the meaning of applicable securities laws including, without limitation, those listed under "Risk Factors" and "Forward-looking Statements" in Ikkuma's Annual Information Form and in its other filings available on SEDAR at www.sedar.com.  The use of any of the words "expect", "anticipate", "continue", "estimate", "objective", "ongoing", "may", "will", "project", "should", "believe", "plans", "intends" and similar expressions are intended to identify forward‑looking statements or information.  Forward-looking statements and information in this press release includes, but is not limited to, the completion of the Foothills Acquisition and the timing thereof; the use of proceeds of the Offering; the funding of the purchase price of the Assets; the anticipated benefits to be obtained as a result of the Foothills Acquisition; the performance characteristics of the Assets and the anticipated potential of the Assets; the impact of the Foothills Acquisition on the Corporation's production, reserves, inventory and financial condition; and the timing of future well testing.  Although Ikkuma believes that the expectations and assumptions on which the forward‑looking statements and information are based are reasonable, undue reliance should not be placed on the forward‑looking statements and information because Ikkuma cannot give any assurance that they will prove to be correct.  Since forward‑looking statements and information address future events and conditions, by their very nature they involve inherent risks and uncertainties.  Actual results could differ materially from those currently anticipated due to a number of factors and risks.  These include but are not limited to the risks associated with the oil and gas industry in general (e.g., operational risks in development, exploration and production; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to production, costs and expenses; failure to obtain necessary regulatory approvals for planned operations; health, safety and environmental risks; uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects or capital expenditures; volatility of commodity prices, currency exchange rate fluctuations; imprecision of reserve estimates; and competition from other explorers) as well as general economic conditions, stock market volatility, and the ability to access sufficient capital.  We caution that the foregoing list of risks and uncertainties is not exhaustive.

In addition, the reader is cautioned that historical results are not necessarily indicative of future performance.  The forward-looking statements and information contained in this press release are made as of the date hereof and Ikkuma undertakes no obligation to update publicly or revise any forward‑looking statement or information, whether as a result of new information, future events or otherwise, unless so required by applicable securities laws.

Certain information set out herein may be considered as "financial outlook" within the meaning of applicable securities laws.  The purpose of this financial outlook is to provide readers with disclosure regarding Ikkuma's reasonable expectations as to the anticipated results of its proposed business activities for the periods indicated.  Readers are cautioned that the financial outlook may not be appropriate for other purposes.

Non-IFRS Measures

This press release provides certain financial measures that do not have a standardized meaning prescribed by IFRS.  These non-IFRS financial measures may not be comparable to similar measures presented by other issuers.  Funds flow from operations and operating netback are not recognized measures under IFRS. Management believes that in addition to net income (loss), funds flow from operations and operating netback are useful supplemental measures that demonstrate the Corporation's ability to generate the cash necessary to repay debt or fund future capital investment.  Investors are cautioned, however, that these measures should not be construed as an alternative to net income (loss), determined in accordance with IFRS, as an indication of Ikkuma's performance.  Funds flow from operations is calculated by adjusting net income (loss) for depletion and depreciation, exploration and evaluation expense, impairment, gain (loss) on sale of petroleum, natural gas and equipment, share-based payments, unrealized gain (loss) on financial instruments and accretion.  Operating netback equals the total of petroleum and natural gas sales, realized gains or losses on commodity contracts, less royalties, transportation and operating expenses.  Reconciliations of operating netback to the most directly comparable measures specified under IFRS are contained in the Corporation's MD&A, copies of which are available on SEDAR.

Oil and Gas Advisory

In this press release, the abbreviation BOE means a barrel of oil equivalent derived by converting gas to oil in the ratio of 6 Mcf of gas to 1 bbl of oil (6 Mcf:1 bbl).  BOE may be misleading, particularly if used in isolation.  A BOE 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 Mcf:1 bbl, utilizing a conversion ratio on a 6 Mcf of gas to 1 bbl of oil basis may be misleading as an indication of value.

NEITHER TSX VENTURE EXCHANGE NOR ITS REGULATION SERVICES PROVIDER (AS THAT TERM IS DEFINED IN THE POLICIES OF THE TSX VENTURE EXCHANGE) ACCEPTS RESPONSIBILITY FOR THE ADEQUACY OR ACCURACY OF THIS RELEASE.

SOURCE Ikkuma Resources Corp.

For further information: Tim de Freitas, President & CEO; Kim Benders, Interim CFO & Corporate Controller; Ikkuma Resources Corp., 2700, 605-5th Avenue S.W. Calgary, AB, T2P 3H5, Phone: 403-261-5900, Fax: 403-261-5902