HomeMy WebLinkAbout1.0 ApplicationGARFIELD COUNTY
Building & Planning Department
108 8th Street, Suite 401
Glenwood Springs, Colorado 81601
Telephone: 970.945.8212 Facsimile: 970.384.3470
www.qarfield-county.com
RECENED
FEB 1 9 2009
GARFIELD COUNTY
BUILDING & PLANNING
P ynO9
ID PIPELINE DEVELOPMENT PLAN
LD PIPELINE DEVELOPMENT PLAN AMENDMENT
(Check the box that applies)
GENERAL INFORMATION (Please print legibly)
➢ Name of Pipeline Owner: Enterprise Gas Processing, LLC
➢ Mailing Address: 1100 Lousiana Telephone: (303 )820-5607
➢ City: Houston State: TX Zip Code: 77002 Cell: (303 ) 319-6034
➢ E-mail address: Deru, P.E. email: jcderu@epco.com (303 ) 820-5601
D. Name of Owner's Representative, if any, (Attorney, Planner, Consultant, etc):
➢ PVCMI- Land Planning Division
➢ Mailing Address: 1038 County Road 323 Telephone: (970 )625 5350
D. City: Rifle State: CD Zip Code: 81650 Cell: (970 )379-0428
➢ E-mail address:phil@pvcmi.com FAX: (970 )625-4522
). Description of Project: Request for the installation of a concrete batch plant for the sole use
of construction of the Jackrabbit Compressor Station
➢ General Location of Pipeline (Right -of -Way): Discharge line termination: Section 13, T6S
R96W. Jackrabbit Compressor Station Section 33, T5S, R96W. North tie-in point to Enterprise PCP
Pipeline Section 7, T5S, R96W.
➢ Diameter and Distance of Pipeline: 3.7 miles of 20" diam. suction/5.5 miles of 16" diam disch.
D. General Legal Description: Please see Tab 5 of the original application
➢ Existing Use: Agricultural and Natural Resources Development
D.Pipeline ROW Distance (in acres) No additional disturbance
➢ Zone District: Resource Lands
Last Revised 1/1/09
promptly forward one copy to the County Road & Bridge, Oil & Gas Auditor,
Vegetation Management and Engineering Departments; the appropriate fire district
or County Sheriff; the surface owners of an individual pipeline development plan;
and any adjacent municipality for comment.
a. Referral comments on the proposed development shall be returned to the
Planning Director no later than 18 days from the date of application for an
individual site application and 30 days from the date of application for an
area development plan.
3. Notice (Section 9-105(B)). Once the application has been deemed technically
complete, the applicant shall notify the property owners within 200 feet of the route
that are not affected surface owners with an agreement with the applicant. A sign
(provided to the Applicant by the Planning Department) will be posted on the
portions of the route crossing or adjacent to a public road within seven days after
receiving a complete application for an individual development plan review. Both
the notice and the sign shall indicate that a development plan review application
has been made, and the phone number of the Planning Department where
information regarding the application may be obtained.
4. Director Review & Decision (Section 9-105(D)) Any determination by the Planning
Director to approve or conditionally approve a development plan application must
be in writing and mailed or otherwise provided to the applicant no later than 28 days
for an individual pipeline development plan or 60 days for an area pipeline
development plan, after the date on which the development plan application is filed.
Failure to make a determination on the application within this time period shall
result in the application being considered approved and the applicants building
permit or access, or other permits being processed, provided the applicant builds
the pipeline in compliance with the application.
5. Board of County Commissioner "Call -Up" (Section 9-109) Once the Director has
determined the application to be approved, the Director will immediately notify the
Board of County Commissioners (BOCC) of the approval. From this point, the
BOCC has 14 calendar days to call-up the application. No development can occur
of the pipeline project until this period has elapsed and the conditions of approval
have been met.
I have read the statements above and have provided the required attached information
which is correct and accurate to the best of my knowledge.
\INA 2/19/09
(Signature of Owner of Right -of -Way) Date
GARFIELD COUNTY BUILDING AND PLANNING DEPARTMENT
PAYMENT AGREEMENT FORM
(Shall be submitted with application)
GARFIELD COUNTY (hereinafter COUNTY) and Enterprise Gas Processing, LLC
Property Owner (hereinafter OWNER) agree as follows:
1. OWNER has submitted to COUNTY an application for Amendment to the
Marathon Gathering System (hereinafter, THE PROJECT).
2. OWNER understands and agrees that Garfield County Resolution No. 98-09, as
amended, establishes a fee schedule for each type of subdivision or land use review
applications, and the guidelines for the administration of the fee structure.
3. OWNER and COUNTY agree that because of the size, nature or scope of the
proposed project, it is not possible at this time to ascertain the full extent of the costs
involved in processing the application. OWNER agrees to make payment of the Base Fee,
established for the PROJECT, and to thereafter permit additional costs to be billed to
OWNER. OWNER agrees to make additional payments upon notification by the COUNTY
when they are necessary as costs are incurred.
4. The Base Fee shall be in addition to and exclusive of any cost for publication or
cost of consulting service determined necessary by the Board of County Commissioners for
the consideration of an application or additional COUNTY staff time or expense not covered
by the Base Fee. If actual recorded costs exceed the initial Base Fee, OWNER shall pay
additional billings to COUNTY to reimburse the COUNTY for the processing of the
PROJECT mentioned above. OWNER acknowledges that all billing shall be paid prior to
the final consideration by the COUNTY of any land use permit, zoning amendment, or
subdivision plan.
PROPERTY OWNER (OR AUTHORIZED REPRESENTATIVE)
atQl
2/19/09
Signature Date
Philip Vaughan- PVCMI-Land Planning Div.
Print Name
Mailing Address:
1038 County Road 323
Rifle, CO 81650
Page 4
VA4IAN
CONSTR 16.TION
MAMA BIENT,
1038 Courrry Rd 323 k®s RiflE, CO 81650
INC.
February 19, 2009
Mr. Fred Jarman
Director
Garfield County Building and
Planning Department
108 8th Street, 4th Floor
Glenwood Springs, CO 81601
Dear Mr. Jarman,
Please consider this letter and associated attachments an amendment to the Revised Second
Amended Administrative Permit issued on 2/13/09 for the Development Plan Review for Right -
of -Way for the Enterprise Gas Processing, LLC -Marathon Gathering System.
As per section 9.07.13 of the Garfield County Zoning Resolution of 1978 "9.07.13 Amendments
to a Development Plan: Any proposal to change a development plan approved under this
Resolution shall require an application to the Planning Department to determine whether the
proposed change constitutes a substantial modification to the approved plan."
I refer to the 1978 code as this application was approved under the previous code.
Please find attached the following documents:
1. Garfield County Pipeline Development Plan Amendment Application and Payment
Agreement Form.
2. Revised Second Amended Administrative Permit for Enterprise Gas Processing, LLC
dated 2/13/09
3. Drawing "Jackrabbit Compressor Station- Plot Plan- Drawing P13436-976-300". This
drawing notes the proposed concrete batch plant in the North half of the 200'x300'
Summit Structures, temporary enclosure. If the 200'x300' structure is not built, this
facility will be uncovered.
4. Updated Spill Prevention, Control, and Countermeasures Plan for Jackrabbit Compressor
Station dated February 2009.
5. Portable Concrete Batch Plant- CDPHE- Construction Air Permit 08P01188 dated
January 30, 2009.
6. Photos of Port -a -Pour Concrete Batch Plant Equipment
Page 1 of 3
Amendment Overview
The construction of the Jackrabbit Compressor Station requires the batching of concrete for use
in equipment support systems, building foundation systems and pipe rack support footings.
Enterprise Gas Processing has hired Optimized Process Designs (OPD) to construct the
Jackrabbit Compressor Station.
OPD has contracted with Northwest Ready Mix, Inc. to supply the concrete for the project.
Northwest Ready Mix has secured a Construction Air Permit for the mobile concrete batch plant.
The on-site concrete batch plant is proposed to be located in the North half of the 200'x300'
Summit Structures, temporary enclosure. If the 200'x300' structure is not built, this facility will
be uncovered.
There are a number of benefits afforded to the project and to the public in regards to the
placement of the concrete batch plant on-site.
A. Traffic
1. Cement, sand and aggregate will be hauled to the site in larger belly -dump type trucks.
a. This effectively reduces the number of truck trips to the project. A standard
concrete ready mix truck will carry approximately 10 cubic yards of concrete.
This ready mix truck will no longer come to the jobsite from a remote concrete
batch plant as it will be stationed on-site.
b. Cement, sand and aggregate will be hauled to the site in 20 cubic yard belly -
dump type trucks. Water will be brought to the site in tankers. The same tonnage
of materials is being delivered to the jobsite, it is occurring in less trips because of
utilizing higher capacity transits.
B. Quality Control/Quality Assurance
1. The travel time from remote concrete batch plants to the Jackrabbit Compressor
Station can exceed 1.5 hours, not accounting for weather delays. Having the concrete
batch plant on-site will increase the quality of the concrete product and will reduce, if not
eliminate, the possibility of concrete cold joints. "Clean-up" loads and overage loads and
the associated traffic and concrete placement delay will also be eliminated by having the
concrete batch plant on-site.
We also believe that the on-site concrete batch plant will allow for an accelerated project
schedule which is a benefit for the project and the public.
We have attached the revised SPCC and the construction air permit for your review and
consideration.
Page 2 of 3
The existing administrative permit conditions remain applicable to this change as well.
In order to determine if there is a Substantial Change to the Marathon Gathering System
Administrative Permit, I have reviewed the definition.
"Substantial Change" is defined within the 2009 Unified Land Use Resolution as:
"Substantial Change. A change to an existing approved land use resulting in one or more of the
following:
1. A change in land use category.
2. A change in site design which increases
a the number of dwelling units
b. the maximum square footage of structures less than 10,000 sq. ft. over 100%
and structures over 10,000 sq. ft. by 10%, if a maximum has been specified in
a permit or approval.
c. projected traffic such that a highway access permit or an amendment to a
highway access permit is required as a result of the change.
d. the size of the land which is the subject of the permit or approval
3. A change in land use which creates or increases the incompatibility of the use.
After review, it is my interpretation that the requested amendment is not a "Substantial Change"
to the Marathon Gathering System Administrative Permit.
Please let me know if you agree with the assessment that this request is not a "Substantial
Modification" to the Marathon Gathering System Administrative Permit and thus Enterprise Gas
Processing, LLC is entitled to proceed with the installation of the on-site concrete batch plant.
Thank you for your assistance on this project.
Please contact me with any questions.
Sincerely
n
ali
Philip B. Vaught
President
PVCMI-Land Planning Division
Page 3 of 3
JtN-30-2029 14:20 From:RIR POLLUTION SSP To:19709245166
F'aoe:e/H
STATE OF COLORADO
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
AIR POLLUTION CONTROL DIVISION
TELEPHONE: (303) 692-3150
111
CONSTRUCTION PERMI
PERMIT NO: 08P01188
INITIAL APPROVAL
DATE ISSUED: January 30,2009
ISSUED TO: Northwest Ready Mix Portable Operations, Inc.
THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS:
Portable conrete batch plant, home based at 2930 E. US Highway 40, Craig In Garfield County,
Colorado.
THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING:
One (1) Port -a -Pour, 10, DB20307, concrete mix batch plant rated at 100 cubic yards per hour.
One (1) Port -a -Pour, Series 1I, silo with 66,000 cubic yards capacity, and
One (1) Port -a -Pour, port silo with 150,000 cubic yards capacity.
This plant is equipped with dust collector vented into a baghouse, and watering to control
particulate emissions.
THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR
QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL
ACT C.R.S. (25-7-101 et seri), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS
DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS:
1. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source.
During periods of startup, process modification, or adjustment of control equipment visible emissions
shall not exceed 30% opacity for more than six minutes In any sixty consecutive minutes. EPA Method
9 shall be used to measure opacity. (Reference: Regulation 1, Section II.A 1.l 4.)
2. The permit number shall be marked on the subject equipment for ease of Identification. (Reference:
Regulation No. 3, Part B, III.E,) (State only enforceable)
3. This source shall be limited to a maximum production rate as listed below and all other activities,
operational rates and numbers of equipment as stated in the application. Annual records of the actual
production rate shall be maintained by the applicant and made available to the Division for inspection
upon request. (Reference: Regulation 3, Part B,II.A.4)
Concrete production rate shall not exceed 50,000 cubic yards per year.
4. Emissions of air pollutants from point sources shall not exceed the following limitations (as calculated in
the Division's preliminary analysis). Point sources Include: sand and aggregate transfers, silo loading,
bucket elevator, weigh hopper loading, mixer loading, and truck loading. (Reference: Regulation 3, Part
B, II.A.4)
Particulate Matter (TSP): 1.5 tons per year.
Particulate Matter Matters 10 pm (PM10): 0.7 tons per year.
77713313/001
Page 1 of 7
JRN-:SN-'ab'J 14: 1-'ULLU I lUN b: r
Bill Ritter, Jr„ Governor
James 13 Martin, Executive Director
Dedicated to protecting and Improving the health and environment or the people or Colorado
Laboratory Services Division
8100 Lowry Blvd.
Denver, Colorado 80230-6928
(303)802.3090
1 0; 17 f ielO tJit
rdye. 1'C�
STATE. OF COLORADO
4300 Cherry Creek Dr S.
Denver, Colorado 80246.1630
Phone (303) 892.2000
TDD Line (303) 691-7700
Located m Glendale. Colorado
hltpJ/www.Cdphe,slate,co.UA
TO: PP to
FAX #:
FROM:
PHONE:
DATE:
AIR POLLUTION CONTROL DIVISION
STATIONARY SOURCES PROGRAM
FACSIMILE TRANSMISSION
0;\ 10- c.6,
—4
TOTAL NUMBER OF PAGES (including cover sheet);
Our Fax: 003)782-0278 -
Verification #: (303)692-3100
COMMENTS:
Colorado Department
of Public Health
and Environment
JON -30-2009 14:21 Frorn:AIR PULLUIIIJN SSI-" ra9e:..vo
Colorado Department of Public Health and Environment
Air Pollution Control Division
Northwest Ready Mix Portable Operations, Inc.
Permit No.: 08P01188
INITIAL APPROVAL
5. Emissions of fugitive particulate natter and fugitive particulate matter of less than ten microns (PM10)
shall not exceed the following limits. Fugitive emissions include: wind erosion from exposed areas and
stockpiles, and vehicular traffic. These emission limits are based on the production rates listed above.
The Division assumes that these levels are being met if the control measures stated in the approved
control plan are followed arid the stated process rates are not exceeded.
Particulate Matter (TSP): 3.4 tons per year.
Particulate Matter Matter<10 pm (PM,o): 1.6 tons per year.
A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Reg 3, Part A,ILC)
a. Annually whenever a significant increase in emissions occurs as follows:
For any criteria pollutant:
For sources emitting less than 100 tons per year, a change in actual emissions of five tons per
year or more, above the level reported on the last APEN; or
b. Whenever there is a change in the owner or operator of any facility, process, or activity; or
c. Whenever new control equipment is installed, or whenever a different type of control equipment
replaces an existing type of control equipment; or
d. Whenever a permit limitation must be modified; or
e. No later than 30 days before the existing APEN expires.
f. This source is subject to New Source Performance Standards requirements of Regulation No. 6,
Part 6, Section III, Standards or Performance for New Manufacturing Processes — Standard for
Particulate Matter.
In addition, the following requirements of Regulation No. 6, Part A, Subpart A, General Provisions, apply.
a. At all times, including periods of start-up, shutdown, and malfunction, the facility and control
equipment shall, to the extent practicable, be maintained and operated in a manner consistent with
good air pollution control practices for minimizing emissions, Determination of whether or not
acceptable operating and maintenance procedures are being used will be based on information
available to the Division, which may include, but is not limited to, monitoring results, opacity
observations, review of operating and maintenance procedures, and inspection of the source.
(Reference: Regulation 6, Part A. General Provisions from 40CFR60.11)
h. No article, machine, equipment or process shall be used to conceal an emission, which would
otherwise constitute a violation of an applicable standard, Such concealment includes, but is not
limited to, the use of gaseous diluents to achieve compliance with opacity standard or with a
standard, which Is based on the concentration of a pollutant in the gases discharged to the
atmosphere. (§ 60,12)
c. Written notification of construction and Initial startup dates shall be submitted to the Division as
required under § 60.7.
d. Records of startups, shutdowns, and malfunctions shall be maintained, as required under § 60 7
777133131001
Page 2 of 7
.JAN -30-2009 14:21 hrom:H1K NULLUIIUN 551'
Colorado Department of Public Health and Environment
Air Pollution Control Division
Northwest Ready Mix Portable Operations, Inc.
Permit No.: 00P01188
INITIAL APPROVAL
7. The particulate emission control measures listed on the attached page (as approved by the Division)
shall be applied to the particulate emission producing sources as required by Regulation No 1, Section
Ili D.1,b.
8 The baghouse control device installed shall be monitored, inspected, maintained and operated
according to the manufacturer's recommendations on an ongoing basis to ensure that emission limits in
condition no 4 above are not exceeded. (Reference: Regulation No.3, Part 8, Section III.E.)
9 When relocating this equipment the owner or operator shall (Reference: Regulation No. 3, Part A,
Section II.C.1.f and Part 8, Section
a Submit a Relocation Notice each time this equipment is moved to a new location within the State
of Colorado, Such notice shall be received by the Division at least ten (10) days prior to the
change in location.
1). The Relocation Notice shall Include a facility emission inventory that includes all emission
units at the site being located to.
2). Records shall be kept of all additional requirements that are Triggered by the relocation
including, but not limited to:
a) State or Federal New Source Performance Standards (NSPS), National Emission
Standards for Hazardous Air Pollutants (NESHAP), Maximum Achievable Control
Technology (MACT), Generally Available Control Technology (GACT) requirements
b). Major source requirements
i• Title V Operating Permits
ii. Prevention of Significant Deterioration (PSD)
c), Permitting of previously Air Pollutant Emission Notice (APEN) required, permit
exempt sources that are no longer permit exempt due to the relocation of this unit to
the site.
3). Provide ambient air quality Impact analysis, or data require to perform such analysis, If so
requested by the Division,
b. Keep a record of all relocation notices submitted to the Division
c. Shall submit a complete emissions inventory and an ambient air quality Impact analysis for
the site with the first Relocation Notice for this equipment. (For information on ambient air
quality impact analysis see the Division's modeling guidance at
http:l/www.cotorado.gov/airqualltylpermits.aspx)
10, This unit shall not remain at any one site for more than two (2) years. Permittee shall keep records of
time spent at each site (Reference: Regulation No, 3, Part A, 1.13.34, ). If this unit remains at a site for two
years then the permittee shall submit a revised Air Pollutant Emission Notice (APEN) requesting a
permit as a non-portable stationary source.
Note: If this replaces a unit and is intended to perform the same function as the unit being replaced
then the cumulate time for both units, including the time between removal of the original unit and
installation of the replacement unit, will be counted toward the total time spent at the site.
777/33131001
Page 3 of 7
JON -30-2009 14:21 h r om: H1K NIJLLU I lIJN &zit'
I o: 17(Uti 4JlbO ra�r•� o
Colorado Department of Public health and Environment
Air Pollution Control Division
Northwest Ready Mix Portable Operations, Inc.
Permit No.: 08P01188
INITIAL APPROVAL
11, If this source relocates to a site causing the facility to become Title V Operating Permit major (see
Regulation No. 3, Part A, I.B.23.) or relocates to an existing Title V Permitted source then this source is
subject to the provisions of Regulation No. 3, Part C, Operating Permits (Title V of the 1990 Federal
Clean Air Act Amendments). The application for the Operating Permit, or modification for inclusion in the
existing Operating Permit, is clue within one year of the date of relocation to the site.
12 Appropriate permitting shall occur If this source is relocated to a facility resulting in that facility becoming
a Major Source for Operating Permit purposes, or Major Stationary Source, or Modification for
Prevention of Significant Deterioration purposes
13, The manufacturer, model number and serial number of the subject equipment shall be provided In the
Division within one hundred and eighty days (180) after commencement of operation. (Reference:
Regulation No. 3, Part B, Section III.E.)
14. Within one hundred and eighty days (180) after commencement of operation, compliance with the
conditions contained on this permit shall be demonstrated to the Division. It is the permlttee's
responsibility to self certify compliance with the conditions. Failure to demonstrate compliance within 180
days may result In revocation of the permit (Information on how to certify compliance was mailed with
the permit.)
15 This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does
not commence construction/modification or operation of this source within 18 months after either the
date of Issuance of this initial approval permit or the date on which such construction or activity was
scheduled to commence as set forth in the permit application associated with this permit, (ii)
discontinues construction for a period of eighteen months or more; or 011) does not complete
construction within a reasonable time of the estimated completion date (See General Condition No, 6.,
Item 1.). Upon a showing of good cause by the permittee. the Division may grant extensions of the
permit. (Reference: Regulation No. 3, Part B, Section 111.F.4.)
y Sund adeyi, I .E. yf R K Hance ck II, P.E.
Permit Engineer Unit Leader
777/3313/001
Page 4 of 7
,Jfttd- 313 - 21309 14:21
From:AIR HILLUI IUN '5I-' 10:1'ilibc'D1bb
d Je.0 u
Colorado Department of Public Health and Environment
Air Pollution Control Division
Northwest Ready Mix Portable Operations, Inc.
Permit No.. 08P01188
INITIAL APPROVAL
Notes to Permit Holder:
1). The production or raw material processing limits and emission limits contained In this permit are based
on the production/prooeSsIng rates requested in the permit application These limits may be revised
upon request of the permittee providing there is no exceedance of any specific emission control
regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and
application form must bo submitted with a request for a permit revision.
2). This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense
Provision for Excess Emissions During Malfunctions. The permittee shall notify the Division of any
malfunction condition which causes a violation of any emission limit or limits stated in this permit as
soon as possible, but no later than noon of the next working day, followed by written notice to the
Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions Regulation
3). The emission levels contained in this permit are based on the following normalized emission factors.
