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PB83-216069

Assessment of Past, Present, and Future Risks of Oil Spills in and
Near the Present SEA Otter Range in California

Richard T. Tinney, Jr.

Prepared for

U.S. Marine Mammal Commission

Washington, D.C. ar i
REMINGTON KELLOGG |

LEBRARY OF
| AFARINE MAMMAL:
moo SMITPHSOMAN INSTITUT

U.S. DEPARTMENT OF COMMERCE
National Technical Information Service

Report No. MMC-83/01

~ ASSESSMENT OF PAST,

RANGE IN CALIFORNIA

Richard T. Tinney, Ware
1501 South George Mason Drive
Arlington, Virginia

Published June 1983

Final Report to U.S. Marine Mammal Commission

PRESENT, AND FUTURE RISKS
OF OIL SPILLS IN AND NEAR THE PRESENT SEA OTTER

in fulfillment of Contract No. MM2324944-0

“NAvailability Unlimited
a \

Oy)

Prepared for

U.S. Marine Mammal Commission
1625 I Street, N.W.
Washington, D.C. 20006

"REPRODUCED BY |
NATIONAL TECHNICAL
INFORMATION SERVICE

U.S. DEPARTMENT OF COMMERCE
SPRINGFIELD, VA. 22161

TAM MAL OT
NOINSTTPUT IONS

ate : a Ard oir oe
rry Rion ia eahvemans! 7 sm

50272-10)

REPORT DOCUMENTATION | 1. REPORT NO. 3. Recipient's Accession No.
PAGE MMC-83/01 PB83-216069

4. Title and Subtitle 5. Report Date
Assessment of Past, Present, and Future Risk of Oil
Spills in dnd Near the Sea Otter Range in California

6.

7. Author(s) 8. Performing Organization Rept. No.

Richard T. Tinney, Jr.

9. Performing Organization Name and Address 10. Project/Task/Work Unit No.

Richard T. Tinney, Jr.
1501 South George Mason Drive
Arlington, Virginia 22204

11. Contract(C) or Grant(G) No.

m2 324944-0
(G)

12. Sponsoring Organization Name and Address 13. Type of Report & Period Covered

Final

Marine Mammal Commission
1625 I Street, NW
Washington, D.C. 20006

14.

15. Supplementary Notes The views, ideas and opinions expressed in this report are those of
the author and are not necessarily shared by the Marine Mammal Commission, its
staff, or its Committee of Scientific Advisors.

16. Abstract (Limit: 200 words)

In 1977 the U.S. Fish and Wildlife Service listed the Sea Otter in California as
a threatened species, primarily because of the potential risk posed to the
population by oil spills. This report examines the extent of the oil spill

risk as it existed in 1977, as it exists now, and as it is expected to exist

in 1988. Included are risk-related factors such as offshore oil exploration,
development, production, and transportation, oil spill response capability,
coastwise transportation of crude oil and refined products, and improved
offshore technology.

17. Document Analysis a. Descriptors

Offshore oil and gas development; California sea otters; only ispadaliraisk
assessment.

b. Identifiers/Open-Ended Terms

c. COSATI Field/Group

18. Availability Statemen:

19. Security Class (This Report) 21. No. of Pages

Unclassified 214
20. Security Class (This Page) | 22. Price
ae

Availability Unlimited

|
OPTIONAL FORM 272 (4-77)
(Formerly NTIS—35)
Department of Commerce

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TABLE OF CONTENTS

ESOC UC AVCEm SUM AeA Meme tate torte cesic cls vellonaisiereleverencl «tebe leieierleliere| lene fe vienene eMensieyelve. iii
LABE@OCUWUGCLOM coc poo oUShoo dood OOD OOOO 46 Boom OOOO Oud no oto D Odor 1
Hye Offshore Oil in and Near the Sea Otter Range.......... 7
IIE Oil Transportation in and Near the Sea Otter Range... 19
IEALIE Oma S pM MenD art avcaradeeMOGd ed sie sic carecelieions ie leileiellene lifelelerels sncter eels 33
IV. OPES PHM GRGIS|PONSICiyewerehoyeicier a cilsloneroleliolercievodedelloneire) elieilelreliel/s) ei iel.eive 53
V. VNC MES HataU ake MMmlstaianl| On Miteiercy susysestele or eicncuopoteKousdsh ella. cie\cleyicceileile/ cio" 69
Wake MACH Sisal OnEXDeGLEGs) ime 19/iGs crs ow cieress eho otc o chee cress « an
Watage SIMMONS SUSreustotebeuersieve letersi s:.cite secre wer 6 eS eae tanronetoneltaasisle tote kenete lake 92
ITLL LOZIOCA MN 5b Ob OOOO OOOO ODO OOOO OD OUD DOU OOOO DUO DUO OD OUUU OOS 100
GUROIS|Salre VireweteMallel aewowel cv eNoietenele: oust chexet sks: cueusereloee Cuotetelereileieitere sllaisieleteuere 6.0 « 105
Appendices
ADT Oi spills from Pillatforms and Driliships in
SouthernmCal ihornila: Waters! or aercciels ls elelel alec aie 108
B Spills in the Sea Otter Range 1977-Present.. 12
Came Xampilemot, Ol sopislds Tra jectOrieS).1.) sy. +) sisi": « 128
D Selecteds Dritt Bottle Prajectoriles sc ccs s\ « iss
E Inventory of Equipment and Materials -
Ciloanmocasmandy CleanimBay Siero ciareroreters olchelielsiers 146
Kemp redietiion: Of On Spill MOVemenity. oe) cte)cle) oie sie 183
Game prediuct ioniwot Olt ySpi 1 Movements.) .)<)< (10161516 196

iat

‘a ist sin! fet
s 55 oie nay, be jovi

i -egyie 3 4

sewage th iLLO

: P
AOL, et

EXECUTIVE SUMMARY

In 1977 there were 198 producing oil and gas wells in the federal
offshore zone of southern California. Seven platforms were in place
on the federal OCS, all but one of which were producing. In state

waters, eight platforms and six subsea completions were in place.

Tanker traffic in the area involved 2,880 arrivals in 1977 at San
Francisco (1217 tankers), Los Angeles (1220) and the ports in between
of Moss Landing (87), Estero Bay (179), Port San Luis (96),
Carpinteria (27), and Port Hueneme (54). Another 400 tankers of
Alaskan crude were expected to begin arriving in the area upon the
completion of the Alaska pipeline.

Lease Sale 48 in the federal OCS was to be held shortly. Spill
rates were estimated to be 1.8 platform spills per billion barrels of
oil produced and 2.3 pipeline spills per billion barrels. At the
time, oil spill response technology and preparedness were at an early
stage, with limited equipment and technology available to deal with
any problem.

Since that time, much has changed. The State Lands Commission
has decided to lease 40,000 acres of state tidelands for oil and gas
development between Point Arguello and Point Conception. In federal
waters, lease sales 48 and 68 were held in 1979 for tracts in the

Santa Barbara channel, sale 53 was held for tracts in the Santa Maria

iii

Basin at the southern end of the sea otter range. Significant new oil
finds have been announced for the sale 53 area, and exploration and
development in this area are proceeding rapidly.

Oil from a variety of sources is transported through the region.
Vessel arrivals at Santa Barbara Channel marine terminals, where crude
oil and some products are loaded, numbered 132 in 1980. Use of the
Morro Bay and Moss Landing tanker facilities declined to 16 and 13
tankers each in 1981. Tanker calls at San Francisco dropped to 992
vessels, and at Los Angeles rose to 1,381. Other ports saw 200
tankers in 1981, most of which were by 6 or 7 vessels on repeated
trips.

Oil spill rates for offshore operations were revised to reflect
more recent experience. For spills of 1,000 barrels or greater, the
new rates are 1.0 spills per billion barrels from platforms, 1.6 from
pipelines, and 1.3 from tankers.

Oil spill trajectory modelling is still an inexact science.
Industry and government models are very different, and both have been
criticized. Apparently, currents and winds off the California coast
are extremely complex, making genuinely representative models
decidedly difficult to formulate.

As for oil spill response, the amount and location of response
equipment has improved substantially. Nevertheless, oil spill
response capability is generally regarded as inadequate for large

spills or spills under severe weather or sea states.

iv

By 1988 the oil spill risk situation should change substantially.
Hundreds of new offshore oil wells are expected, both in the Santa
Barbara Channel and the Santa Maria basin off the Central California
coast. New platforms are planned for both areas, with Santa Maria
basin tracts receiving their first platforms by 1985. Tracts in the
Point Arguello state tidelands will also receive platforms. Oil from
these areas is expected, at least in part, to be tankered to San
Francisco, transiting the entire sea otter range in the process.

Alaskan production is expected to remain high, thereby keeping
the amount of Alaskan oil transported south high.

Oil spill response equipment will continue to be acquired,
although in terms of the area covered or the amount of equipment per

volume unit of oil may not increase concomitantly.

INTRODUCTION

On January 14, 1977 the U.S. Fish and Wildlife Service
issued a rulemaking which determined that the Southern Sea Otter
(Enhydra lutra nereis) is a threatened species within the
provisions of the Endangered Species Act, VO SUAS eGo SS ISIS 3. 7
Stat. 884. (42 F.R. 2965-69). This determination came about
after over a year and a half of analysis of extensive and complex
information by the Service. The analysis had been triggered by a
May 22, 1975 request for the listing as endangered species of 216
taxa of plants and animals, which included the Southern Sea
Otter.

The sea otter formerly ranged around the rim of the North
Pacific Ocean from the northern islands of Japan to central Baja
California (Kenyon, 1981). In the mid-eighteenth century,
extensive European exploitation of the sea otter began. The
exploitation was so complete that by the beginning of the
twentieth century the sea otter, while not in fact extinct, was
widely believed to be doomed. Small remnant groups persisted
however, including one in southern Monterey County, California.
From this group of otters, numbering something more than 150
individuals, the present stock of Southern Sea Otters has sprung
(Kenyon, 1969).

Although known to certain local ranchers, scientists, and

California Department of Fish and Game personnel, the Monterey

County remnant group was publicly "rediscovered" in 1938. Both
its range, which was centered in 1938 between Bixby Creek and Big
Creek, and its population soon expanded. By 1977 sea otters had
reached as far south as Avila and as far north as Sunset State
Beach near Santa Cruz. The Southern Sea Otter population at that
time was estimated to be 1789 animals (based on a count of 1561)
and, like the range, growing. Since that time the range has
expanded slightly to Pismo Beach in the south and Soquel Point to
the north. A November 1982 count of 1,194 free-swimming otters
has thrown the population question into uncertainty.

The original Fish and Wildlife Service decision to list the
Southern Sea Otter as a threatened species was based primarily on
the perceived threat that oil spills posed to the animals.
Specifically, the Service expressed the conclusion that a "major
spill of oil from a tanker in the waters in the vicinity of the
range of the Southern Sea Otter is probably the most serious
potential threat to the species." (42 F.R. 2965, 2966). At the
time, important factors in the perception were the relatively
small number of animals and the relatively restricted range, both
of which were believed to be increasing.

The Service noted that oil unloading facilities existed at
Moss Landing near the northern end of the sea otter's range and
at Estero Bay near the southern end of the range. At the time of
the listing, both terminals were the subjects of proposals for
enlargement. Also noted as items of concern were tankered oil
imports and the then-pending start-up of oil shipments from the

Alaska Pipeline tanker facility at Valdez.

The Service stated that a single oil spill would not likely
wipe out the entire sea otter population. There was concern that
a major spill, under the right weather and sea conditions, could
eliminate a significant portion of the population. The remaining
animals could then be classified as "endangered" due to reduction
in numbers, disruption, and vulnerability to further problems.

In designating the sea otter as threatened, the Service
noted that the probability of an oil spill occurring could not be
predicted. At the same time, however, the Service observed that
an oil spill was possible. This possibility, together with the
consequences of a spill, plus the projected increase in oil
tanker activity in the sea otter area, led to the decision to
make the listing.

The Endangered Species Act requires the Fish and Wildlife
Service to conduct a review of all listed species at least once
every five years. The purpose of this review is to ensure that
the listing accurately reflects the most current information
concerning the status of the listed species.

On September 27, 1982 the Fish and Wildlife Service
published a notice of review for wildlife classified as
threatened or endangered in 1977 (47 F.R. 42387-88). Among the
Species for which notice of review was given was the Southern Sea
Otter. The notice of review solicited comments concerning the
status of the listed species from the public, government
agencies, the scientific community, industry, or any other

interested party.

As background for its comments on the sea otter listing, the

Marine Mammal Commission contracted for this study of oil spill
risks in and near the sea otter range.

Importantly, the Endangered Species Act requires that the
five-year review be conducted in the same manner as the original
listing. Accordingly, this project looks at oil spill risks from
three perspectives. The first of these involves the conditions
existing in 1977 when the original listing occurred. This
includes the number, location, and extent of offshore leases,
platforms, wells, and production as well as oil transportation
to, from, and through the sea otter range and its vicinity. Also
included are accident rates, oil spill response capabilities, and
oil spill models.

The second look at these factors is from the present
perspective. The Alaska Pipeline has been operational for years,
and substantial new oil finds have been made near the sea otter
range. At the same time, offshore technology has advanced and
understanding of oceanographic conditions and oil spill dynamics
has increased. Clearly the situation has changed since 1977, and
this report will show how in the following chapters.

Finally, the report will attempt to look into the future, at
what might be expected five years hence in 1988. While even the
finest crystal balls are clouded, some reasonable predictions can
be made, all with relevance to the question of the continued
existence of an oil spill threat significant enough to constitute
a likelihood of the sea otter becoming endangered.

Geographically, the focus of this project is the sea otter

range. Important nearby areas are included, however, not so much

because they are likely range expansion sites, but because they
are comparatively likely sources of oil spills or spill-causing
agents, e.g. tankers. These areas include the offshore area out
to and including the normal shipping lanes, areas to the north up
to the San Francisco harbor entrance, and areas to the south as

far as the eastern end of the Santa Barbara Channel (Figure 1).

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SOURCE: Fish and Wildlife Service (1982)

6

CHAPTER 1

Offshore Oil in and Near
The Sea Otter Range

The world's first commercial offshore oil development
occurred in the study area beginning in 1896 as wells were
drilled from piers along the Santa Barbara Channel shoreline.
State government leasing of oil drilling and development rights
in the area began in 1929. The area's first federal lease sale,
in waters seaward of the three-mile state jurisdiction, took
place in 1963. Since these initial efforts the area has been the
seene of substantial offshore oil and gas leasing, exploration,
development, and production. The timing and size of state and
federal lease sales are described on the following pages. In
addition, information is provided about existing leases, numbers

of wells, and platforms, and amount and value of production.

State Leases

State offshore leases were held periodically from the first
sales in 1929 up to 1969. A blowout on a Santa Barbara Channel
federal lease in 1969 led to the State Lands Commission declaring
a moratorium on all new exploratory or production drilling in
State waters. Figure 1A shows the extent of the spill from the
blowout five days after it occurred. The spill eventually

reached as far as Point Arguello at the western end of the

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Channel, and San Miguel Island to the south. in) NO onal
companies began to seek permission to drill on existing but
undeveloped leases. Beginning in 1980, exploratory permits were
again issued.

Up to 1969 (and since then as no new leases have been
granted), offshore development in state lease areas has been
confined to the Santa Barbara Channel and the Los Angeles and
Orange County coasts. In Santa Barbara and Ventura Counties, the
total area leased between 1929 and 1969 totals 152,987 acres, of
which 136,278 acres is still under lease. See Table 1.

On the leased areas in state waters in the Santa Barbara
Channel, eight platforms and six subsea completions are in
place. The locations of these facilities are shown in Figure
3. Off Los Angeles and Orange Counties are two more platforms
and six man-made islands in state waters. Total production of
oil from all state leases through the end of 1980 has amounted to
1,752 million barrels. Gas production has amounted to almost 650
million cubic feet. See Table 2.

The State Lands Commission recently decided to lease eight
tracts covering 40,000 acres between Point Conception and Point
Arguello. Current plans call for bids to be opened on August 15,
1983 and accepted by November (Oil & Gas Journal, Jan. 3,

1983). The State Lands Commission estimates that the total
undiscovered hydrocarbon resources in the lease area may range
from 63 million barrels of oil and 53 billion cubie feet of gas

to 274 million barrels and 219 billion cubic feet.

TABLE 1 - State of California offshore oil and gas leases

Parcel Date
number Present Lessee Acreage issued
Santa Barbara County

129 Aminoil 254 1/27/44
208 Aminoil 1,920 1/18/46
308 Atlantic Richfield and others 1,920 3/4/47
309 Atlantic Richfield and others 1,920 3/4/47
421 Aminoil 68.48 10/22/29
424 Aminoil 20 11/12/292
428 William L. Appleford 69.21 7/29/30
1824 Chevron-Exxon 5,500 1/10/57
2199 Chevron-Shell 3,840 7/25/58
2205 Phillips-Pauley and others 3,840 7/25/58%
2260 Texaco 3,840 7/25/58
2207 Phillips-Exxon and others 3,840 7/25/58°
2725 Texaco 4,250.14 5/4/61
2726 Atlantic Richfield and others 4,250.14 5/4/61
2793 Atlantic Richfield and others 4,250.14 10/26/61
2879 Union 5,653.10 4/26/62
2894 Chevron-Shell 4,250.14 6/28/62
2920 Shell-Chevron 4,250.14 8/28/62
2933 Phillips-Pauley 4,250.14 10/25/62
2955 Texaco NH ARO 6 ILC 10/20/62
2991 Union 4,250.14 2/28/63
3004 Union-Exxon S50 4/25/63
3120 Atlantic Richfield-Mobil 3,324 4/29/64
3133 Exxon 7 SSS 5/28/64
3150 Atlantic Richfield-Standard By A553} 7/28/64
3242 Atlantic Richfield-Mobil 4,290 4/8/65
3498 Chevron-Exxon alos 6/15/66
3499 Philllips-Pan Petroleum 1,340 6/15/66
3503 Union 1,660 6/28/66
4000 Atlantic Richfield-Chevron 204 8/28/68
4001 Chevron 780 8/28/68
4002 Chevron 600 8/28/68
4031 Continental 2A SP 8/28/68
Ventura County

145 Energy Development Corp. 326 7/3/44
410 Norris 50 4/17/29
427 Mobil 148 5/19/30
429 Norris 80 4/21/31
735 Chevron 220 6/30/52
1446 Atlantic Richfield aL Fakes 8/29/55
3184 Chevron 5,540 9/24/64

10

Parcel _Date
number Present Lessee Acreage issued
3314 Shell 5,430 7/2/65
3403 Chevron 5,300 11/18/65
3489 Mobil-Union 4,570 5/26/66
3490 Mobil-Union 5,305 5/26/66
3945 Shell 5,546 5/23/68 ,
3946 Shell 5,589 5/23/68
91 Aminoil, Exxon 589 5/21/43
163 Aminoil 640 11/15/44
186 Exxon-Texaco AAS) 9/24/45
392 Aminoil 835 9/26/38
425 Aminoil 835 2/10/50
426 Aminoil 640 2/10/50
3033 Union Ape ie ac ee Bo) 7/25/63
3095 Chevron 3,360 1/30/69
3119 Mobil 3,420 4/29/64°
3177 Pauley Petroleum 1,549 8/18/64
3413 Union 1,871 12/1/65

i

4ouitclaimed

Quitclaimed
Couitclaimed
douitclaimed
SQuitclaimed

Source; Collins, et al., 1982

LL 3/ 71
4/8/68

WASUS
4/18/73
4/25/73

TABLE 2: TOTAL PRODUCTION FROM CALIFORNIA STATE LEASES

Year Oil (thousands of barrels) Gas (millions of cubic feet)
1953 and ADDS Bae. et SL Oe Sere
before

1954 DIO OOM ) Su ua a gk Se
1955 SS e252 eens ee ee COO TR eee
1956 Ses SVEN, tye ae ee ae? Se en Ee
1957 SOM CHAR ete yo ett iy aes caer
1958 ON} SYS Shiv ds Soe eee a Meee eA re
1959 DORI Sd te a a ee gS ERR! Pe Cel ce
1960 28,074 abe bakes}
1961 29,887 5,903
1962 34,613 10,671
1963 38,346 25,769
1964 40,526 351,325
1965 42,772 40,770
1966 53,294 46,839
1967 64,807 46,732
1968 83,632 85,699
1969 86,530 76,446
1970 79,255 59,117
1971 70,185 44,758
1972 72,518 34,967
1973 70,482 30,441
1974 64,494 24,728
1975 64,456 23,454
1976 Bye} abi) Oe Si72
1977 48,158 11,670
1978 43,747 13,250
1979 41,661 13,095
1980 35,479 11,619
1981

1982

Source: U.S. Department of the Interior
Outer Continental Shelf Statistics, 1981

12

Federal Leases

Seven federal lease sales have been held in the waters
seaward of the state waters in the study area. Most leasing and
exploratory drilling in federal waters has taken place in the
Santa Barbara Channel, as has virtually all development and
production (except for two platforms off San Pedro with a total
of 31 wells).

