NR 440.682(1)(a)3.
3. The group of all equipment except compressors, as defined in
sub. (2), within a process unit is an affected facility.
NR 440.682(1)(b)
(b) Any affected facility under
par. (a) that commences construction, reconstruction or modification after January 20, 1984 is subject to the requirements of this section.
NR 440.682(1)(c)
(c) Addition or replacement of equipment, as defined in
sub. (2), for the purpose of process improvement that is accomplished without a capital expenditure may not by itself be considered a modification under this section.
NR 440.682(1)(e)
(e) A compressor station, dehydration unit, sweetening unit, underground storage tank, field gas gathering system, or liquified natural gas unit is covered by this section if it is located at an onshore natural gas processing plant. If the unit is not located at the plant site, then it is exempt from the provisions of this section.
NR 440.682(2)
(2) Definitions. As used in this section, terms not defined in this subsection have the meanings given in
s. NR 440.02 or
440.62.
NR 440.682(2)(a)
(a) “Alaskan north slope" means the approximately 69,000 square-mile area extending from the Brooks Range to the Arctic Ocean.
NR 440.682(2)(b)
(b) “Equipment" means each pump, pressure relief device, open-ended valve or line, valve, compressor, and flange or other connector that is in VOC service or in wet gas service and any device or system required by this section.
NR 440.682(2)(c)
(c) “Field gas" means feedstock gas entering the natural gas processing plant.
NR 440.682(2)(e)
(e) “In wet gas service" means that a piece of equipment contains or contacts the field gas before the extraction step in the process.
NR 440.682(2)(f)
(f) “Natural gas liquids" means the hydrocarbons, such as ethane, propane, butane and pentane, that are extracted from field gas.
NR 440.682(2)(g)
(g) “Natural gas processing plant" or “gas plant" means any processing site engaged in the extraction of natural gas liquids from field gas fractionation of mixed natural gas liquids to natural gas products, or both.
NR 440.682(2)(h)
(h) “Nonfractionating plant" means any gas plant that does not fractionate mixed natural gas liquids into natural gas products.
NR 440.682(2)(i)
(i) “Onshore" means all facilities except those that are located in the territorial seas or on the outer continental shelf.
NR 440.682(2)(j)
(j) “Process unit" means equipment assembled for the extraction of natural gas liquids from field gas, the fractionation of the liquids into natural gas products, or other operations associated with the processing of natural gas products. A process unit can operate independently if supplied with sufficient feed or raw materials and sufficient storage facilities for the products.
NR 440.682(2)(k)
(k) “Reciprocating compressor" means a piece of equipment that increases the pressure of a process gas by positive displacement employing linear movement of the driveshaft.
NR 440.682(3)(a)(a) Each owner or operator subject to the provisions of this section shall comply with the requirements of
s. NR 440.62 (3) (a) 1.,
2. and
4., and
(b) to
(j), except as provided in
sub. (4), as soon as practicable, but no later than 180 days after initial startup.
NR 440.682(3)(c)
(c) An owner or operator may apply to the department for permission to use an alternative means of emission limitation that achieves a reduction in emissions of VOC at least equivalent to that achieved by the controls required in this section. In doing so, the owner or operator shall comply with requirements of
sub. (5).
NR 440.682(3)(f)
(f) An owner or operator shall use the following provision instead of
s. NR 440.62 (6) (d) 1. Each piece of equipment is presumed to be in VOC service or in wet gas service unless an owner or operator demonstrates that the piece of equipment is not in VOC service or in wet gas service. For a piece of equipment to be considered not in VOC service, it shall be determined that the VOC content can be reasonably expected never to exceed 10.0% by weight. For a piece of equipment to be considered in wet gas service, it shall be determined that it contains or contacts the field gas before the extraction step in the process. For purposes of determining the percent VOC content of the process fluid that is contained in or contacts a piece of equipment, procedures that conform to the methods described in ASTM E169-93, E168-92, or E260-96, incorporated by reference in
s. NR 440.17 (2) (a) 74., 73. and 75., respectively, shall be used.
NR 440.682(4)(a)(a) Each owner or operator subject to the provisions of this section may comply with the exceptions to the provisions of
s. NR 440.62.
NR 440.682(4)(b)2.
