CALGARY, AB


,


Nov. 3, 2022


/CNW/ – Headwater Exploration Inc. (the ”

Company

” or ”

Headwater

“) (TSX: HWX) is pleased to announce its inaugural quarterly cash dividend in conjunction with its operating and financial results for the three and nine months ended

September 30, 2022

and its 2023 budget.

Headwater expects approximately 38% production per share growth in 2023 while underspending anticipated cash flow. As a result of continued exceptional results, Headwater’s Board of Directors (the “Board”) has implemented a return of capital strategy with the declaration of Headwater’s inaugural quarterly cash dividend of

$0.10

per common share. The first dividend will be payable on

January 16, 2023

, to shareholders of record at the close of business on

December 30, 2022

. This dividend is designated as an eligible dividend for Canadian income tax purposes. The Board expects that the regular quarterly dividend can be maintained in conjunction with our anticipated growth profile at a long term WTI oil price of

US$55

/bbl. Based on Headwater’s closing common share price on

November 2, 2022

, of

$7.21

per share, this represents an annual yield of approximately 5.5%.

Headwater drilled a successful exploration test at 16-22-075-02W5 in

Marten Hills West

which has extended our proven pool boundaries by approximately 3.5 miles. This well has achieved an average 30-day production (“IP30”) rate of 330 bbls/d of oil, providing payout in approximately 4-5 months at

US$80

/bbl WTI.

We also drilled two successful 1.5 mile extended reach step-out wells in our Marten Hills core area. The 12-08-075-24W4 well has achieved an IP30 rate of 377 bbls/d and the 11-08-075-24W4 well will complete its 30-day initial production period mid-November. The wells have extended our core area pool boundaries by approximately 1.5 miles.

In our Marten Hills central area we drilled two successful pool extension wells. The wells at 02/16-14-075-26W4 and 03/16-14-075-26W4 have confirmed our geotechnical interpretation of this pool which covers approximately 5 sections of 100% owned Headwater lands. These wells achieved IP30’s of 130 bbls/d, providing payout in approximately 8-9 months at

US$80

/bbl WTI.

In assessing our continued success and our initial return of capital strategy, the Board has approved an initial capital budget for 2023 of

$200 million

resulting in 2023 annual average production of 18,000 boe/d (92% heavy oil).

The capital budget is expected to generate 38% production per share growth at a reinvestment rate of 60%-70% of 2023 forecasted adjusted funds flow from operations at

US$75

/bbl to

US$85

/bbl WTI.

At

US$75

/bbl to

US$85

/bbl WTI, Headwater forecasts 2023 adjusted funds flow from operations of

$285

–

$330 million

and free cash flow of approximately

$85

–

$130 million

resulting in estimated positive exit 2023 adjusted working capital of

$105

–

$150 million

.

Selected financial and operational information is outlined below and should be read in conjunction with the unaudited condensed interim financial statements and the related management’s discussion and analysis (“MD&A”). These filings will be available at

www.sedar.com

and the Company’s website at

www.headwaterexp.com

Financial and Operating Highlights

THIRD QUARTER 2022 HIGHLIGHTS

• Realized adjusted funds flow from operations
  
  ⁽¹⁾
  
  of
  
  $58.4 million
  
  (
  
  $0.25
  
  per share basic) and cash flows from operating activities of
  
  $72.1 million
  
  (
  
  $0.31
  
  per share basic) representing an increase of 85% and 158%, respectively, over the third quarter of 2021.

• Recognized net income of
  
  $31.5 million
  
  (
  
  $0.14
  
  per share basic) representing an increase of 21% from the third quarter of 2021.

• Achieved an operating netback
  
  ⁽²⁾
  
  of
  
  $56.54
  
  /boe and an adjusted funds flow netback
  
  ⁽²⁾
  
  of
  
  $54.39
  
  /boe representing an increase of 22% and 21%, respectively, over the third quarter of 2021.

• Production averaged 11,612 boe/d (consisting of 10,842 bbls/d of heavy oil, 4.3 mmcf/d of natural gas and 55 bbls/d of natural gas liquids) representing an increase of 51% from the third quarter of 2021.

• Executed a
  
  $71.0 million
  
  capital expenditure
  
  ⁽³⁾
  
  program including 9 successful exploration wells in
  
  Marten Hills West
  
  plus 8 injection wells in Marten Hills as part of Headwater’s enhanced oil recovery project.

• Added 8.25 sections of additional crown lands prospective for
  
  Clearwater
  
  oil in the Greater Peavine area.

• As at
  
  September 30, 2022
  
  , Headwater had adjusted working capital
  
  ⁽¹⁾
  
  of
  
  $118.0 million
  
  , working capital of
  
  $113.4 million
  
  and no outstanding bank debt.

