Indian Example: Initial Reporting for Processed Gas in Non-Index Zone (Major Portion) Areas

Product Code 03 – Residue Gas

Royalty is due on residue gas resulting from processing, including disallowed plant fuel.

Step 1:

In order to determine the plant fuel volume in Mcf, you need to calculate a residue Btu factor:

• The Btu factor is the heating value per volume of the residue gas, calculated by dividing the net residue gas MMBtu (1,922.39 MMBtu) (H) by the volume of the net residue gas Mcf (1,697.81 Mcf) (G)
• The residue Btu factor is 1.13228 MMBtu/Mcf
  

Step 2:

Calculate the plant fuel volume (Mcf):

• Identify the total plant fuel reported on the plant statement. In this example, the plant fuel is called “Contractual Allocated Fuel” and is 326.40 MMBtu (F)
• Determine the total plant fuel volume (Mcf). Divide the contractual allocated fuel (326.40 MMBtu) (F) by the Btu factor (1.13228 MMBtu/Mcf)
• The total plant fuel volume is 288.27 Mcf

Step 3:

Calculate the total residue gas sales volume:

• Add the volume of the residue gas sales (1,697.81 Mcf) (G) to the plant fuel volume from Step 2 (288.27 Mcf)
• The total residue gas sales volume is 1,986.08 Mcf
  

Step 4:

Calculate the total residue gas sales MMBtu:

• Add the energy content of the residue gas sales (1,922.39 MMBtu) (H) to the energy content of the plant fuel, here the “Contractual Allocated Fuel” (326.40 MMBtu) (F)
• The total residue gas sales energy content is 2,248.79 MMBtu

Step 5:

Calculate the residue gas sales value:

• Multiply the residue gas sales MMBtu determined under Step 4 (2,248.79 MMBtu) by the residue unit price ($3.13905/MMBtu) (J)
• The residue gas price may not be reduced by any costs of placing the gas into marketable condition under §1206.174(h)
  
• The total residue gas sales value is $7,059.06
  

Step 6:

Calculate the Royalty Value Prior to Allowances (RVPA):

• Multiply the residue gas sales value calculated under Step 5 ($7,059.06) by the royalty rate (18%)
• The total RVPA is $1,270.63
  

Here is what the royalty reporting looks like so far:

Form ONRR-2014 Royalty Report

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Product Code 07 – Natural Gas Liquids (NGLs)

Royalty is due on any NGLs resulting from processing. In order to comply with the minimum NGL value provision (explained in greater detail in the Minimum NGL Value Example), you should:

1. calculate the regulatory minimum price (the published NGL price less the regulatory adjustment)
2. determine the price at the plant
   
3. compare the prices for each NGL component
   

If the regulatory minimum price is higher, you use that in calculating the sales value for that component. If the price at the plant is higher, you use the downstream sales price (post-fractionation) to calculate the sales value for that component. Because the price at the plant is net of T&F fees, you must add those fees back in to calculate the downstream sales price. As those fees cannot be netted against the sales value, they should instead be taken as allowances where appropriate. For a more in-depth explanation of why the NGL minimum value is calculated this way, please see our full Processed Gas Reporting: Minimum Value Provision for NGLs Example (refer to Scenario 2 for details pertaining to this example).

Step 1:

Determine the NGL minimum value price for each NGL component:

• Under §1206.174(g)(2), the NGL value must not be less than the regulatory minimum value given in the regulations
• In this example, use the minimum value for Montana at §1206.174(g)(2)(i)(B), which is the published NGL price at Conway, Kansas less seven cents

Conway, Kansas published NGL prices

Step 1a:

Calculate the regulatory minimum price by adjusting the published NGL component price. For Montana, reduce the published NGL price at Conway, Kansas by seven cents:

• Take the published NGL price for ethane ($0.24890/gallon) and subtract $0.07. The regulatory minimum price for ethane is $0.17890/gallon.
• Take the published NGL price for propane ($0.85283/gallon) and subtract $0.07. The regulatory minimum price for propane is $0.78283/gallon.
  
