§ 435.15 - Standards of performance for new sources (NSPS).

§ 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

Waste source	Pollutant parameter	NSPS
Produced water	Oil and grease	The maximum for any one day shall not exceed 42 mg/l; the average of daily values for 30 consecutive days shall not exceed 29 mg/l.
Drilling fluids and drill cuttings:
(A) For facilities located within 3 miles from shore		No discharge.1
(B) For facilities located beyond 3 miles from shore:
Water-based drilling fluids and associated drill cuttings	SPP Toxicity	Minimum 96-hour LC50. of the SPP Toxicity Test2 shall be 3% by volume.
	Free oil	No discharge.3
	Diesel oil	No discharge.
	Mercury	1mg/kg dry weight maximum in the stock barite.
	Cadmium	3 mg/kg dry weight maximum in the stock barite.
Non-aqueous drilling fluids		No charge.
Drill cuttings associated with non-aqueous drilling fluids:
Stock Limitations (C16-C18 internal olefin	Mercury	1mg/kg dry weight maximum in the stock barite.
	Cadmium	3 mg/kg dry weight maximum in the stock barite.
	Polynuclear Aromatic Hydrocarbons (PAH)	PAH mass ratio5 shall not exceed 1 × 10−5.
	Sediment toxicity	Base fluid sediment toxicity ratio6 shall not exceed 1.0.
	Biodegradation rate	Biodegradation rate ratio7 shall not exceed 1.0.
Discharge Limitations	Diesel oil	No discharge.
	SPP Toxicity	Minimum 96-hour LC50. of the SPP Toxicity Test2 shall be 3% by volume.
	Sediment toxicity	Drilling fluid sediment toxicity ratio8 shall not exceed 1.0.
	Formation Oil	No discharge.9
	Base fluid retained on cuttings	For NAFs that meet the stock limitations (C16-C18 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 cuttings.10 For NAFs that meet the C12-C14 ester or C8 ester stock limitations in footnote 11 of this table, the maximum weighted mass ratio averaged over all NAF well sections shall be 9.4 g-NAF base fluid/100 g-wet drill cuttings.
Well treatment, completion, and workover fluids	Oil and grease	The maximum for any one day shall not exceed 42 mg/l; the average of daily values for 30 consecutive days shall not exceed 29 mg/l.
Deck drainage	Free oil	No discharge.4
Produced sand		No discharge.
Sanitary M10	Residual chlorine	Minimum of 1 mg/l and maintained as close to this as possible.
Sanitary M9IM	Floating solids	No discharge.
Domestic Waste	Floating solids	No discharge.
	Foam	No discharge.
	All other domestic wastes	See 33 CFR part 151.

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

² As determined by the suspended particulate phase (SPP) toxicity test. See § 435.11(gg).

³ As determined by the static sheen test. See § 435.11(hh).

⁴ As determined by the presence of a film or sheen upon or a discoloration of the surface of the receiving water (visual sheen).

⁵ PAH 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 as an appendix to subpart A of this part and in “Analytic Methods for the Oil and Gas Extraction Point Source Category,” EPA-821-R-11-004. See § 435.11(uu).

⁶ Base fluid sediment toxicity ratio = 10-day LC₅. of C₁₆-C₁₈ internal olefin/10-day LC₅. of stock base fluid as determined by EPA Method 1644: “Method for Conducting a Sediment Toxicity Test with Leptocheirus plumulosus and Non-Aqueous Drilling Fluids or Synthetic-Based Drilling Muds” after preparing the sediment according to the procedure specified in EPA Method 1646, which are published as appendices to subpart A of this part and in “Analytic Methods for the Oil and Gas Extraction Point Source Category,” EPA-821-R-11-004. See § 435.11(ee) and (uu).

⁷ Biodegradation rate ratio = Cumulative headspace gas production (ml) of C₁₆-C₁₈ internal olefin/Cumulative headspace gas production (ml) of stock base fluid, both at 275 days as determined by EPA Method 1647, which is published as an appendix to subpart A of this part and in “Analytic Methods for the Oil and Gas Extraction Point Source Category,” EPA-821-R-11-004. See § 435.11(e) and (uu).

⁸ Drilling fluid sediment toxicity ratio = 4-day LC₅. of C₁₆-C₁₈ internal olefin drilling fluid/4-day LC₅. of drilling fluid removed from drill cuttings at the solids control equipment as determined by EPA Method 1644: “Method for Conducting a Sediment Toxicity Test with Leptocheirus plumulosus and Non-Aqueous Drilling Fluids or Synthetic-Based Drilling Muds” after sediment preparation procedures specified in EPA Method 1646, which are published as appendices to subpart A of this part and in “Analytic Methods for the Oil and Gas Extraction Point Source Category,” EPA-821-R-11-004. See § 435.11(ee) and (uu).

⁹ As determined before drilling fluids are shipped offshore by the GC/MS compliance assurance method (EPA Method 1655), and as determined prior to discharge by the RPE method (EPA Method 1670) applied to drilling fluid removed from drill cuttings. If the operator wishes to confirm the results of the RPE method (EPA Method 1670), the operator may use the GC/MS compliance assurance method (EPA Method 1655). Results from the GC/MS compliance assurance method (EPA Method 1655) shall supersede the results of the RPE method (EPA Method 1670). EPA Method 1655 and 1670 are published as appendices to subpart A of this part and in “Analytic Methods for the Oil and Gas Extraction Point Source Category,” EPA-821-R-11-004. See § 435.11(uu).

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 EPA Method 1674, which is published as an appendix to subpart A of this part and in “Analytic Methods for the Oil and Gas Extraction Point Source Category,” EPA-821-R-11-004. See § 435.11(uu). 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-C₁₈ 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 EPA Method 1674, which is published as an appendix to subpart A of this part and in “Analytic Methods for the Oil and Gas Extraction Point Source Category,” EPA-821-R-11-004. See § 435.11(uu). 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 LC₅. of C₁₂-C₁₄ ester or C₈ ester/10-day LC₅. of stock base fluid as determined by EPA Method 1644: “Method for Conducting a Sediment Toxicity Test with Leptocheirus plumulosus and Non-Aqueous Drilling Fluids or Synthetic-Based Drilling Muds” after sediment preparation procedures specified in EPA Method 1646, which are published as appendices to subpart A of this part and in “Analytic Methods for the Oil and Gas Extraction Point Source Category,” EPA-821-R-11-004. See § 435.11(ee) and (uu);

(b) ester biodegradation rate ratio = Cumulative headspace gas production (ml) of C₁₂-C₁₄ ester or C₈ ester/Cumulative headspace gas production (ml) of stock base fluid, both at 275 days as determined by EPA Method 1647, which is published as an appendix to subpart A of this part and in “Analytic Methods for the Oil and Gas Extraction Point Source Category,” EPA-821-R-11-004. See § 435.11(e) and (uu); and (c) PAH mass ratio (Footnote 5), mercury, and cadmium stock limitations (C₁₆-C₁₈ 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; 77 FR 29836, May 16, 2012]