Marten Hills West

In addition to the previously discussed successful exploration extension well at 16-22-075-02W5, an additional 5 wells were drilled in the Clearwater A in the third quarter of 2022. The IP30 rates on these wells have continued to exceed our expectations, achieving average rates of >175 bbls/d of oil.

Headwater has continued to delineate the Clearwater B formation with a total of 3 wells being drilled in the quarter. IP30 rates on these wells have averaged 100 bbls/d of oil which is consistent with expectations for the Clearwater B.

A pilot waterflood to assess the enhanced oil recovery potential in the Clearwater A is contemplated for the first quarter of 2023.

Marten Hills Core

We have continued operations in the Marten Hills core area with the development of the upper bench in section 24-074-25W4. Six wells were drilled during the quarter with exceptional results.  On average the wells have achieved IP30 rates of >350 bbls/d per well.

Waterflood implementation in the core area has resulted in production stabilization of approximately 2,000 bbls/d (20% of current core area production). The production stabilization witnessed over the last several months is consistent with expectations and it continues to demonstrate that enhanced oil recovery is a viable option for the

Clearwater

formation that is expected to materially increase ultimate oil recovery. Headwater plans to continue to implement additional waterflood patterns with expectations that all of the core area will be under waterflood by the middle of 2024.

Greater Peavine Area

Our first exploration test, a stratigraphic test at 06-16-074-18W5 in our Shadow prospect is currently drilling.  Immediately following this well, the rig will spud our first multi-lateral horizontal well in the same prospect area. Headwater has one drilling rig assigned to continue drilling exploration prospects through year end and into the first quarter of 2023. The current schedule will see this rig drill a total of three horizontal wells at Shadow, prior to moving to test additional prospects at Peavine, Utikima Lake and Seal. The initial seven exploration wells are expected to be rig released by early February.  We look forward to providing results on the exploration program throughout the first quarter of 2023.

Since the start of the fourth quarter, Headwater has added an additional 6 sections of land in Peavine, increasing our total land position in the Greater Peavine area to 117.5 sections.

McCully

McCully is scheduled to be placed back on production at the end of November. We have hedged approximately 4.3 mmcf/d representing 57% of our estimated winter season’s production at a price of

Cdn$28

/mcf. McCully is anticipated to deliver record free cash flow of approximately

$28 million

over the winter season

⁽¹⁾

. This asset is long-life, low decline and adds to the sustainability of Headwater’s dividend.

The Company remains on track to achieve its previously released annual production guidance of 13,000 boe/d. Capital expenditures for the year are now expected to be

$245 million

which represents an increase of approximately 6.5% from our previously released capital budget of

$230 million

. The increase in the capital budget is a result of approximately

$7.5 million

of additional costs associated with inflation and an additional

$7.5 million

of spending on equipment inventory and civil construction work to prepare for an active first quarter in 2023. With the

$15 million

increase in capital and the declared

$23 million

dividend, the forecast exit adjusted working capital is now approximately

$113 million

.

Headwater has executed a commitment letter for a credit facility in the amount of

$100 million

with a senior lender. With the 2023 guidance as outlined, Headwater does not intend to draw on the credit facility.

The positive working capital balance and credit facility provide a war chest to continue to provide Headwater the optionality to organically expand its

Clearwater

resources base, pursue accretive acquisitions and implement additional enhanced oil recovery schemes.

2023 will be another exciting year for Headwater as it targets 38% production growth while testing material exploration potential. Based on current strip pricing, we anticipate generating significant free cash flow above our capital expenditures and committed quarterly dividend which will allow the optionality to continually increase our regular quarterly dividend and/or provide special dividends while pursuing incremental opportunities.

Additional corporate information can be found in the Company’s corporate presentation and on Headwater’s website at

www.headwaterexp.com

FORWARD LOOKING STATEMENTS: This press release contains forward-looking statements. The use of any of the words “guidance”, “initial, “anticipate”, “scheduled”, “can”, “will”, “prior to”, “estimate”, “believe”, “potential”, “should”, “unaudited”, “forecast”, “future”, “continue”, “may”, “expect”, “project”, and similar expressions are intended to identify forward-looking statements. The forward-looking statements contained herein, include, without limitation, revised 2022 and 2023 guidance related to expected annual average production, expected reinvestment rate in 2023, capital expenditures and the breakdown thereof, adjusted funds flow from operations, expected dividends, free cash flow and exit adjusted working capital; the expectation to deliver 38% production per share growth in 2023 while underspending anticipated cash flow; the expected timing of the inaugural quarterly dividend; the expectation the quarterly dividend can be maintained in conjunction with our long-term growth profile at long term WTI of