• Take the published NGL price for isobutane ($1.43603/gallon) and subtract $0.07. The regulatory minimum price for isobutane is $1.36603/gallon.
  
• Take the published NGL price for normal butane ($1.34133/gallon) and subtract $0.07. The regulatory minimum price for normal butane is $1.27133/gallon.
  
• Take the published NGL price for natural gasoline ($2.17513/gallon) and subtract $0.07. The regulatory minimum price for natural gasoline is $2.10513/gallon
  

Step 1b:

Compare the regulatory minimum price from Step 1a to the price at the plant (which for this example is the price on the example gas plant statement (R)) and note which is higher

• For ethane, the price at the plant of $0.194145/gallon is higher than the regulatory minimum price of $0.17890/gallon
• For propane, the price at the plant of $0.810270/gallon is higher than the regulatory minimum price of $0.78283/gallon
  
• For isobutane, the regulatory minimum price of $1.36603/gallon is higher than the price at the plant of $1.365051/gallon
  
• For normal butane, the regulatory minimum price of $1.27133/gallon is higher than the price at the plant of $1.261770/gallon
  
• For natural gasoline (called “pentanes plus” on example statement), the regulatory minimum price of $2.10513/gallon is higher than the price at the plant of $2.049583/gallon
  

PC 07 Calculate Regulatory Minimum Price and Compare to Price at Plant (Steps 1a-1b):

Step 2:

Calculate the NGL sales value

Step 2a:

Calculate the gross proceeds value of components where the price at the plant was higher than the regulatory minimum value (from Step 1b, ethane and propane). As discussed in Assumption #7 and the introduction to this section, the price at the plant is net of T&F fees, and we therefore cannot use it to calculate the sales value. Instead, we’ll use the downstream price, which is the price at the plant for each component plus the T&F fees.

• Take the price at the plant for ethane ($0.194145/gallon) and add the T&F fee ($0.12/gallon) to get the ethane downstream sales price of $0.314145/gallon.
• Multiply the ethane downstream sales price ($0.314145/gallon) by the ethane gallons (2,684.22 gallons) (S) to get the ethane value. The ethane value is $843.23.
  
• Take the price at the plant for propane ($0.810270/gallon) and add the T&F fee ($0.12/gallon) to get the propane downstream sales price of $0.930270/gallon.
  
• Multiply the propane downstream sales price ($0.930270/gallon) by the propane gallons (2,038.99 gallons) (S) to get the propane value. The propane value is $1,896.81.
  

PC 07 Value of Price at the Plant Components (Step 2a):

Step 2b:

Calculate the value of NGL components where the regulatory minimum price was higher

• Take the regulatory minimum price for isobutane ($1.36603/gallon) and multiply by the isobutane gallons (367.74 gallons) (S). The isobutane value is $502.34.
• Take the regulatory minimum price for normal butane ($1.27133/gallon) and multiply by the normal butane gallons (647.12 gallons) (S). The normal butane value is $822.70.
  
• Take the regulatory minimum price for natural gasoline ($2.10513/gallon) and multiply by the natural gasoline (pentanes plus) gallons (1,165.52 gallons) (S). The natural gasoline value is $2,453.57.

PC 07 Value of Regulatory Minimum Price Components (Step 2b):

Step 2c:

Calculate the total NGL sales value

• Add the ethane value ($843.23), propane value ($1,896.81), isobutane value ($502.34), normal butane value ($822.70), and natural gasoline value ($2,453.57) for a total sales value of $6,518.65 

Step 3:

Determine the NGL sales volume:

• Locate the NGLs actually recovered by the plant on the plant statement under the Component Settlement section showing the “Allocated” amount (L)
• This is the NGL sales volume (6,903.59 gallons)
  

Step 4:

Determine the Royalty Value Prior to Allowances (RVPA):

• Multiply the sales value from Step 2c ($6,518.65) by the royalty rate (18%)
• The RVPA is $1,173.36
  

Here is what the royalty reporting looks like so far:

Form ONRR-2014 Royalty Report

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Product Code 15 – Pipeline Fuel

Report gas used or lost along a pipeline using PC 15. The reporter letter dated December 18, 2014, addresses this topic in detail.

