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Subpart D-Federal and Indian Gas

SOURCE: 53 FR 1271, Jan. 15, 1988, unless otherwise noted.

8 202.150 Royalty on gas.

(a) Royalties due on gas production from leases subject to the requirements of this subpart, except helium produced from Federal leases, shall be at the rate established by the terms of the lease. Royalty shall be paid in value unless MMS requires payment in kind. When paid in value, the royalty due shall be the value, for royalty purposes, determined pursuant to 30 CFR part 206 of this title multiplied by the royalty rate in the lease.

(b)(1) All gas (except gas unavoidably lost or used on, or for the benefit of, the lease, including that gas used off-lease for the benefit of the lease when such off-lease use is permitted by the MMS or BLM, as appropriate) produced from a Federal or Indian lease to which this subpart applies is subject to royalty.

(2) When gas is used on, or for the benefit of, the lease at a production facility handling production from more than one lease with the approval of MMS or BLM, as appropriate, or at a production facility handling unitized or communitized production, only that proportionate share of each lease's production (actual or allocated) necessary to operate the production facility may be used royalty free.

(3) Where the terms of any lease are inconsistent with this subpart, the lease terms shall govern to the extent of that inconsistency.

(c) If BLM determines that gas was avoidably lost or wasted from an onshore lease, or that gas was drained from an onshore lease for which compensatory royalty is due, or if MMS determines that gas was avoidably lost or wasted from an OCS lease, then the value of that gas shall be determined in accordance with 30 CFR part 206.

(d) If a lessee receives insurance compensation for unavoidably lost gas, royalties are due on the amount of that compensation. This paragraph shall not apply to compensation through self-insurance.

(e)(1) In those instances where the lessee of any lease committed to a Fed

erally approved unitization or communitization agreement does not actually take the proportionate share of the production attributable to its Fed. eral or Indian lease under the terms of the agreement, the full share of production attributable to the lease under the terms of the agreement nonetheless is subject to the royalty payment and reporting requirements of this title. Except as provided in paragraph (e)(2) of this section, the value for royalty purposes of production attributable to unitized or communitized leases will be determined in accordance with 30 CFR part 206. In applying the requirements of 30 CFR part 206, the circumstances involved in the actual disposition of the portion of the production to which the lessee was entitled but did not take shall be considered as controlling in arriving at the value for royalty purposes of that portion, as if the person actually selling or disposing of the production were the lessee of the Federal or Indian lease.

(2) If a Federal or Indian lessee takes less than its proportionate share of agreement production, upon request of the lessee MMS may authorize a royalty valuation method different from that required by paragraph (e)(1) of this section, but consistent with the purpose of these regulations, for any volumes not taken by the lessee but for which royalties are due.

(3) For purposes of this subchapter, all persons actually taking volumes in excess of their proportionate share of production in any month under a unitization or communitization agreement shall be deemed to have taken ratably from all persons actually taking less than their proportionate share of the agreement production for that month.

(4) If a lessee takes less than its proportionate share of agreement produc. tion for any month but royalties are paid on the full volume of its proportionate share in accordance with the provisions of this section, no additional royalty will be owed for that lease for prior periods at the time the lessee subsequently takes more than its proportionate share to balance its account or when the lessee is paid a sum of money by the other agreement participants to balance its account.

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lease, unit area, or communitized area, when the reinjection is included in a plan of development or operations and the plan has received BLM or MMS approval for onshore or offshore operations, respectively, until such time as they are finally produced from the reservoir for sale or other disposition off-lease.

(f) For production from Federal and Indian leases which are committed to federally-approved unitization or communitization agreements, upon quest of a lessee MMS may establish the value of production pursuant to a method other than the method required by the regulations in this title if: (1) The proposed method for establishing value is consistent with the requirements of the applicable statutes, lease terms and agreement terms; (2) to the extent practical, persons with an interest in the agreement, including royalty interests, are given notice and an opportunity to comment on the proposed valuation method before it is authorized; and (3) to the extent practical, persons with an interest in a Federal or Indian lease committed to the agreement, including royalty interests, must agree to use the proposed method for valuing production from the agreement for royalty purposes. 8 202.151 Royalty on processed gas.

