11 Maximum permissible retention of non-aqueous drilling fluid (NAF) base fluid on wet drill cuttings average over drilling intervals using NAFs as determined by the API retort method (Appendix 7 of subpart A of this part). This limitation is applicable for NAF base fluids that meet the ester base fluid sediment toxicity ratio and ester biodegradation rate ratio stock limitations defined as: (a) ester base fluid sediment toxicity ratio = 10-day LCs of Ciz-C1: ester or Cs ester /10-day LCs of stock base fluid as determined by ASTM E 1367–92 (specified at $435.11(ee)) method: "Standard Guide for Conducting 10-day Static Sediment Toxicity Tests with Marine and Estuarine Amphipods," 1992, after preparing the sediment according to the method specified in Appendix 3 of subpart A of this part. This incorporation by reference was approved by the Director of the Federal Register in accordance with 5 U.S.C. 552(a) and 1 CFR part 51. Copies may be obtained from the American Society for Testing and Materials, 100 Barr Harbor Drive, West Conshohocken, PA, 19428. Copies may be inspected at the National Archives and Records Administration (NARA). For information on the availability of this material at NARA, call 202–741-6030, or go to: http://www.archives.gov/ federal__register/code_of_federal__regulations/ ibr_locations.html. A copy may also be inspected at EPA's Water Docket, 1200 Pennsylvania Ave., NW., Washington, DC 20460. (b) ester biodegradation rate ratio = Cumulative gas production (ml) of CirC14 ester or Cs ester/Cumulative gas production (ml) of stock base fluid, both at 275 days as determined by ISO 11734:1995 (specified at $435. 11(e)) method: "Water quality-Evaluation of the ultimate' anaerobic biodegradability of organic compounds in digested sludgeMethod by measurement of the biogas production (1995 edition)" as modified for the marine environment (Appendix 4 of subpart A of this part). This incorporation by reference was approved by the Director of the Federal Register in accordance with 5 U.S.C. 552(a) and 1 CFR part 51. Copies may be obtained from the American National Standards Institute, 11 West 42nd Street, 13th Floor, New York, NY 10036. Copies may be inspected at the National Archives and Records Administration (NARA). For information on the availability of this material at NARA, call 202–741-6030, or go to: http:// www.archives.gov/tederal_register/ code_of_federal_regulations/br_locations.html. A copy may also be inspected at EPA's Water Docket, 1200 Pennsylvania Ave., NW., Washington, DC 20460. (C) PAH mass ratio Footnote 5), mercury, and cadmium stock limitations (C16Cis internal olefin) defined above in this table.

Sanitary M91M

Domestic Waste

(58 FR 12504, Apr. 13, 1979, as amended at 66 FR 6898, Jan. 22, 2001; 69 FR 18803, Apr. 9, 2004]

1 All Alaskan facilities are subject to the drilling fluids and drill cuttings discharge limitations for facilities located more than 3 miles offshore

2 As determined by the static sheen test (appendix 1).

3 As determined by the presence of a film or sheen upon or a discoloration of the surface of the receiving water (visual sheen).

(58 FR 12504, Apr. 13, 1979, as amended at 66 FR 6899, Jan. 22, 2001)

$ 435.14 Effluent limitations guidelines

representing the degree of effluent reduction attainable

by the application of the best conventional pollutant control technology (BCT). Except as provided in 40 CFR 125.30 32, any existing point source subject to this subpart must achieve the following effluent limitations representing the degree of effluent reduction attainable by the application of the best conventional pollutant control technology (BCT):

$ 435.15 Standards of performance for

new sources (NSPS). Any new source subject to this subpart must achieve the following new source performance standards (NSPS):

New SOURCE PERFORMANCE STANDARDS

Drilling fluids and drill

cuttings: (A) For facilities lo

cated within 3

miles from shore. (B) For facilities lo

cated beyond 3
miles from shore:
Water-based

drilling fluids
and associated
drill cuttings.

For NAFs that meet

the stock limitations (C1-C internal olefin) in this table, the maximum weighted mass ratio averaged over all NAF well sections shall be 6.9 g-NAF base fluid/100 g-wet drill

SPP Toxicity

cuttings. 10

Free oil Diesel oil Mercury

Cadmium

Non-aqueous

drilling fluids. Drill cuttings associ

ated with non-
aqueous drilling
fluids:
Stock Limitations Mercury

(C16-Cim inter-
nal oletin.