Step 1:

Determine the pipeline fuel sales value:

• Locate the “Contractual Field Deducts” MMBtu amount on the plant statement and report as a positive number for the Gas Sales MMBtu (162.20 MMBtu) (D)
• Also locate the pipeline fuel volume to report as the Sales Volume (129.75 Mcf) (C)
  
• Multiply the pipeline fuel MMBtu (162.20 MMBtu) (D) by the residue gas unit price ($3.13905/MMBtu) (J)
  
• Since there is no sale of the pipeline fuel, you value the pipeline fuel as a no-sale situation under §1206.174(c), and specifically §1206.174(c)(2), using the residue gas sales price to value like-quality gas
  
• The pipeline fuel sales value is $509.15
  

Step 2:

Determine the Royalty Value Prior to Allowances (RVPA):

• Multiply the pipeline fuel sales value from Step 1 ($509.15) by the royalty rate (18%)
• The RVPA is $91.65
  

Here is what the royalty reporting looks like so far:

Form ONRR-2014 Royalty Report

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Transportation Allowance

In this example, we assume there are no pre-plant transportation costs. Also, this example assumes the post-plant transportation fee for NGLs does not include marketable condition or other disallowed costs and can be claimed as an allowance. Only the post-plant transportation costs of NGL components valued using gross proceeds (i.e., components where the price at the plant is higher than the minimum regulatory price) will contribute to the transportation allowance, as those are the only actual post-plant transportation costs incurred by the lessee. Therefore, we will only apply post-plant transportation costs as an allowance for the ethane and propane components.

Step 1:

Determine the gallons of NGLs reported using gross proceeds:

• Locate the components from Step 2a PC 07 – NGLs where the price at the plant was higher and we used the downstream price to calculate gross proceeds
• We calculated the gross proceeds for ethane and propane
  
• Add the gallons of ethane (2,684.22 gallons) (S) and gallons of propane (2,038.99 gallons) (S) to get the total gallons valued using gross proceeds
  
• The total gallons valued using gross proceeds is 4,723.21 gallons

Step 2:

Calculate the transportation allowance

• In this example, we assume that NGL post-plant transportation fee costs are allowable, so you can include the value of the NGL post-plant transportation fee in your transportation allowance for components valued using gross proceeds
• Multiply the total NGL gallons valued using gross proceeds from Step 1 (4,723.21 gallons) by the post-plant NGL transportation fee ($0.05/gallon), and then by the royalty rate (18%)
  
• The transportation allowance is $42.51
  

Step 3:

Ensure the transportation allowance does not exceed the 50% transportation allowance limit under §1206.177(c)(1):

"Except as provided in paragraphs (c)(2) and (3) of this section, your transportation allowance deduction for each sales type code may not exceed 50 percent of the value of the unprocessed gas, residue gas, or gas plant product."

You may only take your reasonable, actual, allowed costs up to 50% of the value of the transported product.

Step 3a:

Calculate the 50% limit for NGLs:

• Locate the NGL Royalty Value Prior to Allowances (RVPA) amount from Step 5 of PC 07 – NGLs ($1,173.38)
• Multiply the RVPA of the NGLs ($1,173.38) by 50% to find the limit of $586.69
  

Step 3b:

Compare the transportation allowance for NGLs to the 50% limit calculated above:

• Locate the transportation allowance for NGLs from Step 2 ($42.51)
• $42.50 is less than $586.69 and is therefore within the transportation allowance limit
  

Here is what the royalty reporting looks like at this point:

Form ONRR-2014 Royalty Report

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Processing Allowance

You may only take a processing allowance against PC 07 – NGLs or other gas plant products. In this example, we assume there are no other unbundled processing costs besides the fractionation costs. Also, this example assumes the fractionation fee does not include marketable condition or other disallowed costs and can be claimed as an allowance. Only the processing costs of components valued using gross proceeds (i.e., components where the price at the plant is higher than the minimum regulatory price) will contribute to the processing allowance. Therefore, we will only apply fractionation costs as a processing allowance for the ethane and propane components.

