Exhibit 99   Totals may not add because of rounding.
 
 
 Acquisition of properties.         Analogous  reservoir   Instruction to paragraph (a)(2)      Bitumen       Condensate      Deterministic estimate       Developed oil and gas reserves        Supplemental definitions from the 2018 Petroleum Resources Management System:       Developed Producing Reserves – Expected quantities to be recovered from completion intervals that are open and producing       at the effective date of the estimate.  Improved recovery Reserves are considered producing only after the improved recovery       project is in operation.       Developed Non-Producing Reserves – Shut-in and behind-pipe Reserves.  Shut-in Reserves are expected to be recovered       from (1) completion intervals that are open at the time of the estimate but which have not yet started producing, (2) wells which       were shut-in for market conditions or pipeline connections, or (3) wells not capable of production for mechanical reasons.        Behind-pipe Reserves are expected to be recovered from zones in existing wells that will require additional completion work       or future re-completion before start of production with minor cost to access these reserves.  In all cases, production can be       initiated or restored with relatively low expenditure compared to the cost of drilling a new well.         Development costs.
 Development  project   Development well    Economically producible     Estimated ultimate recovery (EUR)    Exploration costs     Exploratory well     Extension well   Field     Oil and gas producing activities             (1)           (2)
 Instruction 1 to paragraph (a)(16)(i)   Instruction  2  to  paragraph  (a)(16)(i):                                            saleable  hydrocarbons   Possible reserves.     Probable reserves.
 Probabilistic estimate.    Production costs   Proved area.  Proved  oil  and  gas  reserves.
 Proved properties.      Reasonable certainty.        Reliable technology.         Reserves.     Note to paragraph (a)(26)        Excerpted from the FASB Accounting Standards Codification Topic 932, Extractive Activities—Oil and Gas:       932-235-50-30  A standardized measure of discounted future net cash flows relating to an entity's interests in both of the       following shall be disclosed as of the end of the year:         a.  Proved oil and gas reserves (see paragraphs 932-235-50-3 through 50-11B)         b.  Oil and gas subject to purchase under long-term supply, purchase, or similar agreements and contracts in which the            entity participates in the operation of the properties on which the oil or gas is located or otherwise serves as the producer            of those reserves (see paragraph 932-235-50-7).       The standardized measure of discounted future net cash flows relating to those two types of interests in reserves may be       combined for reporting purposes.         932-235-50-31  All of the following information shall be disclosed in the aggregate and for each geographic area for which       reserve quantities are disclosed in accordance with paragraphs 932-235-50-3 through 50-11B:          a.  Future cash inflows.  These shall be computed by applying prices used in estimating the entity's proved oil and gas            reserves to the year-end quantities of those reserves.  Future price changes shall be considered only to the extent            provided by contractual arrangements in existence at year-end.         b.  Future development and production costs.  These costs shall be computed by estimating the expenditures to be incurred            in  developing and  producing  the  proved oil and gas reserves at the end of  the  year, based on  year-end costs and            assuming continuation of existing economic conditions.  If estimated development expenditures are significant, they            shall be presented separately from estimated production costs.         c.  Future income tax expenses.  These expenses shall be computed by applying the appropriate year-end statutory tax            rates, with consideration of future tax rates already legislated, to the future pretax net cash flows relating to the entity's            proved oil and gas reserves, less the tax basis of the properties involved.  The future income tax expenses shall give            effect to tax deductions and tax credits and allowances relating to the entity's proved oil and gas reserves.         d.  Future net cash flows.  These amounts are the result of subtracting future development and production costs and future            income tax expenses from future cash inflows.
 e.  Discount.  This amount shall be derived from using a discount rate of 10 percent a year to reflect the timing of the future      net cash flows relating to proved oil and gas reserves.    f.  Standardized measure of discounted future net cash flows.  This amount is the future net cash flows less the computed       discount.     Reservoir.  Resources.   Service well.   Stratigraphic test well.   Undeveloped oil and gas reserves.   From the SEC's Compliance and Disclosure Interpretations (October 26, 2009):  Although  several  types  of  projects  —  such  as  constructing  offshore  platforms  and  development  in  urban  areas,  remote  locations or environmentally sensitive locations — by their nature customarily take a longer time to develop and therefore often do justify longer time periods, this determination must always take into consideration all of the facts and circumstances. No  particular type of project per se justifies a longer time period, and any extension beyond five years should be the exception,  and not the rule.  Factors that a company should consider in determining whether or not circumstances justify recognizing reserves even though  development may extend past five years include, but are not limited to, the following:       The company's level of ongoing significant development activities in the area to be developed (for example, drilling only       the minimum number of wells necessary to maintain the lease generally would not constitute significant development       activities);       The company's historical record at completing development of comparable long-term projects;        The amount of time in which the company has maintained the leases, or booked the reserves, without significant       development activities;       The extent to which the company has followed a previously adopted development plan (for example, if a company has       changed its development plan several times without taking significant steps to implement any of those plans, recognizing       proved undeveloped reserves typically would not be appropriate); and       The extent to which delays in development are caused by external factors related to the physical operating environment       (for  example,  restrictions  on  development  on  Federal  lands,  but  not  obtaining  government  permits),  rather  than  by       internal factors (for example, shifting resources to develop properties with higher priority).    Unproved properties.