The first federal lease sale, designated "P1", was held on
May 14, 1963. It resulted in the leasing of 57 tracts off
Central and Northern California. All of these leases were
relinquished after 20 exploratory wells were drilled and no
commercial discoveries made. The relinquishments occurred
between 1965 and 1967.

The second California-area federal lease sale was sale P3.
It was held December 15, 1966 and involved only one tract,
located immediately seaward of state leases in the Carpinteria
Offshore field. The sale was held to protect the tract from
drainage by wells in the state lease area. Six exploratory wells
were drilled on the tract in 1967. A total of 92 development
wells have been drilled on the tract, of which 47 are producing
oil. Two platforms, Hogan and Houchin, exist on the tract, and
were placed by the tract owner, Phillips Petroleum Company.
Production began from the platforms in 1968 and 1969,
respectively.

Lease sale P4 was held February 6, 1968, and resulted in the

leasing of 71 tracts in the Santa Barbara Channel. Of these, 34

19S

remain active. Approximately a year after this lease sale was
held (on January 28, 1969), the blowout at Union Oil's Platform A
in the Dos Cuadras field off Santa Barbara occurred. As a reult
of the oil spill that followed, the Secretary of the Interior
suspended all operations on federal Santa Barbara Channel leases
as of February 7, 1969. The suspension was lifted shortly
thereafter.

Almost six years passed before the next federal lease sale
in the study area, number 35 on December 11, 1975. Fifty-six
leases were awarded in that sale, of which four are still
active. As of January 31, 1982, 40 exploratory wells had been
drilled on the 56 leases. No production from within the study
area has occurred as a result of this sale.

Lease sale 48 was the next Southern California sale, held
June 29, 1979. It resulted in 54 leases in the Santa Barbara
Channel, on Santa Rosa-Cortes Ridges, and in San Pedro Bay. All
of these leases were still active in early 1982, with 14
exploratory wells having been drilled. One discovery has been
announced from this sale.

A second sale off Central and Northern California, number
53, was held May 28, 1981. Despite plans to offer tracts from
five basins, only tracts in the Santa Maria basin, the
southernmost, were offered. A total of 111 tracts were offered,
of which 55 were leased. Twenty-one additional tracts were bid
upon, but the Bureau of Land Management was enjoined from
accepting those bids. A modification of the injunction later
allowed BLM to take action on two of those tracts, on one of
Which a lease was awarded.

14

Lease Sale 68 was held for Southern California tracts in
June, 1982. Bids were received on 35 tracts, located in the
Santa Barbara Channel and south of the Channel Islands.

Sale RS-2, a reoffering of previously offered tracts, was
held in July, 1982. Included in RS-2 were tracts offered in sale
53 but not bid on, tracts for which bids were rejected, and
tracts under litigation for which no bids were received.

Table 3 sets out pertinent statistics for these federal
lease sales held in and near the sea otter range. Included there
is information on tracts offered and leased, areas offered and
leased, and total lease bonuses paid.

Several discoveries have resulted from the federal leasing
activity in the study area. Most of these have been "unitized,"
a process through which two or more companies holding separate
leases consolidate their operations, allowing one company to be
the operator for exploration, development and production.

The first discovery in the federal offshore zone came in
1966 at the Carpinteria Offshore field in the tract lease in the
1966 drainage sale (P3). A second tract was added to this field
in the 1968 lease sale. Platforms Hogan and Houchin have been
installed on these tracts. Hogan produces 830 barrels of oil and
1.6 million cubic feet of gas a day. Houchin produces J525e
barrels and 2.5 million cubic feet per day. Production from
these two platforms is piped ashore. In 1979 a third platform,
Henry, was placed in the western portion of the Carpinteria
field, with development drilling beginning in February 1980 and
production in May 1980. Production from Henry is piped ashore

via Platform A and the Dos Cuadras Offshore field.

15

TABLE 3: Statistics for Federal Pacifc OCS lease sales

Statistic

Lease Tracts Acres Tracts Acres Total bonus
Sale offered offered leased leased leased tracts

(in thousands)
PI 129 669,777 7 311627194'5 0S 12,807
(1963)
P3 aL 1,995 1 1995) 7S 21,189
(1966)
P4 110 540,609 TAL 36:3) 8a5 7S) 7602). 719
(1968)
35 231 1,257,593 56 SLO MOAS Sie Vali sieD
(1975)
48 148 792,845 54 is Aa0) SIAR
(1979)
534 111 603,611 55 29:2) ,099I4S2 7257/7587
(1981)
RS-2 27 10
(1981)

4 Statistics for Lease Sale 53 include all bids.

The decision to accept or

reject 19 bids received on some tracts is pending results of litigation. The

sum of high bids on the 19 tracts in litigation is $220,632,072.

SOURCE: BLM, New Orleans OCS Office,

19 Sars

The Dos Cuadras field was leased in 1968 and currently
produces oil and gas via four platforms, A,B,C, and Hillhouse.
Production began from A,B, and C in 1969, 1970, and 1977
respectively. Hillhouse began producing in 1970.

The Pitas Point Unit is composed of tracts also leased in
1968. The first discovery was made that year, but no development
took place until 1981. Platform Habitat was installed in October
of 1981, and is the only platform in the federal portion of the
Santa Barbara Channel devoted entirely to gas production. Gas
from Habitat, initially 15 million cubic feet per day, but
expected to peak at about 63 million cubie feet a day in 1983 and
maintain at this rate for 4 or 5 years before beginning a 15 year
decline, is piped ashore.

The first discovery in the Santa Clara unit occurred in 1970
on a tract leased in 1968. In 1979 Platform Grace was installed
in the unit, followed by Gilda in 1981. Production from Grace is
expected to peak in 1984 at 13,000 barrels of oil and 13 million
cubic feet of gas a day. Gilda began producing in late 1981, and
is expected to peak in 1983 at 18,000 barrels of oil and 19
million cubic feet of gas a day.

The Hueneme Offshore field is also on 1968 sale tracts.
Platform Gina sits in this field, with production having begun in
1982. Peak production is expected in 1983 at 6,450 barrels of
oil and 1.2 million cubie feet of gas a day.

The Santa Yuez Unit, in the western part of the Santa
Barbara Channel, takes in four fields, only one of which, Hondo,
is presently producing. Platform Hondo was installed in 1976,

but production did not begin until April, 1981 due to controversy

G7)

over transport of produced hydrocarbons to shore. Current
poduerons 35,000 barrels of oil and 15 million cubic feet of
gas a day, is processed on an offshore storage and treatment
vessel (a converted tanker) and then transferred to tankers for
transport.

Oil companies have announced a number of other discoveries
which have yet to be developed. The Santa Rosa unit, in the
eastern end of the Channel is presently in the development
planning stages. Chevron announced a discovery on Sale 48
acreage near Point Arguello in November 1981, and delineation
drilling continues.

Big news was made in late 1982 when Chevron USA and Texaco
USA announced major finds off Point Arguello and Point
Conception. Initial estimates indicate that as much as 500
million to 1 billion barrels of oil are present there, making
this the biggest find since Alaska's Prudhoe Bay.

Union Oil Co. in January, 1983 announced a separate find
nearby, and rumors of additional finds in the area are rampant.
Many leaseholders are actively drilling in the area or plan
drilling soon. The Minerals Management Service has approved
plans for 130 exploration wells in the Point Conception-Point
Arguello area, with more plans under consideration. As many as
40 wells are expected to be drilled this year. One observer has
characterized the area as perhaps the most significant U.S. oil

play for the 1980's (Oil and Gas Journal, Nov. 1, 1982).

18

CHAPTER II

Oil Transportation

In and Near the Sea Otter Range

The transportation of oil - crude oil to refineries and
refined products to consumers - has been identified as the
largest source of marine oil pollution. It causes pollution ina
number of ways, including bilge cleaning, tank deballasting
(tankers with empty tanks will sometimes "ballast down" with sea
water for stability, and then jettison the sea water,
contaminated with whatever was left in the tank from earlier
cargoes, prior to taking on new cargoes), and catastrophic
accidents. With respect to sea otter risks, it is the accidents,
with their potentially huge and relatively instantaneous oil
discharges, that pose the gravest threat.

Oil transportation in the study area takes several forms.
Oil (and gas) produced from offshore wells in the study area is
taken ashore via pipelines or tankers, and some is later
transferred to refineries. Crude oil from Alaska and Southeast
Asia enters the study area as it is taken to refineries near the
study area or is in transit to other refineries. Refined
products are taken from refineries in the area to consumers both

within and without the study area.

1g

Crude Oil From Offshore Wells

At the beginning of 1982, about 74,000 barrels of oil and
44.6 million cubie feet of gas were being produced from federal
leases in Southern California. All of this production, except
that from Hondo and including that from Platforms A,B,C,
Hillhouse, Henry, Hogan, Houchin, Gilda, Grace and Gina, is
brought ashore via pipelines. Production from Hondo is collected
on an offshore storage and treatment vessel located near the
platform and periodically loaded on a tanker for shipment to
Exxon's Baytown, Texas refinery. Table 4 shows existing and
proposed pipelines in the federal offshore zone. Figure 1B shows
the locations of the various platforms and other facilities in
the Santa Barbara Channel.

Production from all state waters, including that from
platforms, subsea completions, and Rincon island, is piped
ashore. Table 5 shows pipelines in the state waters.

Once the oil and gas is ashore, it is given preliminary
treatment to separate it from water and other contaminants
produced with it. Treatment facilities are located at various
points along the Santa Barbara Channel mainland shoreline (plus
the offshore treatment vessel for Hondo). Table 6 shows the
treatment facilities handling OCS production at this time. After
treatment, gas is placed in pipelines for transmission elsewhere

or use in local utility lines.

20

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TABLE: 4

Existing and proposed OCS pipelines
off Southern California

je

ne EEE a EIIIyIIUIESSSIIISD SSRI SSDS SINS SSSI

Unit/ Pipeline Type and
(Field) operator Platform Landfall size Status
I a eran ee
a a a OS
Santa POPCO Hondo! Las Flores 12-in gas Approved
Ynez Canyon not
constructed
————————————E————————————————————————————————————— ee
(Dos Union A, Henry Rincon 12-in oil Existing
Cuadras/ and Hillhouse 12-in gas
Carpinteria Sun B,C
Offshore)
(Carpinteria Phillips Hogan La Conchita 10-in oil Existing
Offshore) Houchin 12-in gas
a ee
Pitas Pacific Habitat Carpinteria 12-in gas Proposed
Point Interstate
Offshore
Company
a a er
Santa Chevron Grace to Carpinteria 12-in oil Existing
Clara Hope 10-in gas
Union Gilda Mandalay 12-in oil Existing
Beach
10-in gas
a UE I eae ee
(Hueneme Union Gina Mandalay 10-in oil Existing

Offshore) Beach and gas

I

loi from Platform Hondo is stored and treated on an offshore storage and
\treatment vessel, then offloaded onto tankers.

SOURCES: Collins, et al. (1982).

22

TABLE: 5

EXISTING OIL PIPELINES LOCATED IN THE
STATE WATERS OFF SOUTHERN CALIFORNIA

ORIGINATING DIAMETER LENGTH
STRUCTURES (Inches) (Miles)
HERMAN 6 2s
HELEN 6 ere
HOLLY 6 Qo
HILDA & HAZEL 6 5.0
HOPE & HEIDI 10 ye
RINCON 6 0.6

SOURCE: BLM, FEIS Lease Sale 68 (1981)

———————— 0000000 OOOO nee

TABLE 6

Separation and treatment facilities currently handling

nnn
——_ eee

Unit/Field

(OCS platforms)

—_—_——

Dos Cuadras
Field

AY B)C.,
Hillhouse)
Carpinteria
Offshore
Field
(Henry)

Carpinteria
Offshore
Field
(Houchin,
Hogan)

Santa Clara
Unit (Grace)

Santa Clara
Unit (Gilda)
Hueneme
Offshore
Field (Gina)

Facility
location

Rincon,
Ventura
County

La Conchita,
Ventura
County

Carpinteria,
Santa
Barbara
County

Mandalay
Beach,
Ventura
County

Facility
operator

Mobil

Phillips

Chevron

Union

OCS production in Southern California

Current OCS
throughput

Oil:
14,000 bpd
Gas:
12,800,000
efd

Oil:
3,400 bpd
Gas:
1,500,000
efd

Oils:
5,500 bpd
Gas:
12,000,000
efd

Oils:

1,000 bpd
Gas:
250,000 cfd

bpd = barrels per day; cfd = cubic feet per day.

BOURCE: Collins, et al. (1982)

24

Design
capacity

Oil:
95,000 bpd
Gas:
60,000,000
efd

Oil:
27,000 bpd
Gas:
22,000,000
efd

Oil:
38,000 bpd
Gas:
25,000,000
efd

Oil:
36,000 bpd
Gas:
2,000,000
efd

a

TABLE 7 —- MARINE TERMINALS IN SOUTHERN CALIFORNIA

Terminal
County Location Operator Function
Santa Barbara Cojo Bay (Point Union Onloading crude oil
Conception)
Gaviota Getty Onloading crude oil
Elwood Aminoil Onloading crude oil
Carpinteria Chevron Onloading crude oil
Ventura Ventura River Getty Onloading OCS and
other crude oil and
natural gasolines
Ventura Union Onloading OCS and
other crude oil
Mandalay Beach Southern CA. Offloading fuel oil
Edison

—————EREaEa—
a SS

SOURCE: Collins et al., (1982)

25

Much of the crude oil produced in the Santa Barbara Channel
is loaded onto tankers after onshore treatment and transported to
refineries. Table 7 lists the marine terminals currently
handling transshipment of treated crude oil for transportation
via tanker to refineries.

Vessel traffic from the onshore treatment and transshipment
facilities and from Hondo's offshore storage and treatment
facility is not heavy. Statistics for the year ending October
31, 1980, the most recent statistics available, show a total of
132 seagoing vessels calling at these facilities to handle oil
production. Present tanker use actually is less than these
figures indicate due to the completion of two new onshore
pipelines.

The first of these is Chevron's pipeline from Carpinteria in
Santa Barbara County to the Rincon facility in Ventura County.
The 10 inch pipeline is six miles long and has a capacity of
500,000 barrels per month. Oil from platform Grace in the
federal OCS and from state leases is presently transported by the
Pipeline at a rate of 150,000 barrels per month. From Rincon the
oil is transported to Los Angeles area refineries via existing
pipelines. This Chevron pipeline has eliminated the need for
tanker transport of oil from Carpinteria.

A second new pipeline connects Union Oil's new Mandalay
Beach separation and treatment facility with an existing Union
pipeline which runs from Ventura County to Union's Wilmington
refinery. This new 2.5 mile pipeline, which began operating in
December, 1981, has a capacity of about 30,000 barrels per month

and handles production from platforms Gilda and Gina.

26

TABLE 8 : VESSEL ARRIVALS AT SANTA BARBARA CHANNEL MARINE TERMINALS

LOCATION SEAGOING VESSEL ARRIVALS FOR 12 MONTHS
ENDING OCTOBER 31, 1980

Cojo Bay 1

Gaviota 20
Elwood 20
Carpinteria 20
Ventura (Union) 0
Ventura (Getty) 61
Mandalay 10
TOTAL 132

eS oc cc et
SOURCE: U.S. Coast Guard (1981)

27

Crude Oil from Outside the Study Area

Crude oil from Alaska, Indonesia, and elsewhere regularly is
brought into or through the study area as it is transported in
tankers to U.S. refineries.

Alaskan Oil, including that from the North Slope and from
southern Alaska, is delivered to the lower 48 states at a rate of
about 1.6 million barrels a day (Department of the Interior,
1982). Of this total, only about 88,000 barrels is from southern
Alaska, with the remainder coming from fields serviced by the
Trans Alaska Pipeline System (TAPS). TAPS is a 48-inch diameter
line with a design capacity of 2.0 million barrels a day,
although it is currently operating at about three-quarters of
that capacity. TAPS oil, from the 9.6 billion barrel Prudhoe Bay
field and the 1.5 billion barrel Kuparuk field, is loaded into
tankers at a terminal in Valdez, Alaska which can handle four
tankers at one time. The average turnaround time for tankers at
this facility is 24 hours.

About half of the Alaskan crude oil shipments are processed
by west coast refineries. The remainder is sent to east and gulf
coast refineries via the Panama Canal and the recently-opened

Trans-Isthmus pipeline.

28

Refined Products

Refined products are delivered to various facilities within
the study area via tanker. The two most prominent of these
facilities are the Pacific Gas and Electric generating plants at
Morro Bay and at Moss Landing.

The Morro Bay plant uses a ship's mooring consisting of
seven buoys located 4,500 feet offshore in the south end of
Estero Bay. Fuel oil is offloaded from tankers at the mooring
through 305 feet of 16-inch sea hose which is connected to a 24-
inch submarine pipeline. The pipeline has a capacity of 10,000
barrels per-hour. Onshore storage at Morro Bay consists of nine
tanks with a total capacity of 1,836,000 barrels. As of June 1,
1982 there were 1,552,000 barrels of fuel oil stored in these
tanks (Pacific Gas & Electric, 1982). Table 9 shows the number
of vessels using this facility from 1974 to 1981, and the amount
of fuel oil discharged.

The Moss Landing facility also consists of seven mooring
buoys. It is located 3,200 feet offshore in 52 feet of water. A
Single 3,600 foot long, 18-inch pipeline runs from shore to the
mooring, with 300 feet of hose at the end. Nineteen onshore
tanks have a capacity of 5,965,000 barrels. As of June Ve, Ik32
there were 4,582,000 barrels in storage. Table 10 shows the
number of tankers using the facility and the amount of oil

discharged from 1974 to 1981.

29

TABLE 9 : USE OF THE MORRO BAY FUEL OIL OFFLOADING FACILITY

YEAR NO. OF VESSELS AMOUNT OF OIL DISCHARGED BBLS
1974 13 1,930,000
1975 17 2,070,000
1976 35 4,293,000
1977 24 3,193,000
1978 31 3,860,000
1979 36 4,195,336
1980 25 3,345,000
1981 16 2,466,000

SOURCE: PG & E (1982)

TABLE 10: USE OF THE MOSS LANDING FUEL OIL OFFLOADING FACILITY

YEAR NO. OF VESSELS AMOUNT OF OIL DISCHARGED BBLS.
1974 26 4,380,000
1975 28 4,415,000
1976 58 8,132,000
1977 87 13,250,000
1978 30 4,710,000
1979 yy 7,080,000
1980 28 5,490,000
1981 13 3,200,000

SOURCE: PG & E (1982)

Crude Oil and Products to and from Other Ports

Tankers also call at crude oil loading facilities at Estero
Bay and Port San Luis. Chevron operates two crude oil loading
facilities as Estero Bay, and Union operates one at Port San
Luis. At Morro Bay, the Navy and Texaco each operate facilities
for the receipt of refined products. In 1981, annual port calls
at these facilities by tankers totalled 200, most of which were
made by 6 or 7 vessels on repeated trips (USCG, 1982).

At each end of the study area are large harbors, San
Francisco Bay in the north and the Los Angeles/Long Beach complex
in the south. In 1982, total tanker calls at San Francisco Bay
amounted to 992 vessels (Marine Exchange of San Francisco,
1983). Tanker calls at Los Angeles/Long Beach in 1982 totalled

1,381 (Marine Exchange of Los Angeles-Long Beach Harbor, 1983).

3}72

CHAPTER III

Oil Spill Data and Models

The probability and likely trajectory of oil spills in and
near the sea otter range has been a subject of lively discussion
and debate at least since the 1969 Santa Barbara Channel oil
spill from Platform A. The chief topics have been two: the
technique used to predict the number of oil spills per unit of
oil produced or transported; and the sophistication of the models
used to predict the trajectory and effect of postulated spills.

The Minerals Management Service (MMS) has the federal
governmental responsibility for oil spill risk assessment and
modeling. The MMS efforts have been undergoing continued
revision as new information and experience is gathered. They
likewise have been undergoing continual criticism from all
sides. The oil spill risk assessments for lease sales 53 and 68
provide the most recent examples of the MMS risk assessment for
the spill areas, although a new risk assessment for Central and
Northern California will be presented in the Draft Environmental
Impact Statement for lease sale 73, which is expected to be

issued in late February or early March.

38

Oil Spill Rates

The oil spill rates used in the lease sale 53 and 68 risk
assessments were developed for three possible sources (platforms,
pipelines, and tankers). Three possible sizes were used in sale
68 (50-1,000 barrels, 1,000 + barrels, and 10,000 + barrels) with
two sizes (1,000 barrels or less, greater than 1,000 barrels) for
sale 53. Oil spill rates in the MMS (then USGS) model are based
on the assumption that realistic estimates of future spill
frequencies can be based on past OCS experience. This analysis
assumes that spills occur independently of each other as a
Poisson process, and that the spill rate is dependent on the
volume of oil produced or transported.

Accident rates for platforms on the U.S. OCS were derived
from USGS accident files and from USGS production records. For
spills less than 1,000 barrels in the lease sale 53 risk
assessment, records through 1975 were used, they being the same
as used in the risk assessment for the 1975 lease sale 35. (BLM,
1980) For larger spills, records as recent as 1978 were used
with respect to platforms, 1975 for pipelines, and 1973 for
tankers. For lease sale 68, updated records were used, generally
including spill and production rates through 1979 (BLM, 1981).
The lease sale 68 rates, being the more recent and based on more
complete data, are the more meaningful for the present
purposes. Table 11 presents the spill rates used in the lease
sale 68 risk assessment.

