Santa Barbara County APCD Rule 359 359 - 1 June 28, 1994

RULE 359. FLARES AND THERMAL OXIDIZERS. (Adopted 6/28/1994)

A. Applicability

The provisions of this Rule shall apply to the use of flares and thermal oxidizers at oil and gas

production sources (SIC code 13), petroleum refinery and related sources (SIC code 29), natural gas

services and transportation sources (SIC code 49) and wholesale trade in petroleum/petroleum products

(SIC code 51). This Rule shall, on the date of its adoption, supersede the fuel combustion provisions

of Rule 311 only insofar as these fuel combustion provisions apply to flares and thermal oxidizers.

B. Exemptions

1. The provisions of this Rule shall not apply to the burning of sulfur, hydrogen sulfide, acid

sludge or other sulfur compounds in the manufacturing of sulfur or sulfur compounds. For oil

and gas sources (SIC Code 13) that recover sulfur as a by-product of gas treating/sweetening

processes, the exemption for manufacturing shall apply only to those specific processes, e.g.,

sulfur recovery plant.

2. The provisions of this Rule, with the exception of Section D.2 (Technology Standards), shall

not apply to the burning of any gas with a net heating value of less than 300 British Thermal

Unit (Btu) per standard cubic foot (scf) provided the fuel used to incinerate such gas does not

contain sulfur compounds in excess of the following:

a. 15 grains/100 cu.ft. (calculated as H2S at standard conditions) in the Southern Zone,

and

b. 50 grains/100 cu.ft. (calculated as H2S at standard conditions) in the Northern Zone of

Santa Barbara County.

3. The provisions of this Rule, with the exception of Sections D.1 (Sulfur Content in Gaseous

Fuels), D.2 (Technology Standards), G (Monitoring and Recordkeeping) and H (Reporting)

shall not apply to flare or thermal oxidizer units rated, per their operating permits, at 1.7

MMBtu/hour or less. However, if the total cumulative rating of all such rated units at a source

exceeds 5 MMBtu/hr, then the exemption shall not apply.

4. The following are exempt only from Section D.3 (Flare Minimization Plan) of this Rule:

a. Flare and thermal oxidizer units rated, per their operating permits, at less than 15

MMBtu/hour. However, if the total cumulative rating of all such rated units at a

source exceeds 50 MMBtu/hr, then this exemption shall not apply.

b. Flares and thermal oxidizers whose flaring operations solely consist of planned,

continuous flaring due to the non-availability of a produced gas pipeline outlet.

C. Definitions

For purposes of this Rule, the following definitions shall apply. See Rule 102 (Definitions) for

definitions that are not restricted to interpretation of this Rule only.

"Burn" means combustion of any fuel including a gaseous fuel, whether for useful heat or by

incineration without heat recovery.

"Day" or "days" means calendar day(s) unless otherwise stated.
Santa Barbara County APCD Rule 359 359 - 2 June 28, 1994

"Emergency" means any situation arising from sudden and reasonably unforeseeable events beyond

the control of the permittee, including acts of God. An emergency situation requires immediate

corrective action to restore normal, safe operation. It also causes an exceedance of an emission

standard or a limit stipulated in this Rule, due to unavoidable increases in emissions attributable to the

emergency situation only. Events which have been deemed as planned events (for definition, see later

in this section) by a federal regulatory agency shall be precluded from being considered as emergency

events.

"Emergency Flare Event" means the combustion (flaring) of gaseous fuels caused by an emergency

event.

"Flare" means a direct combustion device in which air and all combustible gases react at the burner

with the objective of complete and instantaneous oxidation of the combustible gases. Flares are used

either continuously or intermittently and are not equipped with devices for fuel-air mix control or for

temperature control.

"Flare Gas" means produced gas or natural gas burned in a flare or thermal oxidizer.

"Gaseous fuel" means gases used as combustion fuel which include, but are not limited to, any natural,

process, synthetic, landfill, sewage digester, or waste gases. Gaseous fuel includes produced gas, pilot

gas and, when burned, purge gas.

"Month" or "monthly" means calendar month or refers to calendar month.

"Net heating value" means the heating value of the flare gas being combusted, as specified under 40

CFR 60.18(f)(3) [1992 Edition].

