Touchstone Exploration Regulatory News (TXP)

TOUCHSTONE EXPLORATION INC.

ANNOUNCES SECOND QUARTER 2017 RESULTS AND SIX MONTHS TO 30 JUNE 2017 INTERIM RESULTS

Calgary, Alberta - August 11, 2017 - Touchstone Exploration Inc. ("Touchstone" or the "Company") (TSX / LSE: TXP) announces its financial and operating results for the three months ended June 30, 2017 (the "second quarter"). Selected financial and operational information is outlined below and should be read in conjunction with Touchstone's June 30, 2017 unaudited interim consolidated financial statements and related management's discussion and analysis, both of which will be available under the Company's profile on SEDAR (www.sedar.com) and the Company's website (www.touchstoneexploration.com). Unless otherwise stated, tabular amounts herein are in thousands of Canadian dollars, and amounts in text are rounded to thousands of Canadian dollars.

Highlights

· Completed an admission and listing on the AIM market of the London Stock Exchange ("AIM") on June 26, 2017. In conjunction with the admission, the Company successfully placed 20,000,000 new common shares with United Kingdom investors for gross proceeds of $2,446,000.

· Successfully drilled three wells and recompleted five wells in the second quarter of 2017.

· Achieved second quarter average crude oil sales of 1,334 barrels per day ("bbls/d"), representing an increase of 4% from the first quarter of 2017.

· Realized operating netback before realized derivatives of $21.72 per barrel during the six months ended June 30, 2017, representing an increase of 134% from $9.27 per barrel recorded in the equivalent period of 2016.

· Generated second quarter funds flow from operations of $438,000 ($0.01 per basic share) compared to $393,000 ($0.01 per basic share) recorded in the first quarter of 2017.

2017 Second Quarter and Year to Date Financial and Operating Results Summary

1Refer to advisory regarding non-GAAP measures.

In the second quarter of 2017, Touchstone commenced its four well 2017 drilling program. Three wells were drilled in the quarter, two of which were completed and on production by the end of June 2017. Touchstone's workover program continued in the quarter with five wells recompleted, totaling ten well recompletions in the calendar year of 2017. The Company invested $5,460,000 in the second quarter of 2017 on exploration and development expenditures, of which $4,726,000 related to drilling and well recompletions. As a result, second quarter 2017 production increased to 1,334 bbls/d, representing an increase of 4% from the first quarter of 2017 and 1% from the second quarter of 2016. The two new wells commenced production in mid-June 2017, contributing a field estimated 3,350 barrels of incremental production in the second quarter.

Realized second quarter 2017 pricing for crude oil was $61.26 (US$45.51) per barrel versus $49.83 (US$38.59) per barrel received in the equivalent quarter of 2016. Petroleum revenues increased 24% from the prior year comparative quarter primarily based on the significant year over year increase in realized crude oil prices. Second quarter 2017 royalty expenses represented 29.1% of petroleum revenues compared to 27.1% in the prior year comparative period. The increase reflected the sliding scale effect of increased commodity prices on royalty rates. Second quarter 2017 operating expenses increased 17% per barrel based on increased workover activity. General and administrative costs increased 5% from the prior year second quarter, as less costs were capitalized in the second quarter of 2017. Second quarter 2017 net finance expenses increased 16% from the prior year equivalent quarter, as increased term loan interest expenses were slightly offset by reduced interest on income taxes and bank loan finance fees.

Funds flow from operations for the three months ended June 30, 2017 was $438,000 ($0.01 per basic share) versus funds flow from operations of $3,278,000 ($0.04 per basic share) recognized in the second quarter of 2016. Funds flow from operations decreased in comparison to the prior year comparative quarter largely due to $3,316,000 in realized derivative gains that were recorded in 2016. The Company recorded a net loss of $1,848,000 ($0.02 per basic share) during the three months ended June 30, 2017, versus a net loss of $2,553,000 ($0.03 per basic share) recognized in the second quarter of 2016.

