Final NPDES General Permit for Oil and Gas Exploration, Development and Production Facilities in Cook Inlet, AL (AKG285000)

[Federal Register Volume 64, Number 46 (Wednesday, March 10, 1999)]
[Notices]
[Pages 11885-11908]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 99-5667]

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ENVIRONMENTAL PROTECTION AGENCY

[FRL-6307-4]

Final NPDES General Permit for Oil and Gas Exploration,
Development and Production Facilities in Cook Inlet, AL (AKG285000)

AGENCY: Environmental Protection Agency (EPA), Region 10.

ACTION: Notice of final NPDES general permit.

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SUMMARY: The Director, Office of Water, EPA Region 10, is issuing the
National Pollutant Discharge Elimination System (NPDES) General Permit
for Cook Inlet, Alaska, pursuant to the provisions of the Clean Water
Act, 33 U.S.C. 1251 et seq. The permit authorizes discharges from
existing oil and gas exploration, development and production platforms
and shore-based facilities in Upper Cook Inlet (north of the
Forelands). The permit also authorizes future exploratory operations in
Cook Inlet north of the line between Cape Douglas on the west, and Port
Chatham on the east. All dischargers covered by this permit fall within
the Coastal and Offshore Subcategory of the Oil and Gas Extraction
Point Source Category (40 CFR part 435, subparts A and D).
Discharges authorized by this permit include drilling muds and
cuttings; produced water; deck drainage; sanitary and domestic wastes;
completion, workover, well treatment and test fluids; and miscellaneous
discharges. Discharges from facilities in the Onshore Subcategory (40
CFR Part 435, Subpart C), or to wetlands adjacent to the territorial
seas and inland coastal waters of Alaska are not authorized by this
permit. The permit does not authorize discharges from ``new sources,''
as defined in 40 CFR 122.2.
The existing permit was published in the Federal Register at 51 FR
35460 on October 3, 1986, and authorized discharges from oil and gas
facilities in Upper Cook Inlet, and from oil and gas exploration wells
in federal waters offered for lease by the U.S. Department of the
Interior's Minerals Management Service (MMS) in Federal Lease Sales 55
(Gulf of Alaska) and 60 (Cook Inlet) in state waters offered for lease
by the State of Alaska in Lease Sales 32, 33, 35, 40, 46A, and 49. The
permit issued in 1986 also covered areas offered under state lease
sales held during the effective period of the permit. The area of
coverage for the permit issued today is not linked to lease sale areas,
and covers all state and federal waters in Cook Inlet north of the line
between Cape Douglas on the west and Port Chatham on the east.
A total of 23 facilities were covered under the 1986 general
permit. Of those 23 facilities, 18 are currently active. All of those
permittees have complied with the reissuance application procedures and
indicated preference to be covered under this general permit.

FOR FURTHER INFORMATION CONTACT: Ms. Laurie Mann, EPA Region 10, 1200
Sixth Avenue, Seattle, Washington 98101, Telephone: (206) 553-1583, or
via e-mail to the following address: mann.laurie@epamail.epa.gov.

SUPPLEMENTARY INFORMATION:

Public Comment

Pursuant to section 402 of the Clean Water Act (CWA), 33 U.S.C.
1342, EPA proposed and solicited comments on NPDES general permit
AKG285000 at 60 FR 48796 (September 20, 1995). The public comment
period was scheduled to close November 30, 1995, but was extended to
January 29, 1996 at 60 FR 6155 (November 30, 1995). Public hearings
were held in Anchorage on November 28, 1995, Soldotna on November 29,
1995, and Homer on January 25, 1996.
EPA Region 10 received over 350 letters, petitions and verbal
comments from tribal, federal and state governments, companies, non-
profit organizations, and individuals. All comments specifically
addressing the draft Cook Inlet permit which were submitted during the
public comment period were considered during finalization of the
permit. Changes have been made from draft permit to the final permit in
response to public and governmental comment. All comments, along with
the EPA's responses, are summarized in the Response to Comments, which
may be obtained from Laurie Mann at the above address, or may be
obtained from the EPA Region 10 web site at www.epa.gov/r10earth/
offices/water/ow.htm.

Other Legal Requirements

Ocean Discharge Criteria Evaluation

EPA Region 10 has determined that discharges occurring under the
proposed permit are in compliance with section 403 of the Clean Water
Act. These discharges will not cause unreasonable degradation as long
as the depth-related conditions, discharge restrictions, and
environmental monitoring requirements in the permit are met. For
example, all discharges are prohibited within the boundaries, or within
1,000 meters of a coastal marsh, river delta, river mouth, and
designated Critical Habitat Areas, Areas of Special Attention, National
Park, State Game Refuges, and State Game Sanctuaries. The permit also
prohibits discharges in Kamishak Bay, Chinitna Bay, and Tuxedni Bay.

Coastal Zone Management Act

The State of Alaska, Office of Management and Budget, Division of
Governmental Coordination found this action to be consistent with the
approved Alaska Coastal Zone Management Program.

Endangered Species Act

EPA has determined that issuance of the Cook Inlet General Permit
will not

[[Page 11886]]

adversely affect any listed, threatened, or endangered species or
designated habitat, and National Marine Fisheries Service (NMFS) and
U.S. Fish and Wildlife provided written concurrence with EPA's
determination on the proposed NPDES General Permit.

State Water Quality Standards and State Certification

The State of Alaska, Department of Environmental Conservation, has
issued a Certificate of Reasonable Assurance that the subject
discharges comply with the Alaska State Water Quality Standards. The
EPA has considered Alaska's antidegradation policy (18 Alaska
Administrative Code (AAC 70.101(c)). The reissuance of this permit will
not result in additional pollutant loading to the receiving water;
therefore this action complies with the State's antidegradation policy.

Executive Order 12866

EPA has determined that this general permit is not a ``significant
regulatory action'' under the terms of Executive Order 12866 and is
therefore not subject to OMB review.

Paperwork Reduction Act

The information collection requirements of this permit were
previously approved by the Office of Management and Budget (OMB) under
the provisions of the Paperwork Reduction Act, 44 U.S.C. 3501 et seq.,
and assigned OMB control numbers 2040-0086 (NPDES permit application)
and 2040-0004 (discharge monitoring reports).

Regulatory Flexibility Act

The Regulatory Flexibility Act (RFA), 5 U.S.C. 601 et seq.,
requires that EPA prepare a regulatory flexibility analysis for rules
subject to the requirements of 5 U.S.C. 553(b) that have a significant
impact on a substantial number of small entities. The permit issued
today, however, is not a ``rule'' subject to the requirements of 5
U.S.C. 553(b) and is therefore not subject to the Regulatory
Flexibility Act.

Unfunded Mandates Reform Act

Section 201 of the Unfunded Mandates Reform Act (UMRA), Public Law
104-4, generally requires Federal agencies to assess the effects of
their ``regulatory actions'' (defined to be the same as ``rules''
subject to the RFA) on tribal, state, and local governments and the
private sector. The permit issued today, however, is not a ``rule''
subject to the RFA and is therefore not subject to the requirements of
UMRA.

Appeal of Permit

Any interested person may appeal the Cook Inlet General NPDES in
the Federal Court of Appeals in accordance with Section 509(b)(1) of
the Clean Water Act. This appeal must be filed within 120 days of
permit issuance. The date of permit issuance is defined at 40 CFR 23.2
to be at 1:00 PM eastern time, two weeks after the date of publication
in the Federal Register.

Authorization To Discharge Under the National Pollutant Discharge
Elimination System for Oil and Gas Exploration, Development and
Production

In compliance with the provisions of the Clean Water Act, 33 U.S.C.
1251 et seq., the ``Act'', the following discharges are authorized in
accordance with this National Pollutant Discharge Elimination System
(``NPDES'').

------------------------------------------------------------------------
Discharge
Discharge No.
------------------------------------------------------------------------
Drilling Mud & Cuttings.................................... 01
Deck Drainage.............................................. 02
Sanitary Wastes............................................ 03
Domestic Wastes............................................ 04
Desalination Unit Wastes................................... 05
Blowout Preventer Fluid.................................... 06
Boiler Blowdown............................................ 007
Fire Control System Test Water............................. 008
Non-Contact Cooling Water.................................. 009
Uncontaminated Ballast Water............................... 010
Bilge Water................................................ 011
Excess Cement Slurry....................................... 012
Mud, Cuttings, Cement at Seafloor.......................... 013
Waterflooding Discharges................................... 014
Produced Water............................................. 015
Completion Fluids.......................................... 016
Workover Fluids............................................ 017
Well Treatment Fluids...................................... 018
Test Fluids................................................ 019
------------------------------------------------------------------------

from oil and gas development and production facilities to state waters
north of the Forelands in Upper Cook Inlet, and from exploratory
facilities to all state and federal waters in Cook Inlet north of the
line between Cape Douglas (at 58 deg.51' North, 153 deg. 15' West) on
the west and Port Chatham (at 59 deg.13' North, 151 deg. 47' West) on
the east (Figure 1). These development and production facilities are
classified in the Coastal Subcategory of the Oil and Gas Extraction
Point Source Category, as defined in 40 CFR Part 435, Subpart D.
Exploratory facilities are classified in the Offshore and Coastal
Subcategories as defined in 40 CFR Part 435, Subparts A and D.
Discharges must be in accordance with effluent limitations, monitoring
and reporting requirements, and other conditions set forth in Parts I
through VII herein.
Permittees who are not granted coverage under this general permit
as described in Part I are not authorized to discharge to the specified
waters unless an individual permit has been issued to the Permittee by
EPA, Region 10. Discharges from facilities in the Onshore Subcategory
(40 CFR Part 435, Subpart C), or to wetlands adjacent to the
territorial seas and inland coastal waters of the State of Alaska, are
not authorized under this permit.
During the effective period of this permit, operators authorized to
discharge under the general permit are authorized to discharge the
enumerated pollutants subject to the restrictions set forth herein.
This permit does not authorize the discharge of any waste streams,
including spills and other unintentional or non-routine discharges of
pollutants, that are not part of the normal operation of the facility,
or any pollutants that are not ordinarily present in such waste
streams.
The facilities listed below are authorized to discharge under this
permit. The conditions of the previous permit become null and void upon
the effective date of this permit.

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Operator Facility NPDES Permit No.
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Unocal......................... Granite Point Production Facility.......... AKG285001.
Unocal......................... Trading Bay Treatment Facility............. AKG285002.
Cross Timbers.................. East Foreland Treatment Facility........... AKG285003.
Unocal......................... Platform Anna.............................. AKG285004.
Unocal......................... Platform Baker............................. AKG285005.
Unocal......................... Platform Bruce............................. AKG285006.
Unocal......................... Platform Dillon............................ AKG285007.
Unocal......................... King Salmon Platform....................... AKG285008,
Unocal......................... Dolly Varden Platform...................... AKG285009.

[[Page 11887]]

Marathon....................... Spark Platform............................. AKG285010.
Phillips....................... Platform A (Tyonek Platform)............... AKG285011.
Cross Timbers.................. Platform A................................. AKG285012.
Cross Timbers.................. Platform C................................. AKG285013.
Marathon....................... Spurr Platform............................. AKG285014.
Unocal......................... Granite Point Platform..................... AKG285015.
Unocal......................... Grayling Platform.......................... AKG285016.
Unocal......................... Monopod Platform........................... AKG285017.
ARCO........................... Fire Island (Exploratory Well)............. AKG285018-INACTIVE.
Unocal......................... Steelhead Platform......................... AKG285019.
Marathon....................... Steelhead (Blowout Relief Well)............ AKG285020-INACTIVE.
ARCO........................... Sturgeon (Exploratory Well)................ AKG285021-INACTIVE.
ARCO........................... Sunfish (Exploratory Well)................. AKG285022-INACTIVE.
ARCO........................... North Forelands (Exploratory Well)......... AKG285023-INACTIVE.
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This permit may be modified or revoked at any time if, on the basis
of any new data, the Director determines that this information would
have justified the application of different permit conditions at the
time of issuance. Permit modification or revocation will be conducted
in accordance with 40 CFR, Secs. 122.62, 122.63, and 122.64. In
addition to any other grounds specified herein, this permit shall be
modified or revoked at any time if, on the basis of any new data, the
Director determines that continued discharges may cause unreasonable
degradation of the marine environment.
This permit does not authorize discharges from ``new sources'' as
defined in 40 CFR 122.2.
This permit shall become effective on April 1, 1999.
This permit and the authorization to discharge shall expire at
midnight on April 1, 2004.

Signed this 25th day of February, 1999.
Randall F. Smith,
Director, Office of Water, U.S. Environmental Protection Agency, Region
10.