(a) A royalty, as provided in the lease, shall be paid on the value of: (1) Any condensate recovered downstream of the point of royalty settlement without resorting to processing; and (2) residue gas and all gas plant products resulting from processing the gas produced from a lease subject to this subpart. The MMS shall authorize a processing allowance for the reasonable, actual costs of processing the gas produced from Federal and Indian leases. Processing allowances shall be determined in accordance with subpart D of 30 CFR part 206.

(b) A reasonable amount of residue gas shall be allowed royalty free for operation of the processing plant, but no allowance shall be made for boosting residue gas or other expenses incidental to marketing, except as provided in 30 CFR part 206. In those situations where a processing plant processes gas from more than one lease, onl that proportionate share of each lease's residue gas necessary for the operation of the processing plant shall be allowed royalty free.

(c) No royalty is due on residue gas, or any gas plant product resulting from processing gas, which is reinjected into a reservoir within the same

8 202.152 Standards for reporting and

paying royalties on gas. (a)(1) Gas volumes and Btu heating values, if applicable, shall be determined under the same degree of water saturation. Gas volumes shall be reported in units of one thousand cubic feet (mcf), and Btu heating value shall be reported at a rate of Btu's per cubic foot, at a standard pressure base of 14.73 pounds per square inch absolute (psia) and a standard temperature base of 60 °F, except that for OCS leases in the Gulf of Mexico, gas volumes and Btu heating values shall be reported at a standard pressure base of 15.025 psia and a standard temperature base of 60 F. Gas volumes and Btu heating values shall be reported, for royalty purposes, on the same water vapor saturated or unsaturated basis prescribed by Federal Energy Regulatory Commission (FERC) regulation, or on the basis prescribed in the lessee's gas sales contract provided that the sales contract does not conflict with FERC regulation.

(2) The frequency and method of Btu measurement as set forth in the lessee's contract shall be used to determine Btu heating values for reporting purposes. However, the lessee shall measure the Btu value at least semiannually by recognized standard industry testing methods even if the lessee's contract provides for less frequent measurement.

(b)(1) Residue gas and gas plant product volumes shall be reported as specified in this paragraph.

(2) Carbon dioxide (CO2), nitrogen (N2), helium (He), residue gas, and any other gas marketed as a separate product shall be reported by using the same standards specified in paragraph (a) of this section.

(3) Natural gas liquids (NGL) volumes shall be reported in standard

U.S. gallons (231 cubic inches) at 60 (2) Geothermal resources that are 'F.

unavoidably lost, as determined by the (4) Sulfur (S) volumes shall be re- Bureau of Land Management (BLM), ported in long tons (2,240 pounds). and geothermal resources that аге

reinjected prior to use on or off the Subpart E-Solid Minerals, General- lease, as approved by BLM, are not [Reserved)

subject to royalty. The Minerals Man

agement Service (MMS) will allow free Subpart F-Coal

of royalty a reasonable amount of geo

thermal energy necessary to generate 8 202.250 Overriding royalty interest. electricity for internal powerplant op

The regulations governing overrid- erations or to generate electricity reing royalty interests, production pay- turned to the lease for lease operments, or similar interests created ations. If a powerplant uses geotherunder Federal coal leases are in 43 mal production from more than one CFR Group 3400.

lease, or uses unitized or communi.

tized production, only that proportion(54 FR 1522, Jan. 13, 1989)

ate share of each lease's production

(actual or allocated) necessary to operSubpart G-Other Solid Minerals

ate the powerplant may be used royal[Reserved)

ty free. The MMS will also allow free

of royalty a reasonable amount of Subpart H-Geothermal Resources

commercially demineralized water nec

essary for powerplant operations or SOURCE: 56 FR 57275, Nov. 8, 1991, unless otherwise used on or for the benefit of otherwise noted.

the lease. 8 202.350 Scope and definitions.