On June 26, 2017, the Company completed an admission and listing on the AIM market of the London Stock Exchange. In conjunction with the AIM admission, the Company placed an additional 20,000,000 new common shares at a price of $0.12, resulting in gross and net proceeds of $2,446,000 and $777,000, respectively.

Touchstone exited the quarter with a cash balance of $9,925,000, a working capital surplus of $1,186,000 and a $15,000,000 principal term loan balance. $4,925,000 of the Company's cash balance was considered available at June 30, 2017, as Touchstone must maintain a minimum cash reserves balance of $5,000,000 in accordance with its term loan. In addition, the Company classified $3,186,000 in cash used to collateralize letters of credit that secured future work obligations on production and development contracts as long-term restricted cash. Cash and working capital decreased from the first quarter of 2017 due to drilling activity in the second quarter; the Company expects to realize the benefits of increased production in the second half of 2017.

The fourth well of Touchstone's 2017 drilling program was drilled subsequent to the end of the second quarter, and all four wells were completed and on production. The Company will provide an operational update when all new wells have stabilized with at least 30 days of production data.

Paul Baay, President and Chief Executive Officer of Touchstone, commented:

"We have had a very positive second quarter, as we completed a successful admission and listing on AIM and achieved a 134% year-over-year rise in our year to date operating netback prior to derivatives. I would like to thank all of our staff for their continued hard work in ensuring we successfully and safely drilled three wells and performed five well recompletions during the second quarter." He went on to say, "The fourth well was successfully drilled post quarter end with all four wells currently on production. This drilling program had little effect on second quarter financial and operating results as incremental production came on late in June, however, we expect to see the full impact of these wells during the second half of the year."

For further information, please contact:

About Touchstone

Touchstone Exploration Inc. is a Calgary based company engaged in the business of acquiring interests in petroleum and natural gas rights, and the exploration, development, production and sale of petroleum and natural gas. Touchstone is currently active in onshore properties located in the Republic of Trinidad and Tobago. The Company's common shares are traded on the Toronto Stock Exchange and the AIM market of the London Stock Exchange under the symbol "TXP".

Advisories

Non-GAAP Measures: This announcement contains terms commonly used in the oil and natural gas industry, such as funds flow from operations per share, operating netback and net debt. These terms do not have a standardized meaning under International Financial Reporting Standards and may not be comparable to similar measures presented by other companies. The Company calculates funds flow from operations per share by dividing funds flow from operations by the weighted average number of common shares outstanding during the applicable period. Operating netback is presented on a per barrel basis and is calculated by deducting royalties and operating expenses from petroleum revenue. The Company discloses operating netback both prior to realized gains or losses on derivatives and after the impacts of derivatives are included. Realized gains or losses represent the portion of risk management contracts that have settled in cash during the period, and disclosing this impact provides Management and investors with transparent measures that reflect how the Company's risk management program can impact netback metrics. The Company uses operating netback as a key performance indicator of field results, and considers it to be a key measure as it demonstrates Touchstone's profitability relative to current commodity prices. Net debt is calculated by summing the Company's working capital and non-current undiscounted interest bearing liabilities. Working capital is defined as current assets less current liabilities as they appear on the statements of financial position. The Company uses this information to assess its true debt and liquidity position and to manage capital and liquidity risk. Management uses these non-GAAP measures for its own performance measurement and to provide stakeholders with measures to compare the Company's operations over time.

Forward-Looking Statements: Certain information provided in this announcement may constitute forward-looking statements within the meaning of applicable securities laws. Forward-looking information in this announcement may include, but is not limited to, statements regarding expectations related to the future incremental production to be achieved from the drilling program. 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. Certain of these risks are set out in more detail in the Company's Annual Information Form dated March 21, 2017 which has been filed on SEDAR and can be accessed at www.sedar.com. The forward-looking statements contained in this announcement are made as of the date hereof, and except as may be required by applicable securities laws, the Company assumes no obligation to update publicly or revise any forward-looking statements made herein or otherwise, whether as a result of new information, future events or otherwise.