Table of Contents

I. Notification Requirements
A. New Exploration Facilities
B. New Discharges of Produced Water
C. Existing Facilities
D. All Facilities Covered by the Permit
E. Changes from Coverage under General Permit to Coverage under
Individual Permit
II. Prohibited Areas of Discharge and Depth-Related Requirements
A. 10 Meter Isobath
B. 5 Meter Isobath
C. Geographic Restrictions
III. Effluent Limitations and Monitoring Requirements
A. Representative Sampling (Routine and Non-Routine Discharges)
B. Drilling Mud, Drill Cuttings (Discharge 001)
C. Deck Drainage (Discharge 002)
D. Sanitary Wastes and Domestic Wastes (Discharges 003, 004)
E. Miscellaneous Discharges (Discharges 005-014)
F. Produced Water (Discharge 015)
G. Completion Fluids, Workover Fluids, Well Treatment Fluids,
and Test Fluids (Discharges 016-019)
H. Other Discharge Limitations
I. Best Management Practices Plan Requirement
IV. Recording and Reporting Requirements
A. Reporting of Monitoring Results
B. Annual Biocide Report
C. Annual Chemical Inventory and TAH/TAqH Report Requirements
D. Additional Monitoring by Permittee
E. Records Contents
F. Retention of Records
G. Twenty-four Hour Notice of Noncompliance Reporting
H. Other Noncompliance Reporting
I. Changes in Discharge of Toxic Substances
V. Compliance Responsibilities
A. Duty to Comply
B. Penalties for Violations of Permit Conditions
C. Need to Halt or Reduce Activity not a Defense
D. Duty to Mitigate
E. Proper Operation and Maintenance
F. Removed Substances
G. Bypass of Treatment Facilities
H. Upset Conditions
I. Toxic Pollutants
J. Planned Changes
K. Anticipated Noncompliance
VI. General Provisions
A. Permit Actions
B. Duty to Provide Information
C. Other Information
D. Signatory Requirements
E. Availability of Reports
F. Inspection and Entry
G. Oil and Hazardous Substance Liability
H. Property Rights
I. Severability
J. Transfers
K. State Laws
L. Reopener Clause
VII. Definitions
Figure 1. Area of Coverage: Cook Inlet Permit AKG285000

I. Notification Requirements

A. New Exploration Facilities

1. Requests To be Covered by General Permit
Written request to be covered by this permit must be provided to
EPA at least 60 days prior to initiation of discharges. The request
must include the following information:
a. Name and address of the Permittee.
b. General location (lease and block numbers) of operations and
discharges.
c. Any discharge or operating conditions subject to special
monitoring requirements (Part III.B.3.).
2. Authorization To Discharge
The Permittee is not authorized to discharge without written
notification from EPA that operations at the discharge site have been
assigned an NPDES permit number under this general permit. A permit
number cannot be assigned until the following information is received.
This information must be provided to EPA at least 30 days prior to
initiation of discharges.
a. Name and location of discharge site, including lease block
number and latitude and longitude.
b. Range of water depths (below mean lower low water) in the lease
block(s), and the depth(s) of discharge(s).
c. Initial date(s) and expected duration of operations.
3. Commencement of Discharges
The Permittee must notify EPA during the 7-day period prior to
initiation of discharges from the platform. The notification must
include the exact, final latitude and longitude and water depth of the
discharge site, as well as written certification that a Best Management
Practices Plan (Part III.I.1) is complete, on site and available to the
Agency upon request. This notification may be oral or in writing; if
notification is given orally, written confirmation must follow within 7
days.

[[Page 11888]]

B. New Discharges of Produced Water

1. Eligibility
Existing facilities are eligible to obtain authorization to
discharge produced water subject to the interim produced water
limitations specified at Part III.F.1. of the permit when produced
water discharge is planned, but has not been authorized at Part I.C.2.
of this permit.
2. Requests To Be Covered by General Permit
Written request to obtain authorization to discharge produced water
subject to the interim limitations specified in Part III.F. must be
provided to EPA at least 60 days prior to initiation of discharge.
Facilities wishing to obtain such authorization within 60 days of the
final effective date of this permit need not comply with the 60-day
requirement, but must provide the request as soon as possible prior to
initiation of discharge. The request must include the following
information:
a. Description of eligibility (Part I.B.1.)
b. Name and address of the Permittee.
c. Name of facility.
d. Specific location (including latitude and longitude, and
section, range, and township) of operations and discharges.
e. Water depth at site and depth of discharge(s) with respect to
MLLW.
f. Daily produced water flow rate.
g. Date of commencing discharge and expected duration of
operations.
3. Authorization
The Permittee is not authorized to discharge produced water subject
to the interim produced water limitations without written notification
from EPA.
4. Commencement of Discharges
The Permittee must notify EPA within the 7-day period prior to
initiation of produced water discharges subject to the interim
limitations.

C. Existing Facilities

1. Discharges 001-014 and 016-019
Facilities authorized to discharge under the 1986 Cook Inlet
General NPDES permit are automatically authorized to discharge by this
general permit as of its effective date. These facilities are listed
above. These Permittees need not submit a formal request for
authorization to discharge prior to commencement of discharges under
this permit.
2. Discharge 015
The following facilities are automatically authorized to discharge
produced water by this general permit as of its effective date: Granite
Point Production Facility, Trading Bay Treatment Facility, East
Foreland Treatment Facility, Anna, Baker, Bruce, Dillon, and Platform A
(Tyonek). These Permittees need not submit a formal request for
authorization to discharge prior to commencement of discharges under
this permit.

D. All Facilities Covered by the Permit

1. Duty To Reapply and/or Notice of Intent To Continue Activity
If the Permittee wishes to discharge under the authority of this
permit after its expiration date, the Permittee must submit a notice of
intent to EPA to do so. The Notice of Intent must be submitted at least
180 days before the expiration date of this permit. An NPDES permit
application (EPA Form 3510-2C, Wastewater Discharge Information,
Consolidated Permits Program (revised February 1985)) constitutes a
complete Notice of Intent. Timely receipt by EPA of a complete Notice
of Intent will qualify the Permittee for an administrative extension of
its authorization to discharge under this permit pursuant to 5 USC
Section 558(c).
2. Termination of Discharges
The Permittee must notify EPA within 30 days following cessation of
discharges from the discharge site. The notification may be provided in
a Discharge Monitoring Report (DMR) or under separate cover.
3. Submission of Requests To Be Covered and Other Reports
Reports and notifications required herein must be submitted to the
following addresses.
All requests for coverage: Director, Water Division, US EPA, Region
10, Attn: NPDES Permits Unit, OW-130, 1200 6th Avenue, Seattle,
Washington 98101, Phone: (206) 553-1583.
All monitoring reports and notifications of non-compliance:
Director, Water Division, US EPA, Region 10, NPDES Compliance Unit, OW-
133, 1200 6th Avenue, Seattle, Washington 98101, Phone: (206) 553-1846.
For discharges to state waters only: Alaska Department of
Environmental Conservation, Attn: Watershed Management Section, 555
Cordova Street, Anchorage, AK 99501.

E. Changes From Coverage Under General Permit To Coverage Under
Individual Permit

1. The Director may require any permittee discharging under the
authority of this permit to apply for and obtain an individual NPDES
permit when any one of the following conditions exist:
a. The discharge(s), including stormwater, is a significant
contributor of pollution.
b. The Permittee is not in compliance with the conditions of this
general permit.
c. A change has occurred in the availability of the demonstrated
technology or practices for the control or abatement of pollutants
applicable to the point source.
d. Effluent limitation guidelines are promulgated for point sources
covered by this permit.
e. The point sources covered by this permit no longer:
(1) Involve the same or substantially similar types of operations,
(2) Discharge the same types of wastewaters,
(3) Require the same effluent limitations or operating conditions,
or
(4) Require the same or similar monitoring.
f. In the opinion of the Director, the discharges are more
appropriately controlled under an individual permit than under a
general NPDES permit.
2. The Director may require any permittee authorized by this permit
to apply for an individual NPDES permit only if the Permittee has been
notified in writing that an individual permit application is required.
3. Any permittee authorized by this permit may request to be
excluded from the coverage of this general permit by applying for an
individual permit. The owner or operator must submit an application
together with the reasons supporting the request to the Director no
later than 90 days after the effective date of the permit.
4. When an individual NPDES permit is issued to a permittee
otherwise subject to this general permit, the applicability of this
general permit to that owner or operator is automatically terminated on
the effective date of the individual permit.

II. Prohibited Areas of Discharge and Depth-Related Requirements

Discharges from operations in Cook Inlet are prohibited in the
cases listed below. Permit applicants should contact EPA if they are
uncertain whether or not their discharges will be located in a
prohibited area.

A. 10 Meter Isobath

New dischargers (as defined at 40 CFR 122.2) are prohibited from
discharging produced water shoreward of the 10 m isobath (as measured
from mean lower low water).

[[Page 11889]]

B. 5 Meter Isobath

The discharge of all effluents is prohibited shoreward of the 5 m
isobath (as measured from mean lower low water) including intertidal
areas.

C. Geographic Restrictions

All discharges are prohibited in the following areas:
1. Shoreward of the 5.5 m isobath adjacent to either (1) the Clam
Gulch Critical Habitat Area (Sales 32, 40, 46A, and 49) or (2) from the
Crescent River northward to a point one-half mile north of Redoubt
Point (Sales 35 and 49).
2. Within the boundaries or within 1,000 m of a coastal marsh,
river delta, river mouth, designated Area Meriting Special Attention,
State Game Refuge, State Game Sanctuary, Critical Habitat Area, or
National Park. (The seaward edge of a coastal marsh is defined as the
seaward edge of emergent wetland vegetation.)
The following Areas Meriting Special Attention (AMSA), State Game
Refuges (SGR), State Game Sanctuaries (SGS), Critical Habitat Areas
(CHA), and National Park are located in the area covered by this
permit:

Palmer Hay Flats SGR
Goose Bay SGR
Potter Point SGR
Susitna Flats SGR
McNeil River SGS
Redoubt Bay CHA
Anchorage Coastal Wildlife Refuge
Trading Bay SGR
Kalgin Island CHA
Clam Gulch CHA
Kachemak Bay CHA
Lake Clark National Park
Port Graham/Nanwalek AMSA

The legal descriptions of state specialty areas are found in Alaska
Statues Title 16, Chapter 20. The present boundaries of these state
special areas are described in ``State of Alaska Game Refuges, Critical
Habitat Areas, and Game Sanctuaries,'' Alaska Department of Fish and
Game, Habitat Division, March 1991. Further information can be obtained
from the Alaska Department of Fish and Game, Habitat Division, Regional
Supervisor, 333 Raspberry Road, Anchorage, Alaska 99518-1599; phone
(907) 267-2284 or (907) 267-2342.
3. In Kamishak Bay west of line from Cape Douglas to Chinitna
point.
4. In Chinitna Bay inside of the line between the points on the
shoreline at latitude 59 deg.52'45'' N, longitude 152 deg.48'18'' W on
the north and latitude 59 deg.46'12'' N, longitude 153 deg.00'24'' W on
the south (Figure 1).
5. In Tuxedni Bay inside of the lines on either side of Chisik
Island (Figure 1).
a. From latitude 60 deg.04'06'' North, longitude 152 deg.34'12''
West on the mainland to the southern tip of Chisik Island (latitude
60 deg.05'45'' North, longitude 152 deg.33'30'' West).
b. From the point on the mainland at latitude 60 deg.13'45'' North,
longitude 152 deg.32'42'' West to the point on the north side of Snug
Harbor on Chisik Island (latitude 60 deg.06'36'' North, longitude
152 deg.32'54'' West).

III. Effluent Limitations and Monitoring Requirements

The operators must limit discharges as specified in the permit
below. All figures represent maximum effluent limits unless otherwise
indicated. The Permittee must comply with the following effluent limits
at all times unless provided for by this permit (e.g., unanticipated
bypass) regardless of the frequency of monitoring or reporting required
by other provisions of this permit.

A. Representative Sampling (Routine and Non-Routine Discharges)

1. The operators must collect all effluent samples from the
effluent stream prior to discharge into the receiving waters. Samples
and measurements must be representative of the volume and nature of the
monitored discharge.
2. In order to ensure that the effluent limits set forth in this
permit are not violated at times other than when routine samples are
taken, the operators must collect additional samples at the appropriate
outfall(s), and analyze them for the parameters appropriate to that
waste stream, limited in Parts III.B.-III.I. of this permit, whenever
any discharge occurs that may reasonably be expected to cause or
contribute to a violation that is unlikely to be detected by a routine
sample.
3. The Permittee must collect such additional samples as soon as
possible after the spill or discharge. The samples must be analyzed in
accordance with the monitoring requirements in Parts III.B.-III.I. of
this permit. In the event of an anticipated bypass, as defined in Part
V.G. of this permit, the Permittee must collect and analyze additional
samples as soon as the bypassed effluent reaches the outfall. The
Permittee must report all additional monitoring in accordance with Part
IV.D.

B. Drilling Mud, Drill Cuttings (Discharge 001)

1. Effluent Limitations
In addition to the restrictions set out in Parts III.A., III.B.2-3.
and IV, the Permittee must comply with the following effluent
limitations and monitoring requirements.

----------------------------------------------------------------------------------------------------------------
Monitoring requirements
Discharge ---------------------------------------------------------------
Effluent characteristic limitation Sample type/
Measurement frequency method Reported values
----------------------------------------------------------------------------------------------------------------
Flow Rate ¹ (Water Depth):
>40 m..................... 1,000 bbl/hr.... Continuous during Estimate........ Maximum hourly rate.
>20-40 m.................. 750 bbl/hr...... discharge.
5-20 m.................... 500 bbl/hr......
<5 m...................... No discharge....
Total volume.................. See note ²...... Daily................ Estimate........ Monthly total.
Toxicity of drilling mud...... 30,000 ppm SPP Monthly & End-of-Well Grab/Drilling Part III.B.2.e.
minimum. Fluids Toxicity
Test.
Free oil...................... No discharge.... Daily & before bulk Grab/Static Number of days sheen
discharges. Sheen Test Part observed.
III.B.2.d.
Oil-based fluids, Synthetic No discharge.... N/A.................. N/A............. N/A.
based fluids, Enhanced
Mineral Oil-based fluids.
Diesel oil.................... No discharge.... End-of-well, and at Grab/GC Part Presence or absence.
failure of static III.B.2.c.
sheen.
Metals........................ N/A............. Once per mud system.. Part III.B.2.f.. Part III.B.2.f.

