Indian Example: Processed Gas Reporting (Arm’s-Length Dedicated Contract) in an Index Zone with Actual Dual Accounting
Overview
The lease and contracts for this example meet all the following conditions:
- The gas is produced from an Indian oil and gas lease located within an index zone.
- The lease contains a major portion provision (or provides for the Secretary to determine value) and requires accounting for comparison.
- The sales contract is for processed gas under an arm’s-length dedicated contract (30 CFR §1206.172(b)(3)). Dedicated means a contractual commitment to deliver gas production (or a specified portion of production) from a lease or well when that production is specified in a sales contract and that production must be sold pursuant to that contract to the extent that production occurs from that lease or well. (§1206.171)
- Gas for royalty purposes is based on the higher of the index-based value in §1206.172(d) or gross proceeds under §1206.174(b).
- The lessee elected actual dual accounting to satisfy the “accounting for comparison” lease provision.
If you have any questions regarding whether this example applies to your situation, contact royaltyvaluation@onrr.gov. You can find a map of Indian index zones on Indian Gas Index Zone Pricing.
As this example proceeds, “you” refers to the lessee or their designee as defined in §1206.20: “the person whom the lessee designates to report and pay the lessee's royalties for a lease.”
This example walks you through the royalty calculation and reporting for each product code and completes relevant fields on a sample Form ONRR2014 after each step. This example only covers the valuation-related fields in the order they appear on the Form ONRR-2014. You can find more information about product codes, complete instructions on filing the Form ONRR-2014, and other reporting topics in the ONRR Reporter and Payor Handbooks.
Locating the Indian Index Zone Price
Indian Gas Index Zone Pricing: Each month, ONRR publishes natural gas prices for the six Indian index zones referenced in §1206.172.
Downloadable Example
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Detailed Example
Note: The following is based on a sample statement. Plant statements may vary. Be sure to read carefully and contact royaltyvaluation@onrr.gov if you need further assistance.
These assumptions are for purposes of this example only. The assumptions provide the basis to show you how to perform the necessary calculations. Your situation may vary from these assumptions. Please contact royaltyvaluation@onrr.gov with specific questions.
Assumptions for this example:
- The gas is produced from an Indian lease in the Central Rocky Mountain Index Zone.
- The gas is valued as processed gas.
- The gas is transported, processed, and sold under arm’s-length contracts.
- The processor retains 15% of the residue gas and NGLs.
- No condensate is recovered along the pipeline or in the gas plant. You should check your statement or transportation invoice for condensate. If you have questions on how to value or report condensate, contact royaltyvaluation@onrr.gov.
- The royalty rate is 18%.
- The prices per gallon of NGL components shown on the example gas plant statement ("price at the plant") are the component prices downstream of the gas plant less the processor's transportation and fractionation (T&F) fees. The processor deducted a post-plant NGL transportation fee of $0.05/gallon and an NGL fractionation fee of $0.07/gallon from the downstream price. We provide the T&F fee; you may need to check your contract or other source for the amount. The transportation portion of the T&F fee for this example is NOT a "transportation factor" under the regulations at 30 CFR §1206.178(a)(5). NOTE: This situation falls under "Scenario 2" in the Processed Gas Reporting: Minimum Value Provision for NGLs example. Use that example for additional information on calculating the regulatory minimum NGL value.
- The lease instrument for this example does not allow deductions for transportation or processing costs. Therefore, no allowances will be calculated or taken.
- The production month is January 2019 (as shown on the example statement).
- The Indian index zone price is the January 2019 price for the Central Rocky Mountain index zone.
- The NGL minimum value provision for production in Utah under §1206.174(g)(2)(i)(B) uses the following Conway, Kansas published prices:
| Component | Purity Ethane (C2) | Propane (C3) | Isobutane (iC4) | Normal Butane (nC4) | Natural Gasoline (C5+) |
|---|---|---|---|---|---|
| $/gallon | 0.24890 | 0.85283 | 1.43603 | 1.34133 | 2.17513 |
Determining Dual Accounting
Many Indian leases require accounting for comparison, or “dual accounting.” The following is one example of dual accounting language: “… and that royalty will be computed on the value of gas or casinghead gas, or on the products thereof (such as residue gas, natural gasoline, propane, butane, etc.), whichever is the greater.” (Emphasis added) Dual accounting may not be the only requirement of your lease. Your reporting may also be subject to other requirements. Please read the complete details of your lease to be sure you meet all the provisions in it.
