(ii) Use the results from subsequent grab sampling events for all 15 minute periods starting with the 15-minute block in which the sample was collected and ending with the 15-minute block prior to the 15-minute block in which the next grab sample is collected. For the purpose of this requirement, use the time the sample was collected rather than the time the analytical results become available.
    (7) If the owner or operator monitors separate gas streams that combine to comprise the total flare vent gas flow, the 15-minute block average net heating value shall be determined separately for each measurement location according to the methods in paragraphs (l)(1) through (6) of this section and a flow-weighted average of the gas stream net heating values shall be used to determine the 15-minute block average net heating value of the cumulative flare vent gas.
    (m) Calculation methods for determining combustion zone net heating value. The owner or operator shall determine the net heating value of the combustion zone gas (NHVcz) as specified in paragraph (m)(1) or (2) of this section, as applicable.
    (1) Except as specified in paragraph (m)(2) of this section, determine the 15-minute block average NHVcz based on the 15-minute block average vent gas and assist gas flow rates using the following equation. For periods when there is no assist steam flow or premix assist air flow, NHVcz = NHVvg.

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Where:
NHVcz = Net heating value of combustion zone gas, Btu/scf.
NHVvg = Net heating value of flare vent gas for the 15-minute block period, Btu/scf.
Qvg = Cumulative volumetric flow of flare vent gas during the 15-minute block period, scf.
Qs = Cumulative volumetric flow of total steam during the 15-minute block period, scf.
Qa,premix = Cumulative volumetric flow of premix assist air during the 15-minute block period, scf.
    (2) Owners or operators of flares that use the feed-forward calculation methodology in paragraph (l)(5)(i) of this section and that monitor gas composition or net heating value in a location representative of the cumulative vent gas stream and that directly monitor flare supplemental gas flow additions to the flare must determine the 15-minute block average NHVcz using the following equation.

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Where:
NHVcz = Net heating value of combustion zone gas, Btu/scf.
NHVvg = Net heating value of flare vent gas for the 15-minute block period, Btu/scf.
Qvg = Cumulative volumetric flow of flare vent gas during the 15-minute block period, scf.
QNG2 = Cumulative volumetric flow of flare supplemental gas during the 15-minute block period, scf.
QNG1 = Cumulative volumetric flow of flare supplemental gas during the previous 15-minute block period, scf. For the first 15-minute block period of an event, use the volumetric flow value for the current 15-minute block period, i.e., QNG1=QNG2.
NHVNG = Net heating value of flare supplemental gas for the 15-minute block period determined according to the requirements in paragraph (j)(5) of this section, Btu/scf.
Qs = Cumulative volumetric flow of total steam during the 15-minute block period, scf.
Qa,premix = Cumulative volumetric flow of premix assist air during the 15-minute block period, scf.
    (n) Calculation methods for determining the net heating value dilution parameter. The owner or operator shall determine the net heating value dilution parameter (NHVdil) as specified in paragraph (n)(1) or (2) of this section, as applicable.
    (1) Except as specified in paragraph (n)(2) of this section, determine the 15-minute block average NHVdil based on the 15-minute block average vent gas and perimeter assist air flow rates using the following equation only during periods when perimeter assist air is used. For 15-minute block periods when there is no cumulative volumetric flow of perimeter assist air, the 15-minute block average NHVdil parameter does not need to be calculated.

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Where:
NHVdil = Net heating value dilution parameter, Btu/ft[2].
NHVvg = Net heating value of flare vent gas determined for the 15-minute block period, Btu/scf.
Qvg = Cumulative volumetric flow of flare vent gas during the 15-minute block period, scf.
Diam = Effective diameter of the unobstructed area of the flare tip for flare vent gas flow, ft. Use the area as determined in paragraph (k)(1) of this section and determine the diameter as

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Qs = Cumulative volumetric flow of total steam during the 15-minute block period, scf.
Qa,premix = Cumulative volumetric flow of premix assist air during the 15-minute block period, scf.
Qa,perimeter = Cumulative volumetric flow of perimeter assist air during the 15-minute block period, scf.
    (2) Owners or operators of flares that use the feed-forward calculation methodology in paragraph (l)(5)(i) of this section and that monitor gas composition or net heating value in a location representative of the cumulative vent gas stream and that directly monitor flare supplemental gas flow additions to the flare must determine the 15-minute block average NHVdil using the following equation only during periods when perimeter assist air is used. For 15-minute block periods when there is no cumulative volumetric flow of perimeter assist air, the 15-minute block average NHVdil parameter does not need to be calculated.

    View or download PDF
Where:
NHVdil = Net heating value dilution parameter, Btu/ft[2].
NHVvg = Net heating value of flare vent gas determined for the 15-minute block period, Btu/scf.
Qvg = Cumulative volumetric flow of flare vent gas during the 15-minute block period, scf.
QNG2 = Cumulative volumetric flow of flare supplemental gas during the 15-minute block period, scf.
QNG1 = Cumulative volumetric flow of flare supplemental gas during the previous 15-minute block period, scf. For the first 15-minute block period of an event, use the volumetric flow value for the current 15-minute block period, i.e., QNG1 =QNG2.
NHVNG = Net heating value of flare supplemental gas for the 15-minute block period determined according to the requirements in paragraph (j)(5) of this section, Btu/scf.
Diam = Effective diameter of the unobstructed area of the flare tip for flare vent gas flow, ft. Use the area as determined in paragraph (k)(1) of this section and determine the diameter as