The lease sale 53 risk analysis used rates of 1.8 spills

34

TABLE 11
OIL SPILL RATES USED IN THE LEASE SALE 68 RISK ASSESSMENT

SOURCE SPILLS PER BILLION BARRELS

50-1,000 bbl 1,000+ bbl 10,000+ bbl
Platforms 8.42 2.05 0.91
Pipelines 3.43 1.82 0.46
Tankers N/A 3.87 2.32

SOURCE: BLM (1981)

from platforms per billion barrels, 2.3 spills from pipelines per
billion barrels, and 3.9 spills from tankers per billion barrels,
all for spills of greater than 1,000 barrels.

A more recent MMS evaluation of risk, using data through
1980, shows decreased occurrence rates for most accidental spills
(Lanfear & Amstutz, 1983). This evaluation looked only at larger
spills (of 1,000 barrels or more) on the basis that these larger
spills are the ones which are liable to travel long distances and
do serious damage. As shown in Table 12, these rates are
Substantially different than those used in the lease sale 53 and
68 analyses.

The oil spill occurrence rates may be applied to the
estimates of oil reserves in the lease sale areas to provide an
estimate of the number of spills expected from production and
transportation of oil from those areas.

For the lease sale 53 areas, the risked mean undiscovered
recoverable oil resources were 402 million barrels for the Santa
Maria basin and a total of 146 million barrels for the other four
basins to the north. Using the lease sale 53 EIS occurrence
rates, 0.97 platform spills, 1.19 pipeline spills, and 0.13
tanker spills, all over 1,000 barrels, are predicted, assuming
that oil from the Santa Maria and Santa Cruz basins is piped
ashore. If that oil is tankered, the pipeline spills decrease to
0.0 and the tanker spills increase to 2.13 spills. The actual
transportation methods to be used in any northern or central
California basins have not been determined.

The lease sale 68 areas were estimated to contain 63 million

36

TABLE: 12

OIL SPILL RATES DEVELOPED BY MMS IN 1983

SOURCE SPILLS PER BILLION BARRELS

1,000+ bb1 10,000+ bb1
Platforms 60) 0.44
Pipelines a6 On 6i
Tankers Tos 0.65

SOURCE: Lanfear & Amstutz (1983).

barrels for the Santa Barbara Channel and 58 million barrels for
the inner and outer banks. Using the occurrence rates from the
lease sale 68 risk analysis, spills in excess of 1,000 barrels
are estimated to number 0.25 from platforms, 0.23 from pipelines,
and 0.49 from tankers, for a total of about one spill greater
than 1,000 barrels.

Applying the 1983 MMS oil spill rates to the sale 53 and 68
resource estimates substantially lowers the total expected number
of spills for oil produced from tracts involved in these sales.
Table 13 presents these figures along with those based on the
earlier spill rates.

The Western Oil and Gas Association (WOGA) has criticized
the MMS's oil spill occurrence frequencies (Bigham, et al.,
1983). For example, WOGA states that the spill frequency (the
number of spills per unit of oil produced or transported) is not
adjusted for improved safety measures, technology, or intrinsic
system variables such as climate or lease operator. These
criticisms are not new, as review of comments submitted in
response to the lease sale 53 and 68 draft environmental impact
statements reveal. MMS (Lanfear and Samuels, 1983) responds to
such criticisms by pointing out that many of these factors cancel
each other out, and in any event, when there is a substantial
base of experience the effects of these factors will become
statistically apparent and the various hypotheses such as those
advanced by WOGA and others will be statistically proven or
disproven. At the present time, however, the record of the

offshore industry has been sufficiently good that statistical

383

TABLE 13
SUMMARY OF PREDICTED OIL SPILL OCCURRENCE RATES
SPILLS GREATER THAN 1,000 BARRELS - LEASE SALES 53 AND 68

Source

Platform Pipelines Tankers TOTAL
Lease Sale 68 Tracts ele 219 -16 47
Using MMS 1983 Spill Rates
Lease Sale 68 Tracts 525 223 49 97
Using FEIS Spill Rates
Lease Sale 53 Tracts 55 ott 1.26
Using MMS 1983 Spill Rates
(100% Tankering)
Lease Sale 53 Tracts 55) 82 O04 1.41
Using MMS 1983 Spill Rates
(Pipeline-Tanker Mix)
Lease Sale 53 Tracts 97 Crs Bio U
Using FEIS Spill Rates
(100% Tankering)
Lease Sale 53 Tracts 97 1.19 0.13 2.29

Using FEIS Spill Rates
(Pipeline-Tanker Mix)

ie
a

Source: BLM (1980 and 1981)

tests of various hypotheses are very difficult and clear
superiority of various factors in determining spill rates
impossible to demonstrate.

Once spill frequencies are known, spill probabilities can be
calculated by assuming a Poisson distribution using volume of oil
produced or handled as the exposure variable. This is based on
the assumption that all spills occur randomly, that the number of
spills in an interval of time is proportional to the size of the
interval, and that a very small interval may be identified so
that no more than one spill is possible in any interval of that
size.

The chief criticism of the MMS model in this regard is the
exposure variable - amount of oil produced or handled (Bigham et
al). Variables such as wells drilled, pipeline-kilometer, rig
year, and others have been suggested, but none have been
statistically verified. The MMS notes that in any event most of
these suggested exposure variables are factors of volume
(Langfear & Samuels, 1983).

For lease sale 68, the probability of one or more spills of
1,000 barrels or greater was calculated to be 0.67, and 0.39 for
one or more spills of 10,000 barrels or more (BLM, 1981). For
lease sale 53, these figures are 0.62 and 0.37 respectively
assuming a pipeline-tanker transportation mix, and 0.63 and 0.37

assuming 100% tankering (BLM, 1980).

40

Oil Spill Trajectories

The MMS trajectory simulation process results in a large
number of hypothetical oil spill trajectories that collectively
represent both the general trend and the variability of winds and
currents. The trajectory model looks only at the route of the
center of the mass of spilled oil. No explicit attempt is made
to account for weathering effects or other factors which may
affect the impact of the oil spill on the marine life and
habitats with which it may come in contact. This is appropriate
since all MMS is attempting to do is model trajectories, not
effects.

The modeling is based on selection of representative
platform spill sites as well as tanker and pipeline routes and
existing leases. Figure 2, from the lease sale 53 trajectory
analysis, shows the subdivisions of the proposed leases into
production spill launch areas. Figure 3 likewise shows
subdivisions of existing leases in the lease sale 53 analysis,
and Figure 4 shows transportation route segments. Figure 5 shows
the coastline divided into target segments. Figure 6 shows
special oil spill "targets" selected for lease sale 53.

In the lease sale 53 analysis, 500 spills were simulated for
each production spill launch area (proposed and existing lease
subdivisions) and transportation route segment for each of four
seasons. In the lease sale 68 analysis, 50 simulations were run

for each production spill launch area and 500 for each

4]

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Figure 2: Map showing subdivisions of the proposed leases for Central and
Northern Californta OCS Lease Sale 53,

Source: BLM (1980).

EEL RIVER

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CA bean

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Figure 3: .:ap showing the subdivisions of the existi i
the study area. sanomieeses son
Source: BLM (1980).

43

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aa:

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Map showing the transportation route segments (T] - 731); polygons

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represent proposed and existing lease tracts.

BLM (1980).

Figure 4:

Source:

44

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3-2-2 4 st +

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Figure 5: Map showing the division of the shoreline of Centra] and Northern
California into segments of approximately equal length.
Source: BLM (1980).

AS

4 5 3 a 5 g £ z
Figure 6: Map showing the locations of 14 targets, Northern and Central

California OCS Lease Sale 53: cross hatching indicates area}
extent of targets.

Source: BLM (1980).

46

transportation route segment. Spills along transportation routes
are evenly spaced.

Once a spill is "launched", its trajectory is determined by
a series of determinations of wind vectors and current vectors.
In the lease sale 53 and 68 analysis, the current vector was
determined by the spill's location and the simulated month,
generally based on CALCOFI geostrophic flow, except in shallow
waters (less than 600 feet) where specialized studies or high
altitude or satellite photos were used. Interestingly, the
CALCOFI drift bottle studies shows that general trends
notwithstanding, currents are capable of carrying objects or
substances to the north in any month. See Appendix D for charts
of selected release and recovery records from the CALCOFI
studies. The wind vector was determined by taking the date from
wind stations having hourly recorded data continuously for at
least a five-year period, constructing wind transition matrix
with elements consisting of probabilities that a particular wind
direction and speed will be succeeded by another wind direction
and speed in the next time step, and sampling that matrix.
Adjustments are made for Coreolis effects.

Once the targets, winds, currents, and launch points are
known, oil spills trajectories are simulated. By examining data
from the trajectory simulations, the MMS model then calculates
the probability that, if an oil spill occurs at a given launch
point, it will contact a particular target within 3, 10 or 30
days. These three time periods were chosen to represent various

milestones during an oil spill:

47

3 days - Most toxie fractions of the oil will have
evaporated or dissolved.

10 days - Sufficient time for clean up measures to have
been employed.

30 days - The oil spill will not be detectable if it
is still at sea

Note that the model treats all three of these points in time the
same. No assumptions change after three or ten days since these
are merely the points at which "snapshots" of the spill
trajectories are made.

The probability of a spill reaching a particular target is
termed a "conditional probability," the condition being that a
spill has occurred.

The conditional probability of a spill hitting a target,
multiplied by the probability of spill of a given size occurring,
produces the probability that a spill will occur and hit a
target. The lease sale 53 oil spill risk analysis calculated the
probability of oil spills reaching the sea otter range from
proposed sale 53 tracts as shown in Table 14. The maximum
probability there is 22 percent, based on the combined effect of
sale 53 tracts plus projected oil transport activities, and
looking at 30 day impact time. Shorter impact times reduce the
probability of contact to as little as six percent.

As stated above, MMS uses 3, 10 and 30 day points of

reference in oil spill trajectory modeling. In their oil spill

48

TABLE 14

PROBABILTY OF OIL SPILL IMPACT ON SEA OTTER RANGE

3 DAYS 10 DAYS 30 DAYS
Assuming Pipeline-Tanker Mix .09 . 16 S22
Assuming 100% Tankering .06 sald as

SOURCE: BLM, FEIS SALE 53 (1980).

contingency plans, the oil industry typically uses much shorter
periods. For example, Shell Oil Company, in its oil spill
contingency plan for OCS lease no. P-0435 in the Santa Maria
basin terminates its oil spill trajectory figures after a maximum
Ofc mnours CShelll Oil sCo., 1982). ARCO, inwits oi] spill
contingency plan for the Santa Maria basin terminated its
trajectories after a maximum of 144 hours (ARCO, 1982). In both
eases, trajectories were based on vectors resulting from
combining wind and current vectors, although in a simpler method
than that used by MMS, based on monthly averages. Figure 7 is
typical of the ARCO and Shell trajectory modeling.

An interesting empirical illustration of a spill trajectory
is presented by the February 12, 1978 lumber spill which occurred
40 km off Point Sur in central California. Within 30 days of the
spill, lumber beached itself along two sections of coastline, one
of about 42 km around Point Sur, and one of 120 km between Cape
San Martin and Diablo Canyon. Patches of lumber were sighted
elsewhere, both on the beach and at sea, reaching as far south as
San Miguel Island in the western end of the Santa Barbara
Channel (VanBlaricom & Jameson, 1982).

The authors of the lumber spill review related that spill to
an oil spill. After noting that spilled oil weathers differently
depending on type (e.g. crude oil is more persistent than light
refined oils), they observed that a spill from a blowout or a
large tanker grounding would pose particular dangers to the sea
otters. Oil from a prolonged spill of that type, they noted,

would be carried toward shore and then along shore by the

50

prevailing winds. This lumber spill seems to show that Spill

transport is more complex than either the USGS or oil company

analyses indicate.

Byil

121°

Grover City

e
Point Sal _ Santa Maria

Purisima Point

Surf
24 Point Arguello
Jalama
12 t
48 Point

Conception

CLS

San Miguel Island

Figure 7: Typical ARCO Trajectory Model
Source: ARCO (1982).

10

nautical miles

1” = approximately

11 nautical miles

LEGEND

Spill Movement
——> Oirection in

12 Hours

Gaviota

Coal Oil Point

Santa
Cruz
Island

bk 34°
Santa Rosa
Island

35°

CHAPTER IV

Oil Spill Response

The response to oil spills is, after prevention, the most
important human-related factor in the risk of oil spills. The
better the response, in terms of timeliness and effectiveness,
the less the risk to the sea otters and their habitat.

Prevention is accomplished through the use of blow-out
preventers, well-maintained state-of-the-art equipment, well-
trained personnel, well-engineered drilling programs, adhered-to
operational procedures and good housekeeping practices. Oil
spill response is optimized through preparation.

Pacific Region OCS Order No. 7 requires that each leasee
Maintain or have available to it, pollution control materials and
equipment. Specifically, the order requires "containment booms,
skimming apparatus, cleanup materials, chemical agents, and other
items needed for the existing climactic conditions." (P.R. OCS
Order No. 7, Section 3.1).

The Order does not specify exactly what equipment, other
than general types, should be available for use. The Pacific OCS
Region Oil Spill Contingency Plan Guidelines (July 29, 1982),
however, require that oil spill response capabilities be "state-
of-the-art." It goes on to define "state-of-the-art", based on

R&D studies, observations, and experiences" as capable of

De)

operating in 8-10 foot seas and 20 knot winds with deployment
accomplished in 5-6 foot seas. The guidelines also note that
certain local conditions, such as high energy sea states with
Short wave lengths, may not allow these operational criteria to
be met.

The exploration plans and oil spill contingency plans
prepared by the individual leasees contain listings of the
materials and equipment carried on board the drilling rigs or on
standby supports vessels (required to be within 15 minutes of the
rigs.) Table 15, from Chevron USA's exploration plan for OCS
leases P-0451, P-0452, and P-0453, in the Santa Maria Basin
(February 23, 1982), provides a typical list of materials and
equipment.

A second list of equipment and materials held on-site is
provided by Union Oil Company of California's Oil Spill
Contingency Plan for exploration activities on lease P-0203,
located at the eastern end of the Santa Barbara Channel. This
list is presented here in Table 16.

As a general rule, the onsite spill containment and cleanup
equipment and materials are adequate for use with only small
spills. Union Oil Company's equipment listed in Table 16 is
described in the Oil Spill Contingency Plan as being capable of
containing and cleaning up spills involving up to 100 barrels of
oil. For spills of up to 10 barrels, the onsite equipment is the
sole equipment used. For larger spills, the onsite equipment is
deployed as part of the initial response effort.

In the event of large spills, equipment and materials are

54

NODE ae Nila do oe Oe A ————————————EE
Table 15: Chevron USA Oil Spill Equipment and Materials Inventory

Cee EEE

a a

1500 ft. - OSD 3-12-24-050-6 oil containment Boom 12" Freeboard x 24" Draft
1 - 1977 Model 10011 Skim Skimmer Inc. with hoses, connectors & floats

2 - 1200 Gal Kepner Sea Containers (60 bbl. equivalent)

240 ft. - 3M or Conwed Sorbent Boom

1 Box - 3M or Conwed Sorbent Pads 18"x18"

3 Drums - Corexit 9527 Dispersant

1 Drum - Shell Oil Herder Surface Collecting Agent

Source: Chevron USA (1982).

55

Table 16: Union Oil Company Spill Equipment and Materials Inventory

On Drilling Vessel
5-10 Bales - 3M Sorbent Pads 18" x 18"
500 Ft. - 3M Sorbent Boom
2 Drums - Corexit 9527 Dispersant
10 Drums - Shell Oil Herder

2 - Backpack Sprayers for Chemical Agent Application

On Standby Vessel
1500 Ft. - Mode 4300 Whitaker Expandi Boom, 18" freeboard x 25" draft

1 - Walosep W3 Oil Recovery System (Skimmer), including Oil/Water
Separator

2 - 5000 gallon capacity sea containers

2 - Sea Anchors

SOURCE: Union Oil Company of California (1982).

available from a variety of sources. Most leasees in the study
area are members of oil spill cooperatives which maintain
substantial amounts of equipment and materials. The oil spill
cooperatives respond to any oil spill call, free for members (who
underwrite the cooperative) and at a fee for non-members.

Two oil spill cooperatives operate within the study area.
The larger of these, Clean Seas, Inc., is based in Santa Barbara
and is responsible for the Santa Barbara Channel and the Central
California coast as far north as Cape San Martin. Clean Bay,
Inc., based in Concord on San Francisco Bay, operates to the
north.

In addition to these two cooperatives, equipment and
Materials are available from other sources including other
cooperatives to the north and south, other platforms and oil
company facilities, government agencies, and private contractors.

The Clean Seas, Inc. inventory and structure is the most
elaborate and, given the present limits to drilling and
production activity, the most important with respect to offshore
oil operations in the study area. Table 17 lists the sites where
Clean Seas facilities and equipment are located. Appendix E
fully lists and describes the equipment and materials maintained
by Clean Seas and where each item is located. Also in Appendix E
is the Clean Bay equipment inventory.

Clean Seas presently operates two vessels dedicated solely
to oil spill containment and clean up. Mr. Clean is a 136 foot
diesel powered boat capable of a speed of 12 knots. It is based

at Santa Barbara and carries a skimmer, various containment

57

TABLE 17: Location of Clean Seas Equipment

Carpinteria
Gaviota

Avila

Ventura

Santa Barbara
Point Dume
Morro Bay

Point Mugu

SOURCE: Union Oil Company of California (1982)

58

booms, absorbents, and dispersants. Mr. Clean II, a 130 foot
boat, is based at Port San Luis and carries similar equipment and
materials.

Clean Seas also stores equipment and materials on shore in
eight mobile oil spill response vans stationed at Point Dume,
Port Hueneme, Ventura, Carpinteria, Santa Barbara, Gaviota,
Avila, and Morro Bay. These are 40 foot enclosed trailer vans
and are stocked with booms, sorbents, small skimmers, and
miscellaneous cleanup equipment. Figure 8 shows the locations of
the vans and the Mr. Clean and Mr. Clean II.

Once notified, Clean Seas mobilizes its equipment in the
time necessary to allow the personnel to reach the equipment
storage sites. This is nominally two hours, although it may be
less during normal working hours. All Clean Seas equipment is on
24 hour standby.

In most open water spill situations, the first equipment to
be sent to the site would be that onboard one of the other of the
Mr. Cleans, depending on the location. Figure 9 shows vessel
travel times to potential spill sites in the Santa Barbara
Channel. Figure 10 shows the travel times to potential spill
sites in the Santa Maria basin. Note that this area is only the
extreme southern part of the otter range.

Uphore in eight mobile oil spill response vans stationed at
Point Dume, Port Hueneme, Ventura, Carpinteria, Santa Barbara,
Gaviota, Avila, and Morro Bay. These are 40 foot enclosed
trailer vans and are stocked with booms, sorbents, small

skimmers, to the beginning of oil recovery is estimated to be 2.5

59

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hours, plus travel time.

Other equipment is stored at a variety of locations along
the west coast. Staging areas for transport of equipment to
spill sites have been designated at Santa Barbara and Port San
Luis. Travel and response times for this equipment to the
staging areas via overland routes in given in Table 18. Once the
equipment reaches the staging area it will be transported by boat
or helicopter to the spill site. The travel times from the
staging areas to the spill sites by boat are those shown in
Figures 9 and 10. Helicopter travel times are shown in Figure 11
for spills in the Santa Barbara Channel and in the Santa Maria
Basin. Again, this is only the extreme southern end of the otter
range. Response to more northerly areas, of course, would be
longer.

In the event that an oil spill threatens an area along the
mainland coastline, Clean Seas' mobile oil spill response vans
will be activated. Total response times to areas within Clean
Seas' current operational area, i.e., the Santa Barbara Channel
and the area south of Morro Bay, including mobilization, travel,
and equipment deployment, range from two to five hours, with
mobilization and travel times being dependent on traffic
conditions, types of roads, and weather. Importantly, the
landslides accompanying the recent winter storms in California
cut the main coastal roads in many places. Some of these cuts
will take many months to repair. These coastal roads are the

main routes of access for the vans, giving significance to a road

blockage factor in response times.

63

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The California Coastal Commission (CCC) is presently
conducting a study of oil spill cooperatives along the California
coast in order to evaluate their capabilities and assure that
they are providing the maximum feasible oil spill response. The
CCC's staff issued a preliminary draft report on Clean Seas, Inc.
in April 1981.

The CCC staff concluded that an oil spill can never be
totally contained and cleaned up regardless of the technology
used. Clean Seas has developed a reasonable response capability
for small to medium spills, the staff said (California Coastal
Commission, 1981).

The CCC staff also concluded that Clean Seas estimates of
response time and efficiencies of mechanical and chemical spill
control methods are optimistic. In particular, the staff felt
that staging facilities at the western end of the Santa Barbara
Channel and the Santa Maria Basin needed improvement. The staff
also felt that yearly oil spill equipment deployment drills
should be run, although it praised the Clean Seas personnel
training program and found the Clean Seas oil spill response
Manual adequate (California Coastal Commission, 1981).