[[Page 11890]]

Mercury & cadmium in barite... 1 mg/kg Hg...... Once per well........ Part III.B.2.g.. mg/kg dry wt.
3 mg/kg Cd
----------------------------------------------------------------------------------------------------------------
¹ Maximum flow rate of total muds and cuttings includes predilutant water; water depths are measured from mean
lower low water.
² Report total volumes for all types of operations (exploratory, production and development). For exploratory
operations, drilling discharges are limited to no more than five wells at a single drilling site. If a step-
out or sidetracked well is drilled from a previously drilled hole, the step-out well is counted as new well.
Dual lateral, which involve drilling a primary well bore and kicking off a second leg, are considered to be
one well. Requests to discharge from more than five wells per site will be considered by the Water Division
Director on a case-by-case basis.

a. Mineral oil pills. The discharge of residual amounts of mineral
oil pills (mineral oil plus additives) is authorized by the permit
provided that the mineral oil pill and at least a 50 bbl buffer of
drilling fluid on either side of the pill are removed from the
circulating drilling fluid system and not discharged to waters of the
United States. If more than one pill is applied to a single well, the
previous pill and buffer must be removed prior to application of a
subsequent pill.
(2) Residual mineral oil concentration in the discharged mud must
not exceed 2% volume/volume (API Recommended Practice 13-1, 1990) (see
Part III.B.2.c.). If drilling mud containing residual mineral oil pill
(after pill and buffer removal) is discharged, the following
information must be reported within 60 days of the discharge:
(a) Dates of pill application, recovery, and discharge;
(b) Results of the Drilling Fluids Toxicity Test on samples of the
mud before each pill is added and after removal of each pill and buffer
(taken when residual mineral oil pill concentration is expected to
greatest);
(c) Name of spotting compound and mineral oil product used;
(d) Volumes of spotting compound, mineral oil, water, and barite in
the pill;
(e) Total volume of mud circulating prior to pill application,
volume of pill formulated, and volume of pill circulated;
(f) Volume of pill recovered, volume of mud buffer recovered, and
volume of mud circulating after pill and buffer recovery;
(g) Percent recovery of the pill (include calculations);
(h) Estimated concentrations of residual spotting compound and
mineral oil in the sample of mud discharged, as determined from amounts
added and total mud volume circulating prior to pill application;
(i) Measured oil content of the mud samples, as determined by the
API retort method; and
(j) An itemization of other drilling fluid components and specialty
additives contained in the discharged mud with concentrations reported
in gal/bbl or lb/bbl.
2. Monitoring and Reporting Requirements
Monitoring must be conducted according to test procedures approved
under 40 CFR Part 136, unless other test procedures are specified here
or elsewhere in this permit. Representative sampling requirements are
discussed in Part III.A.
a. Chemical Inventory. For each mud system discharged, the
Permittee must maintain a precise chemical inventory of all
constituents added downhole, including all drilling mud additives used
to meet specific drilling requirements. The Permittee must maintain
these records for each mud system for a period of five years, and must
make these records available to the EPA upon request.
b. End of well reports. End of well reports contain the information
required in parts c-f below, and must be submitted within 90 days of
well completion.
c. Diesel oil. 1. Compliance with the limitation on diesel oil must
be demonstrated by gas chromatography (GC) analysis of drilling mud
collected from the mud used at the greatest well depth (``end-of-well''
sample) and of any muds or cuttings which fail the daily Static Sheen
Test (Part III.B.2.d. below). In all cases, the determination of the
presence or absence of diesel oil must be based on a comparison of the
GC spectra of the sample and of diesel oil in storage at the facility.
The method for GC analysis must be that described in ``Analysis of
Diesel Oil in Drilling Fluids and Drill Cuttings'' (CENTEC, 1985)
available from EPA, Region 10. Gas chromatography/mass spectrometry
(GC/MS) may be used if an instance should arise where the operator and
EPA determine that greater resolution of the drilling mud
``fingerprint'' is needed for a particular drilling mud sample.
2. Reporting. The results and raw data, including the spectra, from
the GC analysis must be provided to the Director by written report (1)
within 30 days of a positive result with the Static Sheen Test when a
discharge has occurred, or (2) for the end-of-well analysis, within 90
days of well completion.
d. Static Sheen Test. 1. The Permittee must perform the Static
Sheen Test on separate samples of drilling muds and cuttings, as
required in Appendix 1 to Subpart A of 40 CFR Part 435. Samples must be
collected on each day of discharge and prior to bulk discharges.
2. The test must be conducted in accordance with ``Approved
Methodology: Laboratory Sheen Tests for the Offshore Subcategory, Oil
and Gas Extraction Industry'' which is Appendix 1 to Subpart A of 40
CFR Part 435. For discharge below ice or during periods of unstable or
broken ice, water temperature for the Static Sheen Test must
approximate surface water temperatures at ice breakup.
3. Whenever muds or cuttings fail the Static Sheen Test and a
discharge has occurred in the past 24 hours, the Permittee is required
to analyze an undiluted sample of the material which failed the test to
determine the presence or absence of diesel oil. The determination and
reporting of results must be performed according to Part III.B.2.c.
above.
e. Toxicity test for drilling fluids. 1. If no mineral oil is used
(Part III.B.1.a.), a toxicity test must be conducted monthly to
determine compliance with the drilling fluid toxicity limit. At the
end-of-well, a sample must be collected for toxicity testing. This
sample can also serve as the monthly monitoring sample.
2. The Permittee must complete a minimum of two toxicity tests on
each mud system where a mineral oil lubricity or spotting agent is
used. One sample must be collected before applying the pill and one
after removing the pill (see Part III.B.1.a.(2)). The ``after pill''
sample test results can be used as the monthly monitoring sample. If
the well is completed within 96 hours of collection of the ``after
pill'' drilling mud sample, then these test results can also serve as
the end-of-well test.
3. The testing and reporting of drilling fluid toxicity test
results must be in accordance with Appendix 2 to Subpart A of 40 CFR
Part 435 (Drilling Fluids

[[Page 11891]]

Toxicity Test) using either the full or partial toxicity test. If the
partial toxicity test shows a failure, however, all testing of future
samples from that well shall be conducted using the full toxicity test
method to determine the 96-hour LC50. Results of drilling fluid
toxicity tests (in terms of pass/fail or 96-hr LC50 value) must be
reported on the DMRs, and complete copies of the test reports must be
attached to the DMR.
f. Metals analysis. 1. The Permittee shall analyze each discharged
mud system for the following metals: barium, cadmium, chromium, copper,
mercury, zinc, and lead. Analyses for total recoverable concentrations
shall be conducted and reported for each metal utilizing the methods
specified in 40 CFR Part 136. The results shall be reported in ``mg/kg
of whole mud (dry weight)'' and the moisture content (percent by
weight) of the original drilling mud sample shall be reported.
2. Samples shall be collected when the residual mineral oil
concentration is at its maximum value (see Part III.B.1.a.). If no
mineral oil is used, the analysis shall be done on a drilling mud
sample collected from the mud system used at the greatest well depth.
All samples shall be collected prior to any predilution. Each drilling
mud sample shall be of sufficient size to allow for both the chemical
testing described here and toxicity testing described above in Part
III.B.2.e.
g. Mercury and cadmium content of barite. 1. The Permittee must
analyze a representative sample of stock barite once prior to drilling
each well and submit the results for total mercury and total cadmium in
the DMR upon well completion. Analyses must be conducted by absorption
spectrophotometry and results expressed as mg/kg (dry weight) of
barite.
2. If more than one well is drilled at a site, new analyses are not
required for subsequent wells if no new supplies of barite have been
received since the previous analysis. In this case, the DMR should
state that no new barite was received since the last reported analysis.
Operators may provide certification, as documented by the supplier(s),
that the barite meets the above limits. The concentration of mercury
and cadmium in stock barite must be reported on the DMR as documented
by the supplier.
3. Environmental Monitoring Requirements
a. Within 4000 m of sensitive areas. Monitoring of the fate and
effects of drilling muds and/or cuttings discharges are required for
new exploration facilities when the location of the discharges is
within 4000 m of an area such as a coastal marsh, river delta, river
mouth, designated AMSA, game refuge, game sanctuary, critical habitat
area, or National Park. Discharges are prohibited within 1000 m of
sensitive areas (see Part II.C.2.).
b. Environmental Monitoring Study. If monitoring is required by
Part III.B.3.a., the Permittee must submit a plan of study for
environmental monitoring to EPA for review with, or prior to,
submission of a written request for authorization to discharge (Parts
I.A. and I.B.).
c. Objectives. The objectives of the environmental monitoring must
be to:
(1) Monitor for discharge-related impacts,
(2) Determine statistically significant changes in sediment
pollutant concentrations and sediment toxicity with time and distance
from the discharge,
(3) Monitor for discharge related impacts to the benthic community,
(4) Assess whether any impacts warrant an adjustment of the
monitoring program, and
(5) Provide information for permit reissuance.
d. Requirements. The monitoring must include, but not be limited
to, relevant hydrographic, sediment hydrocarbon, and heavy metal data
from surveys conducted before and during drilling mud disposal and up
to at least one year after drilling operations cease. The monitoring
plan must address:
(1) The monitoring objectives,
(2) Appropriate null and alternate test hypotheses,
(3) A statistically valid sampling design,
(4) All monitoring procedures and methods,
(5) A quality assurance/quality control program,
(6) A detailed discussion of how data will be used to meet, test
and evaluate the monitoring objectives, and
(7) A summary of the results of previous environmental monitoring
as they apply to the proposed program plan.
e. Reporting requirements. (1) The Permittee must analyze the data
and submit a draft report within 180 days following the completion of
sample collection. The report must address the environmental monitoring
objectives by using appropriate descriptive and analytical methods to
test for and to describe any impacts of the effluent on sediment
pollutant concentrations, sediment quality, water quality and/or the
benthic community. The report must include all relevant quality
assurance/quality control (QA/QC) information, including but not
limited to instrumentation, laboratory procedures, detection limits/
precision requirements of the applied analyses, and sample collection
methodology.
(2) The EPA will review the draft report in accordance with the
environmental monitoring objectives and evaluate it for compliance with
the requirements of the permit. If revisions to the report are
required, the Permittee must complete them and submit the final report
to EPA within two months of the Director's request. The Permittee will
be required to correct, repeat and/or expand environmental monitoring
programs which have not fulfilled the requirements of the permit.
f. Modification of Monitoring Program. The monitoring program may
be modified if EPA determines that it is appropriate. The modified
program may include changes in sampling stations, sampling times, and/
or parameters.
g. Exemption. Region 10 may grant a written exemption to this
requirement if the Permittee can satisfactorily demonstrate that
information on the fate and effects of the discharge is available and/
or the discharge will not have significant impacts on the area of
biological significance. An exemption to post-drilling monitoring will
be granted if no impact was indicated during drilling. An exemption
request must be submitted to the EPA for review with, or prior to,
submission of a written request for authorization to discharge (Parts
I.A. and I.B.).

C. Deck Drainage (Discharge 002)

1. Effluent Limitations
In addition to the restrictions set out in Parts III.A., III.C.2-5.
and IV, the Permittee must comply with the following effluent
limitations and monitoring requirements.

[[Page 11892]]

Free oil...................... No discharge.... Daily, during Visual/Sheen on Number of days sheen
discharge. receiving water observed.
or Static
Sheen. \1\
Whole effluent toxicity. \2\ N/A............. Once during the first Part III.F.7.b.. TUc. \4\
year the Permittee
is covered by the
permit. \3\
----------------------------------------------------------------------------------------------------------------
\1\ If discharge occurs during broken or unstable ice conditions, or during stable ice conditions, the Static
Sheen Test must be used (see Appendix 1 to 40 CFR part 435, subpart A).
\2\ Contaminated deck drainage must be processed through an oil-water separator prior to discharge and samples
for that portion of the deck drainage collected from the separator effluent must be sampled for WET testing.
\3\ Sample must be collected during a significant rainfall or snowmelt. If discharge of deck drainage separate
from produced water is initiated after the first year of the permit, sampling must occur during the year
following the initiation of separate deck drainage discharge.
\4\ With the final report for each test, the following must also be reported: date and time of sample, the type
of sample (i.e., rainfall or snowmelt), estimate of daily flow and basis for the estimate (e.g., turbine
meters, monthly precipitation, estimated washdown).

2. Drains
Area drains for either washdown or rainfall that may be
contaminated with oil and grease must be separated from those area
drains that would not be contaminated. The contaminated deck drainage
must be processed through an oil-water separator prior to discharge and
samples for that portion of the deck drainage collected from the
separator effluent must be tested for sheen.
3. Commingled Wastestreams
If deck drainage is commingled with produced water, then this
discharge must be considered produced water for monitoring purposes
(Part III.F.). The estimated deck drainage flow rate must be reported
in the comment section of the DMR.
4. Unstaffed Facilities
Monitoring of unstaffed facilities is not required. Written
notification that a facility is no longer staffed must be provided to
EPA prior to terminating monitoring requirements.
5. Monitoring Requirements
Monitoring must be conducted according to test procedures approved
under 40 CFR 136, unless other test procedures are specified here or
elsewhere in this permit. Representative sampling requirements are
discussed in Part III.A.

D. Sanitary Wastes and Domestic Wastes (Discharges 003, 004)

1. Effluent Limitations
In addition to the restrictions set out in Parts III.A., III.D.2-3.
and IV, the Permittee must comply with the following effluent
limitations and monitoring requirements.

