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 4.0 calculator, and the OR-GREET 4.0 equivalent with the fuel transportation distance and mode modified for the fuel pathway to Oregon; (c) The CARB review report or staff summary for the approved fuel pathway; (d) A positive or qualified positive validation or verification statement for the pathway issued under the CARB verification program required by California Code of Regulations Title 17, § 95500; (e) Any other supporting materials relating to the fuel pathway, as requested by DEQ; and (f) If the applicant is seeking to use a provisional fuel 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 calendar 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 fuel 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) EPA’s assigned 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, or an equivalent figure for facilities that do not produce liquid fuels; (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; and (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 and any other materials or information related to the fuel pathway requested by DEQ: (a) The applicable simplified calculator with all necessary inputs completed, following the instructions in the applicable instruction manual dated December 2024 for that calculator; (b) The most recent RFS third party engineering report, if one has been conducted for the facility; and (c) Proof that the inputs completed in the simplified calculator supplied under subsection (a) are correct in the form of a positive or qualified 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 subsection (a). (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 4.0 model must first submit the information required in subsections (b) through (h) to DEQ and request approval of their proposed approach for modeling the carbon intensity of their pathway or pathways. In response to such a submission, DEQ may either approve it, deny it, or approve it with draft operating conditions that a verifier can use to determine the scope of the verification services they must provide. If DEQ denies the submission, DEQ must provide the applicant with an explanation why it was denied, and the applicant may resubmit information to seek an approval. Once the applicant gains DEQ’s initial approval, they may then seek verification of their application under OAR chapter 340, division 272, in order to satisfy subsection (a). Then they must submit the following and any other materials or information related to the fuel pathway requested by DEQ: (a) Proof that the Tier 2 model inputs are correct in the form of a positive or qualified 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 the data used to form the inputs for the Tier 2 calculator submitted under subsection (c); (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 calendar days but less than 24 months, it can apply for a provisional carbon intensity. An existing facility that undergoes a major modification that affects its fuel production process and energy use may also 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 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 registered party 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, or a temporary fuel pathway code otherwise approved and posted by DEQ under OAR 340-253-0450(12). A fuel producer may also apply to DEQ for approval to have a temporary fuel pathway code assigned to its facility. (a) The request must: (A) Be submitted within 45 calendar 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. DEQ may impose conditions on the use of a temporary fuel pathway code by an applicant in order to ensure the accuracy and proper reporting of the carbon intensity being used. (9) For hydrogen Tier 1 or Tier 2 applications where the hydrogen is produced using either or both biomethane and renewable electricity through a book and claim method: (a) The producer of the hydrogen must submit retirement records from an electronic tracking system recognized by DEQ such as WREGIS or M-RETS Renewable Thermal on an annual basis demonstrating that the environmental attributes of the renewable electricity and biomethane, as applicable, were not claimed in any other program except for one or more of the following: (A) The federal RFS; (B) Any federal tax credit program; and (C) The greenhouse gas reporting program under OAR chapter 340, division 215 or an equivalent emissions inventory applicable to hydrogen production that is out-of-state and the producer is required to report its energy consumption to such an inventory; and (b) If the producer of the hydrogen is making any claim regarding the use of the hydrogen as a vehicle fuel under any program described in subsection (a), the producer’s CFP claim must be for the same use and volume of hydrogen as is being claimed in the other program(s); (10) Review and approval process to use carbon intensities for fuels other than grid electricity and renewable electricity with a deemed CI of zero under OAR 340-253-0470. (a) For applications proposing to use CARB-approved fuel pathways, including provisional fuel pathways, DEQ will: (A) Confirm that the proposed fuel pathway is consistent with OR-GREET 4.0; and (B) Review the materials submitted under subsection (2) and request additional materials if necessary. (b) For applications proposing to use a Tier 1 or Tier 2 calculator, DEQ may approve the application if it can: (A) Replicate the calculator outputs; (B) Verify the energy consumption and other inputs; and (C) Agrees with the following in the application: (i) Its classification of its feedstock(s); (ii) The scope of its lifecycle and, for Tier 2 applications, how the process has been modeled and if the carbon intensity values are scientifically defensible in the DEQ’s engineering and scientific judgement; (iii) Any modifications to emissions factors; (iv) Any other aspects of the pathway(s) in the application that affect the carbon intensity value. (D) For Tier 2 pathway applications, if DEQ intends to approve an application, it first must: (i) Present a review report with a proposed carbon intensity value or values and operating conditions to the applicant or applicants. If the applicant or applicants accept the proposed review report, carbon intensity value(s) and operating conditions, DEQ will post the review report and application on its website for a 14-day public comment period. DEQ staff will work with the applicant to aggregate and summarize any submitted data in order to ameliorate concerns regarding trade secrets included in the application. The aggregated data must still allow external stakeholders to understand the pathway(s) and carbon intensity value(s) that DEQ is proposing to approve; and (ii) Based on comments received during that public comment period, DEQ may move forward with approving the application as provided in this section, deny the application, request additional information from the applicant or applicants, or modify the review report. If DEQ modifies the review report or receives additional information that has a material bearing on the proposed EER value, it will issue the modified review report and any affected supplemental materials for another round of public comment. (c) If DEQ has approved or denied an application for a carbon intensity under this rule, DEQ will notify the applicant of its determination. (d) DEQ may impose conditions in its approval of a carbon intensity under this rule. 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 and proper use of the approved carbon intensity. Failure to meet those conditions may result in the carbon intensity approval being revoked, an enforcement action being taken by DEQ, or both. (A) For applicants seeking a provisional fuel pathway, DEQ will specify the conditions used to establish the fuel pathway. (i) In order to maintain an active provisional fuel 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. (ii) At any point during the 24 months following the certification of a provisional fuel pathway, DEQ may revise as appropriate the CI score for the provisional fuel pathway based on new information or a better understanding of the fuel pathway. (iii) DEQ may remove the provisional status of the fuel pathway after the applicant provides 24 months of operational data with a positive or qualified positive verification status. (iv) For fuel pathways that are not subject to verification, DEQ may remove the provisional status upon review of 24 months of operational data demonstrating that the fuel 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 fuel pathway approval is revoked by CARB then: (i) The fuel pathway holder must inform DEQ within seven calendar 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 fuel pathways for use in Oregon at any time. (iv) If CARB modifies its approval of the fuel pathway, then the fuel pathway holder must notify DEQ of the modification not later than 14 calendar 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 fuel pathway status, within 30 calendar 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 under this rule, 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) Comply with the requirements of this division and OAR chapter 340, division 272. In addition to, and not in lieu of, any other remedies for violations of this division, failure to timely submit an annual fuel pathway report or a required verification statement for fuel pathways will result in the deactivation of those fuel pathways; (D) For non-provisional fuel pathways, a fuel producer must inform DEQ within fourteen calendar days after it becomes aware that its operational carbon intensity will exceed its certified carbon intensity on one or more fuel pathways; and (E) If a fuel 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) Annual Fuel Pathway Reports. 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: (A) 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; (B) If the fuel pathway is a recertification of a CARB-approved fuel pathway, the fuel pathway holder must comply with regulations under OAR 340-253-0450(10)(d)(B); (C) The annual fuel pathway report for renewable electricity and hydrogen pathways, in addition to the applicable calculator, must include invoices or metering records substantiating the quantity of renewable electricity or biomethane or low-CI inputs procured from a qualifying source. If the renewable electricity, biomethane, or other qualifying source of low-CI inputs is owned by another party, the unredacted contract by which the fuel pathway holder obtained those environmental attributes must be provided;(D) If a fuel or fuel production process involves biomethane, biogas, or renewable electricity, the fuel producer must provide the attestation regarding environmental attributes or proof of non-generation or retirement of any RECs or RTCs as required by OAR 340-253-0640 or OAR 340-253-0470(5)(d); and (E) For biomethane injected into a natural gas common carrier pipeline, then: (i) The retirement records for the RTCs from M-RETS Renewable Thermal or another renewable thermal tracking system recognized by DEQ. The use of an electronic tracking system is required instead of an attestation, and the specific volume of biomethane claimed as being used as a feedstock for the fuel production process must have been injected into the pipeline in the current or prior quarter as the fuel is being produced; (ii) If the renewable electricity, biomethane, or other qualifying source of low-CI inputs is owned by another party, the unredacted contract and unredacted invoices by which the fuel pathway holder obtained those environmental attributes must be provided; and (iii) Biomethane can only be claimed in this manner in a fuel pathway application as the feedstock for CNG, LNG, L-CNG or hydrogen production, and cannot be claimed as an energy source for another fuel production process; (F) Any fuel pathway holder, including a joint applicant, who is not subject to site visits by a third party verifier, whose fuel pathway involves the use of renewable or low-CI process energy, must submit invoices for that energy to the AFP. Additionally, for any renewable electricity, including an on-site or directly connected generator, that is used to reduce the carbon intensity of electricity used as a fuel or hydrogen production via electrolysis, the fuel 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. Any offsite source of renewable electricity must meet the qualifications in OAR 340-253-0470(5).; (G) 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; (H) Any additional information