In an appendix to the report were two memoranda on oil spill
response drills conducted on offshore drilling rigs in late
1980. The first of these involved a delay in getting the standby
oil spill vessel underway. Once the boat was underway (one hour
and fifteen minutes after the drill began, although it was
anchored only several hundred yards from the drill rig) boom

deployment and other actions went smoothly. The second drill was

66

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67

"conducted in an exceptionally efficient and rapid manner," with
the standby vessel coming alongside the drilling vessel from its
nearby anchorage in 17 minutes. Within 25 minute of the start of
the drill, the 1500 foot boom was in the water in a proper
configuration and the oil skimmer over the side.

The CCC staff also noted that even if equipment is properly
and timely deployed it may not be capable of containing and
cleaning up a spill except in calm seas under ideal circum-
stances. In rough weather, high winds can cause the boom to lay
over, allowing oil to splash out. In currents stronger than 0.75
knots oil may be lost under the boom due to entrainment of oil
droplets in the water column. And of course in really severe
weather the boom may break apart (California Coastal Commission,
1981).

Time may have changed the situation which the CCC
evaluated. Clean Seas has purchased additional equipment and
materials since the CCC study was undertaken, including the Mr.
Clean II. At the time of the CCC study, the original Mr. Clean
had only recently been purchased. The state of the oil spill

response art itself, however, has not changed.

68

CHAPTER V

The Situation in 1977

The Southern Sea Otter was placed on the threatened species
list in 1977 primarily because of the perceived menace of oil
spills. As might be expected, the situation regarding the risk
of oil spills was different in 1977 than it is now. The Trans
Alaska Pipeline System had not yet begun to send North Slope oil
to the waiting tankers at Valdez. OCS lease sale 35 had been
held two years before and sale 48 was coming up two years
hence. In this chapter, these and other factors of oil spill

risk will be examined from the perspective of 1977.

Offshore Oil Development

Federal Offshore oil and gas operations in 1977 were limited
to southern California. A sale had been held for tracts in
central and northern California in 1963, but by 1967 all of those
tracts had been relinquished. By the end of 1977, a total of 356
wells had been drilled in southern California, of which 198 were
active producers and 20 were shut-in producers. A total of 121
wells had been plugged and abandoned, and 5 wells were actively

drilling. During 1977, 58 new wells were started and 26

69

completed. Thirty-two were plugged and abandoned (U.S.
Department of the Interior, 1981).

Through the end of 1977, oil production from the California
OCS amounted to 167,897,088 barrels, on which $100,477,752 in
royalties had been paid. Gas production totaled 67,156,731
thousand cubic feet, with royalties amounting to $3,169,709
(Mineral Management Service, 1981). Production in 1977 came to
12,267,598 barrels of oil (worth $58,205,617 with a royalty value
of $9,707,115) and 3,289,963 thousand cubic feet of gas (worth
$1,699,845 with a royalty value of $283,381).

Production from state leases in 1977 amounted to 47,930,000
barrels of oil worth $227,667,500 and 11,669,000 thousand cubic
feet of gas, worth $6,067,880.

In 1977, there were seven platforms in place on the
California OCS: Hogan, Houchin, Hondo, Hillhouse, A,B, and C. Of
these, all except Hondo were producing. Controversies over
transportation schemes prevented initiation of production from
Hondo until 1981. The eight platforms and six subsea completions
currently in place on state leases have been in place since

before 1977.
Tanker Traffic in the Study Area

Tanker traffic in the study area in 1977 was somewhat
differently distributed than in 1982. For example, at the Moss

Landing PG & E plant, the 1977 number of tanker arrivals was 87

compared to less than 30 per year in the early 1980's. Traffic

70

at the Morro Bay PG & E plant, in contrast, has remained fairly
constant, with the 1977 arrivals numbering 24 vessels (PG & E,
1982).

Other tanker ports in the study area had the following
arrival rates in 1976 (USAF, 1977):

Los Angeles/Long Beach - 1220 tankers

Port Hueneme - 54 tankers
Carpinteria - 27 tankers
Port San Luis - 96 tankers
Estero Bay - 179 tankers

&

Additionally, 1217 tankers called at San Francisco Bay in 1977
(Sabella Moreno, Corps of Engineers, pers. comm. March 24, 1983).

At the time of the sea otter listing in 1977, oil and
natural gas from Alaska was very much in the public mind and
those of oil industry and government planners. Alaskan oil and
gas was seen as making significant contributions to the overall
tanker traffic in the region.

In 1977, the State of California's Office of Planning &
Research was projecting that crude oil from Valdez, Alaska would
be tankered to Long Beach and other pipelined to Texas and
California refineries (Office of Planning & Research, 1977). OPR
used figures of 1.1 tanker trips per day to the study area, using
ships with a mean size of 136,825 DWT, carrying a total of 1.2
million barrels a day. This would have amounted to 400 tankers

per year.

The proposed Pt. Conception LNG terminal was seen in 1977 as

Dal

a substantial contributor to vessel traffic in the study area.
Office of Planning and Research estimates showed that from 3.5 to
4.6 trips a day were made to the terminal and to other southern
California harbors (Oxnard and Los Angeles/Long Beach). Four
billion cubic feet a day of LNG was projected for each of the

three terminals (Office of Planning & Research, 1977).

Oil Spill Risk

The oil spill risk analysis for OCS Lease Sale 48 was
prepared in 1978. It gives some idea of the perceived threat of
oil spills at the time the sea otter was listed, despite the fact
that it came over a year after the listing took place.

In the sale 48 analysis, existing and proposed leases were
confined to southern California. Transportation routes extended
from this area to include coastwise traffic from and to San
Francisco, traffic from Alaska, and traffic from Southeast Asia.

Proprietary USGS data on oil reserve estimates were used to
calculate expected platform, pipeline, and tanker spill
frequencies and probabilities for spills greater than 1,000
barrels. The results of these calculations are shown in Table
19. The probability of one or more spills occurring and hitting
the sea otter range, assuming tanker transportation, was no
higher than eight percent, and this probability level occurred
only with 30 and 60 days time periods (USGS, 1978). In all
eases, the most likely number of spills predicted to occur and

impact the sea otter range was 0. All these predictions were

V2

TABLE 19

Oilspill probability estimates for spills
greater than 1,000 barrels in the
Southern California area

A. Tanker Transportation

Proposed Leases Existing Leases Both
Expected Number | 05 WAG
Probability of at .98 * *

least one spill

B. Mixed Transportation

Proposed Leases Existing Leases Both
Expected Numer 5.0 9.3 14.2
Probability of at 99 * *

least one spill

C. Platform Spills Alone

Proposed Leases Existing Leases Both
Expected Number tos 2.4 3.7
Probability of at 5 1 .88 96

least one spill

———— a ee eee
a

* Greater than 0.995

SOURCE: USGS (1978)

based on spill rates of 1.8 platform spills per billion barrels
produced, 2.3 pipeline spills per billion barrels. Applying
these rates to the then-estimated reserves in state leases
resulted in an estimated 0.0868 spills of 1,000 barrels or more
(BLM, FEIS Lease Sale 48, 1978).

Recent work by MMS (Lanfear and Amstutz, 1983) shows that
oil spill rates were decreasing beginning in 1974, and could have
been statistically discernable by 1978. This was not noticed,
however, and the oil spill risks as stated in the 1978 lease sale

48 oil spill risk assessment were overstated.

Oil Spill Response

One measure of oil spill response capability is the
availability of equipment and materials for containing anad
cleaning up oil spills. In measuring this capability, one should
look at two aspects of availability: equipment and materials at
the well site, and equipment and materials at the nearest oil
Spill cooperative.

Table 20 lists equipment described by Shell Oil Company in
December 1976 as being aboard its drilling unit assigned to
exploratory work in the lease sale 35 area (Shell Oil Co.,

1976). Table 21 lists the Clean Seas, Ine. inventory of

equipment as of March 1976.

74

TABLE 20
OIL SPILL PREVENTION, CONTAINMENT AND RETRIEVAL
Equipment Aboard the Drilling Unit

A. All blowout prevention equipment listed in Final OCS Order,
Drilling Procedure, effective May 1, 1976, U.S. Geological Survey.

B. Curbs, gutters, drains, and drip pans properly designed and placed
to collect contaminants from the deck areas and prevent them from
discharging into ocean waters.

C. A Vikoma Seapack fast deployment containment system with 1600 feet
of boom.
D. A Vikoma Komara Miniskimmer capable of recovering 70 barrels per

hour of crude or 14 barrels per hour of diesel oil.

IG A Workboat on stand-by service with the rig at all times.

F. Ten bales of 3M type 156 Sorbent Pads 18" x 18".

G. Two bales of 3M type 1070 Sorbent Boom (five 8-foot booms per
bale).

lag Two 55-gallon drums of Shell Oil Herder (8) collecting agent.

igs Ten 55-gallon drums of Corexit 7664 dispersant.

J. Spray application equipment.

K. Two pillow tanks, 1200 gallons each, Sea Containers.

ling Communications equipment as described in the Appendix.

ey

SOURCE: > Shell O72" Con, 211976

TS

TABLE 21

CLEAN SEAS, INC. -— INVENTORY OF EQUIPMENT
(as of March 1976)

Containment - Ocean Protection Booms

1 - 2000' Bottom Tension Boom
2 - 1600' Vikoma Sea Pack and Boom

Containment - Harbor Protection Booms

2000' Medium Duty Boom

2000' Light Duty Boom

1210' Goodyear Sea Sentury Medium Boom
1700' Expanding Medium Boom

Recovery

- CSI Skimmer System

- Sea Dragon Skimmer

- Mark II Skimmers

- Exxon Floating Weir Skimmers

Acme 39T Gasoline/Air Pump

- Acme 51T Gasoline/Air Pump

- Tide-Mar VII Barge

- Air-Driven Pumps

- Floating Storage Bags (two 500 gal., two 1200 gal.)
- Oil Mop MK-11-9

eS FM @ = = WN > =
I

Miscellaneous Absorbants and Chemicals

Large inventory of absorbants, sweeps, blankets, booms, rugs,
Shell Oil Herder.

Equipment

- Work Boat (19' Skiff)

- 2 1/2 -ton Truck

40' Enclosed Trailer Vans
- Compressor (600 CFM Rotary)

= —-= =
i}

SOURCE: Shell Oil Co., 1976.

76

CHAPTER VI

The Situation Expected in 1988

Just as the Fish and Wildlife Service in 1977 looked forward
at such things as Alaskan oil and natural gas, decision makers
today should look forward over the next five years and consider
the risk of oil spills that sea otters will be facing between now

and 1988.

Offshore Oil Development

Big changes will come to the study area in terms of offshore
oil development and all that accompanies it. The OCS tracts
leased in sales 53, 68 and 73 will undergo much of their
exploration phase and development phase and can be expected to be
in the initial stages of production. Tables 22, 23 and 23A show
the expected drilling schedules from sales 53, 68 and 73 respec-
tively.

Lease sale 53 is likely to bring about the most significant
changes in the OCS of the study area by 1988. Major oil finds
from the area announced by Chevron USA at Point Arguello (Oil &
Gas Journal, Nov. 16, 1981 and Oct. 25, 1982), Texaco at Point

Conception (Oil & Gas Journal, June 28, 1982), Union Oil Company

Ud

TABLE 22
LEASE SALE 53

Santa Maria Basin Development Timetable
(Low - Most Probable - High Resource Estimates)

eee—e—eeeeeeeEeeeeeeEeEe—————————————————————— OO EEE EEE EEE EEE SE eet

Exploratory Delineation Development
Wells Wells? Wells Platforms Subsea?

ng
———OOOOOeeeeeeee OO SO ee

1961 85 Hes

1982 5- 6- 8 Ne G40

1983 3- 5- 6 6-12-14

198N es 2= 3= 3 Je Sod

1985 ©5 Ve je gia ha)

1986 O- 3- 6 We 1S 16 Bez RCE 2c

1987 05 Oo 3 35- 63- 72 } ee ge

1988 2g= 62 =) lnl6 Tog om Oats
1989 30- 69- 115 Bese ese Me! O=0=0=
1990 30- 64- 88 0 o.2 2 Oat t=
1991 5- 46- 66 OS 062 O01
1992 O- 9- 40

1993 0s 5 ©

Total 13-19-23 16-33-52 137-351-523 ff oS) 20 O=2=3

@These are sometimes also termed exploratory wells.

Dsubsea or floating production system.

Cone of which is an offshore storage and loading facility.
One of which is an alternate gas processing platform.

SOURCE: BLM, Lease Sale 53 FEIS

78

TABLE 23
LEASE SALE 68
Santa Barbara Channel

Exploratory Delineation Platforms Subsea e
Wells Wells Wells Platforms Completions
1981
1982 1-3-5
1983 2-9-16 2-6-9
1984 3-12-21 3-8-13
1985 3-10-17 3-10-16
1986 1-6-10 5-16-25
1987 2-8-12 3-9-18 1-1-1
1988 5-13-24 124
1989 4-12-23 1%
1990 4-23-23 0-0-1
1991 1465111 02024
1992 0-0-0-
1993
1994
1995
1996
Total 10-40-69 15-48-75 17-52-99 1-2-3 0-0-2
INNER BANKS AND BASINS
Exploratory Delineation Platforms Subsea
Wells Wells Wells Platforms Completions

T9861 aa hat og eae
1982 (STE

1983 2a
1984 2B
1985 dose?
1986 1-4

1987 2-9-19 1
1988 Hoi7e34 0
1989 2-8-16 0
1990 0
1991 0
1992

1993

1994

1995

1996

Total 5-10-55 7-19-70 8-34-69 1-2*-3% 0-0-2
*Deep Water

SOURCE: BLM (1981)
v9)

TABLE 23A
LEASE SALE 73
Santa Maria Basin Development Timetable
(Most Likely-Conditional Mean Resource Estimates)

ML CM ML CM ML CM ML CM ML CM
Year Exploration Delineation Development Platform Subsea
well well well Completion
1983 3 is
1984 4 22 3 8
1985 3 VI 4 12
1986 2 10 2 9
1987 v4 4 26 2
1988 4 3 14 76 2 5
1989 2 1 Mie) 124 2 6
1990 2 1 64 144 1 5 2]
1991 2 1 28 131 4
1992 1 1 115 4
1993 91 2
1994 55 1
1995 20
1996 1
1997 5 1
1998 if
1999 5
Total 12 80 9 40 155 800 5 30 0 2

Ten Year Lease

SOURCE: Minerals Management Service. 1983.
Lease Sale 73 DEIS.

80

of California at Point Pendernales (Oil & Gas Journal, Jan. 24,
1983), and Oxy Petroleum Ine. at Point Sal (Oil & Gas Journal,
Feb. 7, 1983), will bring quick development to the area described
as the hottest prospect since Prudhoe Bay on Alaska's North
Slope.

News reports of Chevron USA's and Texaco's development plans
indicate that these plans are already well underway. Chevron USA
has let a contract for a platform to be erected in mid-1985 on
its Santa Maria basin strike, the first of what could be four
Chevron platforms on this field producing as much as 100,000 to
150,000 barrels of oil per day (Oil & Gas Journal, Oct. 4,

1982). Texaco has also let a platform contract for its
discovery, one of possibly two yielding perhaps 100,000 barrels a
day by 1986. The Texaco platform is expected to be installed
before the end of 1985 with production beginning a few months
later. Exploration continues in the Santa Maria basin at a brisk
pace with 40 or more exploratory wells to be drilled this year
alone and with rumors of additional discoveries abounding (Oil &
Gas Journal, Jan. 24, 1983).

Adjacent state waters also hold the prospect of substantial
hydrocarbon exploration and development inthe next five years.
The California State Lands Commission has taken initial steps
toward a sale of 40,000 acres of oil rights in eight tracts

between Point Conception and Point Arguello. This would be the

81

Y

first issuance of state oil and gas leases since 1968. The sale
is expected to take place by the end of 1983. The State Lands
Commission has estimated that total undiscovered hydrocarbon
resources in the eight tracts amount to 274 million barrels of
oil and 219 billion cubie feet of gas at 5 percent probability,
153 million barrels and 117 billion cubic feet at 50 percent
probability, and 63 million barrels and 55 billion cubic feet at
95 percent probability (Oil & Gas Journal, Jan. 3, 1983).

Additional development is expected in state waters in the
Santa Barbara Channel. The South Elwood offshore field will be
further developed by ARCO using a two platform complex expected
to double the current output of the field to 20,000 barrels per
day. Other operators are also seeking permission to undertake
exploration in the Channel's state waters, including Texaco,
Phillips, Chevron, Shell and Union (Oil & Gas Journal, Oct. 4,
1982).

In the Channel's federal waters, further development is
planned by Exxon at the Santa Ynez Unit on the Hondo, Pescado,
and Secate fields. Reserves for these three fields are estimated
to total 400 million barrels of oil and 700 billion cubic feet of
gas. Two to four additional platforms are anticipated, with two
of them, Hondo B and a Pescado platform in over 1,000 feet of
water, possibly exceeding the U.S. water depth record.

Production from the Unit is expected to rise from its present

82

40,000 barrels per day to 125,000 barrels of oil per day and 135
million cubic feet of gas per day (Oil & Gas Journal, Nov. 22,
1982). Exploration and development of other existing leases will
likely go ahead between now and 1988.

More lease sales in the federal waters of the study area are
scheduled for the next five years. Lease sale 73, in central and
northern California, is slated for late 1983. Sale number 80, a
southern California sale, is set for early 1984. Number 91,
central and northern California is scheduled for late 1985, and

number 95, southern California, for early 1986.
Transportation

The future transportation situation in the study area is
uncertain. The changing infrastructure for oil transport,
coupled with the range of options open for future production
makes prediction of transportation methods and rates a risky
business.

The greatest impact on transportation of oil in the study
area will come from the new Santa Maria basin discoveries.
Exactly how oil from those finds will be transported is unknown
at this time, although it will probably be moved ashore initially
by pipeline (Oil & Gas Journal, Jan. 17, 1983). Once ashore, the

oil may be treated and then reloaded on tankers for transport to

83

refineries, or new pipelines may be built to take it to
refineries overland. Much of the Santa Maria basin crude is
unsuitable for existing southern California refineries and so may
need to be transported to San Francisco Bay area refineries or to
out of state refineries. If the San Francisco option is pursued
via tankers, this would expose the entire sea otter range to the
possibility of spills from these tankers. Initial production
from the Santa Maria basin will amount to more than 200,000
barrels a day from the Chevron and Texaco finds, plus whatever
oil is produced from the other finds in the area.

Several proposals are pending for expanded marine terminals
in the Santa Barbara Channel. Getty proposes to expand its
Gaviota terminal from its present 50,000 barrels per day capacity
to 300,000 barrels per day, with an initial storage capacity of
one million barrels. Storage capacity would eventually be
increased to 2 million barrels (Oil & Gas Journal, Jan. 17,
1983). The terminal would include a mooring facility for crude
oil tankers, and is intended to treat, separate, and store
production from recent and anticipated discoveries in the Santa
Barbara Channel and Santa Maria basin.

Exxon proposes a terminal at Las Flores Canyon to handle the
increased production from the Santa Ynez Unit. Capacities are
set to be 125,000 barrels per day of oil and 135 million cubic

feet of gas per day. Both terminals are expected to be on-line

84

by 1986.

Chevron also proposes a Gaviota terminal, with a 200,000
barrel per day capacity, with the intention of handling oil from
the Santa Maria basin finds. Apparently either the Getty or the
Chevron proposals will be approved, but not both. Aminoil
proposes to expand its Coal Oil Point marine terminal from a
capacity of 30,000 barrels per day to 80,000 barrels per day.

The State Lands Commission estimates that the 63,000 barrels
per day peak production from the Point Arguello-Point Conception
area might require as many as 10 tanker calls a month (State
Lands Commission, 1982).

Other influences on oil transportation within the study area
come from outside it, especially from Alaska. The Prudhoe Bay
field is expected to begin its decline during 1985-87, reducing
the amoung of oil being sent south via TAPS and the tankers from
Valdez. Offsetting this decrease, however, will be an increase
in production from the nearby Kuparuk field, from present levels
of less than 100,000 barrels per day to about 250,000 barrels per
day by 1989. In addition to the 4 to 5 billion barrel reserves
at Kuparuk, of which about 1.25 billion barrels are thought to be
recoverable (compared with 23 billion barrels and 13 billion
barrels respectively for Prudhoe Bay), Kuparuk holds 18-40
billion barrels of heavy oil that ARCO may develop in the future
(Oil & Gas Journal, July 12, 1982).

85

The tracts leased offshore in the 1982 OCS lease sale 71 in
the Beaufort Sea could add as much as 100,000 barrels per day to
North Slope production by 1988. Conoco's Milne Point unit could
add another 50,000 barrels per day. Thus, these fields, plus the
Kuparuk field could keep the level of tankers going to the study
area at or above its present level.

Further complicating the picture is the prospect of the
Northern Tier pipeline being built from Washington State to the
Midwest. This pipeline, if built, would carry Alaskan crude and
do away with the tankering past the terminal in Washington
State. The prospects of building this pipeline, once bright, are
unknown at the present time, although the project appears to be
moribund, especially since there have been movements recently to
allow export to Japan of Alaskan oil (Oil & Gas Journal, Jan. 31,
1983).