----------------------------------------------------------------------------------------------------------------
Monitoring requirements
Discharge ---------------------------------------------------------------
Effluent characteristic limitation Sample type/
Measurement frequency method Reported values
----------------------------------------------------------------------------------------------------------------
All Discharges (003, 004):
Flow Rate................. NA.............. Monthly.............. Estimate........ Monthly Average.
Domestic Wastes (004):
Floating solids........... No discharge.... Daily................ Observation \1\. Number of days solids
observed.
Foam...................... No discharge.... Daily................ Observation \1\. Number of days foam
observed.
Sanitary Wastes (003) All
Treatment Systems:
Fecal Coliform............ ................ Monthly for one year, Grab............ Daily Maximum Number
beginning the first of people on board.
month of permit
coverage.
Total Residual Chlorine 19 mg/l......... Monthly.............. Grab............ Daily Maximum
(TRC) mg/l. 9 mg/l Monthly average.
Sanitary Wastes (003) \2\ M10
MSD and MSD/Biological
Treatment Units:
Total Residual Chlorine... As close as Monthly.............. Grab............ Concentration in mg/
possible to, l.
but no less
than,.
(TRC)(mg/l)............... 1 mg/l
BOD \3\ (mg/l)............ 60 mg/l......... Monthly.............. Grab............ Daily Maximum.
30 mg/l......... Monthly Average.
TSS \3\ (mg/l)............ 67 mg/l......... Monthly.............. Grab............ Daily Maximum.
51 mg/l......... Monthly Average.
Sanitary Wastes(003) \2\ M9IM
MSD and MSD/Biological
Treatment Units:

[[Page 11893]]

BOD \3\ (mg/l)............ 60 mg/l......... Monthly.............. Grab............ Daily Maximum.
30 mg/l......... Monthly Average.
TSS \3\ (mg/l)............ 67 mg/l......... Monthly.............. Grab............ Daily Maximum.
51 mg/l......... Monthly Average.
Sanitary Wastes(003) \2\ M10
Biological Treatment Units:
Floating solids........... No discharge.... Daily................ Observation \1\. Number of days solids
observed.
Total Residual Chlorine... As close as Monthly.............. Grab............ Concentration in mg/
possible to, l.
but no less
than,
(TRC) (mg/l).............. 1 mg/l..........
BOD \3\ (mg/l)............ 60 mg/l......... Monthly.............. Grab............ Daily Maximum.
30 mg/l Monthly Average.
TSS ^3, ⁴ (mg/l)........... 60 mg/l......... Monthly.............. Grab............ Daily Maximum.
30 mg/l Monthly Average.
Sanitary Wastes(003) \2\ M9IM
Biological Treatment Units:
Floating solids........... No discharge.... Daily................ Observation \1\. Number of days solids
observed.
BOD \3\ (mg/l)............ 90 mg/l......... Monthly.............. Grab............ Daily Maximum.
48 mg/l Monthly Average.
TSS ^3, ⁴ (mg/l)........... 108 mg/l........ Monthly.............. Grab............ Daily maximum.
56 mg/l Monthly Average.
----------------------------------------------------------------------------------------------------------------
\1\ Permittee must monitor by observing the surface of the receiving water in the vicinity of the outfall(s)
during daylight at the time of maximum estimated discharge. For domestic waste, observations must follow
either the morning or midday meal.
\2\ In cases where sanitary and domestic wastes are mixed prior to discharge, and sampling of the sanitary waste
component stream is infeasible, the discharge may be sampled after mixing. In such cases, the discharge
limitations for sanitary wastes must apply to the mixed waste stream.
\3\ The numeric limits for BOD and TSS apply only to discharges to state waters.
\4\ The TSS limitation for biological treatment units is a net value. The net TSS value is determined by
subtracting the TSS value of the intake water from the TSS value of the effluent. Report the TSS value of the
intake water on the comment section of the DMR. For those facilities that use filtered water in the biological
treatment units, the TSS of the effluent may be reported as the net value.
Samples collected to determine the TSS value of the intake water must be taken on the same day, during the same
time period that the effluent sample is taken. Intake water samples must be taken at the point where the water
enters the facility prior to mixing with other flows. Influent samples must be taken with the same frequency
that effluent samples are taken.

2. Discharge Below Water Surface
Domestic and sanitary wastes must be discharged below the water
surface.
3. Monitoring Requirements
Monitoring must be conducted according to test procedures approved
under 40 CFR 136, unless other test procedures are specified here or
elsewhere in this permit. Representative sampling requirements are
discussed in Part II.B.
Fecal Coliform Monitoring. Permittees must submit a facility
specific mixing zone application to ADEC based on the first 12 months
monitoring data within 18 months after the effective date of the permit
(or within 18 months after commencement of discharge for new
dischargers).

E. Miscellaneous Discharges (Discharges 005-014)

1. Effluent Limitations
In addition to the restrictions set out in Parts III.A., III.E.2-4,
and IV, the discharge of desalination unit wastes (005); blowout
preventer fluid (006); boiler blowdown (007): fire control system test
water (008); non-contact cooling water (009); uncontaminated ballast
water (010); bilge water (011); excess cement slurry (012); mud,
cuttings, cement at the seafloor (013); and waterflooding (014) must
comply with the following effluent limitations and monitoring
requirements.

[[Page 11894]]

Free Oil.................. No discharge.... Once/discharge for Visual/Sheen on Number or days sheen
discharges lasting < receiving water is observed.
24 hrs. \1\.
Once/24-hrs for
discharges lasting
>24 hours
Waterflooding, Non-Contact
Cooling Water, Desalination
Wastestreams:
Chemical Inventory........ N/A............. Annual............... Part III.E.2.... Part III.E.2.
----------------------------------------------------------------------------------------------------------------
\1\ For Uncontaminated Ballast Water (010) and Bilge Water (011) only: uncontaminated ballast and bilge water
must be processed through an oil-water separator prior to discharge. If discharge of bilge water occurs during
broken, unstable, or stable ice conditions, the sample type/method used to determine compliance with the no
free oil limitation must be ``Grab Static Sheen Test'' (Appendix 1 to Subpart A of 40 CFR Part 435). For
discharges above stable ice, below ice, to unstable or broken ice, a water temperature that approximates
surface water temperatures after breakup must be used.

2. Chemical Inventory
The Permittee must maintain an inventory of the type and quantity
of chemicals (other than fresh or seawater) added to waterflooding,
non-contact cooling water and desalination systems. The inventory(ies)
must be submitted annually. The annual inventories must be assembled
for the calendar year, and must be submitted to the EPA within 90 days
of the completion of the calendar year.
3. Commingled Wastestreams
If excess waterflood water is added to the produced water
discharge in order to minimize the possibility of line freezing, then
this discharge must be considered produced water for monitoring
purposes. The estimated waterflood flow rate must be reported in the
comment section of the DMR.
4. Monitoring Requirement
Monitoring must be conducted according to test procedures approved
under 40 CFR 136, unless other test procedures are specified here or
elsewhere in this permit. Representative sampling requirements are
discussed in Part III.A.

F. Produced Water (Discharge 015)

1. Effluent Limitations
In addition to the restrictions set out in Parts III.A., III.F.2-
7., and IV, the Permittee must comply with the following effluent
limitations and monitoring requirements.

----------------------------------------------------------------------------------------------------------------
Monitoring requirements
Discharge ---------------------------------------------------------------
Effluent characteristic limitation Sample type/
Measurement frequency method Reported values
----------------------------------------------------------------------------------------------------------------
All Locations:
Flow rate (MGD)........... N/A............. Weekly............... Estimate........ Monthly Average.
Produced sands............ No discharge
pH
Flow rate <1mgd........... 6-9............. Monthly.............. Grab............ Daily Max and Min.
Flow rate >1mgd........... 6-9............. Weekly............... Grab............ Daily Max and Min.
Cadmium &................. N/A............. Monthly for one year, Grab............ Daily Max.
Mercury................... beginning the first Part III.F.7.c.
month of permit
coverage.
Individual Dischargers:
Granite Point Production
Facility:
AKG285001................. 42 mg/l daily Weekly............... Grab or average Daily Maximum.
Oil and Grease............ max. of 4 samples Monthly Average.
29 mg/l monthly taken within 24
avg hour period.
Copper................ 238 g/l Monthly.............. Grab............ Daily Maximum.
163 g/l Part III.F.7.c.. Monthly Average.
Lead.................. 543 g/l Monthly.............. Grab............ Daily Maximum.
372g/l Part III.F.7.c.. Monthly Average.
Mercury............... 2.42 g/l........ Monthly.............. Grab............ Daily Maximum.
1.66 g/ Part III.F.7.c.. Monthly Average.
l

[[Page 11895]]

Total Aromatic 63,700 g/l. Part III.F.7.a.. Monthly Average.\1\
43,700 g/l
Whole Effluent Toxicity 133 TUc......... Annual............... Grab............ Daily Maximum.
(WET). 91 TUc Parts III.F.7.b. Monthly Average.
Trading Bay:
AKG285002, Oil and Grease. 42 mg/l daily Weekly............... Grab or average Daily Maximum.
max. of 4 samples Monthly Average.
29 mg/l monthly taken within 24
avg hour period.
Copper.................... 136 g/l Weekly............... Grab............ Daily Maximum.
93.4 g/ Part III.F.7.c.. Monthly Average.
l
Lead...................... 883 g/l Weekly............... Grab............ Daily Maximum.
605 g/l Part III.F.7.c.. Monthly Average.
Total Aromatic 24,500 g/l. Part III.F.7.a.. Monthly Average.\1\
12,200 g/l
Total Aqueous Hydrocarbons 36,800 g/l. Part III.F.7.a.. Monthly Average.\1\
18,300 g/l
Whole Effluent Toxicity 140 TUc......... Quarterly............ Grab............ Daily Maximum.
(WET). 96 TUc Parts III.F.7.b. Monthly Average.
East Forelands:
AKG285003, Oil and Grease. 42 mg/l daily Weekly............... Grab or average Daily Maximum.
max. of 4 samples Monthly Average.
29 mg/l monthly taken within 24
avg hour period.
Copper.................... 122 g/l Monthly.............. Grab............ Daily Maximum.
84 g/l Part III.F.7.c.. Monthly Average.
Arsenic................... 2900 g/ Monthly.............. Grab............ Daily Maximum.
l. Part III.F.7.c.. Monthly Average.
1990 g/
l
Silver.................... 97 g/l. Monthly.............. Grab............ Daily Maximum.
66 g/l Part III.F.7.c.. Monthly Average.
Lead...................... 754 g/l Monthly.............. Grab............ Daily Maximum.
517 g/l Part III.F.7.c.. Monthly Average.
Mercury................... 3.37 g/ Monthly.............. Grab............ Daily Maximum.
l. Part III.F.7.c.. Monthly Average.
2.31 g/
l
Total Aromatic 61,800 g/l. Part III.F.7.a.. Monthly Average. \1\
42,400 g/l
Total Aqueous Hydrocarbons 92,700 g/l. Part III.F.7.a.. Monthly Average.\1\
63,500 g/l
Whole Effluent Toxicity 115............. Annual............... Grab............ Daily Maximum.
(WET). TUc 79 TUc Parts III.F.7.b. Monthly Average.
Anna:
AKG285004, Oil and Grease. 42 mg/l daily Weekly............... Grab or average Daily Maximum.
max. of 4 samples Monthly Average.
29 mg/l monthly taken within 24
avg. hour period.
Copper.................... 209 g/l Monthly.............. Grab............ Daily Maximum.
143 g/l Part III.F.7.c.. Monthly Average.
Mercury................... 8.23 g/ Monthly.............. Grab............ Daily Maximum.
l. Part III.F.7.c.. Monthly Average.
5.64 g/
l
Total Aromatic 86,000 g/l. Part III.F.7.a.. Monthly Average.
58,900 g/l
Total Aqueous Hydrocarbons 129,000 g/l. Part III.F.7.a.. Monthly Average.
88,400 g/l

[[Page 11896]]

Whole Effluent Toxicity 486 TUc......... Annual............... Grab............ Daily Maximum.
(WET). 333 TUc Parts III.F.7.b. Monthly Average.
Baker:
AKG285005, Oil and Grease. 42 mg/l daily Weekly............... Grab or average Daily Maximum.
max. of 4 samples Monthly Average.
29 mg/l monthly taken within 24
avg. hour period.
Zinc...................... 16,700 g/l. Part III.F.7.c.. Monthly Average.
5330 g/
l
Whole Effluent Toxicity 100 TUc......... Annual............... Grab............ Daily Maximum.
(WET). 72 TUc Parts III.F.7.b. Monthly Average.
Bruce:
AKG285006, Oil and Grease. 42 mg/l daily Weekly............... Grab or average Daily Maximum.
max. of 4 samples Monthly Average.
29 mg/l monthly taken within 24
avg. hour period.
Silver.................... 766 g/l Monthly.............. Grab............ Daily Maximum.
525 g/l Part III.F.7.c.. Monthly Average.
Total Aromatic 298,000 g/l. Part III.F.7.a.. Monthly Average.
205,000 g/l
Whole Effluent Toxicity 912 TUc......... Annual............... Grab............ Daily Maximum.
(WET). 625 TUc Parts III.F.7.b. Monthly Average.
Dillon:
AKG285007, Oil and Grease. 42 mg/l daily Weekly............... Grab or average Daily Maximum.
max. of 4 samples Monthly Average.
29 mg/l monthly taken within 24
avg. hour period.
Copper.................... 244 g/l Monthly.............. Grab............ Daily Maximum.
167 g/l Part III.F.7.c.. Monthly Average.
Lead...................... 1030 g/ Monthly.............. Grab............ Daily Maximum.
l. Part III.F.7.c.. Monthly Average.
706 g/l
Zinc...................... 7,980 g/ Monthly.............. Grab............ Daily Maximum.
l. Part III.F.7.c.. Monthly Average.
5,470 g/
l
Total Aromatic 59,300 g/l. Part III.F.7.a.. Monthly Average.\1\
40,600 g/l
Total Aqueous Hydrocarbons 88,900 g/l. Part III.F.7.a.. Monthly Average.\1\
61,000 g/l
Whole Effluent Toxicity 174 TUc......... Annual............... Grab............ Daily Maximum.
(WET). 119 TUc Parts III.F.7.b. Monthly Average.
Phillips A/Tyonek (gas) see
Part III.F.6:
AKG285011, Oil and Grease. 20 mg/l daily Weekly............... Grab or average Daily Maximum.
max. of 4 samples Monthly Average.
15 mg/l monthly taken within 24
avg hour period.
Arsenic................... 1240 g/ Monthly.............. Grab............ Daily Maximum.
l. Part III.F.7.c.. Monthly Average.
851 g/l
Copper.................... 58 g/l. Monthly.............. Grab............ Daily Maximum.
40 g/l Part III.F.7.c.. Monthly Average.
Lead...................... 193 g/l Monthly.............. Grab............ Daily Maximum.
132 g/l Part III.F.7.c.. Monthly Average.
Mercury................... 0.862 g/ Monthly.............. Grab............ Daily Maximum.
l. Part III.F.7.c.. Monthly Average.
0.591 g/
l
Total Aqueous Hydrocarbons 4530 g/ Monthly.............. Grab............ Daily Maximum.\1\
(TAqH). l. Part III.F.7.a.. Monthly Average.\1\
3110 g/
l
Whole Effluent Toxicity 16 TUc.......... Annual............... Grab............ Daily Maximum.
(WET). 11 TUc Parts III.F.7.b. Monthly Average.