Cadmium

Well treatment, com

pletion, and
workover fluids.

For NAFs that meet

the Cir-C;ester
or Cester stock
limitations in foot-
note 11 of this
table, the max-
imum weighted
mass ratio aver-
aged over all NAF
well sections shall
be 9.4 g-NAF base
fluid/100 g-wet drill

cuttings Oil and

The maximum for grease

any one day shall not exceed 42 mg/ 1; the average of daily values for 30 consecutive days shall not exceed

29 mgi. Free oil

No discharge. *

No discharge. Residual chlo- Minimum of 1 mgi rine.

and maintained as close to this as

possible, Floating sol

No discharge. ids. Floating sol

Deck drainage Produced sand Sanitary M10

Polynuclear

Aromatic
Hydro-
carbons

(PAH). Sediment tox

icity

Sanitary M9IM

Biodegrada

tion rate.

Diesel oil

Discharge Limita

tions.

SPP Toxicity

Sediment tox

SPAH mass ratio = Mass (g) of PAH (as phenanthrene)/ Mass (g) of stock base fluid as determined by EPA Method 1654, Revision A, (specified at $435.11(u)) entitled "PAH Content of Oil by HPLC/UV," December 1992, which is published in Methods for the Determination of Diesel, Mineral, and Crude Oils in Offshore Oil and Gas Industry Discharges, EPA-821-R-92-008. This incorporation by reference was approved by the Director of the Federal Register in accordance with 5 U.S.C. 552(a) and 1 CFR part 51. Copies may be obtained from the National Technical Information Service, Springfield, VA 22161, 703-605-6000. Copies may be inspected at the National Archives and Records Administration (NARA). For information on the availability of this material at NARA, call 202-741-6030, or go to: http://www.archives.gov/ federal_register/code_of_federal_regulations/

dr_locations.html. A copy may also be inspected at EPA's Water Docket, 1200 Pennsylvania Ave., NW., Washington, DC 20460,

Base fluid sediment toxicity ratio = 10-day LCs. of C16-C18 internal olefin 10-day LCs of stock base fluid as determined by ASTM E 1367-92 (specified at $435.11(ee)) method: Standard Guide for Conducting 10-day Static Sediment Toxicity Tests with Marine and Estuarine Amphipods," 1992, after preparing the sediment according to the method specified in Appendix 3 of subpart A of this part

. This incorporation by reference was approved by the Director of the Federal Register in accordance with 5 U.S.C. 552(a) and 1 CFR part 51. Copies may be obtained from the American Society for Testing and Materials, 100 Barr Harbor Drive, West Conshohocken, PA, 19428. Copies may be inspected at the National Archives and Records Administration (NARA). For information on the availability of this material at NARA, call 202-741-6030, or go to:

http://www.archives.gov/federal_registeri code_of_federal_regulations/ibr_locations.html. A copy may also be inspected at EPA's Water Docket, 1200 Pennsylvania Ave., NW., Washington, DC 20460.

7 Biodegradation rate ratio = Cumulative gas production (ml) of C16-Cis internal olefin/Cumulative gas production (mi) of stock base fluid, both at 275 days as determined by iso 11734:1995 (specified at $435.11(e)) method: "Water quality Evaluation of the 'ultimate anaerobic biodegradability of organic compounds in digested sludgeMethod by measurement of the biogas production (1995 edition)" as modified for the marine environment (Appendix 4 of subpart A of this part). This incorporation by reference was approved by the Director of the Federal Register in accordance with 5 U.S.C. 552(a) and 1 CFR part 51. Copies may be obtained from the American National Standards Institute, 11 West 42nd Street, 13th Floor, New York, NY 10036. Copies may be inspected at the National Archives and Records Administration (NARA), For information on the availability of this material at NARA, call 202-741-6030, or go to: http://www.archives.gov/ federal_register/code_of_federal_regulations/ br_locations.html. A copy may also be inspected at EPA's Water Docket, 1200 Pennsylvania Ave., NW., Washington, D 20460. Drilling fluid sediment toxicity ratio = 4-day LCs of C16-Cis internal olefin drilling fluid/4-day LCs, of drilling fluid removed from drill cuttings at the solids control equipment as determined by ASTM E 1367-92 (specified at $ 435.11(ee)) method "Standard Guide for Conducting 10-day Static Sediment Toxicity Tests with Marine and Estuarine Amphipods," 1992, after preparing the sediment according to the method specified in Appendix 3 of subpart A of this part. This incorporation by reterence was approved by the Director of the Federal Register in accordance with 5 U.S.C. 552(a) and 1 CFR part 51. Copies may be obtained from the American Society for Testing and Materials, 100 Barr Harbor Drive, West Conshohocken, PA, 19428. Copies may be inspected at the National Archives and Records Administration (NARA). For information on the availability of this material at NARA, call 202-741-6030,

go to: http://www.archives.gov/ federal_register/code_of_federal_regulations! br_locations.html. A copy may also be inspected at EPA's Water Docket, 1200 Pennsylvania Ave., NW., Washington, D 20460.

