Morgans interpretation of Operational Update, page-28

@moremoneyplease 

I checked the actual filed credit facility document. The full text of the definitions referenced is below. Comes down to definitions for Borrowing Base Value and Total Proved PV-9. The bolding is mine.

Given the strict hedging requirements in the credit facility for borrowing, SEA is in effect hedged out almost 4 years for the present 2018 (and earlier) production. That "tail" is protected IMO, and should not cause an issue in any redetermination. Only the proposed 2019 program adds risk. The argument then would be if for instance no drilling was done in H1 2019, only the PUD from 2018 drilling would be effected - and that is a maximum of 40% of the current BB. And they could not have possibly drawn down present BB to the max $122.5M (because they sid they wouldn't).

Hopefully I expressed that clearly.  For me, liquidity would not be an issue at the next BB re-dermination - which would be based off of Mar 31 Reserve report.

“Borrowing Base Value” means, at any time with respect to any Swap Agreement considered in determining the then effective Borrowing Base or any Property to which Proved Reserves were attributed in the Reserve Report then most recently delivered, the value attributed thereto by the Administrative Agent in determining the then current Borrowing Base. The Administrative Agent will notify the Borrower of the value attributed to any such Swap Agreement or Property specified by the Borrower upon request.

“Total Proved PV-9” means, as of any date of determination thereof with respect to the Oil and Gas Properties described in the then most recent Reserve Report delivered to the Administrative Agent pursuant to Section 8.12(a),Section 8.12(b) or otherwise, the net present value, discounted at nine percent (9%) per annum, of the future net revenues expected to accrue to the Loan Parties’ collective interest in such Oil and Gas Properties from the date of such determination during the remaining expected economic lives of such Oil and Gas Properties. Each calculation of such expected future net revenues shall be made in accordance with SEC guidelines for reporting proved oil and gas reserves, provided that in any event (a) appropriate deductions shall be made for severance and ad valorem taxes, and for operating, gathering, transportation and marketing costs required for the production and sale of such Oil and Gas Properties, (b) the pricing assumptions used in determining Total Proved PV-9 for any Oil and Gas Properties shall be based upon the Strip Price, adjusted for local basis differentials or premiums and transportation costs and to reflect the Loan Parties’ Swap Agreements then in effect, in each case as determined in the Administrative Agent’s reasonable discretion and (c) the cash-flows derived from the pricing assumptions set forth in clause (b) shall be further adjusted to account for the historical basis differential in a manner reasonably acceptable to the Administrative Agent; provided however, that for purposes of this calculation, no more than 40% of the Total Proved PV-9 shall be attributable to Oil and Gas Properties described in the Reserve Report that constitute Proved Reserves classified as “Developed Non-Producing Reserves” and “Undeveloped Reserves”. The amount of Total Proved PV-9 at any time shall be calculated on a pro forma basis as of the date of any calculation thereof for (i) production and depletion during the period from the“as of” date of the Reserve Report through the date of determination and (ii) dispositions and acquisitions of Oil and Gas Properties with fair market value or consideration in excess of five percent (5%) of the then effective Borrowing Base consummated by the Loan Parties since the date of the Reserve Report most recently delivered hereto; provided that, (A) in the case of any such acquisition, the Administrative Agent shall have received a Reserve Report evaluating the Proved Reserves attributable to the Oil and Gas Properties subject thereto and(B) that at the Borrower’s sole discretion, the amount of Total Proved PV-9 at any time may be calculated on a proforma basis as of the date of any calculation thereof for acquisition or dispositions with aggregate fair market value or consideration, as applicable, of less than five percent (5%) of the then effective Borrowing Base if, in the case of any such acquisition, the Administrative Agent shall have received a Reserve Report evaluating the Proved Reserves attributable to the Oil and Gas Properties subject thereto. As used herein, “Strip Price” shall mean as of any date of determination, the forward month prices as of the last Business Day of the fiscal year or fiscal quarter of the Parent immediately preceding such date of determination for the most comparable hydrocarbon commodity applicable to such future production month for a four-year period (or such shorter period if forward month prices are not quoted for a reasonably comparable hydrocarbon commodity for the full four year period), with such price held flat for each subsequent year based on the average forward month price for each of the twelve months in such fourth year, as such prices are quoted on the NYMEX (or its successor) as of the date of determination, without future escalation; provided that with respect to estimated future production for which prices are defined, within the meaning of SEC guidelines, by contractual arrangements excluding escalations based upon future conditions, then such contract prices shall be applied to future production subject to such arrangements.