Process Emissions;
Particulate Matter (TSP),
Particulate Matter Matter<10 microns (PM,o):
Fugitive Emissions;
Particulate Matter (TSP).
Particulate Matter Matter<10 microns (PM1o):
4). This source is classified as a: Minor source.
777/33131001
0.06110 pounds per cubic yard of concrete produced.
0.02010 pounds per cubic yard of concrete produced.
0.13667 pounds per cubic yard of concrete produced.
0.06508 pounds per cubic yard of concrete produced
Page 5 of 7
JAtI-30-2009 14:e1 From:AIR POLLUTION SSP
T o: 1970824516E I-' a 9e : r/U
Colorado Department of Public Health and Environment
Air Pollution Control Division
Northwest Ready Mix Portable Operations, Inc.
Permit No.; 08P01188
INITIAL APPROVAL
PARTICULATE EMISSIONS CONTROL PLAN FOR MATERIAL PROCESSING ACTIVITIES
THE FOLLOWING PARTICULATE EMISSIONS CONTROL MEASURES SHALL BE USED FOR COMPLIANCE
PURPOSES ON THE ACTIVITIES COVERED BY THIS PERMIT, AS REQUIRED BY THE AIR QUALITY
CONTROL COMMISSION REGULATION NO.1, Section III.D.1.b. THIS SOURCE IS SUBJECT TO THE
FOLLOWING EMISSION GUIDELINES.
a Processing Activities - Visible emissions not to exceed 20%, no off -property transport of visible
emissions.
b Haul Roads - No off -property transport of visible emissions shall apply to on-slte haul roads, the
nuisance guidelines shall apply to off-site haul roads.
c. Haul Trucks - There shall be no off -property transport of visible emissions from hauls trucks when
operating on the property of the owner or operator. There shall be no off -vehicle transport of visible
emissions from the material in the haul trucks when operating off of the property of the owner or
operator.
CONTROL. MEASURES
1 Material stockpiles shall be watered as necessary to control fugitive particulate emissions. Aggregate
materials shall be sprayed with water during material loading into the storage bins or stockpiles.
2. Plant entryway, truck service roads, and concrete batching areas shall be graveled. Watering shall be
implemented if dust problems occur.
3. Vehicle speed on haul roads and service roads shall be restricted to 35 miles per hour. Speed limit signs
shall be posted.
77713313/001
Page 6 of 7
JAN -3e-2009 14:22 From:AIR POLLUTION SSP To:19708245166 Daae:d'tml
Colorado Department of Public Health and Environment
Air Pollution Control Division
Northwest Ready Mix Portable Operations, Inc.
Permit No.: 08P01188
INITIAL APPROVAL
GENERAL TERMS AND CONDITIONS: (IMPORTANT! READ ITEMS §.,6,7 AND 8)
1, This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and
Is conditioned upon conduct of the activity, ar construction, installation and operation of the source. in accordance
with this Information and with representations made by the applicant or applicant's agents. R is valid only for the
equipment and operations or activity specifically identified on the permit.
d in this
ave been
2. Unless determined by they APCD to bestated e necessary te o assure coneral andmpliance with the provis c conditions lonseof Section 25-7-1114 5(7)(0),
C.R.S,
3 Each and every condition of this permit Is a material part hereof and is not severable. Any challenge to or appeal
of, a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall
be deemed denied ab inftio. This permit may be revoked at any time prior to final approval by the Air Pollution
Control Division (APCD) on grounds set forth In the Colorado Air Quality Control Act and regulations of the Air
Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the
Division denies a permit, conditions imposed upon a permit are contested by the applicant, or the Division revokes
a permit, the applicant or owner or operator of a source may request a hearing before the AQCC For review of the
Division's action.
4, This permit and any required attachments must be retained and made available for Inspection upon request at the
location set forth herein. With respect to a portable source that is moved to a new location, a copy of the
Relocation Notice (required by law to be submitted to the APCD whenever a portable source is relocated) should
be attached to this permit. The permit may be reissued to a new owner by the APCD as provided in AQCC
Regulation No. 3, Part 8, Section II.B. upon a request for transfer of ownership and the submittal of a revised
APEN and the required fee.
5. Issuance (initial approval) of an emission permit does not provide "final" authority for this activity or operation of
this source. Final approval of the permit must be secured from the APCD in writing in accordance with the
provisions o125 -7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part 8, Section 111.0. Final approval cannot
be granted until the operation or activity commences and has been verified by the APCD as conforming in all
respects with the conditions of the permit. If the APCD so determines, it will provide written documentation of such
final approval, which does constitute "final" authority to operate. Compliance with the permit conditions must
be demonstrated within 180 days after commencement of operation.
6. THIS PERMIT AUTOMATICALLY EXPIRES IF you (1) do not commence construction or operation within 18
months after either the date of issuance of this permit ar the date on which such construction or activity was
scheduled to commence as set forth in the permit, whichever is later: (2) discontinue construction for a period of
18 months or more; or (3) do riot complete construction within a reasonable time of the estimated completion date.
Extensions of the expiration date may be granted by the APCD upon a showing of good cause by the pem111lee
prior to the expiration dale.
7. YOU MUST notify the APCD at least thirty days (fifteen days for portable sources) prior to commencement
of the permitted operation or activity. Failure to do so is a violation of Section 25-7-114.5(12)(a), C.R.S. and
AQCC Regulation No. 3, Part 8, Section 111.0.1„ and can result in the revocation of the permit, You must
demonstrate compliance with the pemilt conditions within 180 days after commencement of operation as stated In
condition 6.
8. Section 26-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN)
must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be
discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon
notification, annual fee billing will terminate.
9. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and control Act
or the regulations of the AQCC may result In administrative, civil or criminal enforcement actions under
Sections 25-7-115 (enforcement), -121 (injunctions), .122 (civil penalties), -122.1 (criminal penalties), C.R.S.
777133131001
Page 7 of 7
SPILL PREVENTION, CONTROL, AND
COUNTERMEASURES PLAN
For
EPA Regulated Facilities
Located At:
Jackrabbit Compressor Station
N1/2 SW Sec 33, T5S, R96W
Owner
Enterprise Product Operating, LLC
c/o Environmental Department
P.O. Box 4324
Houston, Texas 77210
February 2009
Copy #
Spill Prevention, Control, and Countermeasure Plan Forward
TABLE OF CONTENTS
Paae
Table of Contents
Regulatory Cross -Reference iv
Section 1 — Plan Introduction
1.1 Plan Overview 1-1
1.2 Plan Availability 1-1
1.3 Deviations to the SPCC Rule 1-1
1.4 Plan Review and Update Process 1-2
1.5 Spill Reporting to Regional Administrator 1-3
Section 2 — Plan Administration
2.1 Plan Distribution List 2-1
2.2 Log of Plan Review and Amendments 2-2
2.3 Management Approval and Designated Persons 2-3
2.4 Professional Engineer Certification 2-4
2.5 Substantial Harm Certification 2-5
Section 3 — General Facility Information
3.1 Facility and Owner/Operator Information 3-1
3.2 Contact List and Phone Numbers 3-1
3.4 Facility Description and Activities 3-1
3.5 Facility Diagram 3-1
Section 4 — Discharge Prevention — General Requirements
4.1 Potential Discharge Sources, Volumes, and Flow Direction 4-1
4.2 Containment and Diversionary Structures 4-1
4.3 Secondary Containment Impracticability 4-1
4.4 Inspections, Tests, and Records 4-1
4.5 Personnel Training and Spill Prevention Briefings 4-2
4.6 Facility Security 4-3
4.7 Tank Truck and Tank Car Loading Racks 4-3
4.8 Brittle Fracture Evaluation 4-3
4.9 Conformance with Other State and Local Regulations 4-3
Section 5 — Discharge Prevention — Specific Onshore Facility Requirements
5.1 Facility Drainage 5-1
5.1.1 Facility Diked Drainage 5-1
5.1.2 Facility Undiked Drainage 5-1
5.1.3 Effluent Treatment Systems 5-1
5.2 Bulk Storage Containers 5-1
5.2.1 Bulk Storage Container Construction 5-1
5.2.2 Bulk Storage Container Secondary Containment 5-2
5.2.3 Completely or Partially Buried Metallic Oil Storage Containers 5-2
5.2.4 Mobile or Portable Oil Storage Containers 5-3
5.2.5 Bulk Storage Container Inspection and Testing Procedures 5-3
Jackrabbit Compressor Station ii Date: February 2009
SpiII Prevention, Control, and Countermeasure Plan Forward
TABLE OF CONTENTS (Cont'd)
Page
5.3 Transfer Operations, Pumping, and In -Plant Processes 5-4
5.3.1 Buried Piping 5-4
5.3.2 Out -of -Service Piping 5-4
5.3.3 Aboveground Valves and Piping 5-4
5.3.4 Vehicle Warnings 5-5
Section 6 — Discharge Response
6.1 Discharge Notification 6-1
6.2 Response/Countermeasures 6-1
6.3 Cleanup Capabilities 6-2
6.4 Waste Disposal 6-2
APPENDICES
A. Notification A-1
B. Facility Container, Secondary Containment, and Spill Data B-1
C. Facility Location and Diagram C-1
D. Facility Inspection and Integrity Testing Program D-1
E. Sample Logs and Forms E-1
F. Oil Spill Contingency Plan F-1
G. Plan Implementation Measures Not Yet Fully Operational G-1
Jackrabbit Compressor Station iii Date: February 2009
Spill Prevention, Control, and Countermeasure Plan
Forward
REGULATORY CROSS-REFERENCE
Citation
Description
Section
§112.3
Requirement to Prepare and Implement a SPCC Plan
See below
§112.3
Owner/operator must prepare SPCC plan
All
§112.3(d)(1)
Professional Engineer Certification
2.3
§112.3(e)
Maintain complete copy of plan
1.2, 2.1
§112.4
Amendment of SPCC Plan by Regional Administrator
See below
§112,4(a)
Report to EPA after specific discharges
1.5, App A
§112,4(c)
Send above report to appropriate state agencies
1.5, App A
§112.5
Amendment of SPCC by Owners I Operators
See below
§112.5(a)
Amendment of SPCC plan by owner or operator
1.4, 2.2
§112.5(b)
Management of Five Year Review
1.4, 2.2
§112.5(c)
PE certification of amendments
1.4,2.2
§112.7
General Requirements for SPCC Plans
See below
§112.7
Management approval of plan
2.3
§112,7
Cross reference table if plan does not follow sequence of regulations
As provided
§112,7
Facilities not yet fully operational
2.5
§112,7(a)(1)
Discussion of conformance with the requirements of SPCC
All
§112.7(a)(2)
Explanation of any deviations
1.3, throughout
§112,7(a)(3)
Physical layout of the facility including facility diagram
3.3, 3.4, App C
§112.7(a)(3)0)
Type of oil in each container and its storage capacity
App B
§112.7(a)(3)(ii)
Discharge prevention measures including procedures for routine handling of
products
4.0
§112.7(a)(3)(iii)
Discharge or drainage controls such as secondary containment around containers
and other structures, equipment and procedures for control of a discharge
4.2
§112.7(a)(3)(iv)
Countermeasures for discharge discovery, response and cleanup
6.2, 6.3
§112.7(a)(3)(v)
Methods of disposal of recovered materials
6.4
§112.7(a)(3)(vi)
Contact list and phone numbers
3.2, App A
§112,7(a)(4)
Procedures for reporting a discharge, unless FRP has been submitted
6.1, App A
§112,7(b)
Discharge predication / Fault analysis
4.1, App B
§112.7(o)
Appropriate containment or diversion
4.2, App B
§112.7(d)
Deviations due to impracticability
4.3
§112.7(e)
Inspections, tests, and records
4.4
§112.7(f)
Employee training and discharge prevention procedures
4.5
§112.7(f)(1)
Oil -handling personnel training
4.5
§112,7(f)(2)
Accountable person for discharge prevention
2.2
§112,7(f)(3)
Discharge prevention briefings
4.5
§112.7(g)
Security (excluding oil production facilities)
4.6
§112.7(q)(1)
Fencing and lock/guard gates
4.6
§112.7(g)(2)
Fail-safe valves for containers
4.6
§112.7(g)(3)
Starter control on each pump
4.6
§112.7(g)(4)
Loading/unloading connections of oil pipelines or facility piping when not in service
4.6
§112.7(g)(5)
Lighting
4.6
§112.7(h)
Tank Car and Tank Truck Loading / Unloading Rack (excludes offshore facilities)
4.7
§112.7(h)(1)
Handling discharges
4.7
§112.7(h)(2)
Preventing early vehicle departure
4.7
§112.7(h)(3)
Inspection for discharges prior to filling and departure
4.7
§112.70)
Evaluate field -construct above ground tanks upon repair, etc.
