(a) For purposes of this chapter, a producer's lease expenditures for a calendar year are

1. (1) costs, other than items listed in (e) of this section, that are

   1. (A) incurred by the producer during the calendar year after March 31, 2006, to explore for, develop, or produce oil or gas deposits located within the producer's leases or properties in the state or, in the case of land in which the producer does not own an operating right, operating interest, or working interest, to explore for oil or gas deposits within other land in the state; and

   2. (B) allowed by the department by regulation, based on the department's determination that the costs satisfy the following three requirements:

      1. (i) the costs must be incurred upstream of the point of production of oil and gas;
      2. (ii) the costs must be ordinary and necessary costs of exploring for, developing, or producing, as applicable, oil or gas deposits; and
      3. (iii) the costs must be direct costs of exploring for, developing, or producing, as applicable, oil or gas deposits;
2. (2) a reasonable allowance for that calendar year, as determined under regulations adopted by the department, for overhead expenses that are directly related to exploring for, developing, or producing, as applicable, the oil or gas deposits; and

3. (3) lease expenditures incurred in a previous calendar year, subject to (l) — (r) of this section, that

   1. (A) met the requirements of AS 43.55.160(e) in the year in which the lease expenditures were incurred;
   2. (B) have not been deducted in the determination of the production tax value of oil and gas under AS 43.55.160(a) or (h) in a previous calendar year;
   3. (C) were not the basis of a credit under this title; and
   4. (D) were incurred to explore for, develop, or produce an oil or gas deposit located in the state outside the Cook Inlet sedimentary basin.

(b) For purposes of (a) of this section,

1. (1) direct costs include

   1. (A) an expenditure, when incurred, to acquire an item if the acquisition cost is otherwise a direct cost, notwithstanding that the expenditure may be required to be capitalized rather than treated as an expense for financial accounting or federal income tax purposes;
   2. (B) payments of or in lieu of property taxes, sales and use taxes, motor fuel taxes, and excise taxes;
2. (2) an activity does not need to be physically located on, near, or within the premises of the lease or property within which an oil or gas deposit being explored for, developed, or produced is located in order for the cost of the activity to be a cost upstream of the point of production of the oil or gas;

3. (3) in determining whether costs are lease expenditures, the department may consider, among other factors, the

   1. (A) typical industry practices and standards in the state that determine the costs, other than items listed in (e) of this section, that an operator is allowed to bill a producer that is not the operator, under unit operating agreements or similar operating agreements that were in effect before December 2, 2005, and were subject to negotiation with at least one producer with substantial bargaining power, other than the operator; and
   2. (B) standards adopted by the Department of Natural Resources that determine the costs, other than items listed in (e) of this section, that a lessee is allowed to deduct from revenue in calculating net profits under a lease issued under AS 38.05.180(f)(3)(B), (D), or (E).

(e) For purposes of this section, lease expenditures do not include

1. (1) depreciation, depletion, or amortization;
2. (2) oil or gas royalty payments, production payments, lease profit shares, or other payments or distributions of a share of oil or gas production, profit, or revenue, except that a producer's lease expenditures applicable to oil and gas produced from a lease issued under AS 38.05.180(f)(3)(B), (D), or (E) include the share of net profit paid to the state under that lease;
3. (3) taxes based on or measured by net income;
4. (4) interest or other financing charges or costs of raising equity or debt capital;
5. (5) acquisition costs for a lease or property or exploration license;
6. (6) costs arising from fraud, wilful misconduct, gross negligence, violation of law, or failure to comply with an obligation under a lease, permit, or license issued by the state or federal government;
7. (7) fines or penalties imposed by law;
8. (8) costs of arbitration, litigation, or other dispute resolution activities that involve the state or concern the rights or obligations among owners of interests in, or rights to production from, one or more leases or properties or a unit;
9. (9) costs incurred in organizing a partnership, joint venture, or other business entity or arrangement;
10. (10) amounts paid to indemnify the state; the exclusion provided by this paragraph does not apply to the costs of obtaining insurance or a surety bond from a third-party insurer or surety;
11. (11) surcharges levied under AS 43.55.201 or 43.55.300;
12. (12) an expenditure otherwise deductible under (b) of this section that is a result of an internal transfer, a transaction with an affiliate, or a transaction between related parties, or is otherwise not an arm's length transaction, unless the producer establishes to the satisfaction of the department that the amount of the expenditure does not exceed the fair market value of the expenditure;
13. (13) an expenditure incurred to purchase an interest in any corporation, partnership, limited liability company, business trust, or any other business entity, whether or not the transaction is treated as an asset sale for federal income tax purposes;
14. (14) a tax levied under AS 43.55.011 or 43.55.014;
15. (15) costs incurred for dismantlement, removal, surrender, or abandonment of a facility, pipeline, well pad, platform, or other structure, or for the restoration of a lease, field, unit, area, tract of land, body of water, or right-of-way in conjunction with dismantlement, removal, surrender, or abandonment; a cost is not excluded under this paragraph if the dismantlement, removal, surrender, or abandonment for which the cost is incurred is undertaken for the purpose of replacing, renovating, or improving the facility, pipeline, well pad, platform, or other structure;
16. (16) costs incurred for containment, control, cleanup, or removal in connection with any unpermitted release of oil or a hazardous substance and any liability for damages imposed on the producer or explorer for that unpermitted release; this paragraph does not apply to the cost of developing and maintaining an oil discharge prevention and contingency plan under AS 46.04.030;
17. (17) costs incurred to satisfy a work commitment under an exploration license under AS 38.05.132;
18. (18) that portion of expenditures, that would otherwise be qualified capital expenditures, as defined in AS 43.55.023, incurred during a calendar year that are less than the product of $0.30 multiplied by the total taxable production from each lease or property, in BTU equivalent barrels, during that calendar year, except that, when a portion of a calendar year is subject to this provision, the expenditures and volumes shall be prorated within that calendar year;