As determined before drilling fluids are shipped offshore by the GC/MS compliance assurance method (Appendix 5 of subpart A of this part), and as determined prior to discharge by the APE method (Appendix 6 of subpart A of this part) applied to drilling fluid removed from drill cuttings. If the operator wishes to confirm the results of the APE method (Appendix 6 of subpart A of this part), the operator may use the GC/MS compliance assurance method Appendix 5 of subpart A of this part). Results from the GC/MS compliance assurance method (Appendix 5 of subpart A of this part) shall supercede the results of the RPE method (Appendix 6 of subpart A of

10 Maximum permissible retention of non-aqueous drilling fluid (NAF) base fluid on wet drill cuttings averaged over drilling intervals using NAFs as determined by the API retort method (Appendix 7 of subpart A of this part). This limitation is applicable for NAF base fluids that meet the base fluid sediment toxicity ratio (Footnote 6), biodegradation rate ratio (Footnote 7), PAH, mercury, and cadmium stock limitations C16-Cis internal olefin) defined above in this table.

11 Maximum permissible retention of non-aqueous drilling fluid (NAF) base fluid on wet drill cuttings average over drilling intervals using NAFs as determined by the API retort method (Appendix 7 ot subpart A of this part). This limitation is applicable for NAF base fluids that meet the ester base fluid sediment toxicity ratio and ester biodegradation rate ratio stock limitations defined as: (a) Ester base fluid sediment toxicity ratio = 10-day LCs. of Cir-C14 ester or Cs ester /10-day LCs. of stock base fluid as determined by ASTM E 1367-92 (specified at $ 435.11(ee)) method: "Standard Guide for Conducting 10-day Static Sediment Toxicity Tests with Marine and Estuarine Amphipods," 1992, after preparing the sediment according to the method specified in Appendix 3 of subpart A of this part. This incorporation by reference was approved by the Director of the Federal Register in accordance with 5 U.S.C. 552(a) and 1 CFR part 51. Copies may be obtained from the American Society for Testing and Materials, 100 Barr Harbor Drive, West Conshohocken, PA, 19428. Copies may be inspected at the National Archives and Records Administration (NARA). For information on the availability of this material at NARA, call 202–741-6030, or go to: http://www.archives.gov/ federal__register/code_of_federal_regulations/ ibr_locations.html. A copy may also be inspected at EPA's Water Docket, 1200 Pennsylvania Ave., NW., Washington, DC 20460; (b) Ester biodegradation rate ratio = Cumulative gas production (ml) of C1-C14 ester or Cg ester/Cumulative gas production (ml) of stock base fluid, both at 275 days as determined by ISO 11734.1995 (specified at $435.11(e)) method: "Water quality-Evaluation of the 'ultimate anaerobic biodegradability of organic compounds in digested sludge Method by measurement of the biogas production (1995 edition)" as modified for the marine environment (Appendix 4 of subpart A of this part). This incorporation by reference was approved by the Director of the Federal Register in accordance with 5 U.S.C. 552(a) and 1 CFR part 51. Copies may be obtained from the American National Standards Institute, 11 West 42nd Street, 13th Floor, New York, NY 10036. Copies may be inspected at the National Archives and Records Administration (NARA). For information on the availability of this material at NARA, call 202-741-6030, or go to: http:// www.archives.gov/federal_register/ code_of federal regulations/ibr_locations.html. А

Copy may also be inspected at EPA's Water Docket, 1200 Pennsylvania Ave., NW., Washington, DC 20460; and (c) PAH mass ratio (Footnote 5), mercury, and cadmium stock limitations (C16-Cis internal olefin) defined above in this table.