"Northern Zone of the Santa Barbara County" means that portion of Santa Barbara County

described in Section 60103(b) of Title 17 of the California Administrative Code as written on

December 21, 1968 (Register 68, No.48). The Northern Zone also includes (a) State waters and, (b)

those areas of the OCS waters for which the District has been designated the corresponding onshore

area by the USEPA -- which are located offshore of that portion of Santa Barbara County lying north

of the latitude of the mouth of Jalama Creek.

"Pilot Gas" means gas that is used to ignite or continually ignite flare gas. Pilot gas may be PUCquality gas, liquefied petroleum gas (LPG) or produced gas.

"Planned Flaring" means a flaring operation that constitutes a designed and planned process at a

source, and which would have been reasonably foreseen ahead of its actual occurrence, or is scheduled

to occur. Planned flaring includes, but is not limited to, the following activities:

1. Flaring during well tests, well-related work, tests ordered by applicable regulatory agencies;

2. Flaring due to equipment depressurization for preventive maintenance that includes: (a)

routine engine overhauls (b) turbine start-ups (c) compressor start-ups (d) engine exchange/

removal (e) platform modification/construction (f) hot-jobs (welding, etc.), (g) new

platform/well start-up, (h) well work-over, (i) maintenance at onshore source supporting

offshore production, (j) Installation of Sulferox etc., system, (k) planned plant shut-downs, (l)

unloading from new well, (m) rupture disc maintenance, (n) acid job, (o) source testing, and

(p) any pipeline depressurization not due to breakdown conditions (e.g., pigging);

3. Flaring of produced gas at production sources for which no gas handling, gas injection, or gas

transmission facilities currently exist;
Santa Barbara County APCD Rule 359 359 - 3 June 28, 1994

4. Flaring of "off-specification" gas (e.g., non-PUC quality gas), unless the permittee can

demonstrate that the gas must be flared for engineering or safety reasons, e.g., under an

emergency.

"Planned continuous flaring" shall include flare purge and flare pilot operations, and continuous

flaring of produced gas which is not otherwise processed at the source.

"Planned intermittent flaring" shall include all other planned flaring of limited duration in time and

volume of gaseous fuel, e.g., pigging or equipment depressurization for maintenance.

"Preventive Maintenance" means a regularly scheduled course of procedure designed to prevent

equipment failure or decline of equipment function.

"Produced gas" means organic compounds that are both: (a) gaseous at standard pressure and

temperature (1 atmosphere and 60°F), and (b) associated with the production, gathering, separation or

processing of crude oil and/or natural gas.

"Public Utilities Commission (PUC) Quality Gas" means, in the context of sulfur content of the

gaseous fuel, gas containing no more than one-fourth (0.25) grain of hydrogen sulfide per one hundred

(100) standard cubic feet and no more than five grains of total sulfur per one hundred (100) standard

cubic feet. PUC quality gas shall also mean high methane (at least 80 % by volume) gas as specified in

PUC's General Order 58-A.

"Purge Gas" means an inert gas mixture, LPG, PUC quality gas, or produced gas, any of which can be

used to maintain a non-explosive mixture of gases in the flare header or provide sufficient exit velocity

to prevent any regressive flame travel back into the flare header.

"Smokeless" means, in the context of flare or thermal oxidizer combustion, operation with visible

emissions not exceeding an opacity level, for a period or periods aggregrating more than three minutes

in any one hour, as dark or darker in shade as that designated as No. 1 on the Ringelmann Chart as

published by the U.S. Bureau of Mines.

"Southern Zone of the Santa Barbara County" means that portion of Santa Barbara County so

described in Section 60104 of Title 17 of the California Administrative Code as written on December

21, 1968 (Register 68, No.48). The Southern Zone also includes (a) State waters and, (b) those areas of

the OCS waters for which the District has been designated the corresponding onshore area by the

USEPA -- which are located offshore of that portion of Santa Barbara County lying south of the

latitude of the mouth of Jalama Creek.

"Thermal Oxidizer" means a combustion device that includes enclosed, ground-level flares and in

which the gases to be flared pass through one or more staged burners which may be steam quenched or

assisted to control smoke. The products of combustion are funneled through a naturally drafted stack

to above ground elevations. Thermal oxidizers come equipped with controls for combustion chamber

temperature and often with combustion fuel-air mix controls.