Another apparently moribund project is the Point Conception
LNG terminal. The present date for initial operation of this
facility is 1990, with construction starting about two years
before that (Joe Cook, Western LNG Associates, pers. comm., Feb.
14, 1983). When fully operational, as early as 1992, the

facility should receive 130 tankers per year.

86

Oil Spill Risk

As shown by the MMS (Lanfear and Amstutz, 1983) and the
Western Oil and Gas Association (Bigham, et al., 1983) oil spill
risks have been declining over time. WOGA's analysis shows that
the rate of decline has itself been decreasing and the spill rate
may in fact have reached a leveling out. If this is the case,
then the risk of a spill between now and 1988 per unit of volume
produced or transported should remain the same as it is now. As
WOGA notes, the change in spill rate over the last five years for
platform spills has been minimal, converging on a rate somewhat
less than one spill of 1,000 barrels or more per billion barrels
produced (Bigham, et al., 1983). This is consistent with the MMS
rate of 1.0 per billion barrels (Lanfear and Amstutz, 1983).

The current Department of the Interior five-year plan for
OCS oil and gas lease sales lists five lease sales for the
California coast: the recently-held number 68, and the future 73,
80, 91 and 95. According to Interior, a mean estimate of about
1.4 billion barrels of oil and 2.2 trillion cubic feet of gas
will be recovered from tracts leased in these sales (these
projections were made before the strikes in the Santa Maria basin
were announced).

In producing and transporting this oil and gas, Interior

estimated that 0.7 spills of 1,000 barrels or more would result

87

from platforms in southern California, and 2.6 spills from
transportation. For central and northern California these
figures are 0.4 and 1.6 respectively (DOI, 1981). These spill
frequencies were calculated prior to the determination of the new
MMS spill rates.

Revising the spill frequencies for expected production and
transportation off California result in the following figures

(assuming evenly mixed transportation):

* Southern California platforms - 0.9 spills

* Southern California transportation - 1.3
Spills

* Central and Northern California platforms -
0.5 spills

* Central and Northern California transpor-

tation - 0.7 spills

Interior estimated that production would begin from both areas in

1987 and continue for at least 35 years.

88

Oil Spill Response

The future adequacy of oil spill response capabilities is
not easily assessed. Since past and present adequacy has been
examined in terms of equipment and materials and their loation,
future plans for equipment acquisition and placement can give
some indication of future response capabilities.

With respect to equipment and materials located on
platforms, more platforms intuitively means better respose
capabilities as more equipment is placed close together. In the
event of a spill, equipment from nearby platforms can be brought
to bear on the problem relatively quickly.

As for oil spill cooperatives, new equipment and facilities
may likewise be interpreted to result in enhanced response
capabilities. Clean Seas, Inc. has recently announced plans to
increase its fleet of dedicated vessels from two to three and its
40-foot trailer fleet from eight to eleven. The third vessel
could be purchased as early as the first quarter of 1984, but the
actual date depends on the need created by activity in the
federal and state lease areas in the Point Conception-Point
Arguello region. The vessel would initially be based at Cojo
Bay, then moved to Gaviota when the new terminal or terminals are
built there (Waage, Clean Seas, Ine., pers. comm., Feb. 15,
1983).

The three trailers will be purchased shortly. One will be
Stationed at Avila and two will be stationed at Carpinteria. The

trailers will enhance response capabilities from those areas

89

\

rather than extend equipment basing and coverage to new areas.

As development and production increase in the Santa Maria
basin, Clean Seas likely will establish a permanently staffed
facility in the San Luis Obispo area. From two to four full time
employees will be stationed there. At the present time, no full
time employees are based in the area. Instead, employees from
the Santa Barbara area make weekly visits to the northern area
(Waage, Clean Seas, Inc., pers. comm., Feb. 15, 1983).

The intent of all these changes is to improve the response
time for spill containment as the new Santa Maria basin lease
areas open up. The effect would be to make equipment
availability and response times in these new areas comparable to
those presently existing in the more established regions of the
Santa Barbara Channel.

In the northern part of the study area (north of Cape San
Martin), Clean Bay is responsible for oil spill response. Like
Clean Seas, Clean Bay is constantly updating and improving its
inventory of equipment of materials. Given the more distant
prospect of offshore leasing in this northern area, Clean Bay has
no plans to base equipment or establish facilities outside of the
Bay area, although it is under study (Jack Mortenson, Clean Bay,
Ine, pers. comme, heb... 15), 1983)).

Worth noting in regard to oil spill response is that the
offshore oil industry, through the American Petroleum Institute
and the Western Oil and Gas Association, is planning to undertake
a study of sea otter deoiling, although funding for this study

has recently been eliminated from current research funds. This

90

study is intended to look at methods of capturing oiled otters,
removing oil from their pelts, rehabilitating them (including
their fur, replacing natural oils with other natural or synthetic
oils, blood chemistry, and physiology), and ways to lessen and
deal with the trauma of the capture and cleanup process
(Chamberlain, pers. comm., Feb. 9, 1983). This, too, may figure
in future oil spill response plans should successful and
acceptable methods of capturing, cleaning, and rehabilitating sea

otters be found.

gal

CHAPTER VII

Synopsis

On the following pages is a series of tables bringing
together the information and data presented in the preceding
chapters. These tables are intended to permit a quick comparison
of probative facts regarding the past, present, and future risks

of oil spills in and near the sea otter range.

TABLE S-l1: OCS LEASE SALES

See eee ee eee eee eee eee eee e ee eee

eyyy,yeeettttttttee

Through 1977 Through 1983 Through 1988
(estimate)

Tracts offered? 471 870 2
Acres offered? 4,583,296 6,696,618 2
Tracts leased? 195 329 2
Acres leased? 988,170 1,744,782 2
Total bonuses? $1,054,027,000 $4,016 ,692,000 2

b

Total royalties $100,477,752 215,740,587 &

(through 1981)

“source: Collins, et al., 1982

Bsource: MMS, Royalties (1982)

98

TABLE S-2: OFFSHORE OIL AND GAS LEASES

1977 1983 1988
Number of Active Leases 121 182 Ge
Acreage of Active Leases 640,027 1,229,037 ?

SOURCE: USGS, Outer Continental Shelf Statistics (1982)

94

TABLE S-3: PLATFORMS AND WELLS

1977 1983 1988
Number of Platforms- 9 12 14-16 minimum in
Federal Waters Santa Barbara Channel

2-6 minimum in Santa
Maria basin

Number of Platforms- 8 (plus 8 10 minimum (plus one
State Waters 1 island) plus island) in Santa
1 Barbara Channel
island 6 minimum in Santa
Maria basin
Number of Subsea 6 6 7 minimum
Completions
Number of Exploratory &
Wells
Number of Production Wells 306 605 200 minimum in
(Santa (Santa Sane Maria pao
Barbara Barbara © minimum in Santa
Channel) Channel) Barbara ichenne!

95

TABLE S-4: PRODUCTION

Through 1977 Through 1981 Through 1988

Quantity of Produced Oil 167,897,088 bbl 217,549,934 ?
Value of Produced Oil $602,829,366 $1,261,896,255 ?
Quantity of Produced 67,156,731 84,314,419 ?

Natural Gas thousand

cubic feet

Value of Produced $19,017,810 $33,675,164 ?

Natural Gas

SOURCE: MMS, Royalties (1982)

96

TABLE S-5: TRANSPORTATION

Quantity of Offshore Oil Transported to
Shore by Pipeline (State & Federal)

Quantity of Offshore Oil Transported to
Shore by Tanker (State & Federal)

Number of Tanker Trips from Marine
Terminals Carrying Crude from Offshore
Wells

Number of Tanker Trips to Moorings
Carrying Refined Products

Number of Other Tanker Trips Including
Los Angeles and San Francisco Traffic

7

1977

1982

60,198,000 44,910,000(1980)

barrels

111

2,423

0(1980)

13 2'9(298'0))

29

2,373

(1981)

1988

?

2

2

TABLE S-6: OIL SPILL RESPONSE CAPABILITIES

1977 1983 1988

Number of Dedicated Vessels - 0 2 3
Clean Seas

Number of Skimmers - Clean Seas 7 20 ?
Feet of Containment Boom - Clean Seas6910 34,957 2
Number of Dedicated Vessels - 0 0 0
Clean Bay

Number of Skimmers - Clean Bay 2 8 z
Feet of Containment Boom - Clean Bay ? 16,440 2

TABLE S-7: OIL SPILL MODELS

1977 1983 1988
Projected Spill Rate per Billion Barrels
(spills greater than 1,000 barrels)
Platform IL) 1.0 &
Pipeline ZS 1.6 ?
Tanker ?
Probability of Otter Range Being
Impacted by OCS Spill .082 .222 ?

SL a SS IEE

,Lease Sale 48
Lease Sale 53

JE)

Bibliography

ARCO (1982), Oil Spill Contingency Plan for the Santa Maria
Basin.

Bigham et al. (1983), An Overview of Sea Otter Oil Spill Risk
Analysis.

Bureau of Land Management (1982a), Final Environmental Impact

(1982b), Final Environmental Impact Statement,

(1981), Final Environmental Impact Statement, OCS

Sale No. 68.

(1980), Final Environmental Impact Statement, OCS Sale
o. 53.

(1979), Final Environmental Impact Statement, OCS Sale
o. 48.

January 1982-December 1986.

» New Orleans Office (1981), Outer Continental Shelf
Statistics.

California Coastal Commission (1981), Oil Spill Response
Capability Study.

Chevron USA (1982), Exploration Plan, OCS Leases P-0451, P-0452,
and P-0453, Outer Continental Shelf, Santa Maria Basin, Offshore
California.

Collins et al. (1982), Pacific Summary Report 2, USGS Open File
Report 82-21.

Danenberger (1980), Outer Continental Shelf Oil and Gas Blowouts,
USGS Open-file Report 80-101.

Department of the Interior (1981), Secretarial Issue Document for
Tentative Proposed Final 5-Year OCS Leasing Program.

Fish & Wildlife Service (1977a), Proceedings of the 1977 Oil Spill
Response Workshop, FWS/0BS/77-24.

(1977b), Determination that the Southern Sea Otter is

a Threatened Species, 42 F.R. 2965 (January 14, 1977).

100

(1980), Biological Opinion Regarding Outer Continental
Shelf Leasing and Exploration Offshore Central and Northern
California.

(1982), Southern Sea Otter Recovery Plan.

General Accounting Office (1978), Coast Guard Response to 0il

Interagency Committee on Ocean Pollution Research, Development,
and Monitoring (1981), Marine Oil Pollution: Federal Program
Review.

Holmes & DeWitt (1970), Santa Barbara Oil Symposium.

Kenyon (1981), Sea Otter, in Ridgway & Harrison, eds., Handbook
of Marine Mammals.

file ete wes ZS COO OOS

Lanfear & Samuels (1981), Documentation and User’s Guide to the
U.S. Geological Survey Oilspill Risk Analysis Model: Oilspill
Trajectories and Calculation of Conditional Respons*bilities,
USGS Open-file Report 81-316.

Macpherson & Bernstein (1980), Outer Continental Shelf Oil and

Gas Activities in the Pacific (Southern California) and their

Onshore Impacts: A Summary Report, May 1980, USGS Open-file
Report 80-645.

Mansvelt Beck & Wiig (1977), The Economics of Offshore Oil and
Gas Supplies.

Marine Exchange of Los Angeles-Long Beach Harbor (1983), Vessel
Arrivals and Departures at Los Angeles-Long Beach Harbor.

Marine Exchange of San Francisco (1983), Vessel Arrivals &
Departures at San Francisco Harbor.

Minerals Management Service (1982), Royalties.

National Academy of Sciences (1975), Petroleum in the Marine
Environment.

(1981), Safety and Offshore Oil.
Office of Planning & Research (1977), Offshore Oil in California.
Oil and Gas Journal (various dates), various articles.

Pacific Gas & Electric (1982), Prepared Testimony of R.G. Mohr
and N.B. Wheelock.

101

1
i

Samuels et al. (1981), An Oilspill Risk Analysis for the Southern
California (Proposed Sale 68) Outer Continental Shelf Lease Area,

USGS Open~-file Report 81-605.

Shell Oil Co. (1982), Oil Spill Contingency Plan, Trout Prospect,
OSC Lease No. P-0435.

(1976), Oil Spill Contingency Plan for Exploratory

Slack et al. (1978), An Oilspill Risk Analysis for the Southern

USGS Water-resources Investigations 78-80.

Smith et al. (1980), The oilspill Risk Analysis of the U.S.
Geological Survey, USGS Open-file Report 80-687.

State Lands Commission (1982), Program Environmental Impact

Report, Leasing, Exploration and Development of Oil and Gas
Resources on State Tide and Submerged Lands, Point Conception to

Point Arguello, Santa Barbara County, California.

Stolzenbach et al. (1977), A Preview and Evaluation of Basic

Union Oil Company of California (1982), Oil Spill Contingency
Plan for Exploration Activities on Lease OCS-P 0203 in the Santa

Barbara Channel, Offshore California.

U.S. Air Force (1977), Environmental Impact Analysis Process
Reference Document to Environmental Impact Statement Space
Shuttle Program.

U.S. Coast Guard (various dates), Polluting Incidents in and
around U.S. Waters.

U.S. Coast Guard (1982), Port Access Route Study, 12th District.

U.S. Coast Guard (1981), Seagoing Vessel Arrivals.

in

USGS (no date), Accidents Connected With Federal Oil and Ga

QO
Ls)
2)

(1981), Federal and Indian Lands Oil and
Production, Royalty Income, and Related Statistics.

VanBlaricom & Jameson (1982), "Lumber Spill in Central California
Waters: Implications for Oil Spills and Sea Otters," Science, v.
215, pp. 1503-1505.

102

Side na ae Lier 68 .
emer, he) Nak She eons
tae aan Lar AES apres isms

He ax sieha sin he pouel

chs lad Hehe aan

oe bona hs ape +

: ae

hax se
yo ku ‘eal .
faye phew f

(amgnh airoliey)

Weitoe 1983), pons

a ie PRN CHD hat

i ig Sexaimasa gated) pad | M
Saesmse Perr ee, ait RA

List of Persons Contacted

Brian Baird
California Coastal Commission
San Francisco, California

Robert L. Brownell
Fish & Wildlife Service
San Simeon, California

D. W. Chamberlain
Senior Science Advisor
Atlantic Richfield Co.
Los Angeles, California

Joe Cook
Pacifie LNG Associates
Los Angeles, California

Ruthann Corwin

OCS Planner

Marin County

San Rafael, California

Carol Fuiton
Friends of the Sea Otter
Pacifie Grove, California

Susan Hansch
California Coastal Commission
San Francisco, California

Jack Mortenson
Manager

Clean Bay, Inc.
Coneord, California

Sabella Moreno

Construction Operations

San Francisco District Office
Corps of Engineers

San Francisco, California

Jan Terveen

Chief, OCS Management Branch
11th Coast Guard District
Long Beach, California

Bud Waage

Manager

Clean Seas, Inc.

Santa Barbara, California

103

William Walkers
12th Coast Guard District
San Francisco, California

Cal Weide
Minerals Management Service
Los Angeles, California

104

BASIN-

BLOCK-

BLOWOUT-

BONUS-

CONTINGENCY
PLAN

DEVELOPMENT -

EXPLORATION-

GLOSSARY

A depression of the earth in which sedimentary
materials accumulate or have accumulated, usually
characterized by continuous deposition over a
long period of time; a broad area of the earth
beneath which the strata dip, usually from the
sides toward the center.

A geographical area of approximately 9 square
Miles (5,760 acres or 2,330 hectares), which is
used in official BLM protraction diagrams or
leasing maps.

An uncontrolled flow of gas, oil, and other
fluids from a well to the atmosphere. A blowout
occurs when formation pressure exceeds pressure
applied to the well by the column of drilling
fluid.

Money paid by the lessee for the execution of an
oil and gas lease.

A plan for possible offshore emergencies prepared
and submitted by the oil or gas operator as part
of the plan of development and production.

Activities that take place following exploration
for, discovery of, and delineation of minerals in
commercial quantities, including but not limited
to geophysical activity, drilling, platform
construction, and operation of all directly
related onshore support facilities; and that are
for the purpose of ultimately producing the
minerals discovered.

The process of searching for minerals.
Exploration activities include (1) geophysical
Surveys where magnetic, gravity, seismic, or
other systems are used to detect or infer the
geologic conditions conducive to the accumulation
of such minerals and (2) any drilling, except
development drilling, whether on or off known
geological structures. Exploration also includes
the drilling of a well in which a discovery of
oil or natural gas in paying quantities is made
and the drilling of any additional well after
such a discovery that is needed to delineate a
reservoir and to enable the lessee to determine
whether to proceed with development and
Production.

105

FIELD-—

LEASE SALE-

OFFLOADING-—

OFFSHORE
STORAGE AND
TREATMENT
VESSEL (OS&T)

OUTER
CONTINENTAL
SHELF (OCS)

PLATFORM-

PRODUCTION-

TREATMENT
FACILITY

An area within which hydrocarbons have been
concentrated and trapped in economically
producible quantities in one or more structural
or stratigraphically related reservoirs.

The public opening of sealed bids made after
competitive auction for leases granting companies
or individuals the right to explore for and
develop certain minerals within a defined period
of time.

Another name for unloading; offloading refers
more specifically to liquid cargo - crude oil,
and refined products.

A converted tanker anchored by a platform and
used to remove natural gas, water, and other
impurities from crude oil and to store the
treated product until it is offloaded by a
shuttle tanker.

All submerged lands that comprise the Continental
Margin adjacent to the United States and seaward
of State offshore lands. The OCS has been
subject to Federal jurisdiction and control since
enactment of the Submerged Lands Act of 1953 (43
UsSeGe F301 sand a3 0/2)

A steel or concrete structure from which offshore
wells are drilled.

Activities that take place after the successful
completion of any means for the removal of
Minerals, including such removal, field
operations, transfer of minerals to shore,
operation monitoring, maintenance, and work
overdrilling.

Portion of the identified oil or gas resource
that can be economically extracted.

Equipment used for drilling an oil or gas well.

The portion of the Continental Shelf between the
shore and the boundaries claimed by the States.

The geographic and legal extent of a single lease
area; a convenient way of numbering blocks
offered for sale.

A facility that separates hydrocarbons from water
emulsions, and other impurities.

106

UNDISCOVERED
RESOURCES

UNIT-

Quantities of oil and gas estimated to exist
outside known fields.

Administrative consolidation of OCS leases held
by two or more companies but explored, developed
and/or produced by one Operator for purposes of
conservation, eliminating duplication of
operations, and/or maximizing resources
recovered.

Ul

107

APPENDIX A
OIL SPILLS FROM PLATFORMS AND DRILLSHIPS
IN SOUTHERN CALIFORNIA WATERS

1969 TO PRESENT

108

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APPENDIX B

SPILLS IN THE SEA OTTER RANGE
1977 — PRESENT

US COAST GUARD, 1983

112

WATERBODY

DEFINITION Describes the type of waterbody in which the incident occurrred.

DISCUSSION Inland and coastal areas are defined in accordance with 40 CFR
1510.5 (e) and (f) (The National Contingency Plan) as
implemented by the applicable Regional Contingency Plan.

CODES The first character position identifies the general area, while the
remainder of the field further refines the body of water.

