Oregon Department of Environmental Quality

Rule Rule 340-253-0450
Obtaining a Carbon Intensity


(1)

Fuel producers can apply to obtain a carbon intensity by following the process to obtain a carbon intensity under this rule.

(2)

Applicants seeking approval to use a carbon intensity that is currently approved by the CARB must provide:

(a)

The application package submitted to CARB;

(b)

The CARB-approved Tier 1 or Tier 2 CA-GREET 3.0 calculator, and the OR-GREET 3.0 equivalent with the fuel transportation and distribution cells modified for that fuel’s pathway to Oregon;

(c)

The CARB review report for the approved fuel pathway;

(d)

Any other supporting materials relating to the pathway, as requested by DEQ; and

(e)

If the applicant is seeking to use a provisional pathway approved by CARB, then the applicant must submit to DEQ the ongoing documentation it provides to CARB, and as required in section (6). The applicant must provide DEQ within fourteen days:

(A)

Any additional documentation it has submitted to CARB; and

(B)

A notification of any changes to the status of its CARB-approved provisional pathway.

(3)

Applicants seeking to obtain a carbon intensity using either the Tier 1 or Tier 2 calculator must submit the following information:

(a)

Company name and full mailing address.

(b)

Company contact person’s contact information including the name, title or position, phone number, mobile phone number, facsimile number, email address, and website address.

(c)

Facility name (or names if more than one facility is covered by the application).

(d)

Facility address (or addresses if more than one facility is covered by the application).

(e)

Facility ID for facilities covered by the RFS program.

(f)

Facility geographical coordinates (for each facility covered by the application).

(g)

Facility contact person’s contact information including the name, title or position, phone number, mobile phone number, facsimile number, and email address.

(h)

Facility nameplate production capacity in million gallons per year (for each facility covered by the application).

(i)

If applicable, consultant’s contact information including the name, title or position, phone number, mobile phone number, facsimile number, email address, and website URL.

(j)

Declaration whether the applicant is applying for a carbon intensity for a Tier 1 or Tier 2 fuel.

(4)

In addition to the items in section (3), applicants seeking to obtain a carbon intensity for a Tier 1 fuel using one of the simplified calculators must submit the following:

(a)

The applicable simplified calculator with all necessary inputs completed, following the instructions in the applicable manual for that calculator;

(b)

A positive verification statement from an approved verification body, provided in compliance with OAR chapter 340, division 272, stating that it has reviewed and validated all of the data used to form the inputs for the Tier 1 calculator submitted under (a), or the invoices and receipts for all forms of energy consumed in the production process, all fuel sales, all feedstock purchases, and all co-products sold for the most recent 24 months of full commercial production, along with a summary of those invoices and receipts; and

(c)

The most recent RFS third party engineering report, if one has been conducted for the facility.

(5)

In addition to the items in section (3), applicants seeking to obtain a carbon intensity for a Tier 2 fuel using the full OR-GREET 3.0 model must submit the following:

(a)

A positive verification statement from an approved verification body, provided in compliance with OAR chapter 340, division 272, stating that it has reviewed and validated all of the data used to form the inputs for the Tier 2 calculator submitted under (c), or the invoices and receipts for all forms of energy consumed in the production process, all fuel sales, all feedstock purchases, and all co-products sold for the most recent 24 months of full commercial production, and a summary of those invoices and receipts;

(b)

The geographical coordinates of the fuel production facility;

(c)

A completed Tier 2 model;

(d)

Process flow diagrams that depict the complete fuel production process;

(e)

Applicable air permits issued for the facility;

(f)

A copy of the RFS third party engineering report, if available;

(g)

A copy of the RFS fuel producer co-products report; and

(h)

A lifecycle analysis report that describes the fuel pathway and describes in detail the calculation of carbon intensity for the fuel. The report shall contain sufficient detail to allow staff to replicate the carbon intensity the applicant calculated. The applicant must describe all inputs to, and outputs from, the fuel production process that are part of the fuel pathway.

(6)

Applicants seeking a provisional carbon intensity. If a fuel production facility has been in full commercial production for at least 90 days but less than 24 months, it can apply for a provisional carbon intensity.

(a)

The applicant shall submit operating records covering all periods of full commercial operation in accordance with sections (2) through (5).

(b)

DEQ may approve the provisional carbon intensity under section (9).

(c)

At any time before the plant reaches a full 24 months of full commercial production, DEQ may revise as appropriate the operational carbon intensity based on the required ongoing submittals or other information it learns.

(d)

If, after a plant has been in full commercial production for more than 24 months of full commercial production, the facility’s operational carbon intensity is higher than the provisionally-certified carbon intensity, DEQ will replace the certified carbon intensity with the operational carbon intensity in the Oregon Fuels Reporting System and adjust the credit balance accordingly.