"Unplanned Flaring" means a flaring event that is not planned or scheduled to occur. An emergency

event is an example of an unplanned event (emergency event is a subset of unplanned event).
Santa Barbara County APCD Rule 359 359 - 4 June 28, 1994

D. Requirements

1. Sulfur Content in Gaseous Fuels

a. Effective June 28, 1994, any planned flaring shall not burn gaseous fuel which

contains sulfur compounds in excess of 15 grains per 100 cubic feet (239 ppmv) in

the Southern Zone of Santa Barbara County or 50 grains per 100 cubic feet (796

ppmv) in the Northern Zone of Santa Barbara County -- calculated as hydrogen

sulfide at standard conditions (i.e., 1 atmosphere and 60°F).

b. An owner or operator of a source may apply for an exemption from Section D.1.a, by

doing the following:

1) Demonstrate to the Control Officer that it is infeasible to comply with

Section D.1.a. The demonstration shall provide a detailed explanation

analyzing all engineering, safety or cost constraints. This demonstration

shall be submitted within 90 days of June 28, 1994; and,

2) Submit an offset plan as a compliance plan, mitigating the SO2 emissions

from the source associated with planned flaring which are in excess of the

limits in section D.1.a. at an offset ratio of 1:1. The offset plan shall meet all

federal and District criteria and guidelines for emission reductions; and may

include an inter-pollutant offset scheme, if allowed under the USEPA and the

State of California air quality regulations and guidelines. This plan shall be

submitted with the demonstration required under Section D.1.b.1). If the

exemption is granted by the Control Officer, the owner or operator shall

implement the offset plan.

c. All costs associated with the District's review and approval of the exemption

determination and offset plan shall be reimbursable by the owner or operator, in

accordance with the requirements of District Rule 210.I.C (Cost Reimbursements).

d. Emergency flare events are exempt from the provisions of Section D.1.a of this Rule.

2. Technology-based Standard

The owner or operator of any source subject to this Rule shall comply with the following

technology standards:

a. All flares and thermal oxidizers installed or operating after June 28, 1994 shall be

smokeless (cf: Definition in Section C).

b. All new and existing flares and thermal oxidizers shall comply with the following:

1) The outlet shall be equipped with an automatic ignition system including a

pilot-light gas source or equivalent system, or, shall operate with a pilot

flame present at all times -- with the exception of purge periods for

automatic-ignition equipped flares or thermal oxidizers.

2) The presence of the flame in the pilot of the flare or the thermal oxidizer shall

be continuously monitored using a thermocouple or an equivalent device that

detects the presence of a flame, unless such device(s) can be demonstrated by

the permittee to be infeasible, based on engineering, safety or costs

constraints, and to the satisfaction of the Control Officer; and,
Santa Barbara County APCD Rule 359 359 - 5 June 28, 1994

3) The flame shall be operating at all times when combustible gases are vented

through the flare or thermal oxidizer.

c. The following provisions shall apply to low-pressure, open pipe flare operations

where the flare gas pressure at the flare tip inlet is less than 5 psig:

1) Steam-assisted or air-assisted flares shall be operated only if the gaseous fuel

burned in such flares has a net heating value of 300 Btu/scf or greater. Nonassisted flares shall be operated only if the gaseous fuel burned in such flares

has a net heating value of 200 Btu/scf or greater.

2) Steam-assisted, air-assisted and non-assisted flares burning gaseous fuel with

a net heating value between 300 (200 for non-assisted flares) and 1,000

Btu/scf shall be operated with an actual exit velocity not exceeding a design

maximum velocity Vmax, defined in Appendix B to this Rule. The "actual

exit velocity" of a flare shall be determined by dividing the volumetric flow

rate (in units of standard temperature and pressure) by the unobstructed (free)

cross-sectional area of the flare tip.

3) Steam-assisted, air-assisted and non-assisted flares burning gaseous fuel with

net heating value exceeding 1000 Btu/scf shall be operated with an actual

exit velocity not exceeding 400 ft/sec.