4.8
§112.7(j)
Conformance with other requirements
4.9
Jackrabbit Compressor Station
iv
Date: February 2009
Spill Prevention, Control, and Countermeasure Plan
Forward
Jackrabbit Compressor Station v Date: February 2009
REGULATORY CROSS-REFERENCE (Cont'd.)
§112.8
Requirements for onshore facilities (excluding Production facilities)
See below
§112.8(a)
General and specific requirements
4.0, 5.0
§112.8(b)
Facility drainage
5.1
§112.8(b)(1)
Restrain drainage from diked storage areas
5.1.1
§112.8(b)(2)
Manual valves in diked areas
5.1.1
§112.8(b)(3)
Facility drainage systems from undiked areas with a potential for a discharge
5.1.2
§112.8(b)(4)
If not 8(b)(3), diversion system for ditches
5.1.2
§112.8(b)(5)
If pump transfer required for drainage water treatment, provide fail-safe pumps and
at least two pumps
5.1.3
§112.8(c)
Bulk storage containers
5.2, App B
§112.8(c)(1)
Material and construction
5.2.1
§112.8(c)(2)
Secondary means of containment
5.2.2
§112.8(c)(3)
Drainage controls to storm drain or open water bodies
5.1.1
§112.8(c)(4)
Protection of completely buried metallic tanks from corrosion
5.2.3
§112.8(c)(5)
Partially buried or bunkered metallic tanks protection from corrosion
5.2.3
§112.8(c)(6)
Aboveground container testing for integrity
5.2.5, App D
§112.8(c)(7)
Monitor possible leakage from defective internal heating coils
5.2.1
§112.8(o)(8)
Container installation updates per good engineering practice (fail-safe precautions)
5.2.1
§112.8(c)(9)
Observation of effluent treatment facilities
5.1.3
§112.8(c)(10)
Correction of visible discharges
5.2.2
§112.8(c)(11)
For mobile or portable containers provide secondary containment
5.2.4
§112.8(d)
Facility transfer operations, pumping, and facility process
5.3
§112.8(d)(1)
Buried pipe corrosion protection
5.3.1
§112.8(d)(2)
Capping and marking pipe out of service
5.3.2
§112.8(d)(3)
Pipe supports
5.3.3
§112.8(d)(4)
Inspect aboveground valves, pipelines, appurtenances and buried piping
5.3.3
§112.8(d)(5)
Vehicle warnings
5.3.4
Jackrabbit Compressor Station v Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Plan Introduction
1.0 PLAN INTRODUCTION
1.1 Pian Overview 40 CFR §112.1
This Spill Prevention, Control, and Countermeasures ("SPCC") Plan is intended to
demonstrate that the Jackrabbit Compressor Station, (hereinafter referred to as the "Facility")
is in compliance with the applicable regulations found in EPA's 40 CFR §112, Oil Pollution
Prevention; specifically sections §112.1-7 of Subpart A and §112.8 of Subpart B. The SPCC
regulations apply to owners or operators of non -transportation related onshore and offshore
facilities engaged in drilling, producing, gathering, storing, processing, refining, transferring,
distributing, or consuming oil and oil products that meet each of the following criteria:
• Due to their location, could reasonably be expected to discharge oil in quantities that
may be harmful into or upon navigable waters of the United States or adjoining
shorelines and;
• Has an aggregate aboveground storage capacity greater than 1,320 gallons, excluding
containers less than 55 gallons and/or has an underground storage capacity greater
than 42,000 gallons.
This SPCC Plan covers the EPA regulated (non -transportation -related) portions of the Facility.
It may cover a single storage tank or transformer up to an entire terminal/station. This SPCC
Plan does not include information pertaining to the transportation -related portions of the
Facility except for the location of such transportation -related areas on the Facility Diagram.
Enterprise Product Operating, LLC has chosen to follow a company modified version of API's
D-16 SPCC Plan Template to comply with SPCC Plan Requirements. The API format is being
used for this template because of agency familiarity with it and accepted compliance reviews
that have been conducted on it by multiple industry experts.
1.2 Plan Availability §112.3
A copy of this SPCC Plan is maintained at the following locations and is available for on-site
review upon request of the EPA Regional Administrator (a distribution list is provided in
Section 2.1):
• Facility (if normally attended at least 4 hours per day).
• Regional or Local Field Office.
• Corporate EHS&T Office.
1.3 Deviations to the SPCC Rule §112.7(d)
The SPCC rule allows deviations from most technical elements of the rule with the exception
of any secondary containment requirements, general recordkeeping and training provisions,
and the administrative provisions of the rule (§112.1 through §112.5), provided that equivalent
environmental protection measures are provided to prevent a discharge. Any deviations to the
rule will be identified in this Plan along with reasoning for the nonconformance and a detailed
description of the alternative method and how that method will achieve equivalent
environmental protection.
Jackrabbit Compressor Station
1-1 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Plan Introduction
1.4 Plan Review and Update Process §112.5
Five Year Review
In accordance with §112.5(b), Enterprise Products Operating, LP will complete a formal review
and evaluation of this SPCC Plan at least once every five (5) years and document the review
on the Log of Plan Review and Amendments located in Section 2.2. This review will be
conducted by the Facility's Designated Person (identified in Section 2.3) with assistance from
the Field Environmental Representative ("FER"), as needed and will include review of the
following:
• Accuracy of the Plan with current operations and procedures.
• Accuracy of the Plan with current SPCC Regulations.
• Applicability of new prevention and control technology that may significantly reduce the
likelihood of a spill event from the Facility if such technology has been field -proven at
the time of review.
• Capacity and structural integrity of secondary containment systems.
• SPCC inspection documentation and records.
Facility Changes Requiring Plan Revision
Whenever there is a change in the Facility design, construction, operation or maintenance
which materially affects the Facility's potential for a discharge of oil into or upon the navigable
waters of the United States or adjoining shorelines, the SPCC Plan will be amended.
Changes that require revision to the Plan may include, but are not limited to:
• Commissioning or decommissioning of containers.
• Replacement, reconstruction, or movement of containers.
• Reconstruction, replacement, or installation of piping systems.
• Construction or demolition that might alter secondary or tertiary containment structures
and/or drainage systems.
• Revision of standard operating or maintenance procedures at the Facility.
The Facility's Designated Person is responsible for notifying the FER of such changes to the
facility. Revisions and amendments to the Plan will be performed by the Corporate Houston
Office. The Plan shall be amended within six (6) months and fully implemented as soon as
possible but no later than six (6) months after the preparation of the amendments. Any
amendments to the Plan shall be documented on the Log of Plan Review and Amendments
located in Section 2.2.
Certification of Revisions
All amendments which could materially affect the Facility's potential for a discharge into
navigable waters of the United States or adjoining shores (technical amendments) must be
certified by a Registered Professional Engineer ("PE"). Non-technical amendments such as
changes to personnel, telephone references, and other non-technical text changes do not
require recertification by a PE.
Jackrabbit Compressor Station
1-2 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Plan Introduction
1.5 Spill Reporting to Regional Administrator 9112.7(a)(4)
The information found in Appendix A, "Submittal of Information to Regional Administrator for
Qualified Discharge(s)" must be submitted to the EPA Regional Administrator within sixty (60)
days of a discharge event(s) which meets one of the following conditions:
• The Facility has a single discharge event greater than 1,000 gallons of oil or oil
products into or upon navigable waters of the United States or adjoining shorelines or:
• The Facility has two (2) discharge events greater than 42 gallons of oil or oil products
into or upon navigable waters of the United States or adjoining shorelines in a 12 -
month period.
The FER will submit such reports to the EPA. A copy of this report will also be sent to the
appropriate state agency(ies) in charge of oil pollution control activities and the Corporate
EHS&T office. All spill events greater than 1 gallon must be internally reported using the
ecerts program.
Jackrabbit Compressor Station
1-3 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan
2.0 PLAN ADMINISTRATION
2.1 Plan Distribution List §112.2(e)
Plan Administration
Jackrabbit Compressor Station
2-1 Date: February 2009
PLAN DISTRIBUTION LIST
COPY
NUMBER
PLAN HOLDER (Hard Copies)
1
Corporate EHS&T Department
Attn: Environmental Plans
2727 North Loop West
Houston, TX 77008
2
Jackrabbit Compressor Station
3
4
5
6
Jackrabbit Compressor Station
2-1 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan
Plan Administration
2.2 Log of Pian Review and Amendments §112.5
LOG OF PLAN REVIEW AND AMENDMENTS
NON-TECHNICAL AMENDMENTS
• Non-technical amendments do not require recertification by a Professional Engineer.
■ Examples of changes include, but are not limited to, phone numbers, name changes, or any non-
technical text change(s).
TECHNICAL AMENDMENTS
• Technical amendments require recertification by a Professional Engineer.
• Examples of changes include, but are not limited to, commissioning or decommissioning containers;
replacement, reconstruction, or movement of containers; reconstruction, replacements, or installation
of piping systems; construction or demolition that might alter secondary containment structures;
changes of product or service; or revision of standard operation or maintenance procedures at a
facility.
■ An amendment made under this section will be prepared within six (6) months of the change and
implemented as soon as possible but not later than six (6) months following preparation of the
amendment.
MANAGEMENT REVIEW
• Management will review this SPCC Plan at least each five (5) years and document the review on the
form below.
Review/
Amend
Date
By Whom
Activity
P'E'
Certification
Required?