[[Page 11897]]

Phillips A/Tyonek (crude) see
Part III.F.6:
AKG285011, Oil and Grease. 42 mg/l daily Weekly............... Grab or average Daily Maximum.
max of 4 samples Monthly Average.
29 mg/l monthly taken within 24
avg hour period.
Silver.................... 766 g/l Monthly.............. Grab............ Daily Maximum.
525 g/l Part III.F.7.c.. Monthly Average.
Mercury................... 21.9 g/ Monthly.............. Grab............ Daily Maximum.
l. Part III.F.7.c.. Monthly Average.
15.0 g/
l
Arsenic, Cadmium, Copper, N/A............. Monthly for one year. Grab............ Daily Maximum.
Lead, Nickel, Zinc. Part III.F.7.c.. Monthly Average.
Total Aromatic 298,000 g/l. Part III.F.7.a.. Monthly Average.\1\
205,000 g/l
Total Aqueous Hydrocarbons 448,000 g/l. Part III.F.7.a.. Monthly Average.\1\
307,000 g/l
Whole Effluent Toxicity 912 TUc......... Quarterly............ Grab............ Daily Maximum.
(WET). 625 TUc Parts III.F.7.b. Monthly Average.
Interim Limitations (Flow Rate
<1mgd):
Oil and Grease............ 42 mg/l daily Weekly............... Grab or average Daily Maximum.
max.. of 4 samples Monthly Average.
29 mg/l monthly taken within 24
avg. hour period.
Silver.................... 766 g/l Monthly.............. Grab............ Daily Maximum.
525 g/l Part III.F.7.c.. Monthly Average.
Mercury................... 21.9 g/ Monthly.............. Grab............ Daily Maximum.
l. Part III.F.7.c.. Monthly Average.
15.0 g/
l
Arsenic, Cadmium, Copper, N/A............. Monthly for one year. Grab............ Daily Maximum.
Lead, Nickel, Zinc. Part III.F.7.c.. Monthly Average.
Total Aromatic 298,000 g/l. Part III.F.7.a.. Monthly Average.\1\
205,000 g/l
Total Aqueous Hydrocarbons 448,000 g/l. Part III.F.7.a.. Monthly Average.\1\
307,000 g/l
Whole Effluent Toxicity 912 TUc......... Annual............... Grab............ Daily Maximum.
(WET). 625 TUc Parts III.F.7.b. Monthly Average.
Interim Limitations (Flow Rate
>1mgd):
Oil and Grease............ 42 mg/l daily Weekly............... Grab or average Daily Maximum.
max.. of 4 samples Monthly Average.
29 mg/l monthly taken within 24
avg. hour period.
Silver.................... 766 g/l Weekly............... Grab............ Daily Maximum.
382 g/l Part III.F.7.c.. Monthly Average.
Mercury................... 21.9 g/ Weekly............... Grab............ Daily Maximum.
l. Part III.F.7.c.. Monthly Average.
10.9 g/
l
Arsenic, Cadmium, Copper, N/A............. Monthly for one year. Grab............ Daily Maximum.
Lead, Nickel, Zinc. Part III.F.7.c.. Monthly Average.
Total Aromatic 298,000 g/l. Part III.F.7.a.. Monthly Average.\1\
149,000 g/l

[[Page 11898]]

Total Aqueous Hydrocarbons 448,000 g/l. Part III.F.7.a.. Monthly Average.\1\
223,000 g/l
Whole Effluent Toxicity 912 TUc......... Quarterly............ Grab............ Daily Maximum.
(WET). 625 TUc Parts III.F.7.b. Monthly Average.
----------------------------------------------------------------------------------------------------------------
\1\ Fifteen months after permit issuance, a report summarizing the concentrations of the individual TAH
components (benzene, toluene, ethylbenzene and xylene isomers) and individual TAqH components from data
collected during the first year of permit coverage must be provided to the EPA.

2. Rerouting Platform Discharge to a Shore-Based Facility
In situations where the platforms are not able to treat produced
water and a bypass may occur, the Baker and Dillon platforms may route
their produced water discharge to the Granite Point Production Facility
for treatment and discharge; the Anna and Bruce platforms may route
their produced water discharge to the East Foreland Production Facility
for treatment and discharge. The Permittee must report rerouting by
telephone or facsimile within 24 hours of rerouting, and must provide a
written submission within five days of rerouting that describes why
rerouting was necessary, and the anticipated time that rerouting is
expected to continue. The permittee must cease rerouting as soon as
possible.
3. Interim Produced Water Limitations
Facilities which obtain authorization to discharge produced water
subject to interim produced water limitations (see Part I.B.) must
submit a facility specific mixing zone application to ADEC based on the
first 12 months of monitoring data within 18 months after commencement
of discharge.
4. Trading Bay Groundwater
Trading Bay is authorized to discharge treated groundwater
extracted pursuant to State Compliance Order #91-23-01-053-02 as part
of the produced water waste stream.
5. Spill Clean-Up
Water that is collected as a result of spill clean-up can be
treated as produced water and discharged with the produced water waste
stream. The Permittee must report the treatment and discharge of spill
clean-up water to the EPA within 24 hours of initiating such treatment,
and must provide a written submission within five days of initiating
treatment that describes the spill, the anticipated volume of spill
clean-up water, and the anticipated time that treatment and discharge
of spill clean-up water is expected to continue.
6. Phillips A/Tyonek
Two sets of limits for Phillips A/Tyonek are listed at Part
III.F.1. The ``gas'' limits are effective at the time of permit
issuance, and will continue to be the effective permit limits until
Phillips A/Tyonek initiates discharge of crude related discharge
directly from the Phillips A/Tyonek platform. The Permittee must submit
a notification letter to EPA prior to initiating the discharge of crude
related produced water from the platform. The ``crude'' limits become
effective on the day identified in the notification letter. A facility
specific mixing zone application must be submitted to ADEC for Phillips
A/Tyonek based on the first 12 months monitoring data within 18 months
after commencement of crude related produced water discharges.
7. Monitoring Requirements
Monitoring must be conducted according to test procedures approved
under 40 CFR 136, unless other test procedures are specified here or
elsewhere in this permit. Representative sampling requirements are
discussed in Part III.A.
a. Total Aromatic Hydrocarbons (TAH) and Total Aqueous Hydrocarbons
(TAqH). For analysis of TAH and TAqH, all analytical requirements cited
in the Alaska Standards, 18 AAC 70.020(b) are applicable.
b. Whole effluent toxicity. (1) The Permittee must conduct tests on
grab effluent samples with one vertebrate and two invertebrate species,
as follows.
Vertebrate (survival and growth): Inland silverside, Menidia
beryllina.
Invertebrate: Atlantic myside Mysidopsis bahia (survival, growth
and fecundity test) and one of the following two bivalve species tests:
Mussel Mytilis sp. or Pacific oyster Crassostrea gigas (larval
development test ). Due to seasonal variability, testing may be
performed during reliable spawning periods (e.g. December through
February for mussels; June through August for oysters).
(2) Each year, the permittee must re-screen with the three species
listed above, and continue to monitor with the most sensitive species.
Rescreening must consist of one test conducted at a different time of
year from the previous years test.
(3) The presence of chronic toxicity must be estimated as specified
in ``USEPA Short-Term Methods for Estimating the Chronic Toxicity of
Effluents and Receiving Waters to Marine and Estuarine Organisms,
Second Edition,'' (EPA/600/4-91/003). For the bivalve species, chronic
toxicity must be estimated as specified in ``Short-Term Methods for
Estimating the Chronic Toxicity of Effluents and Receiving Water to
West Coast Marine and Estuarine Organisms'' (EPA/600/R-95/136).
(4) Results must be reported in TUc, where
TUc = 100/NOEC. The reported NOEC must be the highest NOEC
calculated for the applicable survival, growth or fecundity endpoints.
(5) A series of five dilutions and a control will be tested. The
series must include the instream waste concentration (IWC), two
dilutions above the IWC, and two dilutions below the IWC. The IWC is
the concentration of effluent at the edge of the mixing zone.
(6) In addition to those quality assurance measures specified in
the methodology, the following quality assurance procedures must be
followed:
(a) If organisms are not cultured in-house, concurrent testing with
reference toxicants must be conducted. Where organisms are cultured in-
house, monthly reference toxicant testing is sufficient.
(b) If either of the reference toxicant tests or the effluent tests
do not meet all test acceptability criteria as specified in the test
methods manual, then the permittee must re-sample and re-test as soon
as possible.
(c) Control and dilution water should be receiving water, or
salinity adjusted

[[Page 11899]]

lab water. If the dilution water used is different from the culture
water, a second control, using culture water must also be used.
(7) Accelerated Testing. (a) If chronic toxicity is detected above
the permit limits, collection and analysis of one additional sample is
required within two weeks of receipt of the test results.
(b) If chronic toxicity is not detected in the sample required by
Part III.F.7.a, the Permittee must notify the EPA and ADEC in writing
of the results within fifteen (15) days of receipt of the results, and
must discuss the cause of the exceedance, and the corrective actions
which were taken.
(c) If chronic toxicity is detected in the sample required by Part
III.F.7.a., then the Permittee must conduct four bi-weekly tests over
an eight week period. Accelerated testing must be initiated within
fifteen (15) days of the receiving the sample results required by Part
III.F.7.a.
(8) Toxicity Reduction Evaluation (TRE). (a) If chronic toxicity is
detected above the permit limits during accelerated testing, then in
accordance with EPA/600/2-88/070, a toxicity reduction evaluation (TRE)
must be initiated within fifteen days of this exceedance in order to
expeditiously locate the source(s) of toxicity and evaluate the
effectiveness of pollution control actions and/or in plant
modifications toward attaining compliance.
(b) If none of the four tests indicates toxicity, then the
permittee may return to the normal testing frequency.
(9) Toxicity Identification Evaluation (TIE). (a) If chronic
toxicity is detected in any two of the four bi-weekly tests, the
permittee must initiate a TIE to identify the specific chemical(s)
responsible for toxicity (EPA/600/6-91/005F (Phase I), EPA/600/R-92/080
(Phase II), and EPA-600/R-92/081 (Phase III).
(b) If a TIE is triggered prior to completion of the accelerated
testing, the accelerated testing schedule may be terminated, or used as
necessary in performing the TIE.
(10) Reporting. (a) The permittee must notify EPA and the State in
writing within fifteen (15) days of receipt of the results of the
exceedance of the permit limit, of the finding of the TRE/TIE or other
investigation to identify the cause(s) of toxicity; actions the
permittee has taken or will take to mitigate the impact of the
discharge, to correct the noncompliance and to prevent the recurrence
of toxicity; where corrective actions including a TRE/TIE have not been
completed, an expeditious schedule under which corrective actions will
be implemented; and if no actions have been taken, the reason for not
taking action.
c. Metals. The method detection limits and interim minimum level
listed below are needed in order to determine whether or not violations
of water quality are occurring at the point of discharge. In addition
to the procedures approved under 40 CFR 136, the ICP-MS test procedure
200.8 (``Methods for Chemical Analyses of Water and Wastes,'' EPA-600/
4-79-020) may be used for analysis of these samples.

------------------------------------------------------------------------
Aquatic life Method Interim
chronic detection minimum
Pollutant criteria limit level
(g/ (g/ (g/
l) l) l)
------------------------------------------------------------------------
Arsenic....................... 36 7.2 N/A
Cadmium....................... 9.3 1.9 N/A
Copper........................ 2.9 0.6 N/A
Lead.......................... 5.6 1.1 N/A
Nickel........................ 7.1 1.4 N/A
Silver........................ 2.3 0.5 N/A
Mercury....................... 0.025 0.2 0.5
Zinc.......................... 58 12 N/A
------------------------------------------------------------------------

G. Completion Fluids, Workover Fluids, Well Treatment Fluids, and Test
Fluids (Discharges 016-019)

1. Effluent Limitations
In addition to the restrictions set out in Parts III.A., III.G.2-
4., and IV, the Permittee must comply with the following effluent
limitations and monitoring requirements.

--------------------------------------------------------------------------------------------------------------------------------------------------------
Monitoring requirements
Effluent characteristic Discharge ------------------------------------------------------------------------------------------------------
limitation Measurement frequency Sample type/ method Reported values
--------------------------------------------------------------------------------------------------------------------------------------------------------
All Wastestreams:
Discharge frequency....... N/A.............. Once/discharge \1\.... Count................ Type and total number of discharges.
Flow rate (MGD)........... N/A.............. Daily \1\............. Estimate............. Monthly average.
Oil-based fluids.......... No discharge..... Included in free oil
monitoring, below \2\.
Free oil \3\.............. No free oil...... Once per discharge \1\ Grab/Static Sheen Number of times sheen observed.
Test.
Oil and grease \3\........ 42 mg/l max. Once per discharge \1\ Grab or average of 4 Daily max. and monthly average.
daily. samples taken within
29 mg/l monthly 24 hours.
avg
pH............................ 6.5-8.5.......... Once per discharge \1\ Grab................. pH.