3. Flare Minimization Plan

a. Any source subject to this Rule and operating flare or thermal oxidizer units rated at

15 MMBtu/hour or greater (ref: Section B.4 of this Rule) as listed in the source's

operating permits, or in the source's ATC if no operating permit has been issued, shall

submit a flare minimization plan to the Control Officer. The plan shall meet the

requirements set forth in Appendix A to this Rule.

b. For planned flaring, the minimization plan for all sources subject to this Rule shall list

a targeted maximum monthly flared gas volume. The target volume shall not exceed

five (5) per cent of the average monthly gas handled/produced/treated at the source,

calculated per Section D.3.c below. This targeted volume limit will be placed in the

source permit at the next operating permit issuance/renewal/reevaluation for the

source owner or operator. However, a higher limit may be granted by the Control

Officer, if the following condition is met:

The owner or operator can demonstrate such a maximum volume limit to be

infeasible based on safety, engineering or cost constraints and proposes a

different percentage as volume limit, based on the same considerations. The

proposed limit shall be included in the flare minimization plan for approval

by the Control Officer. After approval, the new throughput limit will be

placed on the Permit to Operate at the next permit renewal/reevaluation.

c. For sources which have operated for more than three years as of June 28, 1994, the

average monthly gas volume referred to in Section D.3.b. shall be based on the last

three calendar years of historical data for such volume. However, any three

consecutive calendar years of data may be used for such purpose if the permittee so

requests and demonstrates to the satisfaction of the Control Officer that such period is

more representative of the permitted operations at the source. For new or modified

sources or sources operating for less than three years, five (5) per cent of the source
Santa Barbara County APCD Rule 359 359 - 6 June 28, 1994

design capacity for gas handled/produced/treated shall be the target monthly volume

for the first three years of operation. Following three years of operation, the data

history obtained shall establish a new, planned flaring volume limit, which limit shall

be incorporated in the next operating permit for the source.

For existing sources, an increase in the monthly flared gas volume limit due to

produced/handled/treated gas volume increases shall not be considered a part of the

source's net emission increase, provided neither the permitted emission limits nor the

permitted volumes for gas produced/handled/treated are exceeded, and the Control

Officer has been notified, in writing, of such increases within 30 days of the end of

the month on which the increase occurs and the basis thereof.

d. Where limits have been established for sources pursuant to Section D.3.b above, the

owner or operator shall develop and submit an emissions mitigation plan, if both of

the following apply to the source's operations:

1) The permitted or proposed volume limit exceeds ten (10) per cent of average

monthly volume of handled/produced/treated gas (this average shall be

calculated per Section D.3.c above); and,

2) The sulfur content of the flared gas exceeds the fuel sulfur limits stipulated in

Section D.1.a. of this Rule.

e. The emissions mitigation plan shall achieve the following:

Reduction by 50 per cent, of either the actual average monthly flare gas volume

(calculated per Section D.3.c above) or the proposed volume limit, not later than five

(5) years after June 28, 1994, whichever reduction volume is greater. Such reduction

shall also follow the volume reduction schedule listed in the flare mitigation plan.

After the plan is approved, the plan listed limit(s) will be placed in the source permit

at the next operating permit issuance/renewal/reevaluation. 

f. All costs associated with the District's review and approval of plans submitted

pursuant to Section D.3 shall be reimbursable by the owner or operator, in accordance

with the requirements of District Rule 210.I.C (Cost Reimbursements).

4. Emergency Events

Any flaring which causes an exceedance of the emission limits or standards of this Rule shall

not be a violation of this Rule if the owner or operator of the source demonstrates that the

exceedance resulted from an emergency event. To demonstrate that an emergency event

occurred, the owner or operator shall do the following:

a. Inform the Control Officer (Attn: Compliance Manager), via phone or facsimile

equipment, of the commencement of any emergency event not later than four (4)

hours after the start of the next regular business day;

b. Contemporaneously document that an emergency event has occurred and the causes

have been identified in an operating log, and properly sign in each entry. Such logs

shall be available to the Control Officer on request;
Santa Barbara County APCD Rule 359 359 - 7 June 28, 1994

c. Submit to the Control Officer within seven (7) days of the end of the emergency

event:

1) a complete description of the event and all mitigating and corrective actions

implemented at the source per Appendix A (cf: flare minimization plan); and,

2) a demonstration that all reasonable steps were taken to minimize emissions in

excess of permit conditions or other permit requirements; and,

3) a demonstration that the emergency was not caused by improperly designed

equipment, lack of preventive maintenance, careless or improper operation,

operator error or willful misconduct.

4) a document that the source was being properly operated at the time the

emergency event occurred;

In any enforcement proceeding, the permittee seeking to establish the occurrence of

an emergency event has the burden of proof. A list of typical causes for emergency

flare events is provided in Appendix C of this Rule as guidance to the permittees.