    View or download PDF
Qs = Cumulative volumetric flow of total steam during the 15-minute block period, scf.
Qa,premix = Cumulative volumetric flow of premix assist air during the 15-minute block period, scf.
Qa,perimeter = Cumulative volumetric flow of perimeter assist air during the 15-minute block period, scf.
    (o) Emergency flaring provisions. The owner or operator of a flare that has the potential to operate above its smokeless capacity under any circumstance shall comply with the provisions in paragraphs (o)(1) through (7) of this section.
    (1) Develop a flare management plan to minimize flaring during periods of startup, shutdown, or emergency releases. The flare management plan must include the information described in paragraphs (o)(1)(i) through (vii) of this section.
    (i) A listing of all refinery process units, ancillary equipment, and fuel gas systems connected to the flare for each affected flare.
    (ii) An assessment of whether discharges to affected flares from these process units, ancillary equipment and fuel gas systems can be minimized or prevented during periods of startup, shutdown, or emergency releases. The flare minimization assessment must (at a minimum) consider the items in paragraphs (o)(1)(ii)(A) through (C) of this section. The assessment must provide clear rationale in terms of costs (capital and annual operating), natural gas offset credits (if applicable), technical feasibility, secondary environmental impacts and safety considerations for the selected minimization alternative(s) or a statement, with justifications, that flow reduction could not be achieved. Based upon the assessment, each owner or operator of an affected flare shall identify the minimization alternatives that it has implemented by the due date of the flare management plan and shall include a schedule for the prompt implementation of any selected measures that cannot reasonably be completed as of that date.
    (A) Modification in startup and shutdown procedures to reduce the quantity of process gas discharge to the flare.
    (B) Implementation of prevention measures listed for pressure relief devices in §63.648(j)(3)(ii)(A) through (E) for each pressure relief device that can discharge to the flare.
    (C) Installation of a flare gas recovery system or, for facilities that are fuel gas rich, a flare gas recovery system and a co-generation unit or combined heat and power unit.
    (iii) A description of each affected flare containing the information in paragraphs (o)(1)(iii)(A) through (G) of this section.
    (A) A general description of the flare, including whether it is a ground flare or elevated (including height), the type of assist system (e.g., air, steam, pressure, non-assisted), whether the flare is used on a routine basis or if it is only used during periods of startup, shutdown or emergency release, and whether the flare is equipped with a flare gas recovery system.
    (B) The smokeless capacity of the flare based on a 15-minute block average and design conditions. Note: A single value must be provided for the smokeless capacity of the flare.
    (C) The maximum vent gas flow rate (hydraulic load capacity).
    (D) The maximum supplemental gas flow rate.
    (E) For flares that receive assist steam, the minimum total steam rate and the maximum total steam rate.
    (F) For flares that receive assist air, an indication of whether the fan/blower is single speed, multi-fixed speed (e.g., high, medium, and low speeds), or variable speeds. For fans/blowers with fixed speeds, provide the estimated assist air flow rate at each fixed speed. For variable speeds, provide the design fan curve (e.g., air flow rate as a function of power input).
    (G) Simple process flow diagram showing the locations of the flare following components of the flare: Flare tip (date installed, manufacturer, nominal and effective tip diameter, tip drawing); knockout or surge drum(s) or pot(s) (including dimensions and design capacities); flare header(s) and subheader(s); assist system; and ignition system.
    (iv) Description and simple process flow diagram showing all gas lines (including flare waste gas, purge or sweep gas (as applicable), supplemental gas) that are associated with the flare. For purge, sweep, supplemental gas, identify the type of gas used. Designate which lines are exempt from composition or net heating value monitoring and why (e.g., natural gas, gas streams that have been demonstrated to have consistent composition, pilot gas). Designate which lines are monitored and identify on the process flow diagram the location and type of each monitor. Designate the pressure relief devices that are vented to the flare.
    (v) For each flow rate, gas composition, net heating value or hydrogen concentration monitor identified in paragraph (o)(1)(iv) of this section, provide a detailed description of the manufacturer's specifications, including, but not limited to, make, model, type, range, precision, accuracy, calibration, maintenance and quality assurance procedures.
    (vi) For each pressure relief device vented to the flare identified in paragraph (o)(1)(iv) of this section, provide a detailed description of each pressure release device, including type of relief device (rupture disc, valve type) diameter of the relief device opening, set pressure of the relief device and listing of the prevention measures implemented. This information may be maintained in an electronic database on-site and does not need to be submitted as part of the flare management plan unless requested to do so by the Administrator.
    (vii) Procedures to minimize or eliminate discharges to the flare during the planned startup and shutdown of the refinery process units and ancillary equipment that are connected to the affected flare, together with a schedule for the prompt implementation of any procedures that cannot reasonably be implemented as of the date of the submission of the flare management plan.
    (2) Each owner or operator required to develop and implement a written flare management plan as described in paragraph (o)(1) of this section must submit the plan to the Administrator as described in paragraphs (o)(2)(i) through (iii) of this section.
    (i) The owner or operator must develop and implement the flare management plan no later than January 30, 2019 or at startup for a new flare that commenced construction on or after February 1, 2016.
    (ii) The owner or operator must comply with the plan as submitted by the date specified in paragraph (o)(2)(i) of this section. The plan should be updated periodically to account for changes in the operation of the flare, such as new connections to the flare or the installation of a flare gas recovery system, but the plan need be re-submitted to the Administrator only if the owner or operator alters the design smokeless capacity of the flare. The owner or operator must comply with the updated plan as submitted.
    (iii) All versions of the plan submitted to the Administrator shall also be submitted to the following address: U.S. Environmental Protection Agency, Office of Air Quality Planning and Standards, Sector Policies and Programs Division, U.S. EPA Mailroom (E143-01), Attention: Refinery Sector Lead, 109 T.W. Alexander Drive, Research Triangle Park, NC 27711. Electronic copies in lieu of hard copies may also be submitted to<EMAIL_ADDRESS>    (3) The owner or operator of a flare subject to this subpart shall conduct a root cause analysis and a corrective action analysis for each flow event that contains regulated material and that meets either the criteria in paragraph (o)(3)(i) or (ii) of this section.
    (i) The vent gas flow rate exceeds the smokeless capacity of the flare based on a 15-minute block average and visible emissions are present from the flare for more than 5 minutes during any 2 consecutive hours during the release event.
    (ii) The vent gas flow rate exceeds the smokeless capacity of the flare and the 15-minute block average flare tip velocity exceeds the maximum flare tip velocity determined using the methods in paragraph (d)(2) of this section.
    (4) A root cause analysis and corrective action analysis must be completed as soon as possible, but no later than 45 days after a flare flow event meeting the criteria in paragraph (o)(3)(i) or (ii) of this section. Special circumstances affecting the number of root cause analyses and/or corrective action analyses are provided in paragraphs (o)(4)(i) through (v) of this section.
    (i) You may conduct a single root cause analysis and corrective action analysis for a single continuous flare flow event that meets both of the criteria in paragraphs (o)(3)(i) and (ii) of this section.
    (ii) You may conduct a single root cause analysis and corrective action analysis for a single continuous flare flow event regardless of the number of 15-minute block periods in which the flare tip velocity was exceeded or the number of 2 hour periods that contain more the 5 minutes of visible emissions.
    (iii) You may conduct a single root cause analysis and corrective action analysis for a single event that causes two or more flares that are operated in series (i.e., cascaded flare systems) to have a flow event meeting the criteria in paragraph (o)(3)(i) or (ii) of this section.
    (iv) You may conduct a single root cause analysis and corrective action analysis for a single event that causes two or more flares to have a flow event meeting the criteria in paragraph (o)(3)(i) or (ii) of this section, regardless of the configuration of the flares, if the root cause is reasonably expected to be a force majeure event, as defined in this subpart.
    (v) Except as provided in paragraphs (o)(4)(iii) and (iv) of this section, if more than one flare has a flow event that meets the criteria in paragraph (o)(3)(i) or (ii) of this section during the same time period, an initial root cause analysis shall be conducted separately for each flare that has a flow event meeting the criteria in paragraph (o)(3)(i) or (ii) of this section. If the initial root cause analysis indicates that the flow events have the same root cause(s), the initially separate root cause analyses may be recorded as a single root cause analysis and a single corrective action analysis may be conducted.
    (5) Each owner or operator of a flare required to conduct a root cause analysis and corrective action analysis as specified in paragraphs (o)(3) and (4) of this section shall implement the corrective action(s) identified in the corrective action analysis in accordance with the applicable requirements in paragraphs (o)(5)(i) through (iii) of this section.
    (i) All corrective action(s) must be implemented within 45 days of the event for which the root cause and corrective action analyses were required or as soon thereafter as practicable. If an owner or operator concludes that no corrective action should be implemented, the owner or operator shall record and explain the basis for that conclusion no later than 45 days following the event.
    (ii) For corrective actions that cannot be fully implemented within 45 days following the event for which the root cause and corrective action analyses were required, the owner or operator shall develop an implementation schedule to complete the corrective action(s) as soon as practicable.
    (iii) No later than 45 days following the event for which a root cause and corrective action analyses were required, the owner or operator shall record the corrective action(s) completed to date, and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates.
    (6) The owner or operator shall determine the total number of events for which a root cause and corrective action analyses was required during the calendar year for each affected flare separately for events meeting the criteria in paragraph (o)(3)(i) of this section and those meeting the criteria in paragraph (o)(3)(ii) of this section. For the purpose of this requirement, a single root cause analysis conducted for an event that met both of the criteria in paragraphs (o)(3)(i) and (ii) of this section would be counted as an event under each of the separate criteria counts for that flare. Additionally, if a single root cause analysis was conducted for an event that caused multiple flares to meet the criteria in paragraph (o)(3)(i) or (ii) of this section, that event would count as an event for each of the flares for each criteria in paragraph (o)(3) of this section that was met during that event. The owner or operator shall also determine the total number of events for which a root cause and correct action analyses was required and the analyses concluded that the root cause was a force majeure event, as defined in this subpart.
    (7) The following events would be a violation of this emergency flaring work practice standard.
    (i) Any flow event for which a root cause analysis was required and the root cause was determined to be operator error or poor maintenance.
    (ii) Two visible emissions exceedance events meeting the criteria in paragraph (o)(3)(i) of this section that were not caused by a force majeure event from a single flare in a 3 calendar year period for the same root cause for the same equipment.
    (iii) Two flare tip velocity exceedance events meeting the criteria in paragraph (o)(3)(ii) of this section that were not caused by a force majeure event from a single flare in a 3 calendar year period for the same root cause for the same equipment.
    (iv) Three visible emissions exceedance events meeting the criteria in paragraph (o)(3)(i) of this section that were not caused by a force majeure event from a single flare in a 3 calendar year period for any reason.
    (v) Three flare tip velocity exceedance events meeting the criteria in paragraph (o)(3)(ii) of this section that were not caused by a force majeure event from a single flare in a 3 calendar year period for any reason.
    (p) Flare monitoring records. The owner or operator shall keep the records specified in §63.655(i)(9).
    (q) Reporting. The owner or operator shall comply with the reporting requirements specified in §63.655(g)(11).
    (r) Alternative means of emissions limitation. An owner or operator may request approval from the Administrator for site-specific operating limits that shall apply specifically to a selected flare. Site-specific operating limits include alternative threshold values for the parameters specified in paragraphs (d) through (f) of this section as well as threshold values for operating parameters other than those specified in paragraphs (d) through (f) of this section. The owner or operator must demonstrate that the flare achieves 96.5 percent combustion efficiency (or 98 percent destruction efficiency) using the site-specific operating limits based on a performance evaluation as described in paragraph (r)(1) of this section. The request shall include information as described in paragraph (r)(2) of this section. The request shall be submitted and followed as described in paragraph (r)(3) of this section.
    (1) The owner or operator shall prepare and submit a site-specific test plan and receive approval of the site-specific performance evaluation plan prior to conducting any flare performance evaluation test runs intended for use in developing site-specific operating limits. The site-specific performance evaluation plan shall include, at a minimum, the elements specified in paragraphs (r)(1)(i) through (ix) of this section. Upon approval of the site-specific performance evaluation plan, the owner or operator shall conduct performance evaluation test runs for the flare following the procedures described in the site-specific performance evaluation plan.
    (i) The design and dimensions of the flare, flare type (air-assisted only, steam-assisted only, air- and steam-assisted, pressure-assisted, or non-assisted), and description of gas being flared, including quantity of gas flared, frequency of flaring events (if periodic), expected net heating value of flare vent gas, minimum total steam assist rate.
    (ii) The operating conditions (vent gas compositions, vent gas flow rates and assist flow rates, if applicable) likely to be encountered by the flare during normal operations and the operating conditions for the test period.
    (iii) A description of (including sample calculations illustrating) the planned data reduction and calculations to determine the flare combustion or destruction efficiency.
    (iv) Site-specific operating parameters to be monitored continuously during the flare performance evaluation. These parameters may include but are not limited to vent gas flow rate, steam and/or air assist flow rates, and flare vent gas composition. If new operating parameters are proposed for use other than those specified in paragraphs (d) through (f) of this section, an explanation of the relevance of the proposed operating parameter(s) as an indicator of flare combustion performance and why the alternative operating parameter(s) can adequately ensure that the flare achieves the required combustion efficiency.
    (v) A detailed description of the measurement methods, monitored pollutant(s), measurement locations, measurement frequency, and recording frequency proposed for both emission measurements and flare operating parameters.
    (vi) A description of (including sample calculations illustrating) the planned data reduction and calculations to determine the flare operating parameters.
    (vii) The minimum number and length of test runs and range of operating values to be evaluated during the performance evaluation. A sufficient number of test runs shall be conducted to identify the point at which the combustion/destruction efficiency of the flare deteriorates.
    (viii) [Reserved]
    (ix) Test schedule.