US$55

/bbl; the expected timing of the enhanced oil recovery pilot in the Clearwater A; the expectation that waterflood implementation is expected to materially increase ultimate oil recovery and the expectation that Headwater plans to continue to implement additional waterflood patterns with expectations that all of the core area will be under waterflood by the middle of 2024; the expected drilling schedule in the Greater Peavine area including two additional wells at Shadow and additional prospects at Peavine, Utikima Lake and Seal, which are all expected to be rig released by early

February 2023

with the expectation that results on the exploration program will be provided throughout the first quarter of 2023; the expectation to re-start McCully operations in late

November 2022

; the expectation that the McCully asset will generate

$28 million

of free cash flow over the winter season; the expectation that the Company will not draw on its credit facility in 2023; the expectation that the Company’s positive working capital balance and credit facility will provide Headwater the optionality to organically expand its

Clearwater

resources base, pursue accretive acquisitions and implement additional enhanced oil recovery schemes; and the anticipation that the Company will generate significant free cash flow above our capital expenditures and committed quarterly dividend which will allow the optionality to continually increase our regular quarterly dividend and/or provide special dividends while pursuing incremental opportunities. The forward-looking statements contained herein are based on certain key expectations and assumptions made by the Company, including but not limited to expectations and assumptions concerning the success of optimization and efficiency improvement projects, the availability of capital, current legislation, receipt of required regulatory approvals, the success of future drilling, development and waterflooding activities, the performance of existing wells, the performance of new wells, Headwater’s growth strategy, general economic conditions, availability of required equipment and services, prevailing equipment and services costs, prevailing commodity prices and certain other guidance assumptions as detailed below under the heading


“Future Oriented Financial Information” as set out below. Although the Company believes that the expectations and assumptions on which the forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because the Company can give no assurance that they will prove to be correct. Since forward-looking statements 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, risks associated with the oil and gas industry in general (e.g., operational risks in development, exploration and production; disruptions to the Canadian and global economy resulting from major public health events, the Russian-Ukrainian war and the impact on the global economy and commodity prices; the impacts of inflation and supply chain issues and steps taken by central banks to curb inflation; COVID-19 pandemic, war, terrorist events, political upheavals and other similar events; events impacting the supply and demand for oil and gas including the COVID-19 pandemic and actions taken by the OPEC + group; 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, and health, safety and environmental risks), commodity price and exchange rate fluctuations, changes in legislation affecting the oil and gas industry and uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects or capital expenditures. Refer to Headwater’s most recent Annual Information Form dated

March 10, 2022

, on SEDAR at

www.sedar.com

, and the risk factors contained therein.

FUTURE ORIENTED FINANCIAL INFORMATION: Any financial outlook or future oriented financial information in this press release, as defined by applicable securities legislation, has been approved by management of the Company as of the date


hereof. Readers are cautioned that any such future-oriented financial information contained herein should not be used for purposes other than those for which it is disclosed herein. The Company and its management believe that the prospective financial information as to the anticipated results of its proposed business activities for 2022 and 2023 has been prepared on a reasonable basis, reflecting management’s best estimates and judgments, and represent, to the best of management’s knowledge and opinion, the Company’s expected course of action. However, because this information is highly subjective, it should not be relied on as necessarily indicative of future results. The assumptions used in the revised 2022 guidance include: WTI

US$94.90

/bbl, WCS

Cdn$99.90

/bbl, AGT

US$15.10

/mmbtu, foreign exchange rate of US$/Cdn$ of 0.77, blending expense of WCS less

$2.00

, royalty rate of 20%, operating and transportation costs of

$10.00

/boe, financial derivatives losses of

$0.40

/boe, G&A and interest income and other expense of

$0.90

/boe and cash taxes of

$3.90

/boe. The AGT price is the volume weighted average price for the winter producing months in the McCully field which include January to April and November to December. The assumptions used in the 2023 guidance include: WTI

US$75.00

–

US$85.00

/bbl, WCS Cdn$75.00-Cdn$88.50/bbl, AGT

US$19.20

/mmbtu, foreign exchange rate of US$/Cdn$ of 0.73, blending expense of WCS less

$2.00

, royalty rate of 16%-18%, operating and transportation costs of

$10.50

/boe, financial derivatives losses of

$0.70

/boe, G&A and interest income and other expense of

$0.90

/boe and cash taxes of

$6.10

/boe-

$8.10

/boe. The AGT price is the volume weighted average price for the winter producing months in the McCully field which include January to April and November to December.

DIVIDENDS: The amount of future cash dividends paid by the Company, if any, will be subject to the discretion of the Board and may vary depending on a variety of factors and conditions existing from time to time, including, among other things, adjusted funds from operations, fluctuations in commodity prices, production levels, capital expenditure requirements, acquisitions, debt service requirements and debt levels, operating costs, royalty burdens, foreign exchange rates and the satisfaction of the liquidity and solvency tests imposed by applicable corporate law for the declaration and payment of dividends. Depending on these and various other factors, many of which will be beyond the control of the Company, the Board will adjust the Company’s dividend policy from time to time and, as a result, future cash dividends could be reduced or suspended entirely.