[[Page 11900]]

Treatment, Workover, ................. Once per discharge \1\ Part III.G.4.........
Completion Metals.
--------------------------------------------------------------------------------------------------------------------------------------------------------
\1\ The type of discharge (i.e., completion, workover, treatment, test fluid, or any combination) must be reported. Discharge of individual wastestreams
must be reported separately from the discharge of commingled wastestreams.
\2\ Discharge of oil-based fluids is prohibited.
\3\ No free oil and oil and grease limits apply to each discharge, whether these wastestreams are discharged individually or are commingled. All fluids
must be processed through an oil-water separator prior to discharge. Samples must be collected after the final step of treatment.

2. Commingled Wastestreams
If workover, completion, well treatment or test fluids are mixed
with produced water, then this discharge must be considered produced
water for monitoring purposes (Part III.F.). The estimated flow rate of
workover, completion, well treatment or test fluids must be reported in
the comment section of the DMR.
3. Chemical Inventory
The Permittee must maintain an inventory of the type and quantity
of chemicals (other than fresh or seawater) added to completion,
workover, well treatment, and test fluids. The inventory(ies) must be
submitted annually. The annual inventories must be assembled for the
calendar year, and must be submitted to the EPA within 90 days of the
completion of the calendar year.
4. Monitoring Requirements
Monitoring must be conducted according to test procedures approved
under 40 CFR 136, unless other test procedures are specified here or
elsewhere in this permit. Representative sampling requirements are
discussed in Part III.A.
Metals. For each discharge of well treatment, completion or
workover fluids which is characterized as an acid job (strong or weak,
including but not limited to hydrochloric or hydrofluoric acid, EDTA),
samples of effluent must be taken for analyses of the following:
cadmium, chromium, copper, lead, nickel and zinc. Analyses for total
recoverable concentrations must be conducted and reported for each
metal.

H. Other Discharge Limitations

1. Floating Solids, Visible Foam, or Oily Wastes
There must be no discharge of floating solids or visible foam in
other than trace amounts, nor of oily wastes which produce a sheen on
the surface of the receiving water.
2. Surfactants, Dispersants, and Detergents
The discharge of surfactants, dispersants, and detergents must be
minimized except as necessary to comply with the safety requirements of
the Occupational Health and Safety Administration and the Minerals
Management Service. The discharge of dispersants to marine waters in
response to oil or other hazardous spills is not authorized by this
permit.
3. Applicable Marine Water Quality Criteria
There must be no discharge of any constituent in concentrations
which results in an exceedence of applicable marine water quality
criteria at the edge of any permitted mixing zone.
4. Other Toxic and Non-conventional Compounds
There must be no discharge of diesel oil, halogenated phenol
compounds, trisodium nitrilotriacetic acid, sodium chromate or sodium
dichromate.

I. Best Management Practices Plan Requirement.

1. Development
The Permittee must develop a Best Management Practices (BMP) Plan
which achieves the objectives and the specific requirements listed
below.
The Permittee must certify that its BMP Plan is complete, on-site,
and available upon request to EPA . This certification must identify
the NPDES permit number and be signed by an authorized representative
of the Permittee. For new exploratory operations, the certification
must be submitted no later than the written notice of intent to
commence discharge (Part I.A.3). For existing dischargers, the
certification must be submitted within one year of permit issuance.
2. Purpose
The BMP Plan must be designed to prevent or minimize the generation
and the potential for the release of pollutants from the facility to
the waters of the United States through normal operations and ancillary
activities.
3. Objectives
The Permittee must develop and amend the BMP Plan consistent with
the following objectives for the control of pollutants.
a. The number and quantity of pollutants and the toxicity of
effluent generated, discharged or potentially discharged at the
facility must be minimized by the Permittee to the extent feasible by
managing each influent waste stream in the most appropriate manner.
b. The Permittee must establish specific objectives for the control
of pollutants by conducting the following evaluations.
(1) Each facility component or system must be examined for its
waste minimization opportunities and its potential for causing a
release of significant amounts of pollutants to waters of the United
States due to equipment failure, improper operation, natural phenomena
such as rain or snowfall, etc.
(2) Where experience indicates a reasonable potential for equipment
failure (e.g., a tank overflow or leakage), natural condition (e.g.,
precipitation), or other circumstances to result in significant amounts
of pollutants reaching surface waters, the program should include a
prediction of the direction, rate of flow and total quantity of
pollutants which could be discharged from the facility as a result of
each condition or circumstance.
4. Requirements
The BMP Plan must be consistent with the objectives in Part 3 above
and the general guidance contained in the publication entitled
``Guidance Document for Developing Best Management Practices (BMP)''
(EPA 833-B-93-004, U.S. EPA, 1993) or any subsequent revisions to the
guidance document. The BMP Plan must:
a. Be documented in narrative form, and must include any necessary
plot plans, drawings or maps, and must be

[[Page 11901]]

developed in accordance with good engineering practices. At a minimum,
the BMP Plan must contain the planning, development and implementation,
and evaluation/reevaluation components discussed in ``Guidance Document
for Developing Best Management Practices (BMP)'' (EPA 833-B-93-004,
U.S. EPA, 1993) or any subsequent revisions to the guidance document.
b. Include the following provisions concerning BMP Plan review:
(1) Be reviewed by plant engineering staff and the plant manager as
warranted by changes in the operation or at the facility which are
covered by the BMP.
(2) Be reviewed and endorsed by the individuals responsible for
development and implementation of the BMP plan.
(3) Include a statement that the above reviews have been completed
and that the BMP Plan fulfills the requirements set forth in this
permit. The statement must be certified by the dated signatures of the
individuals responsible for development and implementation of the BMP
Plan.
c. Establish specific best management practices to meet the
objectives identified in Part 3 of this section, addressing each
component or system capable of generating or causing a release of
significant amounts of pollutants, and identifying specific
preventative or remedial measures to be implemented.
5. Documentation
The Permittee must maintain a copy of the BMP Plan at the facility
and must make the plan available to EPA upon request.
6. BMP Plan Modification
The Permittee must amend the BMP Plan whenever there is a change in
the facility or in the operation of the facility which materially
increases the generation of pollutants or their release or potential
release to the receiving waters. The Permittee must also amend the
Plan, as appropriate, when plant operations covered by the BMP Plan
change. Any such changes to the BMP Plan must be consistent with the
objectives and specific requirements listed above. All changes in the
BMP Plan must be reviewed by the plant engineering staff and plant
manager.
7. Modification for Ineffectiveness
At any time, if the BMP Plan proves to be ineffective in achieving
the general objective of preventing and minimizing the generation of
pollutants and their release and potential release to the receiving
waters and/or the specific requirements above, the permit and/or the
BMP Plan must be subject to modification to incorporate revised BMP
requirements.

IV. Recording and Reporting Requirements

A. Reporting of Monitoring Results

The Permittee must summarize monitoring results each month on the
Discharge Monitoring Report (DMR) form (EPA No. 3320-1). The Permittee
must submit reports monthly, postmarked by the 20th day of the
following month. Quarterly sampling results must be reported on, or
before the March, June, September, and December DMRs. The Permittee
must sign and certify all DMRs, and all other reports, in accordance
with the requirements of Part VI.D. of this permit (``Signatory
Requirements'').
The Permittee must submit the legible originals of these documents
to the Director, Water Division, with copies to ADEC, at the following
addresses:

United States Environmental Protection Agency, Region 10, 1200 Sixth
Avenue, OW-133, Seattle, Washington 98101
Alaska Department of Environmental Conservation, Attn: Watershed
Management Section, 555 Cordova Street, Anchorage, Alaska 99501

B. Annual Biocide Report

The Permittee must maintain an inventory of the type and volume of
all biocides added to any waste streams authorized for discharge under
this permit. Each annual inventory must be assembled for the calendar
year, and must be submitted to the EPA within 90 days of the completion
of the calendar year.

C. Annual Chemical Inventory and TAH/TAqH Report Requirements

See chemical inventory requirements at Part III.E.2. and III.G.3,
and the TAH/TAqH requirement at Part III.F.1., footnote 1.

D. Additional Monitoring by Permittee

If the Permittee monitors any pollutant more frequently than
required by this permit, using test procedures approved under 40 CFR
136 or as specified in this permit, the Permittee must include the
results of this monitoring in the calculation and reporting of the data
submitted in the DMR. The Permittee must indicate on the DMR whenever
it has performed additional monitoring, and must explain why it
performed such monitoring.
Upon request by the Director, the Permittee must submit results of
any other sampling, regardless of the test method used.

E. Records Contents

All effluent monitoring records must bear the hand-written
signature of the person who prepared them. In addition, all records of
monitoring information must include:
1. The date, exact place, and time of sampling or measurements;
2. The names of the individual(s) who performed the sampling or
measurements;
3. The date(s) analyses were performed;
4. The names of the individual(s) who performed the analyses;
5. The analytical techniques or methods used; and
6. The results of such analyses.

F. Retention of Records

The Permittee must retain records of all monitoring information,
including, but not limited to, all calibration and maintenance records
and all original strip chart recordings for continuous monitoring
instrumentation, copies of all reports required by this permit, copies
of DMRs, a copy of the NPDES permit, and records of all data used to
complete the application for this permit, for a period of at least five
years from the date of the sample, measurement, report or application,
or for the term of this permit, whichever is longer. This period may be
extended by request of the Director at any time.
A copy of the final permit must be maintained at the drilling site.

G. Twenty-four Hour Notice of Noncompliance Reporting

1. The Permittee must report the following occurrences of
noncompliance by telephone or facsimile within 24 hours from the time
the Permittee becomes aware of the circumstances:
a. Any noncompliance that may endanger health or the environment;
b. Any unanticipated bypass that results in or contributes to an
exceedance of any effluent limitation in the permit (see Part V.G.,
``Bypass of Treatment Facilities'');
c. Any upset that results in or contributes to an exceedance of any
effluent limitation in the permit (see Part V.H., ``Upset
Conditions''); or
d. Any violation of a maximum daily discharge limitation for any of
the pollutants listed in the permit .
2. The Permittee must also provide a written submission within five
days of the time that the Permittee becomes aware of any event required
to be reported under subpart 1 above. The written submission must
contain:
a. A description of the noncompliance and its cause;

[[Page 11902]]

b. The period of noncompliance, including exact dates and times;
c. The estimated time noncompliance is expected to continue if it
has not been corrected; and
d. Steps taken or planned to reduce, eliminate, and prevent
reoccurrence of the noncompliance.
3. The Director may, at her or his sole discretion, waive the
written report on a case-by-case basis if the oral report has been
received within 24 hours by the Water Compliance Section in Seattle,
Washington, by telephone, (206) 553-1846.
4. Reports must be submitted to the addresses in Part IV.A.
(``Reporting of Monitoring Results'').

H. Other Noncompliance Reporting

The Permittee must report all instances of noncompliance, not
required to be reported within 24 hours, at the time that monitoring
reports for Part IV.A. are submitted. The reports must contain the
information listed in Part IV.G.2. of this permit.

I. Changes in Discharge of Toxic Substances.

The Permittee must notify the Director as soon as it knows, or has
reason to believe:
1. That any activity has occurred or will occur that would result
in the discharge, on a routine or frequent basis, of any toxic
pollutant that is not limited in the permit, if that discharge will
exceed the highest of the following ``notification levels'':
a. One hundred micrograms per liter (100 g/l);
b. Two hundred micrograms per liter (200 g/l) for acrolein
and acrylonitrile; five hundred micrograms per liter (500 g/l)
for 2,4-dinitrophenol and for 2-methyl-4, 6-dinitrophenol; and one
milligram per liter (1 mg/l) for antimony;
c. Five (5) times the maximum concentration value reported for that
pollutant in the permit application in accordance with 40 CFR
122.21(g)(7); or
d. The level established by the Director in accordance with 40 CFR
122.44(f).
2. That any activity has occurred or will occur that would result
in any discharge, on a non-routine or infrequent basis, of any toxic
pollutant that is not limited in the permit, if that discharge will
exceed the highest of the following ``notification levels'':
a. Five hundred micrograms per liter (500 g/l);
b. One milligram per liter (1 mg/l) for antimony;
c. Ten (10) times the maximum concentration value reported for that
pollutant in the permit application in accordance with 40 CFR
122.21(g)(7); or
d. The level established by the Director in accordance with 40 CFR
122.44(f).

V. Compliance Responsibilities

A. Duty To Comply

The Permittee must comply with all conditions of this permit. Any
permit noncompliance constitutes a violation of the Act and is grounds
for enforcement action, for permit termination, revocation and
reissuance, or modification, or for denial of a permit renewal
application. The Permittee must give reasonable advance notice to the
Director of any planned changes in the permitted facility or activity
that may result in noncompliance with permit requirements.