(e)

If the facility’s operational carbon intensity appears to be lower than the certified carbon intensity, DEQ will take no action. The applicant may, however, petition DEQ for a new carbon intensity that reflects the operational data. In support of such a petition, the applicant must submit a revised application packet that fully documents the requested reduction.

(7)

Applicants employing co-processing at a petroleum refinery. Applicants employing co-processing of biogenic feedstocks at a petroleum refinery must submit all information required under sections (3) and (5).

(a)

For the renewable diesel or other renewable refinery product of the fuel, the applicant must also submit:

(A)

The planned proportions of biogenic feedstocks to be processed;

(B)

A detailed methodology for the attribution of biogenic feedstocks to the renewable products; and

(C)

The corresponding carbon intensities from each biogenic feedstock.

(b)

The attribution methodology will be subject to approval by DEQ and may be modified at DEQ’s discretion based on ongoing quarterly reporting of production data at the refinery.

(c)

DEQ may adjust the carbon intensities applied for under this section as it determines is appropriate.

(8)

Temporary Fuel Pathway Codes for Fuels with Indeterminate Carbon Intensities. A regulated party or credit generator that has purchased a fuel without a carbon intensity must submit a request to DEQ for permission to use a temporary fuel pathway code found in Table 9 under OAR 340-253-8010 (Tables), or a temporary fuel pathway code otherwise approved and posted by DEQ under OAR 340-253-0450 (Obtaining a Carbon Intensity)(11).

(a)

The request must:

(A)

Be submitted within 45 days of the end of the calendar quarter for which the applicant is seeking to use a temporary fuel pathway code; and

(B)

Explain and document that the production facility is unknown or that the production facility is known but there is no approved fuel pathway code.

(b)

Temporary fuel pathway codes may be used for up to two calendar quarters. If more time is needed to obtain a carbon intensity, the party that obtained the temporary fuel pathway must submit an additional request to DEQ for an extension of the authorization to use a temporary fuel pathway code.

(c)

If DEQ grants a request to use a temporary fuel pathway code, credits and deficits may be generated subject to the quarterly reporting provisions in OAR 340-253-0630 (Quarterly Reports).

(9)

Approval process to use carbon intensities for fuels other than electricity.

(a)

For applications proposing to use CARB-approved fuel pathways, including provisional pathways, DEQ will:

(A)

Confirm that the proposed fuel pathway is consistent with OR-GREET 3.0; and

(B)

Review the materials submitted under subsection (2).

(b)

For applications proposing to use the Tier 1 or Tier 2 calculators, DEQ may approve the application if it can:

(A)

Replicate the calculator outputs; and

(B)

Verify the energy consumption and other inputs.

(c)

If DEQ has approved or denied the application for a carbon intensity, DEQ will notify the applicant of its determination.

(d)

DEQ may impose conditions in its approval of the carbon intensity. Conditions may include specific limitations, recordkeeping or reporting requirements, adherence to protocols to assure carbon reduction or sequestration claims, or operational conditions that DEQ determines should apply to assure the ongoing accuracy of the approved carbon intensity. Failure to meet those conditions may result in the carbon intensity approval being revoked.

(A)

For applicants seeking a provisional pathway, DEQ will specify the conditions used to establish the pathway.

(i)

In order to maintain an active provisional pathway eligible to generate credits, the applicant must file the annual fuel pathway report and seek third-party verification if required under OAR 340-253-0700 (Third Party Verification Requirements).

(ii)

At any point during the 24 months following the certification of a provisional pathway, DEQ may revise as appropriate the CI score for the provisional pathway based on new information or a better understanding of the pathway.

(iii)

DEQ may remove the provisional status of the pathway after the applicant provides 24 months of operational data with a positive or qualified positive verification status.

(iv)

For pathways that are not subject to verification, DEQ may remove the provisional status upon review of 24 months of operational data demonstrating that the pathway data supports the provisional CI.

(B)

For a CARB-approved fuel pathway that DEQ has approved for use in Oregon, if at any time the pathway’s approval is revoked by CARB then:

(i)

The fuel pathway holder must inform DEQ within seven days of the revocation and provide DEQ with documentation related to that decision.

(ii)

Upon DEQ request, the fuel pathway holder must provide to DEQ additional documentation.

(iii)

DEQ may at its discretion revoke its approval of the pathway’s use in Oregon at any time.

(iv)

If CARB modifies its approval of the pathway then the fuel pathway holder must notify DEQ of the modification not later than 14 days after CARB’s modification and must provide to DEQ any accompanying documentation the fuel pathway holder received from CARB.

(v)

Based on the underlying facts that led to CARB’s modification of the pathway’s status, within 30 days DEQ may modify its approval, take no action, or revoke its approval and will provide the fuel pathway holder with written notice of its decision.