Interim Consolidated Statements of Financial Position

(Unaudited, thousands of Canadian dollars)

Commitments (note 14)

See accompanying notes to these consolidated financial statements.

Approved on behalf of the Board of Directors of Touchstone Exploration Inc.:

/s/ John D. Wright /s/ Kenneth McKinnon

Director and Chairman of the Board of Directors Director and Chair of the Audit Committee

Interim Consolidated Statements of Loss and Comprehensive Loss

(Unaudited, thousands of Canadian dollars, except per share amounts)

See accompanying notes to these consolidated financial statements.

Interim Consolidated Statements of Changes in Shareholders' Equity

(Unaudited, thousands of Canadian dollars)

See accompanying notes to these consolidated financial statements.

Interim Consolidated Statements of Cash Flows

(Unaudited, thousands of Canadian dollars)

See accompanying notes to these consolidated financial statements.

Notes to the Interim Consolidated Financial Statements (unaudited)

1. Reporting Entity

Touchstone Exploration Inc. (the "Company") is incorporated under the laws of Alberta, Canada with its head office located in Calgary, Alberta. The Company is an oil and gas exploration and production company active in the Republic of Trinidad and Tobago ("Trinidad").

The principal address of the Company is located at 4100, 350 7th Avenue SW, Calgary, Alberta, T2P 3N9. The Company's common shares are listed on the Toronto Stock Exchange ("TSX") and on the AIM market of the London Stock Exchange ("AIM") under the symbol "TXP".

2. Basis of Preparation and Statement of Compliance

These unaudited interim consolidated financial statements (the "financial statements") have been prepared in accordance with International Accounting Standard ("IAS") 34 Interim Financial Reporting, using accounting policies consistent with International Financial Reporting Standards ("IFRS") as issued by the International Accounting Standards Board ("IASB"). These financial statements are condensed as they do not include all the information required by IFRS for annual financial statements and should be read in conjunction with the Company's audited consolidated financial statements for the year ended December 31, 2016. Unless otherwise stated, amounts presented in these financial statements are rounded to thousands of Canadian dollars and tabular amounts are stated in thousands of Canadian dollars.

These financial statements have been prepared on a historical cost basis, except as detailed in the accounting policies disclosed in Note 3 "Summary of Significant Accounting Policies" of the Company's audited consolidated financial statements for the year ended December 31, 2016. All accounting policies and methods of computation followed in the preparation of these financial statements are consistent with those of the previous financial year, except as noted in Note 3 "Accounting Policies". There have been no significant changes to the use of estimates or judgments since December 31, 2016.

At December 31, 2016, the audited consolidated financial statements included the accounts of the Company and its wholly owned subsidiaries, including Archon Technologies Ltd. Effective January 1, 2017, Archon Technologies Ltd. amalgamated with Touchstone Exploration Inc. All intercompany transactions have been eliminated upon consolidation between the Company and its subsidiaries in these financial statements.

These financial statements were authorized for issue by the Board of Directors on August 10, 2017.

3. Accounting Policies

(a) Segment reporting

Effective January 1, 2017, the Company's operations were viewed as a single operating segment by the chief operating decision makers of the Company for the purpose of resource allocation and assessing operational performance. Accordingly, certain reclassification adjustments have been made to the comparative period to conform to the current presentation.

(b) Accounting standards adopted

There were no new or amended accounting standards or interpretations adopted by the Company during the six months ended June 30, 2017.