CODES for the first position:

1

2

Applicable if
the CODE in the
first character
position is:

Inland Area

Atlantic Coast

Pacific Coast

Gulf Coast

Great Lakes Coast

Arctic Coast/Alaska Coast (North-northwest of the Aleutian
Islands )

Central and Western Pacific (used only for spills in
American Samoa, Guam or northern Mariana Islands)

or 7

or 7

03

04

05

CODES for the second and third positions

VA
x

WA

Lake, roadstead or other large body of
open internal water

Bay, estuary or a sound

River area, channel or other restricted
navigable waterway

Port or harbor area (including terminal
or dock)

Non-navigable tributary to navigable
waters

Other non-navigable area (including
seqage or drainage ditches)

Beach/sbore adjoining navigable water
or a tributary to a navigable water

Other beach or shore

Territorial Seas (baseline to 3 miles)
Contiguous Zone (3 to 12 miles)

High Seas (12 to 50 miles)

Bigh Seas (50 to 100 miles)

High Seas (more than 100 miles)

Ika)

MATERIAL

Crude Oil
1000 Light crude oil
1001 Heavy crude oil
1@02 Medium crude oil

Gasoline
1010. Natural (casing head) gasoline
1011 Gasoline (aviation or automotive)

Other Distillate Fuel Oil

1020 Jet fuel (JP-1 through JP-5)
1021 Kerosene

1022 Other distillate fuel oil

Solvents

1030 Naptha

1031 Mineral spirits

1032 Other petroleum solvent

Diesel Oil
1040 Light diesel oil
1041 Heavy diesel oil

Residual Fuel Oil
1050 #4 Fuel oil
1051 #5 Puel oil
1052 #6 Puel oil

Asphalt or Other Residual |

1060
1061
1062

Creosote
Asphalt or road oil
Coal tar or pitch

Animal or Vegetable Oil

‘1070
1071

Animal. oil
Vegetable oil

Waste

1080

Other

1089
1090
1091
1092
1093
1094
1095

1096
1097
1098
1099

Oil
Waste oil
Oil
Lube oil

Liquefied petroleum gas
Hydraulic fluid
Lacquer-based paint
Paraffin wax

Grease

Mixture of two or more
petroleum products
Oil-based pesticides
Unidentified light oil
Unidentified heavy oil
Other oil or unknown

2088
2203
2089
2204
2205
2090
2091
2206
2092
2207
2208
2093

2209

Other

7001
7002
7003
7004
7005
7006
7007
7008
7009
7010
7011

8000
9000
9999

Tetraethyl Lead

Tetraethyl Pyrophosate

Toluene
Toxaphene

Tuchlor fon
Trichloroethane
Trichloroethylene
Trichlosophenal
Triethanolamine
Triethylamine
Trimethylamine
Turpentine

Uranuim Compounds

Pollutant

Dredged spoil

Solid waste
Incinerator residue
Sewage

Sewage sludge
Garbage

Munitions

Chemical wastes
Biological materials
Radioactive materials
Heat

Natural Substance
Other Material

Unknown Material

Actual Spill

G = Gallons
P = Pounds

§ = Sheen

U0 = Unknown

2210
2094
2095

2096
22101

2212
2213
2214

2097

7012

7013
7014
7015
7016
7017
7018
7019
7020
7021

z

-

LIL)

Vanadium Compounds
Vinyl Acetate
Vinylidene Chloride

Xylene
Xylenol

Zectran
Zinc Compounds
Zirconium Compounds

Other hazardous substances

Wrecked or discarded
equipment

Rock

Sand

Cellar dirt
Industrial waste
Municipal waste
Agricultural waste
Coal dust

Coke

Salt water

sPotential® ‘Spinl
= Gallons

X
Y = Pounds

SOURCE
Marine Traffic Systems

VESSEL:

000 Other vessel
ool Unknown but suspected vessel

(S)

Ol Tankship

Sak

O3iny shank Barge

lee

fon)

~

oo

oO

050 Dry Cargoship

051 Dry Cargo Barge
052 Tugboat or Towboat
053 Fishing Vessel

054 Passenger Vessel

055 Recreational Vessel

0 - 149 Gross Tons

Y50iR—
30/0
500 -
1,000
10,000
20,000
35,000
50,000

299 Gross Tons

499 Gross Tons

999 Gross Tons
- 9,999 Gross Tons

19,999 Gross
34,999 Gross
49,999 Gross
99,999 Gross

100,000 Gross Tons or

056 Combatant Vessel (All Naval vessels except Tank Vessels)

057 Other Public Vessels
OSE Coast Guard Vessel
059 Service Vessel

060 Research Vessel

061 Crew Boat

MARINE FACILITY:

100 Other transportation-related marine facility,

101 Onshore bulk cargo transfer
102 Onshore Fueling

103 Onshore non-bulk cargo transfer

116

Tons
Tons
Tons
Tons

more

104 Offshore buik cargo transfer

105 Offsnore Fueling

106 Offshore non-bulk cargo transfer
107 Deepwater Port Complex

108 Single Point Mooring

109) Gas Freeing Plant

ther Transportation Systems
VEHICLE:

200 Other land vehicle

201 Rail vehicle liguid bulk

202 Rail vehicle dry bulk

203 Rail vehicle general cargo
204 Rail vehicle transfer

205 Highway vehicle liquid bulk
206 Highway vehicle dry bulk

207 Highway vehicle general cargo
208 Highway vehicle passenger
209 Aircraft

210 Tank Truck

250 Unknown type of land vehicle

LAND FACILITIES:

300 Other land transportation facility

301 Railway cargo transfer

302 Railway fueling facility

303 Highway cargo transfer

304 Highway fueling

305 Unknown type of land transportation facility

17

3-B-5-(c)-(3). (€ont'da)

207
208
209
210
250

Highway vehicle general cargo
Highway vehicle passenger
Aircraft -

Tank truck

Unknown type of land vehicle

(4) Land Facilities.

300
301
302
303
304
305

Other land transportation facility

Railway cargo transfer

Railway fueling facility

Highway cargo transfer

Highway fueling

Unknown type of land transportation facility

(5) Transportation Related Pipelines.

401
402

Onshore pipeline
Offshore pipeline

(6) Non-Transportation-Related Facilities.

500

501
502

503

504
505

506
507
508

Other onshore non-transportation-related
facility

Onshore refinery

Onshore bulk storage facility (includes tank
farms) ©

Onshore industrial plant or processing
facility

Onshore oil or gas production facility

Other offshore non-transportation-related
Ba cisbaaty,

Offshore production facility

Power plant

Pipeline within non-transportation-related
facility

(7) Miscellaneous.
Surana Poa eee

900
901
902

999

Miscellaneous
Natural oil seep

Natural material other than oil or hazardous
substance

Unknown type of source

d. EDIT CONSIDERATIONS.

(1) This is a REQUIRED field. Blank spaces are not
acceptable, :

(2) Only the codes described above are acceptable.

118

CAUSE

IMMEDIATE CAUSE:

Structural Failure or Loss

A.

B
Cc

189]

tow a a It

vw O 2 &

Hull rupture or leak
Tank rupture or leak
Transportation pipeline
rupture or leak

Dike rupture or leak
Container lost intact
Well blow-out

Other structural failure

Quipment Failure

Pipe rupture or leak

Hose rupture or Leak
Manifold rupture or leak
Loading arm failure, rupture
or leak

Valve failure

Pump Failure

Flange failure

Gasket failure

ALA)

CONTRIBUTING FACTOR:

tee) Qt wWwon Ww Y

[a ee

HOV O 2 &

moavymondw py

Collision

Grounding
Fire/Explosion
Capsizing/Overturning
Sinking

Other casulty

Adverse weather or sea
conditions

Earthquake or other natural
disaster

Minor damage

Material fault

Design fault

Personnel error (PE)
improper maintenance

PE - overpressurization
Other personnel error
Corrosion

Sand cutouts

Other or unknown factor
Ramming

Minor damage

Excessive wear

Corrosion

Material fault

Design fault

PE -improper installation

PE -improper maintenance
PE-Hose, pipe, or loading arm

cut or severed

R

Other equipment failure

uv FoR 4

—__

PE-Hose, pipe, or loading arm
twisted or kinked

PE-improper valve operation
PE-Flanges improperly secured
PE-overpressurization

Other personnel error

Other or unknown factor

Personnel Error (Unintentional Discharge)

Ss
T

W

Tank overflow

Improper equipment handling

Or operation

Other personnel error

A

B
Cc
D

te

PR oh oa SY

Inadequate sounding

Failure to shut down
Topping off at excessive rate
Loading too many tanks
simultaneously

Overfilling (and subsequent
overflow)

Improper hose handling
Improper valve operation
Flanges improperly secured
Failure to communicate
Inattention to duty

Other or unknown factor
Improper training

Intentional Discharge

X Intentional discharge Bilge pumping

Ballast pumping

Tank cleaning or stripping
Emergency discharge
Disposal of waste
Discharge under COE/EPA

permit

ym oN wD YP

G Sabotage or vandalism
H Salvage operations

J Other or unknown factor

Other Transportation Casualty

Q Railroad accident A Personnel error
U Highway accident B Adverse weather
Vv Aircraft accident Cc Overturning
; D Equipment failure
E Collision/crash
Fi F Other or unknown factor
Natural or Chronic Phenomenon
Y Natural or chronic phenomenon A Natural seepage from sea

bottom

B Natural substance reported as
oil slick

Cc Leaching from saturated
ground

E Other factor
Unknown Cause

Z Unknown A Palse Alarm/Potential Spill
Z Unknown

AMAL

eee La Le

OPERATION.

00

DEFINITION. Indicates the type of operation in which
the source or suspected source was engaged at the
time of the discharge.

CODES.

Type of Operation
Ro operation in progress

Pacility and Land Transportation-Related Operations

Routine industrial or manufacturing process
Starting, stopping, or changing industrial or
manufacturing process

Repair, modification, or maintenance of plant of
equipment

Internal transfer or shifting of liquid

Transfer of bulk liquid to or from transportation
mode

Transport of bulk liquid by pipeline or vehicle
Receiving fuel

Storage of bulk liquid

Tank stripping process

Tank cleanup process

Other cleaning process

Ship breaking

Deepwater port (DWP) cargo transfer plem (pipeline
end manifold) to platform

DWP - cargo transfer platform to shoreside

Other facility or land transportation-related
operation

Non-Transportation-Related Operations

Exploration for natural resource
Industrial or manufacturing process
Repair, modification, or maintenance of plant of equip-
ment

Internal transfer or shifting of liquid
Receiving fuel

Production from a natural resource

Storage of bulk liquid

Tank stripping or cleaning process

Other cleaning process

Other non-transportation related operation

- aus...

Vessel-Related Operations

Receiving dry cargo

Off-loading dry cargo

Receiving liquid cargo at an onshore facility
Discharging liquid cargo at an onshore facility
Receiving fuel

Taking on ballast

Discharging ballast

Pumping bilges

Stripping tanks

Cleaning tanks

Other cleaning process

Transfer or shifting of liquid within vessel
Repair, modification, or maintenance of vessel
Repair, modification, or maintenance of equipment
Mooring at dock

Departing from dock

Moored (not engaged in any operation listed above)
Anchored (not engaged in any operation listed above)
Onderway

Lightering

Dredging

Deepwater port - cargo transfer vessel to plem (pipeline
end manifold)

Other vessel-related operation

Unknown operation..er “potential” spill

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APPENDIX C
EXAMPLE OIL SPILL TRAJECTORIES

OIL SPILL RISK ANALYSIS LEASE SALE 48
USGS, 1978

128

Figure Cl --Example oilspill trajectories for a spill site
near the center of the proposed lease area: winter conditions.
Number on trajectory is the time to the end point in days.

DEZIS

Figure C2 --Example oilspill trajectories for a spill site
near the center of the proposed lease area: spring conditions.
Number on trajectory is the time to the end point in days.

130

Figure C3 .--Example oilspill trajectories for a spill site
near the center of the proposed lease area: summer conditions.
Number on trajectory is the time to the end point in days.

iLB}al

Figure C4 .--Example Oilspill trajectories for a spill site
near the center of the proposed lease area: autumn conditions.
Number on trajectory is the time to the end point in days.

3 12.

APPENDIX D
Selected Drift Bottle Trajectories

Source: F.J. Crowe & R.A. Schwartzlose, Release and Recovery
Records of Drift Bottles in the California Current
Region 1955 through 1971, CalCOFI Atlas No. 16.

N.B. These trajectories were selected specifically to
show northward flowing currents in each month, and
as such are not necessarily representative of normal
current flows.

| 133

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JANUARY 1969

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SEPTEMBER 1966

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‘ NOVEMBER 1969

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DIRECTION TO PICK UP POINT
~<— PLACE OF RECOVERY
37 DAYS ELAPSED
- RELEASE POINT (NO RETURNS)
3.8% RECOVERED

PUNTA
EUGENIA
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45°

40°

35°

30°
) —425°
110°

DRIFT BOTTLES

NOVEMBER

1969

APE
MENDOCINO

SAN
FRANCISCO

E 66

35°

30°

Peay

(ey i20°

DRG BOM ES
DECEMBER 1957

© RELEASE POINT
& DIRECTION TO PICK UP POINT oe
<— PLACE OF RECOVERY -
37 DAYS ELAPSED
- RELEASE POINT (NO RETURNS)

96% RECOVERED

Ris

252

415° $10°

DR iiine BOE ES
DECEMBER 1957

APPENDIX E

Inventory of Equipment and Materials -- Clean Seas & Clean Bay

146

CLEAN SEAS INVENTORY OF EQUIPMENT AND MATERIALS

a)

b)

CONTAINHENT

2,000' Bottom Tension Boom

This is a heavy duty, open ocean containment boom with
4' x 13' floats and 8' curtains extending 34%' above water
line and 4%' below the water line. It is usually stored
on land and deployed from the beach, requiring 24-36 hours
for assembly.

Capability: Will contain oil in 6'=-8' significant waves
and winds to 25 knots at currents up to 1% knots.

Vikoma Seapack with 1,600' boom

2 Units.

_ For very fast response to an oil spill. The Vikoma Sea-

pack is based on a 23' Rull and contains 1,600' of seaboom
connected at one end to a diesel driven fan and ducted
propeller water pump. The Vikoma Seapack unit can be
transported by road trailer, towed by a small vessel, or
carried on a workboat or tanker. It could also be trans-
ported by an aircraft.

Capability: Experience over the past several years indi-
cates this boom can be on a scene and deployed in less
than an hour. It is effective in preventing spread of oil
in significant waves up to six feet and winds of 20 to 25
knots. In the mode in which this boom is used, there is
little or no current across the boom which could cause
loss of oil due to underflow. Clean Seas exercises with
this boom would parallel this in response and deployment

CG)

ec)

a)

time. Response is the most important factor. Deployment
is instantaneously accomplished on arrival at the site,

10-12 minutes.

Oil Containment Booms

2,000 feet medium duty boom (16" x 12" skirt Kepner Sea

Curtain) for harbor protection.

~e 2,000 feet Light duty boom. (8"9x 12% skirt Kepnerisea
Curtain) for secondary harbor protection.

-- 2,695 feet (12" x 24" Goodyear Sea Sentry) for harbor
protection and offshore containment boom.

-- 5,527 feet (Model 3,000 Expandi light duty oil boom).
This boom may be used for offshore rapid deployment for
containment as well as harbor protection.

-» 9,100 feet (Model 4,300 Expandi) medium duty oil boom.
This boom would primarily be used for offshore rapid
deployment and containment.

-. 2,500 feet (36" Supermax) 50 sections of 2802. fabric
with 3/4" cable. :

-- 5,500 feet (Minimax boom) 55 sections of 2202. fabric
with 5/8" chain.

-- 2,035 feet (14" x 24" Goodyear Sea Sentry) offshore

containment boom.

Tide-Mar VII Barge:

One (1) 641 ton tank barge, Tide-Mar VII, for collecting
oil picked up by skimmers as they work in an oil spill.
This is a 160' x 39' ocean going barge with 10 tanks,
Capacity of 7,840 barrels and six (6) diesel engine driven
pumps. Presently moored in Santa Barbara Harbor.

148

e)

a)

b)

ce)

Floating Storage Bags:

Six (6) 5,000 gallon Kepner Floating Storage Bags
Six (6) 1,200 gallon Kepner Floating Storage Bags
One (1) 6,000 gallon Dracone Floating Barge

These bags to be used as interim storage awaiting arrival
of the Tide-Mar VII or similar tank barge/vessels.

Cyclonet-100:

One (1) Cyclonet-100 skimmer. This skimmer is an cpen sea
skimmer and is fitted to the Mr. Clean I (OSRV). This
skimmer contains a diesel engine, hydraulic unit and pump-
ing system.

Cyclonet-050: cs

One (1) Cyclonet-050 skimmer fitted to a Zodiac Mark-V in-
Elatable dinghy. This skimmer is primarily for protected
and semi-protected waters but may be used in the open
ocean in light sea conditions. This skimmer is self-pro-
pelled, contains a pump system and small oil storage.

Acme 39T Weir Skimmer:

One (1) Acme 39T weir skimmer, gasoline driven pump. This
pump is designed to collect oil .in somewhat heavy concen-
tration. Ideal for harbor areas. Will recover oil in
Open ocean in light seas. Fluid recovery rates up to 340
GPM. Light in weight and can be handled by two men.

a)

e)

f)

Acme 51T Weir Skimmers:

Five (5) Acme 51T weir skimmers, gasoline driven pumps.
These pumps are designed to collect oil in somewhat heavy
concentration. Ideal for harbor area. Will recover oil
in open ocean in light seas. Fluid recovery rates up to
340 GPM. Light weight and can be handled by two men.

Oil Mop-MK-II-9:

Two (2) Oil Mop MK-II-9 systems each consisting of a two-
wheel trailer, oil mop machine, tail pulleys and 400' of
9" mop. This system is primarily used in protected waters
will recover all grades of oil. Maximum capacity 100
bbls/hr.

Komara Miniskimmer:

One (1) Floating Disc Skimmer hydraulically driven disc
and pump. This pump is designed to collect oil in con-
centrated areas and is ideal for containment booms. Will
recover oil in open ocean in light sea conditions. Fluid
rate 15 to 76 bBbbl/hr. Light weight, can be handled by
manpower.

CS Skimmer System:

One (1) CS skimmer system consisting of 45' x 17' x 6'
catamaran-type adjustable weir skimmer barge; two (2) 240'
lengths of 30” Kepner Sea Curtain boom; a 2,000 GPM pump-
ing system; and two (2) 100 barrel oil-water separation
tanks or a 5,000 gallon floating storage bag. The CS
Skimmer is currently in dry storage at the Clean Seas yard
in Carpinteria.

150

h)

i)

Capability: This system is capable of recovering all
grades of oil trom light to bunker C at rates up EQ 12,000
GPM plus some debris and sorbent material in moderate sea
states. Modification to this skimmer eliminates the
necessity of the tanks by installing a pump onboard and a
5,000 gallon floating storage bag. Also, may be pumped
directly into the Tide-Mar VII barge. .

Mark-II Skimmer:

Two (2) Mark-II skimmers, 14' x 30' weir type, are avail-
able in Carpineria Yard. These may be used one on each
side of a vessel, singularly with a vessel, or may be used
independently with O/B motors in a harbor situation. Re-
covery system can be either an 80 barrel, skid-mounted
vacuum tank or compressed air-driven Wilden pumps and 100
bbl. oil-water separation tanks, or a self-contained pump
and floating 1,200 gallon storage bag, all of which are

available. a

Capability: These are very simple skimmers and may be
used in a number of ways to solve the particular problem
at hand. All grades of oil from light to bunker C can be
recovered plus small amounts of debris. Fluid recovery
rates from 50 GPM to 200 GPM are available. These skin-
mers are limited to light winds and light sea states.
Trailers capable of carrying these skimmers on the highway
have been constructed.

Floating Weir Skimmers:

Three (3) Floating weir skimmers, compressed air-driven
Acme type pump. These were designed to collect oil con-
centrated in the B-T boom area and work in harbor area and

quiet waters.

3)

k)

Capability: These skimmers will ehandle™ Tighe tito »faazilly,
heavy oil, no debris, in 2-3 foot waves. Fluid recovery
rates are up to 300 GPM for eacn skimmer.

Offshore Device Skimming Barrier:

Two ODI offshore oil containment barrier and high seas
skimming and pumping system are located on Mr. Clean II
berthed at Port San Luis. The systems are comprised of
two (2) offshore device skimming barriers with 3 pumps
each, with total capability of 750 gallons per minute.
The 48" barrier is fitted to a 130' OSRV (MR. CLEAN II).

Capability: The ODI open water barrier and skimming
system has been successfully tested in open water with
high seas. It is capable of operating in winds up to 20
knots and wave highs of five feet. However, performance
at much higher wave heights has been good.

Walosep Skimmer:

One (1) Walosep skimmer (W3) stationary skimmer with all
accessory equipment, including pumps, power pack, hoses,
etc. is stored on MR. CLEAN II at Port San Luis.

The Walosep W3 is a low weight, high capacity oil recovery
System which can recover up to 100 m3/hr (629 bph) of oil.

Capability: Official tests have shown that the Walosep W3

can Operate in waves up to 10 feet and wind speeds of
around 20 mph. 5

SS 2

III. VEHICLES/TRAILERS

a)

c)

a)

e)

Truck

One (1) 2% ton. Used to tow Vikoma Seapack, boats, haul
boom, absorbents, etc. i

40' Enclosed Trailer Vans

Eight (8) trailers stocked with booms, absorbents, small
skimmers, miscellaneous cleanup equipment. Stored in
strategic locations in CS area of interest.

25' Mobile Communications Center

id
Has mobile base station, portable radios, auxiliary elec-
trical power and all other equipment for self containment.

e

36' Flatbed Trailer

x

One (1) 36' Flatbed trailer for use with the 100 bbl. vace
uum tank.

Harbor Trailer

Fast Response Harbor Trailer (FRHT) equipped with pollu-
tion control equipment.

Tank Wagon Trailers

Two (2) 100 bbl. tank wagon trailers loaded with disper-
sant. (Corexit 9527). =

IL) 3}

g)

Truck

Rapid Response Truck (RRT). One (1) 2% ton. Enclosed
bed. Equipped with pollution control equipment.

IV. BOATS/VESSELS

a)

b)

Oil Soill Response Vessel (OSRV) "Mr. Clean I"

136' x 36'. Powered by two (2) V-12 diesel engines pro-
viding 1,600 HP, capable of a speed of 12 knots. Fuel
capacity of 99,500 gals. Two (2) 60 kw generators for
electrical power.

Major items onboard include: Cyclonet-100 Acme skimmer,
2,000! of 43" Expandi boom on a 10' powered reel, 2,500'
of heavy duty Goodyear boom, Vikoma Seapack, with 1,600'
of inflatable boom, 12 ton crane, oil/water separation
tank (100 bbl). In addition, a 16" skiff, a 32' boom
boat, and storage of absorbents and dispersants with
necessary applicators. 6,000 gl. Dracone storage bags.