Step 1:

Determine the gallons of NGLs reported using gross proceeds:

• Locate the total gallons valued using gross proceeds from Step 1 of the Transportation Allowance (4,723.21 gallons)

Step 2:

Calculate the processing allowance

• In this example, we assume that fractionation fee costs are allowable, so you can include the value of the fractionation fee in your processing allowance for components valued using gross proceeds
• Multiply the total NGL gallons valued using gross proceeds from Step 1 (4,723.21 gallons) by the NGL fractionation fee ($0.07/gallon), and then by the royalty rate (18%)
  
• The processing allowance is $59.51
  

Step 3:

Ensure the processing allowance does not exceed the 66 2⁄3% processing allowance limit under §1206.179(c):

"You may only take your reasonable, actual, allowed costs up to 66 2⁄3% of the value of the processed product less post-plant transportation."

Step 3a:

Reduce the value for transportation allowances related to post-processing transportation and calculate the limit:

• Subtract the post-plant NGL transportation from Step 2 of transportation allowance ($42.50) from the NGL Royalty Value Prior to Allowances from Step 5 of PC 07 – NGLs ($1,173.38) to get $1,130.88
• Multiply the reduced amount ($1,130.88) by 66 2⁄3 %
• The limit is $753.92
  

Step 3b:

Compare the processing allowance to the limit calculated above:

• Compare the $753.92 processing allowance limit to the processing allowance in Step 2 ($59.51)
• $59.51 is less than $753.92 and is therefore within the processing allowance limit
  

Here is what the royalty reporting looks like at this point:

Form ONRR-2014 Royalty Report

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Royalty Value Less Allowances

In this example, the allowances include the transportation allowance from the post-plant transportation fee and the processing allowance from the fractionation fee for the NGL components valued using gross proceeds. If you choose to unbundle the costs of transportation and processing to ensure marketable condition costs are not included, you may be able to calculate additional allowances for transportation and processing. If you have questions about unbundling or allowances, you may contact us at onrrunbundling@onrr.gov or royaltyvaluation@onrr.gov.

For the product codes without allowances, the RVPA and Royalty Value Less Allowances (RVLA) will be the same.

Step 1:

Calculate the RVLA for the NGLs:

• Find the RVPA for Product Code 07 from Step 5 of PC 07 – NGLs ($1,173.38) and then subtract the transportation allowance from Step 2 of transportation allowance ($42.51) and the processing allowance from Step 2 of processing allowance ($59.51)
• The RVLA for Product Code 07 is $1,071.37
  

The final initial reporting looks like this:

Form ONRR-2014 Royalty Report

Step 2:

For leases in a non-index zone (major portion), initial reporting is only the first step in the process.

After ONRR publishes the major portion price, you must compare the residue sales price to the major portion price to fulfill the major portion requirement in your lease. You also need to complete any required dual accounting.

• If you elected alternative dual accounting for your processed gas, view the Revised Processed Gas in a Non-Index Zone (Major Portion) Using Alternative Dual Accounting example. You can make an election for alternative dual accounting using the Form ONRR-4410 Part B.
• If you elected actual dual accounting on Form ONRR-4410 Part B for your processed gas, view the Revised Processed Gas in a Non-Index Zone (Major Portion) Using Actual Dual Accounting example.
  
• If you believe you are exempt from dual accounting for your processed gas (see §§1206.176(c)-(e)), you should file Form ONRR-4410 Part A for each lease you believe to be exempt. Regardless of your dual accounting status, you still need to fulfill the major portion provision of your lease. If you need assistance with this comparison, please contact Royalty Valuation at royaltyvaluation@onrr.gov.
  

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