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(c) Standards issued but not yet adopted

In April 2016, the IASB issued its final amendments to IFRS 15 Revenue from Contracts with Customers, which replaces IAS 18 Revenue, IAS 11 Construction Contracts, and related interpretations. IFRS 15 provides a single, principles-based five-step model to be applied to all contracts with customers. The standard requires an entity to recognize revenue to reflect the transfer of goods and services for the amount it expects to receive when control is transferred to the purchaser. Disclosure requirements have also been expanded. The standard is required to be adopted either retrospectively or using a modified retrospective approach for annual periods beginning on or after January 1, 2018, with earlier adoption permitted. IFRS 15 is expected to be applied by the Company on January 1, 2018. The Company is currently in the process of reviewing its underlying crude oil contracts to determine the impact, if any, that the adoption of IFRS 15 will have on its financial statements, as well as the impact that adoption of the standard will have on disclosure.

In July 2014, the IASB completed the final elements of IFRS 9 Financial Instruments. The standard supersedes earlier versions of IFRS 9 and completes the IASB's project to replace IAS 39 Financial Instruments: Recognition and Measurement. IFRS 9 introduces a single approach to determine whether a financial asset is measured at amortized cost or fair value and replaces the multiple rules within IAS 39. For financial liabilities, IFRS 9 retains most of the requirements of IAS 39. The Company does not anticipate any material changes in the carrying values of the Company's financial instruments because of the adoption of IFRS 9. The standard will come into effect for annual periods beginning on or after January 1, 2018, with earlier adoption permitted. IFRS 9 is expected be applied on a retrospective basis by the Company on January 1, 2018.

In January 2016, the IASB issued IFRS 16 Leases, which replaces IAS 17 Leases. For lessees applying IFRS 16, a single recognition and measurement model for leases would apply, with required recognition of assets and liabilities for most leases. The standard will come into effect for annual periods beginning on or after January 1, 2019, with earlier adoption permitted if the entity is also applying IFRS 15 Revenue from Contracts with Customers. The standard is required to be adopted either retrospectively or using a modified retrospective approach. IFRS 16 is expected to be applied by the Company on January 1, 2019, and the Company is currently evaluating the impact of the standard on its financial statements.

4. Exploration Assets

Exploration assets consist of the Company's projects in the exploration and evaluation stage which are pending determination of technical and commercial feasibility. The following table is a continuity schedule of the Company's exploration assets.

During the three and six months ended June 30, 2017, $11,000 and $31,000 (2016 - $123,000 and $134,000) of general and administrative expenses were capitalized to exploration assets, respectively.

During the three and six months ended June 30, 2017, the Company incurred $391,000 and $477,000 (2016 - $114,000 and $227,000) in accrued lease expenses and letter of credit holding costs relating to its East Brighton property, respectively. These costs were impaired given the property's estimated recoverable amount was $nil. An additional $39,000 in corporate exploration property lease expenses were incurred and impaired during the three and six months ended June 30, 2017 (2016 - $nil and $nil, respectively).

5. Property and Equipment

As at June 30, 2017, $63,293,000 in future development costs were included in Trinidad production asset cost bases for depletion calculation purposes (December 31, 2016 - $70,870,000). During the three and six months ended June 30, 2017, $207,000 and $403,000 in general and administrative expenses were capitalized to property and equipment, respectively (2016 - $194,000 and $515,000). During the three and six months ended June 30, 2017, $9,000 and $18,000 in share-based compensation expenses were capitalized to property and equipment, respectively (2016 - $16,000 and $36,000).

Lease operatorship agreements

The Company's Lease Operating Agreements ("LOAs") in respect of its four core properties (Coora 1, Coora 2, WD-4 and WD-8) with the Petroleum Company of Trinidad and Tobago Limited ("Petrotrin"), initially expire on December 31, 2020, with the Company holding a five-year renewal option upon reaching agreement regarding the proposed work program and financial obligations. The practice in Trinidad is for extensions to be issued in most cases on terms substantially similar to those in effect at the time. Presently, the Company is subject to annual minimum production levels and five-year minimum work commitments from 2016 through 2020 (see note 14).