There are two choices for dual accounting—actual and alternative. You make this election using Form ONRR-4410 Part B
Assume, for this example, that the lessee chose actual dual accounting. Actual dual accounting requires you to determine which is higher (§1206.176(a)): the royalty value of the processed gas or the royalty value of the unprocessed gas. If you need guidance on alternative dual accounting, refer to the Processed Gas Reporting (Arm’s-Length Dedicated Contract) in an Index Zone Using Alternative Dual Accounting example.
When calculating royalties due for gas sold under an arm’s-length dedicated contract, you should follow this process:
- Part A: Calculate the gross proceeds received for the gas sale under §1206.174.
- Part B: Calculate the index zone value under §1206.172 and perform actual dual accounting under §1206.176.
- Part C: Compare the values determined in parts A and B and report and pay on the higher value.
Part A - Calculate the Gross Proceeds, PC 03 Residue Gas
Royalty is due on residue gas resulting from processing, including disallowed plant fuel.
This example includes the assumption the payor has not unbundled. However, the regulations at 30 CFR §1206.179(e) allow for a reasonable amount of plant fuel royalty free. You may wish to determine the reasonable portion of plant fuel and exclude it from royalty calculations.
Step 1:
In order to determine the disallowed 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 Btu factor is 1.13228 MMBtu/Mcf
Step 2:
Calculate the disallowed plant fuel volume (Mcf):
- Identify the total MMBtu 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 disallowed 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 disallowed 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 disallowed 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 gas 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 gross proceeds look like so far:
| PC | Sales Volume | Gas MMBtu | Sales Volume | RVPA | Trans Allow | Proc Allow | RVLA |
|---|---|---|---|---|---|---|---|
| 03 | 1,986.08 | 2,248.79 | $7,059.06 | $1,270.63 |
Part A: Calculate the Gross Proceeds, PC 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:
- Calculate the regulatory minimum price (the published NGL price less the regulatory adjustment)
- Determine the price at the plant
- 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 refer to 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, the minimum value for production in Utah (where our hypothetical lease is located) under §1206.174(g)(2)(i)(B), is the published NGL price at Conway, Kansas less seven cents. Below are the published NGL prices at Conway, Kansas:
| Component | Purity Ethane (C2) | Propane (C3) | Isobutane (iC4) | Normal Butane (nC4) | Natural Gasoline (C5+) |
|---|---|---|---|---|---|
| $/gallon | 0.24890 | 0.85283 | 1.43603 | 1.34133 | 2.17513 |
Step 1a:
Calculate the regulatory minimum price by adjusting the published NGL component price, under §1206.174(g). For production in Utah, 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):
| Component | Published NGL Price (/gal) | Regulatory Adjustment (/gal) | Regulatory Minimum Price (/gal) | Price at the plant (/gal) | Higher Price? |
|---|---|---|---|---|---|
| Ethane | $0.24890 | – $0.07 | = $0.17890 | $0.194145 | Price at Plant |
| Propane | $0.85283 | – $0.07 | = $0.78283 | $0.810270 | Price at Plant |
| Isobutane | $1.43603 | – $0.07 | = $1.36603 | $1.365051 | Regulatory Minimum Price |
| Normal Butane | $1.34133 | – $0.07 | = $1.27133 | $1.261770 | Regulatory Minimum Price |
| Natural Gasoline | $2.17513 | – $0.07 | = $2.10513 | $2.049583 | Regulatory Minimum Price |
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 Regulatory Minimum Price Components (Step 2a):
| Component | Price at Plant (/gal) + T&F fee (/gal) | Downstream Sales Price (/gal) | Gallons | Value |
|---|---|---|---|---|
| Ethane | $0.194145 + $0.12 | = $0.314145 | × 2,684.22 | = $843.23 |
| Propane | $0.810270 + $0.12 | = $0.930270 | × 2,038.99 | =$1,896.81 |
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):
| Component | Regulatory Minimum Price (/gal) | Gallons | Value |
|---|---|---|---|
| Isobutane | $1.36603 | × 367.74 | = $502.34 |
| Normal Butane | $1.27133 | × 647.12 | = $822.70 |
| Natural Gasoline | $2.10513 | × 1,165.52 | = $2,453.57 |
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.