    (2) The request for flare-specific operating limits shall include sufficient and appropriate data, as determined by the Administrator, to allow the Administrator to confirm that the selected site-specific operating limit(s) adequately ensures that the flare destruction efficiency is 98 percent or greater or that the flare combustion efficiency is 96.5 percent or greater at all times. At a minimum, the request shall contain the information described in paragraphs (r)(2)(i) through (iv) of this section.
    (i) The design and dimensions of the flare, flare type (air-assisted only, steam-assisted only, air- and steam-assisted, pressure-assisted, or non-assisted), and description of gas being flared, including quantity of gas flared, frequency of flaring events (if periodic), expected net heating value of flare vent gas, minimum total steam assist rate.
    (ii) Results of each performance evaluation test run conducted, including, at a minimum:
    (A) The measured combustion/destruction efficiency.
    (B) The measured or calculated operating parameters for each test run. If operating parameters are calculated, the raw data from which the parameters are calculated must be included in the test report.
    (C) Measurement location descriptions for both emission measurements and flare operating parameters.
    (D) Description of sampling and analysis procedures (including number and length of test runs) and any modifications to standard procedures. If there were deviations from the approved test plan, a detailed description of the deviations and rationale why the test results or calculation procedures used are appropriate.
    (E) Operating conditions (e.g., vent gas composition, assist rates, etc.) that occurred during the test.
    (F) Quality assurance procedures.
    (G) Records of calibrations.
    (H) Raw data sheets for field sampling.
    (I) Raw data sheets for field and laboratory analyses.
    (J) Documentation of calculations.
    (iii) The selected flare-specific operating limit values based on the performance evaluation test results, including the averaging time for the operating limit(s), and rationale why the selected values and averaging times are sufficiently stringent to ensure proper flare performance. If new operating parameters or averaging times are proposed for use other than those specified in paragraphs (d) through (f) of this section, an explanation of why the alternative operating parameter(s) or averaging time(s) adequately ensures the flare achieves the required combustion efficiency.
    (iv) The means by which the owner or operator will document on-going, continuous compliance with the selected flare-specific operating limit(s), including the specific measurement location and frequencies, calculation procedures, and records to be maintained.
    (3) The request shall be submitted as described in paragraphs (r)(3)(i) through (iv) of this section.
    (i) The owner or operator may request approval from the Administrator at any time upon completion of a performance evaluation conducted following the methods in an approved site-specific performance evaluation plan for an operating limit(s) that shall apply specifically to that flare.
    (ii) The request must be submitted to the Administrator for approval. The owner or operator must continue to comply with the applicable standards for flares in this subpart until the requirements in §63.6(g)(1) are met and a notice is published in the Federal Register allowing use of such an alternative means of emission limitation.
    (iii) The request shall also be submitted to the following address: U.S. Environmental Protection Agency, Office of Air Quality Planning and Standards, Sector Policies and Programs Division, U.S. EPA Mailroom (E143-01), Attention: Refinery Sector Lead, 109 T.W. Alexander Drive, Research Triangle Park, NC 27711. Electronic copies in lieu of hard copies may also be submitted to<EMAIL_ADDRESS>    (iv) If the Administrator finds any deficiencies in the request, the request must be revised to address the deficiencies and be re-submitted for approval within 45 days of receipt of the notice of deficiencies. The owner or operator must comply with the revised request as submitted until it is approved.
    (4) The approval process for a request for a flare-specific operating limit(s) is described in paragraphs (r)(4)(i) through (iii) of this section.
    (i) Approval by the Administrator of a flare-specific operating limit(s) request will be based on the completeness, accuracy and reasonableness of the request. Factors that the EPA will consider in reviewing the request for approval include, but are not limited to, those described in paragraphs (r)(4)(i)(A) through (C) of this section.
    (A) The description of the flare design and operating characteristics.
    (B) If a new operating parameter(s) other than those specified in paragraphs (d) through (f) of this section is proposed, the explanation of how the proposed operating parameter(s) serves a good indicator(s) of flare combustion performance.
    (C) The results of the flare performance evaluation test runs and the establishment of operating limits that ensures that the flare destruction efficiency is 98 percent or greater or that the flare combustion efficiency is 96.5 percent or greater at all times.
    (D) The completeness of the flare performance evaluation test report.
    (ii) If the request is approved by the Administrator, a flare-specific operating limit(s) will be established at the level(s) demonstrated in the approved request.
    (iii) If the Administrator finds any deficiencies in the request, the request must be revised to address the deficiencies and be re-submitted for approval.
[80 FR 75258, Dec. 1, 2015, as amended at 81 FR 45241, July 13, 2016]
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§63.671   Requirements for flare monitoring systems.
    (a) Operation of CPMS. For each CPMS installed to comply with applicable provisions in §63.670, the owner or operator shall install, operate, calibrate, and maintain the CPMS as specified in paragraphs (a)(1) through (8) of this section.
    (1) Except for CPMS installed for pilot flame monitoring, all monitoring equipment must meet the applicable minimum accuracy, calibration and quality control requirements specified in table 13 of this subpart.
    (2) The owner or operator shall ensure the readout (that portion of the CPMS that provides a visual display or record) or other indication of the monitored operating parameter from any CPMS required for compliance is readily accessible onsite for operational control or inspection by the operator of the source.
    (3) All CPMS must complete a minimum of one cycle of operation (sampling, analyzing and data recording) for each successive 15-minute period.
    (4) Except for periods of monitoring system malfunctions, repairs associated with monitoring system malfunctions and required monitoring system quality assurance or quality control activities (including, as applicable, calibration checks and required zero and span adjustments), the owner or operator shall operate all CPMS and collect data continuously at all times when regulated emissions are routed to the flare.
    (5) The owner or operator shall operate, maintain, and calibrate each CPMS according to the CPMS monitoring plan specified in paragraph (b) of this section.
    (6) For each CPMS except for CPMS installed for pilot flame monitoring, the owner or operator shall comply with the out-of-control procedures described in paragraph (c) of this section.
    (7) The owner or operator shall reduce data from a CPMS as specified in paragraph (d) of this section.
    (8) The CPMS must be capable of measuring the appropriate parameter over the range of values expected for that measurement location. The data recording system associated with each CPMS must have a resolution that is equal to or better than the required system accuracy.
    (b) CPMS monitoring plan. The owner or operator shall develop and implement a CPMS quality control program documented in a CPMS monitoring plan that covers each flare subject to the provisions in §63.670 and each CPMS installed to comply with applicable provisions in §63.670. The owner or operator shall have the CPMS monitoring plan readily available on-site at all times and shall submit a copy of the CPMS monitoring plan to the Administrator upon request by the Administrator. The CPMS monitoring plan must contain the information listed in paragraphs (b)(1) through (5) of this section.
    (1) Identification of the specific flare being monitored and the flare type (air-assisted only, steam-assisted only, air- and steam-assisted, pressure-assisted, or non-assisted).
    (2) Identification of the parameter to be monitored by the CPMS and the expected parameter range, including worst case and normal operation.
    (3) Description of the monitoring equipment, including the information specified in paragraphs (b)(3)(i) through (vii) of this section.
    (i) Manufacturer and model number for all monitoring equipment components installed to comply with applicable provisions in §63.670.
    (ii) Performance specifications, as provided by the manufacturer, and any differences expected for this installation and operation.
    (iii) The location of the CPMS sampling probe or other interface and a justification of how the location meets the requirements of paragraph (a)(1) of this section.
    (iv) Placement of the CPMS readout, or other indication of parameter values, indicating how the location meets the requirements of paragraph (a)(2) of this section.
    (v) Span of the CPMS. The span of the CPMS sensor and analyzer must encompass the full range of all expected values.
    (vi) How data outside of the span of the CPMS will be handled and the corrective action that will be taken to reduce and eliminate such occurrences in the future.
    (vii) Identification of the parameter detected by the parametric signal analyzer and the algorithm used to convert these values into the operating parameter monitored to demonstrate compliance, if the parameter detected is different from the operating parameter monitored.
    (4) Description of the data collection and reduction systems, including the information specified in paragraphs (b)(4)(i) through (iii) of this section.
    (i) A copy of the data acquisition system algorithm used to reduce the measured data into the reportable form of the standard and to calculate the applicable averages.
    (ii) Identification of whether the algorithm excludes data collected during CPMS breakdowns, out-of-control periods, repairs, maintenance periods, instrument adjustments or checks to maintain precision and accuracy, calibration checks, and zero (low-level), mid-level (if applicable) and high-level adjustments.
    (iii) If the data acquisition algorithm does not exclude data collected during CPMS breakdowns, out-of-control periods, repairs, maintenance periods, instrument adjustments or checks to maintain precision and accuracy, calibration checks, and zero (low-level), mid-level (if applicable) and high-level adjustments, a description of the procedure for excluding this data when the averages calculated as specified in paragraph (e) of this section are determined.
    (5) Routine quality control and assurance procedures, including descriptions of the procedures listed in paragraphs (b)(5)(i) through (vi) of this section and a schedule for conducting these procedures. The routine procedures must provide an assessment of CPMS performance.
    (i) Initial and subsequent calibration of the CPMS and acceptance criteria.
    (ii) Determination and adjustment of the calibration drift of the CPMS.
    (iii) Daily checks for indications that the system is responding. If the CPMS system includes an internal system check, the owner or operator may use the results to verify the system is responding, as long as the system provides an alarm to the owner or operator or the owner or operator checks the internal system results daily for proper operation and the results are recorded.
    (iv) Preventive maintenance of the CPMS, including spare parts inventory.
    (v) Data recording, calculations and reporting.
    (vi) Program of corrective action for a CPMS that is not operating properly.
    (c) Out-of-control periods. For each CPMS installed to comply with applicable provisions in §63.670 except for CPMS installed for pilot flame monitoring, the owner or operator shall comply with the out-of-control procedures described in paragraphs (c)(1) and (2) of this section.
    (1) A CPMS is out-of-control if the zero (low-level), mid-level (if applicable) or high-level calibration drift exceeds two times the accuracy requirement of table 13 of this subpart.
    (2) When the CPMS is out of control, the owner or operator shall take the necessary corrective action and repeat all necessary tests that indicate the system is out of control. The owner or operator shall take corrective action and conduct retesting until the performance requirements are below the applicable limits. The beginning of the out-of-control period is the hour a performance check (e.g., calibration drift) that indicates an exceedance of the performance requirements established in this section is conducted. The end of the out-of-control period is the hour following the completion of corrective action and successful demonstration that the system is within the allowable limits. The owner or operator shall not use data recorded during periods the CPMS is out of control in data averages and calculations, used to report emissions or operating levels, as specified in paragraph (d)(3) of this section.
    (d) CPMS data reduction. The owner or operator shall reduce data from a CPMS installed to comply with applicable provisions in §63.670 as specified in paragraphs (d)(1) through (3) of this section.
    (1) The owner or operator may round the data to the same number of significant digits used in that operating limit.
    (2) Periods of non-operation of the process unit (or portion thereof) resulting in cessation of the emissions to which the monitoring applies must not be included in the 15-minute block averages.
    (3) Periods when the CPMS is out of control must not be included in the 15-minute block averages.
    (e) Additional requirements for gas chromatographs. For monitors used to determine compositional analysis for net heating value per §63.670(j)(1), the gas chromatograph must also meet the requirements of paragraphs (e)(1) through (3) of this section.
    (1) The quality assurance requirements are in table 13 of this subpart.
    (2) The calibration gases must meet one of the following options:
    (i) The owner or operator must use a calibration gas or multiple gases that include all of compounds listed in paragraphs (e)(2)(i)(A) through (K) of this section that may be reasonably expected to exist in the flare gas stream and optionally include any of the compounds listed in paragraphs (e)(2)(i)(L) through (O) of this section. All of the calibration gases may be combined in one cylinder. If multiple calibration gases are necessary to cover all compounds, the owner or operator must calibrate the instrument on all of the gases.
    (A) Hydrogen.
    (B) Methane.
    (C) Ethane.
    (D) Ethylene.
    (E) Propane.
    (F) Propylene.
    (G) n-Butane.
    (H) iso-Butane.
    (I) Butene (general). It is not necessary to separately speciate butene isomers, but the net heating value of trans-butene must be used for co-eluting butene isomers.
    (J) 1,3-Butadiene. It is not necessary to separately speciate butadiene isomers, but you must use the response factor and net heating value of 1,3-butadiene for co-eluting butadiene isomers.
    (K) n-Pentane. Use the response factor for n-pentane to quantify all C5+ hydrocarbons.
    (L) Acetylene (optional).
    (M) Carbon monoxide (optional).
    (N) Propadiene (optional).
    (O) Hydrogen sulfide (optional).
    (ii) The owner or operator must use a surrogate calibration gas consisting of hydrogen and C1 through C5 normal hydrocarbons. All of the calibration gases may be combined in one cylinder. If multiple calibration gases are necessary to cover all compounds, the owner or operator must calibrate the instrument on all of the gases.
    (3) If the owner or operator chooses to use a surrogate calibration gas under paragraph (e)(2)(ii) of this section, the owner or operator must comply with paragraphs (e)(3)(i) and (ii) of this section.
    (i) Use the response factor for the nearest normal hydrocarbon (i.e., n-alkane) in the calibration mixture to quantify unknown components detected in the analysis.
    (ii) Use the response factor for n-pentane to quantify unknown components detected in the analysis that elute after n-pentane.
[80 FR 75266, Dec. 1, 2015]
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§§63.672-63.679   [Reserved]
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Appendix to Subpart CC of Part 63 -- Tables
    Table 1 -- Hazardous Air Pollutants
Chemical name
CAS No.[a]
Benzene
71432
Biphenyl
92524
Butadiene (1,3)
106990
Carbon disulfide
75150
Carbonyl sulfide
463581
Cresol (mixed isomers[b])
1319773
Cresol (m-)
108394
Cresol (o-)
95487
Cresol (p-)
106445
Cumene
98828
Dibromoethane (1,2) (ethylene dibromide)
106934
Dichloroethane (1,2)
107062
Diethanolamine
111422
Ethylbenzene
100414
Ethylene glycol
107211
Hexane
110543
Methanol
67561
Methyl isobutyl ketone (hexone)
108101
Methyl tert butyl ether
1634044
Naphthalene
91203
Phenol
108952
Toluene
108883
Trimethylpentane (2,2,4)
540841
Xylene (mixed isomers[b])
1330207
xylene (m-)
108383
xylene (o-)
95476
xylene (p-)
106423
    [a]CAS number = Chemical Abstract Service registry number assigned to specific compounds, isomers, or mixtures of compounds.
    [b]Isomer means all structural arrangements for the same number of atoms of each element and does not mean salts, esters, or derivatives.
    Table 2 -- Leak Definitions for Pumps and Valves
Standard[a]
Phase
Leak definition (parts per million)
§63.163 (pumps)
I
10,000