requested by DEQ after its review of the annual fuel pathway report; and (I) 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 new certified CI will take effect for the following reporting year. DEQ may elect to make the new certified CI a provisional pathway if it determines that the fuel production facility or fuel pathway has undergone a significant modification from its original certification, or is a novel fuel or fuel pathway from that facility. The fuel pathway holder may elect to add a margin of safety to the new certified CI. Prior to DEQ certifying the new pathways, the fuel pathway holder 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. For a fuel pathway with a carbon capture and sequestration project, that margin of safety elected to be added by a fuel producer must be added on top of any required contribution of credits to the reserve account established under OAR 340-253-1060. (g) If DEQ determines that a proposal for a 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. (h) Notwithstanding OAR 340-253-0670, DEQ may modify any approved fuel pathway CI or approval conditions upon receipt of a verification statement that shows that the verified operational CI is higher than the certified CI. (i) Any applicant for a fuel pathway under this rule 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. (j) In approving applications or adjusting certified CIs through an Annual Fuel Pathway Report for fuel producers that employ carbon capture and sequestration, DEQ may require the applicant to make a contribution of credits to the reserve account as described in OAR 340-253-1060. (11) Completeness determination process. DEQ will follow the steps described in subsections (a) through (d) to determine whether a fuel pathway application is complete. (a) For Tier 2 applications, DEQ will seek to determine whether the proposed modeling approach and application package is complete and valid within 1 month after receiving a application prior to releasing it for validation. (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 will determine if the supplemental submittal is complete within 30 calendar days, or will notify the party and identify the continued deficiencies within that time. 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 application. (12) 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 fuel pathway codes) under OAR 340-253-8010. DEQ may approve such substitute or temporary fuel pathway codes if it concludes they are technically sound and supported by appropriate evidence. If any are approved, DEQ will post these additional fuel 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 fuel pathway may be technically sound and supported by appropriate evidence, then it will post the proposed new substitute or temporary fuel 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 fuel pathway. (d) If DEQ concludes the proposed fuel 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. (13) 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 as required under subsection (a). 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) through (C) below and must be documented in the monitoring plan required under OAR 340-253-0600. (A) A written request for postponement must be submitted to DEQ not less than 30 calendar 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 14 calendar days of a request for documentation. (B) The request under paragraph (B) 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; (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; and (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. (14) 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. (15) Biomethane applications. In addition to the other requirements of this division, for any fuel pathway where biomethane is being injected into a natural gas common carrier pipeline to be reported in the CFP using book and claim accounting, the fuel pathway holder, fuel producer, or both must ensure that no other party can make a claim on the specific biomethane attributes that are being used in the CFP. If the biomethane is being injected into the pipe of a local distribution company, the fuel producer must have an agreement with that company along with any other purchaser of the physical gas that they will not make any claims on the biomethane reported through book and claim in this program. That agreement must be submitted at the time of the fuel pathway application or in the next annual fuel pathway report if the fuel pathway is currently certified. (16) For non-provisional pathways, if a fuel pathway's operational CI is found to be greater than its certified CI, the fuel pathway holder is out of compliance with this division and may be subject to investigation and enforcement by DEQ. (17) Transition from OR-GREET 3.0 to OR-GREET 4.0. (a) 2025 and 2026 Annual Fuel Pathway Reports. In addition to all the materials required to be submitted for the Annual Fuel Pathway report due in 2025 and 2026 under OAR 340-253-0400(9)(f), all fuel pathway holders must submit filled out copies of both the applicable OR-GREET 3.0 and OR-GREET 4.0 calculators for their fuel production facility, or the CA-GREET equivalent for recertification pathways. If the fuel pathway holder is required to go through verification, they must have their verifier review and confirm the data in both calculators. (b) All OR-GREET 3.0 fuel pathway codes may no longer be used for reporting as of January 1, 2026, unless the purpose of that reporting is to re-assign a quantity of fuel from the 3.0 fuel pathway code to the 4.0 fuel pathway code, where that quantity of fuel is in existing storage or transit in the state as of midnight on December 31, 2025. Statutory/Other Authority: ORS 468.020, 468A.266, 468A.268 & 468A.277 Statutes/Other Implemented: ORS 468.020 & ORS 468A.265 - 468A.277 History: DEQ 2-2025, amend filed 01/09/2025, effective 01/09/2025 DEQ 17-2022, amend filed 09/23/2022, effective 01/01/2023 DEQ 7-2021, amend filed 03/26/2021, effective 03/26/2021 DEQ 14-2020, amend filed 05/07/2020, effective 05/07/2020 DEQ 199-2018, amend filed 11/16/2018, effective 01/01/2019 DEQ 27-2017, amend filed 11/17/2017, effective 11/17/2017 DEQ 13-2015, f. 12-10-15, cert. ef. 1-1-16 DEQ 3-2015, f. 1-8-15, cert. ef. 2-1-15 DEQ 8-2012, f. & cert. ef. 12-11-12