BARRELS OF OIL AND CUBIC FEET OF NATURAL GAS EQUIVALENT: The term “boe” (or barrels of oil equivalent) and “Mcf” (or thousand cubic feet of natural gas equivalent) may be misleading, particularly if used in isolation. A boe and Mcf conversion ratio of six thousand cubic feet of natural gas to one barrel of oil equivalent (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. Additionally, 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 ratio of 6:1 may be misleading as an indication of value.

I


NITIAL PRODUCTION RATES: References in this press release to IP rates, other short-term production rates or initial performance measures relating to new wells are useful in confirming the presence of hydrocarbons; however, such rates are not determinative of the rates at which such wells will commence production and decline thereafter and are not indicative of long-term performance or of ultimate recovery. All IP rates presented herein represent the results from wells after all “load” fluids (used in well completion stimulation) have been recovered. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production for the Company. Accordingly, the Company cautions that the test results should be considered to be preliminary.

NON-GAAP AND OTHER FINANCIAL MEASURES

In this press release, we refer to certain financial measures (such as free cash flow, total sales, net of blending and capital expenditures) which do not have any standardized meaning prescribed by IFRS. Our determinations of these measures may not be comparable with calculations of similar measures for other issuers. In addition, this press release contains the terms adjusted funds flow from operations and adjusted working capital, which are considered capital management measures.  The term cash flow in this press release is equivalent to adjusted funds flow from operations.

Non-GAAP Financial Measures

Free cash flow

Management utilizes free cash flow to assess the amount of funds available for future capital allocation decisions. It is calculated as adjusted funds flow from operations net of capital expenditures.

Total sales, net of blending

Management utilizes total sales, net of blending expense to compare realized pricing to benchmark pricing. It is calculated by deducting the Company’s blending expense from total sales. In the interim financial statements blending expense is recorded within blending and transportation expense.

Capital expenditures

Management utilizes capital expenditures to measure total cash capital expenditures incurred in the period. Capital expenditures represents capital expenditures – exploration and evaluation and capital expenditures – property, plant and equipment in the statement of cash flows in the Company’s interim financial statements netted by the government grant.

Capital Management Measures

Adjusted Funds Flow from Operations

Management considers adjusted funds flow from operations to be a key measure to assess the Company’s management of capital. In addition to being a capital management measure, adjusted funds flow from operations is used by management to assess the performance of the Company’s oil and gas properties. Adjusted funds flow from operations is an indicator of operating performance as it varies in response to production levels and management of production and transportation costs. Management believes that by eliminating changes in non-cash working capital and deducting current income taxes, adjusted funds flow from operations is a useful measure of operating performance. While current income taxes will not be paid until 2023, management believes adjusting for current income taxes in the period incurred is a better indication of the funds generated by the Company.

Adjusted Working Capital

Adjusted working capital is a capital management measure which management uses to assess the Company’s liquidity.

Non-GAAP Ratios

Payout

Headwater uses this ratio to evaluate is operational performance and capital allocation processes. Payout is calculated as the time at which a well or project’s cumulative operating netback equals total capital expenditures.

Reinvestment Rate

Management believes the reinvestment rate is a useful measure to analyze the ratio of funds generated by the Company and used for reinvestment. Reinvestment rate is calculated as capital expenditures divided by adjusted funds flow from operations.

Adjusted funds flow netback, operating netback and operating netback, including financial derivatives

Adjusted funds flow netback, operating netback and operating netback, including financial derivatives are non-GAAP ratios and are used by management to better analyze the Company’s performance against prior periods on a more comparable basis. Adjusted funds flow netback is defined as adjusted funds flow from operations divided by sales volumes in the period.

Operating netback is defined as sales less royalties, transportation and blending costs and production expense divided by sales volumes in the period. The sales price, transportation and blending costs, and sales volumes exclude the impact of purchased condensate. Operating netback, including financial derivatives is defined as operating netback plus realized gains or losses on financial derivatives.

Adjusted funds flow per share

Adjusted funds flow per share is a non-GAAP ratio and is used by management to better analyze the Company’s performance against prior periods on a more comparable basis. Adjusted funds flow per share is calculated as adjusted funds flow from operations divided by weighted average shares outstanding on a basic or diluted basis.

Per boe numbers

This press release represents various results on a per boe basis including Headwater average realized sales price, net of blending, financial derivatives gains (losses) per boe, royalty expense per boe, transportation expense per boe, production expense per boe, general and administrative expenses per boe, interest income and other expense per boe and current taxes per boe. These figures are calculated using sales volumes.

SOURCE Headwater Exploration Inc.

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