II
5,000

III
2,000
§63.168 (valves)
I
10,000

II
1,000

III
1,000
    [a]Subpart H of this part.
    Table 3 -- Equipment Leak Recordkeeping and Reporting Requirements for Sources Complying With §63.648 of Subpart CC by Compliance With Subpart H of this Part[a]
Reference (section of subpart H of this part)
Description
Comment
63.181(a)
Recordkeeping system requirements
Except for §§63.181(b)(2)(iii) and 63.181(b)(9).
63.181(b)
Records required for process unit equipment
Except for §§63.181(b)(2)(iii) and 63.181(b)(9).
63.181(c)
Visual inspection documentation
Except for §§63.181(b)(2)(iii) and 63.181(b)(9).
63.181(d)
Leak detection record requirements
Except for §63.181(d)(8).
63.181(e)
Compliance requirements for pressure tests for batch product process equipment trains
This subsection does not apply to subpart CC.
63.181(f)
Compressor compliance test records.

63.181(g)
Closed-vent systems and control device record requirements.

63.181(h)
Process unit quality improvement program records.

63.181(i)
Heavy liquid service determination record.

63.181(j)
Equipment identification record.

63.181(k)
Enclosed-vented process unit emission limitation record requirements.

63.182(a)
Reports.

63.182(b)
Initial notification report requirements.
Not required.
63.182(c)
Notification of compliance status report
Except in §63.182(c); change "within 90 days of the compliance dates" to "within 150 days of the compliance dates"; except in §§63.182 (c)(2) and (c)(4).
63.182(d)
Periodic report
Except for §§63.182 (d)(2)(vii), (d)(2)(viii), and (d)(3).
    [a]This table does not include all the requirements delineated under the referenced sections. See referenced sections for specific requirements.
    Table 4 -- Gasoline Distribution Emission Point Recordkeeping and Reporting Requirements[a]
Reference (section of
subpart R)
Description
Comment
63.428(b) or (k)
Records of test results for each gasoline cargo tank loaded at the facility

63.428(c)
Continuous monitoring data recordkeeping requirements

63.428(g)(1)
Semiannual report loading rack information
Required to be submitted with the Periodic Report required under 40 CFR part 63, subpart CC.
63.428(h)(1) through (h)(3)
Excess emissions report loading rack information
Required to be submitted with the Periodic Report required under 40 CFR part 63, subpart CC.
    [a]This table does not include all the requirements delineated under the referenced sections. See referenced sections for specific requirements.
    Table 5 -- Marine Vessel Loading Operations Recordkeeping and Reporting Requirements[a]
Reference (section of subpart Y)
Description
Comment
63.562(e)(2)
Operation and maintenance plan for control equipment and monitoring equipment

63.565(a)
Performance test/site test plan
The information required under this paragraph is to be submitted with the Notification of Compliance Status report required under 40 CFR part 63, subpart CC.
63.565(b)
Performance test data requirements

63.567(a)
General Provisions (subpart A) applicability

63.567(c)
Request for extension of compliance

63.567(d)
Flare recordkeeping requirements

63.567(e)
Summary report and excess emissions and monitoring system performance report requirements
The information required under this paragraph is to be submitted with the Periodic Report required under 40 CFR part 63, subpart CC.
63.567(f)
Vapor collection system engineering report

63.567(g)
Vent system valve bypass recordkeeping requirements

63.567(h)
Marine vessel vapor-tightness documentation

63.567(i)
Documentation file maintenance

63.567(j)
Emission estimation reporting and recordkeeping procedures

    [a]This table does not include all the requirements delineated under the referenced sections. See referenced sections for specific requirements.
    Table 6 -- General Provisions Applicability to Subpart CC[a]
Reference
Applies to subpart CC
Comment
63.1(a)(1)
Yes

63.1(a)(2)
Yes

63.1(a)(3)
Yes

63.1(a)(4)
Yes

63.1(a)(5)
No
Reserved.
63.1(a)(6)
Yes
Except the correct mail drop (MD) number is C404-04.
63.1(a)(7)-63.1(a)(9)
No
Reserved.
63.1(a)(10)
Yes

63.1(a)(11)
Yes

63.1(a)(12)
Yes

63.1(b)(1)
Yes

63.1(b)(2)
No
Reserved.
63.1(b)(3)
No

63.1(c)(1)
Yes

63.1(c)(2)
No
Area sources are not subject to subpart CC.
63.1(c)(3)-63.1(c)(4)
No
Reserved.
63.1(c)(5)
Yes
Except that sources are not required to submit notifications overridden by this table.
63.1(d)
No
Reserved.
63.1(e)
No
No CAA section 112(j) standard applies to the affected sources under subpart CC.
63.2
Yes
§63.641 of subpart CC specifies that if the same term is defined in subparts A and CC, it shall have the meaning given in subpart CC.
63.3
Yes

63.4(a)(1)-63.4(a)(2)
Yes

63.4(a)(3)-63.4(a)(5)
No
Reserved.
63.4(b)
Yes

63.4(c)
Yes

63.5(a)
Yes

63.5(b)(1)
Yes

63.5(b)(2)
No
Reserved.
63.5(b)(3)
Yes

63.5(b)(4)
Yes
Except the cross-reference to §63.9(b) is changed to §63.9(b)(4) and (5). Subpart CC overrides §63.9 (b)(2).
63.5(b)(5)
No
Reserved.
63.5(b)(6)
Yes

63.5(c)
No
Reserved.
63.5(d)(1)(i)
Yes
Except that the application shall be submitted as soon as practicable before startup, but no later than 90 days after the promulgation date of subpart CC if the construction or reconstruction had commenced and initial startup had not occurred before the promulgation of subpart CC.
63.5(d)(1)(ii)
Yes
Except that for affected sources subject to this subpart, emission estimates specified in §63.5(d)(1)(ii)(H) are not required, and §63.5(d)(1)(ii)(G) and (I) are Reserved and do not apply.
63.5(d)(1)(iii)
No
Subpart CC §63.655(f) specifies Notification of Compliance Status report requirements.
63.5(d)(2)
Yes

63.5(d)(3)
Yes

63.5(d)(4)
Yes

63.5(e)
Yes

63.5(f)
Yes
Except that the cross-reference in §63.5(f)(2) to §63.9(b)(2) does not apply.
63.6(a)
Yes

63.6(b)(1)-63.6(b)(5)
No
Subpart CC specifies compliance dates and notifications for sources subject to subpart CC.
63.6(b)(6)
No
Reserved.
63.6(b)(7)
Yes

63.6(c)(1)-63.6(c)(2)
No
§63.640 of subpart CC specifies the compliance date.
63.6(c)(3)-63.6(c)(4)
No
Reserved.
63.6(c)(5)
Yes

63.6(d)
No
Reserved.
63.6(e)(1)(i) and (ii)
No
See §63.642(n) for general duty requirement.
63.6(e)(1)(iii)
Yes.