5. Emission and Operational Limits

The following emission and operating limits shall apply to any source subject to this Rule:

a. Flares and thermal oxidizers which use flow-sensing automatic ignition systems and

which do not use a continuous flame pilot shall use inert gas or PUC quality gas for

purging.

b. Flares or thermal oxidizers rated at fifteen (15) million Btu/hour or greater shall not

exceed, for planned flaring, the targeted (cumulative) monthly volume limit of flare

gas (expressed as scf/month), established pursuant to Section D.3 (Flare Minimization

Plan).

c. Pollutant emissions from all thermal oxidizers and ground-level enclosed flares with

planned continuous flaring (per definition in Section C) exceeding 120,000 scf/day

(daily maximum basis) shall meet the following emission standards:

FLARE TYPE Heat Release Rate

(MMBtu/hr)

 Emissions

 ( in

Standards

lbs/MMBtu)

NOx ROC

w/o Steam-assist <10 MMBtu/hr 0.0952 0.0051

10-100 MMBtu/hr 0.1330 0.0027

>100 MMBtu/hr 0.5240 0.0013

with Steam Assist All 0.068 0.14--as TOG
Santa Barbara County APCD Rule 359 359 - 8 June 28, 1994

E. Test Methods

The standard test methods listed below shall be used during required tests, as applicable, by the source

owner or operator to demonstrate compliance with this Rule. Test methods not listed may be used if

the owner or operator demonstrates to the Control Officer that the method is an equivalent test method,

and obtains the USEPA or ARB approval of this method prior to its use.

1. Visible emissions shall be determined using the USEPA Reference Method 9.

2. For an open pipe flare, the volumetric flow rate for actual velocity shall be determined by the

USEPA Reference Methods 2, 2A, 2C or 2D as appropriate.

3. The net heating value of gaseous fuel shall be determined by ASTM D4891-89, or ASTM

D1945-81, or ASTM D1946-90.

4. For total gas sulfur content measurement:

a. Total reduced sulfur in the gaseous fuel shall be measured using the USEPA

Reference Method 16 (Gas Chromatography-Flame Photometric Detector analysis) or

16A or BAAQMD ST-21.

b. Gas sampling using the USEPA Method 18 and laboratory gas analysis using ASTM

D1072-90 or ASTM D4468-85 may be used in limited circumstances when preapproved by the Control Officer to determine the total reduced sulfur in gaseous fuels.

Strict controls on sampling materials and analysis turnaround time shall be required.

c. For field determination of H2S level during emergency flaring events, color detection

tube methods (e.g., Draeger, Sensidyne or other methods) may be used if the H2S

level in the gas stream is within the acceptable limits for the method.

5. NOx and ROC levels in the exhaust of thermal oxidizers or ground-level enclosed flares shall

be measured following procedures outlined in the applicable reference test methods listed in

40 CFR 60.17. The reference test methods include, but are not limited to the following:

a. NOx -- USEPA Method 7 or CARB 100

b. ROC -- USEPA Method 18 or USEPA Method 25.

c. Flow rate and mass emission rate -- USEPA Method 19

d. CO2 and O2 concentrations -- USEPA Method 3 or CARB 100.

6. Hydrogen sulfide in the gaseous fuel shall be measured using the USEPA Reference Method

11, modified as applicable for concentrations greater than 500 ppmv H2S.
Santa Barbara County APCD Rule 359 359 - 9 June 28, 1994

F. Source Testing

Any owner or operator of a source subject to this Rule shall perform the following:

1. Measure triennially the NOx and ROC emissions through the stack of any thermal oxidizer or

ground-level enclosed flare operated for planned continuous flaring of 120,000 scf/day of

gases or more (daily maximum basis), by source testing (annually for sources subject to

federal Part 70 operating permits, or more frequently if required by applicable rules). A source

test plan/schedule shall be submitted to the Control Officer as part of the required permit

application for the source.

2. Measure (a) the purge gas fuel sulfur content, if such gas is not a PUC quality gas or an inert

gas, and (b) the gaseous fuel sulfur content and the net heating value for all gaseous fuel

which constitute planned flaring. Measurement shall be performed triennially, except for

sources which require federal Part 70 operating permits, in which case annual or more frequent

testing shall be performed as required by applicable Part 64 Rules.