In 2016, the Company did not meet the annual minimum production levels and the minimum work obligations specified in the Coora 1, Coora 2 and WD-8 LOAs or the minimum work obligations specified in the WD-4 LOA. Although the LOAs provide that the minimum production levels are to be achieved on a best endeavors basis, the LOAs also describe the failure to achieve the minimum production levels or the failure to complete the work obligations as potentially constituting a material breach of the LOAs. As a result of this inconsistency, the Company sought legal advice regarding the effect of not meeting the production levels and not completing the work obligations.

On May 17, 2017, the Company received additional correspondence from Petrotrin approving the Company's development plans for the Coora 1 and WD-4 properties and requesting the Company to provide a definite timeline under which the work obligations for the Coora 2 and WD-8 licences will be met. At the date of these financial statements, the Company has fulfilled its work commitments on the Coora 1 and WD-4 properties for 2016 and 2017. The Company will respond to the Coora-2 and WD-8 request after the results of the initial four well program have stabilized, and the impact of continued low commodity pricing and available capital resources are evaluated.  

Based on correspondence and quarterly lease operatorship reviews to date, Petrotrin has not taken the position that there is any breach of the LOAs. It is not anticipated that a default notice will be issued; however, in any event, the Company is only required to begin to rectify the breach within seven days from the date of receipt of such notice. The Company has been advised by its legal counsel that the risk of the loss of the LOAs for an allegation of noncompliance is extremely remote. No assurance can be given that, if future breaches of these obligations occur, they will not result in a material adverse impact to the Company's cash flows. As at June 30, 2017, the Company was in compliance with all other obligations specified in the LOAs.

Exploration and production licences

The Company's Fyzabad and Palo Seco exploration and production agreements with the Trinidad and Tobago Minister of Energy and Energy Industries ("MEEI") contain no major work obligations or covenants but expired on August 19, 2013. The Company is currently negotiating licence renewals and has permission from the MEEI to operate in the interim period. The Company has no indication that the two licences will not be renewed. During the three and six months ended June 30, 2017, production volumes produced under expired MEEI production licences represented 4.6% and 5.0% of total production, respectively (2016 - 5.2% and 5.4%).

Private lease agreements

The Company is operating under a number of Trinidad private lease agreements which have expired and are currently being renewed. Based on legal opinions received, the Company is continuing to recognize revenue on the producing properties because the Company is the operator, is paying all associated royalties and taxes, and no title to the revenue has been disputed. The Company currently has no indication that any of the producing expired leases will not be renewed. During the three and six months ended June 30, 2017, production volumes produced under expired Trinidad private lease agreements represented 3.2% and 3.0% of total production, respectively (2016 - 2.2% and 2.3%).

6. Restricted cash and cash equivalents

The Company has United States dollar ("US$") denominated cash collateralized letters of credit that secure long-term work obligations on its production and exploration concessions. A reconciliation of the long-term restricted cash and cash equivalents balance is set forth below:

On March 14, 2017, the Company received formal approval from the MEEI to reduce the letter of credit related to the East Brighton exploration property from US$6,000,000 to US$2,150,000. The funds were released to the Company on March 30, 2017.

In addition, at June 30, 2017 the Company had a security agreement with Export Development Canada in connection with a performance security guarantee that supports a US$3,313,000 letter of credit provided to the MEEI related to work commitments on its Ortoire exploration property. The letter of credit expired on August 6, 2017 and will be replaced with a parent company guarantee.

7. Term Loan and Associated Liabilities

On November 23, 2016, the Company completed an arrangement for a $15,000,000, five-year term loan from a Canadian investment fund. The term loan replaced the Company's former bank loan, which was discharged.