(3) Royalties on byproducts are due

at the time the recovered byproduct is (a) This subpart is applicable to all

used, sold, or otherwise finally disgeothermal resources produced from

posed of. Byproducts produced and Federal geothermal leases issued pur

added to stockpiles or inventory do not suant to the Geothermal Steam Act of 1970, as amended (30 U.S.C. 1001 et

require payment of royalty until the

byproducts are sold, utilized, or otherseq.). (b) The definitions in 30 CFR

wise finally disposed of. The MMS 206.351 are applicable to this subpart.

may ask BLM to increase the lease

bond to protect the lessor's interest 8 202.351 Royalties geothermal when BLM determines that stockpiles

or inventories become excessive. (a) Royalties on geothermal re

(c) If BLM determines that geothersources, including byproduct minerals mal resources (including byproducts) and commercially demineralized were avoidably lost or wasted from the water, shall be at the royalty rate(s) lease, or that geothermal resources specified in the lease, unless the Secre- (including byproducts) were drained tary of the Interior temporarily from the lease for which compensatowaives, suspends, or reduces that ry royalty is due, the value of those rate(s). Royalties shall be paid in geothermal resources shall be detervalue. The royalty due shall be the

mined in accordance with subpart H of value determined pursuant to subpart 30 CFR part 206. H of 30 CFR part 206 multiplied by (d) If a lessee receives insurance or the royalty rate in the lease.

other compensation for unavoidably (b)(1) Royalties are due on all geo

lost geothermal resources (including thermal resources, except those speci- byproducts), royalties at the rates fied in paragraph (b)(2) of this section,

specified in the lease are due on the that are produced from a lease and are

amount of that compensation. This sold or utilized by the lessee or are reasonably susceptible to sale or utili

paragraph shall not apply to compenzation by the lessee.

sation through self-insurance.

on

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sources.

8 202.352 Minimum royalty.

In no event shall the lessee's annual royalty payments for any producing lease be less than the minimum royalty established by the lease.

MMS-2014 in hundreds of gallons the nearest hundred gallons.

(e) Lessees are not required to repc the quality of geothermal resource including byproducts, to MMS. TI lessee must maintain quality measur ments for audit and valuation pu poses. Quality measurements includ but are not limited to, temperatur and chemical analyses for fluid ge thermal resources and chemical anal ses, weight percent, or other puri measurements for byproducts.

Subpart 1-OCS Sulfur-[Reserved

PART 203_RELIEF OR REDUCTION

ROYALTY RATES

Subpart A-General Provisions—[Reserved

Subpart B-Oil, Gas and OCS Sulfur, Genere

Sec. 203.50 Reduction of royalty or net pro

share.

Subpart C-Federal and Indian Oil

[Reserved)

Subpart D-Federal and Indian Gas

[Reserved)

8 202.353 Measurement standards for re

porting and paying royalties. (a) For geothermal resources used to generate electricity, the quantity on which royalty is due shall be reported on Form MMS-2014 (Report of Sales and Royalty Remittance) as follows:

(1) For geothermal resources valued under arm's-length or non-arm'slength contracts, quantities shall be reported in:

(i) Kilowatthours to the nearest whole kilowatthour if the contract specifies payment in terms of generated electricity,

(ii) Thousands of pounds to the nearest whole thousand pounds if the contract specifies payment in terms of weight, or

(iii) Millions of Btu's to the nearest whole million Btu if the contract specifies payment in terms of heat or thermal energy.

(2) For geothermal resources valued by the netback procedure pursuant to 30 CFR 206.352(c)(1)(ii) or (d)(1)(ii), the quantities shall be reported in kilowatthours to the nearest whole kilowatthour.

(b) For geothermal resources used in direct utilization processes, the quantity on which royalty is due shall be reported on Form MMS-2014 in:

(1) Millions of Btu's to the nearest whole million Btu if valuation is in terms of thermal energy used or displaced,

(2) Hundreds of gallons to the nearest hundred gallons of geothermal fluid produced if valuation is in terms of volume, or

(3) Other measurement unit approved by MMS for valuation and reporting purposes.