Oil Spill Response Vessel (OSRV) "Mr. Clean II"

130" x 36'. Powered by two (2) 16-V-92 diesel engines.
Fuel capacility of 25,000 gals. Two (2) 75 kw generators
for electrical power. SOA 13 knots.

Major items onboard include: Two (2) Offshore Devices'
Advancing Skimmers 750 gpm each and all accessory equip-
ment, Walosep Skimmer, Vikoma Seapack, 2,000' of 14' x 24!
Goadyear boom, 2,000' of 4,300 Expandi boom, 100 bbl. oil/
water separation system, 32' aluminum boom boat with 175
HP/OB, 14 ton pedestal crane, surface dispersant spray

ec)

a)

system, four (4) Kepner storage bags, 14' Skiff with out-
board. In addition, storage of absorbents and disper-

sants.

Fast Response Boom Boats (FRBB)

Two (2) high speed response vessels, one for each Oil
Spill Response Vessel (OSRV) "Mr. Clean I" and “Mr. Clean
Ir". 32' x 8' aluminum boom boats.

One (1) 19' Larson skiff with 75 HP Johnson motor, kept in
Santa Barbara harbor or Clean Seas' yard, for use as work

boat around skimmers and barge.

Five (5) 14' aluminum skiffs with OB-one on Mr. Clean II,
two on Mr. Clean I, one in the Van in Avila Beach, and one
on the FRHT. :

One (1) 21° Monark Utility boat with O/B for use as a
workboat-stored in Clean Seas' yard in Carpinteria.

One (1) 10' Avon Rubber Raft with O/B-stored in Clean
Seas' yard in Carpinteria.

Vv. ABSORBENTS /CHEMICALS /DISPERSANTS

a)

A large inventory of absorbents including Conwed: sweeps,
blankets, booms and rugs; 3M Company: sweeps, sheets,
booms, and Dow Imbiber bags and blankets.

Stored in the Carpinteria warehouse are smaller quantities
of Oil Herder, 101 boxes of booms (3,376'), 138 boxes of
sweeps (100 per box), 9 rolls of blankets (300' each), 7
rolls of rugs (300' each), 18 boxes of sweeps (100' each).

The above are from Conwed and 3M Company.

ILS) 5)

©

i

Valse

b)

c)

d)

e)

298)

199 Dow Imbiber Blankets
Ll boxes of Oil Snare

Additional quantities are available as "back-up" from
warehouses in the Los Angeles area.

Corexit #9527
225 Drums (200 drums stored in tank wagons)

Helicopter Chemical Dispersant Spray Units

Two (2) Simplex Model 2000, with 150 gallon buckets and
32' boom. i

Surface Chemical Dispersant Spray Units

Two (2) Surface Chemical Dispersant Spray Urits with pump,
booms and mountings for differént types of vessels.

DC=$4 Aircraft

With crew, dispersant spraying equipment, radio, portable
dispersant loading equipment, 3,000 gal. per/load.

Model 10 Fluorometer, Turner Designs

For use during dispersant applications.

RADIO COMMUNICATIONS SYSTEM

a)

A complete radio system consisting of UHF on 454.459.00
MHz and VHF on 158.445/159.480 MHz. This provides solid

156

communication throughout the Clean Seas area of interest.
This system consists of:

1 each VHF/UHF base station in Santa Barbara office
l each VHF/UHF base station in Carpinteria warehouse
1 repeater on Santa Ynez Peak (158.445 MHz)

1 each VHF/UHF mobile unit in car and mobile van

20 portable Handie-Talkie units (UHF)

12 portable Handi-Talker units (VHF)

l transportable repeater 454.00 MHZ

VII. MISCELLANEOUS

a)

b)

c)

d)

e)

Air Driven Pumps:

Two (2) M15 Wilden double diaphram pumps used with MK-11l
Skimmers and miscellaneous equipment.

Six (6) Scare-Away Exploders: s

Bird frightening devices. Operates automatically on LP
gas.

One _ (1) Wiggins Model WD-44 Forklift
40004

One (1) Vixoma Seaboom Vulcanizer Machine
For repair of boom

One (1) Power Block

- For Vikoma Boom recovery

aL Sy7/

Ne

g)

h)

i)

af)

k)

100 bbl. Skid=-Mounted Vacuum Tank with Trailer

One (1) 100 bbl. Vacuum Tank used with MK-II Skimmers or

may be used independently.

100 bbl. Oil/Water Recovery Tanks

Two (2) Oil/Water Recovery Tanks, Coast Guard approved.
Used with the CS Skimmer or other skimmer systems.

100 bbl. Flat Storage Tanks

Four (4) 100 bbl. Flat Storage Tanks. Used with all skim-

mer systems.

Bridger Shoulder Line Gun

One (1) Line Gun with rewinding machine, Model N, with ac-
cessories-for use with Vans in boom launching operations.

Compressor

One (1) Gardner-Denver 600 CFM rotary, diesel engine driv-
en, wheel mounted compressor stored in Carpinteria yard.
Usually used with air tools and to drive the Exxon Float-
ing Weir Skimmers, Acme Skimmers or the Wilden pumps.

Lines, Hoses, Tools
Complete set of all necessary sizes of nylon and poly
lines for deploying and towing booms and skimmers. All

hoses are fitted with Camleck fittings. Air hoses for
compressors and complete sets of tools for all equipment.

158

1)

m)

Skim-Pak Head and Control System

4,200 SH Double Port 4,000 gpm CS Control Wand, 4,000 E£
Extender.

2-43" 900# Magnets-adaptcrs for the Expandi Boom.

I55)9)

Van #1 (Green)

Carpinteria Yard

800' 16" Kepner boom
600' 8" Kepner boom

Sorbents
Conwed
Booms 5 bales/24' per
Sweeps 5 boxes/100'per
Rugs 2 rolls/300° per
3M Company
Booms 15 bales/40' per
Sheets 10 bales/100' per
Sweeps 2 bales/100'per
Dow Imbibers
Bags 1 box/100 per
Blankets 20 boxes/l per
Oil Snare 1 box/30 per

51T Acme Skimmer w/1,200 gal. bag
25':3" hose w/2"=-3" valves
25':3" skimmer discharge hose
1/30' bouy line w/bouy

5" nylon, 3/4" nylon, %" manila
5 - Floats/Skimmer

1 =- Rake

2 - Pitchforks

Miscellaneous Tools

- §5 gallon Drum

- Anchors 3/40#, 1/22

- Anchor Line 200':5" nylon

- Crown Line w/bouy 200'

- Towing Bridle-5/8" wire

15 - Chemical Lights

4 - Life Preservers

5 - Mops

dm - m 0

a 160

VAN #2 42 (Blue)
Getty Oil Terminal-Gaviota

800' 16" Kepner Boom

Sorbents
Conwed
Booms 10 bales/24' per
Sweeps 5 boxes/100' per
3M Compan
Sheets 10 bales/100' per
Sweeps 2 bales/100' per
Dow Imbibers
Bags 1 box/100 per :
Blankets 20 boxes/1l per
Oil Snare 1 box/30 per

51T Acme Skimmer with 5,000 gal. bag

- 25':3" hose with 30':%5" bouy line and with bouy
- Skimmer hoses 75':3" blue (51T)

each - 100':&" nylon, 100':3/4" tow line
box - 1,000':%" manila line

- Hose floats: a

- Life Preservers ;
- Pitchforks

- Rake

Miscellaneous Tools

2 - 55 gallon drums

- Anchors, 3/40#, 1/22#

Anchor Line 200':45" nylon

Crown Line 200':5" poly with bouy

3" valve

chemical Lights

PNkrUrPRNe

VAN #3 (Red)
Avila

1,300':43" Expandi boom
990':30" Expandi boom (12 saseiond)

161

Sorbents

Conwed

Booms 5 bales/24' per

Sweeps 3 boxes/100' per

3M Company

Boom 5 bale/40' per

Sheets § bales/100 per

Sweeps 2 bales/100' per

Dow Imbibers

Bags 1 box/100 per

Blankets 20 boxes/l per

Ovlusnare 1 box/100 per
S1T Acme Skimmer with 1,200 gal. bag

- Skimmer hoses

- 25':3" Discharge hose

- 3" Valve

- 30':k" poly bouy line with bouy
each - 100':5" nylon, 100':3/4" tow line
- 1,000':%" manila line

box - 1,000':%" manila line

- Hose floats

- Life Preservers

- Pitchforks

- Rake

scellaneous Tools

- 55 gallon drums

- Anchors, 22?

- Anchor Line 200':%5" nylon

- Crown Line 200':5" poly with bouy

PNUUNRP REPRE hk

Chemical Lights
14' Skiff with OB

eS SS

Van #4 (Yellow)

Port Hueneme Ventura Channel Islands

(1,200') (1,500') (1,500')

4,200':43" Expandi boom
743':30" Expandi boom (9 sections)

Sorbents

3M Company

Boom 20 bales/40' per
Sheets 12 bales/100 per.
Sweeps 5 bales/100' per
Type 100 Roll Troll ESO per

162

Dow Imbibers

Bags 1 box/100 per
Blankets 20 boxes/1 per
Oil Snare 1 box/30 per

51T Acme Skimmer with 1,200 gal. bag

2

PNPRWURP RRR hH

2
3
4
4

- Skimmer hoses

- 25':3" hose

- 3" Valve

- 30':&" poly line with bouy
each - 100':%" nylon, 100':3/4" tow line
- 1,000':k" manila line

- 1,000':%" manila line

- Hose floats

- Life Preservers

- Pitchforks

- Rake

Miscellaneous Tools

- 55 gallon drums

- Anchors, 22#

- Anchor Line 200':%" nylon

- Crown Line 200':5" poly with bouy

10 - Chemical Lights

1

- 14' Skiff with OB

Van #5 (Black)

Santa Barbara

l,
i,

500':43" Expandi boom
400':8" Kepner boom

Sorbents

Conwed
Sweeps 1 box/100' per
Blankets 1 roll/200' per

3M Company
Booms 10 bale/40' per

Sheets ' § bale/100 per
Sweeps - 4 bale/100' per

Dow Imbibers
Bags 1 box/100 per
Blankets 20 boxes/1 per

Oil Snare 1 box/30 per

39T Acme Skimmer with 1,200 gal. bag

2
1
2

- Skimmer hoses
- 25':3" Discharge hose
- 3" Valve

163

aa

©

fe SOM an DO Ly sine
l each - 100':4" nylon, 100':3/4" tow line
- 1,000':%" manila line

- Hose floats

- Life Preservers

- Pitchforks

- Rake

iscellaneous Tools

2 - 55 gallon drums

2 - Anchors, 222

4 - Anchor Line 200':%" nylon

4

5

1

Bs
5
4
2
1
M

Crown Line 200':%" poly with bouy
Mops
Q - Chemical Lights

Van #6 (White)

Point Dume

2,475':30" Expandi boom (30 sections)
Sorbents 5

Conwed
Sweeps 6 boxes/100' per

3M Company 5
Booms ll bale/40' per

Sheets 10 bale/100 per
Sweeps 2 bale/100' per

Dow Imbibers
Bags 1 box/100 per
Blankets 20 boxes/1 per

Oil Snare 1 box/30 per

531T Acme Skimmer with 1,200 gal. bag
- Skimmer hoses

- 25':3" Discharge hose

- 3” Valves

- 30':5" poly line with bouy

each - 100':4", 100°:3/4" tow line
- 1,000':%" manila line

- Hose floats

- Lite Preservers

- Pitchforks

- Rake

scellaneous Tools

55 gallon drums

Anchors, 22

Anchor Line 200':4" poly with bouy
Crown Line 200':5" poly with bouy
Chemical Lights

See IDI OCIS WIE Wr 08

164

Van #7 (Brown)
Morro Bav

495':30" Expandi boom -
1,050':43" Expandi Boom

Sorbents

3M _ Company
Booms

Sheets
Sweeps

Dow Imbibers
Bags
Blankets

Oil Snare

4 - Life Preservers
Miscellaneous Tools

2 = Bitchforks

- Rakes

- 55 gallon drums
Anchors, 22#

Anchor Line 200':&"

100':3/4" Tow Line

PRP PR PND

Van #8 (Orange)

Port Mugu

825':30" Expandi boom -
1,050':43" Expandi Boom

Sorbents

3M_ Company
Booms

Sheets
Sweeps

Dow Imbibers
Bags
Blankets

Oil Snare
4 - Life Preservers

Miscellaneous Tools
j 2 - Pitchforks

6 sections
- 21 sections

5 bale/40' per
15 bale/100 per
5 bale/100' per

1 box/100 per
20 boxes/1 per
1 box/30 per

nylon

Crown Line 200':5" poly with bouy

1,000':" manila line’

10 sections
- 21 sections

5 bale/40' per
15 bale/100 per
S bale/100' per

1 box/100 per
20 boxes/1l per

1 box/30 per

O

Pee & PN

Rakes

55 gallon drums

Anchors, 22#

Anchor Line 200':%" nylon

Crown Line 200':%" poly with bouy
100':3/4" Tow Line

1,000':%" manila line

166

801 CLEAN BAY CLEANUP EQUIPMENT AND MATERIALS

= : This equipment is owned by Clean Bay. It is stored at locations
shown in the itemized listing which follows. The following
locations are frequently referred to by name only in the listings.
The addresses are shown here.

Clean Bay (CB) 2070 Commerce Avenue
Concord, CA 94520

Diablo Hitch & Trailer 2241 Commerce Avenue
Concord, CA 94520

IT Corporation 4575 Pacheco Blvd.
= Martinez, CA 94553

Calling Procedure
All equipment listed may be obtained by calling:

Clean Bay Manager 415/685-2800 (24 hr.)
Hauling service from the storage sites listed is available
from many companies. Contractors with established
contracts for hauling are:
Diablo Hitch & Trailer 415/676-4216
IT Corporation 415/228-5100 (24 hr.)

Where CB has a preferred hauling procedure for hauling any item
the name of that hauler has been shown.

’

167
8/81

801

8/81

le

CLEAN BAY CLEANUP EQUIPMENT AND MATERIALS

MOBILE HEADQUARTERS TRAILER

8' x 25' Office Trailer w/tandem axle

Location

Union 011 Refinery, Rodeo, Calif.

Hauling

Union Oil Company will provide a driver and vehicle to deliver
the trailer at any time to a location as directed by Clean Bay.

Call (415) 799-4411, Ext. 471; ask for Bulk Shift Foreman.

If the Bulk Shift Foreman is unavailable, ask for Marine
Terminal Dispatcher. Tell him that you are calling for the
Clean Bay Mobile Headquarters Trailer and give him the exact
location for delivery, your name, company and telephone number.

During Off-Hours -(415) 799-2478 or 799-4411 and ask for the
Bulk Shift Foreman. If the Bulk Shift Foreman is unavailable,
ask for the Marine Terminal Dispatcher and proceed as above.

A list of the equipment in the trailer is as follows:

801-2
168

801 CLEAN BAY CLEANUP EQUIPMENT AND MATERIALS

Mobile Headquarters Trailer - Equipment List

8 Batteries, 1.5 volt, Size C
6 ie , 1.5 volt, Size D
W for. Binoculars
2 Blankets
] Camera, Polarois w/case, film & flash cubes
] Combustible Gas Tester, J-W
Many Directories, Telephone for CB area

Electrical Equipment
gal. Battery Water, Distilled

]

2 Extension cords, McGill, 50 ft.
] Y ela OO} hte

] z ", Hubbell, 50 ft.
] Generator, gasoline, Onan

2 Lights, trouble, McGill

Emergency Equipment, Road

30 Flares, road, 15 min.
3 Flashlights w/batteries
12 Hand Lanterns w/batteries
1 bx. Hand tools, assorted
6 Reflectors, road
4 Fire Extinguishers
] First Aid Kit
4 Folding Chairs
6 Flagpoles, w/CB flags
Many Hardhats
Minor Kitchen Supplies
10 Life Vests, Sterns San-Souci
Maps & Charts
12 California Road Maps
) Map Overlays
2 sets Nautical Charts for CB Area
1 set Petroleum pipeline maps
4 Tide & Current Books, pocket size

2 sets USGS maps for CB Area

801-3
8/81 169

801 CLEAN BAY CLEANUP EQUIPMENT AND MATERIALS

Mobile Headquarters Trailer - Equipment list (cont.)

Office Supplies

1 File
Assorted Forms, supplies
] Tapewriter, Dymo Model 2300 w/case & 6 rolls tape
oi
2 ats. Motor oil, HD SAE 30
1] Funnel

Radio & Telephone
] AM Receiver, Craftsman, multi-band
2 Chargers, Motorola, multi-unit
2 sets Headphones
6 sets Headsets, helicopter
] Marine Base Station, Intech (Channels 10, 16, 18A & 22A)
] Marine Radio Telephone Manual
] Mobile Radio, UHF, Motorola
0 Paksets, 6 watt, Motorola & Cases w/belts
] Scan Receiver, Intech (Channels 10, 16, 18A, 22A & WXI)
2 coils Telephone Cable

12 Raincoats

Recording Equipment
] ape Recorder, Sony Cassetts

Dx. Tapes, Cassette, Sony

—

18 Sample jars, pint

801-4

8/81 170

801 CLEAN BAY CLEANUP EQUIPMENT AND MATERIALS

2. OIL CONTAINMENT BOOM
A - VIKOMA SEAPACK

1600' Ocean boom, 27" float x 17" water tube, stored in
23' boat on trailer.

Location

The complete unit is stored at Diablo Hitch & Trailer,
and is packed for quick deployment

Hauling
Diablo Hitch & Trailer

B - KEPNER SEACURTAIN BOOM

4600 ' - 16" float x 12" curtain; 3/8" chain weight
in curtains.

Location (1) 2000'

Two (2) 35' semi-trailer vans, each containing 1000'
of this boom stored at IT Corporation yard, Martinez.
Each trailer has 5 -200' sections joined by Navy
connectors, making 1000' boom. Boom is packed for
easy deployment; one end with towing bridle attached
is at the rear door and ready to be pulled. The
trailing end of the boom is fitted with a quick
release sea anchor. Navy connectors are installed
at each end so that the two booms can be quickly
joined to create a single 2000' boom.

Hauling (1)

IT Corporation
Location (2) 2600'

Two (2) 40' chassis mounted on ocean container type
vans; one (1) containing 1200' and one (1) containing
1400'. These are stored at Diablo Hitch & Trailer.
One trailer has 6 -200' lengths and one has 7 -200'
lengths joined by Navy connectors. The boom is packed
for easy deployment; one end with towing bridle
attached is at rear door and ready to be pulled. The
trailing end of the boom fitted with a quick release
sea anchor. Navy connectors are installed at each

end so that the 2 booms can be quickly joined to

8/81

801

8/81

CLEAN BAY CLEANUP EQUIPMENT AND MATERIALS

Kepner SeaCurtain/Location 2 (cont. )

create a single 2600' boom. It should be noted that
the 2000' (Location 1) and this 2600' in sea containers
can be joined quickly to form a single 4600' length.

AMERICAN MARINE OPTIMAX BOOM

6400' of 6" float x 12" skirt, "“Optimax' boom
w/universal connectors at each end.

Location (1)

1400' stored in trailer at CB Warehouse. The trailer
contains 14 -100' separated sections with Navy
connectors. In addition, the trailer contains

anchors, lines and floats to deploy the boom.

Hauling (1)

Diablo Hitch & Trailer

Location (2)

5000' in 100' lengths with universal connectors (not Navy

type) located in CB warehouse.

WHITTAKER CORPORATION EXPANDI-BOOM

1640' of 30" Expandi-Boom; manufactured in 82' sections.
This is a fast deployable boom that can be handled by
one or two men; boom weight, 1!3#/ft.

Location

Stored in CB warehouse:

492' on pallett; can be moved by forklift, helicopter
or crane - wt. 1300#, incl. pallet

820' on pallett; can be moved by forklift, helicopter
or crane - wt. 1720#, incl. pallet

328' in 82' sections, boxed and stored in 4 boxes

801-6

1702

801

8/81

CLEAN BAY CLEANUP EQUIPMENT AND MATERIALS

PUMPING EQUIPMENT

Location

All
Awe

located at CB warehouse

TANKER LIGHTERING EQUIPMENT

An ADAPTS type tanker lightering system consisting of:

(1) a 40 HP air-cooled diesel engine prime
mover mounted in a fiberglass container
complete w/hydraulic pump

(2) one (1) 8" submersible pump and one (1) 6"
submersible pump each with 1000 GPM capacity

(3) 1600' of 8" floating discharge hose
800' of 6" " "

(4) accessory equipment for handling prime mover,
pumps and hoses, incl. 1 drum hydraulic oil.

DIAPHRAGM PUMP

Two (2) Wilden MI5B spark free, disphragm pumps;
compressed air driven, 150 GPM w/100 PSI air pressure.