(Yes/No)
Comments/
Affected Section(s)
2/12/2009
Chris Gauthier
Prepare Plan
Yes
Initial Plan. Next Review— 2/12/2014
Jackrabbit Compressor Station
2-2 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan
Plan Administration
2.3 Management Approval and Designated Persons §112.7, §112.7(f)(2)
MANAGEMENT APPROVAL AND DESIGNATED PERSONS
Facility Name: Jackrabbit Compressor Station
Owner/Operator Responsible for Facility: Enterprise Products Operating, LP
Enterprise Products Operating, LP is committed to preventing discharges of oil to navigable
waters of the United States or adjoining shorelines. By signature below, I approve this Plan and
acknowledge that the elements identified in the Plan have been implemented. The Designated
Person Accountable for Oil Spill Prevention at the Facility, as identified below, has been giving
the authority to commit the necessary resources to implement this Plan. This SPCC Plan will be
implemented as herein described. Details to any impracticability are discussed in Section 4.3 of
this SPCC Plan.
Signature: Date:
Name: Rick Fullmer
Title: Regional Manager
Designated Person Accountable for Oil Spill Prevention at the Facility:
Name: Stephen Cochran
Title: Plant Supervisor
Additional Person Accountable for Oil Spill Prevention at the Facility:
Name: TBD
Title:
Additional Person Accountable for Oil Spill Prevention at the Facility:
Name: Chris Gauthier
Title: Field Environmental Representative
Jackrabbit Compressor Station
2-3 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan
Plan Administration
2.4 Professional Engineer Certification §112.5(c)
PROFESSIONAL ENGINEER CERTIFICATION
By means of this Professional Engineer Certification, I hereby attest to the following:
• I am familiar with the requirements of 40 CFR §112 and have verified that this Plan has
been prepared in accordance with the requirements of this Part.
• I or my agent have visited and examined the Facility(ies).
• I have verified that this Plan has been prepared in accordance with good engineering
practice, including consideration of applicable industry standards.
• I have verified that the required inspection and testing procedures have been
established as described in this Plan.
• I have verified that the Plan is adequate for the Jackrabbit Compressor Station.
• This certification in no way relieves the owner or operator of the Facility of his/her duty
to prepare and fully implement this SPCC Plan in accordance with the requirements of
40 CFR §112.
■ This Plan is valid only to the extent that the Facility owner or operator maintains, tests,
and inspects equipment, containment, and other devices as prescribed in the Plan.
■ This certification is contingent upon the successful completion of all implementation
measures identified in the Section 2.5: Plan Implementation Measures Not Yet Fully
Operational.
Date
Paul V. Henehan
Name of Registered Professional Engineer
Signature of Registered Professional Engineer
Registration No. 6123 State WY
Jackrabbit Compressor Station
2-4 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan
Plan Administration
2.5 Substantial Harm Certification §112— Appendix CII
CERTIFICATION OF THE APPLICABILITY OF THE SUBSTANTIAL HARM CRITERIA
Facility Name : Jackrabbit Compressor Station
Facility Address: N1/2 SW Sec.33, T5S, R96W
1. Does the facility transfer oil over water to or from vessels and does the facility have a total oil storage
capacity greater than or equal to 42,000 gallons?
YES ❑ NO
2. Does the facility have a total oil storage capacity greater than or equal to 1 million gallons and does the
facility lack secondary containment that is sufficiently large to contain the capacity of the largest
aboveground oil storage tank plus sufficient freeboard to allow for precipitation within any aboveground
oil storage tank area?
YES ❑ NO
3. Does the facility have a total oil storage capacity greater than or equal to 1 million gallons and is the
facility located at a distance (as calculated using the appropriate formula in Attachment C -III to this
appendix or a comparable formula') such that a discharge from the facility could cause injury to fish
and wildlife and sensitive environments? For further description of fish and wildlife and sensitive
environments, see Appendices I, II, and III to DOC/NOAA's "Guidance for Facility and Vessel
Response Plans: Fish and Wildlife and Sensitive Environments" (59 FR 14713, March 29, 1994) and
the applicable Area Contingency Plan.
YES NO®
4. Does the facility have a total oil storage capacity greater than or equal to 1 million gallons and is the
facility located at a distance (as calculated using the appropriate formula in Attachment C -III to this
appendix or a comparable formula 1) such that a discharge from the facility would shut down a public
drinking water intake2?
YES ❑ NO
5. Does the facility have a total oil storage capacity greater than or equal to 1 million gallons and has the
facility experienced a reportable oil spill in an amount greater than or equal to 10,000 gallons within the
last 5 years?
YES ❑ NO El
CERTIFICATION
I certify under penalty of law that 1 have personally examined and am familiar with the information submitted
in this document, and that based on my inquiry of those individuals responsible for obtaining this
information, I believe that the submitted information is true, accurate, and complete.
Engineer
Signature Title
Paul V. Henehan
Name (please type or print) Date
t
If a comparable formula is used, documentation of the reliability and analytical soundness of the comparable formula must be attached to this form.
2
For the purposes of 40 CFR part 112, public drinking water intakes are analogous to public water systems as described at 40 CFR 143.2(c).
Jackrabbit Compressor Station 2-5
Date: February 2009
Spill Prevention, Control, and Countermeasure Plan
Discharge Prevention — General
3.0 GENERAL FACILITY INFORMATION
3.1 Facility and Owner/Operator Information §112.7(a)(3)
Facility Name:
Street Address:
Mailing Address:
County:
Facility Phone:
Latitude:
Longitude:
Nearest Receiving Water:
Landside Directions:
Owner:
Mailing Address:
Street Address:
Telephone:
Jackrabbit Compressor Station
Meeker, CO
Garfield
TBD Control Room
39.5498N
-108.118W
House Log Gulch (tributary of Parahute Creek)
Enterprise Products Operation, LLC
c/o Environmental Department, P.O. Box 4324
Houston, TX 77210
713-803-8358
3.2 Contact List and Phone Numbers §112.7(a)(3)(vi)
• The contact list and phone numbers for the Facility is provided in Appendix A.
3.3 Facility Description §112.7(a)(3)
• The Jackrabbit Compressor Station is a natural gas compressor station situated on 17.5
acres of land in Garfield County, Colorado.
• The primary role of the facility is to compress the natural gas flow stream for further
transport via pipeline to downstream markets. During the compression process, liquid
condensate will condense from the flow stream. This condensate is stored in bulk storage
containers on site. It is then transported via tanker to offsite markets.
• The facility is located at an approximate elevation of 8,000 feet and is leased from Berry
Petroleum Company. The limited precipitation in this area supports sparse vegetation
characterized mainly by sage brush. The facility drainage pattern is presented on the plot
plan in Appendix B. A topographic map indicates that the local drainage is to the south
then east.
• The nearest water body is House Log Gulch (a tributary of Parachute Creek) which is
located immediately adjacent to the facility. Ephermeral drainages provide a pathway from
the facility to this water body.
3.4 Facility Diagram §112.7(a)(3)
• A Facility diagram is provided in Appendix C which includes, at a minimum, the following
details and location information (as applicable):
• Containers and their contents.
• Transfer stations and connecting lines.
• Completely buried and bunkered tanks (including USTs covered under 40 CFR Part
280 or 281).
• Drum and portable container storage areas.
Jackrabbit Compressor Station
4-1 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Discharge Prevention - General
4.0 DISCHARGE PREVENTION - GENERAL REQUIREMENTS §112.7
4.1 Potential Discharge Sources, Volumes, and Flow Direction §112.7(b)
• Potential discharge sources, volumes, and flow directions at the Facility that are regulated
under this Plan are identified in the Container and Potential Spills Table in Appendix B.
4.2 Containment and Diversionary Structures §112.7(c), §112.7(h)(1), §112.8(c)(2) & (11)
• The purpose of the SPCC rule and goal of the Facility is to prevent discharges of oil to
navigable waters of the United States and adjoining shorelines. One of the primary ways
by which this is achieved is through the use of secondary containment systems.
• Secondary containment requirements are divided into two (2) categories:
• General Secondary Containment Requirements — §112.7(c)
✓ Addresses the potential for oil discharges from all regulated parts of the Facility.
✓ Containment method, design, and capacity are determined by good engineering
practice to contain the most likely oil discharge until cleanup occurs.
• Specific Secondary Containment Requirements — §112.7(h)(1), §112.8(c)(2) & (11)
✓ Addresses the potential of oil discharges from specific parts of the Facility
including loading/unloading racks and bulk storage containers.
✓ Containment design, sizing, and freeboard requirements are specified by the
SPCC rule to address major container failures.
• Methods of secondary containment utilized at the Facility include a combination of
containment structures, drainage systems, and land-based spill response to prevent oil
from reaching navigable waters or adjoining shorelines.
■ Secondary containment measures for each regulated spill source at the Facility are
identified in Appendix B in the Container and Potential Spills Table and further described in
Appendix B in the Secondary Containment Systems Table.
• Specific secondary containment requirements for loading/unloading racks, if applicable,
are discussed in Section 4.7.
• Specific secondary containment requirements for bulk storage containers, if applicable, are
discussed in Section 5.2.2.
■ Secondary containment impracticabilities, if applicable, are discussed in Section 4.3.
4.3 Secondary Containment Impracticability §112.7(d)
• It has been determined that secondary containment is practicable at the Facility.
4.4 Inspection, Tests, and Records §112.7(e)
Inspection and Integrity Testing
• A summary of the inspection and integrity testing requirements applicable to the Facility
is provided in Appendix D. Details are provided in applicable sections of the Plan.
Records
Jackrabbit Compressor Station
4-2 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Discharge Prevention — General
• Recordkeeping logs and forms are signed by the appropriate supervisor or inspector and
maintained at the Facility or the Region or Local Field Office for a minimum period of
three (3) years.
• The Facility may utilize recordkeeping logs and forms that are kept under usual and
customary business practices for meeting the requirements for SPCC.
• Optional sample logs and forms are provided in Appendix E. If these forms are opted not
to be used, other forms providing the same information will be required.
4.5 Personnel Training and Spill Prevention Briefings §112.7(f)
Training
• The Facility's training objective is to provide a continuous program that teaches
employees and drivers the proper procedures and practices related to their particular job
assignments to ensure the safe and effective operation of the Facility.
• The Facility provides the following minimum training to oil -handling personnel:
✓ Operation and maintenance of equipment to prevent oil discharges;
✓ Oil discharge procedure protocols;
✓ Overview of applicable pollution control laws, rules, and regulations;
✓ General facility operations; and
✓ The Facility SPCC Plan.
• The training program may be conducted through classroom instructions, video/computer
based modules, on-the-job training, and safety meetings.
• All truck drivers that perform loading and/or unloading activities at the Facility are
appropriately trained to carry out their activities in a safe manner. New drivers receive
safety orientation prior to being approved to transfer products at the Facility.
• Training records are maintained at the Corporate EHS&T Office for a minimum period of
three (3) years and are available electronically.
Spill Prevention Briefings
• The Facility conducts spill prevention briefings for oil -handling personnel at least once a
year to assure adequate understanding of the SPCC Plan for the Facility.
• These briefings will include discussion of potential discharges or component failures and
recently developed precautionary measures.