(e)

In order to receive and maintain an active fuel pathway code, the producer of any fuel must:

(A)

Maintain an active registration with the AFP;

(B)

Provide proof of delivery to Oregon through a physical pathway demonstration in the quarter in which the fuel is first reported in the Oregon Fuels Reporting System;

(C)

Beginning in calendar year 2021, each fuel pathway holder must submit an annual fuel pathway report into the AFP no later than March 31st of each calendar year. The annual fuel pathway report must include:

(i)

The certified version of the simplified OR-GREET or full OR-GREET calculator, as applicable, updated to include the most recent two calendar years of operational data;

(ii)

The annual fuel pathway report for renewable electricity and hydrogen lookup table pathways, in lieu of the CI calculator, must include invoices or metering records substantiating the quantity of renewable or low-CI inputs procured from a qualifying source.;

(iii)

If the fuel or fuel production process involves biomethane or renewable electricity, the fuel producer must provide the attestation regarding environmental attributes or proof of non-generation or retirement of any RECs as required by OAR 340-253-0640 (Specific Requirements for Reporting)(1)(d) or OAR 340-253-0470 (Determining the Carbon Intensity of Electricity)(3)(d);

(iv)

Any fuel pathway holder, including a joint applicant, who is not subject to site visits by a third party verifier, whose pathway involves the use of renewable or low-CI process energy, must submit invoices for that energy to the AFP. Additionally, for any on-site or directly connected renewable electricity that is used to reduce the carbon intensity of electricity used as a transportation fuel or hydrogen production via electrolysis, the pathway holder must upload records demonstrating that any renewable energy certificates generated were retired in WREGIS or another comparable, recognized REC tracking system for the purpose of lowering the certified CI, or for credit generation;

(v)

Any temporally-variable information that was requested or required by DEQ to be included in the initial application as supplemental information, or any required data or documentation listed in the pathway’s operating conditions. The information required to be submitted under this section must cover the same time period as the updated OR-GREET model required under subparagraph (i);

(vi)

If the verified operational CI as calculated from the operational data covering the prior two calendar years of production is found to be lower than the certified CI, and a positive verification statement is issued for this period, the fuel pathway holder may elect to keep the original certified CI, or may request to replace the certified CI with the verified operational CI. The pathway holder may elect to add a margin of safety to the new certified CI, and must submit an attestation that the new CI can be maintained through the next reporting period with the acknowledgement that exceeding the newly certified CI in subsequent annual reports or verifications is a violation of the requirements of this division; and

(vii)

If the operational CI is found to be greater than the certified CI, the fuel pathway holder is out of compliance with this division and may be subject to investigation and enforcement by DEQ;

(D)

Comply with the requirements of this division and OAR chapter 340, division 272. Failure to timely submit an annual fuel pathway report or a required verification statement for a facility’s pathways will result in the deactivation of those pathways; and

(E)

If a pathway employs carbon capture and sequestration, the fuel pathway holder or joint applicant must submit annual reports of greenhouse gas emissions reductions, project operations, and ongoing monitoring results. Reports must include measurements of relevant parameters sufficient to ensure that the quantification and documentation of CO2 sequestered is replicable and verifiable. DEQ may specify a protocol for measuring and reporting such information in its approval of such an application.

(f)

If DEQ determines the proposal for the carbon intensity has not met the criteria in subsection (b), DEQ will notify the applicant that the proposal is denied and identify the basis for the denial.

(g)

DEQ may modify an approved fuel pathway’s CI or approval conditions upon receipt of a verification statement that shows that the verified operational CI is higher than the certified CI.

(h)

Any applicant may include a margin of safety in its application which will increase its certified CI in order to account for potential process variability and to reduce the risk that it will violate this division by having its operational CI exceed its certified CI.

(10)

Completeness determination process.

(a)

For applications calculated using the Tier 1 or Tier 2 calculator, DEQ will determine whether the proposal is complete within 1 month after receiving a registration application.

(b)

If DEQ determines the proposal is complete, DEQ will notify the applicant in writing of the completeness determination.

(c)

If DEQ determines the proposal is incomplete, DEQ will notify the applicant of the deficiencies. The applicant has 30 calendar days to address the deficiencies or DEQ will deny the application. Upon request, DEQ may grant an extension of up to 30 additional days.

(d)

If the applicant submits supplemental information, DEQ has 30 calendar days to determine if the supplemental submittal is complete, or to notify the party and identify the continued deficiencies. This process may repeat until the application is deemed complete or 180 calendar days have elapsed from the date that the applicant first submitted the registration application.