(c) For byproduct minerals, the quantity on which royalty is due shall be reported on Form MMS-2014 consistent with MMS-established reporting standards.

(d) For commercially demineralized water, the quantity on which royalty is due shall be reported on Form

Subpart E-Solid Minerals, General

[Reserved)

Subpart F-Coal

203.250 Advance royalty. 203.251 Reduction in royalty rate or rent:

Subpart G-Other Solid Minerals—[Reserve

Subpart H-Geothermal Resources,

(Reserved]

Subpart 1-OCS Sulfur—[Reserved]

AUTHORITY: 25 U.S.C. 396 et seq.; 25 U.S. 396a et seq.; 25 U.S.C. 2101 et seq.; 30 U.S. 181 et seq.; 30 U.S.C. 351 et seq.; 30 U.S. 1001 et seq.; 30 U.S.C. 1701 et seq.; 31 U.S. 9701; 43 U.S.C. 1301 et seq.; 43 U.S.C. 1331 seq.; and 43 U.S.C. 1801 et seq.

Subpart A-General Provisions

[Reserved)

Aug. 5, 1983, and further redesignated at 53 FR 1218, Jan 15, 1988)

Subpart B-Oil, Gas and OCS Sulfur,

General

Subpart C-Federal and Indian Oil

[Reserved)

Subpart D-Federal and Indian Gas

[Reserved]

Subpart E-Solid Minerals, General

(Reserved]

Subpart F-Coal

8 203.250 Advance royalty.

Provisions for the payment of advance royalty in lieu of continued operation are contained at 43 CFR 3483.4.

(54 FR 1522, Jan. 13, 1989)

8 203.251 Reduction in royalty rate or

rental. An application for reduction in coal royalty rate or rental shall be filed and processed in accordance with 43 CFR Group 3400. (54 FR 1522, Jan. 13, 1989)

8 203.50 Reduction of royalty or net profit

share. (a) In order to promote increased production on the lease area through direct, secondary, or tertiary recovery means, the Director may reduce or eliminate any royalty or net profit share on the entire leasehold, or on any deposit, tract, or portion thereof that is segregated for royalty purposes.

(b) An application for relief under paragraph (a) of this section must contain: the serial number of the lease; the name of the titleholder of record; a description of the area included in the lease; the number, location, and status of each well that has been drilled; and a tabulated statement for each month, covering a period of not less than 6 months prior to the date of filing the application, of the aggregate amount of minerals subject to royalty or net profit share computed in accordance with the lease and applicable regulations. Every application must also contain a detailed statement of: the cost of operating the entire lease; the income from the sale of any products from the lease; and all other facts tending to show whether the wells can be successfully operated under the royalty or net profit share fixed in the lease. Full information shall be furnished as to whether royalties or payments out of production are paid to anyone other than the United States, the amounts paid, and the efforts made to reduce them. The applicant must also file agreements of the holders of the lease and of royalty holders to a reduction of all other royalties from the leasehold to an aggregate not in excess of one half the revised Gov. ernment royalty or net profit share that would result if the request for a reduction were allowed.

(c) An application for relief under paragraph (a) of this section shall be filed in triplicate with the Director. (44 FR 61892, Oct. 26, 1979; 45 FR 20464, Mar. 28, 1980. Redesignated at 48 FR 35641,

Subpart G-Other Solid Minerals

[Reserved

Subpart H-Geothermal Resources,

[Reserved]

Subpart 1-OCS Sulfur-[Reserved)

PART 206–PRODUCT VALUATION

Subpart A-General Provisions

Sec. 206.10 Information collection.

Subpart B-Oil, Gas, and OCS Sulfur,

General-{Reserved]

Subpart C-Federal and Indian Oil

206.100 Purpose and scope. 206.101 Definitions. 206.102 Valuation standards. 206.103 Point of royalty settlement. 206.104 Transportation allowances-gener

al. 206.105 Determination of transportation

allowances.

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