• These briefings will also include refresher training, as deemed necessary, on the
minimum training standards described in the above subsection.
• The briefing program is conducted through classroom instructions, video/computer based
modules, on-the-job training, safety meetings or actual spill events.
• Spill prevention briefing records are maintained at the Facility or the Region or Local
Field Office for a minimum period of three (3) years and at the Corporate EHS&T office.
• A sample Spill Prevention Briefing Log is provided in Appendix E.
Jackrabbit Compressor Station
4-3 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Discharge Prevention - General
4.6 Facility Security §112.7(g)
Fencing
• The Facility is surrounded by 6 -ft tall chain link security fencing which encircles the
entire footprint of the Facility.
• All entrance gates are locked when the Facility is unattended.
Lighting
• Facility lighting is commensurate with the operations and the type and location of the
Facility to assist in the discovery of discharges and to prevent discharges occurring
through acts of vandalism.
• Area lights illuminate the oil storage and transfer areas.
Valves
• Drain valves are not utilized in the oil storage secondary containment areas
Starter Controls
• Starter controls on all oil pumps in non-operating or standby status are locked in the off
position and located at a site accessible only to authorized personnel.
Out -of -Service Piping
• The Facility securely caps or blank flanges the loading/unloading connections of facility
piping when not in service or when in standby service for an extended period of time
(i.e. greater than 6 months), or when piping is emptied of liquid content either by
draining or by inert gas pressure.
4.7 Tank Truck and Tank Car Loading Racks §112.7(h)
• A tank truck loading rack is present at the Facility.
• Loading/unloading areas, not defined as a loading/unloading rack, are required to meet the
general secondary containment requirements of §112.7(c) discussed in Section 4.2. Such
loading/unloading areas are identified in Appendix B, if applicable.
4.8 Brittle Fracture Evaluation §112.7(i)
• No field -constructed aboveground oil storage containers are present at the facility.
4.9 Conformance with Other State and Local Regulations §112.7(j)
• The facility comples with all State and Local discharge prevention requirements.
Jackrabbit Compressor Station 4-4 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Discharge Prevention — Specific
5.0 DISCHARGE PREVENTION — SPECIFIC ONSHORE FACILITY REQUIREMENTS
5.1 Facility Drainage §112.8(b)
5.1.1 Facility Diked Drainage §112.8(b)(1)&(2)
• Typically, drainage of stormwater from the Facility's diked storage areas is not intended
to occur. It is anticipated that precipitation will be removed via evaporation only.
However, drain valves are provided on the oil containment structures.
• The contents of the diked storage area are inspected by Facility personnel prior to
each draining event to ensure that only oil -free water (no product sheen) is discharged.
• If oil or oil sheen is observed in the diked storage area, vacuum trucks or other
appropriate means will be used to remove any and all oil before drainage.
• Each drainage event and associated inspection is recorded on the Secondary
Containment Drainage Event Log found in Appendix E. The Facility may use Togs or
forms that are kept under usual and customary business practices in lieu of the above
reference log.
5.1.2 Facility Undiked Area Drainage §112.8(b)(3)&(4)
• The Facility does not have the potential to discharge oil into undiked areas.
5.1.3 Effluent Treatment Facilities §112.8(b)(5) and §112.8(c)(9)
• The Facility does not treat drainage water prior to discharge.
5.2 Bulk Storage Containers §112.8(c)
• Bulk storage containers covered by this Plan are identified in the Container and Potential
Spills Table located in Appendix B and the Facility Diagram in Appendix C.
• Bulk storage containers covered under the SPCC rule includes the following:
• Field -erected aboveground storage containers.
• Shop -built storage containers.
• Mobile or portable storage containers (drums, totes, etc).
• Completely or partially buried storage containers.
• Underground storage containers not covered under the technical requirements of
40 CFR Part 280 or a state approved Underground Storage Tank program.
• Only bulk storage containers greater than 55 -gallons are subject to the SPCC rule.
• Oil -filled electrical, operating, or manufacturing equipment are not bulk storage containers
and thus are not subject to bulk storage container requirements identified in this section.
5.2.1 Bulk Storage Container Construction §112.8(c)(1),(7),&(8)
• Bulk storage containers are constructed in accordance with industry standards.
• The material and construction of the bulk storage containers are compatible with the
material stored and conditions of storage such as pressure and temperature.
Jackrabbit Compressor Station
5-1 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Discharge Prevention—Specific
• High liquid level alarms at pre-programmed tank content levels are utilized to prevent
overfill.
• Containers not equipped with level alarms are equipped with manual sight gauges
and/or hand gauged for inventory control prior to filling.
■ Containers are operated within "Safe Fill" levels positioned below the operating limits of
the bulk storage container.
• Visible discharges, which result in a loss of product from containers, are promptly
corrected.
• The Facility's bulk storage container inspection and integrity testing program is
discussed in Section 5.2.5.
• The Facility's bulk storage containers do not utilize internal heating coils.
5.2.2 Bulk Storage Container Secondary Containment §112.8(c)(2),(3),&(10)
• Secondary containment structures for bulk storage containers are identified in the
Container and Potential Spills Table and the Secondary Containment Systems Table
found in Appendix B.
• All bulk storage container installations are constructed so that a means of secondary
containment is provided for the entire capacity of the largest single container plus
sufficient freeboard to contain precipitation.
• The Facility utilizes the industry standard API -12R1 for additional freeboard capacity
which recommends containment equal to at least 110% of the largest single container.
• Where bulk containers are manifolded together such that the loss of one results in the
loss of all, the combined storage capacity of the manifolded containers will be used to
determine secondary containment and freeboard capacity.
• Secondary containment diked areas are sufficiently impervious to contain discharged
oil from reaching navigable waters or adjoining shorelines before cleanup begins.
• Unless otherwise noted in Appendix 8, Secondary Containment Systems Table, dike
floors and walls are constructed of compacted native earthen material.
• Spills that may occur inside the diked areas will generally be contained within the
containment walls and/or absorbed in the underlying soils before reaching navigable
waters or adjoining shorelines.
• Details concerning the construction of fixed secondary containment systems are
provided in the Secondary Containment Systems Table in Appendix B.
• Visible discharges, which result in any accumulations of oil in the diked area(s), are
promptly removed and disposed of according to the applicable regulation and company
procedures.
■ Secondary containment volume calculations are provided in Appendix B.
• Drainage from secondary containment areas is discussed in Section 5.1.1.
5.2.3 Completely or Partially Buried Metallic Oil Storage Containers §112.8(c)(4)&(5)
■ The Facility does not have completely buried metallic storage containers that were
installed on or after January 10, 1974.
• The Facility does not have partially buried or bunkered metallic storage containers.
Jackrabbit Compressor Station
5-2 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Discharge Prevention — Specific
5.2.4 Mobile or Portable Oil Storage Containers §112.8(c)(11)
• Mobile or portable oil storage containers are identified, if applicable, on the Container
and Potential Spills Table in Appendix B.
• A secondary means of containment is provided for the largest single compartment or
container plus sufficient freeboard to contain precipitation.
• The Facility utilizes the industry standard API -12R1 for additional freeboard capacity
which recommends containment equal to at least 110% of the largest single container.
• These containers are generally located in dedicated storage areas which are
positioned or located so as to prevent a spill from reaching navigable waters or
adjoining shorelines.
• These containers are located where they will not be subject to periodic flooding or
washout.
• Dedicated mobile or portable storage container areas are identified on the Facility
Diagram in Appendix C.
• Containers that may be temporary located outside the dedicated storage area are
positioned or located so as to prevent a spill from reaching navigable waters or
adjoining shorelines until they can be returned to the dedicated storage area.
5.2.5 Bulk Storage Container Inspection and Testing Procedures §112.8(c)(6)
Bulk Storage Container Inspection
• The outside of all bulk storage containers and their associated supports and
foundations are frequently inspected during normal Facility walk-throughs for signs of
deterioration, discharges, or accumulation of oil inside secondary containment areas.
• These frequent Facility walk-through inspections are not documented unless a
corrective action must be taken.
• Documented visual external inspections for all bulk storage containers and their
associated supports and foundations are conducted annually and noted on the Tank,
Piping, and Containment Inspection Form. The Facility may use logs or forms that
are kept under usual and customary business practices, including any DOT forms
required under O&M Manual procedures, in lieu of the above reference form.
• Liquid level sensing devices (overfill prevention) are tested annually to ensure proper
operation.
• In the event that a field -constructed aboveground container undergoes a repair,
alteration, reconstruction, or a change in service, the container will be evaluated for
the risk of discharge or failure due to brittle fracture or other catastrophe.
• Inspection forms are maintained at the Facility or the Region or Local Field Office.
• A summary of the inspection requirements applicable to the Facility is provided in
Appendix D, Facility SPCC Inspection Program.
Bulk Storage Container Integrity Testing
• The integrity testing program includes a combination of visual inspections and at
least one of the following alternate testing techniques: hydrostatic, radiographic,
ultrasonic, and/or acoustic emissions.
Jackrabbit Compressor Station
5-3 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Discharge Prevention - Specific
• Field -erected aboveground bulk containers are integrity tested on a regular schedule
and when material repairs are made using API Standard 653.
• Small shop -built containers will follow testing standards set forth in STI-SP001.
• The Facility chooses to deviate from the integrity testing requirements of elevated
shop -built containers up to 30,000 gallons and single -use containers such as drums,
totes, and other small portable containers. These containers are elevated such that
all sides of the container are visible during inspections and any problems that may
occur will be quickly identified. These frequent inspections, as further described in
the subsection above, provide equivalent environmental protection for integrity
testing of such containers.
• A summary of the integrity testing requirements applicable to the Facility is provided
in Appendix D, Facility SPCC Integrity Testing Program.
5.3 Transfer Operations, Pumping, and In -Plant Processes §112.8(d)
5.3.1 Buried Piping §112.8(d)(1)
• New or replaced buried piping will be cathodically protected against corrosion and
provided with protected wrapping and coating.
• If a section of buried line is exposed, it will be inspected for signs of deterioration and
corrective actions will be taken as indicated by the magnitude of the damage.
• Integrity and leak testing of buried piping is performed at the time of installation,
modification, construction, relocation, and/or replacement.
• Note: Aboveground piping that passes through dikes and roadways are not considered
to be buried piping.
5.3.2 Out -of -Service Piping §112.8(d)(2)
• Facility connections are capped or blank -flanged at the transfer point and marked as to
origin when the piping is not in service or in standby service for extended periods (i.e.
greater than 6 months).
5.3.3 Aboveground Valves and Piping §112.8(d)(3)&(4)
• All pipe supports are designed to minimize abrasion and corrosion and allow for
expansion and contraction.
• Aboveground valves and piping and appurtenances are regularly examined during
normal Facility walk-throughs for general condition and necessity for corrective action.
• The following items are included in the examination:
Flange joints,
Expansion joints,
Valve glands and bodies,
Piping supports,
Metal surfaces,
Catch pans, and
Valve locks and/or seals.
«\««
Jackrabbit Compressor Station
5-4 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Discharge Prevention — Specific
• These frequent Facility walk-through inspections are not documented unless a
corrective action must be taken.