Note: royalty is due on the NGLs actually recovered, not on the theoretical NGLs or the NGLs on which the lessee is actually paid.
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 look like so far:
| PC | Sales Volume | Gas MMBtu | Sales Value | RVPA | Trans Allow | Proc Allow | RVLA |
|---|---|---|---|---|---|---|---|
| 03 | 1,986.08 | 2,248.79 | $7,059.06 | $1,270.63 | |||
| 07 | 6,903.59 | $6,518.65 | $1,173.36 |
Part A: Calculate the Gross Proceeds, PC 15 – Pipeline Fuels
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)(2). One reasonable measure of value under this paragraph is the residue gas sales price (ensuring it is not reduced by marketable condition costs, per §1206.174(h)
- 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 gross proceeds look like so far:
| Prod Code | Sales Volume | Gas MMBtu | Sales Value | RVPA | Trans Allow | Proc Allow | RVLA |
|---|---|---|---|---|---|---|---|
| 03 | 1,986.08 | 2,248.79 | $7,059.06 | $1,270.63 | |||
| 07 | 6,903.59 | $6,518.65 | $1,173.36 | ||||
| 15 | 129.75 | 162.20 | $509.15 | $91.65 |
Part A: Calculate the Gross Proceeds, Royalty Value Less Allowances
Lease terms dictate if you can take allowances. If you have questions about unbundling or allowances, contact us at onrrunbundling@onrr.gov or royaltyvaluation@onrr.gov. 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 allowances for transportation and processing.
In this example, we assume our lease instrument does not allow deductions for transportation or processing costs (Assumption #8). Therefore, no allowances may be taken. Thus, the Royalty Value Prior to Allowances (RVPA) and Royalty Value Less Allowances (RVLA) are the same for all 3 product codes.
The final calculated gross proceeds look like this:
| PC | Sales Volume | Gas MMBtu | Sales Value | RVPA | Trans Allow | Proc Allow | RVLA |
|---|---|---|---|---|---|---|---|
| 03 | 1,986.08 | 2,248.79 | $7,059.06 | $1,270.63 | $1,270.63 | ||
| 07 | 6,903.59 | $6,518.65 | $1,173.36 | $1,173.36 | |||
| 15 | 129.75 | 162.20 | $509.15 | $91.65 | $91.65 |
Part B: Actual Dual Accounting Index Zone Calculations
Having completed part A, you now calculate the actual dual accounting value in part B:
- Part A: Calculate the gross proceeds received for the gas sale under §1206.174. (Complete)
- Part B: Calculate the index zone value under §1206.172 and perform actual dual accounting under §1206.176.
- Part C: Compare the values determined in parts A and B and report and pay on the higher value.
Step 1:
Locate the index zone price on the Indian Gas Index Prices table. In this example, the lease is in the Central Rocky Mountain index zone.
- The production month is January 2019
- The index zone price is $3.98/MMBtu
Step 2:
Calculate the residue gas index zone value using the index zone price:
- Multiply the residue gas sales MMBtu determined under Step 4 in PC 03 (2,248.79 MMBtu) by the index zone price ($3.98/MMBtu)
- The residue gas index zone value is $8,950.18
Step 3:
Calculate the Index-Zone Royalty Value Prior to Allowances (RVPA) and the Royalty Value Less Allowances (RVLA) for residue gas:
- Multiply the index-zone sales value for the residue gas calculated in Step 2 ($8,950.18) by the royalty rate (18%)
- The index-zone RVPA for residue gas is $1,611.03
- When you value a gas product using the index-zone price, you may not take a transportation allowance (§1206.172(d)(8))
- With no allowances, the RVLA equals the RVPA
- The RVLA is $1,611.03
Step 4:
Determine the index pipeline fuel sales value using the index zone price:
- Multiply the pipeline fuel MMBtu (162.20 MMBtu) (D) by the index zone price ($3.98/MMBtu)
- The index-zone pipeline fuel sales value is $645.56
Step 5:
Calculate the Index Royalty Value Prior to Allowances (RVPA) and the Royalty Value Less Allowances (RVLA) for pipeline fuel:
- Multiply the index sales value for the pipeline fuel calculated under Step 3 ($645.56) by the royalty rate (18%)
- The index RVPA is $116.20
- When you value a gas product using the index zone price, you may not take a transportation allowance (§1206.172(d)(8))
- With no allowances, the RVLA equals the RVPA
- The RVLA is $116.20
Step 6:
Calculate the total index zone RVLA
- The value and royalty value of PC 07 remains the same as calculated in the gross proceeds section. ONRR does not publish index zone prices for NGLs.