PORTABLE PUMPS,

One (
Two (
One

One

2" gasoline driven, portable pump w/hoses

)
)
) 6" W " uu " u
)

356 CFM portable air compressor

OIL HERDER HELICOPTER SPRAY PUMPING UNIT

One (1) Simplex Pumping Unit; consists of fiberglass
bucket, 150 gal. cap., 3 HP Briggs & Stratton gas
engine and small gear pump, set at 1 GPM flow rate.

Designed as helicopter undersling unit. Includes 4
drums of Shell Oi] Herder.

801-7

IL7/ 3:

801

8/81

CLEAN BAY CLEANUP EQUIPMENT AND MATERIALS

5. SKIMMING EQUIPMENT

A -

MARCO CLASS III OIL RECOVERY VESSELS

1 - M/V Spill Spoiler maintained at San Francisco
Sree y i i "Martinez Marina

These two vessels are 58' x 24' jet propelled Bay
skimmers w/2 -3' wide Martin-Marietta filterbelts
and 90 bbls. onboard storage capacity. Capable of
recovering all grades of oil and debris at 071
recovery rates up to 750 GPM in 3-4 ft. waves.

Can be obtained by calling IT Corporation.
MARCO CLASS I OIL RECOVERY VESSELS

1 - M/V Mini Spoiler maintained at Long Wharf, Richmond

i "Union Oil Co., Rodeo

These two MARCO Class I oil recovery modules are

mounted on a 34' x 10' catamaran and powered by twin

50 HP outboard motors. Floodlights for night operation.
One (1) 500 gal. storage bag towed behind vessel; one (1)
250 gal. storage bag on deck.

Skimmers are stored on three-axle trailers; can be
towed over road to scene or powered through water
at 16 knots.

Require a long launching ramp and high water, or a
10-ton crane for launching.

FLOATING WEIR SKIMMERS

Two (2) Exxon Open Seas 77" dia. floating weir skimmers
designed for use in recovering fairly thick 011] concen-
trated within a boom. Each skimmer equipped with an
air driven pump, 200' of Acme 4" discharge hose w/hose
floats and 150' of 1" Dayco air hose.

Each skimmer weighs 400# and, together with steel
container, grosses 1500#; they require crane for
hoisting and are designed to work in conjunction with
a barge. Air supply can be provided by CB's 356 CFM
air compressor.

Location

Skimmers w/related equipment located in CB warehouse;
portable air compressor located at Diablo Hitch & Trailer.

801-8

174

801

CLEAN BAY CLEANUP EQUIPMENT AND MATERIALS

RAIDER SRV 34' SPILL RESPONSE BOATS

Location

| - Raider boat maintained at Union 0i1 Company, Rodeo
Ties in 0) " Shell Oil Company, Martinez

These boats are shallow draft, all-purpose workboats, each
powered by two (2) 175 HP outboard motors. Cabin equipment
includes radar, radio, compass and depthfinder. The boats
are also equipped with three each quartz-iodine floodlights
for night work. The shallow draft and bow door allows
beaching of boats for loading/unloading personnel and equip-
ment or for cleanup operations in marshes and shallow
water areas. With the portable mop machine and motor
generator (stored in CB warehouse) mounted on deck,
together with 2-3 gal. drums for receiving recovered oil,
these boats become versatile and efficient skimmers.

A wide-load permit is necessary for over-the-road movement,
and the boat/trailer must be clearly and prominently
marked "WIDE LOAD".

BOSTON WHALER 16'

Trailer mounted with 40 HP outboard motor. Towing requires
a 2" ball. Towing and operating instructions are on the
boat.

Location

CB Warehouse

Hauling

No preference; CB company car is fitted to tow this boat
and trailer.

801-9

175

801 CLEAN BAY CLEANUP EQUIPMENT AND MATERIALS

8. SORBENTS & DISPERSANTS

[Ns

Quantity

1 coil
coal
lescon)l
NORGENST
42 bales
8 bxs.
16 rolls
10 ctns.
55 rolls
DX
ctns.
ctns.
ea.
coil
bxs.
bxs.

OX.

— PH MMW MAH AWN

B -

8/81

Sorbent Trailer

35' semi-trailer van; inventory of equipment & supplies
in trailer shown below.

Location - IT Corporation yard, Martinez
Item

Manila rope, 1" (600')

" " Sy/EAW (1200')

" " Wiex (600')
3M Type 270 sorbent booms
3M Type 151/156 pads, 18" x 18" x 3/8"
3M Type 356, 25/bx.

Conwed Sorbent Blankets, 35" x 200' roll

4 Pad seen liviaeexan l/min

: it Rug, 40" x 300' rol}

y i Sweep, 17" x 17", 120/bx.
heavy duty boom, 10" x 8"
Johns-Manville Adsorbent boom, 10/container
Hedwin 5-gal. plastic containers
Rope, wire, 1/2", black (200')

Rags, approx. 3’ x° x 4° boxes

Grefco Sorbent boom

#52 Merrill Drum Lifter Clamp

Morse Model 85A drum carrier

Assorted Shackles w/screw pins, galvanized
Ansul A-5, 5 1b. fire extinguishers

MS Medical First-Aid Kit

Dispersant

50 drums - Corexit 9527 011 Spill Dispersant
Concentrate

Location
IT Corporation yard
Hauling

Not to be moved except by explicit instructions

from CB Manager

801-10

LAS

801

8/81

10:

CLEAN BAY CLEANUP EQUIPMENT AND MATERIALS

PORTABLE RADIO REPEATER TRAILER

This radio repeater trailer can be used in conjunction
with the radio paksets in remote areas to improve
communications. It contains a primary and secondary
radio repeater and has two batteries which make the
repeater independent for 48 hrs. If available, 110 VAC
should be connected to the self-contained battery
Charger. 110 VAC is also available for this unit from
the Floodlight Trailer or from the diesel generating
unit of the Oil Mop machine.

The trailer requires a 2" ball hitch and standard
4-plus, 12 v. electrical adapter to the towing
vehicle for stoplights ana brake lights.

Gross vehicle weight is 20004; it is recommended that
the vehicle be towed with a heavy duty station wagon
or larger. The CB station wagon is equipped with a
2" ball hitch and standard electrical adapter and has
sufficient GVW to tow this trailer.

Location

CB Warehouse

FLOODLIGHT TRAILER

A 12.5 KW Onan diesel-driven generator with four (4)
1500 watt tungsten halogen quartz lights on a telescoping
tower.

Equipment mounted on a 2-wheel trailer requiring a

2 -5/16" ball hitch and standard 4-plug, 12 v. electrical
adapter to the towing vehicle for stoplights and brake
lights. Gross vehicle weight 35604; it is recommended
that this vehicle be towed with a 1/2 t. pickup truck

or larger.

Generator is equipped with a 25', 240 volt, single phase,
female end, standard plus extension cord. A distribution
box contains two 240 volt Single phase, standard female
receptacles and four 120 volt single phase standard female
receptacles. Generator uses No. 2 diesel fuel and has a
tank capacity of 7'3 gals. At full load, it will consume
approximately 1.5 gals/hour.

Location

Diablo Hitch & Trailer yard

801-11

ITY

801 CLEAN BAY CLEANUP EQUIPMENT AND MATERIALS

11. TOOL TRAILER

Trailer requires at least a 1-ton truck to move. Unladen
trailer weighs 6640 lbs. Tongue hitch requires a 2-5/16"
ball or can be converted to a ring hitch; ball and ring
stored in front storage section of trailer. License is
taped to inside front door; trailer has surge brakes on
both axles. Tool trailer inventory listed below.

Location

CB Warehouse

Quantity Item
] Axe
2 Boats, plastic
] Chain Bar & sprocket oi]
] Chain Saw
4 Gas Tanks w/hose attachments (empty)
] Hitch, ball
] ", tow ring
aS Hoes
2 ", large
Uae. Jumper cables
10 Life Jackets
1/2 qt. Oil, 2-cycle
4 Outboard Motors (also shown in whse, inventory) (Item 13)
1 gal. Paint, blue enamel
6 rolls Plastic sheet
12 Pitchforks
100 Rainsuits, vinyl
Os) irs Rubber boots
100 pr. i gloves
21 Shovels (19 square/3 round)
2 Sledge hammers
7 Sickles, long handle
13 w » short
] Spray nozzle
1 roll Twine
Tool Box No. 1
1 bx. ea. Bolts & Nuts, 5/8
4 Drum lifting clamps
2 Mechanics Wire, 5#

801-12

8/8]

801 CLEAN BAY CLEANUP EQUIPMENT AND MATERIALS

Tool Trailer Inventory (continued)

Quantity [Seecm

Tool Box No. 2

Bolt Cutters
Flashlights (w/o batteries)
Hammers, machinists
Knives, utility
Pliers
Saw, hand
", pruning
Strap
Wrench, adjustable

AH HAHN NHWU—

801-13

197.9
8/8]

801 CLEAN BAY CLEANUP EQUIPMENT AND MATERIALS
12. ADDITIONAL WAREHOUSE INVENTORY
Following is a list of other items available in the
Clean Bay Warehouse:
Quantity iestrenm
Absorbents - see Sorbent
2 Anchors, Danforth (225) w/att. rope & chain
Belts & Filterpads
4 sets MARCO Class III Filterpads (5 pads/set)
4 sets " a " (4 pads/set)
2 ea 3' Backing Belts, MARCO III
4 ea. ] ! u it} " if
3 Bird Scare-Away Guns w/2 propane bottles
] Bird Scarer (Av-Alarm)
Boats
2 Skiffs, Aluminum, 10' John Boats
2 au » Plastic, Pioneer 12, unsinkable
Booms
500 ft. AQUAFENCE boom, 12' x 12", in 5 fiberglass containers
30" x 46" x 90". Belt type w/rigid plastic
floats
Boom Accessories
Assorted Repair Kits, connectors, etc.
14 Buoys, mooring
8 Containers, trash, plastic
1 drum Diesel fuel
8 rolls Fencing, Chain link, plastic w/spreader bars
] Forklift, Clark, electric
1 set Forklift extension
4 Heaters, electric, Arvin
Hose (palletized)
C5 Omititr 8" transfer hose, 25' & 50' lengths
525 ft ‘ 6" iu u u mu u
900 ft. 3" vacuum hose
ZOO): ise Ve 8 a
200) Ft. Wan ® v
400 ft. hydraulic hose
400 ft. air hose
801-14
8/81

180

801 CLEAN BAY CLEANUP EQUIPMENT AND MATERIALS

Additional Warehouse Inventory (continued)

Quantity Item
] Inflatable Life Raft (15 person cap.)
10 ife Vests

Oil Skimmers

077-HAWG

Oil Mop, Model I-4E, w/3.5 KW M-G set
Skim Paks (for use with vac. hose)
Skimmer - Skim, Inc.

—npmo oo

Outboard Motors

2 50 HP Johnson Outboard (spares for Mini I & II)
2 15 HP Evinrude " w/gas tanks (In Tool Trir.) (Item 11)
2 6 HP " " Ty " u (a i u ) ( i ")
Pipe Fittings, misc.
Pumps
] Barrel pump
] Radio Repeater Trailer
200 ft. Rope, polypropylene
Sorbents
The warehouse carries a small sorbent inventory of
various sizes and types for current usage. Deployable
sorbent inventory is in the Sorbent Trailer (Item 8).
é Winches - air driven w/stands
8/81 801-15

alts}

801

8/81

lish

CLEAN BAY CLEANUP EQUIPMENT AND MATERIALS

EQUIPMENT UNDER LEASE T0 CLEAN BAY

Contractor: Marine Pollution Control Service, Inc.
305 First Street
Benicia, CA 94510

J. L. Garske, Jr.
(707) 745-2949 (24 hr.)

Equipment located at Exxon Crude Dock, Benicia:

2 Mark II O71 Skimmers
1 56' LCM Boat, SPONGE

Equipment located at C&H Sugar Co. Wharf, Crockett:

2 Mark II Oi] Skimmers
1 56' LCM Boat, SQUEEGEE

801-16

182

APPENDIX F

PREDICTION OF OIL SPILL MOVEMENT

OIL SPILL CONTINGENCY PLAN FOR THE SANTA MARIA BASIN
ARCO OIL & GAS CO., 1982

133

121° 120°

Grover City

4s

35°

36 nautical miles

24 =
, e 1” =approximately
12 Ne Point Sal Santa Maria 11 nautical mites
24
LEGEND
12

Spill Movernent
Direction in

Purisima Point 12 Hours

Point Arguello

Point
Conception

ma Coal Oil Point

18

San Miguel Island

Santa Rosa
Island

Figure 2-3. PREDICTION OF SPILL MOVEMENT-JANUARY

134

1219 120°

te) 5 10
Ee

“ A Oo
nautical miles 35

1” = approximately
Santa Maria

11 nautical miles

LEGEND

Spill Movernent
—e Direction in
Purisima Point 12 Hours

Point Arguello

Point
Conception

Coal Oil Point

LL

San Miguel Island

34°
Santa Rosa

Island

Figure 2-4. PREDICTION OF SPILL MOVEMENT-FEBRUARY

185

1212 120°

t)
nautical miles 38

e 1" = approximately
Santa Maria 11 nautical miles

LEGEND

Spill Movernent
Direction in
Purisima Point 12 Hours

Point Arquello

3 Coal Oil Point

San Migue! Island 34°
Santa Rosa
Island

Figure 2-5. PREDICTION OF SPILL MOVEMENT-MARCH

186

121°

e
Santa Maria

Purisima Point

Point Arguello

18 :
Conception

San Miguel Island

Figure 2-6. PREDICTION OF SPILL MOVEMENT-APRIL

- 187

ie) 5 10
ee eS |

i 5 °
Nautical miles 35
1” = approximately

11 nautical miles

LEGEND

Spill Movement
Direction in
H

12 ours

Coal Oil Point

34°

Santa Rosa
Island

Grover City

ie) 5 10

=
°
Nautical miles 35

@ uae

= approximately
Point Sal Santa Maria

11 nautical miles

LEGEND
Spill Movement

— > Direction in
Purisima Point 12 Hours

Coal Oil Point

San Miguel Island

34°
Santa Rosa

Island

Figure 2-7. PREDICTION OF SPILL MOVEMENT-MAY

188

121° 120°

ie) 5 10
———EEE—EE |

Nautical miles

359

) 1" =approximately
Point Sal Santa Maria 11 nautical miles

LEGEND

Spill Movement
Direction in
Purisima Point 12 Hours

Point Arquello

Conception

Coal Oil Point

ELS.

San Miguel Island

Santa Rosa
Island

Figure 28. PREDICTION OF SPILL MOVEMENT-JUNE

1'3'9

121° 120°

Grover City

5 10
5 ‘ o
Nautical miles 28)
e 1” = approximately

Santa Maria 11 nautical miles

LEGEND

Spill Movement
Direction in
Purisima Point 12 Hours

Point Arquello

Coal Oil Point

San Miguel Island 34°
Santa Rosa
Island

Figure 2-9. PREDICTION OF SPILL MOVEMENT-JULY

£90

121° 120°

2 a °°
nautical miles 35

e 1° = approximately
Santa Maria 11 nautical miles

LEGEND

Spill Movernent
Direction in
Purisima Point 12 Hours

Point Arguello

Coal Oil Point

San Miguel Island
Santa Rosa
Island

Figure 2-10. PREDICTION OF SPILL MOVEMENT-AUGUST

191

121° ; 120°

Grover City

oO
nautical miles a)

e 1" =approximately
Point Sal Santa Maria 11 nautical miles

LEGEND

Spill Movement
Direction in
Purisima Point 12 Hours

4 Z 4
2 Point Conception

30 Coal Oil Point

San Miguel Island 34?
Santa Rosa
Island

Figure 2-11. PREDICTION OF SPILL MOVEMENT-SEPTEMBER

192

1219

Grover City

e
Point Sal Santa Maria

Purisima Point

Point Arguello

Point
Conception

foes

San Miguel Island

Figure 2-12. PREDICTION OF SPILL MOVEMENT-OCTOBER

19) 3}

120°

te) 5 10
EE)

+ 2 (2)
nautical miles 35

1” = approximately
11 nautical miles

LEGEND
Spill Movement

Direction in
Hour.
12 lours

Coal Oil Point

Santa Rosa
Island

121°

e
Point Sal Santa Maria

Very Slow
Movement

/ Wind Offsets
Water Current

Purisima Point

Point Arquello

Point
Conception

ON

San Miguel Island

Figure 2-13. PREDICTION OF SPILL MOVEMENT-NOVEMBER

194

120°

Q 5 10

—— EE

°
nautical miles 35

1" = approximately
11 nautical miles

LEGEND

Spill Movernent

—_ Direction in
12

Hours

Coal Oil Point

34°
Santa Rosa

Island

1219 120°

35°

Nautical miles

e 1" = approximately
Santa Maria 11 nautical miles

LEGEND

438

Spill Movement
Direction in
Purisima Point 12 Hours

Point Arguello

Point
Conception

Coal Oil Point

BLS

San Miguel Island

Santa Rosa
Island

Figure 2-14. PREDICTION OF SPILL MOVEMENT-DECEMBER

195

APPENDIX G

PREDICTION OF OIL SPILL MOVEMENT
OIL SPILL CONTINGENCY PLAN
TROUT PROSPECT
OCS LEASE NO. P-0435

SHELL OIL CO., 1982

196

121° 120°

0 5 10
——————

e fe °
nautical miles 35

1” = spproximately
11 nevtical miles

C)
Santa Maria

LEGEND

Spill Movement

——-> Direction in
Purisima Point 12 Hours

Coal Oil Point

San Miguel Island
Santa Rosa
Island

Figure 1. PREDICTION OF SPILL MOVEMENT- JANUARY

10/82

ILS) 7/

121° 120°

0 5 10

_————EEE |

nautical miles

1° = approximately
11 nautical miles

e
Santa Maria

LEGEND

Spill Movernent
fae Direction in
Purisima Point 12 Hours

Conception

San Miguel Island

Santa Rosa
Island

Figure 2. PREDICTION OF SPILL MOVEMENT: FEBRUARY

10/82

121°

®
Santa Maria

Conception

San Miguel Island

Figure 3. PREDICTION OF SPILL MOVEMENT- MARCH

10/82
199

120°

0 5 10
LE

Nautical miles

1° = approximately
11 nautical miles

LEGEND
Spill Movement

te Direction in

12 Hours

Coal Oil Point

Santa Rosa
Island

LY) 5 10

——————E,

nautica! miles

1° = approximately
11 nsutical miles

®
Santa Maria

LEGEND

Spill Movernent
Direction in
12 Hours

Conception

San Miguel Island

Figure 4. PREDICTION OF SPILL MOVEMENT- APRIL

10/82

121° 120°

i] 5 10
—————E

nautical miles

1” = approximately
11 nautical miles

9
Santa Maria

LEGEND
Spill Movernent

ota Direction in
Purisima Point 12 Hours

Point Arguello

Point Conception

San Miguel Island
Santa Rosa
Island

Figure 5. PREDICTION OF SPILL MOVEMENT: MAY

10/82

121° 120°

i) 5 10

EEE

Nautical miles 35°

1” = approximately
11 nautical miles

e
Santa Maria

LEGEND
Spill Movernent

—- Direction in
Purisima Point 12 Mours

Conception

San Miguel Island

Santa Rosa
Island

Figure 6. PREDICTION OF SPILL MOVEMENT- JUNE

10/82

2012

121° 120°

0 5 10
——EEE)

Nautical miles

1” = approximately
11 nautical miles

e
Santa Maria

LEGEND
Spill Movement

= Direction in
Purisima Point 12 ory

Point Arguello

Coal Oil Point

San Miguel Island

Santa Rosa
Island

Figure 7. PREDICTION OF SPILL MOVEMENT- JULY

10/82

121° 120°

i?) 5 10
_—E

nautical miles

35°

e 1” = spproximately
Santa Maria 11 nautical miles

24 Point Arquello

48 Point

Conception

Coa! Oil Point

San Miguel Island

Santa Rosa
Island

Figure 8. PREDICTION OF SPILL MOVEMENT- AUGUST

10/82
204

421° 120°

t+) 5 10
EE

nautical miles

1” = approximately
11 neutical miles

)
Santa Maria

LEGEND
Spill Movement

aa Direction in
12 Hours

Point Conception

San Miguel! Isiand
Santa Rosa
Island

Figure 9. PREDICTION OF SPILL MOVEMENT-SEPTEMBER

10/82

0 5 10
—

nautical miles

e 1” = approximately
Santa Maria 11 nautical miles

LEGEND

Spill Movernent
Direction in
Purisima Point 12 Hours

Point Arguello

San Miguel Island
Santa Rosa
Island

Figure 10. PREDICTION OF SPILL MOVEMENT- OCTOBER

10/82
206

421° 120°

t] 5 10

————EE

Nautical miles

1” = epproximately
11 nautical miies

e
Santa Maria

LEGEND
Spill Movernent

Direction in
12 Hours

Conception

San Miguel Island

Santa Rosa
Island

Figure 11. PREDICTION OF SPILL MOVEMENT- NOVEMBER

10/82

921° 120°

0 -} 10
EEE

nautical miles 35°

1” = approximately
11 nautical miles

®
Santas Maria

LEGEND
Spill Movement

=> Direction in

12 fours

San Miguel island

Santa Rosa
Island

Figure 12. PREDICTION OF SPILL MOVEMENT- DECEMBER

10/82
208

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