B. Penalties for Violations of Permit Conditions.

1. Civil and Administrative Penalties
Any person who violates a permit condition implementing Sections
301, 302, 306, 307, 308, 318, or 405 of the Act must be subject to a
civil or administrative penalty, not to exceed the maximum amounts
specified in Section 309(d) and 309(g) of the Act.
2. Criminal Penalties
a. Negligent Violations. Any person who negligently violates a
permit condition implementing Sections 301, 302, 306, 307, 308, 318, or
405 of the Act must, upon conviction, be punished by a fine and/or
imprisonment as specified in Section 309(c)(1) of the Act.
b. Knowing Violations. Any person who knowingly violates a permit
condition implementing Sections 301, 302, 306, 307, 308, 318, or 405 of
the Act must, upon conviction, be punished by a fine and/or
imprisonment as specified in Section 309(c)(2) of the Act.
c. Knowing Endangerment. Any person who knowingly violates a permit
condition implementing Sections 301, 302, 303, 306, 307, 308, 318, or
405 of the Act, and who knows at that time that he thereby places
another person in imminent danger of death or serious bodily injury,
must, upon conviction, be subject to a fine and/or imprisonment as
specified in Section 309(c)(3) of the Act.
d. False Statements. Any person who knowingly makes any false
material statement, representation, or certification in any
application, record, report, plan, or other document filed or required
to be maintained under this Act or who knowingly falsifies, tampers
with, or renders inaccurate any monitoring device or method required to
be maintained under this Act, must be punished by a fine and/or
imprisonment as specified in Section 309(c)(4) of the Act.
Except as provided in permit conditions in Part V.G., (``Bypass of
Treatment Facilities'') and Part V.H., (``Upset Conditions''), nothing
in this permit must be construed to relieve the Permittee of the civil
or criminal penalties for noncompliance.

C. Need To Halt or Reduce Activity Not a Defense.

It must not be a defense for the Permittee in an enforcement action
that it would have been necessary to halt or reduce the permitted
activity in order to maintain compliance with the conditions of this
permit.

D. Duty To Mitigate

The Permittee must take all reasonable steps to minimize or prevent
any discharge in violation of this permit that has a reasonable
likelihood of adversely affecting human health or the environment.

E. Proper Operation and Maintenance

The Permittee must at all times properly operate and maintain all
facilities and systems of treatment and control (and related
appurtenances) that are installed or used by the Permittee to achieve
compliance with the conditions of this permit. Proper operation and
maintenance also includes adequate laboratory controls and appropriate
quality assurance procedures. This provision requires the operation of
back-up or auxiliary facilities or similar systems only when the
operation is necessary to achieve compliance with the conditions of the
permit.

F. Removed Substances

Solids, sludges, filter backwash, or other pollutants removed in
the course of treatment or control of water and wastewaters must be
disposed of in a manner such as to prevent any pollutant from such
materials from entering navigable waters.

G. Bypass of Treatment Facilities

1. Bypass Not Exceeding Limitations
The Permittee may allow any bypass to occur that does not cause
effluent limitations to be exceeded, but only if it also is for
essential maintenance to assure efficient operation. These bypasses are
not subject to the provisions of paragraphs 2 and 3 of this Part.
2. Notice
a. Anticipated bypass. If the Permittee knows in advance of the
need for a bypass, it must submit prior notice, if

[[Page 11903]]

possible at least 10 days before the date of the bypass.
b. Unanticipated bypass. The Permittee must submit notice of an
unanticipated bypass as required under Part IV.G. (``Twenty-four Hour
Notice of Noncompliance Reporting'').
3. Prohibition of Bypass
a. Bypass is prohibited, and the Director may take enforcement
action against the Permittee for a bypass, unless:
(1) The bypass was unavoidable to prevent loss of life, personal
injury, or severe property damage;
(2) There were no feasible alternatives to the bypass, such as the
use of auxiliary treatment facilities, retention of untreated wastes,
or maintenance during normal periods of equipment downtime. This
condition is not satisfied if adequate back-up equipment should have
been installed in the exercise of reasonable engineering judgment to
prevent a bypass that occurred during normal periods of equipment
downtime or preventive maintenance; and
(3) The Permittee submitted notices as required under paragraph 2
of this Part.
b. The Director may approve an anticipated bypass, after
considering its adverse effects, if the Director determine that it will
meet the three conditions listed above in paragraph 3.a. of this Part.

H. Upset Conditions

1. Effect of an Upset
An upset constitutes an affirmative defense to an action brought
for noncompliance with such technology-based permit effluent
limitations if the Permittee meets the requirements of paragraph 2 of
this Part. No determination made during administrative review of claims
that noncompliance was caused by upset, and before an action for
noncompliance, is final administrative action subject to judicial
review.
2. Demonstration of an Upset
To establish the affirmative defense of upset, the Permittee must
demonstrate, through properly signed, contemporaneous operating logs,
or other relevant evidence that:
a. An upset occurred and that the Permittee can identify the
cause(s) of the upset;
b. The permitted facility was at the time being properly operated;
c. The Permittee submitted notice of the upset as required under
Part IV.G., Twenty-four Hour Notice of Noncompliance Reporting; and
d. The Permittee complied with any remedial measures required under
Part V.D., Duty to Mitigate.
3. Burden of Proof
In any enforcement proceeding, the Permittee seeking to establish
the occurrence of an upset has the burden of proof.

I. Toxic Pollutants

The Permittee must comply with effluent standards or prohibitions
established under Section 307(a) of the Act for toxic pollutants within
the time provided in the regulations that establish those standards or
prohibitions, even if the permit has not yet been modified to
incorporate the requirement.

J. Planned Changes

The Permittee must give notice to the Director as soon as possible
of any planned physical alterations or additions to the permitted
facility whenever:
1. The alteration or addition to a permitted facility may meet one
of the criteria for determining whether a facility is a new source as
determined in 40 CFR 122.29(b); or
2. The alteration or addition could significantly change the nature
or increase the quantity of pollutants discharged. This notification
applies to pollutants that are subject neither to effluent limitations
in the permit, nor to notification requirements under Part IV.I.
The Permittee must give notice to the Director as soon as possible
of any planned changes in process or chemical use whenever such change
could significantly change the nature or increase the quantity of
pollutants discharged.

K. Anticipated Noncompliance

The Permittee must also give advance notice to the Director of any
planned changes in the permitted facility or activity that may result
in noncompliance with this permit.

VI. General Provisions

A. Permit Actions

This permit may be modified, revoked and reissued, or terminated
for cause. The filing of a request by the Permittee for a permit
modification, revocation and reissuance, or termination, or a
notification of planned changes or anticipated noncompliance, does not
stay any permit condition.

B. Duty To Provide Information

The Permittee must furnish to the Director, within the time
specified in the request, any information that the Director may request
to determine whether cause exists for modifying, revoking and
reissuing, or terminating this permit, or to determine compliance with
this permit. The Permittee must also furnish to the Director, upon
request, copies of records required to be kept by this permit.

C. Other Information

When the Permittee becomes aware that it failed to submit any
relevant facts in a permit application, or that it submitted incorrect
information in a permit application or any report to the Director, it
must promptly submit the omitted facts or corrected information.

D. Signatory Requirements

All applications, reports or information submitted to the Director
must be signed and certified.
1. All permit applications must be signed as follows:
a. For a corporation: by a responsible corporate officer.
b. For a partnership or sole proprietorship: by a general partner
or the proprietor, respectively.
c. For a municipality, state, federal, or other public agency: by
either a principal executive officer or ranking elected official.
2. All reports required by the permit and other information
requested by the Director must be signed by a person described above or
by a duly authorized representative of that person. A person is a duly
authorized representative only if:
a. The authorization is made in writing by a person described above
and submitted to the Director, and
b. The authorization specifies either an individual or a position
having responsibility for the overall operation of the regulated
facility or activity, such as the position of plant manager, operator
of a well or a well field, superintendent, position of equivalent
responsibility, or an individual or position having overall
responsibility for environmental matters for the company.
3. Changes to authorization. If an authorization under Part VI.D.2.
is no longer accurate because a different individual or position has
responsibility for the overall operation of the facility, a new
authorization satisfying the requirements of paragraph VI.D.2. must be
submitted to the Regional Administrator prior to or together with any
reports, information, or applications to be signed by an authorized
representative.

[[Page 11904]]

4. Certification. Any person signing a document under this Part
must make the following certification:

I certify under penalty of law that this document and all
attachments were prepared under my direction or supervision in
accordance with a system designed to assure that qualified personnel
properly gather and evaluate the information submitted. Based on my
inquiry of the person or persons who manage the system, or those
persons directly responsible for gathering the information, the
information submitted is, to the best of my knowledge and belief,
true, accurate, and complete. I am aware that there are significant
penalties for submitting false information, including the
possibility of fine and imprisonment for knowing violations.

E. Availability of Reports

Except for data determined to be confidential under 40 CFR 2, all
reports prepared in accordance with this permit must be available for
public inspection at the offices of the state water pollution control
agency and the Director. As required by the Act, permit applications,
permits, Best Management Practices Plans, and effluent data must not be
considered confidential.

F. Inspection and Entry

The Permittee must allow the Director, or an authorized
representative (including an authorized contractor acting as a
representative of the Administrator), upon the presentation of
credentials and other documents as may be required by law, to:
1. Enter upon the Permittee's premises where a regulated facility
or activity is located or conducted, or where records must be kept
under the conditions of this permit;
2. Have access to and copy, at reasonable times, any records that
must be kept under the conditions of this permit;
3. Inspect at reasonable times any facilities, equipment (including
monitoring and control equipment), practices, or operations regulated
or required under this permit; and
4. Sample or monitor at reasonable times, for the purpose of
assuring permit compliance or as otherwise authorized by the Act, any
substances or parameters at any location.

G. Oil and Hazardous Substance Liability

Nothing in this permit must be construed to preclude the
institution of any legal action or relieve the Permittee from any
responsibilities, liabilities, or penalties to which the Permittee is
or may be subject under Section 311 of the Act.

H. Property Rights

The issuance of this permit does not convey any property rights of
any sort, or any exclusive privileges, nor does it authorize any injury
to private property or any invasion of personal rights, nor any
infringement of federal, state or local laws or regulations.

I. Severability

The provisions of this permit are severable. If any provision of
this permit, or the application of any provision of this permit to any
circumstance, is held invalid, the application of such provision to
other circumstances, and the remainder of this permit, must not be
affected thereby.

J. Transfers

This permit may be automatically transferred to a new Permittee if:
1. The current Permittee notifies the Director at least 30 days in
advance of the proposed transfer date;
2. The notice includes a written agreement between the existing and
new Permittees containing a specific date for transfer of permit
responsibility, coverage, and liability between them; and
3. The Director does not notify the existing Permittee and the
proposed new Permittee of his or her intent to modify, or revoke and
reissue the permit.
If the notice described in paragraph 3 above is not received, the
transfer is effective on the date specified in the agreement mentioned
in paragraph 2 above.

K. State Laws

Nothing in this permit must be construed to preclude the
institution of any legal action or relieve the Permittee from any
responsibilities, liabilities, or penalties established pursuant to any
applicable state law or regulation under authority preserved by Section
510 of the Act.

L. Reopener Clause

This permit is subject to modification, revocation and reissuance,
or termination at the request of any interested person (including the
permittee) or upon EPA initiative. However, permits may only be
modified, revoked or reissued, or terminated for the reasons specified
in 40 CFR 122.62 or 122.64, and 40 CFR 124.5. This includes new
information which was not available at the time of permit issuance and
would have justified the application of different permit conditions at
the time of issuance including future monitoring results. All requests
for permit modification must be addressed to EPA in writing and must
contain facts or reasons supporting the request.

VII. Definitions

1. ``AAS'' means atomic absorption spectrophotometry.
2. ``Acute toxic unit (TUa)'' is a measure of acute
toxicity. The number of acute toxic units in the effluent is calculated
as 100/LC50, where the LC50 is measured in percent effluent.
3. ``ADEC'' means the Alaska Department of Environmental
Conservation.
4. ``Average monthly discharge limitation'' means the highest
allowable average of ``daily discharges'' over a calendar month,
calculated as the sum of all ``daily discharges'' measured during a
calendar month divided by the number of ``daily discharges'' measured
during that month.
5. ``Ballast water'' means harbor or seawater added or removed to
maintain the proper ballast floater level and ship draft.
6. ``bbl/hr'' means barrels per hour. One barrel equals 42 gallons.
7. ``Bilge water'' means water which collects in the lower internal
parts of the drilling vessel hull.
8. ``Biocide'' means any chemical agent used for controlling the
growth of or destroying nuisance organisms (e.g., bacteria, algae, and
fungi).
9. ``Blowout preventer fluid'' means fluid used to actuate
hydraulic equipment on the blowout preventer.
10. ``BOD'' means biochemical oxygen demand.
11. ``Boiler blowdown'' means the discharge of water and minerals
drained from boiler drums.
12. ``Bulk discharge'' means the discharge of more than 100 barrels
in a one-hour period.
13. ``Bypass'' means the intentional diversion of waste streams
from any portion of a treatment facility.
14. ``Cd'' means cadmium.
15. ``Chronic toxic unit (TUc)'' is a measure of chronic
toxicity. The number of chronic toxic units in the effluent is
calculated as 100/NOEC, where the NOEC is measured in percent effluent.
16. ``Coastal'' means any location in or on a water of the United
States landward of the inner boundary of the territorial seas (40 CFR
435.40).
17. ``COD'' means chemical oxygen demand.
18. ``Completion fluid'' means salt solutions, weighted brines,
polymers, and various additives used to prevent damage to the wellbore
during operations which prepare the drilled well for hydrocarbon
production.