2. If an instrument reading of 10,000 ppm or greater is measured, a leak is detected.
NR 440.682(4)(b)3.a.a. When a leak is detected, it shall be repaired as soon as practicable, but no later than 15 calendar days after it is detected except as provided in
s. NR 440.62 (3) (i).
NR 440.682(4)(b)3.b.
b. A first attempt at repair shall be made no later then 5 calendar days after each leak is detected.
NR 440.682(4)(b)4.a.a. Any pressure relief device that is located in a nonfractionating plant that is monitored only by nonplant personnel may be monitored after a pressure release the next time the monitoring personnel are on site, instead of within 5 days as specified in
subd. 1. and
s. NR 440.62 (3) (d) 2. a.
NR 440.682(4)(b)4.b.
b. No pressure relief device described in
subd. 4. a. may be allowed to operate for more than 30 days after a pressure release without monitoring.
NR 440.682(4)(d)
(d) Pumps in light liquid service, valves in gas/vapor and light liquid service and pressure relief devices in gas vapor service that are located at a nonfractionating plant that does not have the design capacity to process 283,000 standard cubic meters per day (scmd) (10 million scf/day) or more of field gas are exempt from the routine monitoring requirements of
s. NR 440.62 (3) (b) 1. a. and
(g) 1. and
par. (b) 1.
NR 440.682(4)(e)
(e) Pumps in light liquid service, valves in gas/vapor and light liquid service, and pressure relief devices in gas/vapor service within a process unit that is located in the Alaskan North Slope are exempt from the routine monitoring requirements of
ss. NR 440.62 (3) (b) 1. a., and
(3) (g) 1. and
par. (b) 1.
NR 440.682(4)(h)1.
1. Equipment is in heavy liquid service if the weight percent evaporated is 10% or less at 150
°C (302
°F) as determined by ASTM D86-96, incorporated by reference in
s. NR 440.17 (2) (a) 7.
NR 440.682(4)(h)2.
2. Equipment is in light liquid service if the weight percent evaporated is greater than 10% at 150
°C (302
°F) as determined by ASTM D86-96, incorporated by reference in
s. NR 440.17 (2) (a) 7.
NR 440.682(5)(a)(a) If, in the administrator's judgement, an alternative means of emission limitation will achieve a reduction in VOC emissions at least equivalent to the reduction in VOC emissions achieved under any design, equipment, work practice or operational standard, the administrator will publish, in the federal register, a notice permitting the use of that alternative means for the purpose of compliance with that standard. The notice may condition permission on requirements related to the operation and maintenance of the alternative means.
NR 440.682(5)(b)
(b) Any notice under
par. (a) shall be published only after notice and an opportunity for a public hearing.
NR 440.682(5)(c)
(c) The administrator will consider applications under this subsection from either owners or operators of affected facilities, or manufacturers of control equipment.
NR 440.682(5)(d)
(d) The administrator will treat applications under this subsection according to the following criteria, except in cases where he or she concludes that other criteria are appropriate:
NR 440.682(5)(d)1.
1. The applicant shall collect, verify and submit test data, covering a period of at least 12 months, necessary to support the finding in
par. (a).
NR 440.682(5)(d)2.
2. If the applicant is an owner or operator of an affected facility, he or she shall commit in writing to operate and maintain the alternative means so as to achieve a reduction in VOC emissions at least equivalent to the reduction in VOC emissions achieved under the design, equipment, work practice or operational standard.
NR 440.682(6)(a)(a) Each owner or operator subject to the provisions of this section shall comply with the requirements of
pars. (b) and
(c) in addition to the requirements of
s. NR 440.62 (7).
NR 440.682(6)(b)
(b) The following recordkeeping requirements shall apply to pressure relief devices subject to the requirements of
sub. (4) (b) 1.:
NR 440.682(6)(b)1.
1. When each leak is detected as specified in
sub. (4) (b) 2., a weatherproof and readily visible identification, marked with the equipment identification number, shall be attached to the leaking equipment. The identification on the pressure relief device may be removed after it has been repaired.
NR 440.682(6)(b)2.
2. When each leak is detected as specified in
sub. (4) (b) 2., the following information shall be recorded in a log and shall be kept for 2 years in a readily accessible location:
NR 440.682(6)(b)2.a.
a. The instrument and operator identification numbers and the equipment identification number.
NR 440.682(6)(b)2.b.
b. The date the leak was detected and the dates of each attempt to repair the leak.