(58 FR 12504, Apr. 13, 1979, as amended at 66 FR 6900, Jan. 22, 2001; 66 FR 33134, June 20, 2001; 69 FR 18803, Apr. 9, 2004)

APPENDIX 1 TO SUBPART A OF PART

435-STATIC SHEEN TEST

or

1. Scope and Application This method is to be used as a compliance test for the “no discharge of free oil" requirement for discharges of drilling fluids, drill cuttings, produced sand, and well treatment, completion and workover fluids. “Free oil” refers to any oil contained in a waste stream that when discharged will cause a film or sheen upon or a discoloration of the surface of the receiving water.

2. Summary of Method 15-mL samples of drilling fluids or well treatment, completion, and workover fluids, and 15-g samples (wet weight basis) of drill cuttings or produced sand are introduced into ambient seawater in a container having

this part)

an air-to-liquid interface area of 1000 cm2 (155.5 in2). Samples are dispersed within the container and observations made no more than one hour later to ascertain if these materials cause a sheen, iridescence, gloss, or increased reflectance on the surface of the test seawater. The occurrence of any of these visual observations will constitute a demonstration that the tested material contains "free oil," and therefore results in a prohibition of its discharge into receiving waters.

3. Interferences Residual "free oil” adhering to sampling containers, the magnetic stirring bar used to mix the sample, and the stainless steel spatula used to mix the sample will be the principal sources of contamination problems. These problems should only occur if improperly washed and cleaned equipment are used for the test. The use of disposable equipment minimizes the potential for similar contamination from pipettes and the test container.

7. Sample Collection and Handling 7.1 Sampling containers must be thoroughly washed with detergent, rinsed a minimum of three times with fresh water, and allowed to air dry before samples are col. lected.

7.2 Samples of drilling fluid to be tested shall be taken at the shale shaker after cuttings have been removed. The sample volume should range between 200 mL and 500 mL.

7.3 Samples of drill cuttings will be taken from the shale shaker screens with a clean spatula or similar instrument and placed in a glass beaker. Cuttings samples shall be collected prior to the addition of any washdown water and should range between 200 g and 500 g.

7.4 Samples of produced sand must be obtained from the solids control equipment from which the discharge occurs on any given day and shall be collected prior to the addition of any washdown water; samples should range between 200 g and 500 g.

7.5 Samples of well treatment, completion, and workover fluids must be obtained from the holding facility prior to discharge; the sample volume should range between 200 mL and 500 mL.

7.6 Samples must be tested no later than 1 hour after collection.

7.7 Drilling fluid samples must be mixed in their sampling containers for 5 minutes prior to the test using a magnetic bar stirrer. If predilution is imposed as a permit condition, the sample must be mixed at the same ratio with the same prediluting water as the discharged muds and stirred for 5 minutes.

7.8 Drill cuttings must be stirred and well mixed by hand in their sampling containers prior to testing, using a stainless steel spatula.

4. Apparatus, Materials, and Reagents 4.1 Apparatus 4.1.1 Sampling Containers: 1-liter poly

ethylene beakers and 1-liter glass beak

ers. 4.1.2 Graduated cylinder: 100-ml grad

uated cylinder required only for operations where predilution of mud dis

charges is required. 4.1.3 Plastic disposable weighing boats. 4.1.4 Triple-beam scale. 4.1.5 Disposable pipettes: 25-mL disposable

pipettes. 4.1.6 Magnetic stirrer and stirring bar. 4.1.7 Stainless steel spatula. 4.1.8 Test container: Open plastic con

tainer whose internal cross-section parallel to its opening has an area of 1000 cm2:50 cm2 (155.5 17.75 in2), and a depth of at least 13 cm (5 inches) and no more

than 30 cm (11.8 inches). 4.2 Materials and Reagents. 4.2.1 Plastic liners for the test container:

Oil-free, heavy-duty plastic trash can liners that do not inhibit the spreading of an oil film. Liners must be of sufficient size to completely cover the interior surface of the test container. Permittees must determine an appropriate local source of liners that do not inhibit the spreading of 0.05 mL of diesel fuel added to the lined test container under the test

conditions and protocol described below. 4.2.2 Ambient receiving water.

8. Procedure 8.1 Ambient receiving water must be used as the “receiving water" in the test. The temperature of the test water shall be as close as practicable to the ambient conditions in the receiving water, not the room temperature of the observation facility. The test container must have an air-to-liquid interface area of 1000 150 cm2. The surface of the water should be no more than 1.27 cm (.5 inch) below the top of the test container.