63.6(e)(2)
No
Reserved.
63.6(e)(3)(i)
No.

63.6(e)(3)(ii)
No
Reserved.
63.6(e)(3)(iii)-63.6(e)(3)(ix)
No.

63.6(f)(1)
No.

63.6(f)(2)
Yes
Except the phrase "as specified in §63.7(c)" in §63.6(f)(2)(iii)(D) does not apply because this subpart does not require a site-specific test plan.
63.6(f)(3)
Yes
Except the cross-references to §63.6(f)(1) and (e)(1)(i) are changed to §63.642(n) and performance test results may be written or electronic.
63.6(g)
Yes

63.6(h)(1)
No.

63.6(h)(2)
Yes
Except §63.6(h)(2)(ii), which is reserved.
63.6(h)(3)
No
Reserved.
63.6(h)(4)
No
Notification of visible emission test not required in subpart CC.
63.6(h)(5)
No
Visible emission requirements and timing is specified in §63.645(i) of subpart CC.
63.6(h)(6)
Yes

63.6(h)(7)
No
Subpart CC does not require opacity standards.
63.6(h)(8)
Yes
Except performance test results may be written or electronic.
63.6(h)(9)
No
Subpart CC does not require opacity standards.
63.6(i)
Yes
Except for §63.6(i)(15), which is reserved.
63.6(j)
Yes

63.7(a)(1)
Yes

63.7(a)(2)
Yes
Except test results must be submitted in the Notification of Compliance Status report due 150 days after compliance date, as specified in §63.655(f) of subpart CC, unless they are required to be submitted electronically in accordance with §63.655(h)(9). Test results required to be submitted electronically must be submitted by the date the Notification of Compliance Status report is submitted.
63.7(a)(3)
Yes

63.7(a)(4)
Yes

63.7(b)
Yes
Except this subpart requires notification of performance test at least 30 days (rather than 60 days) prior to the performance test.
63.7(c)
No
Subpart CC does not require a site-specific test plan.
63.7(d)
Yes

63.7(e)(1)
No
See §63.642(d)(3).
63.7(e)(2)-63.7(e)(4)
Yes

63.7(f)
Yes
Except that additional notification or approval is not required for alternatives directly specified in Subpart CC.
63.7(g)
No
Performance test reporting specified in §63.655(f).
63.7(h)(1)
Yes

63.7(h)(2)
Yes

63.7(h)(3)
Yes
Yes, except site-specific test plans shall not be required, and where §63.7(h)(3)(i) specifies waiver submittal date, the date shall be 90 days prior to the Notification of Compliance Status report in §63.655(f).
63.7(h)(4)(i)
Yes

63.7(h)(4)(ii)
No
Site-specific test plans are not required in subpart CC.
63.7(h)(4)(iii) and (iv)
Yes

63.7(h)(5)
Yes

63.8(a)(1) and (2)
Yes.

63.8(a)(3)
No
Reserved.
63.8(a)(4)
Yes
Except that for a flare complying with §63.670, the cross-reference to §63.11 in this paragraph does not include §63.11(b).
63.8(b)
Yes

63.8(c)(1)
Yes
Except §63.8(c)(1)(i) and (iii).
63.8(c)(1)(i)
No
See §63.642(n).
63.8(c)(1)(iii)
No.

63.8(c)(2)
Yes

63.8(c)(3)
Yes
Except that verification of operational status shall, at a minimum, include completion of the manufacturer's written specifications or recommendations for installation, operation, and calibration of the system or other written procedures that provide adequate assurance that the equipment would monitor accurately.
63.8(c)(4)
Yes
Except that for sources other than flares, this subpart specifies the monitoring cycle frequency specified in §63.8(c)(4)(ii) is "once every hour" rather than "for each successive 15-minute period."
63.8(c)(5)-63.8(c)(8)
No
This subpart specifies continuous monitoring system requirements.
63.8(d)
No
This subpart specifies quality control procedures for continuous monitoring systems.
63.8(e)
Yes.
Except that results are to be submitted electronically if required by §63.655(h)(9).
63.8(f)(1)
Yes

63.8(f)(2)
Yes

63.8(f)(3)
Yes

63.8(f)(4)(i)
No
Timeframe for submitting request is specified in §63.655(h)(5)(i) of subpart CC.
63.8(f)(4)(ii)
Yes

63.8(f)(4)(iii)
No
Timeframe for submitting request is specified in §63.655(h)(5)(i) of subpart CC.
63.8(f)(5)
Yes

63.8(f)(6)
No
Subpart CC does not require continuous emission monitors.
63.8(g)
No
This subpart specifies data reduction procedures in §§63.655(i)(3) and 63.671(d).
63.9(a)
Yes
Except that the owner or operator does not need to send a copy of each notification submitted to the Regional Office of the EPA as stated in §63.9(a)(4)(ii).
63.9(b)(1)
Yes
Except the notification of compliance status report specified in §63.655(f) of subpart CC may also serve as the initial compliance notification required in §63.9(b)(1)(iii).
63.9(b)(2)
No
A separate Initial Notification report is not required under subpart CC.
63.9(b)(3)
No
Reserved.
63.9(b)(4)
Yes
Except for subparagraphs §63.9(b)(4)(ii) through (iv), which are reserved.
63.9(b)(5)
Yes

63.9(c)
Yes

63.9(d)
Yes

63.9(e)
No
Subpart CC requires notification of performance test at least 30 days (rather than 60 days) prior to the performance test and does not require a site-specific test plan.
63.9(f)
No
Subpart CC does not require advanced notification of visible emissions test.
63.9(g)
No

63.9(h)
No
Subpart CC §63.655(f) specifies Notification of Compliance Status report requirements.
63.9(i)
Yes

63.9(j)
No

63.10(a)
Yes

63.10(b)(1)
No
§63.655(i) of subpart CC specifies record retention requirements.
63.10(b)(2)(i)
No.

63.10(b)(2)(ii)
No
§63.655(i) specifies the records that must be kept.
63.10(b)(2)(iii)
No

63.10(b)(2)(iv)
No.

63.10(b)(2)(v)
No.

63.10(b)(2)(vi)
Yes

63.10(b)(2)(vii)
No
§63.655(i) specifies records to be kept for parameters measured with continuous monitors.
63.10(b)(2)(viii)
Yes

63.10(b)(2)(ix)
Yes

63.10(b)(2)(x)
Yes

63.10(b)(2)(xi)
No

63.10(b)(2)(xii)
Yes

63.10(b)(2)(xiii)
No

63.10(b)(2)(xiv)
Yes

63.10(b)(3)
No

63.10(c)(1)-63.10(c)(6)
No

63.10(c)(7) and 63.10(c)(8)
Yes

63.10(c)(9)
No
Reserved.
63.10(c)(10)-63.10(c)(11)
No
§63.655(i) specifies the records that must be kept.
63.10(c)(12)-63.10(c)(15)
No.

63.10(d)(1)
Yes

63.10(d)(2)
No
Although §63.655(f) specifies performance test reporting, EPA may approve other timeframes for submittal of performance test data.
63.10(d)(3)
No
Results of visible emissions test are included in Compliance Status Report as specified in §63.655(f).
63.10(d)(4)
Yes

63.10(d)(5)
No
§63.655(g) specifies the reporting requirements.
63.10(e)
No

63.10(f)
Yes

63.11
Yes
Except that flares complying with §63.670 are not subject to the requirements of §63.11(b).
63.12-63.16
Yes.

    [a]Wherever subpart A of this part specifies "postmark" dates, submittals may be sent by methods other than the U.S. Mail (e.g., by fax or courier). Submittals shall be sent by the specified dates, but a postmark is not required.
    Table 7 -- Fraction Measured (FM), Fraction Emitted (FE), and Fraction Removed (FR) for HAP Compounds in Wastewater Streams
Chemical name
CAS No.[a]
Fm
Fe
Fr
Benzene
71432
1.00
0.80
0.99
Biphenyl
92524
0.86
0.45
0.99
Butadiene (1,3)
106990
1.00
0.98
0.99
Carbon disulfide
75150
1.00
0.92
0.99
Cumene
98828
1.00
0.88
0.99
Dichloroethane (1,2-) (Ethylene dichloride)
107062
1.00
0.64
0.99
Ethylbenzene
100414
1.00
0.83
0.99
Hexane
110543
1.00
1.00
0.99
Methanol
67561
0.85
0.17
0.31
Methyl isobutyl ketone (hexone)
108101
0.98
0.53
0.99
Methyl tert butyl ether
1634044
1.00
0.57
0.99
Naphthalene
91203
0.99
0.51
0.99
Trimethylpentane (2,2,4)
540841
1.00
1.00
0.99
xylene (m-)
108383
1.00
0.82
0.99
xylene (o-)
95476
1.00
0.79
0.99
xylene (p-)
106423
1.00
0.82
0.99
    [a]CAS numbers refer to the Chemical Abstracts Service registry number assigned to specific compounds, isomers, or mixtures of compounds.
    Table 8 -- Valve Monitoring Frequency for Phase III
Performance level
Valve monitoring frequency
Leaking valves[a] (%)