The term loan matures on November 23, 2021 with no mandatory repayment of principal required until January 1, 2019. The Company is required to repay $810,000 per quarter commencing on January 1, 2019 through October 1, 2021, and the then outstanding principal balance is repayable on the maturity date. The term loan bears a fixed interest rate of 8% per annum, compounded and payable quarterly in arrears from January 1, 2017. In connection with the term loan, the Company also granted the lender a 1% gross overriding royalty on petroleum sales from current Company land holdings in Trinidad, which are payable until November 23, 2021 regardless of any repayment or prepayment of the term loan. The Company may prepay any principal portion of the term loan after May 23, 2018 and has the option to negotiate a buyout of the future royalty obligations if the term loan balance is prepaid in full. The term loan and the Company's obligations in respect of the royalty are principally secured by fixed and floating security interests over all present and after acquired assets of the Company and its subsidiaries.

The term loan was initially measured at fair value, net of all transaction fees, using a discount rate of 12%. The term loan balance less transaction costs is unwound using the effective interest rate method to the principal value at maturity with a corresponding non-cash accretion charge to earnings. The royalty obligation was initially measured at fair value, using the estimated royalty payable at the inception of the loan discounted by 15%. The royalty liability is reduced by future amounts paid to the lender. Once the liability is reduced to $nil, any subsequent amounts paid are recorded as finance expenses in the period incurred.

The following is a continuity schedule of the term loan and associated liabilities balance from inception to June 30, 2017:

The term loan arrangement contains industry standard representations and warranties, positive and negative covenants and events of default. The financial covenants and the Company's estimated position as at June 30, 2017 was as follows:

1 Estimated position subject to final approval.

2 Net funded debt is defined as interest-bearing debt less cash reserves. Equity is defined as book value of shareholders' equity less accumulated other comprehensive income (loss).

3 EBITDA is defined as net earnings before interest, income taxes and non-cash items.

8. Decommissioning Obligations

The Company's decommissioning obligations relate to future site restoration and abandonment costs including the costs of production equipment removal and land reclamation based on current environmental regulations. The total decommissioning obligation is estimated by Management based on the Company's net ownership interest in all wells and facilities, estimated costs to reclaim and abandon these wells and facilities, and the estimated timing of the costs to be incurred in future periods.

Pursuant to Trinidad production licences, the Company is obligated to remit funds into an abandonment fund based on production. The abandonment fund obligations are determined based on cumulative crude oil sales and recognized as a current liability and a reduction of the long-term decommissioning obligation. Payments to the fund are recorded as a long-term asset included in property equipment. The Company and the relevant Trinidad government entity must agree on the budget and site to reclaim prior to using the abandonment fund.

As at June 30, 2017, the Company remitted $738,000 of abandonment fund payments, and $266,000 in short-term fund obligations were included in accounts payable and accrued liabilities (December 31, 2016 - $697,000 and $328,000, respectively). As at June 30, 2017, the Company estimated the total undiscounted cash flows required to settle its decommissioning obligations to be approximately $20,159,000 (December 31, 2016 - $20,664,0000). June 30, 2017 decommissioning liabilities were discounted using a weighted average risk-free rate of 5.8% and calculated using an inflation rate of 4.8% (December 31, 2016 - 5.8% and 4.8%, respectively).

The majority of these obligations are anticipated to be incurred in twenty-five years and are expected to be funded from the abandonment fund and the Company's internal resources available at the time of settlement. The following table summarizes the Company's decommissioning obligation provision:

9. Shareholders' Capital

(a) Issued and outstanding common shares

The Company has authorized an unlimited number of voting common shares without nominal or par value.

(b) Private placement

On June 26, 2017, the Company completed an admission and listing on the AIM market of the London Stock Exchange. In conjunction with the AIM admission, the Company placed an additional 20,000,000 common shares at a price of 7.25 pence sterling ($0.1221) for gross proceeds of £1,450,000 ($2,446,000). Following the private placement, the Company had 103,137,143 common shares outstanding.

Total fees incurred from the private placement were $1,669,000, which included brokerage commissions and legal, accounting and corporate finance advisory fees. Net proceeds of the private placement were $777,000. 