- Add the RVLA for PC 07 calculated in Step 1 of Royalty Value Less Allowances ($1,176.36) to the index zone RVLA of PC 03 calculated in Step 4 ($1,611.03) and PC 15 calculated in Step 5 ($116.20)
- The total RVLA for the index reporting is $2,900.59
The Form ONRR-2014 lines using the index zone price are:
| PC | Sales Volume | Gas MMBtu | Sales Value | RVPA | Trans Allow | Proc Allow | RVLA |
|---|---|---|---|---|---|---|---|
| 03 | 1,986.08 | 2,248.79 | $8,950.18 | $1,611.03 | $1,611.03 | ||
| 07 | 6,903.59 | $6,518.65 | $1,173.36 | $1,173.36 | |||
| 15 | 129.75 | 162.20 | $645.56 | $116.20 | $116.20 |
Part B: Fulfill Dual Accounting Requirement
To fulfill actual dual accounting, you must calculate the unprocessed gas value at the royalty measurement point using the index-zone price and compare to the processed gas value calculated in Step 6.
Step 7:
Calculate the unprocessed gas MMBtu value at the royalty measurement point (RMP) using the index zone price:
- Multiply the RMP MMBtu (3,013 MMBtu) (B) by the index zone price ($3.98)
- The unprocessed gas RMP value is $11,991.74
Step 8:
Calculate the unprocessed gas RVPA and RVLA:
- When you value a gas product using the index value, you may not take a transportation allowance (§1206.172(d)(8))
- With no allowances, the RVLA equals the RVPA
- Multiply the unprocessed gas value calculated under Step 7 ($11,991.74) by the royalty rate (18%)
- The unprocessed gas RVPA and RVLA are $2,158.51
Step 9:
Compare the Processed Index Zone RVLA (from Step 6 above) to the Unprocessed Gas RVLA from Step 9:
- The Processed Index Zone RVLA from Step 6 is $2,900.59—this is the processed value
- The Unprocessed gas RVLA is $2,158.51—this is the unprocessed gas value
- The Processed Index Zone RVLA is the higher value
Part C: Comparing the Values Determined in Parts A and B
Having completed part A, you now calculate the actual dual accounting value in part B:
- Part A: Calculate the gross proceeds received for the gas sale under §1206.174. (Complete)
- Part B: Calculate the index zone value under §1206.172 and perform actual dual accounting under §1206.176. (Complete)
- Part C: Compare the values determined in parts A and B and report and pay on the higher value.
Step 1:
Compare the RVLA of the index-zone reporting to the total RVLA of the gross proceeds:
- The RVLA of the index-zone value calculated in Step 6 is $2,900.59
- The RVLA of the gross proceeds calculated in Step 3 of Royalty Value Less Allowances is $2,535.64
- The RVLA for the index-zone reporting is higher
| PC | Sales Volume | Gas MMBtu | Sales Value | RVPA | Trans Allow | Proc Allow | RVLA |
|---|---|---|---|---|---|---|---|
| 03 | 1,986.08 | 2,248.79 | $8,950.18 | $1,611.03 | $1,611.03 | ||
| 07 | 6,903.59 | $6,518.65 | $1,173.36 | $1,173.36 | |||
| 15 | 129.75 | 162.20 | $645.56 | $116.20 | $116.20 |
Sample Statement
This example addresses reporting and calculations for the following product codes. The BOLD BLUE letters refer to fields on the sample statement.
| Product | Location in Statement | |
|---|---|---|
| PC 03 Residue Gas | “Net Residue Mcf” (G) and “Net Residue MMBtu” (H) in the statement’s “Residue Settlement” section | |
| PC 07 Natural Gas Liquids (NGLs) | “Allocated” NGLs (L) in the statement’s “Component Settlement” section | |
| PC 15 Pipeline Fuel | “Contractual Field Deducts Mcf” (C) and “Contractual Field Deducts MMBtu” (D) in the statement’s “Wellhead Information” section |
Product Codes
This example addresses reporting and calculations for various product codes. You can find more information about product codes and reporting in the ONRR Reporter and Payor Handbooks.