(11)

Issuing additional substitute and temporary fuel pathway codes. For new fuels or new fuel blends being provided within Oregon, registered parties may request that DEQ issue additional fuel pathway codes that can be used in the same manner as those in Tables 8 or 9 (substitute or temporary pathway codes) under OAR 340-253-8010 (Tables). DEQ may approve such substitute or temporary pathway codes if it concludes they are technically sound and supported by appropriate evidence. If any are approved, DEQ will post these additional pathway codes in the Oregon Fuels Reporting System and on its public website for the Clean Fuels Program. All of the following requirements apply to such requests:

(a)

Requests must be made in writing to DEQ.

(b)

If DEQ concludes the proposed pathway may be technically sound and supported by appropriate evidence, then it will post the proposed new substitute or temporary pathway codes on its website and take comments for:

(A)

14 calendar days in the case of a substitute fuel pathway code; or

(B)

45 calendar days in the case of a temporary fuel pathway code.

(c)

DEQ will consider any comments received, make any modifications, if necessary, and make a final decision on the proposed pathway.

(d)

If DEQ concludes the proposed pathway is technically sound and supported by appropriate evidence, then DEQ may approve it and publish its final decision on its website.

(e)

Any newly approved substitute or temporary fuel pathway code will be effective for use in the quarter in which it is approved.

(12)

Measurement accuracy.

(a)

All measurement devices that log or record data for use in a fuel pathway application must comply with the manufacturer-recommended calibration frequency and precision requirements. If manufacturer-recommendations are not provided, the measurement devices must be calibrated at least every six years.

(b)

Requests to Postpone Calibration. For units and processes that operate continuously with infrequent outages, it may not be possible to meet manufacturer-recommended calibration deadlines for measurement devices. In such cases, the owner or operator may submit a written request to DEQ to postpone calibration or inspection until the next scheduled maintenance outage. Such postponements are subject to the procedures of paragraphs (A) and (B) below and must be documented in the monitoring plan required under OAR 340-253-0600 (Records).

(A)

A written request for postponement must be submitted to DEQ not less than 30 days before the required calibration, recalibration or inspection date. DEQ may request additional documentation to validate the operator’s claim that the device meets the accuracy requirements of this section. The operator shall provide any additional documentation to DEQ within ten (10) business days of a request for documentation.

(B)

The request must include:

(i)

The date of the required calibration, recalibration, or inspection;

(ii)

The date of the last calibration or inspection;

(iii)

The date of the most recent field accuracy assessment, if applicable;

(iv)

The results of the most recent field accuracy assessment, if applicable, clearly indicating a pass/fail status;

(v)

The proposed date for the next field accuracy assessment, if applicable;

(vi)

The proposed date for calibration, recalibration, or inspection which must be during the time period of the next scheduled shutdown. If the next shutdown will not occur within three years, this must be noted and a new request must be received every three years until the shutdown occurs and the calibration, recalibration or inspection is completed; and.

(vii)

A description of the meter or other device, including at a minimum the: make, model, installation date, location, parameter measured by the meter or other device, the rate of data capture by the meter or other device, description of how data from the meter or other device is used in a fuel pathway, calibration or inspection procedure, reason for delaying the calibration or inspection, proposed method to ensure that the precision requirements listed by the manufacturer are upheld, and the contact details for an individual at the fuel production facility who can answer questions about the meter or other device.

(C)

DEQ will approve or deny the request at its discretion based on whether or not it concludes that the device’s calibration is reasonably reliable.

(13)

Missing Data Provisions.

(a)

Meter Record, Accuracy, or Calibration Requirements Not Met. If a measurement device is not functional, not calibrated within the time period recommended by the manufacturer, or fails a field accuracy assessment, the fuel production facility operator must otherwise demonstrate to a verifier or DEQ that the reported data are accurate within +/-5 percent. The following requirements apply to such demonstration:

(A)

If the operator can demonstrate to the verifier or DEQ that reported data are accurate, the data are acceptable. The entity must then provide a detailed plan describing when the measurement device will be brought into calibration. This plan is subject to approval by DEQ; and

(B)

If the operator cannot demonstrate to the verifier or DEQ that reported data are accurate, the data is not acceptable and the missing data provisions in subsection (b) apply.

(b)

Missing Data Provisions. If missing data exists, the entity must submit for DEQ approval an alternate method of reporting the missing data. Alternate methods shall be evaluated on a case-by-case basis for reasonableness and continuity with the rest of the dataset. DEQ may choose to require a more conservative approach to the missing data if it is concerned that the alternative method may understate actual lifecycle emissions associated with the fuel or fuels produced by the facility.

(c)

Force Majeure Events. In the event of a facility shutdown or disruption drastically affecting production attributable to a force majeure event, the fuel pathway applicant or holder must notify DEQ.
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Last accessed
Jun. 8, 2021