Alaska Senate Bill 21, the state’s current oil production tax, applies a 35 percent rate to the net production tax value of oil and gas produced in the state. The law took effect January 1, 2014, replaced the earlier ACES system, and is codified primarily under Alaska Statute 43.55. The 35 percent headline rate is only the starting point. What a producer actually pays depends on deductions that shrink the taxable base, a sliding per-barrel credit tied to the price of oil, a reduction for new fields, and a minimum floor the state collects no matter what.
How the 35 Percent Rate Is Calculated
SB 21 levies a tax of 35 percent on the annual production tax value of taxable oil and gas from each lease or property in the state.1Justia. Alaska Code 43.55.011 – Oil and Gas Production Tax The rate is applied to a net value, not gross revenue, so most of the math happens before the 35 percent ever enters the picture.
The calculation begins with the Gross Value at the Point of Production (GVPP), the value of oil at the wellhead. GVPP is typically derived from the average monthly price of Alaska North Slope crude, minus the transportation costs needed to move the oil to market. From GVPP, a producer subtracts allowable lease expenditures (operating costs such as labor, maintenance, and supplies) and qualified capital costs (investments in wells, facilities, and infrastructure). What’s left is the Production Tax Value, or PTV. The 35 percent rate applies to that.
Because the deductions come off before the rate is applied, the effective tax rate is always lower than 35 percent in practice. A company that spent heavily on drilling and development in a given year will show a much smaller PTV than one simply pumping from existing wells.
The Per-Barrel Credit and How Price Changes the Effective Rate
SB 21 doesn’t adjust its headline rate as oil prices move. Instead, it uses a sliding per-taxable-barrel credit applied against tax liability. When prices are low, the credit is larger and the effective rate drops well below 35 percent. When prices are high, the credit shrinks toward zero and the full base rate takes hold.
At low prices, the credit can reach $8 per barrel, which keeps marginal fields economically viable through downturns. As the wellhead price climbs, the credit phases down and reaches zero when oil is roughly $150 to $160 per barrel. The system is gentler on producers during slumps and collects closer to the full 35 percent during boom periods, without the steep, nonlinear jumps that defined the previous tax.
Gross Value Reduction for New Oil
To encourage development of new fields, SB 21 created the Gross Value Reduction (GVR). For oil produced from qualifying new leases or newly added acreage, a producer can exclude either 20 percent or 30 percent of the gross value at the point of production before the tax is calculated.2Alaska Department of Natural Resources. Alaska’s Oil and Gas Production Tax – Key Provisions The 30 percent reduction applies to oil from new leases or properties that also meet additional qualification criteria under AS 43.55.160(g); other qualifying new production receives the 20 percent reduction.3Legal Information Institute. Alaska Administrative Code 15 AAC 55.211 – Gross Value Reductions
The GVR runs for the first seven years of commercial production from a qualifying source. It carries a price cap: if the average Alaska North Slope crude price exceeds $70 per barrel for any three years during that window, the benefit ends early.2Alaska Department of Natural Resources. Alaska’s Oil and Gas Production Tax – Key Provisions Because ANS crude has frequently traded well above $70, that sunset matters in practice.
The Minimum Tax Floor
Even after deductions and credits, SB 21 guarantees the state a minimum payment. A producer owes the greater of the calculated production tax (35 percent on PTV, less credits) or a gross-based floor. For North Slope oil, that floor ranges from zero to 4 percent of GVPP depending on the oil price, reaching the full 4 percent when Alaska North Slope crude trades above $25 per barrel.4Alaska State Legislature. Fiscal Systems Seminar2Alaska Department of Natural Resources. Alaska’s Oil and Gas Production Tax – Key Provisions
Because the floor is calculated on gross value, no amount of deductions can zero out the bill. A producer running a paper loss still owes 4 percent of gross wellhead value whenever ANS is above the $25 threshold. During extended stretches of moderate prices, that floor is the effective tax rate for operators with high costs and large deductions.
Capital Credits, Carryforwards, and Transferable Certificates
SB 21 kept a set of tax credits aimed at exploration and development spending. Producers and explorers that incur qualified capital expenditures can claim a credit of 10 percent of those expenditures against production tax liability.5Justia. Alaska Code 43.55.023 – Tax Credits for Certain Losses and Expenditures Annual losses can be carried forward and used to offset future liability, which matters most for smaller operators spending heavily on exploration before a field produces revenue.
A company holding credits larger than its own tax bill can apply to the Alaska Department of Revenue for a transferable certificate and sell it to another company for cash.5Justia. Alaska Code 43.55.023 – Tax Credits for Certain Losses and Expenditures Certificates typically trade at a discount to face value; a $1 million credit certificate might sell for roughly $900,000 to $950,000 depending on market conditions and the buyer’s view of risk.
SB 21 originally allowed companies to obtain cash refunds from the state for unused credits under AS 43.55.028, but the legislature narrowed that option in later years. For lease expenditures incurred on or after July 1, 2017, the cash refund was eliminated, and companies must now either apply credits against their own liability or move them through the transfer market.5Justia. Alaska Code 43.55.023 – Tax Credits for Certain Losses and Expenditures The change responded to the fiscal cost of refunds flowing to companies with little or no current production.
What SB 21 Replaced
SB 21 replaced Alaska’s Clear and Equitable Share (ACES). ACES blended net and gross taxation, with a 10 percent gross tax floor on two mature fields and a main calculation that applied a net approach after costs were subtracted from production value.6Alaska State Legislature. WHAT IS ACES? Alaska’s Clear and Equitable Share Its defining feature was a progressive surcharge that pushed the effective rate up sharply as oil prices rose, with the state’s take sometimes exceeding half of a company’s net profit at peak prices. Industry argued the structure discouraged investment in expensive new projects; supporters argued Alaskans should take a larger share when oil was most valuable. The legislature sided with the first view in 2013 and restructured the system.
The 2014 Repeal Vote
Opponents of SB 21 gathered enough signatures to put a repeal referendum on the August 2014 ballot. The campaign was among the most expensive ballot fights in Alaska history, with oil companies spending heavily to defend the new law. Voters upheld SB 21 by roughly 53 to 47 percent. The vote settled the legal question; the policy debate continues whenever oil prices shift the revenue balance between the state and producers.
Where the Production Tax Sits in What Producers Owe
The production tax is one layer of what oil companies pay to produce in Alaska. Producers also owe royalties on oil taken from state lands, calculated on gross production value and owed regardless of profitability, unlike the production tax, which is based on net value. The state collects corporate income tax and property taxes on oil infrastructure as well. On top of that sit federal income taxes, with their own deductions for drilling costs and depreciation of equipment. SB 21 sets the state production tax piece of that stack; it does not describe the whole bill a North Slope project pays.