[[Page 11905]]

19. ``Cooling water'' means once-through non-contact cooling water.
20. ``Daily discharge'' means the discharge of a pollutant measured
during a calendar day or any 24-hour period that reasonably represents
the calendar day for purposes of sampling. For pollutants with
limitations expressed in units of mass, the ``daily discharge'' is
calculated as the total mass of the pollutant discharged over the day.
For pollutants with limitations expressed in other units of
measurement, the ``daily discharge'' is calculated as the average
measurement of the pollutant over the day.
21. ``Deck drainage'' means all waste resulting from platform
washings, deck washings, spillage, rainwater, and runoff from curbs,
gutters, and drains including drip pans and wash areas within
facilities subject to this permit.
22. ``Desalination unit wastes'' means wastewater associated with
the process of creating freshwater from seawater.
23. ``Development'' operations are those operations that are
engaged in the drilling and completion of production wells. These
operations may occur prior to or simultaneously with production
operations.
24. ``Diesel oil'' means the grade of distillate fuel, as specified
in the American Society for Testing and Materials Standard
Specifications D975-81, that is typically used as the continuous phase
in conventional oil-based drilling fluids, which contains a number of
toxic pollutants. For the purpose of this permit, ``diesel oil''
includes the fuel oil present at the facility.
25. ``Director'' means the Regional Administrator or delegated
authority for administration of the NPDES program in EPA, Region 10.
26. ``Domestic wastes'' means materials discharged from showers,
sinks, safety showers, eye-wash stations, hand-wash stations, fish-
cleaning stations, galleys and laundries.
27. ``Drill cuttings'' means particles generated by drilling into
subsurface geological formations and carried to the surface with the
drilling fluid.
28. ``Drilling Fluid'' refers to the circulating fluid (mud) used
in the rotary drilling of wells to clean and condition the hole and to
counterbalance formation pressure. The four classes of drilling fluids
are:
(a) A water-based drilling fluid has water as its continuous phase
and the suspending medium for solids, whether or not oil is present.
(b) An oil-based drilling fluid has diesel oil, mineral oil, or
some other oil, but neither a synthetic material nor enhanced mineral
oil, as its continuous phase with water as the dispersed phase.
(c) An enhanced mineral oil-based drilling fluid has an enhanced
mineral oil as its continuous phase with water as the dispersed phase.
(d) A synthetic-based drilling fluid has a synthetic material as
its continuous phase with water as the dispersed phase.
29. ``Drilling Fluids Toxicity Test'' means a toxicity test
conducted and reported in accordance the following approved toxicity
test methodology: ``Drilling Fluids Toxicity Test,'' as defined in
Appendix 2 to Subpart A of 40 CFR 435, or other methods approved in
advance by Region 10 that produce results which will assure equivalent
protection levels.
30. ``Enhanced Mineral Oil'' as applied to enhanced mineral oil-
based drilling fluid means a petroleum distillate which has been highly
purified and is distinguished from diesel oil and conventional mineral
oil in having a lower polycyclic aromatic hydrocarbon (PAH) content.
Typically, conventional mineral oils have a PAH content on the order of
0.35 weight percent expressed as phenanthrene, whereas enhanced mineral
oils typically have a PAH content of 0.001 or lower weight percent PAH
expressed as phenanthrene.
31. ``End of well'' describes the point during drilling when the
greatest well depth is obtained.
32. ``Excess cement slurry'' means the excess cement and wastes
from equipment washdown after a cementing operation.
33. ``Exploratory'' operations are limited to those operations
involving drilling to determine the nature of potential hydrocarbon
reserves and does not include drilling of wells once a hydrocarbon
reserve has been defined. Discharges form exploratory operations are
limited to five wells per site.
34. ``Filter Backwash'' means wastewater generated when filters are
cleaned and maintained.
35. ``Fire control system test water'' means the water released
during the training of personnel in fire protection and the testing and
maintenance of fire protection equipment.
36. ``GC'' means gas chromatography. ``GC/MS'' means gas
chromatography/mass spectrometry.
37. A ``Grab'' sample is a single sample or measurement taken at a
specific time or over as short a period of time as is feasible.
38. ``Hg'' means mercury.
39. ``Hydrotest water'' is filtered sea water, or occasionally
fresh water, used to test the integrity of unused produced water lines,
or produced water lines which are suspected of leaking or which have
recently been repaired.
40. ``Interim Minimum Level'' means the level calculated when a
method specified ML does not exist. It is equal to 3.18 times the
method specified MDL.
41. ``lb/bbl'' means pounds per barrel.
42. ``LC50'' means the concentration of effluent that is
acutely toxic to 50 percent of the test organisms exposed.
43. ``Maximum daily discharge limitation'' means the highest
allowable ``daily discharge.''
44. ``Maximum hourly rate'' as applied to drilling mud, cuttings,
and washwater means the greatest number of barrels of drilling fluids
discharged within one hour, expressed as barrels per hour.
45. ``Method Detection Limit (MDL)'' means the minimum
concentration of an analyte that can be measured and reported with 99
percent confidence that the analyte concentration is greater than zero
as determined by a specific laboratory method.
46. ``Minimum Level'' (ML) means the concentration at which the
entire analytical system must give recognizable signal and acceptable
calibration point. The ML is the concentration in a sample that is
equivalent to the concentration of the lowest calibration standard
analyzed by a specific analytical procedures, assuming that all the
method specified sample weights, volumes and processing steps have been
followed.
47. ``MGD'' means million gallons per day.
48. ``mg/kg'' means milligrams per kilogram.
49. ``mg/l'' means milligrams per liter.
50. ``Mineral oil'' means a class of low volatility petroleum
product, generally of lower aromatic hydrocarbon content and lower
toxicity than diesel oil.
51. ``Mineral oil pills'' (also called mineral oil spots) are
formulated and circulated in the mud system as a slug in attempt to
free stuck pipe. Pills generally consist of two parts: a spotting
compound and mineral oil.
52. ``Minimum daily'' discharge limitation means the lowest
allowable ``daily discharge.''
53. ``Monitoring month'' means the period consisting of the
calendar weeks which end in a given calendar month.
54. ``Monthly average'' means the average of ``daily discharges''
over a monitoring month, calculated as the sum of all ``daily
discharges'' measured during a monitoring month divided by the number
of ``daily discharges'' measured during that month.
55. ``Muds, cuttings, cement at sea floor'' means the materials
discharged at

[[Page 11906]]

the surface of the ocean floor in the early phases of drilling
operations, before the well casing is set, and during well abandonment
and plugging.
56. ``MSD'' means marine sanitation device, and is a sanitary
wastewater treatment system specifically designed to meet U.S. Coast
Guard requirements.
57. ``M9IM'' means those facilities continuously manned by nine (9)
or fewer persons or only intermittently manned by any number of
persons.
58. ``M10'' means those facilities continuously manned by ten (10)
or more persons.
59. ``NAA'' means neutron activation analysis.
60. ``No discharge of free oil'' means that waste streams may not
be discharged when they would cause a film or sheen upon or a
discoloration of the surface of the receiving water or fail the static
sheen test defined in Appendix 1 to 40 CFR 435, Subpart A.
61. ``No discharge of diesel oil'' in drilling mud means a
determination that diesel oil is not present based on a comparison of
the gas chromatogram from an extract of the drilling mud and from
diesel oil obtained from the drilling rig or platform. GC/MS may also
be used.
62. ``NOEC'' means no observable effect concentration. The NOEC is
the highest tested concentration of an effluent at which no adverse
effects are observed on the test organisms at a specific time of
observation.
63. ``Non-contact cooling water''--see ``cooling water.''
64. ``Oil-based drilling mud'' means a drilling mud with fossil-
derived petroleum hydrocarbons as the continuous phase.
65. ``Open water'' means less than 25 percent ice coverage within a
one mile radius of the discharge site.
66. ``Produced solids'' means sands and other solids deposited from
produced water which collect in vessels and lines and which must be
removed to maintain adequate vessel and line capacities.
67. ``Produced water'' means fluid extracted from a hydrocarbon
reserve during development or production, and hydrotest water. The
fluid is generally a mixture of oil, water, and natural gas. This may
include formation water, injection water, and any chemicals added
downhole or during the oil/water separation process.
68. ``Production'' operations are those operations involving active
recovery of hydrocarbons from production formations. These operations
may occur simultaneously with or following development operations.
69. ``SPP'' means the suspended particulate phase of a muds sample,
the preparation of which is described in 40 CFR 435, Subpart A,
Appendix 2.
70. ``Sanitary wastes'' means human body waste discharged from
toilets and urinals.
71. ``Severe property damage'' means substantial physical damage to
property, damage to the treatment facilities which causes them to
become inoperable, or substantial and permanent loss of natural
resources which can reasonably be expected to occur in the absence of a
bypass. Severe property damage does not mean economic loss caused by
delays in production.
72. ``Site'' means the single, specific geographical location where
a mobile drilling facility (jackup rig, semi-submersible, or arctic
mobile rig) conducts its activity, including the area beneath the
facility, or to a location of a single gravel island.
73. ``Slush ice'' occurs during the initial stage of ice formation
when unconsolidated individual ice crystals (frazil) form a slush layer
at the surface of the water column.
74. ``Stable ice'' means ice that is stable enough to support
discharged muds and cuttings.
75. ``State waters,'' or territorial seas, means the belt of the
seas measured from the line of ordinary low water along that portion of
the coast which is in direct contact with the open sea or the line
marking the seaward limit of inland waters (``baseline''), and
extending seaward a distance of three miles. The line which marks the
seaward limit of inland waters is also referred to as the inner
boundary of the territorial seas, and is illustrated by the line
separating coastal and offshore waters in Figure 1.
76. ``Static Sheen Test'' means the standard test procedures that
has been developed for this industrial subcategory for the purpose of
demonstrating compliance with the requirement of no discharge of free
oil. The methodology for performing the static sheen test is presented
in Appendix 1 to Subpart A of 40 CFR 435.
77. ``Synthetic material'' as applied to synthetic-based drilling
fluid means material produced by the reaction of specific purified
chemical feedstock, as opposed to the traditional base fluids such as
diesel and mineral oil which are derived from crude oil solely though
physical separation processes. Physical separation processes include
fractionation and distillation and/or minor chemical reactions such as
cracking and hydro processing. Since they are synthesized by the
reaction of purified compounds, synthetic materials suitable for use in
drilling fluids are typically free of polycyclic aromatic hydrocarbons
(PAHs) but test sometimes report levels of PAH up to 0.001 weight
percent PAH expressed as phenanthrene. Poly (alpha olefins) and
vegetable esters are two examples of synthetic materials used by the
oil and gas extraction industry in formulating drilling fluids. Poly
(alpha olefins) are synthesized from the polymerization (dimerization
trimerization, tetramerization and higher oligomerization) of purified
straight-chain hydrocarbons such as C6-C14 alpha
olefins. Vegetable esters are synthesized from the acid-catalyzed
esterification of vegetable fatty acids with various alcohols. The
mention of these two synthetic fluid base materials is to provide
examples, and is not meant to exclude other synthetic materials that
are either in current use or may be used in the future. A synthetic-
based drilling fluid may include a combination of synthetic materials.
78. ``Test fluid'' means the discharge which would occur should
hydrocarbons be located during exploratory drilling and tested for
formation pressure and content. This would consist of fluids sent
downhole during testing along with water from the formation.
79. ``TOC'' means total organic carbon.
80. A ``24-hour composite'' sample must mean a flow-proportioned
mixture of not less than 8 discrete aliquots. Each aliquot must be a
grab sample of not less than 100 ml and must be collected and stored in
accordance with procedures prescribed in the most recent edition of
``Standard Methods for the Examination of Water and Wastewater.''
81. ``Unstable or broken ice conditions'' means greater than 25%
ice coverage within a one mile radius of the discharge site after
spring breakup or after the start of slush ice formation in the fall,
but not stable ice.
82. ``Upset'' means an exceptional incident in which there is
unintentional and temporary noncompliance with technology-based permit
effluent limitations because of factors beyond the reasonable control
of the Permittee. An upset does not include noncompliance to the extent
caused by operational error, improperly designed treatment facilities,
inadequate treatment facilities, lack of preventive maintenance, or
careless or improper operation.
83. ``Waste stream'' means any non-de minimis stream of pollutants
within the Permittee's facility that enters any permitted outfall or
navigable waters. This includes spills and other

[[Page 11907]]

unintentional, non-routine or unanticipated discharges.
84. ``Waterflooding discharges'' means discharges associated with
the treatment of seawater prior to its injection into a hydrocarbon-
bearing formation to improve the flow of hydrocarbons from production
wells, and prior to its use in operating physical/chemical treatment
units for sanitary waste. These discharges include strainer and filter
backwash water.
85. ``Weekly average'' means the average of daily discharges over a
calendar week, calculated as the sum of all daily discharges measured
during a calendar week divided by the number of daily discharges
measured during that week. For fecal coliform bacteria, the weekly
average is calculated as the geometric mean of all daily discharges
measured during a calendar week.
86. ``Well completion fluids'' are salt solutions, weighted brines,
polymers and various additives used to prevent damage to the well bore
during operations which prepare the drilled well for hydrocarbon
production. These fluids move into the formation and return to the
surface as a slug with the produced water.
87. A ``well treatment fluid'' is any fluid used to restore or
improve productivity by chemically or physically altering hydrocarbon
bearing strata after a well has been drilled.
88. ``Workover fluids'' are salt solutions, weighted brines,
polymers, or other specialty additives used in a producing well to
allow for maintenance, repair of abandonment procedures. Drilling
fluids used during workover operations are not considered workover
fluids by definition. Packer fluids (low solid fluids between the
packer, production string, and well casing) are considered to be
workover fluids.
89. ``XFA'' means x-ray fluorescence analysis.
90. ``96-hour LC50'' means the concentration of a test material
that is lethal to 50 percent of the test organisms in a toxicity test
after 96 hours of constant exposure.
91. ``g/l'' means micrograms per liter.

BILLING CODE 6560-50-P

[[Page 11908]]

[GRAPHIC] [TIFF OMITTED] TN10MR99.000

[FR Doc. 99-5667 Filed 3-8-99; 8:45 am]
BILLING CODE 6560-50-C

Final NPDES General Permit for Oil and Gas Exploration, Development and Production Facilities in Cook Inlet, AL (AKG285000)

Federal Register Citation

Suggested Web Citation