NR 440.682(6)(b)2.d.
d. “Above 10,000 ppm" if the maximum instrument reading measured by the methods specified in after each repair attempt is 10,000 ppm or greater.
NR 440.682(6)(b)2.e.
e. “Repair delayed" and the reason for the delay if a leak is not repaired within 15 calendar days after discovery of the leak.
NR 440.682(6)(b)2.f.
f. The signature of the owner or operator (or designate) whose decision it was that repair could not be effected without a process shutdown.
NR 440.682(6)(b)2.g.
g. The expected date of successful repair of the leak if a leak is not repaired within 15 days.
NR 440.682(6)(b)2.h.
h. Dates of process unit shutdowns that occur while the equipment is unrepaired.
NR 440.682(6)(c)
(c) An owner or operator shall comply with the following requirement in addition to the requirement of
s. NR 440.62 (10): Information and data used to demonstrate that a reciprocating compressor is in wet gas service to apply for the exemption in
sub. (4) (f) shall be recorded in a log that is kept in a readily accessible location.
NR 440.682(7)(a)(a) Each owner or operator subject to the provisions of this section shall comply with the requirements of
pars. (b) and
(c) in addition to the requirements of
s. NR 440.62 (8).
NR 440.682(7)(b)
(b) An owner or operator shall include the following information in the initial semiannual report in addition to the information required in
s. NR 440.62 (8) (b) 1. to
4.: number of pressure relief devices subject to the requirements of
sub. (4) (b) except for those pressure relief devices designated for no detectable emission under the provision of
s. NR 440.62 (3) (d) 1. and those pressure relief devices complying with
s. NR 440.62 (3) (d) 3.
NR 440.682 History
History: Cr.
Register, September, 1990, No. 417, eff. 10-1-90; am. (4) (b) 3. a.,
Register, July, 1993, No. 451, eff. 8-1-93
; correction in (4) (b) and (d) made under s. 13.93 (2m) (b) 7.,
Register, November, 1999, No. 527;
CR 06-109: am. (3) (f) and (4) (h) 1. and 2. Register May 2008 No. 629, eff. 6-1-08. NR 440.684
NR 440.684 Onshore natural gas processing: SO2 emissions. NR 440.684(1)(1)
Applicability and designation of affected facilities. NR 440.684(1)(a)(a) The provisions of this section are applicable to the following affected facilities that process natural gas: each sweetening unit, and each sweetening unit followed by a sulfur recovery unit.
NR 440.684(1)(b)
(b) Facilities that have a design capacity less than 2 long tons per day (LT/D) of hydrogen sulfide (H
2S) in the acid gas (expressed as sulfur) are required to comply with
sub. (8) (c) but are not required to comply with
subs. (3) to
(7).
NR 440.684(1)(c)
(c) The provisions of this section are applicable to facilities located on land and include facilities located onshore which process natural gas produced from either onshore or offshore wells.
NR 440.684(1)(d)
(d) The provisions of this section apply to each affected facility identified in
par. (a) which commences construction or modification after January 20, 1984.
NR 440.684(1)(e)
(e) The provisions of this section do not apply to sweetening facilities producing acid gas that is completely reinjected into oil-or-gas-bearing geologic strata or that is otherwise not released to the atmosphere.
NR 440.684(2)(a)1.
1. “Acid gas" means a gas stream of hydrogen sulfide (H
2S) and carbon dioxide (CO
2) that has been separated from sour natural gas by a sweetening unit.
NR 440.684(2)(a)2.
2. “Natural gas" means a naturally occurring mixture of a hydrocarbon and nonhydrocarbon gases found in geologic formations beneath the earth's surface. The principal hydrocarbon constituent is methane.
NR 440.684(2)(a)3.
3. “Onshore" means all facilities except those that are located in the territorial seas or on the outercontinental shelf.
NR 440.684(2)(a)4.
4. “Reduced sulfur compounds" means hydrogen sulfide (H
2S), carbonyl sulfide (COS), and carbon disulfide (CS
2).
NR 440.684(2)(a)5.
5. “Sulfur production rate" means the rate of liquid sulfur accumulation from the sulfur recovery unit.
NR 440.684(2)(a)6.
6. “Sulfur recovery unit" means a process device that recovers element sulfur from acid gas.
NR 440.684(2)(a)7.
7. “Sweetening unit" means a process device that separates the H
2S and CO
2 contents from the sour natural gas stream.