8.2 Plastic liners shall be used, one per test container, and discarded afterwards. Some liners may inhibit spreading of added oil; operators shall determine an appropriate local source of liners that do not inhibit the spreading of the oil film.

8.3 A 15-mL sample of drilling fluid or well treatment, completion, and workover fluids must be introduced by pipette into the test container 1 cm below the water surface. Pipettes must be filled and discharged with

5. Calibration

None currently specified.

6. Quality Control Procedures None currently specified.

observation, discharge may continue and additional sampling is not required.

If a sheen or slick occurs on greater than one-half of the surface area of the test container after the test material is introduced, discharge of the tested material shall cease. The permittee may retest the material causing the sheen or slick. If subsequent tests do not result in a sheen or slick covering greater than one-half of the surface area of the test container, discharge may continue.

APPENDIX 2 TO SUBPART OF PART 435—DRILLING FLUIDS TOXICITY TEST

test material prior to the transfer of test material and its introduction into test containers. The test waterítest material mixture must be stirred using the pipette to distribute the test material homogeneously throughout the test water. The pipette must be used only once for a test and then discarded.

8.4 Drill cuttings or produced sand should be weighed on plastic weighing boats; 15-g samples must be transferred by scraping test material into the test water with a stainless steel spatula. Drill cuttings shall not be prediluted prior to testing. Also, drilling fluids and cuttings will be tested separately. The weighing boat must be immersed in the test water and scraped with the spatula to transfer any residual material to the test container. The drill cuttings or produced sand must be stirred with the spatula to an even distribution of solids on the bottom of the test container.

8.5 Observations must be made no later than 1 hour after the test material is transferred to the test container. Viewing points above the test container should be made from at least three sides of the test container, at viewing angles of approximately 60° and 30° from the horizontal. Illumination of the test container must be representative of adequate lighting for a working environment to conduct routine laboratory procedures. It is recommended that the water surface of the test container be observed under a fluorescent light source such as a dissecting microscope light. The light source shall be positioned above and directed over the entire surface of the pan.

8.6 Detection of a “silvery” or “metallic' sheen or gloss, increased reflectivity, visual color, iridescence, or an oil slick on the water surface of the test container surface shall constitute a demonstration of "free oil." These visual observations include patches, streaks, or sheets of such altered surface characteristics. If the free oil content of the sample approaches or exceeds 10%, the water surface of the test container may lack color, a sheen, or iridescence, due to the increased thickness of the film; thus, the observation for an oil slick is required. The surface of the test container shall not be disturbed in any manner that reduces the size of any sheen or slick that may be present.

If an oil sheen or slick occurs on less than one-half of the surface area after the sample is introduced to the test container, observations will continue for up to 1 hour. If the sheen or slick increases in size and covers greater than one-half of the surface area of the test container during the observation period, the discharge of the material shall cease. If the sheen or slick does not increase in size to cover greater than one-half of the test container surface area after one hour of

1. Sample Collection The collection and preservation methods for drilling fluids (muds) and water samples presented here are designed to minimize sample contamination and alteration of the physical or chemical properties of the samples due to freezing, air oxidation, or drying.

1-A. Apparatus (1) The following items are required for water and drilling mud sampling and storage:

a. Acid-rinsed linear-polyethylene bottles or other appropriate noncontaminating drilling mud sampler.

b. Acid-rinsed linear-polyethylene bottles or other appropriate noncontaminating water sampler.

c. Acid-rinsed linear-polyethylene bottles or other appropriate noncontaminated vessels for water and mud samples.

d. Ice chests for preservation and shipping of mud and water samples.

I-B. Water Sampling (1) Collection of water samples shall be made with appropriate acid-rinsed linearpolyethylene bottles or other appropriate non-contaminating water sampling devices. Special care shall be taken to avoid the introduction of contaminants from the sampling devices and containers. Prior to use, the sampling devices and containers should be thoroughly cleaned with a detergent solution, rinsed with tap water, soaked in 10 percent hydrochloric acid (HCl) for 4 hours, and then thoroughly rinsed with glass-distilled water.

1-C. Drilling Mud Sampling (1) Drilling mud formulations to be tested shall be collected from active field systems. Obtain a well-mixed sample from beneath the shale shaker after the mud has passed through the screens. Samples shall be stored in polyethylene containers or in other appropriate uncontaminated vessels. Prior to sealing the sample containers on the platform, flush as much air out of the container by filling it with drilling fluid sample, leaving a one inch space at the top.