• Documented visual inspections of all regulated aboveground valves and piping and
appurtenances are conducted annually and noted on the Facility Aboveground Piping
Inspection Form. The Facility may use logs or forms that are kept under usual and
customary business practices, including any DOT forms required under O&M Manual
procedures, in lieu of the above reference form.
5.3.4 Vehicle Warnings §112.8(d)(5)
• Warning signs are posted at appropriate locations throughout the Facility to prevent
vehicles from damaging aboveground piping and appurtenances.
• Bumper guards may be provided in critical vehicular access areas to protect
aboveground piping and/or other oil transfer operations.
Jackrabbit Compressor Station
5-5 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Discharge Response
6.0 DISCHARGE RESPONSE
6.1 Discharge Notification §112.7(a)(4)
• Any discharge that may occur at the Facility shall be reported to the immediate supervisor.
• The Designated Person must be notified.
• A discharge of any volume that affects or threatens to affect navigable waters of the United
States or adjoining shorelines must be reported immediately to the following:
✓ National Response Center (NRC)
✓ Local Fire Department (911)
✓ State Emergency Response Commission (SERC)
✓ Local Emergency Planning Committee (LEPC)
✓ Emergency contact numbers including those agencies identified above are
provided in Appendix A: Contact List and Phone Numbers.
• A Notification Data Sheet is provided in Appendix A to assist in reporting a discharge.
• Written reports to the EPA Regional Administrator as required by §112.4 is discussed in
Section 1.5.
• Additional discharge notification procedures including internal and external notifications are
provided in the following:
• Ecerts notification
• Spill and Release Reporting for Colorado
6.2 Response/Countermeasures §112.7(a)(3)(iv)
• Facility personnel are trained to ensure an adequate understanding of the emergency
response procedures.
• General response actions are as follows:
GENERAL RESPONSE ACTIONS
PERSONNEL AND PUBLIC SAFETY IS FIRST PRIORITY
CONTROL
• Eliminate sources of ignition
• Isolate the source of the discharge, minimize further flow
• Keep unnecessary persons and traffic out of the area
NOTIFY
• Make internal and external notifications
• Activate response contractors and other external resources as necessary
CONTAIN
• Begin spill mitigation and response activities
• Monitor and control the containment and clean-up effort
• Protect the public and environmental sensitive areas
Jackrabbit Compressor Station
6-1
Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Discharge Response
6.3 Cleanup Capabilities §112.7(a)(3)(iv)
• Generally, cleanup operations will be performed by an approved contractor which has
been predetermined to have capabilities necessary for spills that may occur at the Facility.
• The contract resources available to the Facility for discharge cleanup are provided in
Appendix A: Contact List and Phone Numbers.
6.4 Waste Disposal §112.7(a)(3)(v)
■ Generally, field environmental personnel will coordinate the proper disposal of any waste
material resulting from a spill at the Facility.
■ Management and disposal of such materials will be conducted in accordance with
applicable federal, state, and local regulations.
Jackrabbit Compressor Station
6-2 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Appendix A
APPENDIX A
NOTIFICATION
• Contact List and Phone Numbers
• Notification Data Sheet
• Submittal of Information to Regional Administrator for Qualified Discharge(s)
Jackrabbit Compressor Station
A-1 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan
Appendix A
Contact List and Phone Numbers
Contact
Primary
Facility Response
Alternate
Designated Persons Accountable For OH Spill Prevention and/or
Coordinator
Mr. Chris Gauthier
303/330-7952
Mr. Rick Fullmer
970-309-8441
970/309-8441
Facility Office
Federal, State and Local Agencies (as necessary):
National Response Center
800/424-8802
202/267-2675
U.S. EPA Region VIII
303/293-1788
State Emergency Response Commission (SERC)
307/777-4900
Local Emergency Planning Committee (LEPC)
307/877-9835
Colorado Department of Public Health and Environment
877/518-5608
Colorado Oil and Gas Conservation Commission
303/894-2100
OSHA
(800) 321-6742
Local Fire Department:
911
Local Police Department:
911
Local Hospital: Rangely
970/675-8311
Local Hospital: Clagett Memorial (Rifle)
970/625-1510
Additional Company Contacts:
Corporate EHS&T Office
713/803-8358
24 -hr Products Pipeline Control Center
800/530-1050
713/759-4765
24 -hr Crude Pipeline Control Center
800/220-1058
Cleanup Contractors (as necessary):
Belfour Environmental (Denver)
303/425-7526
800/930-0011
(24hr)
Fremont Environmental (Denver)
303/956-8714
Jackrabbit Compressor Station
A-2 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Appendix A
Submittal of Information to Regional Administrator for Qualified Discharge(s)
In the event of a qualified discharge or discharges, this page can be utilized to provide official
notification to the Regional Administrator. If the Facility has had a discharge or discharges, which
meet one of the following two criteria, then this report or a report with the same required
information must be submitted to the Regional Administrator within 60 days. (Check as
appropriate.)
❑ This Facility has experienced a reportable spill as referenced in 40 CFR Part 112.1(b) of
10,000 gallons or more.
❑ This Facility has experienced two reportable spills (as referenced in 40 CFR Part 112.1(b) of
greater than 42 gallons each within a 12 -month period.
Facility Name and Location:
Facility Contact Person (Name, address / phone number):
Facility maximum storage or handling capacity:
Facility normal daily throughput:
Describe the corrective action and countermeasures taken (include description of equipment
repairs and replacements):
Describe the Facility (maps, flow diagrams and topographical maps attached as necessary):
Describe the cause of discharge (as referenced in 40 CFR Part 112.1(b)) including failure analysis
of the system is:
Describe the preventative measures taken or contemplated to be taken to minimize the possibility
of recurrence:
Other pertinent information:
• A copy of this report is also to be sent to the appropriate state agency(ies) in charge of oil
pollution control activities.
Jackrabbit Compressor Station
A-3 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Appendix B
APPENDIX B
Facility Container, Secondary Containment, and Spill Data
• Container and Potential Spills Table
• Secondary Containment Systems Table
• Secondary Containment Volume Calculations
Jackrabbit Compressor Station
B-1 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan
Appendix B
CONTAINER AND POTENTIAL SPILLS TABLE
Container ID
Substances Capacity
Stored (Gallons)
Most Likely Rate of Direction of
Failure Flow Flow
Containment
System(s) ID
Bulk Storage Containers (Field -Erected Tanks, Shop -Built Tanks, Buried Tanks, Drums, Totes, etc.)
TK -401
Condensate
18,900
Fitting or valve
20 qpm
Into dike
Vessel containment
TK -402
Condensate
18,900
Fitting or valve
20 gpm
Into dike
Vessel containment
TK -403
Condensate
18,900
Fitting or valve
20 gpm
Into dike
Vessel containment
TK -404
Condensate
18,900
Fitting or valve
20 gpm
Into dike
Vessel containment
TK -405
Condensate
18,900
Fitting or valve
20 gpm
Into dike
Vessel containment
TK -406
Condensate
18,900
Fitting or valve
20 gpm
Into dike
Vessel containment
TK -512
Used Lube
Oil
2,100
Fitting or valve
20 gpm
Into dike
Vessel containment
TK -513
Lube Oil
4,200
Fitting or valve
20 gpm
Into dike
Vessel containment
TK -505
Water
18,900
Fitting or valve
20 gpm
Into dike
Vessel containment
ST -1
Diesel
5,000
Fitting or valve
20 gpm
Into dike
Vessel containment
ST -2
Diesel
4,000
Fitting or valve
20 gpm
Into dike
Vessel containment
ST -3
Gasoline
500
Fitting or valve
20 gpm
Into dike
Vessel containment
Oil -Filled Equipment (Transformers, Hydraulic Systems, Flow -Through Process Vessels, etc.)
Not applicable
Loading/Unloading Racks (Fixed Racks)
Truck loading rack
Condensate
NA
Compartment,
Fitting, Valve
or Hose
300 gpm
Into
containment
Rack containment
Loading/Unloading Areas (Tank Truck Off -Loading Areas, Add'tive Tank Loading Areas, etc.)
Not applicable
Other Potential Spill Sources (Manifold/Pump Areas, Undiked Piping, Buried Piping, Sums, etc.)
Transfer pumps
Condensate
NA
Seal/ fitting failure
100 qpm
Into dike
1 Pump containment
Notes:
Jackrabbit Compressor Station
B-2 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan
Appendix B
Notes:
Jackrabbit Compressor Station
B-3 Date: February 2009
SECONDARY CONTAINMENT SYSTEMS TABLE
Containment ID
Drainage Method
Type of
Containment
Material of
Construction
Volume
(Gallons)
Condensate tanks
containment
Water evaporation
Concrete walls & floor
Concrete
TBD
Truck loading area
Water evaporation
TBD
TBD
TBD
Construction Fuel
Tanks
Water evaporation
TBD
TBD
TBD
Notes:
Jackrabbit Compressor Station
B-3 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Appendix C
APPENDIX C
Facility Location and Diagram
• Facility Location
• Facility Diagram
Jackrabbit Compressor Station
C-1 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Appendix C
Facility Location (Insert labeled Topo map)
Jackrabbit Compressor Station
C-2 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Appendix C
Facility Diagram (Insert Facility Diagram)
Jackrabbit Compressor Station
C-3 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Appendix D
APPENDIX D
Facility SPCC Inspection and Integrity Testing Program
• Facility SPCC Inspection Program
• Facility SPCC Integrity Testing Program
Jackrabbit Compressor Station
D-1 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan
Appendix D
" Inspection logs and forms used under usual and customary business practices (including daily log sheets for facility walk-
throughs) may be used in lieu of the above referenced sample logs and forms which can be found in Appendix E. Forms
that may be used include any DOT Forms that are required under O&M Manual procedures.
$ Monthly documented inspections of electrical equipment is only required if secondary containment for that instrument is
claimed to be impracticable. See Section 4.3.