19. (19) costs incurred for repair, replacement, or deferred maintenance of a facility, a pipeline, a structure, or equipment, other than a well, that results in or is undertaken in response to a failure, problem, or event that results in an unscheduled interruption of, or reduction in the rate of, oil or gas production; or costs incurred for repair, replacement, or deferred maintenance of a facility, a pipeline, a structure, or equipment, other than a well, that is undertaken in response to, or is otherwise associated with, an unpermitted release of a hazardous substance or of gas; however, costs under this paragraph that would otherwise constitute lease expenditures under (a) and (b) of this section may be treated as lease expenditures if the department determines that the repair or replacement is solely necessitated by an act of war, by an unanticipated grave natural disaster or other natural phenomenon of an exceptional, inevitable, and irresistible character, the effects of which could not have been prevented or avoided by the exercise of due care or foresight, or by an intentional or negligent act or omission of a third party, other than a party or its agents in privity of contract with, or employed by, the producer or an operator acting for the producer, but only if the producer or operator, as applicable, exercised due care in operating and maintaining the facility, pipeline, structure, or equipment, and took reasonable precautions against the act or omission of the third party and against the consequences of the act or omission; in this paragraph,

    1. (A) “costs incurred for repair, replacement, or deferred maintenance of a facility, a pipeline, a structure, or equipment” includes costs to dismantle and remove the facility, pipeline, structure, or equipment that is being replaced;
    2. (B) “hazardous substance” has the meaning given in AS 46.03.826;
    3. (C) “replacement” includes renovation or improvement;
20. (20) costs incurred to construct, acquire, or operate a refinery or crude oil topping plant, regardless of whether the products of the refinery or topping plant are used in oil or gas exploration, development, or production operations; however, if a producer owns a refinery or crude oil topping plant that is located on or near the premises of the producer's lease or property in the state and that processes the producer's oil produced from that lease or property into a product that the producer uses in the operation of the lease or property in drilling for or producing oil or gas, the producer's lease expenditures include the amount calculated by subtracting from the fair market value of the product used the prevailing value, as determined under AS 43.55.020(f), of the oil that is processed;
21. (21) costs of lobbying, public relations, public relations advertising, or policy advocacy;
22. (22) costs incurred as part of a capital expenditure or other action taken for a carbon management purpose under AS 38.05.081 or a carbon offset project under AS 38.95.400 — 38.95.499;

23. (23) costs incurred for carbon capture or carbon storage, including fees incurred under AS 41.06.160, surcharges incurred under AS 41.06.175, or costs associated with obtaining, operating, or maintaining a license or lease under AS 38.05.700 — 38.05.795; in this paragraph,

    1. (A) “carbon capture” means the process of capturing carbon dioxide from a chemical, mechanical, or industrial process, or directly from the ambient atmosphere, and reducing the carbon dioxide to a concentrated form, including a supercritical fluid; “carbon capture” does not include gas processing or gas treatment;
    2. (B) “carbon storage” means the long-term geologic storage of carbon dioxide in a carbon storage facility permitted under AS 41.06.120 or a Class VI injection well, as defined in 40 C.F.R. 146.5(f).

(g) The department shall specify or approve a reasonable allocation method for determining the portion of a cost that is appropriately treated as a lease expenditure under this section if a cost that would otherwise constitute a lease expenditure under this section is incurred to explore for, develop, or produce

1. (1) both an oil or gas deposit located within land outside the state and an oil or gas deposit located within a lease or property, or other land, in the state; or
2. (2) an oil or gas deposit located partly within land outside the state and partly within a lease or property, or other land, in the state.

(n) A carried-forward annual loss may only be applied

1. (1) to determine the production tax value of oil or gas for a category for which a separate annual production tax value is required to be calculated under AS 43.55.160(a) or (h) if the lease expenditure resulting in the carried-forward annual loss was incurred in the same category;
2. (2) beginning in the calendar year in which regular production of oil or gas from the lease or property where the lease expenditure resulting in the carried-forward annual loss was incurred commences.

(o) A carried-forward annual loss for a lease expenditure incurred on a lease or property that

1. (1) did not commence regular production of oil or gas before or during the year the lease expenditure was incurred decreases in value each year by one-tenth of the value of the carried-forward annual loss in the preceding year, beginning January 1 of the 11th calendar year after the lease expenditure is carried forward under (a)(3) of this section; a decrease in value under this paragraph does not apply for a year in which the department determines that regular production of oil or gas did not commence because of a natural disaster, an injunction or other court order, or an administrative order;
2. (2) commenced regular production of oil or gas before or during the year the lease expenditure was incurred decreases in value each year by one-tenth of the value of the carried-forward annual loss in the preceding year, beginning January 1 of the eighth calendar year after the lease expenditure is carried forward under (a)(3) of this section.

(s) For purposes of this section,

1. (1) “carried-forward annual loss” means a loss established under (a)(3) of this section;
2. (2) “explore” includes conducting geological or geophysical exploration, including drilling a stratigraphic test well;
3. (3) “ordinary and necessary” has the meaning given in 26 U.S.C. 162 (Internal Revenue Code), as amended, and regulations adopted under that section;
4. (4) “stratigraphic test well” means a well drilled for the sole purpose of obtaining geological information to aid in exploring for an oil or gas deposit and the target zones of which are located in the state.