3. For emergency flare events, the owner or operator shall estimate the H2S content of the flare

gas using available operation and measurement records, provided that the owner or operator

can demonstrate to the satisfaction of the APCO that such records are representative of the gas

stream flared.

G. Monitoring and Recordkeeping

Any owner or operator of a source subject to this Rule shall perform the following, as applicable:

1. Monitor the volume (in scf/month) of all gaseous fuel flared as part of planned/unplanned

flaring, if subject to Section D.3. A flare volume monitoring plan shall be submitted to the

Control Officer for approval as part of the flare minimization plan. A record of monitored

volumes shall be kept by the owner or operator in a format prescribed and approved by the

Control Officer, and shall be available for inspection upon request by the District.

2. Monitor the volume of gaseous fuel flared during each emergency event as part of the required

emergency event description report.

H. Reporting

Any owner or operator of a source subject to this Rule shall provide the following reports, as

applicable:

1. Results of each source test for NOx and ROC, obtained pursuant to Section F.1, shall be

submitted to the Control Officer within 45 days of the completion of source testing.

2. The result of each test report for (a) purge gas S content (if applicable), (b) gaseous fuel S

content and (c) gaseous fuel net heating value, obtained pursuant to Section F.2, shall be

submitted to the Control Officer by March 1st of the year following the calendar year on

which the testing occurred.

3. Data for the monthly volumes (in scf/month) of gas flared per (i) planned continuous and (ii)

planned intermittent flaring categories, obtained pursuant to Section G.1, shall be submitted

annually to the Control Officer. Each calendar year data report shall be submitted by March

1st of the following calendar year.
Santa Barbara County APCD Rule 359 359 - 10 June 28, 1994

4. An annual summary of the total gas volume released during emergencies and the weightedaverage H2S content for the entire volume, obtained pursuant to Sections G.2 and F.3, to be

provided to the Control Officer. The annual report for each calendar year shall be submitted

by March 1st of the following year.

5. Report on any exceedance of the allowable monthly volume of gases for planned flaring, to be

submitted to the Control Officer within sixty (60) days of the end of the exceedance month.

The report shall list the exceedance volume (volume in excess of the allowed volume) and the

estimated sulfur content of the gaseous fuel flared.

I. Compliance Schedule

1. New sources shall comply with this Rule on June 28, 1994.

2. Existing sources shall comply with this Rule as follows:

a. Offsets required pursuant to Section D.1.b. shall be implemented within 180 days

after the Control Officer grants the request for exemption. Extensions may be granted

by the Control Officer for good cause shown. Notwithstanding any other provision of

this rule, an owner or operator of a source who receives an exemption shall have

offsets in place no later than 1 year after the date the exemption request has been filed

with the Control Officer.

b. All flares and thermal oxidizers subject to Section D.2 shall comply within one (1)

year of June 28, 1994.

c. The flare minimization plan and emissions mitigation plan required pursuant to

Sections D.3.a. and D.3.d shall be submitted within 90 days after June 28, 1994, and

approval of the same shall be obtained within 180 days after June 28, 1994. Full

compliance with the targeted volume limits required under Sections D.3.b and D.3.e

shall be achieved within five (5) years of June 28, 1994.

d. Flares and thermal oxidizers subject to D.5.a. shall comply within 180 days of June

28, 1994,

e. If any new equipment is proposed for installation to comply with Section D.2, an

authority to construct application with all necessary information shall be submitted to

the Control Officer within ninety (90) days of June 28, 1994.

f. The flare volume monitoring plan required under Section G.1. shall be implemented

by the owner or operator within 30 days of the Control Officer approval of the plan.

3. Sources on the OCS which become subject to this Rule shall comply with all provisions of

this Rule by the dates specified in the Rule or when the USEPA promulgates this Rule as

applicable to the OCS sources, whichever is later.

J. Effective Date of Rule

This Rule is effective on June 28, 1994.
Santa Barbara County APCD Rule 359 359 - 11 June 28, 1994

APPENDIX A

The flare minimization plan shall include the following, where applicable:

1. Details of measures implemented at each source subject to this Rule to decrease the total

monthly volume of flare gas being combusted and to reduce the number of planned flaring

activities.

2. Descriptions of measures in place to prevent the recurrence of emergency flaring events, and

reduce the occurrence of unplanned flaring events. Such measures may include installation of

redundant equipment.