Jackrabbit Compressor Station
D-2 Date: February 2009
FACILITY SPCC INSPECTION PROGRAM
Facility Component
Action
Frequency/
Circumstances
Documentation*
All Bulk Storage
Containers
Visually inspect outside of
containers for signs of deterioration
and discharges and inspect the
containers supports and
foundations
Monthly (manned facilities)
Periodic (unmanned
facilities)
Tank, Piping, and
Containment Inspection
Form
During normal Facility walk-
throughs
Only if corrective action is
necessary, use above
form
Field -Erected
Aboveground Container
Evaluate container for risk of
discharge due to brittle fracture or
other catastrophe
When container undergoes a
repair, alterations,
reconstruction, or change in
service or every 10 years
whichever is sooner
Brittle Fracture Inspection
Report provide by
inspector
Liquid Level Sensing
Devices (Overfill
Prevention)
Test for proper operation
Monthly (manned facilities)
Periodic (unmanned
facilities)
Tank, Piping, and
Containment Inspection
Form
Secondary Containment
Areas
Visually inspect for signs of
deterioration, discharges, and
accumulation of oil
Monthly (manned facilities)
Periodic (unmanned
facilities)
Tank, Piping, and
Containment Inspection
Form
During normal Facility walk-
throughs
Only if corrective action is
necessary, use above
form
Visually inspect for presence of oil
or oil sheen
Prior to each drainage event
Secondary Containment
Drainage Event Log
Truck Loading
Visually inspect lowermost drain
and all outlets of tank trucks
Prior to filling and departure
No documentation
required
Effluent Treatment
Systems
Visually inspect for possible system
upsets that could cause a discharge
During normal Facility walk-
throughs
Only if corrective action is
necessary
Aboveground Valves,
Piping, and
Appurtenances
Access general conditions of items
such as flange joints, valve and
gland bodies, piping supports,
metal surfaces, expansion joints,
catch pans, and valve locks
Annually
Facility Aboveground
Piping Inspection Form
During normal Facility walk-
throughs
Only if corrective action is
necessary, use above
form
Buried Piping
Visually inspect for signs of
deterioration
Whenever a section of
buried line is exposed
Buried Piping Inspection
Form
Electrical Equipment;
(e.g. transformers)
Visually inspect for signs of
deterioration or discharges
Monthly (manned facilities)
Periodic (unmanned
facilities)
Oil -Filled Electrical
Equipment Inspection
Form
Training
Conduct spill prevention briefings or
CBT for all oil -handling personnel
Annually
Spill Prevention Briefing
Log
" Inspection logs and forms used under usual and customary business practices (including daily log sheets for facility walk-
throughs) may be used in lieu of the above referenced sample logs and forms which can be found in Appendix E. Forms
that may be used include any DOT Forms that are required under O&M Manual procedures.
$ Monthly documented inspections of electrical equipment is only required if secondary containment for that instrument is
claimed to be impracticable. See Section 4.3.
Jackrabbit Compressor Station
D-2 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan
Appendix D
FACILITY
SPCC INTEGRITY TESTING
PROGRAM
Facility Component
Action
Frequency/
Circumstances
Procedure
Field -Erected Storage
Containers
Perform container integrity test
As required
API - 653
Non -Elevated Shop -Built
Storage Containers
Perform container integrity test
As required
STI-SP001
Elevated Shop -Built Storage
Containers
Perform container integrity test.
The Facility provides equivalent
environmental protection through
the use of frequent visual
inspections in lieu of integrity
testing. See Section 5.2.5
Monthly and during normal
Facility walk-throughs
Visual Inspection
as described in the
Facility SPCC
Inspection Program
Table, All Bulk
Storage Containers
Mobile or Portable Storage
Containers
Perform container integrity test.
The Facility provides equivalent
environmental protection through
the use of frequent visual
inspections in lieu of integrity
testing. See Section 5.2.5
Monthly and during normal
Facility walk-throughs
Visual Inspection
as described in the
Facility SPCC
Inspection Program
Table, All Bulk
Storage Containers
Completely Buried Metallic
Storage Containers
Perform leak test
RegularlyEPCO
approved
procedure
Buried Piping
Perform integrity test and leak test
At time of installation,
modifications, construction,
relocation, and/or
replacement
EPCO approved
procedure
Jackrabbit Compressor Station
D-3 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Appendix E
APPENDIX E
Sample Logs and Forms*
• Tank, Piping, and Containment Inspection Form
• Facility Aboveground Piping Inspection Form
• Oil -Filled Operation Equipment Inspection Form
• Buried Piping Inspection Form
• Secondary Containment Drainage Event Log
• Spill Prevention Briefing Log
• The above referenced Togs and forms are provided as samples. The Facility may use logs
and forms that are kept under usual and customary business practices, including any DOT
logs or forms required under O&M Manual procedures, in lieu of the above referenced logs
and forms.
Jackrabbit Compressor Station
E-1 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan
Appendix E
TANK, PIPING, AND CONTAINMENT INSPECTION FORM
Facility:
Tank (Container) ID:
Date:
Contents:
Inspector:
Capacity (gallons):
Complete all sections below for each tank covered by this SPCC P an monthly. If any of the questions below are answered "Yes" a
corrective action must be performed and documented to correct the deficiency.
Tank (Container) Inspection
Yes
No
NA
Comments/Description
Corrective Actions
TakenlDate
Exterior surface shows signs of leakage or staining.
External coating is bubbled, cracked, corroded or damaged.
Tank (container) is corroded, pitted, or damaged.
Bolts, rivets, or seams are damaged, cracked, or corroded.
Overfill protection system is not working.
Tank (container) bottoms have accumulated rust, scats,
microorganisms, or foreign material.
Vents and pressure release devices are obstructed.
External stairways/walkways are unsound or obstructed.
External stairways/walkways have low spots where water can
accumulate.
Level controls are inoperable.
Tank (container) roof drains are blocked or damaged.
Personnel are not aware of emergency procedures at site.
Associated Piping, Valves, Pumps, Gauges
Yes
No
NA
Comments/Description
Corrective Actions
Taken/Date
Equipment is not in good working condition.
Equipment is leaking.
Soil stained with product below equipment.
Associated Containment (Berm) Inspection
Yes
No
NA
Comments/Description
Corrective Actions
Taken/Date
Berm drainage valve is not closed and locked.
Berm shows indications of erosion or disrepair.
Berm has holes, cracks, or other breaches that could result in
a leak,
Vegetation with large root systems (trees, bushes) is present
in berm area.
Ramps or other structures associated with spill control are
damaged.
Berm area has accumulated water.
Sheen or oil observed on accumulated water.
Pooled oil or stained soil is present.
Drainage pipe or structures are clogged or have accumulated
debris.
Berm drainage outfall shows signs of erosion or disrepair.
Additional Remarks
Signature
Inspector or Supervisor Signature:
I Date:
I
Jackrabbit Compressor Station
E-2 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan
Appendix E
FACILITY ABOVEGROUND PIPING INSPECTION FORM
Facility:
Date:
Inspector:
Complete all sections below for Facility Aboveground Piping annually. If any of the questions below are answered "Yes" a corrective
action must be performed and documented to correct the deficiency. Retain record for three (3) years.
Facility Aboveground Piping Inspection
Yes
No
NA
Comments/Description
Corrective Actions
Taken/Date
Leaks
Existing Clamps/Sleeves I I I I I
Misalignment
Piping Misalignment/Restricted Movement
Expansion Joint Misalignment
Vibration
Excessive Overhung Weight
Inadequate Support
Thin, Small -Bore, or Alloy Piping
Threaded Connections
Loose Supports Causing Metal Wear
Supports
Shoes Off Support
Hanger Distortion or Breakage
Bottomed -Out Spring
Brace Distortion/Breakage
Loose Brackets
Slide Plates/Rollers
Counter -Balance Condition
Support Corrosion
Corrosion
Bolting Support Points Under Clamps
Coating/Painting Deterioration
Soil -to -Air Interfaces
Insulation Interfaces
Biological Growth
Corrosion Under TML Ports
Insulation
Damage/Penetrations
Missing Jacketing/Insulation
Sealing Deterioration
Bulging
Banding (broken or missing)
TML Ports (missing plugs/cover tape)
Additional Remarks
Signature
Inspector or Supervisor Signature:
Date:
Jackrabbit Compressor Station
E-3 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan
Appendix E
OIL -FILLED OPERATIONS EQUIPMENT
INSPECTION FORM
Facility:
Equipment ID:
Date:
Contents:
Inspector:
Capacity (gallons):
Complete all sections below for each tank covered by this SPCC Plan month y if some form of secondary containment is not provided. If
any of the questions below are answered "Yes" a corrective action must be performed and documented to correct the deficiency.
Oil -Filled Operational Equipment Inspection
Yes
No
NA
Comments/Description
Corrective Actions
TakenlDate
Exterior surface shows signs of leakage or
staining.
Underlying surface shows signs of leakage or
staining.
External coating is bubbled, cracked, corroded
or damaged.
Container is corroded, pitted, or damaged.
Bolts, rivets, or seams are damaged, cracked, or
corroded.
Container bottoms have accumulated rust,
scale, microorganisms, or foreign material.
Additional Remarks
Signature
Inspector or Supervisor Signature:
Date:
Jackrabbit Compressor Station E-4 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan
Appendix E
BURIED PIPING INSPECTION FORM
Facility:
Date:
Inspector:
Complete all sections below when buried piping is exposed. If any of the questions below are answered "Yes" a corrective action must be
performed and documented to correct the deficiency. Retain record for three (3) years.
General Information
Line Description:
Line Size:
Feet Excavate:
Soil Conditions:
Buried Piping Inspection
Yes
No
NA
Comments/Description
Corrective Actions
Taken/Date
Coating Conditions
Visible Damage
Poorly Bonded
Visible Discoloration
Mechanical Damage
Soil/Air Interface Damage
Insulation Conditions
Visible Damage
Mechanical Damager
Pipe Condition If Not Coated or Coating Damage/Removed
External Corrosion
Coating is Not Well Bonded
Visible Leaks
Visible Misalignment or Bending
Minor Pitting
Extensive Pitting
Pipe Casing Conditions (if applicable)
External Corrosion
Casing Not in Place
Visible Leaks
Visible Misalignment or Bending
Minor Pitting
Extensive Pitting
Additional Remarks
Signature
Inspector or Supervisor Signature:
Date:
Jackrabbit Compressor Station
E-5 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan
Appendix E
SECONDARY CONTAINMENT DRAINAGE EVENT LOG
Date
Containment
ID
Presence
of 011
(Yes/No)
Start End
Time Time
Valve
Resealed
(Yes/No)
Signature
* This form is not intended to meet the more stringent requirements of an applicable state or federal water
discharge program.
Jackrabbit Compressor Station
E-6 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan
Appendix E
Sion In:
Note: Required topics must include SPCC Plan, see Section 4.5)
SPILL PREVENTION BRIEFING LOG
DATE:
Employee ID
LOCATION:
INSTRUCTOR:
See Corporate Training Records
TOPICS:
•
'
•
•
Sion In:
Note: Required topics must include SPCC Plan, see Section 4.5)
Jackrabbit Compressor Station
E-7 Date: February 2009
Name (Please Print)
Position/Location
Employee ID
1.
2.
3.
4.
5.
6.
7.
8.
9.
10.
11.
12.
13.
14.
15.
Subject/Issue Identified
Required Action
Implementation Date:
Jackrabbit Compressor Station
E-7 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Appendix F
APPENDIX F
Oil SpiII Contingency Plan
(Insert 00 SpiII Contingency Plan as appropriate)
Jackrabbit Compressor Station
F-1 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan Appendix G
APPENDIX G
Implementation Measures Not Yet Fully Operational
Jackrabbit Compressor Station
0-1 Date: February 2009
Spill Prevention, Control, and Countermeasure Plan
Appendix G
Implementation Measures Not Yet Fully Operational
Implementation
Measure
Responsible
Party
Actions Taken
Date
Jackrabbit Compressor Station
G-2 Date: February 2009
I
Scale (miles)
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Scale (feet)
USGS 7.5 MINUTE SERIES (TOPOGRAPHIC)
Figure 1
SITE LOCATION MAP
Enterprise Gas Processing
Jackrabbit Compressor Station
Sec 33, T5S, R96W - Garfield Co, Colorado
Prepared Engr Project No.
10/13/08 C008.018
JMA
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