All common shares issued by the Company pursuant to the offering are freely transferable outside of Canada, however these common shares are subject to a four-month restricted hold period in Canada which will prevent such common shares from being resold in Canada, through a Canadian exchange or otherwise, during the restricted period without an exemption from the Canadian prospectus requirement. The restriction period expires on October 27, 2017.

(c) Share options and incentive share options

The Company has a share option plan pursuant to which options to purchase common shares of the Company may be granted by the Board of Directors to directors, officers, employees and consultants of the Company. The exercise price of each option may not be less than the closing price of the common shares prior to the date of grant. Compensation expense is recognized as the options vest. Unless otherwise determined by the Board of Directors, vesting typically occurs one third on each of the next three anniversaries of the date of the grant as recipients render continuous service to the Company, and the share options typically expire five years from the date of the grant. The maximum number of common shares issuable on the exercise of outstanding share options and incentive share options at any time is limited to 10% of the issued and outstanding common shares.

During the three and six months ended June 30, 2017, the Company granted 447,500 and 1,466,300 share options to directors and employees, respectively (2016 - nil and 1,558,800). The weighted average fair value of options granted during the three and six months ended June 30, 2017 was $0.09 and $0.08 per option as estimated on the date of each grant using the Black-Scholes option pricing model (2016 - nil and $0.13 per option).

The Company has an incentive share option plan which provides for the grant of incentive share options to purchase common shares of the Company at a $0.05 exercise price. A maximum of two million incentive shares have been approved for issuance under this plan. Unless otherwise determined by the Board of Directors, vesting typically occurs one third on each of the next three anniversaries of the date of the grant, and the incentive share options typically expire five years from the date of the grant.

During the three and six months ended June 30, 2017, the Company recorded share-based compensation expenses of $44,000 and $100,000 (2016 - $33,000 and $101,000) in the consolidated statement of earnings, respectively, as a result of the vesting of outstanding options and additional share options granted in 2017.

10. Net Finance Expenses

11. Loss per Common Share

There was no dilutive impact to the weighted average number of common shares for the three and six months ended June 30, 2017 and 2016, as all share options, incentive share options and warrants were excluded from the weighted average dilutive share calculation because their effect would be anti-dilutive.

12. Risk Management

(a) Credit risk

Credit risk arises from the potential that the Company may incur a loss if a counterparty to a financial instrument fails to meet its obligation in accordance with agreed terms. The Company's Trinidad crude oil production is sold, as determined by market based prices adjusted for quality differentials, to Petrotrin. Typically, the Company's maximum credit exposure to Petrotrin is revenue for one month's petroleum sales, of which $2,801,000 was included in accounts receivable as at June 30, 2017 (December 31, 2016 - $1,880,000). The aging of accounts receivable as at June 30, 2017 and December 31, 2016 was as follows:

No provision was made for past due receivables as the Company assessed that there were no impaired receivables. The Company believes that the accounts receivable balances that are past due are still collectible, as the majority are due from Trinidad government agencies. The Company's carrying values of accounts receivable balances represents the Company's maximum credit exposure.

(b) Liquidity risk

Liquidity risk is the risk that the Company will not be able to meet its financial obligations as they become due. Liquidity risk also includes the risk of not being able to liquidate assets in a timely manner at a reasonable price. The Company's approach to managing liquidity is to ensure that it will have sufficient liquidity to meet liabilities when due, under both normal and unusual conditions without incurring unacceptable losses or jeopardizing the Company's business objectives. The Company manages this risk by preparing cash flow forecasts to assess whether additional funds are required. The Company's liquidity is dependent on the Company's expected business growth and changes in the business environment.

To manage its capital structure in a period of low commodity prices, the Company may further reduce its fixed cost structure, adjust capital spending, issue new equity or seek additional sources of debt financing. The Company will continue to manage its expenditures to reflect current financial resources in the interest of sustaining long-term viability.