>=4
Monthly or QIP.[b]
<4
Quarterly.
<3
Semiannual.
<2
Annual.
    [a]Percent leaking valves is calculated as a rolling average of two consecutive monitoring periods.
    [b]QIP = Quality improvement program. Specified in §63.175 of subpart H of this part.
    Table 9 -- Valve Monitoring Frequency for Alternative
Performance level
Valve monitoring frequency under §63.649 alternative
Leaking valves[a] (%)

>=5
Monthly or QIP.[b]
<5
Quarterly.
<4
Semiannual.
<3
Annual.
    [a]Percent leaking valves is calculated as a rolling average of two consecutive monitoring periods.
    [b]QIP = Quality improvement program. Specified in §63.175 of subpart H of this part.
    Table 10 -- Miscellaneous Process Vents -- Monitoring, Recordkeeping and Reporting Requirements for Complying With 98 Weight-Percent Reduction of Total Organic HAP Emissions or a Limit of 20 Parts Per Million by Volume
Control device
Parameters to be monitored[a]
Recordkeeping and reporting requirements for monitored parameters
Thermal incinerator
Firebox temperature[b] (63.644(a)(1)(i))
1. Continuous records[c].

2. Record and report the firebox temperature averaged over the full period of the performance test -- NCS[d].

3. Record the daily average firebox temperature for each operating day[e].

4. Report all daily average temperatures that are outside the range established in the NCS or operating permit and all operating days when insufficient monitoring data are collected[f] -- PR[g].
Catalytic incinerator
Temperature upstream and downstream of the catalyst bed (63.644(a)(1)(ii))
1. Continuous records[c].

2. Record and report the upstream and downstream temperatures and the temperature difference across the catalyst bed averaged over the full period of the performance test -- NCS[d].

3. Record the daily average upstream temperature and temperature difference across the catalyst bed for each operating day[e].

4. Report all daily average upstream temperatures that are outside the range established in the NCS or operating permit -- PR[g].

5. Report all daily average temperature differences across the catalyst bed that are outside the range established in the NCS or operating permit -- PR[g].

6. Report all operating days when insufficient monitoring data are collected[f].
Boiler or process heater with a design heat capacity less than 44 megawatts where the vent stream is not introduced into the flame zone[h i]
Firebox temperature[b] (63.644(a)(4))
1. Continuous records[c].

2. Record and report the firebox temperature averaged over the full period of the performance test -- NCS[d].

3. Record the daily average firebox temperature for each operating day[e].

4. Report all daily average firebox temperatures that are outside the range established in the NCS or operating permit and all operating days when insufficient monitoring data are collected[f] -- PR[g].
Flare (if meeting the requirements of §§63.643 and 63.644)
Presence of a flame at the pilot light (63.644(a)(2))
1. Hourly records of whether the monitor was continuously operating and whether a pilot flame was continuously present during each hour.

2. Record and report the presence of a flame at the pilot light over the full period of the compliance determination -- NCS[d].

3. Record the times and durations of all periods when all pilot flames for a flare are absent or the monitor is not operating.

4. Report the times and durations of all periods when all pilot flames for a flare are absent or the monitor is not operating.
Flare (if meeting the requirements of §§63.670 and 63.671)
The parameters specified in §63.670
1. Records as specified in §63.655(i)(9).
2. Report information as specified in §63.655(g)(11) -- PR.[g]
All control devices
Presence of flow diverted to the atmosphere from the control device (§63.644(c)(1)) or
1. Hourly records of whether the flow indicator was operating and whether flow was detected at any time during each hour.
Record and report the times and durations of all periods when the vent stream is diverted through a bypass line or the monitor is not operating -- PR.[g]

Monthly inspections of sealed valves (§63.644(c)(2))
1. Records that monthly inspections were performed.
2. Record and report all monthly inspections that show the valves are not closed or the seal has been changed -- PR.[g]
    [a]Regulatory citations are listed in parentheses.
    [b]Monitor may be installed in the firebox or in the ductwork immediately downstream of the firebox before any substantial heat exchange is encountered.
    [c]"Continuous records" is defined in §63.641.
    [d]NCS = Notification of Compliance Status Report described in §63.655.
    [e]The daily average is the average of all recorded parameter values for the operating day. If all recorded values during an operating day are within the range established in the NCS or operating permit, a statement to this effect can be recorded instead of the daily average.
    [f]When a period of excess emission is caused by insufficient monitoring data, as described in §63.655(g)(6)(i)(C) or (D), the duration of the period when monitoring data were not collected shall be included in the Periodic Report.
    [g]PR = Periodic Reports described in §63.655(g).
    [h]No monitoring is required for boilers and process heaters with a design heat capacity >=44 megawatts or for boilers and process heaters where all vent streams are introduced into the flame zone. No recordkeeping or reporting associated with monitoring is required for such boilers and process heaters.
    [i]Process vents that are routed to refinery fuel gas systems are not regulated under this subpart provided that on and after January 30, 2019, any flares receiving gas from that fuel gas system are in compliance with §63.670. No monitoring, recordkeeping, or reporting is required for boilers and process heaters that combust refinery fuel gas.
    Table 11 -- Compliance Dates and Requirements
If the construction/
reconstruction date
is .  .  .
Then the owner or operator must comply with .  .  .
And the owner or operator must achieve compliance .  .  .
Except as provided in .  .  .
(1) After June 30, 2014
(i) Requirements for new sources in §§63.643(a) and (b); 63.644, 63.645, and 63.647; 63.648(a) through (i) and (j)(1) and (2); 63.649 through 63.651; and 63.654 through 63.656
Upon initial startup
§63.640(k), (l) and (m).

(ii) Requirements for new sources in §§63.642(n), 63.643(c), 63.648(j)(3), (6) and (7); and 63.657 through 63.660
Upon initial startup or February 1, 2016, whichever is later
§63.640(k), (l) and (m).
(2) After September 4, 2007 but on or before June 30, 2014
(i) Requirements for new sources in §§63.643(a) and (b); 63.644, 63.645, and 63.647; 63.648(a) through (i) and (j)(1) and (2); and 63.649 through 63.651, 63.655 and 63.656
Upon initial startup
§63.640(k), (l) and (m).

(ii) Requirements for new sources in §63.654
Upon initial startup or October 28, 2009, whichever is later
§63.640(k), (l) and (m).

(iii) Requirements for new sources in either §63.646 or §63.660 or, if applicable, §63.640(n)
Upon initial startup, but you must transition to comply with only the requirements in §63.660 or, if applicable, §63.640(n) on or before April 29, 2016
§§63.640(k), (l) and (m) and 63.660(d).

(iv) Requirements for existing sources in §63.643(c)
On or before [insert date 30 days after publication in the Federal Register]
§§63.640(k), (l) and (m) and 63.643(d).

(v) Requirements for existing sources in §63.658
On or before January 30, 2018
§63.640(k), (l) and (m).

(vi) Requirements for existing sources in §63.648 (j)(3), (6) and (7) and §63.657
On or before January 30, 2019
§63.640(k), (l) and (m).

(vii) Requirements in §63.642 (n)
Upon initial startup or February 1, 2016, whichever is later

(3) After July 14, 1994 but on or before September 4, 2007
(i) Requirements for new sources in §§63.643(a) and (b); 63.644, 63.645, and 63.647; 63.648(a) through (i) and (j)(1) and (2); and 63.649 through 63.651, 63.655 and 63.656
Upon initial startup or August 18, 1995, whichever is later
§63.640(k), (l) and (m).

(ii) Requirements for existing sources in §63.654
On or before October 29, 2012
§63.640(k), (l) and (m).

(iii) Requirements for new sources in either §63.646 or §63.660 or, if applicable, §63.640(n)
Upon initial startup, but you must transition to comply with only the requirements in §63.660 or, if applicable, §63.640(n) on or before April 29, 2016
§§63.640(k), (l) and (m) and 63.660(d).

(iv) Requirements for existing sources in §63.643(c)
On or before [insert date 30 days after publication in the Federal Register]
§§63.640(k), (l) and (m) and 63.643(d).

(v) Requirements for existing sources in §63.658
On or before January 30, 2018
§63.640(k), (l) and (m).

(vi) Requirements for existing sources in §§63.648(j)(3), (6) and (7) and 63.657
On or before January 30, 2019
§63.640(k), (l) and (m).

(vii) Requirements in §63.642(n)
Upon initial startup or February 1, 2016, whichever is later

(4) On or before July 14, 1994
(i) Requirements for existing sources in §§63.648(a) through (i) and (j)(1) and (2); and 63.649, 63.655 and 63.656
(A) On or before August 18, 1998
(1) §63.640(k), (l) and (m). (2) §63.6(c)(5) or unless an extension has been granted by the Administrator as provided in §63.6(i).

(ii) Either the requirements for existing sources in §§63.643(a) and (b); 63.644, 63.645, 63.647, 63.650 and 63.651; and item (4)(v) of this table
OR
The requirements in §§63.652 and 63.653
(A) On or before August 18, 1998
(1) §63.640(k), (l) and (m). (2) §63.6(c)(5) or unless an extension has been granted by the Administrator as provided in §63.6(i).

(iii) Requirements for existing sources in either §63.646 or §63.660 or, if applicable, §63.640(n)
On or before August 18, 1998, but you must transition to comply with only the requirements in §63.660 or, if applicable, §63.640(n) on or before April 29, 2016
§§63.640(k), (l) and (m) and 63.660(d).

(iv) Requirements for existing sources in §63.654
On or before October 29, 2012
§63.640(k), (l) and (m).