The flare minimization plan shall also incorporate the following:

a. A detailed description of the flare system including process flow diagram(s), flare tip design

details and the manufacturer's information on flare operation and maintenance;

b. A detailed description of the flare gas monitoring system that records the gas throughput, e.g.,

make and model of the meter, precision and accuracy of the meter, data management,

maintenance/calibration or manufacturer's specifications, and of the method to determine the

flare gas sulfur content;

c. The design and operation features of the pilot and purge gas system which minimize the

volume of gas consumed;

d. A description of the design features that demonstrate the capability of the flare to handle the

nominal and peak gas flows and the range of gas composition encountered at the source; all

calculations showing anticipated flare exit velocities for maximum flare gas flow rates;

e. Plans for reduction of emissions from planned flaring activities including those which result

from planned depressurizing of vessels, compressors, and pipelines;

f. Charts outlining the possibility of coordination of schedules to reduce planned shutdowns;

g. Any proposed study program involving operating set points on controllers and safety devices

to determine if a different setting could minimize emissions (for OCS sources, this study may

be submitted to the appropriate safety agency for approval prior to the Control Officer

submittal);

i. Summary of scheduled/typical planned flaring including frequency and volume; also,

summary of each of these parameters after implementation of the proposed plan; data on gas

production rates including the current actual and the maximum anticipated production rates.

The flare owner or operator shall review the flare minimization plan every five (5) years, and shall

submit to the District any findings of new procedures or technologies for flare minimization that were

not addressed in earlier plans. If any such procedures or technologies are identified, the owner or

operator shall also submit a schedule for the implementation of such procedures and technologies.

**********
Santa Barbara County APCD Rule 359 359 - 12 June 28, 1994

APPENDIX B

No flare shall operate with an actual exit velocity exceeding a designed maximum velocity Vmax. This

design velocity Vmax is computed, as follows:

1. For steam-assisted and non-assisted flares, the design maximum velocity Vmax1 is calculated

according to the equation:

Log10 (Vmax1) = (HT + 1214)/852, where

Vmax1 = maximum permitted velocity (in ft/sec); 1214 = a constant; 852 = a constant; and, HT

= net heating value of the gaseous fuel (in Btu/scf), provided 300 < HT < 1000 for steam-assist

and 200 < HT < 1000 for non-assist.

2. For air-assisted flares, the design maximum velocity Vmax2 is calculated by the following

equation:

Vmax2 = 28.56 + 0.0867 (HT), where

Vmax2 = maximum permitted velocity (in ft/sec): 28.56 = a constant: 0.0867 = a constant; and,

HT = net heating value of the gaseous fuel (in Btu/scf), provided 300 < HT <1000.

3. If HT exceeds 1000 Btu/scf, then HT shall equal 1000 Btu/scf for the purpose of applying these

equations to compute the value of Vmax.

Appendix B shall not apply to high-pressure flares where the flare gas pressure at the flare tip inlet is

greater than 5 psig.

*************
Santa Barbara County APCD Rule 359 359 - 13 June 28, 1994

APPENDIX C

The following events comprise a brief list of events that would qualify as emergency events. Note that

these events must also meet the criteria of emergency specified in this Rule, before they can be

considered as emergency events.

1. Equipment Breakdowns: Electrical equipment (transformer, motors) and internal

combustion engine breakdowns. Major equipment

breakdowns (turbine-generator, compressor, compressor

stage fall-outs etc.)

2. Relief Valve Events: All unintentional safety valve releases as caused by

emergency shutdown valve(s) and shut-in valve(s) events,

temperature control events and high/low fluid temperature

and pressure level events.

3. Source/Pipeline Shutdowns: All offshore and onshore process and source or plant

breakdowns and pipeline breakdown events.

4. Other Events: Fire hazard avoidance events, toxic and flammable gas

alarm events, faulty-sensor-caused shutdowns, high/low

temperature and pressure indicated shutdowns.

The following shall also be considered as emergency flaring events:

Sudden power failure at onshore source, sudden process problems including foaming within

production units, process-computer problems at production and pollution control units, pollution

control equipment breakdowns, power supply system breakdowns, pipeline or fuel line breakdowns.

Emergency events continue in duration until the operator gets the emergency situation under control

including the emission exceedances, or shuts down the source, or reroutes production to a different

source.

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