Undiscounted cash outflows relating to financial liabilities as at June 30, 2017 were as follows:

(c) Commodity price risk

The Company is exposed to commodity price movements as part of its operations, particularly in relation to prices received for its oil production. Commodity prices for oil are impacted by the world and continental/regional economy and other events that dictate the levels of supply and demand. Consequently, these changes could also affect the value of the Company's properties, the level of spending for exploration and development and the ability to meet obligations as they come due.

The Company had no commodity risk management contracts in place as at or during the six months ended June 30, 2017. During the three and six months ended June 30, 2016, the Company recorded net losses of $2,783,000 and $1,970,000 related to commodity risk management contracts, respectively. The Company's commodity price contracts were liquidated on June 2, 2016.

To manage commodity price risk, the Company has reduced its operating and administrative cost structure. The Company may reduce capital expenditures, issue new equity or seek additional sources of debt should forward commodity pricing materially decrease. The Company will continue to monitor forward commodity prices and may enter into commodity based risk management contracts in the future to reduce the volatility of petroleum revenues and protect future development capital programs.

(d) Foreign currency risk

Foreign exchange risk arises from changes in foreign exchange rates that may affect the fair value or future cash flows of the Company's financial assets or liabilities. As the Company primarily operates in Trinidad, fluctuations in the exchange rate between the Canadian dollar and the Trinidad and Tobago dollar can have a significant effect on reported results. The Company's foreign exchange gain or losses primarily include unrealized gains or losses on the translation of the Company's US$ denominated working capital balances in Canada and Trinidad. The Company's foreign currency policy is to monitor foreign currency risk exposure in its areas of operations and mitigate that risk where possible by matching foreign currency denominated expenses with revenues denominated in foreign currencies. The Company attempts to limit its exposure to foreign currency through collecting and paying foreign currency denominated balances in a timely fashion. The Company had no contracts in place to manage foreign currency risk as at or during the six months ended June 30, 2017.

13. Capital Management

The basis for the Company's capital structure is dependent on the Company's expected business growth and any changes in the business and commodity price environment. Stewardship of the Company's capital structure is managed through its financial and operating forecast process. The forecast of the Company's future cash flows is based on estimates of production, crude oil prices, royalty expenses, operating expenses, general and administrative expenses, capital expenditures and other investing and financing activities. The forecast is regularly updated based on changes in commodity prices, production expectations and other factors that in the Company's view would impact cash flow.

The Company's objective is to maintain net debt to annualized funds flow from operations at or below a level of 3.0 to 1. While the Company may exceed this ratio from time to time, efforts are made after a period of variation to bring the measure back in line. Net debt is a non-IFRS measure calculated as working capital less long-term portions of undiscounted interest bearing financial liabilities. Working capital is calculated as current assets less current liabilities as they appear on the consolidated statements of financial position. Net debt is used by management as a key measure to assess the Company's liquidity.

The Company also monitors its capital management through the net debt to net debt plus equity ratio. The Company's strategy is to utilize more equity than debt, thereby targeting net debt to net debt plus shareholders' equity at a ratio of less than 0.4 to 1.

1 Calculated as funds flow from operations from July 1, 2016 to June 30, 2017.

14. Commitments

The Company has minimum work obligations under various operating agreements with Petrotrin, exploration commitments under exploration licence and production agreements with the MEEI and various lease commitments for office space and equipment. As at June 30, 2017, the Company's estimated contractual capital requirements over the next four years and thereafter were as follows:

Under the terms of its operating agreements, the Company must fulfill minimum work obligations on an annual basis over the specific licence term. In total, the Company is obligated to drill 12 wells and perform 18 heavy workovers prior to the end of 2021. As of June 30, 2017, three wells and 11 workovers have been completed with respect to these obligations. The Company failed to drill four wells that were required in 2016, two of which were drilled during the three months ended June 30, 2017 (see note 5).

Under the terms of its exploration licences, the Company must drill five wells prior to the end of December 31, 2020, none of which have been completed as of June 30, 2017.