(v) Requirements for existing sources in §63.643(c)
On or before [insert date 30 days after publication in the Federal Register]
§§63.640(k), (l) and (m) and 63.643(d).

(vi) Requirements for existing sources in §63.658
On or before January 30, 2018
§63.640(k), (l) and (m).

(vii) Requirements for existing sources in §§63.648(j)(3), (6) and (7) and 63.657
On or before January 30, 2019
§63.640(k), (l) and (m).

(viii) Requirements in §63.642 (n)
Upon initial startup or February 1, 2016, whichever is later

    Table 12 -- Individual Component Properties
Component
Molecular
formula
MWi
(pounds per pound-mole)
CMNi
(mole per mole)
NHVi
(British
thermal units
per standard
cubic foot)
LFLi
(volume %)
Acetylene
C2H2
26.04
2
1,404
2.5
Benzene
C6H6
78.11
6
3,591
1.3
1,2-Butadiene
C4H6
54.09
4
2,794
2.0
1,3-Butadiene
C4H6
54.09
4
2,690
2.0
iso-Butane
C4H10
58.12
4
2,957
1.8
n-Butane
C4H10
58.12
4
2,968
1.8
cis-Butene
C4H8
56.11
4
2,830
1.6
iso-Butene
C4H8
56.11
4
2,928
1.8
trans-Butene
C4H8
56.11
4
2,826
1.7
Carbon Dioxide
CO2
44.01
1
0
infinity
Carbon Monoxide
CO
28.01
1
316
12.5
Cyclopropane
C3H6
42.08
3
2,185
2.4
Ethane
C2H6
30.07
2
1,595
3.0
Ethylene
C2H4
28.05
2
1,477
2.7
Hydrogen
H2
2.02
0
1,212[a]
4.0
Hydrogen Sulfide
H2S
34.08
0
587
4.0
Methane
CH4
16.04
1
896
5.0
Methyl-Acetylene
C3H4
40.06
3
2,088
1.7
Nitrogen
N2
28.01
0
0
infinity
Oxygen
O2
32.00
0
0
infinity
Pentane+ (C5+)
C5H12
72.15
5
3,655
1.4
Propadiene
C3H4
40.06
3
2,066
2.16
Propane
C3H8
44.10
3
2,281
2.1
Propylene
C3H6
42.08
3
2,150
2.4
Water
H2O
18.02
0
0
infinity
    [a]The theoretical net heating value for hydrogen is 274 Btu/scf, but for the purposes of the flare requirement in this subpart, a net heating value of 1,212 Btu/scf shall be used.
    Table 13 -- Calibration and Quality Control Requirements for CPMS
Parameter
Minimum accuracy requirements
Calibration requirements
Temperature
+-1 percent over the normal range of temperature measured, expressed in degrees Celsius (C), or 2.8 degrees C, whichever is greater
Conduct calibration checks at least annually; conduct calibration checks following any period of more than 24 hours throughout which the temperature exceeded the manufacturer's specified maximum rated temperature or install a new temperature sensor.
At least quarterly, inspect all components for integrity and all electrical connections for continuity, oxidation, and galvanic corrosion, unless the CPMS has a redundant temperature sensor.

Record the results of each calibration check and inspection.

Locate the temperature sensor in a position that provides a representative temperature; shield the temperature sensor system from electromagnetic interference and chemical contaminants.
Flow Rate for All Flows Other Than Flare Vent Gas
+-5 percent over the normal range of flow measured or 1.9 liters per minute (0.5 gallons per minute), whichever is greater, for liquid flow
Conduct a flow sensor calibration check at least biennially (every two years); conduct a calibration check following any period of more than 24 hours throughout which the flow rate exceeded the manufacturer's specified maximum rated flow rate or install a new flow sensor.

+-5 percent over the normal range of flow measured or 280 liters per minute (10 cubic feet per minute), whichever is greater, for gas flow
At least quarterly, inspect all components for leakage, unless the CPMS has a redundant flow sensor.

+-5 percent over the normal range measured for mass flow
Record the results of each calibration check and inspection.
Locate the flow sensor(s) and other necessary equipment (such as straightening vanes) in a position that provides representative flow; reduce swirling flow or abnormal velocity distributions due to upstream and downstream disturbances.
Flare Vent Gas Flow Rate
+-20 percent of flow rate at velocities ranging from 0.03 to 0.3 meters per second (0.1 to 1 feet per second)
+-5 percent of flow rate at velocities greater than 0.3 meters per second (1 feet per second)
Conduct a flow sensor calibration check at least biennially (every two years); conduct a calibration check following any period of more than 24 hours throughout which the flow rate exceeded the manufacturer's specified maximum rated flow rate or install a new flow sensor.
At least quarterly, inspect all components for leakage, unless the CPMS has a redundant flow sensor.

Record the results of each calibration check and inspection.

Locate the flow sensor(s) and other necessary equipment (such as straightening vanes) in a position that provides representative flow; reduce swirling flow or abnormal velocity distributions due to upstream and downstream disturbances.
Pressure
+-5 percent over the normal operating range or 0.12 kilopascals (0.5 inches of water column), whichever is greater
Review pressure sensor readings at least once a week for straightline (unchanging) pressure and perform corrective action to ensure proper pressure sensor operation if blockage is indicated.
Using an instrument recommended by the sensor's manufacturer, check gauge calibration and transducer calibration annually; conduct calibration checks following any period of more than 24 hours throughout which the pressure exceeded the manufacturer's specified maximum rated pressure or install a new pressure sensor.

At least quarterly, inspect all components for integrity, all electrical connections for continuity, and all mechanical connections for leakage, unless the CPMS has a redundant pressure sensor.

Record the results of each calibration check and inspection.

Locate the pressure sensor(s) in a position that provides a representative measurement of the pressure and minimizes or eliminates pulsating pressure, vibration, and internal and external corrosion.
Net Heating Value by Calorimeter
+-2 percent of span
Specify calibration requirements in your site specific CPMS monitoring plan. Calibration requirements should follow manufacturer's recommendations at a minimum.
Temperature control (heated and/or cooled as necessary) the sampling system to ensure proper year-round operation.

Where feasible, select a sampling location at least two equivalent diameters downstream from and 0.5 equivalent diameters upstream from the nearest disturbance. Select the sampling location at least two equivalent duct diameters from the nearest control device, point of pollutant generation, air in-leakages, or other point at which a change in the pollutant concentration or emission rate occurs.
Net Heating Value by Gas Chromatograph
As specified in Performance Specification 9 of 40 CFR part 60, appendix B
Follow the procedure in Performance Specification 9 of 40 CFR part 60, appendix B, except that a single daily mid-level calibration check can be used (rather than triplicate analysis), the multi-point calibration can be conducted quarterly (rather than monthly), and the sampling line temperature must be maintained at a minimum temperature of 60 °C (rather than 120 °C).
Hydrogen analyzer
+-2 percent over the concentration measured or 0.1 volume percent, whichever is greater
Specify calibration requirements in your site specific CPMS monitoring plan. Calibration requirements should follow manufacturer's recommendations at a minimum.

Where feasible, select the sampling location at least two equivalent duct diameters from the nearest control device, point of pollutant generation, air in-leakages, or other point at which a change in the pollutant concentration occurs.
[60 FR 43260, Aug. 18, 1995, as amended at 61 FR 29881, 29882, June 12, 1996; 63 FR 44142, 44143, Aug. 18, 1998; 74 FR 55688, Oct. 28, 2009; 75 FR 37731, June 30, 2010; 80 FR 75269, Dec. 1, 2015; 81 FR 45241, July 13, 2016]


[Federal Register: January 3, 2008 (Volume 73, Number 2)]
[Rules and Regulations]
[Page 395-397]
[DOCID:fr03ja08-3]

-----------------------------------------------------------------------

DEPARTMENT OF TRANSPORTATION

Federal Aviation Administration

14 CFR Part 39

[Docket No. FAA-2007-0379; Directorate Identifier 2007-NM-331-AD;
Amendment 39-15318; AD 2007-26-16]
RIN 2120-AA64

Airworthiness Directives; Cessna Model 680 Airplanes

AGENCY: Federal Aviation Administration (FAA), DOT.

ACTION: Final rule; request for comments.

-----------------------------------------------------------------------

SUMMARY: We are adopting a new airworthiness directive (AD) for certain
Cessna Model 680 airplanes. This AD requires inspecting the routing of
the aft fairing wire bundle assembly for adequate separation between
the wiring and the hydraulic line; inspecting for chafing or damage of
the wire bundle

assembly and for damage to the hydraulic line, and doing corrective
actions if necessary. This AD results from an incident report which
indicated that a hydraulic leak and wire chafing, including signs of
heat damage, were found within the lower tail cone fairing area.
Similar wire chafing has also been found on other airplanes. We are
issuing this AD to detect and correct wire chafing, and inadequate
separation of the wiring and hydraulic line, which could lead to
electrical arcing and a hydraulic leak and could result in a potential
source of ignition and consequent fire.

DATES: This AD is effective January 18, 2008.
    The Director of the Federal Register approved the incorporation by
reference of certain publications listed in this AD as of February 7,
2008.
    We must receive comments on this AD by March 3, 2008.

ADDRESSES: You may send comments by any of the following methods:
     Federal eRulemaking Portal: Go to http://www.regulations.gov.
 Follow the instructions for submitting comments.

     Fax:<PHONE_NUMBER>.
     Mail: U.S. Department of Transportation, Docket
Operations, M-30, West Building Ground Floor, Room W12-140, 1200 New
Jersey Avenue, SE., Washington, DC 20590.
     Hand Delivery: U.S. Department of Transportation, Docket
Operations, M-30, West Building Ground Floor, Room W12-140, 1200 New
Jersey Avenue, SE., Washington, DC 20590, between 9 a.m. and 5 p.m.,
Monday through Friday, except Federal holidays.
    For service information identified in this AD, contact Cessna
Aircraft Co., P.O. Box 7706, Wichita, Kansas 67277.

Examining the AD Docket

    You may examine the AD docket on the Internet at http://www.regulations.gov
; or in person at the Docket Management Facility

between 9 a.m. and 5 p.m., Monday through Friday, except Federal
holidays. The AD docket contains this AD, the regulatory evaluation,
any comments received, and other information. The street address for
the Docket Office (telephone<PHONE_NUMBER>) is in the ADDRESSES section.
Comments will be available in the AD docket shortly after receipt.

FOR FURTHER INFORMATION CONTACT: Jarrett Larrow, Aerospace Engineer,
Electrical Systems and Avionics, ACE-119W, FAA, Wichita Aircraft
Certification Office, 1801 Airport Road, Room 100, Mid-Continent
Airport, Wichita, Kansas 67209; telephone<PHONE_NUMBER>; fax (316)
946-4107.

SUPPLEMENTARY INFORMATION:

Discussion

    We received an incident report which indicated that a hydraulic
leak and wire chafing, including signs of heat damage, were found
within the lower tail cone fairing area on a Cessna Model 680 airplane.
The incident occurred while the airplane was on the ground. Wire
chafing has also been found on other airplanes. Chafing of the wiring,
and inadequate separation of the wiring and hydraulic line, could lead
to electrical arcing and a hydraulic leak and could result in a
potential source of ignition and consequent fire.

Relevant Service Information

    We reviewed Cessna Alert Service Letter ASL680-24-02, dated October
1, 2007. The service letter describes procedures for inspecting the
routing of the aft fairing wire bundle assembly for adequate separation
between the wiring and the hydraulic line; inspecting for chafing or
damage of the wire bundle assembly and for damage to the hydraulic
line; and corrective actions if necessary. The corrective actions
include repairing the wiring if any damage to the wire bundle is found,
replacing the hydraulic line if any damage is found, and re-routing the
wire bundle so there is a minimum of two inches from the hydraulic
line. The service letter refers to the Model 680 wiring diagram and
maintenance manuals, which contain the procedures for doing the
corrective actions.

FAA's Determination and Requirements of This AD

    We are issuing this AD because we evaluated all the relevant
information and determined the unsafe condition described previously is
likely to exist or develop in other products of the same type design.
This AD requires accomplishing the actions specified in the service
information described previously, except as discussed under
``Differences Between the AD and the Service Information.''

Differences Between the AD and the Service Information

    The service information refers only to an ``inspection'' for
routing and chafing or damage of the wire bundles and hydraulic line.
We have determined that the procedures in the service information
should be described as a ``general visual inspection.'' Note 1 has been
included in this AD to define this type of inspection.
    The Accomplishment Instructions of the service information describe
procedures for completing a maintenance transaction report and
submitting a copy to the manufacturer. This AD would not require that
action.

Interim Action

    We consider this AD interim action. If final action is later
identified, we might consider further rulemaking then.

FAA's Determination of the Effective Date

    An unsafe condition exists that requires the immediate adoption of
this AD; therefore, providing notice and opportunity for public comment
before the AD is issued is impracticable, and good cause exists to make
this AD effective in less than 30 days.

Comments Invited

    This AD is a final rule that involves requirements affecting flight
safety, and we did not provide you with notice and an opportunity to
provide your comments before it becomes effective. However, we invite
you to send any written data, views, or arguments about this AD. Send
your comments to an address listed under the ADDRESSES section. Include
``Docket No. FAA-2007-0379; Directorate Identifier 2007-NM-331-AD'' at
the beginning of your comments. We specifically invite comments on the
overall regulatory, economic, environmental, and energy aspects of this
AD. We will consider all comments received by the closing date and may
amend this AD because of those comments.
    We will post all comments we receive, without change, to http://www.regulations.gov
, including any personal information you provide. We

will also post a report summarizing each substantive verbal contact we
receive about this AD.

Authority for This Rulemaking

    Title 49 of the United States Code specifies the FAA's authority to
issue rules on aviation safety. Subtitle I, section 106, describes the
authority of the FAA Administrator. ``Subtitle VII: Aviation
Programs,'' describes in more detail the scope of the Agency's
authority.
    We are issuing this rulemaking under the authority described in
``Subtitle VII, Part A, Subpart III, Section 44701: General
requirements.'' Under that section, Congress charges the FAA with
promoting safe flight of civil aircraft in air commerce by prescribing
regulations for practices, methods, and procedures the Administrator
finds necessary for safety in air commerce. This regulation is within
the scope of that authority because it addresses an unsafe condition
that is likely to exist or develop on

products identified in this rulemaking action.

Regulatory Findings

    This AD will not have federalism implications under Executive Order
13132. This AD will not have a substantial direct effect on the States,
on the relationship between the national government and the States, or
on the distribution of power and responsibilities among the various
levels of government.
    For the reasons discussed above, I certify that this AD:
    (1) Is not a ``significant regulatory action'' under Executive
Order 12866,
    (2) Is not a ``significant rule'' under DOT Regulatory Policies and
Procedures (44 FR 11034, February 26, 1979), and
    (3) Will not have a significant economic impact, positive or
negative, on a substantial number of small entities under the criteria
of the Regulatory Flexibility Act.
    You can find our regulatory evaluation and the estimated costs of
compliance in the AD Docket.

List of Subjects in 14 CFR Part 39

    Air transportation, Aircraft, Aviation safety, Incorporation by
reference, Safety.

Adoption of the Amendment

0
Accordingly, under the authority delegated to me by the Administrator,
the FAA amends 14 CFR part 39 as follows:

PART 39--AIRWORTHINESS DIRECTIVES

0
1. The authority citation for part 39 continues to read as follows:

    Authority: 49 U.S.C. 106(g), 40113, 44701.

Sec.  39.13  [Amended]

0
2. The FAA amends Sec.  39.13 by adding the following new AD:

2007-26-16 Cessna Aircraft Company: Amendment 39-15318. Docket No.
FAA-2007-0379; Directorate Identifier 2007-NM-331-AD.

Effective Date

    (a) This airworthiness directive (AD) is effective January 18,
2008.

Affected ADs

    (b) None.

Applicability

    (c) This AD applies to Cessna Model 680 airplanes, certificated
in any category, serial numbers -0001 through -0152 inclusive, -
0157, and -0158.

Unsafe Condition

    (d) This AD results from an incident report which indicated that
a hydraulic leak and wire chafing, including signs of heat damage,
were found within the lower tail cone fairing area. Similar wire
chafing has also been found on other airplanes. We are issuing this
AD to detect and correct wire chafing, and inadequate separation of
the wiring and hydraulic line, which could lead to electrical arcing
and a hydraulic leak and could result in a potential source of
ignition and consequent fire.

Compliance

    (e) Comply with this AD within the compliance times specified,
unless already done.

Inspections/Corrective Actions

    (f) Within 10 days after the effective date of this AD: Do a
general visual inspection of the routing of the aft fairing wire
bundle assembly for adequate separation between the wiring and the
hydraulic line, and do a general visual inspection for chafing or
damage of the wire bundle assembly and for damage to the hydraulic
line; by doing all of the actions, including all applicable
corrective actions, specified in the Accomplishment Instructions of
Cessna Alert Service Letter ASL680-24-02, dated October 1, 2007;
except as provided by paragraph (g) of this AD. Do all applicable
corrective actions before further flight.

    Note 1: For the purposes of this AD, a general visual inspection
is: ``A visual examination of an interior or exterior area,
installation, or assembly to detect obvious damage, failure, or
irregularity. This level of inspection is made from within touching
distance unless otherwise specified. A mirror may be necessary to
ensure visual access to all surfaces in the inspection area. This
level of inspection is made under normally available lighting
conditions such as daylight, hangar lighting, flashlight, or
droplight and may require removal or opening of access panels or
doors. Stands, ladders, or platforms may be required to gain
proximity to the area being checked.''

Exception to Alert Service Letter

    (g) Although the Accomplishment Instructions of Cessna Alert
Service Letter ASL680-24-02, dated October 1, 2007, specify to
submit certain information to the manufacturer, this AD does not
include that requirement.

Alternative Methods of Compliance (AMOCs)

    (h)(1) The Manager, Electrical Systems and Avionics, ACE-119W,
FAA, ATTN: Jarrett Larrow, Aerospace Engineer, Electrical Systems
and Avionics, ACE-119W, FAA, Wichita Aircraft Certification Office,
1801 Airport Road, room 100, Mid-Continent Airport, Wichita, Kansas
67209; telephone<PHONE_NUMBER>; fax<PHONE_NUMBER>; has the
authority to approve AMOCs for this AD, if requested using the
procedures found in 14 CFR 39.19.
    (2) To request a different method of compliance or a different
compliance time for this AD, follow the procedures in 14 CFR 39.19.
Before using any approved AMOC on any airplane to which the AMOC
applies, notify your appropriate principal inspector (PI) in the FAA
Flight Standards District Office (FSDO), or lacking a PI, your local
FSDO.

Material Incorporated by Reference

    (i) You must use Cessna Alert Service Letter ASL680-24-02, dated
October 1, 2007, to do the actions required by this AD, unless the
AD specifies otherwise.
    (1) The Director of the Federal Register approved the
incorporation by reference of this service information under 5
U.S.C. 552(a) and 1 CFR part 51.
    (2) For service information identified in this AD, contact
Cessna Aircraft Co., P.O. Box 7706, Wichita, Kansas 67277.
    (3) You may review copies of the service information
incorporated by reference at the FAA, Transport Airplane
Directorate, 1601 Lind Avenue SW., Renton, Washington; or at the
National Archives and Records Administration (NARA). For information
on the availability of this material at NARA, call<PHONE_NUMBER>, or
go to: http://www.archives.gov/federal_register/code_of_federal_regulations/ibr_locations.html
.

    Issued in Renton, Washington, on December 20, 2007.
Ali Bahrami,
Manager, Transport Airplane Directorate, Aircraft Certification
Service.
[FR Doc. 07-6265 Filed 1-2-08; 8:45 am]

BILLING CODE 4910-13-P